Abstract

A method for storing a greenhouse gas in a subterranean permeable formation positioned beneath a terranean surface and containing a native liquid includes (a) injecting a drainage fluid into the permeable formation via at least one wellbore extending from the terranean surface and penetrating the permeable formation to increase a gas saturation of the permeable formation whereby at least a portion of the injected drainage fluid is trapped within pores of the permeable formation, and (b) injecting, following (a), the greenhouse gas into the permeable formation via the at least one wellbore to store at least a portion of the greenhouse gas within the permeable formation.

IPC Classes  ?

• E21B 41/00 - Equipment or details not covered by groups
• B65G 5/00 - Storing fluids in natural or artificial cavities or chambers in the earth
• E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons

Abstract

An end effector for an automated electric vehicle charging system includes a chassis including a chassis connector for coupling the end effector to an end of a robotic arm; and a support rail unit coupled to the chassis and including an elongate support rail, a carriage slidably coupled to the support rail and including a carriage connector configured to couple to an electric distributor charging connector of the electric vehicle charging system, and a carriage actuator coupled between the support rail and the carriage for transporting the carriage along the support rail.

IPC Classes  ?

• B60L 53/16 - Connectors, e.g. plugs or sockets, specially adapted for charging electric vehicles
• B25J 15/00 - Gripping heads
• B25J 15/06 - Gripping heads with vacuum or magnetic holding means
• B60L 53/37 - Means for automatic or assisted adjustment of the relative position of charging devices and vehicles using optical position determination, e.g. using cameras

Abstract

An end effector for an automated electric vehicle charging system includes a chassis including a chassis connector for coupling the end effector to an end of a robotic arm; and a support rail unit coupled to the chassis and including an elongate support rail, a carriage slidably coupled to the support rail and including a carriage connector configured to couple to an electric distributor charging connector of the electric vehicle charging system, and a carriage actuator coupled between the support rail and the carriage for transporting the carriage along the support rail.

IPC Classes  ?

• B60L 53/37 - Means for automatic or assisted adjustment of the relative position of charging devices and vehicles using optical position determination, e.g. using cameras
• H01R 13/629 - Additional means for facilitating engagement or disengagement of coupling parts, e.g. aligning or guiding means, levers, gas pressure
• H02J 7/00 - Circuit arrangements for charging or depolarising batteries or for supplying loads from batteries

Abstract

A method for facilitating the management of one or more energy production or processing facilities includes receiving an alert corresponding to an operational anomaly associated with the process equipment, interrogating a data structure linking together and organizing a plurality of distinct data sources, selecting a subset of data sources from the plurality of data sources identified as associated with a potential cause of the alert based on the interrogation of the data structure, statistically analyzing data sourced from the selected subset of data sources, identifying the potential cause of the alert based on the statistical analysis, and recommending a corrective action to resolve the identified potential cause of the alert using the plurality of distinct data sources.

IPC Classes  ?

• H02J 3/00 - Circuit arrangements for ac mains or ac distribution networks

Abstract

In some examples, the disclosure provides a method for deploying a plurality N of seismic sensors, wherein each seismic sensor is adapted to measure seismic energy with at least one gain, within a survey area, the method comprising: obtaining a plurality M of gains from which the at least one gain may be selected; configuring the plurality N of seismic sensors such that, for each given gain of the obtained plurality M of gains, at least N/M seismic sensors are adapted to measure the seismic energy with at least one corresponding gain; and deploying the plurality N of configured seismic sensors on the survey area.

IPC Classes  ?

• G01V 1/20 - Arrangements of receiving elements, e.g. geophone pattern
• G01V 1/16 - Receiving elements for seismic signalsArrangements or adaptations of receiving elements
• G01V 1/24 - Recording seismic data
• G01V 1/30 - Analysis

Abstract

An integrated system comprising a desalination plant comprising a reverse osmosis (RO) array configured to produce an RO permeate blending stream, a blending system comprising a flow line for a fines stabilizing additive blending stream and configured to blend the RO permeate blending stream with the fines stabilizing additive blending stream to produce a blended low salinity water stream having a salinity of less than or equal to 5,000, 4,000, 3,000, 2,000, 1,000, 500, 400, or 300 ppm and a molar ratio of divalent cations to monovalent cations of greater than about 0.2, 0.3, or 0.4, a control unit configured to control operation of the blending system, and an injection system for one or more injection wells, wherein the one or more injection wells penetrate an oil-bearing layer of a reservoir. A method is also provided.

IPC Classes  ?

• C02F 1/44 - Treatment of water, waste water, or sewage by dialysis, osmosis or reverse osmosis
• C09K 8/58 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids

Abstract

The problem of lost circulation is pertinent to the oil industry. To prevent fluid loss, a lost circulation material (LCM), or more generally, a plugging material, can be used to effectively plug the fractures in the rock formation. If the fractures are in the production zone, it is also ideal to unplug them when the drilling operation is complete. Therefore, a material engineered to degrade after a desired period would be useful. In examples, a plugging material has been developed by gelling an oil-based fluid using a low molecular weight gelator, dibenzylidene sorbitol (DBS). DBS gels are robust and show plugging behavior. DBS is shown to chemically degrade in presence of an acid. Hence, a self-degrading gel can be synthesized by incorporating an acid into the system. Further, by varying the type and concentration of the acid, the degradation time of the gel can be controlled.

IPC Classes  ?

• C09K 8/42 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells
• C09K 8/03 - Specific additives for general use in well-drilling compositions
• C09K 8/035 - Organic additives
• E21B 21/00 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
• E21B 33/138 - Plastering the borehole wallInjecting into the formation

Abstract

The problem of lost circulation is pertinent to the oil industry. To prevent fluid loss, a lost circulation material (LCM), or more generally, a plugging material, can be used to effectively plug the fractures in the rock formation. If the fractures are in the production zone, it is also ideal to unplug them when the drilling operation is complete. Therefore, a material engineered to degrade after a desired period would be useful. In examples, a plugging material has been developed by gelling an oil-based fluid using a low molecular weight gelator, dibenzylidene sorbitol (DBS). DBS gels are robust and show plugging behavior. DBS is shown to chemically degrade in presence of an acid. Hence, a self-degrading gel can be synthesized by incorporating an acid into the system. Further, by varying the type and concentration of the acid, the degradation time of the gel can be controlled.

IPC Classes  ?

• C09K 8/035 - Organic additives
• C09K 8/502 - Oil-based compositions
• C09K 8/506 - Compositions based on water or polar solvents containing organic compounds

Abstract

The problem of lost circulation is pertinent to the oil industry. To prevent fluid loss, a lost circulation material (LCM), or more generally, a plugging material, can be used to effectively plug the fractures in the rock formation. If the fractures are in the production zone, it is also ideal to unplug them when the drilling operation is complete. Therefore, a material engineered to degrade after a desired period would be useful. In examples, a plugging material has been developed by gelling an oil-based fluid using a low molecular weight gelator, dibenzylidene sorbitol (DBS). DBS gels are robust and show plugging behavior. DBS is shown to chemically degrade in presence of an acid. Hence, a self-degrading gel can be synthesized by incorporating an acid into the system. Further, by varying the type and concentration of the acid, the degradation time of the gel can be controlled.

IPC Classes  ?

• C09K 8/035 - Organic additives
• C09K 8/502 - Oil-based compositions
• C09K 8/506 - Compositions based on water or polar solvents containing organic compounds

Abstract

A method of identifying events within a wellbore comprises obtaining a first set of measurements of a first signal within a wellbore, identifying one or more events within the wellbore using the first set of measurements, obtaining a second set of measurements of a second signal within the wellbore, wherein the first signal and the second signal represent different physical measurements, training one or more event models using the second set of measurements and the identification of the one or more events as inputs, and using the one or more event models to identify at least one additional event within the wellbore.

IPC Classes  ?

• G06N 5/04 - Inference or reasoning models
• E21B 47/00 - Survey of boreholes or wells
• G06N 20/00 - Machine learning

Abstract

In some examples, the disclosure provides a method for determining a drift in clock data that is provided by a clock of a seismic sensor. The sensor is exposed to an ambient temperature that varies over time. The method includes obtaining temperature data associated with the ambient temperature as a function of time. The method also includes obtaining the clock data. The method also includes obtaining timestamp data provided by a global navigation satellite system. The method also includes determining drift data which minimizes a difference of a temporal drift in the clock data, based on the timestamp data and the temperature data. The method also includes outputting corrective data based on the determined drift data.

IPC Classes  ?

• G06F 1/00 - Details not covered by groups and
• G06F 1/12 - Synchronisation of different clock signals
• G06F 1/14 - Time supervision arrangements, e.g. real time clock
• G06F 1/10 - Distribution of clock signals

Abstract

An offshore node deployment system includes a control system, a surface vessel including a deck, and a propulsion system in signal communication with the control system, a node storage container supported by the deck of the surface vessel, wherein the node storage container is configured to store a plurality of nodes which are physically disconnected from each other, and a node deployment system supported by the deck of the surface vessel and controllable by the control system, wherein the node deployment system is configured to retrieve the nodes from the node storage container and deploy the nodes to a subsea location.

IPC Classes  ?

• B63G 8/00 - Underwater vessels, e.g. submarines
• G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas

Abstract

An offshore node deployment system includes a control system, a surface vessel including a deck, and a propulsion system in signal communication with the control system, a node storage container supported by the deck of the surface vessel, wherein the node storage container is configured to store a plurality of nodes which are physically disconnected from each other, and a node deployment system supported by the deck of the surface vessel and controllable by the control system, wherein the node deployment system is configured to retrieve the nodes from the node storage container and deploy the nodes to a subsea location.

IPC Classes  ?

• B63B 27/22 - Arrangement of ship-based loading or unloading equipment for cargo or passengers of conveyors, e.g. of endless-belt or screw-type
• B63G 8/00 - Underwater vessels, e.g. submarines
• G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas

Abstract

An offshore node deployment system includes a control system, a surface vessel including a deck, and a propulsion system in signal communication with the control system, a node storage container supported by the deck of the surface vessel, wherein the node storage container is configured to store a plurality of nodes which are physically disconnected from each other, and a node deployment system supported by the deck of the surface vessel and controllable by the control system, wherein the node deployment system is configured to retrieve the nodes from the node storage container and deploy the nodes to a subsea location.

IPC Classes  ?

• G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
• B63B 27/22 - Arrangement of ship-based loading or unloading equipment for cargo or passengers of conveyors, e.g. of endless-belt or screw-type
• B63G 8/00 - Underwater vessels, e.g. submarines

Abstract

A method of identifying events includes obtaining an acoustic signal from a sensor, determining one or more frequency domain features from the acoustic signal, providing the one or more frequency domain features as inputs to a plurality of event detection models, and determining the presence of one or more events using the plurality of event detection models. The one or more frequency domain features are obtained across a frequency range of the acoustic signal, and at least two of the plurality of event detection models are different.

IPC Classes  ?

• G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
• E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
• G01V 99/00 - Subject matter not provided for in other groups of this subclass

Abstract

Systems and methods are disclosed for managing skin in a subterranean wellbore. In an embodiment, the method includes oscillating a drawdown pressure of the subterranean wellbore in a predetermined pattern that comprises a plurality of alternating drawdown pressure increases and drawdown pressure decreases. The drawdown pressure increases of the predetermined pattern comprise increasing the drawdown pressure at a first rate, and the drawdown pressure decreases of the predetermined pattern comprise decreasing the drawdown pressure at a second rate that is different from the first rate.

IPC Classes  ?

• E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
• E21B 43/14 - Obtaining from a multiple-zone well

Abstract

A method for facilitating the management of one or more energy production or processing facilities includes receiving an alert corresponding to an operational anomaly associated with the process equipment, interrogating a data structure linking together and organizing a plurality of distinct data sources, selecting a subset of data sources from the plurality of data sources identified as associated with a potential cause of the alert based on the interrogation of the data structure, statistically analyzing data sourced from the selected subset of data sources, identifying the potential cause of the alert based on the statistical analysis, and recommending a corrective action to resolve the identified potential cause of the alert using the plurality of distinct data sources.

IPC Classes  ?

• G05B 23/02 - Electric testing or monitoring

Abstract

Example sensor assemblies, seismic sensor incorporating the sensor assemblies, and methods relating thereto are disclosed. In an embodiment, the sensor assembly includes an electrically conductive outer housing, and an electrically insulating holder disposed within the outer housing. The holder comprises a recess. In addition, the sensor assembly includes a sensor element disposed within the recess of the holder. The sensor element is electrically insulated from outer housing by the holder.

IPC Classes  ?

• G01V 1/18 - Receiving elements, e.g. seismometer, geophone
• G01V 1/16 - Receiving elements for seismic signalsArrangements or adaptations of receiving elements
• G01V 13/00 - Manufacturing, calibrating, cleaning, or repairing instruments or devices covered by groups

Abstract

A method of cementing a wellbore includes injecting into the wellbore a non-aqueous fluid; injecting into the wellbore a cement slurry and a non-ionic surfactant composition after injecting the non-aqueous fluid; and allowing the cement slurry to set, wherein the non-ionic surfactant composition comprises an alkyl end-capped ethoxylated fatty alcohol, a chain extended non-ionic surfactant, or a combination comprising at least one of the foregoing.

IPC Classes  ?

• C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
• C09K 8/487 - Fluid loss control additivesAdditives for reducing or preventing circulation loss
• E21B 33/138 - Plastering the borehole wallInjecting into the formation
• E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
• E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices or the like

Abstract

A desalination system includes a desalination platform, a first skid disposed on a first deck of the desalination platform, the first skid including at least one of a first filtration unit configured to produce a first filtrate stream, and a first permeate unit configured to produce a first permeate stream, a first interconnecting pipework coupled to the first skid, and a first pipework support disposed on the first deck, wherein the first interconnecting pipework is disposed on the first pipework support.

IPC Classes  ?

• B01D 61/58 - Multistep processes
• B01D 61/02 - Reverse osmosisHyperfiltration
• B01D 61/10 - AccessoriesAuxiliary operations
• B01D 61/14 - UltrafiltrationMicrofiltration
• B01D 61/18 - Apparatus therefor
• C02F 1/44 - Treatment of water, waste water, or sewage by dialysis, osmosis or reverse osmosis
• E21B 43/40 - Separation associated with re-injection of separated materials
• C02F 103/08 - Seawater, e.g. for desalination

Abstract

A method of identifying inflow locations along a wellbore comprises obtaining an acoustic signal from a sensor within the wellbore, determining a plurality of frequency domain features from the acoustic signal, and identifying, using a plurality of fluid flow models, a presence of at least one of a gas phase inflow, an aqueous phase inflow, or a hydrocarbon liquid phase inflow at one or more fluid flow locations. The acoustic signal comprises acoustic samples across a portion of a depth of the wellbore, and the plurality of frequency domain features are obtained across a plurality of depth intervals within the portion of the depth of the wellbore. Each fluid flow model of the plurality of fluid inflow models uses one or more frequency domain features of the plurality of the frequency domain features, and at least two of the plurality of fluid flow models are different.

IPC Classes  ?

• G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
• G01V 1/50 - Analysing data
• G01V 1/30 - Analysis
• G01V 1/00 - SeismologySeismic or acoustic prospecting or detecting
• E21B 47/14 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
• E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
• G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]

Abstract

A monitoring system includes a flow line, an optical fiber coupled to the flow line, and a receiver coupled to an end of the optical fiber. The receiver is configured to detect at least one acoustic signal from the optical fiber. In addition, the monitoring system includes processor unit to detect a flow obstruction within the flow line based on the acoustic signal.

IPC Classes  ?

• E21B 47/095 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes by detecting acoustic anomalies, e.g. using mud-pressure pulses
• E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means

Abstract

A control system configured to control operation of reverse osmosis (RO) array(s), nanofiltration (NF) array(s) and/or a blending system including a control panel (CP), regulatory controllers (RCs), and a supervisory controller (SC), wherein the SC is in signal communication with the CP, and with the RCs, wherein the SC is configured to: receive user inputs from the CP, and receive inputs from RCs regarding data from sensors, wherein the RCs are in signal communication with the plurality of sensors, wherein the RCs are configured to: receive data from the sensors, provide outputs to and receive permissions from the SC, and instruct devices in response to the received permissions from the SC, and wherein the SC is configured to: monitor trends in the inputs regarding and/or predict outcomes from data received from the RCs and determine the permissions for RCs based on the monitored trends and/or user inputs from the CP.

IPC Classes  ?

• C02F 1/00 - Treatment of water, waste water, or sewage
• C02F 1/44 - Treatment of water, waste water, or sewage by dialysis, osmosis or reverse osmosis
• B01D 61/02 - Reverse osmosisHyperfiltration
• B01D 61/12 - Controlling or regulating
• B01F 3/08 - Mixing, e.g. dispersing, emulsifying, according to the phases to be mixed liquids with liquids; Emulsifying
• B01F 15/04 - Forming a predetermined ratio of the substances to be mixed

Abstract

A method of dynamically allocating a total amount of produced water (PW) from a reservoir during enhanced oil recovery (EOR) via a low salinity or softened water EOR flood by receiving measurement data; receiving reservoir configuration information comprising: an EOR injection rate associated with one or more EOR injection zones, a disposal zone injection rate associated with one or more disposal injection zones, and a non-reinjection disposal rate associated with one or more non-reinjection disposal routes; determining a blending rate comprising at least a portion of the PW production rate and at least a portion of the low salinity or softened water injection rate to provide a blended injection fluid; blending at least a portion of the PW with at least a portion of the low salinity or softened water at the blending rate; and dynamically allocating the PW production rate among injection and/or non-reinjection routes.

IPC Classes  ?

• E21B 43/38 - Arrangements for separating materials produced by the well in the well
• E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
• E21B 43/20 - Displacing by water
• G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction

Abstract

A process for use in managing a hydrocarbon production system includes: selecting, from among a plurality of changes proposed to operating parameters of the hydrocarbon production system, the proposed change with the greatest estimated positive change in production; assessing whether the selected change violates an operating constraint; based on said assessment, producing a valid change based on at least the selected change or identifying the selected change as an unusable change, iterating the above steps, the iteration excluding the valid change from the plurality of proposed changes; and implementing at least one valid change, the number of implemented valid changes being less than the number of proposed changes.

IPC Classes  ?

• E21B 41/00 - Equipment or details not covered by groups
• E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
• G05B 19/04 - Programme control other than numerical control, i.e. in sequence controllers or logic controllers
• G06G 7/48 - Analogue computers for specific processes, systems, or devices, e.g. simulators

Abstract

A predictive system for monitoring fouling of membranes of a desalination or water softening plant includes ultrafiltration (UF) membranes, reverse osmosis (RO) membranes, and/or nanofiltration (NF) membranes. In addition, the system includes one or more UF skids including a plurality of UF units. Each UF unit contains therein a plurality of UF membranes. Further, the system includes one or more RO/NF skids including one or more RO/NF arrays. Each of the one or more RO/NF arrays includes a plurality of RO units, with each RO unit containing therein a plurality of RO membranes, a plurality of NF units, with each NF unit containing therein a plurality of NF membranes, or a combination thereof. Still further, the system includes UF sensors and/or RO/NF sensors. The system also includes a controller comprising a processor in signal communication with the UF sensors and/or the RO/NF sensors.

IPC Classes  ?

• C02F 1/00 - Treatment of water, waste water, or sewage
• B01D 61/02 - Reverse osmosisHyperfiltration
• B01D 61/12 - Controlling or regulating
• B01D 61/14 - UltrafiltrationMicrofiltration
• B01D 61/22 - Controlling or regulating
• B01D 65/02 - Membrane cleaning or sterilisation
• C02F 9/00 - Multistage treatment of water, waste water or sewage
• C02F 5/00 - Softening waterPreventing scaleAdding scale preventatives or scale removers to water, e.g. adding sequestering agents
• B01D 61/58 - Multistep processes
• C02F 1/44 - Treatment of water, waste water, or sewage by dialysis, osmosis or reverse osmosis
• C02F 103/08 - Seawater, e.g. for desalination

Abstract

An integrated system includes a desalination plant including a reverse osmosis (RO) array to produce an RO permeate blending stream and a nanofiltration (NF) array to produce an NF permeate blending stream. The integrated system also includes a blending system. Further, the integrated system includes a control unit. Still further, the integrated system includes an injection system for one or more injection wells that penetrate an oil-bearing layer of a reservoir. Moreover, the integrated system includes a production facility to separate fluids produced from one or more production wells that penetrate the oil-bearing layer of the reservoir and to deliver a produced water (PW) stream to the blending system. The blending system is configured to blend the RO permeate and NF permeate blending streams with the PW stream to produce a blended low salinity water stream. The control unit is configured to dynamically alter operation of the blending system to adjust amounts of at least one of the RO permeate blending stream and the NF permeate blending stream to maintain a composition of the blended low salinity water stream within a predetermined operating envelope.

IPC Classes  ?

• C02F 1/00 - Treatment of water, waste water, or sewage
• B01D 61/02 - Reverse osmosisHyperfiltration
• B01D 61/08 - Apparatus therefor
• B01D 61/12 - Controlling or regulating
• C02F 1/44 - Treatment of water, waste water, or sewage by dialysis, osmosis or reverse osmosis
• C09K 8/58 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
• E21B 43/20 - Displacing by water
• E21B 43/40 - Separation associated with re-injection of separated materials
• B01F 23/40 - Mixing liquids with liquidsEmulsifying
• B01F 35/22 - Control or regulation
• B01F 35/21 - Measuring
• C02F 103/08 - Seawater, e.g. for desalination
• C02F 103/10 - Nature of the water, waste water, sewage or sludge to be treated from quarries or from mining activities
• B01F 101/49 - Mixing drilled material or ingredients for well-drilling, earth-drilling or deep-drilling compositions with liquids to obtain slurries

Abstract

Spacer-i, is in the range of 0.0001 to 0.1000 of the swept pore volume, PVR, of the layer(s) of reservoir rock. The total injected pore volume of the slugs of aqueous spacer fluid is in the range of 0.9000000 to 0.9999999 of the swept pore volume, PVR, of the layer(s) of reservoir rock. The reservoir rock has a dispersivity, α, in the range of 1 to 30% of the interwell distance between the injection well and production well. The amount of additive delivered to the layer(s) of reservoir rock by the plurality of slugs of aqueous displacement fluid is equal to or greater than a predetermined minimum additive quantity (MAQ).

IPC Classes  ?

• E21B 43/20 - Displacing by water
• C09K 8/584 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific surfactants
• C09K 8/40 - Spacer compositions, e.g. compositions used to separate well-drilling from cementing masses

Abstract

In some examples, the disclosure provides a method for determining a drift in clock data that is provided by a clock of a seismic sensor. The sensor is exposed to an ambient temperature that varies over time. The method includes obtaining temperature data associated with the ambient temperature as a function of time. The method also includes obtaining the clock data. The method also includes obtaining timestamp data provided by a global navigation satellite system. The method also includes determining drift data which minimizes a difference of a temporal drift in the clock data, based on the timestamp data and the temperature data. The method also includes outputting corrective data based on the determined drift data.

IPC Classes  ?

• G01V 1/24 - Recording seismic data
• G01V 13/00 - Manufacturing, calibrating, cleaning, or repairing instruments or devices covered by groups

Abstract

In some examples, the disclosure provides a method for deploying a plurality N of seismic sensors, wherein each seismic sensor is adapted to measure seismic energy with at least one gain, within a survey area, the method comprising: obtaining a plurality M of gains from which the at least one gain may be selected; configuring the plurality N of seismic sensors such that, for each given gain of the obtained plurality M of gains, at least N/M seismic sensors are adapted to measure the seismic energy with at least one corresponding gain; and deploying the plurality N of configured seismic sensors on the survey area.

IPC Classes  ?

• G01V 1/20 - Arrangements of receiving elements, e.g. geophone pattern
• G01V 1/24 - Recording seismic data

Abstract

An integrated system comprising a desalination plant comprising a reverse osmosis (RO) array configured to produce an RO permeate blending stream, a blending system comprising a flow line for a fines stabilizing additive blending stream and configured to blend the RO permeate blending stream with the fines stabilizing additive blending stream to produce a blended low salinity water stream having a salinity of less than or equal to 5,000, 4,000, 3,000, 2,000, 1,000, 500, 400, or 300 ppm and a molar ratio of divalent cations to monovalent cations of greater than about 0.2, 0.3, or 0.4, a control unit configured to control operation of the blending system, and an injection system for one or more injection wells, wherein the one or more injection wells penetrate an oil-bearing layer of a reservoir. A method is also provided.

IPC Classes  ?

• C02F 1/44 - Treatment of water, waste water, or sewage by dialysis, osmosis or reverse osmosis
• B01D 61/02 - Reverse osmosisHyperfiltration
• B01D 61/12 - Controlling or regulating
• C02F 103/08 - Seawater, e.g. for desalination
• C02F 103/10 - Nature of the water, waste water, sewage or sludge to be treated from quarries or from mining activities

Abstract

In some examples, the disclosure provides a method for determining a drift in clock data that is provided by a clock of a seismic sensor. The sensor is exposed to an ambient temperature that varies over time. The method includes obtaining temperature data associated with the ambient temperature as a function of time. The method also includes obtaining the clock data. The method also includes obtaining timestamp data provided by a global navigation satellite system. The method also includes determining drift data which minimizes a difference of a temporal drift in the clock data, based on the timestamp data and the temperature data. The method also includes outputting corrective data based on the determined drift data.

IPC Classes  ?

• G01V 1/24 - Recording seismic data
• G01V 13/00 - Manufacturing, calibrating, cleaning, or repairing instruments or devices covered by groups

Abstract

An integrated system comprising a desalination plant comprising a reverse osmosis (RO) array configured to produce an RO permeate blending stream, a blending system comprising a flow line for a fines stabilizing additive blending stream and configured to blend the RO permeate blending stream with the fines stabilizing additive blending stream to produce a blended low salinity water stream having a salinity of less than or equal to 5,000, 4,000, 3,000, 2,000, 1,000, 500, 400, or 300 ppm and a molar ratio of divalent cations to monovalent cations of greater than about 0.2, 0.3, or 0.4, a control unit configured to control operation of the blending system, and an injection system for one or more injection wells, wherein the one or more injection wells penetrate an oil-bearing layer of a reservoir. A method is also provided.

IPC Classes  ?

• B01D 61/02 - Reverse osmosisHyperfiltration
• B01D 61/12 - Controlling or regulating
• C02F 1/44 - Treatment of water, waste water, or sewage by dialysis, osmosis or reverse osmosis

Abstract

In some examples, the disclosure provides a method for deploying a plurality N of seismic sensors, wherein each seismic sensor is adapted to measure seismic energy with at least one gain, within a survey area, the method comprising: obtaining a plurality M of gains from which the at least one gain may be selected; configuring the plurality N of seismic sensors such that, for each given gain of the obtained plurality M of gains, at least N/M seismic sensors are adapted to measure the seismic energy with at least one corresponding gain; and deploying the plurality N of configured seismic sensors on the survey area.

IPC Classes  ?

• G01V 1/20 - Arrangements of receiving elements, e.g. geophone pattern
• G01V 1/24 - Recording seismic data

Abstract

A method of calibrating a distributed acoustic sensor (DAS) system includes obtaining a backscattered optical signal from a fiber optic cable disposed within a wellbore, determining an origination point within the backscattered optical signal, determining a bottom point within the backscattered optical signal, correlating the origination point and the bottom point with physical depth information for the wellbore, and determining at least a depth calibration for the backscattered optical signal using the correlating. The backscattered optical signal is representative of an acoustic or thermal signal along the fiber optic cable. The origination point identifies a first location at an upper point of the fiber optic cable within the backscattered optical signal, and the bottom point identifies a second location at a lower point of the fiber optic cable within the wellbore. The depth calibration correlates a sensed depth within the backscattered optical signal with a physical depth within the wellbore.

IPC Classes  ?

• E21B 47/04 - Measuring depth or liquid level
• E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling

Abstract

A method of characterizing an inflow into a wellbore comprises obtaining an acoustic signal from a sensor within the wellbore, determining a plurality of frequency domain features from the acoustic signal, identifying at least one of a gas phase flow, an aqueous phase flow, or a hydrocarbon liquid phase flow using the plurality of the frequency domain features, and classifying a flow rate of the at least one of the gas phase flow, the aqueous phase flow, or the hydrocarbon liquid phase flow using the plurality of frequency domain features. The acoustic signal comprises acoustic samples across a portion of a depth of the wellbore.

IPC Classes  ?

• G01F 1/66 - Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by measuring frequency, phase shift or propagation time of electromagnetic or other waves, e.g. using ultrasonic flowmeters
• G01H 9/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means
• G01P 5/24 - Measuring speed of fluids, e.g. of air streamMeasuring speed of bodies relative to fluids, e.g. of ship, of aircraft by measuring the direct influence of the streaming fluid on the properties of a detecting acoustical wave
• G01V 1/50 - Analysing data

Abstract

Systems and methods are disclosed for managing skin in a subterranean wellbore. In an embodiment, the method includes oscillating a drawdown pressure of the subterranean wellbore in a predetermined pattern that comprises a plurality of alternating drawdown pressure increases and drawdown pressure decreases. The drawdown pressure increases of the predetermined pattern comprise increasing the drawdown pressure at a first rate, and the drawdown pressure decreases of the predetermined pattern comprise decreasing the drawdown pressure at a second rate that is different from the first rate.

IPC Classes  ?

• E21B 43/00 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells

Abstract

A method of abandoning a wellbore can include obtaining a first sample data set within a wellbore, wherein the first sample data set is a sample of an acoustic signal originating within the wellbore; determining a plurality of frequency domain features of the first sample data set; identifying a fluid flow location within the wellbore using the first plurality of frequency domain features; setting a barrier (130A, 131A, 130B, 131B, 130C) at or above the fluid flow location; obtaining a second sample data set above the barrier, wherein the second sample data set is a sample of an acoustic signal originating within the wellbore above the barrier; determining a second plurality of frequency domain features of the second sample data set; and identifying that a fluid flow rate or flow mechanism at the fluid flow location has been reduced or eliminated and/or identifying another fluid flow location using the second plurality of frequency domain features.

IPC Classes  ?

• E21B 47/10 - Locating fluid leaks, intrusions or movements

Abstract

Example seismic sensors and methods relating thereto are disclosed. In an embodiment, the seismic sensor includes an outer housing and a proof mass disposed in the inner cavity of the outer housing. In addition, the seismic sensor includes a first biasing member positioned in the inner cavity between the proof mass and an outer housing upper end that is configured to flex in response to axial movement of the outer housing relative to the proof mass. Further, the seismic sensor includes a second biasing member positioned in the inner cavity between the first biasing member and the outer housing upper end. Still further, the seismic sensor includes a sensor element positioned in the inner cavity between the proof mass and an outer housing lower end that is configured to generate a potential in response to movement of the outer housing relative to the proof mass.

IPC Classes  ?

• G01V 1/16 - Receiving elements for seismic signalsArrangements or adaptations of receiving elements
• G01V 1/18 - Receiving elements, e.g. seismometer, geophone

Abstract

Example sensor assemblies, seismic sensor incorporating the sensor assemblies, and methods relating thereto are disclosed. In an embodiment, the sensor assembly includes an electrically conductive outer housing, and an electrically insulating holder disposed within the outer housing. The holder comprises a recess. In addition, the sensor assembly includes a sensor element disposed within the recess of the holder. The sensor element is electrically insulated from outer housing by the holder.

IPC Classes  ?

• G01V 1/18 - Receiving elements, e.g. seismometer, geophone

Abstract

A method of cementing a wellbore includes injecting into the wellbore a non-aqueous fluid; injecting into the wellbore a cement slurry and a non-ionic surfactant composition after injecting the non-aqueous fluid; and allowing the cement slurry to set, wherein the non-ionic surfactant composition comprises an alkyl end-capped ethoxylated fatty alcohol, a chain extended non-ionic surfactant, or a combination comprising at least one of the foregoing.

IPC Classes  ?

• E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices or the like
• C09K 8/487 - Fluid loss control additivesAdditives for reducing or preventing circulation loss
• E21B 33/138 - Plastering the borehole wallInjecting into the formation
• E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
• C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes

Abstract

A method of cementing a wellbore includes injecting into the wellbore a non-aqueous fluid; injecting into the wellbore a cement slurry and a non-ionic surfactant composition after injecting the non-aqueous fluid; and allowing the cement slurry to set, wherein the non-ionic surfactant composition comprises an alkyl end-capped ethoxylated fatty alcohol, a chain extended non-ionic surfactant, or a combination comprising at least one of the foregoing.

IPC Classes  ?

• E21B 33/138 - Plastering the borehole wallInjecting into the formation
• E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
• E21B 43/26 - Methods for stimulating production by forming crevices or fractures
• C09K 8/44 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing organic binders only

Abstract

A monitoring system (100), comprising a flow line (114) comprising at least one bend (120), an optical fiber (116) coupled to an exterior of the flow line, wherein the optical fiber is wrapped around at least a portion of the flow line, and a receiver (164) coupled to an end of the optical fiber, wherein the receiver is configured to detect at least one acoustic signal from the optical fiber.

IPC Classes  ?

• E21B 47/10 - Locating fluid leaks, intrusions or movements
• E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
• E21B 41/00 - Equipment or details not covered by groups

Abstract

A system for processing acoustic data to identify an event includes a receiver unit including a processor and a memory. The receiver unit is configured to receive a signal from a sensor disposed along a sensor path or across a sensor area. A processing application is stored in the memory. The processing application, when executed on the processor, configures the processor to: receive the signal from the sensor, where the signal includes an indication of an acoustic signal received at one or more lengths along the sensor path or across a portion of the sensor area and the signal is indicative of the acoustic signal across a frequency spectrum; determine a plurality of frequency domain features of the signal across the frequency spectrum; and generate an output comprising the plurality of frequency domain features.

IPC Classes  ?

• G01N 29/44 - Processing the detected response signal
• G01H 9/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means
• G01M 3/24 - Investigating fluid tightness of structures by using fluid or vacuum by detecting the presence of fluid at the leakage point using infrasonic, sonic, or ultrasonic vibrations
• G01N 29/46 - Processing the detected response signal by spectral analysis, e.g. Fourier analysis
• G01W 1/00 - Meteorology

Abstract

a desalination plant including a reverse osmosis (RO) array to produce an RO permeate blending stream and a nanofiltration (NF) array to produce an NF permeate blending stream. an injection system for an injection well that penetrates an oil-bearing layer of a reservoir. The blending system is to blend the RO permeate blending stream and the NF permeate blending stream to produce a blended injection water stream. The control unit is to dynamically alter operation of the blending system to adjust amounts of at least one of the RO permeate blending stream and the NF permeate blending stream to alter the composition of the blended injection water stream from an initial composition to a target composition.

IPC Classes  ?

• E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
• E21B 43/20 - Displacing by water
• E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
• C02F 1/44 - Treatment of water, waste water, or sewage by dialysis, osmosis or reverse osmosis
• B01D 61/12 - Controlling or regulating
• B01D 61/58 - Multistep processes
• B01D 61/02 - Reverse osmosisHyperfiltration
• C09K 8/02 - Well-drilling compositions
• C02F 103/08 - Seawater, e.g. for desalination

Abstract

A method for analysing a crude oil to determine the amount of organic acid compounds contained in the crude oil includes extracting the organic acid compounds from a sample of crude oil to form an extract and determining the amount of the extracted organic acids In addition, the method includes dissolving the extract in a polar solvent to form a solution of the extracted organic acid compounds Further, the method includes introducing a sample of the solution of the extracted organic acid to an apparatus including a reversed phase liquid chromatography (LC) column and a mass spectrometer (MS) arranged in series. The reversed phase LC column contains a hydrophobic sorbent and the mobile phase for the LC column includes a polar organic solvent. Still further, the method includes separating the organic acid compounds in the LC column of the LC-MS apparatus and continuously passing the separated organic acid compounds from the LC column to the MS of the LC-MS apparatus to ionize the organic acid compounds and to obtain a chromatogram with mass spectral data over time for the ionized organic acid compounds. Moreover, the method includes determining the area(s) under the peak(s) in an extracted ion chromatogram derived from the mass spectral data assigned to one or more organic acid compounds. The method also includes determining the amount of the organic acid compound(s) in the sample by comparing the area under the peak(s) assigned to the organic acid compound(s) with the area under a peak in an extracted ion chromatogram assigned to a specific amount of a standard organic acid compound. In addition, the method includes extrapolating from the amount of the organic acid compound(s) in the sample to provide the total amount of the organic acid compound(s) in the extract.

IPC Classes  ?

• G01N 30/72 - Mass spectrometers
• G01N 33/28 - Oils
• G01N 1/38 - Diluting, dispersing or mixing samples
• B01J 20/281 - Sorbents specially adapted for preparative, analytical or investigative chromatography
• G01N 30/86 - Signal analysis
• G01N 30/00 - Investigating or analysing materials by separation into components using adsorption, absorption or similar phenomena or using ion-exchange, e.g. chromatography

Abstract

A method includes producing a first blended low salinity injection water for injection into at least one injection well that penetrates a first region of an oil-bearing reservoir and producing a second blended low salinity injection water for injection into at least one injection well that penetrates a second region of an oil-bearing reservoir. The reservoir rock of the first and second regions has first and second rock compositions, respectively, that present different risks of formation damage. The first and second blended low salinity injection waters comprise variable amounts of nanofiltration permeate and reverse osmosis permeate. The compositions of the first and second blended low salinity injection waters are maintained within first and second predetermined operating envelopes, respectively, that balance improving enhanced oil recovery from the first and second regions while reducing formation damage upon injecting the first and second blended low salinity injection waters into the oil-bearing reservoir.

IPC Classes  ?

• B01D 61/02 - Reverse osmosisHyperfiltration
• B01D 61/08 - Apparatus therefor
• B01D 61/12 - Controlling or regulating
• B01F 23/40 - Mixing liquids with liquidsEmulsifying
• C02F 1/44 - Treatment of water, waste water, or sewage by dialysis, osmosis or reverse osmosis
• C02F 1/68 - Treatment of water, waste water, or sewage by addition of specified substances, e.g. trace elements, for ameliorating potable water
• C09K 8/58 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
• E21B 43/20 - Displacing by water
• B01F 35/82 - Forming a predetermined ratio of the substances to be mixed by adding a material to be mixed to a mixture in response to a detected feature, e.g. density, radioactivity, consumed power or colour
• B01F 101/49 - Mixing drilled material or ingredients for well-drilling, earth-drilling or deep-drilling compositions with liquids to obtain slurries
• C02F 103/08 - Seawater, e.g. for desalination
• C02F 103/10 - Nature of the water, waste water, sewage or sludge to be treated from quarries or from mining activities

Abstract

A method of detecting sand ingress within a wellbore includes obtaining a sample data set, determining a plurality of frequency domain features of the sample data set over a plurality of depth ranges, determining a presence of sand ingress at a first depth range of the plurality of depth ranges within the wellbore based on determining that the plurality of frequency domain features over the first depth range match a sand ingress signature, and determining a presence of sand migration along a second depth range of the plurality of depths within the wellbore based on determining that the plurality of frequency domain features over the second depth range match a sand migration signature. The sample data set is a sample of an acoustic signal originating within a wellbore including a fluid. The sample data set is representative of the acoustic signal across a frequency spectrum.

IPC Classes  ?

• E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
• E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
• E21B 47/135 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range using light waves, e.g. infrared or ultraviolet waves
• G01H 3/04 - Frequency
• G01H 9/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means

Abstract

A method of detecting an event by: obtaining a first sample data set; determining a frequency domain feature(s) of the first sample data set over a first time period; determining a first threshold for the a frequency domain feature(s) using the first sample data set; determining that the frequency domain feature(s) matches the first threshold; determining the presence of an event during the first time period based on determining that the frequency domain feature(s) matches the first threshold; obtaining a second sample data set; determining a frequency domain feature(s) of the second sample data set over a second time period; determining a second threshold for the frequency domain feature(s) using the second sample data set; determining that the frequency domain feature(s) matches the second threshold; and determining the presence of the event during the second time period based on determining that the frequency domain feature(s) matches the second threshold.

IPC Classes  ?

• E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
• G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
• G01V 1/22 - Transmitting seismic signals to recording or processing apparatus
• G01V 13/00 - Manufacturing, calibrating, cleaning, or repairing instruments or devices covered by groups

Abstract

A scale inhibition fluid for use in a wellbore comprises a layered double hydroxide (LDH) having a scale inhibitor (SI) intercalated between positively-charged layers thereof. Also disclosed is a scale treatment fluid comprising such an LDH and SI and methods of making and using same. The material can be formed prior to use in a wellbore, formed during a treatment, formed within the wellbore, or the LDH can be recharged within a wellbore by injecting a SI after the material has been in place within the wellbore, or any combination thereof.

IPC Classes  ?

• C09K 8/528 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates
• C09K 8/536 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning characterised by their form or by the form of their components, e.g. encapsulated material
• C01F 7/00 - Compounds of aluminium

Abstract

A method of detecting an event by: obtaining a first sample data set; determining a frequency domain feature(s) of the first sample data set over a first time period; determining a first threshold for the a frequency domain feature(s) using the first sample data set; determining that the frequency domain feature(s) matches the first threshold; determining the presence of an event during the first time period based on determining that the frequency domain feature(s) matches the first threshold; obtaining a second sample data set; determining a frequency domain feature(s) of the second sample data set over a second time period; determining a second threshold for the frequency domain feature(s) using the second sample data set; determining that the frequency domain feature(s) matches the second threshold; and determining the presence of the event during the second time period based on determining that the frequency domain feature(s) matches the second threshold.

IPC Classes  ?

• G01H 3/04 - Frequency
• E21B 47/10 - Locating fluid leaks, intrusions or movements
• G01H 9/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means

Abstract

A method of detecting sand inflow into a wellbore is disclosed. The method can include obtaining a sample data set, detecting a broadband signal within the sample data set, comparing the broadband signal with a signal reference, determining that the broadband signal meets or exceeds the signal reference, and determining the presence of sand inflow into the wellbore based on determining that the broadband signal meets or exceeds the signal reference. The sample data set can be a sample of an acoustic signal originating within a wellbore including a fluid, and the broadband signal at least includes a portion of the sample data set at frequencies above 0.5 kHz.

IPC Classes  ?

• G01H 3/04 - Frequency
• E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
• E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
• G01V 1/22 - Transmitting seismic signals to recording or processing apparatus
• G01V 1/50 - Analysing data
• E21B 43/26 - Methods for stimulating production by forming crevices or fractures
• G01V 1/00 - SeismologySeismic or acoustic prospecting or detecting
• E21B 47/135 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range using light waves, e.g. infrared or ultraviolet waves
• G01H 9/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means
• E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices or the like
• E21B 34/06 - Valve arrangements for boreholes or wells in wells
• E21B 43/14 - Obtaining from a multiple-zone well

Abstract

A method of identifying inflow locations along a wellbore includes obtaining an acoustic signal from a sensor within the wellbore, determining a plurality of frequency domain features from the acoustic signal, and identifying, using a plurality of fluid flow models, a presence of at least one of a gas phase inflow, an aqueous phase inflow, or a hydrocarbon liquid phase inflow at one or more fluid flow locations. The acoustic signal includes acoustic samples across a portion of a depth of the wellbore, and the plurality of frequency domain features are obtained across a plurality of depth intervals within the portion of the depth of the wellbore. Each fluid flow model of the plurality of fluid inflow models uses one or more frequency domain features of the plurality of the frequency domain features, and at least two of the plurality of fluid flow models are different.

IPC Classes  ?

• E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
• E21B 47/14 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
• G01V 1/50 - Analysing data
• G06F 30/20 - Design optimisation, verification or simulation
• G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
• G01V 1/30 - Analysis
• G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
• G01V 1/00 - SeismologySeismic or acoustic prospecting or detecting
• G01V 99/00 - Subject matter not provided for in other groups of this subclass
• G06N 7/01 - Probabilistic graphical models, e.g. probabilistic networks

Abstract

A method of identifying inflow locations along a wellbore comprises obtaining an acoustic signal from a sensor within the wellbore, determining a plurality of frequency domain features from the acoustic signal, and identifying, using a plurality of fluid flow models, a presence of at least one of a gas phase inflow, an aqueous phase inflow, or a hydrocarbon liquid phase inflow at one or more fluid flow locations. The acoustic signal comprises acoustic samples across a portion of a depth of the wellbore, and the plurality of frequency domain features are obtained across a plurality of depth intervals within the portion of the depth of the wellbore. Each fluid flow model of the plurality of fluid inflow models uses one or more frequency domain features of the plurality of the frequency domain features, and at least two of the plurality of fluid flow models are different.

IPC Classes  ?

• E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
• E21B 41/00 - Equipment or details not covered by groups
• E21B 47/135 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range using light waves, e.g. infrared or ultraviolet waves

Abstract

A method of identifying events includes obtaining an acoustic signal from a sensor, determining one or more frequency domain features from the acoustic signal, providing the one or more frequency domain features as inputs to a plurality of event detection models, and determining the presence of one or more events using the plurality of event detection models. The one or more frequency domain features are obtained across a frequency range of the acoustic signal, and at least two of the plurality of event detection models are different.

IPC Classes  ?

• E21B 47/10 - Locating fluid leaks, intrusions or movements
• E21B 47/135 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range using light waves, e.g. infrared or ultraviolet waves
• E21B 47/14 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
• G01H 17/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves, not provided for in the other groups of this subclass

Abstract

A method of identifying events includes obtaining an acoustic signal from a sensor, determining one or more frequency domain features from the acoustic signal, providing the one or more frequency domain features as inputs to a plurality of event detection models, and determining the presence of one or more events using the plurality of event detection models. The one or more frequency domain features are obtained across a frequency range of the acoustic signal, and at least two of the plurality of event detection models are different.

IPC Classes  ?

• G01V 1/50 - Analysing data
• G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
• G01V 1/30 - Analysis
• E21B 47/14 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
• G06N 7/00 - Computing arrangements based on specific mathematical models

Abstract

A method of identifying events includes obtaining an acoustic signal from a sensor, determining one or more frequency domain features from the acoustic signal, providing the one or more frequency domain features as inputs to a plurality of event detection models, and determining the presence of one or more events using the plurality of event detection models. The one or more frequency domain features are obtained across a frequency range of the acoustic signal, and at least two of the plurality of event detection models are different.

IPC Classes  ?

• E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
• E21B 41/00 - Equipment or details not covered by groups
• E21B 47/135 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range using light waves, e.g. infrared or ultraviolet waves

Abstract

A desalination system includes a desalination platform, a first skid disposed on a first deck of the desalination platform, the first skid including at least one of a first filtration unit configured to produce a first filtrate stream, and a first permeate unit configured to produce a first permeate stream, a first interconnecting pipework coupled to the first skid, and a first pipework support disposed on the first deck, wherein the first interconnecting pipework is disposed on the first pipework support.

IPC Classes  ?

• B01D 61/02 - Reverse osmosisHyperfiltration
• C02F 1/44 - Treatment of water, waste water, or sewage by dialysis, osmosis or reverse osmosis
• E21B 43/20 - Displacing by water
• E21B 43/40 - Separation associated with re-injection of separated materials

Abstract

A virtual seismic shot record is generated based at least in part on seismic interferometry of the passive seismic data. Then, a frequency bandwidth of the virtual seismic shot record is determined, wherein the frequency bandwidth comprises a plurality of frequencies. The virtual seismic shot record is transformed into a frequency-dependent seismic shot record based on a first frequency of the plurality of frequencies. Further, a phase shift is applied to the frequency-dependent seismic shot record. A first velocity model is generated from the phase shifted frequency-dependent seismic shot record. A second velocity model may be generated using full-waveform inversion (FWI). One or more depth slices are identified from the second velocity model. A seismic image is generated based on the one or more depth slices for use with seismic exploration above a region of subsurface including a hydrocarbon reservoir and containing structural features conducive to a presence, migration, or accumulation of hydrocarbons.

IPC Classes  ?

• G01V 1/30 - Analysis
• G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas

Abstract

A desalination system includes a desalination platform, a first skid disposed on a first deck of the desalination platform, the first skid including at least one of a first filtration unit configured to produce a first filtrate stream, and a first permeate unit configured to produce a first permeate stream, a first interconnecting pipework coupled to the first skid, and a first pipework support disposed on the first deck, wherein the first interconnecting pipework is disposed on the first pipework support.

IPC Classes  ?

• E21B 43/20 - Displacing by water
• E21B 43/40 - Separation associated with re-injection of separated materials
• C02F 1/44 - Treatment of water, waste water, or sewage by dialysis, osmosis or reverse osmosis
• B01D 61/02 - Reverse osmosisHyperfiltration

Abstract

A virtual seismic shot record is generated based at least in part on seismic interferometry of the passive seismic data. Then, a frequency bandwidth of the virtual seismic shot record is determined, wherein the frequency bandwidth comprises a plurality of frequencies. The virtual seismic shot record is transformed into a frequency- dependent seismic shot record based on a first frequency of the plurality of frequencies. Further, a phase shift is applied to the frequency-dependent seismic shot record. A first velocity model is generated from the phase shifted frequency-dependent seismic shot record. A second velocity model may be generated using full-waveform inversion (FWI). One or more depth slices are identified from the second velocity model. A seismic image is generated based on the one or more depth slices for use with seismic exploration above a region of subsurface including a hydrocarbon reservoir and containing structural features conducive to a presence, migration, or accumulation of hydrocarbons.

IPC Classes  ?

• G01V 1/30 - Analysis
• G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas

Abstract

A virtual seismic shot record is generated based at least in part on seismic interferometry of the passive seismic data. Then, a frequency bandwidth of the virtual seismic shot record is determined, wherein the frequency bandwidth comprises a plurality of frequencies. The virtual seismic shot record is transformed into a frequency-dependent seismic shot record based on a first frequency of the plurality of frequencies. Further, a phase shift is applied to the frequency-dependent seismic shot record. A first velocity model is generated from the phase shifted frequency-dependent seismic shot record. A second velocity model may be generated using full-waveform inversion (FWI). One or more depth slices are identified from the second velocity model. A seismic image is generated based on the one or more depth slices for use with seismic exploration above a region of subsurface including a hydrocarbon reservoir and containing structural features conducive to a presence, migration, or accumulation of hydrocarbons.

IPC Classes  ?

• G01V 1/30 - Analysis
• G01V 1/32 - Transforming one recording into another
• G01V 1/34 - Displaying seismic recordings

Abstract

A method of detecting a leak event within a wellbore can include inducing a pressure differential within a wellbore comprising a fluid, obtaining a sample data set representative of the acoustic signal across a frequency spectrum while inducing the pressure differential, determining a plurality of frequency domain features of the sample data set, determining a presence of a leak event at one or more depths within the wellbore based on determining that the plurality of frequency domain features match a leak event signature, correlating the leak event with the induced pressure differential, and determining a presence and location of a leak within the wellbore based on the presence of the leak event and the correlating of the leak event with the induced pressure differential.

IPC Classes  ?

• E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
• E21B 47/117 - Detecting leaks, e.g. from tubing, by pressure testing
• G01N 29/11 - Analysing solids by measuring attenuation of acoustic waves
• G01N 29/44 - Processing the detected response signal
• G01V 1/00 - SeismologySeismic or acoustic prospecting or detecting

Abstract

A method of detecting sand inflow into a wellbore is disclosed. The method can include obtaining a sample data set, detecting a broadband signal within the sample data set, comparing the broadband signal with a signal reference, determining that the broadband signal meets or exceeds the signal reference, and determining the presence of sand inflow into the wellbore based on determining that the broadband signal meets or exceeds the signal reference. The sample data set can be a sample of an acoustic signal originating within a wellbore comprising a fluid, and the broadband signal at least includes a portion of the sample data set at frequencies above 0.5 kHz.

IPC Classes  ?

• E21B 47/10 - Locating fluid leaks, intrusions or movements
• E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
• E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
• G01V 1/22 - Transmitting seismic signals to recording or processing apparatus
• G01V 1/50 - Analysing data
• E21B 43/26 - Methods for stimulating production by forming crevices or fractures
• G01V 1/00 - SeismologySeismic or acoustic prospecting or detecting
• E21B 47/135 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range using light waves, e.g. infrared or ultraviolet waves
• G01H 3/04 - Frequency
• G01H 9/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means
• E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices or the like
• E21B 34/06 - Valve arrangements for boreholes or wells in wells
• E21B 43/14 - Obtaining from a multiple-zone well

Abstract

A desalination system includes a feed pump having an inlet side and an outlet side. In addition, the system includes a first RO stage having an inlet, RO permeate outlet and RO concentrate outlet. Further, the system includes a second RO stage having an inlet, RO permeate outlet and RO concentrate outlet and an NF stage having an inlet, NF permeate outlet and an NF concentrate outlet. The system also includes a set of conduits adapted to connect: (a) the outlet side of the feed pump to the inlet of the first RO stage; (b) the concentrate outlet of the first RO stage to (i) the inlet of the second RO stage and to the inlet of the NF stage; and (c) the permeate outlet of the first RO stage, the permeate outlet of the second RO stage and the permeate outlet of the NF stage either directly or indirectly to a low salinity water injection line.

IPC Classes  ?

• B01D 61/02 - Reverse osmosisHyperfiltration
• B01D 61/58 - Multistep processes

Abstract

A method of detecting an event within a wellbore includes obtaining a sample data set, determining a plurality of frequency domain features of the sample data set, comparing the plurality of frequency domain features with an event signature, determining that the plurality of frequency domain features matches the thresholds, ranges, or both of the event signature, and determining the presence of the event within the wellbore based on determining that the plurality of frequency domain features match the thresholds, ranges, or both of the event signature. The sample data set is a sample of an acoustic signal originating within a wellbore including a fluid. The sample data set is representative of the acoustic signal across a frequency spectrum. The event signature includes a plurality of thresholds, ranges, or both corresponding to the plurality of frequency domain features.

IPC Classes  ?

• E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
• E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
• G01V 1/22 - Transmitting seismic signals to recording or processing apparatus
• G01V 1/50 - Analysing data
• E21B 43/26 - Methods for stimulating production by forming crevices or fractures
• G01V 1/00 - SeismologySeismic or acoustic prospecting or detecting
• E21B 47/135 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range using light waves, e.g. infrared or ultraviolet waves
• G01H 3/04 - Frequency
• G01H 9/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means
• E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices or the like
• E21B 34/06 - Valve arrangements for boreholes or wells in wells
• E21B 43/14 - Obtaining from a multiple-zone well

Abstract

A control system configured to control operation of reverse osmosis (RO) array(s), nanofiltration (NF) array(s) and/or a blending system including a control panel (CP), regulatory controllers (RCs), and a supervisory controller (SC), wherein the SC is in signal communication with the CP, and with the RCs, wherein the SC is configured to: receive user inputs from the CP, and receive inputs from RCs regarding data from sensors, wherein the RCs are in signal communication with the plurality of sensors, wherein the RCs are configured to: receive data from the sensors, provide outputs to and receive permissions from the SC, and instruct devices in response to the received permissions from the SC, and wherein the SC is configured to: monitor trends in the inputs regarding and/or predict outcomes from data received from the RCs and determine the permissions for RCs based on the monitored trends and/or user inputs from the CP.

IPC Classes  ?

• B01D 61/02 - Reverse osmosisHyperfiltration
• B01D 61/12 - Controlling or regulating
• C02F 1/44 - Treatment of water, waste water, or sewage by dialysis, osmosis or reverse osmosis
• E21B 43/20 - Displacing by water

Abstract

A predictive system for monitoring fouling of membranes of a desalination or water softening plant comprising ultrafiltration (UF) membranes, reverse osmosis (RO) membranes, and/or nanofiltration (NF) membranes, the system including one or more UF skids comprising a plurality of UF units, each UF unit containing therein a plurality of UF membranes; one or more RO/NF skids comprising one or more RO/NF arrays, wherein each of the one or more RO/NF arrays comprises a plurality of RO units, with each RO unit containing therein a plurality of RO membranes, a plurality of NF units, with each NF unit containing therein a plurality of NF membranes; or a combination thereof; UF sensors and/or RO/NF sensors; and a controller comprising a processor in signal communication with the UF sensors and/or the RO/NF sensors.

IPC Classes  ?

• B01D 61/02 - Reverse osmosisHyperfiltration
• B01D 61/12 - Controlling or regulating
• B01D 61/14 - UltrafiltrationMicrofiltration
• B01D 61/22 - Controlling or regulating
• B01D 61/58 - Multistep processes
• B01D 65/02 - Membrane cleaning or sterilisation
• B01D 65/10 - Testing of membranes or membrane apparatusDetecting or repairing leaks
• C02F 1/00 - Treatment of water, waste water, or sewage
• C02F 1/44 - Treatment of water, waste water, or sewage by dialysis, osmosis or reverse osmosis

Abstract

A predictive system for monitoring fouling of membranes of a desalination or water softening plant comprising ultrafiltration (UF) membranes, reverse osmosis (RO) membranes, and/or nanofiltration (NF) membranes, the system including one or more UF skids comprising a plurality of UF units, each UF unit containing therein a plurality of UF membranes; one or more RO/NF skids comprising one or more RO/NF arrays, wherein each of the one or more RO/NF arrays comprises a plurality of RO units, with each RO unit containing therein a plurality of RO membranes, a plurality of NF units, with each NF unit containing therein a plurality of NF membranes; or a combination thereof; UF sensors and/or RO/NF sensors; and a controller comprising a processor in signal communication with the UF sensors and/or the RO/NF sensors.

IPC Classes  ?

• C02F 1/00 - Treatment of water, waste water, or sewage
• B01D 61/12 - Controlling or regulating
• B01D 61/22 - Controlling or regulating
• C02F 1/44 - Treatment of water, waste water, or sewage by dialysis, osmosis or reverse osmosis
• C02F 103/08 - Seawater, e.g. for desalination
• B01D 61/02 - Reverse osmosisHyperfiltration
• B01D 61/14 - UltrafiltrationMicrofiltration
• B01D 61/58 - Multistep processes
• B01D 65/02 - Membrane cleaning or sterilisation
• B01D 65/10 - Testing of membranes or membrane apparatusDetecting or repairing leaks

Abstract

A control system configured to control operation of reverse osmosis (RO) array(s), nanofiltration (NF) array(s) and/or a blending system including a control panel (CP), regulatory controllers (RCs), and a supervisory controller (SC), wherein the SC is in signal communication with the CP, and with the RCs, wherein the SC is configured to: receive user inputs from the CP, and receive inputs from RCs regarding data from sensors, wherein the RCs are in signal communication with the plurality of sensors, wherein the RCs are configured to: receive data from the sensors, provide outputs to and receive permissions from the SC, and instruct devices in response to the received permissions from the SC, and wherein the SC is configured to: monitor trends in the inputs regarding and/or predict outcomes from data received from the RCs and determine the permissions for RCs based on the monitored trends and/or user inputs from the CP.

IPC Classes  ?

• C02F 1/44 - Treatment of water, waste water, or sewage by dialysis, osmosis or reverse osmosis
• B01D 61/02 - Reverse osmosisHyperfiltration
• B01D 61/12 - Controlling or regulating
• E21B 43/20 - Displacing by water
• C02F 103/08 - Seawater, e.g. for desalination
• C02F 103/10 - Nature of the water, waste water, sewage or sludge to be treated from quarries or from mining activities

Abstract

A method of dynamically allocating a total amount of produced water (PW) from a reservoir during enhanced oil recovery (EOR) via a low salinity or softened water EOR floodby receiving measurement data; receiving reservoir configuration information comprising: an EOR injection rate associated with one or more EOR injection zones, a disposal zone injection rate associated with one or more disposal injection zones, and a non-reinjection disposal rate associated with one or more non-reinjection disposal routes; determining a blending rate comprising at least a portion of the PW production rate and at least a portion of the low salinity or softened water injection rate to provide a blended injection fluid; blending at least a portion of the PW with at least a portion of the low salinity or softened water at the blending rate; and dynamically allocating the PW production rate among injection and/or non-reinjection routes.

IPC Classes  ?

• E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
• E21B 43/20 - Displacing by water
• E21B 43/38 - Arrangements for separating materials produced by the well in the well

Abstract

A method of dynamically allocating a total amount of produced water (PW) from a reservoir during enhanced oil recovery (EOR) via a low salinity or softened water EOR floodby receiving measurement data; receiving reservoir configuration information comprising: an EOR injection rate associated with one or more EOR injection zones, a disposal zone injection rate associated with one or more disposal injection zones, and a non-reinjection disposal rate associated with one or more non-reinjection disposal routes; determining a blending rate comprising at least a portion of the PW production rate and at least a portion of the low salinity or softened water injection rate to provide a blended injection fluid; blending at least a portion of the PW with at least a portion of the low salinity or softened water at the blending rate; and dynamically allocating the PW production rate among injection and/or non-reinjection routes.

IPC Classes  ?

• E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
• E21B 43/20 - Displacing by water
• E21B 43/38 - Arrangements for separating materials produced by the well in the well

Abstract

Embodiments relate generally to methods for extracting a core (114) from a percussion side wall core bullet (100) for a digital tomographic description and direct numerical simulations. A method for extracting a core (114) from a percussion side wall core bullet (100) for a digital tomographic description and direct numerical simulations includes pushing a free end (112) of a wire (110) of a wire saw (108) through the core (114). The core (114) is positioned within the percussion side wall core bullet (100). In addition, the method includes attaching the free end (112) to a locking mechanism (113) of the wire saw (108). Further, the method includes cutting the core (114) from the percussion side wall core bullet (100). The method also includes removing the core (114) from the percussion side wall core bullet (100).

IPC Classes  ?

• B23D 49/00 - Machines or devices for sawing with straight reciprocating saw blades, e.g. hacksaws
• B28D 1/00 - Working stone or stone-like materials, e.g. brick, concrete, not provided for elsewhereMachines, devices, tools therefor
• E21B 25/00 - Apparatus for obtaining or removing undisturbed cores, e.g. core barrels or core extractors
• E21B 49/04 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil using explosives in boreholesTesting the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil using projectiles penetrating the wall
• E21B 49/06 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil using side-wall drilling tools or scrapers

Abstract

Embodiments relate generally to methods for extracting a core (114) from a percussion side wall core bullet (100) for a digital tomographic description and direct numerical simulations. A method for extracting a core (114) from a percussion side wall core bullet (100) for a digital tomographic description and direct numerical simulations includes pushing a free end (112) of a wire (110) of a wire saw (108) through the core (114). The core (114) is positioned within the percussion side wall core bullet (100). In addition, the method includes attaching the free end (112) to a locking mechanism (113) of the wire saw (108). Further, the method includes cutting the core (114) from the percussion side wall core bullet (100). The method also includes removing the core (114) from the percussion side wall core bullet (100).

IPC Classes  ?

• E21B 25/00 - Apparatus for obtaining or removing undisturbed cores, e.g. core barrels or core extractors
• E21B 49/04 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil using explosives in boreholesTesting the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil using projectiles penetrating the wall
• E21B 49/06 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil using side-wall drilling tools or scrapers
• B23D 49/00 - Machines or devices for sawing with straight reciprocating saw blades, e.g. hacksaws
• B28D 1/00 - Working stone or stone-like materials, e.g. brick, concrete, not provided for elsewhereMachines, devices, tools therefor

Abstract

Embodiments relate generally to methods for extracting a core from a percussion side wall core bullet for a digital tomographic description and direct numerical simulations. A method for extracting a core from a percussion side wall core bullet for a digital tomographic description and direct numerical simulations includes pushing a free end of a wire of a wire saw through the core. The core is positioned within the percussion side wall core bullet. In addition, the method includes attaching the free end to a locking mechanism of the wire saw. Further, the method includes cutting the core from the percussion side wall core bullet. The method also includes removing the core from the percussion side wall core bullet.

IPC Classes  ?

• E21B 25/00 - Apparatus for obtaining or removing undisturbed cores, e.g. core barrels or core extractors
• G01N 23/046 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by transmitting the radiation through the material and forming images of the material using tomography, e.g. computed tomography [CT]
• E21B 49/04 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil using explosives in boreholesTesting the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil using projectiles penetrating the wall

Abstract

A method for processing seismic data includes receiving, by a seismic data processing system, signals representing seismic data recorded at a remote location. In addition, the method includes receiving, by the seismic data processing system, identification of a sensor via which the signals were acquired. Further, the method includes retrieving, by the seismic data processing system, a sensor transfer function that corresponds to the sensor and relates the motion of the sensor to the signals. The method also includes generating, by the seismic data processing system, based on the sensor transfer function and a reference transfer function, an inverse filter that when applied to the signals changes parameters of the signals to correspond to the reference transfer function. Moreover, the method includes applying, by the seismic data processing system, the inverse filter to the signals to conform the parameters of the signals to the reference transfer function.

IPC Classes  ?

• G01V 1/06 - Ignition devices
• G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
• G01V 1/18 - Receiving elements, e.g. seismometer, geophone
• G01V 13/00 - Manufacturing, calibrating, cleaning, or repairing instruments or devices covered by groups
• G01V 1/16 - Receiving elements for seismic signalsArrangements or adaptations of receiving elements

Abstract

during back-washing, back-wash water to the outside of the hollow fibres through the outlet of the filtration element. Further the method includes discharging, in a first back-wash cycle, back-wash water containing entrained particulate material from the inside of the hollow fibres from one end thereof. Still further, the method includes discharging, in a second back-wash cycle, back-wash water containing entrained particulate material from the inside of the hollow fibres from the other end thereof.

IPC Classes  ?

• C02F 1/44 - Treatment of water, waste water, or sewage by dialysis, osmosis or reverse osmosis
• B01D 61/14 - UltrafiltrationMicrofiltration
• B01D 61/18 - Apparatus therefor
• B01D 61/22 - Controlling or regulating
• B01D 63/02 - Hollow fibre modules
• B01D 65/02 - Membrane cleaning or sterilisation

Abstract

A method of detecting an event within a wellbore includes obtaining a sample data set, determining a plurality of frequency domain features of the sample data set, comparing the plurality of frequency domain features with an event signature, determining that the plurality of frequency domain features matches the thresholds, ranges, or both of the event signature, and determining the presence of the event within the wellbore based on determining that the plurality of frequency domain features match the thresholds, ranges, or both of the event signature. The sample data set is a sample of an acoustic signal originating within a wellbore including a fluid. The sample data set is representative of the acoustic signal across a frequency spectrum. The event signature includes a plurality of thresholds, ranges, or both corresponding to the plurality of frequency domain features.

IPC Classes  ?

• E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
• G01V 1/50 - Analysing data
• E21B 43/26 - Methods for stimulating production by forming crevices or fractures
• G01V 1/00 - SeismologySeismic or acoustic prospecting or detecting
• E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means
• G01V 1/22 - Transmitting seismic signals to recording or processing apparatus
• E21B 47/135 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range using light waves, e.g. infrared or ultraviolet waves
• G01H 3/04 - Frequency
• G01H 9/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means
• E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices or the like
• E21B 34/06 - Valve arrangements for boreholes or wells in wells
• E21B 43/14 - Obtaining from a multiple-zone well

Abstract

A system for processing acoustic data to identify an event comprises a receiver unit comprising a processor (168) and a memory (170), where the receiver unit is configured to receive a signal from a sensor (164) disposed along a sensor path or across a sensor area, wherein a processing application is stored in the memory. The processing application, when executed on the processor, configures the processor to: receive the signal from the sensor (164), where the signal comprises an indication of an acoustic signal received at one or more lengths along the sensor path or across a portion of the sensor area, wherein the signal is indicative of the acoustic signal across a frequency spectrum; determine a plurality of frequency domain features of the signal across the frequency spectrum; and generate an output comprising the plurality of frequency domain features.

IPC Classes  ?

• E21B 47/10 - Locating fluid leaks, intrusions or movements

Abstract

A system for processing acoustic data to identify an event comprises a receiver unit comprising a processor (168) and a memory (170), where the receiver unit is configured to receive a signal from a sensor (164) disposed along a sensor path or across a sensor area, wherein a processing application is stored in the memory. The processing application, when executed on the processor, configures the processor to: receive the signal from the sensor (164), where the signal comprises an indication of an acoustic signal received at one or more lengths along the sensor path or across a portion of the sensor area, wherein the signal is indicative of the acoustic signal across a frequency spectrum; determine a plurality of frequency domain features of the signal across the frequency spectrum; and generate an output comprising the plurality of frequency domain features.

IPC Classes  ?

• E21B 47/10 - Locating fluid leaks, intrusions or movements

Abstract

A method for detecting incremental oil production from an oil-bearing reservoir includes taking a baseline sample of the oil and analyzing the baseline sample of oil to establish a baseline compositional signature for the oxygen-containing organic compounds in the oil. In addition, the method includes commencing a low salinity waterflood by injecting a low salinity water into the reservoir from an injection well. Further, the method includes recovering oil from a production well. Still further, the method includes taking post-flood samples of the oil produced from the production well over time. The method also includes analyzing the post-flood samples of oil to establish post-flood compositional signatures for the oxygen-containing organic compounds in the oil. Moreover, the method includes identifying a difference between one or more of the post-flood compositional signatures and the baseline compositional signature that is characteristic of incremental oil released by the low salinity waterflood.

IPC Classes  ?

• E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
• E21B 43/20 - Displacing by water
• G01N 33/28 - Oils
• C09K 8/58 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids

Abstract

A seismic sensor includes an outer housing having a central axis, an upper end, a lower end, and an inner cavity. In addition, the seismic sensor includes a proof mass moveably disposed in the inner cavity of the outer housing. The outer housing is configured to move axially relative to the proof mass. Further, the seismic sensor includes a first biasing member disposed in the inner cavity and axially positioned between the proof mass and one of the ends of the outer housing. The first biasing member is configured to flex in response to axial movement of the outer housing relative to the proof mass. The first biasing member comprises a disc including a plurality of circumferentially-spaced slots extending axially therethrough. Still further, the seismic sensor includes a sensor element disposed in the inner cavity and axially positioned between the first biasing member and one of the ends of the outer housing. The sensor element includes a piezoelectric material configured to deflect and generate a potential in response to the axial movement of the outer housing relative to the proof mass and the flexing of the first biasing member.

IPC Classes  ?

• G01V 1/18 - Receiving elements, e.g. seismometer, geophone
• G01P 15/09 - Measuring accelerationMeasuring decelerationMeasuring shock, i.e. sudden change of acceleration by making use of inertia forces with conversion into electric or magnetic values by piezoelectric pick-up

Abstract

A seismic sensor for a seismic survey includes an outer housing having a central axis, a first end, and a second end opposite the first end. The first end comprises a portion made of a clear material configured to transmit light having a frequency in the visible or infrared range of the electromagnetic spectrum. In addition, the seismic sensor includes a proof mass moveably disposed in the outer housing. The proof mass includes a power source. Further, the seismic sensor includes a sensor element disposed in the outer housing and configured to detect the movement of the outer housing relative to the proof mass. Still further, the seismic sensor includes electronic circuitry coupled to the sensor element and the power source. The seismic sensor also includes a light guide assembly having a first end adjacent the clear portion of the first end of the outer housing and a second end adjacent the electronic circuitry. The light guide assembly is configured to transmit light in an axial direction between the first end of the light guide assembly the clear section and to transmit light in a non-axial direction between the second end of the light guide assembly and the electronic circuitry.

IPC Classes  ?

• G01V 1/18 - Receiving elements, e.g. seismometer, geophone
• G01H 9/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means

Abstract

A method includes producing a first blended low salinity injection water for injection into at least one injection well (20) that penetrates a first region (56) of an oil-bearing reservoir and producing a second blended low salinity injection water for injection into at least one injection well (20') that penetrates a second region (56') of an oil- bearing reservoir (22). The reservoir rock of the first and second regions has first and second rock compositions, respectively, that present different risks of formation damage. The first and second blended low salinity injection waters comprise variable amounts of nanofiltration permeate (13) and reverse osmosis permeate (9). The compositions of the first and second blended low salinity injection waters are maintained within first and second predetermined operating envelopes, respectively, that balance improving enhanced oil recovery from the first and second regions (56, 56') while reducing formation damage upon injecting the first and second blended low salinity injection waters into the oil-bearing reservoir (22).

IPC Classes  ?

• E21B 43/20 - Displacing by water
• E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
• B01D 61/02 - Reverse osmosisHyperfiltration
• C02F 1/44 - Treatment of water, waste water, or sewage by dialysis, osmosis or reverse osmosis

Abstract

A seismic survey apparatus includes a body having a longitudinal axis, a first end, a second end opposite the first end, and an inner cavity positioned between the first end and the second end. In addition, the seismic survey apparatus includes a proof mass moveably disposed in the inner cavity of the body. The proof mass is configured to move axially relative to the body. Further, the seismic survey apparatus includes a first sensor disposed in the inner cavity. The first sensor comprises a first piezoelectric element configured to detect the axial movement of the proof mass relative to the body. Still further, the seismic survey apparatus includes electronic circuitry coupled to the first piezoelectric element. The electronic circuitry is configured to receive and process an output of the first piezoelectric element. The proof mass comprises a power supply configured to provide electrical power to the electronic circuitry.

IPC Classes  ?

• G01V 1/16 - Receiving elements for seismic signalsArrangements or adaptations of receiving elements
• G01H 11/08 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by detecting changes in electric or magnetic properties by electric means using piezoelectric devices
• G01P 15/09 - Measuring accelerationMeasuring decelerationMeasuring shock, i.e. sudden change of acceleration by making use of inertia forces with conversion into electric or magnetic values by piezoelectric pick-up
• G01V 1/18 - Receiving elements, e.g. seismometer, geophone

Abstract

A method of detecting sand ingress within a wellbore includes obtaining a sample data set, determining a plurality of frequency domain features of the sample data set over a plurality of depth ranges, determining a presence of sand ingress at a first depth range of the plurality of depth ranges within the wellbore based on determining that the plurality of frequency domain features over the first depth range match a sand ingress signature, and determining a presence of sand migration along a second depth range of the plurality of depths within the wellbore based on determining that the plurality of frequency domain features over the second depth range match a sand migration signature. The sample data set is a sample of an acoustic signal originating within a wellbore comprising a fluid, and wherein the sample data set is representative of the acoustic signal across a frequency spectrum.

IPC Classes  ?

• E21B 43/04 - Gravelling of wells
• E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
• E21B 47/00 - Survey of boreholes or wells
• E21B 47/10 - Locating fluid leaks, intrusions or movements
• E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling

Abstract

A method for analysing a crude oil to determine the amount of organic acid compounds contained in the crude oil comprising: extracting the organic acid compounds from a sample of crude oil to form an extract comprising the organic acid compounds and determining the amount of the extracted organic acids; dissolving the extract in a polar solvent to form a solution of the extracted organic acid compounds; introducing a sample of the solution of the extracted organic acid to an apparatus comprising a reversed phase liquid chromatography (LC) column and a mass spectrometer (MS) arranged in series wherein the reversed phase LC column contains a hydrophobic sorbent and the mobile phase for the LC column comprises a polar organic solvent; separating the organic acid compounds in the LC column of the LC-MS apparatus and continuously passing the separated organic acid compounds from the LC column to the MS of the LC-MS apparatus to ionize the organic acid compounds and to obtain a chromatogram with mass spectral data over time for the ionized organic acid compounds; determining the area(s) under the peak(s) in an extracted ion chromatogram derived from the mass spectral data assigned to one or more organic acid compounds; determining the amount of the organic acid compound(s) in the sample by comparing the area under the peak(s) assigned to the organic acid compound(s) with the area under a peak in an extracted ion chromatogram assigned to a specific amount of a standard organic acid compound; and extrapolating from the amount of the organic acid compound(s) in the sample to provide the total amount of the organic acid compound(s) in the extract.

IPC Classes  ?

• G01N 30/72 - Mass spectrometers
• G01N 30/86 - Signal analysis
• G01N 33/28 - Oils
• G01N 1/40 - Concentrating samples

Abstract

An integrated system comprising: a desalination plant comprising a reverse osmosis (RO) array to produce an RO permeate blending stream and a nanofiltration (NF) array to produce an NF permeate blending stream; a blending system; a control unit; an injection system for an injection well that penetrates an oil-bearing layer of a reservoir; and wherein the blending system is to blend the RO permeate blending stream and the NF permeate blending stream to produce a blended injection water stream, wherein the control unit is to dynamically alter operation of the blending system to adjust amounts of at least one of the RO permeate blending stream and the NF permeate blending stream to alter the composition of the blended injection water stream from an initial composition to a target composition.

IPC Classes  ?

• C02F 1/44 - Treatment of water, waste water, or sewage by dialysis, osmosis or reverse osmosis
• E21B 43/20 - Displacing by water

Abstract

The present invention relates to expandable polymeric microparticles comprising cross-linked copolymer chains having structural units derived from (i) a water-soluble or water-dispersible monomer with a betaine group, (ii) a water-soluble or water-dispersible non- ionic comonomer, and, (iii) a water-soluble or water-dispersible non-labile cross-linking monomer having at least two sites of ethylenic unsaturation wherein the copolymer chains of the polymeric microparticles comprise from 9.5 to 45 mol% of structural units derived from the betaine monomer and from 0.1 to 10 mol% of structural units derived from the non-labile cross-linking monomer; the polymeric microparticles have an unexpanded average particle diameter in the range from 0.05 to 5 µm and wherein the polymeric microparticles expand in size when dispersed in an aqueous fluid at or above a transition temperature.

IPC Classes  ?

• C09K 8/508 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds
• C09K 8/512 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds containing cross-linking agents
• C09K 8/516 - Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls characterised by their form or by the form of their components, e.g. encapsulated material
• C09K 8/588 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific polymers

Abstract

An integrated system comprising: a desalination plant comprising a reverse osmosis (RO) array to produce an RO permeate blending stream and a nanofiltration (NF) array to produce an NF permeate blending stream; a blending system; a control unit; an injection system for one or more injection wells that penetrate an oil-bearing layer of a reservoir; and a production facility to separate fluids produced from one or more production wells that penetrate the oil-bearing layer of the reservoir and to deliver a produced water (PW) stream to the blending system, wherein the blending system is to blend the RO permeate and NF permeate blending streams with the PW stream to produce a blended low salinity water stream, wherein the control unit is to dynamically alter operation of the blending system to adjust amounts of at least one of the RO permeate blending stream and the NF permeate blending stream to maintain a composition of the blended low salinity water stream within a predetermined operating envelope.

IPC Classes  ?

• B01D 61/02 - Reverse osmosisHyperfiltration
• C02F 1/44 - Treatment of water, waste water, or sewage by dialysis, osmosis or reverse osmosis
• G05D 11/00 - Control of flow ratio
• C02F 103/08 - Seawater, e.g. for desalination
• C02F 103/10 - Nature of the water, waste water, sewage or sludge to be treated from quarries or from mining activities

Abstract

A liquefaction system for removing heat from a process fluid including a plurality of refrigerant systems configured to liquefy at least a portion of the process fluid in a process feed gas line coupled to the plurality of refrigerant systems, and a common end flash system configured to receive process fluid from the plurality of refrigerant systems. A method for liquefying a process fluid by operating a plurality of refrigeration systems in parallel, wherein each refrigeration system receives a portion of the process fluid, transferring heat from each portion of the process fluid with the corresponding refrigeration system, supplying the portions of the process fluid from the refrigeration systems to a common end flash system, and lowering the pressure of the portions of the process fluid with the common end flash system to provide a liquefied process fluid and an end flash gas.

IPC Classes  ?

• F25J 1/00 - Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
• F25J 1/02 - Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen

Abstract

A liquefaction system for removing heat from a process fluid to condense the process fluid, the liquefaction system including a primary heat exchanger configured to remove heat from the process fluid via heat exchange with one or more refrigerants, a compressor configured to compress the one or more refrigerants, a first secondary heat exchanger configured to remove heat from the one or more refrigerants via heat exchange with ambient air, and a second secondary heat exchanger configured to remove heat from the one or more refrigerants via heat exchange with ambient water.

IPC Classes  ?

• F25J 1/00 - Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
• F25J 1/02 - Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen

Abstract

A process for use in managing a hydrocarbon production system includes: selecting, from among a plurality of changes proposed to operating parameters of the hydrocarbon production system, the proposed change with the greatest estimated positive change in production; assessing whether the selected change violates an operating constraint; based on said assessment, producing a valid change based on at least the selected change or identifying the selected change as an unusable change, iterating the above steps, the iteration excluding the valid change from the plurality of proposed changes; and implementing at least one valid change, the number of implemented valid changes being less than the number of proposed changes.

IPC Classes  ?

• E21B 43/00 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
• E21B 41/00 - Equipment or details not covered by groups

Abstract

A process for reducing the permeability to water of a thief zone of a porous and permeable subterranean petroleum reservoir by injecting a dispersion of polymeric microparticles in an aqueous fluid down a well and into the thief zone, wherein the polymeric microparticles comprise crosslinked copolymer chains having structural units derived from (i) a water-soluble or water- dispersible monomer with a betaine group, (ii) a water-insoluble monomer, and, (iii) a cross- linking monomer having at least two sites of ethylenic unsaturation, and the polymeric microparticles have a transition temperature above the maximum temperature encountered in the well and at or below the maximum temperature encountered in the thief zone and, and the polymeric microparticles expand in size in the thief zone when they encounter a temperature at or greater than the transition temperature so as to reduce the permeability of the thief zone to water.

IPC Classes  ?

• C09K 8/035 - Organic additives
• C09K 8/508 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds
• C09K 8/512 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds containing cross-linking agents
• C09K 8/516 - Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls characterised by their form or by the form of their components, e.g. encapsulated material
• C09K 8/588 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific polymers
• C08F 230/02 - Copolymers of compounds having one or more unsaturated aliphatic radicals, each having only one carbon-to-carbon double bond, and containing phosphorus, selenium, tellurium or a metal containing phosphorus

Abstract

A method of detecting a leak event within a wellbore can include inducing a pressure differential within a wellbore comprising a fluid, obtaining a sample data set representative of the acoustic signal across a frequency spectrum while inducing the pressure differential, determining a plurality of frequency domain features of the sample data set, determining a presence of a leak event at one or more depths within the wellbore based on determining that the plurality of frequency domain features match a leak event signature, correlating the leak event with the induced pressure differential, and determining a presence and location of a leak within the wellbore based on the presence of the leak event and the correlating of the leak event with the induced pressure differential.

IPC Classes  ?

• E21B 47/10 - Locating fluid leaks, intrusions or movements

Abstract

A desalination system comprising: a feed pump having an inlet side and an outlet side; a first RO stage having an inlet, RO permeate outlet and RO concentrate outlet; a second RO stage having an inlet, RO permeate outlet and RO concentrate outlet and an NF stage having an inlet, NF permeate outlet and an NF concentrate outlet; and, a set of conduits adapted to connect: (a) the outlet side of the feed pump to the inlet of the first RO stage; (b) the concentrate outlet of the first RO stage to (i) the inlet of the second RO stage and to the inlet of the NF stage; and (c) the permeate outlet of the first RO stage, the permeate outlet of the second RO stage and the permeate outlet of the NF stage either directly or indirectly to a low salinity water injection line.

IPC Classes  ?

• C02F 1/44 - Treatment of water, waste water, or sewage by dialysis, osmosis or reverse osmosis
• C02F 9/00 - Multistage treatment of water, waste water or sewage
• B01D 61/02 - Reverse osmosisHyperfiltration
• C02F 103/08 - Seawater, e.g. for desalination
• B01D 61/08 - Apparatus therefor

Abstract

A method of detecting a leak event within a wellbore can include inducing a pressure differential within a wellbore comprising a fluid, obtaining a sample data set representative of the acoustic signal across a frequency spectrum while inducing the pressure differential, determining a plurality of frequency domain features of the sample data set, determining a presence of a leak event at one or more depths within the wellbore based on determining that the plurality of frequency domain features match a leak event signature, correlating the leak event with the induced pressure differential, and determining a presence and location of a leak within the wellbore based on the presence of the leak event and the correlating of the leak event with the induced pressure differential.

IPC Classes  ?

• E21B 47/10 - Locating fluid leaks, intrusions or movements

Abstract

A method for recovering crude oil from a reservoir comprising injecting into an oil-bearing reservoir alternating slugs of an aqueous displacement fluid comprising an aqueous solution of zinc chloride or zinc bromide and of an aqueous spacer fluid characterized in that: a) the pH of each of the slugs of aqueous displacement fluid is less than 5.5 and the pH of each of the slugs of aqueous spacer fluid is less than 8.5; b) the number of injected slugs of aqueous displacement fluid, n, is in the range of 15 to 1000 per swept pore volume, PVR; c) the injected pore volume of each individual slug, PVSlug-i, of aqueous displacement fluid is in the range of 10-12 to 10-2 of the PVR; d) the total injected pore volume of the slugs of aqueous displacement fluid is in the range of 10-8 to 10-1 of the PVR; e) the injected pore volume of each individual slug of aqueous spacer fluid, PVSpacer-i, is in the range of 0.0001 to 0.1000 of the PVR; f) the total injected pore volume of the slugs of aqueous spacer fluid is in the range of 0.9000000 to 0.9999999 of the PVR; g) the reservoir rock has a dispersivity, α, in the range of 1 to 30; and 20 h) the quantity of zinc delivered to the reservoir by the plurality of slugs of aqueous displacement fluid is equal to or greater than a predetermined minimum quantity (MQ).

IPC Classes  ?

• C09K 8/58 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
• E21B 43/00 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells

Abstract

A method includes receiving data indicative of outputs of first and second seismic sensors. The outputs include components corresponding to the detection by the first and second seismic sensors of first and second seismic signals. In addition, the method includes identifying, relative to a first clock in the first seismic sensor, a first time associated with a time of arrival of the first seismic signal at the first seismic sensor, and a second time associated with a time of arrival of the second seismic signal at the first seismic sensor. Further, the method includes identifying, relative to a second clock in the second seismic sensor, a third time associated with a time of arrival of the first seismic signal at the second seismic sensor, and a fourth time associated with a time of arrival of the second seismic signal at the second seismic sensor. Still further, the method includes determining an offset of the first clock relative to the second clock using the first, second, third and fourth times.

IPC Classes  ?

• G01V 1/26 - Reference-signal-transmitting devices, e.g. indicating moment of firing of shot
• G01V 1/30 - Analysis

Abstract

A method for recovering crude oil from a reservoir comprising at least one layer of reservoir rock having crude oil and a formation water within the pore space thereof wherein the layer(s) of reservoir rock is penetrated by at least one injection well and at least one production well, the method comprising: injecting into the layer(s) of reservoir rock from the injection well, alternating slugs of an aqueous displacement fluid comprising a concentrated solution of a water-soluble additive in an aqueous solvent and of an aqueous spacer fluid characterized in that: (a) the number of injected slugs of aqueous displacement fluid, n, is in the range of 15 to 1000 per swept pore volume, PVR, of the layer(s) of reservoir rock; (b) the injected pore volume of each individual slug, PVSlug-i, of aqueous displacement fluid is in the range of 10-12 to 10-2 of the swept pore volume, PVR, of the layer(s) of reservoir rock; (c) the total injected pore volume of the slugs of aqueous displacement fluid is in the range of 10-8 to 10-1 of the swept pore volume, PVR, of the layer(s) of reservoir rock; (d) the injected pore volume of each individual slug of aqueous spacer fluid, PVSpacer-i, is in the range of 0.0001 to 0.1000 of the swept pore volume, PVR, of the layer(s) of reservoir rock; (e) the total injected pore volume of the slugs of aqueous spacer fluid is in the range of 0.9000000 to 0.9999999 of the swept pore volume, PVR, of the layer(s) of reservoir rock; (f) the reservoir rock has a dispersivity, a, in the range of 1 to 30% of the interwell distance between the injection well and production well; (g) the amount of additive delivered to the layer(s) of reservoir rock by the plurality of slugs of aqueous displacement fluid is equal to or greater than a predetermined minimum additive quantity (MAQ).

IPC Classes  ?

• C09K 8/58 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
• E21B 43/20 - Displacing by water