A de-asphalting system for solvent de-asphalting including a desasphalter and a controller. The deasphalter defines a contacting zone and a separation zone. The contact zone contacts a feed, including asphaltenes, and a solvent to form a mixture, where the contacting of the feed and the solvent causes at least a portion of the asphaltenes to precipitate out of the mixture. The contacting is disposed at an operating temperature. The separation zone separates the mixture into a de-asphalted oil-comprising material fraction ("S+PDAO") and a asphaltene-rich material fraction. The asphaltene-rich material fraction includes the precipitated asphaltenes. The controller controls at least one operating parameter of the deasphalter based on at least on a refractive index of the S+PDAO phase. The operating parameter is selected from: the operating temperature; the composition of the feed; the composition of the solvent; a ratio of the mass of precipitated asphaltenes to the mass of asphaltenes within the feed; and a ratio of the mass of the solvent to the mass of the feed.
In one aspect, there is provided a process for producing hydrocarbons from a reservoir, comprising: within the reservoir, electrically heating a liquid heating fluid such that the liquid heating fluid is evaporated to produce a gaseous heating fluid that heats the liquid hydrocarbon material within the reservoir such that the heated liquid hydrocarbon material is mobilized and such that the gaseous heating fluid is condensed to produce a condensed heating fluid, wherein the liquid heating fluid includes at least a fraction of the condensed heating fluid such that at least a fraction of the condensed heating fluid is refluxed; and producing a fluid including the mobilized hydrocarbon material; wherein the hydrocarbon reservoir is spaced apart from the earth's surface by a minimum distance of less than 75 metres.
Aspects of the present disclosure may provide devices, systems and methods for modelling resource production for which there may be incomplete information and/or unknown parameters. In some embodiments, the method includes applying an analytical fracture model and reducing a the number of models to be matched in a set of potential subterranean formation models.
There is provided a process for producing hydrocarbon material from a reservoir, comprising: cooling at least a portion of a low permeability zone within the reservoir with effect that water, disposed within the low permeability zone, freezes and expands, with effect that one or more flow paths are formed through the low permeability zone; mobilizing hydrocarbon material within the reservoir such that the mobilized hydrocarbon material is conducted through the low permeability zone via the one or more flow paths; and after the conduction of the mobilized hydrocarbon material through the low permeability zone via the one or more flow paths, producing the mobilized hydrocarbon material.
There is provided a method of producing hydrocarbon material. A first hydrocarbon material is produced from the formation, the first hydrocarbon material including a gaseous hydrocarbon material originally in place in the formation. At least a portion of the produced gaseous hydrocarbon material is injected into the formation to increase the formation pressure. A second hydrocarbon material is produced from the formation.
A system for sensing an estimated composition of a produced fluid being conducted from a reservoir includes: at least one device for measuring temperature data; at least one device for obtaining flow rate data, pressure data, pump speed data and valve travel data; a first produced fluid density generator; a second produced fluid density generator; and a composition generator. The first produced fluid density generator is configured to generate a first produced fluid density based on the obtained flow rate, pressure, pump speed and valve travel data. The second produced fluid density generator is configured to generate a second produced fluid density based at least in part on the measured temperature data. The composition generator is configured to: iteratively generate a phantom component content, a bitumen content and a water content for the produced fluid based on at least in part on: a material balance of the produced fluid.
G01N 9/36 - Analysing materials by measuring the density or specific gravity, e.g. determining quantity of moisture
G01F 1/74 - Devices for measuring flow of a fluid or flow of a fluent solid material in suspension in another fluid
G01N 11/02 - Investigating flow properties of materials, e.g. viscosity or plasticityAnalysing materials by determining flow properties by measuring flow of the material
A method for capturing hydrocarbons from a formation is provided. After a first hydraulic fracturing of a formation to produce a first conditioned formation, and while hydrocarbons are being produced from the first conditioned formation, a predetermined wellbore characteristic is monitored for. The predetermined wellbore characteristic is based on at least a pressure within the first conditioned formation. After detecting the predetermined wellbore characteristic, a second hydraulic fracturing of the formation is effected to produce a second conditioned formation.
A hydrocarbon producing process comprising operating a first thermally-actuated gravity drainage-based process with a first well pair within a first communication zone, wherein the first thermally- actuated gravity drainage-based process includes injecting a mobilizing gaseous material into the first communication zone via an injection well of the first well pair such that hydrocarbon material is mobilized, and producing mobilized hydrocarbon material that has drained into a production well of the first well pair; operating a second thermally-actuated gravity drainage-based process with a second well pair within a second communication zone, wherein the second thermally-actuated gravity drainage-based process includes injecting a mobilizing gaseous material into the second communication zone via an injection well of the second well pair such that hydrocarbon material is mobilized, and producing mobilized hydrocarbon material that has drained into a production well of the second well pair; and after a drive process pre-condition has been established, and while a heated gaseous material is at least being supplied to the first communication zone via an injection well of one of the well pairs, applying a pressure differential across the first and second communication zones; wherein the drive process pre-condition has been established when: (a) the first and second communication zones have merged; or (b) the viscosity of hydrocarbon material within an intermediate reservoir region disposed between the first and second communication zones becomes sufficiently low such that the hydrocarbon material is capable of being mobilized in response to the application of a pressure differential; or (c) the minimum viscosity of hydrocarbon material, within the intermediate reservoir region becomes disposed below about 1200 centipoise; or (d) the minimum temperature within the intermediate reservoir region becomes disposed above 90 degrees Celsius.
Methods and systems for controlling operation of a plurality of wells are described. A system may include a plurality of control devices for adjusting the operational inputs of the plurality of wells; a plurality of input devices for measuring well conditions and production rates; and a controller having at least one processor. The at least one processor is configured for: generating models for each of the plurality of wells based on historical well data from the plurality of input devices, the models mapping a production rate based on at least one operational input; based on one or more defined total operational constraints across all of the plurality of wells and the models, determining a distribution of operational inputs across the plurality of wells or well portions which results in an optimal total production rate; and generating signals for applying, at the plurality of control devices, the operational inputs to the wells or portions of the wells in accordance with the determined distribution.
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
E21B 43/00 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
There is provided a process of stimulating a subterranean formation via a wellbore fluid passage of a cased wellbore. The process includes, with a perforating gun, perforating at least casing to form at least one or more perforations effecting fluid communication, via the wellbore fluid passage, between a first zone of the subterranean formation and a treatment fluid source. Treatment fluid is then injected via the wellbore fluid passage, from the treatment fluid source to the first zone such that fracturing of the first zone is effected. The injecting of the treatment fluid is then suspended. A perforating gun is then deployed within the wellbore fluid passage via wireline. The casing is then perforated to form at least one or more perforations effecting fluid communication, via the wellbore fluid passage, between a second zone of the subterranean formation and the treatment fluid source. While both of the first zone and the second zone are disposed in fluid communication, via the wellbore fluid passage, with the treatment fluid source, injecting treatment fluid from the treatment fluid source and into the wellbore fluid passage with effect that at least a fraction of the injected treatment fluid is directed to the second zone such that fracturing of the second zone is effected.
A process for producing hydrocarbon material from a hydrocarbon reservoir through a production well that is disposed in fluid communication with an injection well via an interwell region disposed within a communication zone, comprising: maintaining pressure within the communication zone above a predetermined high pressure during a high pressure production phase, and during at least a fraction of the high pressure production phase, supplying the first production-initiating fluid to the communication zone such that: mobilization of producible hydrocarbon material within the communication zone is effected, and such that the mobilized hydrocarbon material is conducted to the production well and produced via the production well; and at least a fraction of the supplied non-condensable gaseous material becomes dissolved within hydrocarbon material disposed within the communication zone; effecting a reduction in pressure of the communication zone from above the predetermined high pressure to below a predetermined low pressure such that at least a fraction of the dissolved non-condensable gaseous material becomes liberated from solution within the hydrocarbon material and, upon the liberation, expands and thereby at least contributes to driving the mobilized hydrocarbon material to the production well; after the effected reduction in pressure, maintaining pressure within the communication zone below the predetermined low pressure during a lower pressure production phase; effecting an increase in pressure of the communication zone from below the predetermined low pressure to above the predetermined low pressure; and repeating steps through, at least once.
Methods, devices and computer-readable media for predicting hydrocarbon production rates for a subterranean formation are described. A method includes: receiving or generating, by at least one processor, well logs from data collected from at least one well in the subterranean formation; generating from the well logs a predicted production rate log for the at least one well; receiving, by the at least one processor, a field dataset for the subterranean formation, the field dataset including field data at locations in 3-dimensions of a volume of the subterranean formation; identifying the predicted production rate log for the at least one well as one or more targets, determining a transform relating the field data and the predicted rate log for the at least one well; and using the transform, generating a predicted production rate for each location of the volume of the subterranean formation.
G01V 9/00 - Prospecting or detecting by methods not provided for in groups
G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
E21B 43/00 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
There is provided a process for producing hydrocarbons from a reservoir. The process includes within the hydrocarbon reservoir, electrically heating a liquid heating fluid such that the liquid heating fluid is evaporated to produce a gaseous heating fluid, heating hydrocarbon material with the gaseous heating fluid such that the heated hydrocarbon material is mobilized and such that the gaseous heating fluid is condensed to produce a condensed heating fluid, and electrically heating at least a fraction of the condensed heating fluid such that the at least a condensed heating fluid fraction is re-evaporated, and while the evaporation, the condensing, and the re-evaporation are being effected, producing a produced fluid including at least the mobilized hydrocarbon material.
Solvent is co-injected with steam during the start-up phase of a steam assisted gravity drainage ("SAGD") operation. As well solvent is co-injected with steam during the production phase of a SAGD operation. Both processes improve efficiencies for recovering bitumen from oil sands.
There is provided a process for upgrading a hydrocarbon material. The process includes: (a) treating a hydrocarbon material-comprising feed, wherein the treating includes cracking a hydrocarbon material-comprising feed, such that an upgraded intermediate is produced; and (b) in the absence, or the substantial absence, of adscititious diatomic hydrogen, reducing the content of olefinic material within at least a fraction of the upgraded intermediate such that an olefinic material content-reduced product is produced.
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
C10G 47/22 - Non-catalytic cracking in the presence of hydrogen
16.
METHOD FOR INCREASING GAS RECOVERY IN FRACTURES PROXIMATE FRACTURE TREATED WELLBORES
There is provided processes for producing gaseous hydrocarbon material from a subterranean formation, A process includes hydraulically fracturing the subterranean formation such that a connecting fracture is generated that extends from a lower well to an upper well, and such that gaseous hydrocarbon material is received within the connecting fracture in response to the hydraulic fracturing. Another process includes stimulating the subterranean formation, when the formation already includes the connecting fracture extending from a lower well to an upper well, such that gaseous hydrocarbon material is received within the connecting fracture in response to the stimulating.
A process for converting at least one synthesis gas, having a molar H2 to CO ratio between about 0.25 and 1, into at least one hydrocarbon, via Fischer-Tropsch synthesis by contacting the at least one synthesis gas with at least one catalyst, forming at least one hydrocarbon, wherein said at least one catalyst has Water Gas Shift and Fischer-Tropsch synthesis activity.
C10G 2/00 - Production of liquid hydrocarbon mixtures of undefined composition from oxides of carbon
C01B 3/02 - Production of hydrogen or of gaseous mixtures containing hydrogen
C07C 1/04 - Preparation of hydrocarbons from one or more compounds, none of them being a hydrocarbon from oxides of carbon from carbon monoxide with hydrogen
18.
PROCESSES FOR PRODUCING HYDROCARBONS FROM A RESERVOIR
There is provided a process for producing hydrocarbons from a reservoir. The process includes within the hydrocarbon reservoir, electrically heating a liquid heating fluid such that the liquid heating fluid is evaporated to produce a gaseous heating fluid, heating hydrocarbon-comprising material with the gaseous heating fluid such that the heated hydrocarbon-comprising material is mobilized and such that the gaseous heating fluid is condensed to produce a condensed heating fluid, and electrically heating at least a fraction of the condensed heating fluid such that the at least a condensed heating fluid fraction is re-evaporated, and while the evaporation, the condensing, and the re-evaporation are being effected, producing a produced fluid including at least the mobilized hydrocarbon-comprising material.
Disclosed herein is a method and system for improving the recovery of hydrocarbons from a reservoir. The method includes injecting a steam-solvent mixture at during the start-up phase of a gravity-assisted recovery process, such as a SAGD operation. Using the method disclosed, oil and solvent production rates can be increased while decreasing the steam requirements for the SAGD operation when the solvent-steam mixture is injected prior to substantial inter-well communication being established.
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. 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
20.
OLEFINS REDUCTION OF A HYDROCARBON FEED USING OLEFINS- AROMATICS ALKYLATION
A process for reducing the olefins and/or di-olefins content of a hydrocarbon-containing feed, such as that resulting from the thermal cracking of heavy oil, thermally cracked bitumen, or thermally cracked petroleum are disclosed. The process involves alkylation of di-olefins and olefins with aromatics already present in the hydrocarbon feed and without removal of nitrogen-, sulfur- or oxygen-containing compounds present in the feed. The process can take place without the need to add an external source of hydrogen, olefins or aromatics.
Solvent is co-injected with steam during the start-up phase of a steam assisted gravity drainage ("SAGD") operation. As well solvent is co-injected with steam during the production phase of a SAGD operation. Both processes improve efficiencies for recovering bitumen from oil sands.
A process for upgrading oil including optionally pre-treating a heavy oil including at least one dissolved gas, asphaltenes, water, and mineral solids; reducing at least one dissolved gas content from said heavy oil, optionally further reducing water content from said heavy oil; adding a paraffinic solvent to said heavy oil, at a predetermined paraffinic solvent :heavy oil ratio, facilitating separation of asphaltenes, water, and mineral solids from the heavy oil resulting in a de-asphalted or partially de-asphalted oil ("DAO")-paraffinic solvent stream, comprising a low asphaltenes content DAO-paraffinic solvent stream and an asphaltenes- mineral solids-paraffinic solvent-water slurry stream; optionally separating the paraffinic solvent and water from the asphaltenes-mineral solids-paraffinic solvent-water slurry stream; optionally separating the DAO-paraffinic solvent stream into a paraffinic solvent rich stream and a DAO stream; and optionally adding diluent to the DAO stream resulting in transportable oil.
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
C10G 21/06 - Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents characterised by the solvent used
23.
STEAM ASSISTED GRAVITY DRAINAGE WITH ADDED OXYGEN ("SAGDOX") IN DEEP RESERVOIRS
A process to recover hydrocarbons, from a hydrocarbon reservoir having a bottom, using a substantially horizontal production well, the substantially horizontal production well having a toe and a heel, the process including: (a) injecting oxygen into the hydrocarbon reservoir, the horizontal production well having at least one perforation zone for contact with the reservoir; (b) injecting steam into the hydrocarbon reservoir; the oxygen producing in situ heat and in situ carbon dioxide by combustion and the steam producing in situ heat by conduction and condensation; the in situ carbon dioxide dissolving into the liquid hydrocarbon, lowering its viscosity; (c) recovering the reservoir liquid hydrocarbons of lowered viscosity using the substantially horizontal production well; and (d) optionally conveying the recovered liquid hydrocarbons to the surface; where the process is absent a removal step of any non-condensable gas from the reservoir.
A method of recovering product from a fracture below a surface, said method including: a. providing a first well that may be stimulated or has been stimulated at a first predetermined depth within a formation; b. stimulating said well resulting in at least one fracture in said formation; said fracture having at least one initiation point and at least one distal point; wherein said at least one initiation point is proximate said stimulated well and said at least one distal point is distant said stimulated well; c. providing at least one non-stimulated well, proximate said first well at a second predetermined depth in said formation and contacting said at least one distal point of said at least one fracture; said at least one non-stimulated well further including at least one access point to capture product from said at least one fracture in said formation; capturing said product from said fracture through said at least non-stimulated well, and recovering said captured product optionally at said surface.
A process to recover hydrocarbons from a reservoir having at least one lean zone, wherein said lean zone has an initial bitumen saturation level less than about 0.6, said process including: i) Initially injecting of oxygen into said reservoir; ii) Allowing for combustion of said oxygen to vaporize connate water in said at least one lean zone; and iii) Recovering said hydrocarbons from said reservoir.
A steam assisted gravity drainage with injected oxygen (SAGDOX) process to recover hydrocarbons in a hydrocarbon reservoir including: (a) starting the SAGDOX process at a first oxygen to steam ratio; (b) measuring a produced water to oil ratio (v/v) PWOR associated with the first oxygen to steam ratio; (c) adjusting the oxygen to steam ratio to obtain a predetermined PWOR; and (d) continuing steps (a) to (c) until a target PWOR is obtained improving the hydrocarbon recovery rate.
A SAGDOX process to recover liquid hydrocarbons from at least one thin pay zone in a hydrocarbon bitumen reservoir, via a substantially horizontal production well, where the hydrocarbon bitumen reservoir has a top and a bottom. The process includes: i) Injecting steam into the hydrocarbon bitumen reservoir above the substantially horizontal production well; ii) Injecting oxygen into the hydrocarbon bitumen reservoir above the substantially horizontal production well; iii) Recovering liquid hydrocarbon via gravity drainage into the substantially horizontal production well.
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. 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
E21B 43/30 - Specific pattern of wells, e.g. optimising the spacing of wells
28.
IMPROVED HYDRAULIC FRACTURING PROCESS FOR DEVIATED WELLBORES
A method of stimulating an interval in a hydrocarbon reservoir equipped with a deviated wellbore having a casing, wherein said interval comprises at least two sequential stages in said wellbore without isolation means, said method comprising: i) introducing a first stage, ii) introducing a second stage in the same wellbore wherein said first stage, and second stage are not separated by any isolation means; and optionally, iii) recovering hydrocarbon from said hydrocarbon reservoir to a surface.
A Single Well Steam Assisted Gravity Drainage (SWSAGD) process to recover liquid hydrocarbons from an underground hydrocarbon reservoir, wherein the single well includes a single substantially horizontal well including a heel area and a toe area, wherein the toe area of the horizontal well extends upwardly into the reservoir, the process including 1- injecting steam into the reservoir via a steam injection area, proximate the toe area of the horizontal well, 2-allowing the steam to condense causing heated hydrocarbon liquids and water to drain into a liquid recovery zone of the horizontal well between the toe area and the heel area of the horizontal well, and 3- recovering the heated hydrocarbon liquids to the ground surface from the liquid recovery zone.
A method to operate a Steam Assisted Gravity Drainage with Oxygen (SAGDOX) process, in a leaky bitumen reservoir, wherein the process includes start-up, growth, decline and shut down phases. The start-up phase includes (1) Circulating steam in two horizontal (SAGD) wells, until communication is established between the two wells, (2) Injecting and optionally circulating steam in a SAGDOX oxygen injector well and vent gas well until communication is established, (3) Switching the wells to operate in a SAGD mode, with the upper well as a steam injector and the lower well as a fluid producer, creating a steam chamber, (4) Starting oxygen injection in the oxygen injector well, and (5) Opening at least one Produced Gas (PG) vent gas well, until steam injection is substantially limited to the upper well, oxygen injection has started and PG vent gas removal has started.
The use of a water recycle ratio for controlling at least one Steam Assisted Gravity Drainage (SAGD) parameter in a leaky bitumen reservoir. Further, a process to control a steam injection rate for an individual SAGD well pair, in a leaky bitumen reservoir wherein the process replaces a pressure control for an SAGD steam injection rate with a volume control determined by a Water Recycle Ratio (WRR).
A method for remediation of at least one cold spot in a producer well in a Steam Assisted Gravity Drainage (SAGD) process to increase hydrocarbon recovery from a hydrocarbon reservoir, wherein the SAGD process occurs at a site including an injection well, a production well and a steam chamber. The method includes shutting the production well and maintaining or increasing steam injection through the injection well until pressure in the steam chamber increases. The production well is then resumed while continuing steam injection at rates for normal SAGD or greater until reservoir pressure reaches normal operational pressure. Optionally, the injection/production is adjusted to return to normal SAGD operation.
A process to utilize at least one water lean zone (WLZ) interspersed within a net pay zone in a reservoir and produce bitumen from the reservoir, includes using Steam Assisted Gravity Drainage with Oxygen (SAGDOX) to enhance oil recovery, locating a SAGDOX oxygen injector proximate the WLZ, and removing non-condensable gases.
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. 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
E21B 43/30 - Specific pattern of wells, e.g. optimising the spacing of wells
35.
STEAM ANTI-CONING/CRESTING TECHNOLOGY ( SACT) REMEDIATION PROCESS
A cyclic remediation process to restore oil recovery from a primary oil production well that has watered off from bottom water encroachment (cone or crest) whereby: (a) the primary oil production well has a produced water cut in excess of 95% (v/v); (b) the oil is heavy oil, with in-situ viscosity > 1000 cp; wherein said process includes: (c) injecting a steam slug with a volume of 0.5 to 5.0 times the cumulative primary oil production, with steam volumes measured as water volumes; (d) shutting in the well for a soak period, after the steam injection is complete; and (e) producing the well until the water cut exceeds 95%.
A SAGDOX satellite system for recovering hydrocarbons includes a central SAGDOX site, at least one SAGDOX satellite site, and a pipeline corridor for communication between the central SAGDOX site and the SAGDOX satellite site. The satellite system is designed to recover hydrocarbons using a SAGDOX process at the satellite site and transfer recovered hydrocarbons to the central site.
A process to recover heavy oil from a hydrocarbon reservoir, said process comprising injecting oxygen-containing gas and steam separately injected via separate wells into the reservoir to cause heated hydrocarbon fluids to flow more readily to a production well, wherein: (i) the hydrocarbon is heavy oil (API from 10 to 20; with some initial gas injectivity (ii) the ratio of oxygen/steam injectant gas is controlled in the range from 0.05 to 1.00 (v/v) (iii) the process uses Cyclic Steam Stimulation or Steam Flooding techniques and well geometry, with extra well(s) or a segregated zone to inject oxygen gas wherein the oxygen contact zone within the reservoir is less than substantially 50 metres long.
A process to recover hydrocarbons from a hydrocarbon reservoir, namely bitumen (API < 10; in situ viscosity > 100,000 c.p.), said process comprising; establishing a horizontal production well in said reservoir; separately injecting an oxygen-containing gas and steam into the hydrocarbon reservoir continuously to cause heated hydrocarbons and water to drain, by gravity, to the horizontal production well, the ratio of oxygen/steam injectant gases being controlled in the range from 0.05 to 1.00 (v/v). removing non-condensable combustion gases from at least one separate vent-gas well, which is established in the reservoir to avoid undesirable pressures in the reservoir.
E21B 43/24 - Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. 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
E21B 43/30 - Specific pattern of wells, e.g. optimising the spacing of wells
39.
HYDROCARBON RECOVERY WITH IN-SITU COMBUSTION AND SEPARATE INJECTION OF STEAM AND OXYGEN
A process to recover bitumen from a subterranean hydrocarbon reservoir comprising the following steps: a) injection of steam and oxygen separately into said bitumen reservoir and when mixed therein said mix being in the range of 5 to 50% O2, b) production of hot bitumen and water using a horizontal production well, and c) production/removal of non-condensable combustion gases to control reservoir pressure.
This invention relates to systems and methods for catalytic steam cracking of non-asphaltene containing heavy hydrocarbon fractions. The method enables upgrading heavy hydrocarbons to hydrocarbons capable of being transported through pipelines and/or a pretreated step before further treatment in an upgrading refinery, including the steps of separating the heavy hydrocarbon mixture into a light fraction, a full gasoil fraction and a vacuum residue fraction with or without at least partial reduction or asphaltenes; adding a catalyst to the full gasoil and/or to the blend of this with a reduced asphaltenes fraction and subjecting the catalyst-full gasoil and/or deasphalted oil fraction to catalytic steam cracking to form an effluent stream; separating the effluent stream into a gas stream and a liquid stream; and mixing the liquid stream with the light fraction and the vacuum residue fraction to form an upgraded oil. The system includes hardware capable of performing the method.
C10G 55/06 - 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 catalytic cracking step
41.
HIGH PRESSURE MULTISTAGE CENTRIFUGAL PUMP FOR FRACTURING HYDROCARBON RESERVES
The present invention relates to a multistage centrifugal pump design, which has the diffusers, impellors, and a shaft, inserted within a high pressure housing, such that this assembly is fully enclosed within the housing, and the housing is of sufficient strength to be suitable for safe pressure containment of the fluids being pumped. This invention describes the technical details used to reconfigure the multistage centrifugal pump design to increase the discharge pressure capabilities higher than the 6,000 psig of current designs.
patents
