A grouser for a track shoe, the grouser comprising a matrix material and a plurality of embedded inserts. The inserts are arranged in the matrix material to form one or more ice lugs. The inserts have a hardness greater than a hardness of the matrix material, such that use of the grouser on a track shoe will abrade the matrix material at a rate greater than a rate of abrasion of the insert material.
The present disclosure provides a process that includes providing bitumen; performing thermal upgrading on the bitumen to form mildly upgraded bitumen; distilling the mildly upgraded bitumen to form streams of naphtha; distillates and/or gas oils; and residue; combining the naphtha and residue to form a naphtha/residue stream, which causes deasphalting to occur, and forming streams of deasphalted oil and high-carbon pitch comprising asphaltenes; and adding the distillates and/or gas oils to the deasphalted oil to form partially upgraded bitumen.
C10C 3/06 - Working-up pitch, asphalt, bitumen by distillation
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
C10G 53/04 - Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes plural serial stages only including at least one extraction step
40 - Treatment of materials; recycling, air and water treatment,
42 - Scientific, technological and industrial services, research and design
Goods & Services
(1) Bitumen (1) Oil production services; oil refining; oil treatment and processing
(2) Oil sand refining; oil sand production services; oil sand treatment and processing;
(3) Exploration services in the field of mining industries; geophysical exploration for the oil industry
(4) Exploration services in the field of mining industries; geophysical exploration for the oil industry;
40 - Treatment of materials; recycling, air and water treatment,
42 - Scientific, technological and industrial services, research and design
Goods & Services
(1) Bitumen (1) Oil production services; oil refining; oil treatment and processing
(2) Oil sand refining; oil sand production services; oil sand treatment and processing;
(3) Exploration services in the field of mining industries; geophysical exploration for the oil industry
(4) Oil sand exploration;
5.
NOISE REDUCTION FOR MICRO-SEISMIC MONITORING USING DEEP LEARNING
A method for classifying a microseismic event, including: analyzing microseismic event files through a combination of two fault tolerant machine learning pipelines, an acoustic machine learning pipeline and a visual machine learning pipeline; and generating a classification prediction for the microseismic event files by combining predictions from the acoustic machine learning pipeline and the visual machine learning pipeline.
A process for recovering heat from a bitumen froth tailings stream, the process comprising operating with the bitumen froth tailings stream between 52 C and 70 C such that an insulating layer is present in a lower portion of the bitumen froth tailings stream; removing warm water, with a temperature between 52 C and 70 C, from an upper portion of the bitumen froth tailings stream, above the insulating layer; adding colder water, with a temperature less than 52 C, to the bitumen froth tailings stream; and adding at least a portion of the warm water upstream of the bitumen froth tailings stream to a bitumen process.
A method for treating a tailings stream from an oil sands bitumen extraction process, the method comprising: a) adding a flocculant and a binder to the tailings stream to form treated tailings; b) dewatering the treated tailings, to form dewatered tailings, by: i) depositing the treated tailings into layers and allowing for initial dewatering, atmospheric drying, and strength gain through evaporation to form the dewatered tailings; or ii) mechanical dewatering to form the dewatered tailings; and c) either between steps a) and b) or during step b), adding a coagulant to the treated tailings to initiate pozzolanic reactions.
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
8.
HIGH VELOCITY STEAM INJECTION IN HYDROCARBON CONTAINING STREAMS
A disclosed method comprises degassing process comprising providing high velocity steam and injecting the high velocity steam directly into bitumen froth such that the steam shears gas bubbles for reducing an amount of air in the bitumen froth. Also disclosed is a solvent recovery process comprising providing high velocity steam and injecting the high velocity steam into tailings in a tailings solvent recovery unit (TSRU) or into a bitumen stream in a solvent recovery unit (SRU) for shearing hydrocarbon laden agglomerates for reducing an amount of solvent in the tailings or in the bitumen stream.
C10G 1/00 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
9.
ULTRASONIC PROCESSING OF HYDROCARBON CONTAINING STREAMS
A disclosed method comprises providing an ultrasonic probe and delivering ultrasonic energy via the ultrasonic probe to bitumen froth for reducing an amount of air in the bitumen froth. Also disclosed are methods of delivering ultrasonic energy to a bitumen stream in a solvent recovery unit (SRU) flash drum for reducing an amount of solvent in the bitumen stream or to a tailings stream in a tailings solvent recovery unit (TSRU) for reducing an amount of solvent in the tailings stream.
B01J 19/10 - Processes employing the direct application of electric or wave energy, or particle radiationApparatus therefor employing sonic or ultrasonic vibrations
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
10.
MEASUREMENT IN A VESSEL COMPRISING BITUMEN VIA IR CAMERA
A process for measuring an interface between layers in a vessel comprising bitumen, the process comprising directing an infrared (IR) camera at the vessel and detecting the interface from data from the camera. Also disclosed is a use of an infrared (IR) camera for detecting interior liner wear in a lined vessel or spool.
EXXONMOBIL TECHNOLOGY AND ENGINEERING COMPANY (USA)
Inventor
Smith, Stuart E.
Agrawal, Gaurav
Ferrughelli, David T.
Al-Sabawi, Mustafa
Abstract
A disclosed method comprises providing a heavy hydrocarbon feedstock comprising paraffinic froth treated bitumen and/or solvent de-asphalted bitumen; thermally cracking the heavy hydrocarbon feedstock to produce a cracked stream and a gas; distilling the cracked stream to produce a distillation bottoms stream and a naphtha and distillates stream; and de-asphalting the distillation bottoms stream to produce a pitch fraction and de-asphalted oil (DAO).
C10C 3/02 - Working-up pitch, asphalt, bitumen by chemical means
C10G 55/04 - Treatment of hydrocarbon oils, in the absence of hydrogen, by at least one refining process and at least one cracking process plural serial stages only including at least one thermal cracking step
C10G 57/00 - Treatment of hydrocarbon oils, in the absence of hydrogen, by at least one cracking process or refining process and at least one other conversion process
A wellhead is associated with and fluidly connected to a density sensor and a fluid directing manifold. The manifold is configured to direct the production fluids from a wellhead to one of a plurality of production lines in order to reduce mixing of solvent-rich and solvent-lean streams and, therefore, decrease the likelihood of production fluid phase splitting. In some embodiments, a density of the production fluid is measured by the density sensor and the fluid directing manifold directs the production fluid to a particular production line based on the measured density which may be correlated to the solvent fraction of the production fluid.
Systems and methods are provided for partial upgrading of bitumen (and/or other heavy hydrocarbon feeds) while reducing or minimizing the hydrogen consumption associated with the partial upgrading. The partial upgrading of the bitumen can correspond to any convenient type of catalytic and/or thermal upgrading. After the partial upgrading, a naphtha and/or distillate boiling range portion of the thermally upgraded effluent can be passed into a catalytic reformer. The reformer can be operated under conditions that are suitable for olefin saturation in addition to some aromatic formation. The resulting naphtha and distillate portions of the reformer effluent, having a reduced or minimized content of olefins, can be combined with one or more additional portions of the partially upgraded effluent to form a partially upgraded product.
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
C10G 55/02 - Treatment of hydrocarbon oils, in the absence of hydrogen, by at least one refining process and at least one cracking process plural serial stages only
Systems and methods are provided for partial upgrading of oil sands. The systems and methods include forming a low-asphaltene bitumen using a modified paraffinic froth treatment, followed by visbreaking and/or other thermal cracking of the low- asphaltene bitumen. By using a modified paraffinic froth treatment to form a low- asphaltene bitumen, potential coke precursors are removed from the feed prior to thermal cracking while reducing or minimizing the loss of other hydrocarbons in the bitumen. Removing the coke precursors can allow a substantial increase in thermal cracking severity while producing a cracked product containing a reduced or minimized content of coke particles.
Methods of recovering bitumen from an underground reservoir penetrated by a wellbore are described herein. The methods include injecting a first mobilizing fluid through the wellbore into the underground reservoir, shutting in the first mobilizing fluid that is in the reservoir to lower a viscosity of at least a portion of the bitumen in the reservoir, holding the first mobilizing fluid in the reservoir, recovering bitumen of lowered viscosity from the reservoir, detecting an issue in the wellbore, in response to detecting the issue, injecting a second mobilizing fluid through the wellbore into the reservoir, shutting in the second mobilizing fluid that is in the reservoir, holding the second mobilizing fluid in the reservoir, and recovering bitumen of lowered viscosity from the reservoir. The first mobilizing fluid includes steam and the second mobilizing fluid includes a hydrocarbon solvent. The issue may be a casing integrity issue, a fluid excursion issue or a pump issue.
E21B 43/22 - Use of chemicals or bacterial activity
E21B 43/241 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection combined with solution mining of non-hydrocarbon minerals, e.g. solvent pyrolysis of oil shale
E21B 47/007 - Measuring stresses in a pipe string or casing
16.
METHODS AND SYSTEMS FOR REAL-TIME WATER CUT MEASUREMENT
Methods and systems for determining a water cut for fluid produced from at least one wellbore are disclosed. Methods include transferring thermal energy to a sample of fluid; determining a temperature change for the sample of fluid due to a transfer of thermal energy; and determining a water cut for the sample of produced fluid, based on a quantity of thermal energy transferred to the sample, the temperature change, a specific heat capacity value for water, a specific heat capacity value for at least one hydrocarbon present in the produced fluid, and at least one of: a volume of the sample of fluid; and a mass of the sample of fluid. In some methods, a sample of fluid is diverted to a vessel.
G01F 1/74 - Devices for measuring flow of a fluid or flow of a fluent solid material in suspension in another fluid
G01N 25/58 - Investigating or analysing materials by the use of thermal means by investigating moisture content by measuring changes of properties of the material due to heat, cold, or expansion
17.
CARBON DIOXIDE REMOVAL FROM PRODUCED GASES OF HEAVY OIL IN SITU RECOVERY PROCESSES USING AQUEOUS EXTRACTION
A method for carbon dioxide removal, and optionally additionally hydrogen sulfide removal, from produced gas in heavy oil in situ (HOIS) recovery processes using the produced water may comprise: performing the HOIS recovery process on a heavy oil to yield water, heavy oil, fines, and produced gas, wherein the produced gas comprises light hydrocarbons, carbon dioxide, and optionally hydrogen sulfide; separating the produced gas from the water, the heavy oil, and the fines; compressing the produced gas to yield a compressed produced gas; mixing the compressed produced gas with an absorption water to yield a mixture; cooling the mixture to yield a cooled mixture; separating the cooled mixture into (a) a carbonated water stream comprising the carbon dioxide and optionally the hydrogen sulfide dissolved in the absorption water each at a higher concentration than in the absorption water and (b) one or more hydrocarbon streams.
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
A disclosed method comprises providing tailings from a bitumen froth treatment using solvent, introducing the tailings into a flotation column, using a shearing device to break asphaltenes flocs in the tailings, introducing water and gas into the flotation column through sparging; and removing an overflow and an underflow from the flotation column.
B03B 9/02 - General arrangement of separating plant, e.g. flow sheets specially adapted for oil-sand, oil-chalk, oil-shales, ozokerite, bitumen, or the like
A disclosed method comprises operating a flotation process for separating a bitumen-containing stream in a flotation column into an overflow and an underflow; and maintaining a steam cap above a froth layer in the flotation column for reducing a gas content in the froth layer.
B03B 9/02 - General arrangement of separating plant, e.g. flow sheets specially adapted for oil-sand, oil-chalk, oil-shales, ozokerite, bitumen, or the like
The present disclosure comprises relating to the optimization, including preferably minimization, of greenhouse gas (GHG) emissions associated with the production of heavy oil from a subterranean reservoir in a solvent-based heavy oil recovery process. Optimization of GHG emissions is based on modifications to operating parameters associated with the process based on overall (or "total") GHG emissions intensity modeling based on the analysis of several key GHG emissions sources in the overall process as a function of the solvent fraction of the process injection fluid and/or the solvent composition of the process injection fluid. Solvent fractions and/or solvent compositions of the process injection fluid of the solvent-based heavy oil recovery process can then be adjusted or matched to a select range of solvent fractions and/or solvent compositions corresponding to the GHG emissions minima associated with the total GHG emissions intensity curves for the solvent-based heavy oil recovery process.
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
E21B 43/241 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection combined with solution mining of non-hydrocarbon minerals, e.g. solvent pyrolysis of oil shale
Systems and methods for estimating solvent conformance along a wellbore during a solvent dominated bitumen recovery process are described. The system includes a plurality of temperature sensors distributed along a length of the wellbore, a mass flow meter positioned upstream of a leading outflow region of the wellbore and one or more processors operatively coupled to each temperature sensor and the mass flow meter. The one or more processors are configured to receive a measured temperature of the solvent during injection of the solvent to the reservoir, receive a mass flow rate of the solvent from the mass flow meter; estimate a background temperature along the length of the wellbore, estimate a heat transfer coefficient of the wellbore based on the measured temperatures, and select a mass distribution along the wellbore based on the heat transfer coefficient to yield a calculated temperature distribution that fits the measured temperatures of the solvent during injection of the solvent from the wellbore to the reservoir.
Methods of conditioning an underground reservoir that has undergone a thermal recovery process to promote improved efficiency during a subsequent solvent-dominated recovery process are described herein. The methods include determining a temperature of the reservoir, injecting pressurizing fluid into a voidage formed in the reservoir during the thermal recovery process to increase a pressure of the reservoir; monitoring the pressure of the reservoir; and in response to the monitored pressure reaching a predetermined recovery pressure selected based on a determined temperature: injecting mobilizing fluid comprising vapor solvent into the reservoir, the vapor solvent having a liquid- vapor phase boundary proximate the determined temperature and the predetermined recovery pressure; and producing fluid comprising mobilized bitumen from the reservoir.
C09K 8/592 - Compositions used in combination with generated heat, e.g. by steam injection
C09K 8/594 - Compositions used in combination with injected gas
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
E21B 43/241 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection combined with solution mining of non-hydrocarbon minerals, e.g. solvent pyrolysis of oil shale
23.
METHODS FOR VAPOR SOLVENT FLOOD BITUMEN RECOVERY OPERATIONS FOLLOWING THERMAL RECOVERY PROCESSES
Methods of conditioning an underground reservoir that has undergone a thermal recovery process to promote improved efficiency during a subsequent solvent-dominated recovery process are described herein. The methods include determining a temperature of the reservoir, injecting pressurizing fluid into a voidage formed in the reservoir during the thermal recovery process to increase a pressure of the reservoir; monitoring the pressure of the reservoir; and in response to the monitored pressure reaching a predetermined recovery pressure selected based on a determined temperature: injecting mobilizing fluid comprising vapor solvent into the reservoir, the vapor solvent having a liquid-vapor phase boundary proximate the determined temperature and the predetermined recovery pressure; and producing fluid comprising mobilized bitumen from the reservoir.
C09K 8/592 - Compositions used in combination with generated heat, e.g. by steam injection
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
E21B 43/241 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection combined with solution mining of non-hydrocarbon minerals, e.g. solvent pyrolysis of oil shale
A method for treating a tailings stream from an oil sands bitumen extraction process. The method includes flocculating the tailings stream with a flocculant to produce a flocculated tailings stream and treating the flocculated tailings stream with a coagulant and a silicate to produce a treated tailings stream and water.
C02F 1/52 - Treatment of water, waste water, or sewage by flocculation or precipitation of suspended impurities
C02F 11/14 - Treatment of sludgeDevices therefor by de-watering, drying or thickening with addition of chemical agents
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
25.
REDUCTION OF HYDROGEN INGRESS INTO VACUUM INSULATED TUBING
A vacuum insulated tubing including an inner pipe, an outer pipe concentrically arranged about the inner pipe such that an annulus is defined between the inner and outer pipes. A vacuum is drawn within the annulus, and a hydrocarbon-based coating is applied to at least one of the surfaces of the inner pipe or one of the surfaces of the outer pipe to reduce a rate of hydrogen migration into the annulus.
A method comprising: a) providing an oil sand slurry stream, comprising bituminous ore, to a water based extraction process; b) measuring one or more bitumen ore property; c) adding a primary chemical additive (PCA) and a supplementary chemical additive (SCA) to the oil sand slurry stream; d) processing the oil sand slurry stream into bitumen froth, middlings, flotation tailings (FT), and coarse sand tailings (CST), including using a primary separation cell (PSC); e) measuring one or more slurry property of at least one of the oil sand slurry stream, a hydrotransport line feeding the PSC, a middlings layer inside the PSC, the middlings from the PSC, the FT, and the CST; f) based on the one or more measured bitumen ore property, adjusting, in a feed forward control, at least one of the following in the water-based extraction process: a dosage of the supplementary chemical additive (SCA) added to the oil sand slurry stream, process temperature, a mixing condition, and water addition prior to the PSC; and g) based on the one or more measured slurry property, adjusting, in a feed-back control, at least one of the following in the water- based extraction process: the dosage of the supplementary chemical additive (SCA) added to the oil sand slurry stream, process temperature, a mixing condition, and water addition prior to the PSC.
C10C 3/08 - Working-up pitch, asphalt, bitumen by selective extraction
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
Systems and methods for monitoring the composition of a produced fluid recovered in a bitumen recovery facility in real-time to predict a phase profile of the produced fluid in real-time are described herein. The systems include at least one flow rate sensor, density sensor, temperature sensor and pressure sensor positioned between a bottom hole of a wellbore and an end of a production stream, and one or more processors operatively coupled to each of the sensors. The one or more processors, collectively, are configured to determine a water-cut of the produced fluid in real-time, determine a solvent content of hydrocarbons of the produced fluid in real-time based on the water-cut, a hydrocarbon density correlation and a bitumen density correlation, and predict a phase profile of the produced fluid in real-time based on the temperature and pressure of the produced fluid. The systems are also configured to initiate actions for mitigating potential flow assurance disruptions based on the predicted phase profile of the produced fluid.
A method of recovering bitumen from an underground reservoir penetrated by at least one well is described herein. The method includes injecting a first mobilizing fluid into the reservoir. The first mobilizing fluid has a volume that is less than about 20% by weight of a forecast injection volume of fluid to be injected into the reservoir. The method also includes injecting a first hydrocarbon solvent into the reservoir, the first hydrocarbon solvent having a volume equal to a remainder of the forecast injection volume of fluid to be injected into the reservoir, shutting the first hydrocarbon solvent into the reservoir to lower viscosity of at least a portion of the bitumen in the reservoir, and recovering bitumen of lowered viscosity from the reservoir.
Methods of recovering bitumen from an underground reservoir are described herein. The methods include injecting a first mobilizing fluid into the underground reservoir through a first well, producing a first produced fluid from the underground reservoir through the first well, the first produced fluid including bitumen and at least a portion of the first mobilizing fluid injected into the underground reservoir, mixing at least a portion of the first produced fluid with a make-up fluid to form a second mobilizing fluid, injecting the second mobilizing fluid into the underground reservoir through a second well and producing a second produced fluid from the underground reservoir through the second well, the second produced fluid including bitumen and at least a portion of the second mobilizing fluid injected into the underground reservoir.
Methods of recovering bitumen from a reservoir are provided herein. The methods include operating a first injector-first producer well pair under a first gravity drainage process to form a first gravity drainage chamber and operating a second injector-second producer well pair under a second gravity drainage process to form a second gravity drainage chamber. An infill well is provided in an unswept region formed between the first gravity drainage chamber and the second gravity drainage chamber and the infill well is operated under a cyclic process utilizing a mobilizing fluid to form a mobilized region of the infill well. The infill well is then operated under a flooding process utilizing a driving fluid to displace bitumen in the mobilized region towards the first and second producer wells of the first injector-first producer well pair and the second injector-second producer well pair. The bitumen is then recovered.
A method of controlled deposition for increasing deposition rate, the method comprising providing a first fines dominated stream having a first sand to fines ratio (SFR) of less than 0.6 and having first solids content; providing a second fines dominated stream having a second SFR of between 0.6 and 3.0 and having a second solids content; wherein the first solids content and the second solids content differ by at least 5%, by mass; and depositing the first and second dominated streams into a common deposition cell.
B03B 5/00 - Washing granular, powdered or lumpy materialsWet separating
B03B 9/02 - General arrangement of separating plant, e.g. flow sheets specially adapted for oil-sand, oil-chalk, oil-shales, ozokerite, bitumen, or the like
A method comprises providing a thickener, an underflow pipeline, and a deposition cell, arranged in series, such that flotation tailings (FT) can be introduced into the thickener, formed into thickened tailings, and introduced into the deposition cell; introducing fluid fine tailings (FFT) downstream of the thickener as a bypass; and settling out at least a portion of the FFT in the deposition cell.
B01D 21/01 - Separation of suspended solid particles from liquids by sedimentation using flocculating agents
B03B 9/02 - General arrangement of separating plant, e.g. flow sheets specially adapted for oil-sand, oil-chalk, oil-shales, ozokerite, bitumen, or the like
B03D 1/08 - Subsequent treatment of concentrated product
33.
PROCESSING OF PRODUCED FLUIDS FROM A SUBTERANNEAN FORMATION IN A NEAR-AZEOTROPIC INJECTION PROCESS
The present disclosure relates to production of oil from a subterranean reservoir in a near-azeotropic solvent-based oil recovery process and processing of related process fluids, wherein products from a production well associated with the subterranean reservoir are processed, a heavy oil product stream is produced, and a near-azeotropic solvent mixture is produced and utilized in the reservoir injection mixture for injection into the near-azeotropic solvent- based oil recovery process.
E21B 43/241 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection combined with solution mining of non-hydrocarbon minerals, e.g. solvent pyrolysis of oil shale
E21B 43/40 - Separation associated with re-injection of separated materials
A method comprises introducing oil sand tailings into a thickener; and effecting a shear loop comprising removing thickened tailings (TT) from the thickener, combining at least a portion of the TT with fluid fine tailings (FFT) to form a recycle stream, and recycling the recycle stream back into the thickener.
B03B 9/02 - General arrangement of separating plant, e.g. flow sheets specially adapted for oil-sand, oil-chalk, oil-shales, ozokerite, bitumen, or the like
Methods to improve sweep efficiency in an in-situ bitumen recovery processes are disclosed. In some embodiments, these methods include performing a mobilizing agent chamber development stage, subsequently performing a cyclic sweep stage, and subsequently performing an optional harvesting stage. The chamber development stage renders the bitumen in the bypassed region between two adjacent mobilizing agent chambers mobile. The cyclic sweep stage allows access of the bypassed bitumen by the mobilizing agent, thereby aiding its recovery. The harvesting stage harvests additional bitumen and diluent. Advantages over prior art include accessing bypassed bitumen of prior at recovery processes, eliminating the need for infill wells, improving bitumen recovery, accelerating bitumen production, and improving mobilizing agent utilization efficiency. The methods apply to improving sweep efficiency in both continuous recovery processes, such as steam-assisted gravity drainage (SAGD), expanding solvent SAGD (ES- SAGD), solvent-assisted SAGD (SA-SAGD), vapor extraction (VAPEX) or heated VAPEX, as well as cyclical processes, such as cyclic steam stimulation (CSS) and cyclic solvent process CSP).
E21B 43/22 - Use of chemicals or bacterial activity
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
E21B 43/241 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection combined with solution mining of non-hydrocarbon minerals, e.g. solvent pyrolysis of oil shale
A feedwell system for delivering a slurry to a separation vessel, the system comprising: a feedwell barrel for containing and controlling the slurry; one or more inlet pipes leading into the feedwell barrel for tangentially introducing the slurry into the feedwell barrel to cause the slurry to swirl around the feedwell barrel; and a series of spaced-apart baffles disposed around an inner perimeter of the feedwell barrel for dissipating inflow energy and limiting an internal circulation field within the feedwell barrel, wherein the series of spaced- apart baffles comprises one or more inlet baffles configured to direct the slurry downwardly in the feedwell barrel and against a direction of introduction of the slurry; the feedwell barrel having a bottom with an outlet therein to allow discharge of the slurry.
B01D 21/26 - Separation of sediment aided by centrifugal force
B01D 45/08 - Separating dispersed particles from gases or vapours by gravity, inertia, or centrifugal forces by utilising inertia by impingement against baffle separators
B01D 45/12 - Separating dispersed particles from gases or vapours by gravity, inertia, or centrifugal forces by centrifugal forces
A method includes providing a coarse sand tailings stream (CST) comprising sand, fines, clay, water, and bitumen; mixing the CST to liberate the bitumen from the sand and disperse the bitumen in the water to form a mixed CST stream; and separating the sand from the bitumen to form a bitumen-rich stream.
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
Disclosed is a method comprising providing an oil sand slurry stream stemming from an oil sand ore; processing the oil sand slurry stream into bitumen froth, middlings, and coarse sand tailings (CST), including using a primary separation cell (PSC); and adding an acidic process aid beneath a froth layer in the PSC or to the middlings, for reducing a pH level beneath the froth layer in the PSC or of the middlings, for assisting bitumen and air attachment and for reducing solids in the bitumen froth or a froth recycle stream.
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
A method comprises introducing an oil sand slurry stream to a primary separation cell (PSC) and forming a bitumen froth, a middlings stream, and a coarse sand tailings stream (CST); introducing the middlings stream to a flotation process and forming a recycle froth and a flotation tailings stream; and introducing CO2 into one or more of: i) the PSC, beneath a froth layer; ii) the middlings stream; and iii) the flotation process, for increasing bitumen recovery, sequestering carbon dioxide in the CST and/or the flotation tailings stream, increasing fines capture in the CST, or a combination thereof.
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
40.
SYSTEMS AND METHODS FOR DYNAMIC LIQUID LEVEL MONITORING AND CONTROL
Methods and systems for determining a liquid level above a horizontal segment of a wellbore in a formation are disclosed. Local temperatures and pressures are determined for each of a plurality of zones along the wellbore segment. For each zone, a local inflow rate is determined for fluids entering the wellbore from the formation. Based on the local inflow rate, local temperature, and local pressure, a local reservoir pressure is determined, and a local liquid level is determined based on the local reservoir pressure and a pressure associated with an injector wellbore positioned above the horizontal segment.
The present disclosure comprises methods to model the a solvent-based oil recovery process on an economic return basis as a function of the normal. boiling point (NBP) ranges of available solvents in order to provide the user a simple and encompassing method for selecting the appropriate solvent NBP from which to obtain a preferred solvent (i.e., solvent NBP range) or tailor the recovered solvent to within a specific NBP range for reinjection in solvent-based oil recovery process. The primary variables for building the economic function are Oil Production Rate (OPR), the Solvent + Steam to Oil Ratio (Sol+StOR), the Solvent to Oil Ratio (SolOR), the Steam to Oil Ratio (StOR), and the Energy to Oil Ratio (EnOR). This method can be utilized on any type of solvent-based oil recovery process or system.
C09K 8/58 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
C09K 8/592 - Compositions used in combination with generated heat, e.g. by steam injection
E21B 43/241 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection combined with solution mining of non-hydrocarbon minerals, e.g. solvent pyrolysis of oil shale
E21B 43/40 - Separation associated with re-injection of separated materials
42.
THERMAL RECOVERY METHODS FOR RECOVERING VISCOUS HYDROCARBONS FROM A SUBTERRANEAN FORMATION
Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation. The thermal recovery methods include performing a plurality of injection cycles. Each injection cycle in the plurality of injection cycles includes injecting a heated solvent vapor stream into a heated chamber that extends within the subterranean formation and fluidly contacting the viscous hydrocarbons with the heated solvent vapor stream to generate mobilized viscous hydrocarbons. Each injection cycle also includes injecting a steam stream into the heated chamber. The thermal recovery methods further include producing a chamber liquid and/or mobilized viscous hydrocarbons from the subterranean formation.
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
E21B 43/241 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection combined with solution mining of non-hydrocarbon minerals, e.g. solvent pyrolysis of oil shale
43.
ENHANCED METHODS FOR RECOVERING VISCOUS HYDROCARBONS FROM A SUBTERRANEAN FORMATION AS A FOLLOW-UP TO THERMAL RECOVERY PROCESSES
Enhanced methods for recovering viscous hydrocarbons from a subterranean formation as a follow-up to thermal recovery processes. The methods include injecting a solvent flood vapor stream into a first thermal chamber, which extends within the subterranean formation, via a solvent flood injection well that extends within the first thermal chamber. The injecting includes injecting to generate solvent flood-mobilized viscous hydrocarbons within the subterranean formation. The methods also include, at least partially concurrently with the injecting, producing the solvent flood-mobilized viscous hydrocarbons from a second thermal chamber, which extends within the subterranean formation, via a solvent flood production well that extends within the second thermal chamber. The first thermal chamber was formed via a first thermal recovery process, and the second thermal chamber was formed via a second thermal recovery process, and the first thermal chamber and the second thermal chamber are in fluid communication with one another.
Methods of recovering viscous hydrocarbons from a subterranean formation. The methods include injecting a first solvent-steam vapor mixture into the subterranean formation for a first injection time period to maintain a target operating pressure within the subterranean formation. The methods also include transitioning, during a transition time period, from injecting the first solvent-steam vapor mixture to injecting a second solvent- steam vapor mixture, and further include injecting the second solvent-steam vapor mixture for a second injection time period. The methods further include producing mobilized viscous hydrocarbons from the subterranean formation. The first solvent has a first dew point temperature and is injected under near-azeotropic conditions. The second solvent has a second dew i)oint temperature that is less than the first dew point temperature.
The present disclosure relates to production of a bitumen product from a subterranean reservoir with improved processes for solvent recovery at end of production or near end of production (i.e., "late life") of heavy oil from a solvent-based heavy oil extraction process. The process Include converting at least some of the wells in the subterranean reservoir, and injecting gas phase dilution agent into the reservoir, converting at least a portion of the liquid solvent to a gas phase, and recovering, in the vapor phase, at least a portion of the solvent remaining in the reservoir.
E21B 43/22 - Use of chemicals or bacterial activity
E21B 43/241 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection combined with solution mining of non-hydrocarbon minerals, e.g. solvent pyrolysis of oil shale
46.
USE OF A POLYSACCHARIDE TO ASSIST FINES CAPTURE IN OIL SAND TAILINGS
A method including providing an oil sand tailings stream and introducing a polysaccharide into the oil sand tailings stream to assist fines capture in a resultant treated oil sand tailings stream.
B03B 9/02 - General arrangement of separating plant, e.g. flow sheets specially adapted for oil-sand, oil-chalk, oil-shales, ozokerite, bitumen, or the like
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
47.
RECOVERY OF HEAVY OIL FROM A SUBTERRANEAN RESERVOIR
The present disclosure to provide systems and methods. for regulation of asphaltene production in a solvent-based recovery process and selecting a hydrocarbon solvent mixture composition of a hydrocarbon solvent mixture, including systems and methods for improving bitumen recovery in a solvent-based recovery process by utilizing a near- azeotropic steam/hydrocarbon solvent injection process which includes determining a target asphaltene content for a reservoir heavy oil product stream produced from a subterranean reservoir and tailoring the steam and hydrocarbon solvent composition and content for maximization of desired asphaltene control and injecting the tailored the steam and hydrocarbon solvent composition into the subterranean reservoir at near azeotropic conditions.
Methods to optimize solvent use in solvent-dominated processes for recovery of hydrocarbons are disclosed herein. In some embodiments, disclosed methods include injecting a solvent composition into a reservoir at a pressure above a liquid/vapor phase change of the solvent composition; injecting a chaser into the reservoir at a pressure above the liquid/vapor phase change of the solvent composition; allowing the solvent composition to mix with hydrocarbons in the reservoir and at least partially dissolve into the hydrocarbons to produce a solvent/hydrocarbon mixture; reducing the pressure in the reservoir below the liquid/vapor phase change pressure of the solvent composition thereby flowing at least a fraction of the solvent/hydrocarbon mixture from the reservoir; and repeating these steps as required.
Disclosed is a water-based oil sand extraction method including introducing a feed stream comprising bitumen, solids, and water into an extraction vessel; and introducing a froth overwash into the extraction vessel above a froth layer in the extraction vessel for facilitating solids removal from the froth layer.
B03B 9/02 - General arrangement of separating plant, e.g. flow sheets specially adapted for oil-sand, oil-chalk, oil-shales, ozokerite, bitumen, or the like
A method comprising providing a bitumen extract stemming from solvent-based extraction, the bitumen extract comprising bitumen, water, and solids; adding a diluent to the bitumen extract to produce a diluted bitumen stream; and separating, by enhanced gravity separation, the diluted bitumen stream into a diluted bitumen product and tailings. The diluent is added in an amount sufficient to precipitate asphaltenes such that the diluted bitumen product has a C5 asphaltene precipitation of between 0.1 and 30%.
B01D 11/04 - Solvent extraction of solutions which are liquid
B01D 21/26 - Separation of sediment aided by centrifugal force
B03B 9/02 - General arrangement of separating plant, e.g. flow sheets specially adapted for oil-sand, oil-chalk, oil-shales, ozokerite, bitumen, or the like
A method including introducing an oil sand tailings stream into a classifier and producing a dewatered solids stream and a water-bitumen stream. By separating tailings in this way, it will be possible to increase fines capture or recover thermal energy or bitumen from the tailings.
B01D 21/01 - Separation of suspended solid particles from liquids by sedimentation using flocculating agents
B03B 9/02 - General arrangement of separating plant, e.g. flow sheets specially adapted for oil-sand, oil-chalk, oil-shales, ozokerite, bitumen, or the like
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
52.
SYSTEMS AND METHODS FOR PRODUCING VISCOUS HYDROCARBONS FROM A SUBTERRANEAN FORMATION THAT INCLUDES OVERLYING INCLINED HETEROLITHIC STRATA
Systems and methods for producing viscous hydrocarbons from a subterranean formation that includes overlying inclined heterolithic strata are disclosed herein. The systems include the subterranean formation, which includes a lower zone and an overlying inclined heterolithic strata (IHS) zone. The systems also include a heated chamber within the lower zone, an IHS injection well extending within the IHS zone, and a mobilizing fluid supply system. The IHS injection well includes an IHS injection well conduit that is in direct fluid communication with the IHS zone, and the mobilizing fluid supply system is configured to provide a mobilizing fluid stream to the IHS injection well. The IHS injection well is configured to inject the mobilizing fluid stream into the IHS zone to facilitate flow of viscous hydrocarbons from the IHS zone. The methods include methods of utilizing the systems.
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
E21B 43/241 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection combined with solution mining of non-hydrocarbon minerals, e.g. solvent pyrolysis of oil shale
Disclosed is a method comprising providing a slurry stream comprising bitumen, water, and solids; measuring a natural radiation parameter of the slurry stream; based on the measured natural radiation parameter, obtaining an estimated fines to fluid mass ratio (FFR) of the slurry stream, and based on the estimated FFR, automatically adjusting a process parameter of an oil sand processing plant.
Disclosed is a method of controlling a water-based oil sand extraction process, the method comprising: a) providing a feed stream comprising oil sand; b) analyzing the feed stream to obtain a fines parameter indicative of a fines content of the feed stream; c) introducing the feed stream into a primary separation cell (PSC); d) withdrawing a bitumen froth from the PSC; e) withdrawing a middlings from the PSC; f) withdrawing a coarse sand tailings (CST) from the PSC; and g) adjusting a density gradient in the PSC based on the obtained fines parameter.
A method of froth quality improvement by high shear mixing of an oil sands froth including bitumen, water, and solids by shearing the bitumen froth to facilitate solids migration from a hydrocarbon phase to a water phase, to produce a sheared froth, and separating the sheared froth into sheared froth tailings, comprising solids and water, and a lower solids froth having a lower solids content by weight than the oil sands froth.
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
56.
PROCESS FOR RECOVERING SOLVENT FROM OIL SAND TAILINGS STREAMS
A method comprising providing a tailings stream comprising solvent, precipitated asphaltenes, mineral solids, residual maltenes, and water; and recovering a portion of the solvent from the tailings stream by vaporization in a viscous fluid evaporator or particulate solid desolventizer to produce desolventized tailings and a recovered solvent stream.
B01D 3/00 - Distillation or related exchange processes in which liquids are contacted with gaseous media, e.g. stripping
B03B 9/02 - General arrangement of separating plant, e.g. flow sheets specially adapted for oil-sand, oil-chalk, oil-shales, ozokerite, bitumen, or the like
B09C 1/06 - Reclamation of contaminated soil thermally
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
57.
A METHOD FOR IMPROVING PARAFFINIC FROTH TREATMENT PROCESS IN OIL SANDS EXTRACTION
An unfiltered paraffinic froth treatment (PFT) process. A method for improving a paraffinic froth treatment (PFT) process in oil sands extraction includes identifying a flow path from a bitumen froth storage tank outlet, through a froth feed pump flow passage, a mixer flow passage, a debris filter flow passage, and a froth settling unit flow passage, to a tailings solvent recovery unit inlet passage, identifying a minimum flow passage size in the flow path, excluding the debris filter flow passage, and enlarging the flow path to at least the minimum flow passage size, and removing the debris filter from the flow path, wherein a filterless PFT process is provided.
C10C 3/08 - Working-up pitch, asphalt, bitumen by selective extraction
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
Described is a solvent bitumen extraction with solids agglomeration method, the method comprising: (a) inerting a bituminous feed to produce an inerted bituminous feed; (b) adding a first solvent to the inerted bituminous feed and sizing the inerted bituminous feed to produce a sized bituminous feed; (c) contacting the sized bituminous feed with a first high velocity fluid; (d) dissolving the sized bituminous feed in the first high velocity fluid to produce a dissolved bituminous slurry; (e) contacting the dissolved bituminous slurry with a second high velocity fluid to produce an agglomerated slurry; and (f) filtering, washing with a second solvent and desolventizing the agglomerated slurry.
C10C 3/08 - Working-up pitch, asphalt, bitumen by selective extraction
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
59.
PROCESSING OF OIL SAND STREAMS VIA CHEMICALLY-INDUCED MICRO-AGGLOMERATION
Disclosed is a method comprising providing an oil sand stream comprising bitumen, solids, and water; conditioning the oil sand stream with an aluminate to produce a conditioned stream; treating the conditioned stream with a silicate to produce a treated stream comprising chemically-induced micro-agglomerates to assist bitumen extraction or froth cleaning; and processing the treated stream to form a bitumen stream and a tailings stream.
B03B 9/02 - General arrangement of separating plant, e.g. flow sheets specially adapted for oil-sand, oil-chalk, oil-shales, ozokerite, bitumen, or the like
Described is a method of processing a bitumen froth comprising bitumen, water, coarse solids, and fines, the method comprising: producing a pre-treated bitumen froth by adding a seeding stream comprising asphaltene-mineral solids to the bitumen froth, the asphaltene-mineral solids being for seeding asphaltene precipitation and for controlling asphaltene precipitate morphology; producing a diluted pre-treated bitumen froth by adding paraffinic solvent to the pre-treated bitumen froth; and forming an overflow and an underflow by gravity separating the diluted pre-treated bitumen froth.
C10C 3/08 - Working-up pitch, asphalt, bitumen by selective extraction
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
61.
PARAFFINIC FROTH TREATMENT WITH CONTROLLED AGGREGATION
A method comprising: a) producing a pre-treated bitumen froth by adding a seeding stream comprising asphaltene-mineral solids to a bitumen froth, the asphaltene- mineral solids being for seeding asphaltene precipitation and for controlling asphaltene precipitate morphology, wherein the seeding stream comprises less than 5 weight % hydrocarbon liquid, based on a total weight of the seeding stream; b) producing a diluted pre-treated bitumen froth by adding paraffinic solvent to the pre-treated bitumen froth; c) forming an overflow and an underflow by gravity separating the diluted pre-treated bitumen froth; d) adding additional paraffinic solvent to the underflow and gravity separating a resulting stream to produce a second underflow and a second overflow; e) recycling the second overflow into step b) as a source of the paraffinic solvent; and f) removing at least a portion of the paraffinic solvent from the second underflow by vaporization in a tailings solvent recovery unit.
B03B 9/02 - General arrangement of separating plant, e.g. flow sheets specially adapted for oil-sand, oil-chalk, oil-shales, ozokerite, bitumen, or the like
Described is a process comprising: a) adding a bitumen froth comprising bitumen, water, and solids to a froth settling unit (FSU); b) following settling in the FSU, producing a first hydrocarbon-rich overflow and a first solids-rich underflow from the FSU; c) passing the first solids-rich underflow to a froth settling unit (FSU-2), and following settling in the FSU-2, forming a second hydrocarbon-rich overflow and a second solids-rich underflow; d) adding a first portion of the second hydrocarbon-rich overflow to the FSU; e) sending a second portion of the second hydrocarbon-rich overflow to a separations unit; f) removing at least a portion of a first paraffinic solvent from the second hydrocarbon-rich overflow in the separations unit to form a first solvent-rich recovery stream and a first solvent-lean recycle stream; g) adding at least a portion of the solvent-lean recycle stream to the first hydrocarbon-rich overflow to form a combined stream; and h) adding a second paraffinic solvent to the first solids-rich underflow.
C10C 3/08 - Working-up pitch, asphalt, bitumen by selective extraction
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
Described is a process comprising: a) adding a bitumen froth comprising bitumen, water, and solids to a froth settling unit (FSU); b) following settling in the FSU, producing a first hydrocarbon-rich overflow and a first solids-rich underflow from the FSU; c) passing the solids-rich underflow to a froth settling unit (FSU-2), and following settling in the FSU-2, forming a second hydrocarbon-rich overflow and a second solids-rich underflow; d) adding the second hydrocarbon-rich overflow to the FSU; e) adding a first paraffinic solvent to the second hydrocarbon-rich overflow; and f) adding a second paraffinic solvent to the first solids-rich underflow.
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
Described is a paraffinic froth treatment (PFT) process. Paraffinic solvent and a bitumen froth comprising bitumen, water, and solids are added to a froth settling unit (FSU). Following settling in the FSU, hydrocarbon-rich overflow and a solids-rich underflow is produced from the FSU. A portion of the solids-rich underflow is recirculated into the FSU via a recirculation stream for increasing bitumen recovery.
B03B 9/02 - General arrangement of separating plant, e.g. flow sheets specially adapted for oil-sand, oil-chalk, oil-shales, ozokerite, bitumen, or the like
Disclosed is a method comprising: a) providing a slurry intended as a feed stream to a solid-liquid separation process; b) removing a slip stream from the slurry; c) measuring at least a portion of the slip stream at a plurality of additive dosage levels to obtain a characteristic indicative of a degree of flocculation, agglomeration, or aggregation for each of the plurality of additive dosage levels; and d) adjusting the solid-liquid separation process.
Disclosed is a method comprising: a) providing a slurry intended as a feed to a solid-liquid separation process; b) removing a slip stream from the slurry; and c) measuring at least a portion of the slip stream at a plurality of additive dosage levels to obtain a characteristic indicative of a degree of flocculation, agglomeration, or aggregation for each of the plurality of additive dosage levels.
B01D 21/00 - Separation of suspended solid particles from liquids by sedimentation
B03B 9/02 - General arrangement of separating plant, e.g. flow sheets specially adapted for oil-sand, oil-chalk, oil-shales, ozokerite, bitumen, or the like
67.
RECOVERING HYDROCARBONS FROM AN UNDERGROUND RESERVOIR
A process for recovering hydrocarbons from an underground reservoir may include injecting an injected fluid into the underground reservoir; halting injection and subsequently producing at least a fraction of the injected fluid and the hydrocarbons from the underground reservoir; halting production; repeating the aforementioned steps; injecting a flooding fluid to move residual hydrocarbons towards a flooding production well for further production; and producing at least a fraction of the flooding fluid and the residual hydrocarbons.
A method for treating mine waste is described. The method includes forming a flocculated stream by adding a first flocculant to a waste stream derived from a water based extraction of bitumen from oil sands. The waste stream comprises fine particles and solids. The flocculated stream is transported to a disposal area. A reflocculated stream is formed by adding a second flocculant to the flocculated stream after transporting the flocculated stream. The reflocculated stream is deposited in a deposition area within the disposal area. The first flocculant and the second flocculant comprise a non-ionic polymer and an anionic polymer.
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
A method for processing a bituminous feed includes forming an oil sand slurry, including a bitumen extract and solids, by contacting the bituminous feed with a first extraction liquor; forming a rich bitumen extract stream and separated solids by separating the solids from the bitumen extract; forming a washed solids stream and a lean bitumen extract stream, including precipitated asphaltenes, by washing the separated solids with an aliphatic solvent; forming a deasphalted lean bitumen extract stream by separating the precipitated asphaltenes from the lean bitumen extract stream; and obtaining a bitumen product stream by removing the first solvent from at least one of a first portion of the rich bitumen extract stream and a first portion of the deasphalted lean bitumen extract stream.
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
A method for processing a bituminous feed includes forming an oil sand slurry, including a bitumen extract and solids, by contacting the bituminous feed with a first extraction liquor; forming a rich bitumen extract stream and separated solids by separating the solids from the bitumen extract; forming a washed solids stream and a lean bitumen extract stream, including precipitated asphaltenes, by washing the separated solids with an aliphatic solvent; forming a deasphalted lean bitumen extract stream by separating the precipitated asphaltenes from the lean bitumen extract stream; and obtaining a bitumen product stream by removing the first solvent from at least one of a first portion of the rich bitumen extract stream and a first portion of the deasphalted lean bitumen extract stream.
B01D 21/00 - Separation of suspended solid particles from liquids by sedimentation
B03B 9/02 - General arrangement of separating plant, e.g. flow sheets specially adapted for oil-sand, oil-chalk, oil-shales, ozokerite, bitumen, or the like
71.
METHODS FOR PROCESSING DILUTED BITUMEN FROTH OR FROTH TREATMENT TAILINGS
A method for processing diluted bitumen froth or froth treatment tailings including bitumen and solvent. The method includes forming a settler overflow and a settler underflow by gravity separating the diluted bitumen froth or the froth treatment tailings in a settler; forming a hydrocyclone overflow and a hydrocyclone underflow by separating the settler underflow in a hydrocyclone; and recycling the hydrocyclone overflow to the settler.
C02F 1/00 - Treatment of water, waste water, or sewage
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
72.
METHODS FOR PROCESSING AN OIL SAND SLURRY OR A BITUMEN EXTRACT STREAM
A method may include providing a bitumen extract stream, having bitumen dissolved in a first solvent, and suspended fines; separating the bitumen extract stream into a concentrated fines stream and a low fines bitumen extract stream; producing agglomerated fines by agglomerating the concentrated fines stream; forming washed agglomerated fines by washing the agglomerated fines with a washing solvent that removes residual bitumen extract from the agglomerated fines; producing dry solids by removing the washed solvent from the washed agglomerated fines; and producing a bitumen product stream by removing the first solvent from the low fines bitumen extract stream.
C02F 1/52 - Treatment of water, waste water, or sewage by flocculation or precipitation of suspended impurities
C10C 3/08 - Working-up pitch, asphalt, bitumen by selective extraction
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
A method for processing a bituminous feed may include providing a first bituminous feed having at least one first bituminous feed property falling outside of a target range; selecting a second bituminous feed having at least one second bituminous feed property that has a different value than the at least one first bituminous feed property; selecting a ratio of the first bituminous feed to the second bituminous feed; forming a third bituminous stream, having at least one third bituminous feed property falling within the target range, by combining the first bituminous feed and the second bituminous feed at the ratio; and passing the third bituminous feed to a solvent extraction process for extracting bitumen from the third bituminous feed.
C10C 3/08 - Working-up pitch, asphalt, bitumen by selective extraction
C10G 1/00 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
A method for processing a bituminous feed may include providing the bituminous feed having a bituminous feed water content outside of a target range; selecting a flue gas from a combustion process having a flue gas water content that is different than the bituminous feed water content; forming a resultant bituminous feed with a resultant bituminous feed water content within the target range by contacting the bituminous feed and the flue gas; and passing the resultant bituminous feed to a solvent extraction process for extracting bitumen from the resultant bituminous feed.
Disclosed is a method of processing a bituminous feed including: a) contacting the bituminous feed with a solvent to form a slurry; b) adding a bridging liquid to the slurry and flowing the slurry to agitate solids within the slurry to form an agglomerated slurry comprising agglomerates and a low solids bitumen extract; c) measuring a characteristic of the slurry at one or more points along the slurry flow; d) adjusting the bridging liquid addition to the slurry based on the characteristic; and e) separating the agglomerates from the low solids bitumen extract.
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
76.
GRAVITY DRAINAGE PROCESS FOR RECOVERING VISCOUS OIL USING NEAR-AZEOTROPIC INJECTION
Generally, described herein is a gravity drainage process for recovering viscous oil from an underground reservoir, the process comprising: (a) injecting steam and a solvent into the reservoir to mobilize the viscous oil, wherein the solvent is in a vapor state, and the steam and solvent are injected wherein the solvent molar fraction of the combined steam and solvent is 70-100% of the azeotropic solvent molar fraction of the steam and the solvent as measured at the reservoir operating pressure; and (b) producing at least a fraction of the mobilized oil, the solvent, and water.
Systems and methods for controlling a flow of fluid through an orifice in a flow control device. The systems and methods may include applying an erosion and/or corrosion resistant layer on a surface of the flow control device around an opening of the orifice for reducing or preventing erosion and/or corrosion and for maintaining a size of the opening.
In an oil sand treatment process, disclosed is a method including: (a) providing an oil sand stream; (b) splitting the oil sand stream or a slip stream thereof into a finer solids fraction and a coarser solids fraction based on a predetermined solids size threshold; (c) analyzing the finer solids fraction to obtain a finer solids fraction solids flow rate; (d) analyzing the coarser solids fraction to obtain a coarser solids fraction solids flow rate; and based on c) and d), obtaining a solids percentage, wherein the solids percentage is a percentage of solids in the oil sand stream that are above or below the predetermined solids size threshold.
B03B 9/02 - General arrangement of separating plant, e.g. flow sheets specially adapted for oil-sand, oil-chalk, oil-shales, ozokerite, bitumen, or the like
79.
PROCESS FOR ENHANCING SOLIDS REDUCTION IN BITUMEN PROCESSING
A process for treating bitumen froth comprising a hydrocarbon solvent comprises: adding a settling agent to enhance solids settling in the bitumen froth, and removing settled solids from the bitumen froth to obtain a low solids content bitumen product. Further, a process for treating a bitumen emulsion comprising a first water phase, a first oil phase, and solids, comprises: adding a settling agent to the bitumen emulsion, for enhancing separation of the solids into the water phase of the bitumen emulsion; and separating the bitumen emulsion into a second water phase containing the majority of the solids present in the bitumen emulsion and a second oil phase containing the majority of the bitumen present in the bitumen emulsion to produce a low solids content bitumen product.
B01D 21/01 - Separation of suspended solid particles from liquids by sedimentation using flocculating agents
B03B 9/02 - General arrangement of separating plant, e.g. flow sheets specially adapted for oil-sand, oil-chalk, oil-shales, ozokerite, bitumen, or the like
C08J 3/00 - Processes of treating or compounding macromolecular substances
C08L 95/00 - Compositions of bituminous materials, e.g. asphalt, tar or pitch
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
80.
REGULATION OF ASPHALTENE PRODUCTION IN A SOLVENT-BASED RECOVERY PROCESS AND SELECTION OF A COMPOSITION OF A HYDROCARBON SOLVENT MIXTURE
Regulating asphaltene production in a solvent-based recovery process may include determining a bituminous hydrocarbon deposit composition of a bituminous hydrocarbon deposit that includes asphaltenes, selecting a hydrocarbon solvent mixture composition of a hydrocarbon solvent mixture, injecting the hydrocarbon solvent mixture into a solvent extraction chamber, producing a product hydrocarbon stream from the subterranean formation, determining a product hydrocarbon stream asphaltene content of the product hydrocarbon stream, and comparing the product hydrocarbon stream asphaltene content to a target asphaltene content for the product hydrocarbon stream.
Methods and apparatus for obtaining a heavy oil product from a mixture of a first solvent and heavy oil. If the heavy oil product is to contain asphaltenes, the method includes forming a treated mixture by treating the mixture to prevent substantial precipitation of heavy end components; and producing a recovered solvent and the heavy oil product by separating a portion of the solvent from the treated mixture. If the heavy oil product is to have a lower quantity of asphaltenes than the asphaltenes in the mixture, the method includes forming a treated mixture containing asphaltenes by treating the mixture to cause precipitation of asphaltenes; providing separated asphaltenes and a separated treated mixture by separating the asphaltenes from the treated mixture; and producing a recovered solvent and the heavy oil product by separating a portion of the solvent from the separated treated mixture.
C10G 21/02 - Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents with two or more solvents, which are introduced or withdrawn separately
C10G 53/04 - Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes plural serial stages only including at least one extraction step
82.
METHODS AND APPARATUSES FOR OBTAINING A HEAVY OIL PRODUCT FROM A MIXTURE
Methods and apparatus for obtaining a heavy oil product from a mixture of a first solvent and heavy oil. If the heavy oil product is to contain asphaltenes, the method includes forming a treated mixture by treating the mixture to prevent substantial precipitation of heavy end components; and producing a recovered solvent and the heavy oil product by separating a portion of the solvent from the treated mixture. If the heavy oil product is to have a lower quantity of asphaltenes than the asphaltenes in the mixture, the method includes forming a treated mixture containing asphaltenes by treating the mixture to cause precipitation of asphaltenes; providing separated asphaltenes and a separated treated mixture by separating the asphaltenes from the treated mixture; and producing a recovered solvent and the heavy oil product by separating a portion of the solvent from the separated treated mixture.
B01D 11/04 - Solvent extraction of solutions which are liquid
C09K 8/592 - Compositions used in combination with generated heat, e.g. by steam injection
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
C10G 21/02 - Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents with two or more solvents, which are introduced or withdrawn separately
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
E21B 43/34 - Arrangements for separating materials produced by the well
83.
PRODUCT CLEANING OF BITUMEN EXTRACTED FROM OIL SANDS SOLVENT EXTRACTION PROCESSES
A bitumen extract stemming from solvent-based extraction and an aliphatic solvent are counter-currently passed through one another to produce a light phase comprising deasphalted oil and aliphatic solvent, and a heavy phase comprising asphaltenes, water, and solids.
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
84.
METHODS OF RECOVERING HEAVY OIL FROM A SUBTERRANEAN RESERVOIR
A method of recovering heavy oil from a subterranean reservoir may include injecting a mixture of steam and solvent into the subterranean reservoir to form a liquid comprising the heavy oil and the solvent in condensed form; recovering the heavy oil and at least a portion of the solvent from the subterranean reservoir by producing the liquid from the subterranean reservoir. The heavy oil is residual heavy oil. The mixture may have a concentration of the solvent close to or above an azeotrope concentration for the mixture at a pressure of the subterranean reservoir.
Methods and systems are disclosed for managing pressure and recovering heavy oil. A method may include providing a gas cap injection well in a gas cap raising a gas cap pressure in the gas cap to a target pressure by injecting a non-condensable gas into the gas cap via the gas cap injection well and maintaining the gas cap pressure at the target pressure by at least one of (i) injecting the non-condensable gas into the gas cap via the gas cap injection well and (ii) producing gas from the gas cap through the gas cap injection well.
Disclosed is a process including feeding a diluted bitumen froth into a settler to form a hydrocarbon-rich layer and a water-rich layer, and an interface layer therebetween, and raising and lowering the interface layer by controlling diluted bitumen froth feeding, underflow outflow, or overflow outflow, or a combination thereof, for improving separation.
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
A bituminous feed is fed into a jet pump. A motive fluid, comprising a solvent for extracting bitumen, is provided to the jet pump for mixing with the bituminous feed. A conditioned slurry is discharged from the jet pump. The conditioned slurry is agglomerated to create an agglomerated slurry. ,
C10C 3/08 - Working-up pitch, asphalt, bitumen by selective extraction
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
88.
RECOVERING HYDROCARBONS FROM AN UNDERGROUND RESERVOIR
Disclosed herein is a composition for mitigating the presence of a second liquid phase in an underground hydrocarbon reservoir, in the wellbore, or in surface facilities of a solvent dominated recovery process (SDRP). A goal of mitigating the presence of the second liquid phase is to improve flow assurance in the reservoir, in the wellbore, or in surface facilities. In a SDRP, the viscosity-reducing component may be combined with a high-aromatics component, for instance one comprising at least 60 wt. % aromatics, based upon total weight of the high-aromatics component.
Disclosed is a solvent dominated recovery process for recovering hydrocarbons from an underground reservoir. The process uses a solvent mixture that exhibits liquid- vapor phase behavior over a range pressures from P1 to P2 (P1
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 43/22 - Use of chemicals or bacterial activity
E21B 43/241 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection combined with solution mining of non-hydrocarbon minerals, e.g. solvent pyrolysis of oil shale
Disclosed is a process including providing a bitumen froth comprising bitumen, water, and solids. A paraffinic solvent is added to the bitumen froth in an amount below an asphaltene precipitation point to form a diluted bitumen froth. Water is removed from the diluted bitumen froth to form a dewatered diluted bitumen froth. Additional paraffinic solvent is added to the dewatered diluted bitumen froth in an amount above an asphaltene precipitation point for precipitating asphaltene aggregates. The dewatered diluted bitumen froth is separated to form a hydrocarbon-rich stream and a solids-rich stream.
C10C 3/08 - Working-up pitch, asphalt, bitumen by selective extraction
C10G 1/04 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
91.
A METHOD OF ENHANCING RESOURCE RECOVERY FROM SUBTERRANEAN RESERVOIRS
A method of recovering heavy oil from a subterranean reservoir includes providing an infill well, injecting injected fluid via an infill well, producing produced fluid from the infill well and producing heavy oil from at least one of the infill well and a production well. The infill well may be placed in an area laterally spaced apart from a thermal recovery well pair. The thermal recovery well pair may include an injection well for injecting injection vapor to form a vapor chamber and the production well. The injected fluid may be injected at a time during which the injected fluid establishes a horizontal planar communication path between the infill well and the vapor chamber. The horizontal planar communication path enables generally horizontal planar distribution of the injection vapor to provide horizontal planar communication. The produced fluid at least partially removes heavy oil from the horizontal planar communication path.
Generally, described herein is a gravity drainage process for recovering viscous oil from an underground reservoir. The process includes injecting a mobilizing composition including steam and a diluent through an injection well into the reservoir to mobilize the viscous oil. The mobilizing composition is alternated between a first diluent to steam volume ratio (DSR1) of 0.05-0.5 and a second diluent to steam volume ratio (DSR2) of 0-0.3. The DSR1 is at least 0.05 greater than the DSR2. The process also includes producing the viscous oil and at least a fraction of the mobilizing composition from the reservoir through a production well.
C09K 8/592 - Compositions used in combination with generated heat, e.g. by steam injection
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
E21B 43/241 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection combined with solution mining of non-hydrocarbon minerals, e.g. solvent pyrolysis of oil shale
93.
MOBILIZING COMPOSITION FOR USE IN GRAVITY DRAINAGE PROCESS FOR RECOVERING VISCOUS OIL AND START-UP COMPOSITION FOR USE IN A START-UP PHASE OF A PROCESS FOR RECOVERING VISCOUS OIL FROM AN UNDERGROUND RESERVOIR
Generally, described herein is a mobilizing composition for use in a gravity drainage process for recovering viscous oil from an underground reservoir. The mobilizing composition may comprise (i) 75-98 vol. % diluting agent; (ii) 2-25 vol. % steam having a steam quality of at least 5%; and (iii) 0-5 vol. % accelerating agent for accelerating penetration of the diluting agent into the viscous oil.Also generally described herein is a start-up composition for use in a start-up phase of a process for recovering viscous oil from an underground reservoir. The start-up composition comprises (i) 74.9-97.9 vol. % diluting agent; (ii) 2-25 vol. % steam having a steam quality of at least 5%; and (iii) 0.1-5 vol. % accelerating agent for accelerating penetration of the diluting agent into the viscous oil.
A method of recovering heavy oil from a subterranean heavy oil reservoir. The method includes conducting an exothermic chemical reaction of feedstock chemicals to produce a reaction product that that is a first solvent and injecting an injected solvent including the reaction product into the subterranean heavy oil reservoir. The injected solvent has an injected solvent temperature equal to an elevated temperature resulting from heat generated by the at least one exothermic chemical reaction and the injecting occurs before the injected solvent temperature has decreased to an ambient reservoir temperature.
A method of establishing fluid communication between a first point and a second point within a subterranean reservoir includes injecting a first penetrating liquid at a first injection pressure and at a first injection temperature into the subterranean reservoir at the first point, and establishing fluid communication through a heavy-oil containing region by allowing the first penetrating liquid to penetrate into and completely through the heavy-oil containing region between the first point and the second point. The first penetrating liquid temperature of the first penetrating liquid remains at or below the first injection temperature within the subterranean reservoir, and the first penetrating liquid is configured to dilute heavy oil, and comprises a first penetrating liquid polar compound that is at least partially miscible with water.
A method of recovering heavy oil from a subterranean reservoir. The method includes injecting steam into a subterranean reservoir to heat heavy oil in the subterranean reservoir and thereby produce heavy oil of reduced viscosity; injecting a multi-purpose agent into the subterranean reservoir; and producing the heavy oil of reduced viscosity from the subterranean reservoir after injecting the steam and the multi-purpose agent. The multi-purpose agent comprises an ester of the formula R x COOR y wherein R x is a straight chained or branched alkyl group having 1 to 8 carbon atoms, R y is a straight chained or branched alkyl group having 1 to 12 carbon atoms, C is carbon and O is oxygen.
A process for reducing a solids content of a bituminous slurry, the process comprising: feeding the bituminous slurry into a vessel comprising a rod having a magnetic portion for attracting magnetic solids in the bituminous slurry; rotating an auger disposed lengthwise around the rod to move the magnetic solids downstream and out of the vessel producing a reduced solids content slurry in the vessel after feeding the bituminous slurry and rotating the auger; and removing the reduced solids content slurry from the vessel.
C10G 1/00 - Production of liquid hydrocarbon mixtures from oil shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
C10G 32/02 - Refining of hydrocarbon oils by electric or magnetic means, by irradiation, or by using microorganisms by electric or magnetic means
Methods and apparatus for recovering heavy oil from subterranean reservoirs. A steam-utilizing heavy oil recovery process may be used to recover the heavy oil while employing a steam-solvent mixture. The solvent may be a tailored hydrocarbon solvent obtained from a precursor mixture of hydrocarbon compounds from which light end hydrocarbon compounds have been removed.
E21B 43/22 - Use of chemicals or bacterial activity
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
E21B 43/241 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection combined with solution mining of non-hydrocarbon minerals, e.g. solvent pyrolysis of oil shale
Methods and apparatus for recovering heavy oil from subterranean reservoirs. A steam-utilizing heavy oil recovery process may be used to recover the heavy oil while employing a steam-solvent mixture. The solvent may be a tailored hydrocarbon solvent obtained from a precursor mixture of hydrocarbon compounds from which light end hydrocarbon compounds have been removed. The invention provides a method of producing a tailored solvent useful for a steam-utilizing heavy oil recovery process. The invention also provides an apparatus for producing such a tailored solvent.
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
E21B 43/241 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection combined with solution mining of non-hydrocarbon minerals, e.g. solvent pyrolysis of oil shale
E21B 43/40 - Separation associated with re-injection of separated materials
100.
SYSTEMS AND METHODS FOR ENHANCING PRODUCTION OF VISCOUS HYDROCARBONS FROM A SUBTERRANEAN FORMATION
Systems and methods for enhancing production of viscous hydrocarbons from a subterranean formation. The methods may include heating a hydrocarbon solvent mixture to generate a vapor stream, injecting the vapor stream into the subterranean formation to generate reduced-viscosity hydrocarbons, and producing the reduced-viscosity hydrocarbons from the subterranean formation. The methods also may include selecting a composition of the hydrocarbon solvent mixture by determining a threshold maximum pressure of the subterranean formation, determining a stream temperature at which the vapor stream is to be injected into the subterranean formation, and selecting the composition of the hydrocarbon solvent mixture based upon the stream temperature and the threshold maximum pressure. The systems may include a hydrocarbon production system that may be configured to perform the methods and/or that may include an injection well, an injectant supply assembly, and a production well.
