Classifications

• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
  • C10G15/00—Cracking of hydrocarbon oils by electric means, electromagnetic or mechanical vibrations, by particle radiation or with gases superheated in electric arcs
  • C10G15/08—Cracking of hydrocarbon oils by electric means, electromagnetic or mechanical vibrations, by particle radiation or with gases superheated in electric arcs by electric means or by electromagnetic or mechanical vibrations
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
  • C10G32/00—Refining of hydrocarbon oils by electric or magnetic means, by irradiation, or by using microorganisms
  • C10G32/02—Refining of hydrocarbon oils by electric or magnetic means, by irradiation, or by using microorganisms by electric or magnetic means
• • E—FIXED CONSTRUCTIONS
  • E21—EARTH OR ROCK DRILLING; MINING
  • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
  • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
  • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
• • E—FIXED CONSTRUCTIONS
  • E21—EARTH OR ROCK DRILLING; MINING
  • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
  • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
  • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
  • E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
  • E21B43/2401—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection by means of electricity

Definitions

• the present invention has amongst its potential aims to provide a method and apparatus which offers a beneficial approach to breaking down compounds, typically hydrocarbons, through oxidation. This aim may relate to the compounds whilst still in-situ and/or after extraction by human activity from the location where they occurred.
• the present invention has amongst its potential aims to provide a low power consumption process and apparatus for the processing of geological structures, hydrocarbons below the surface of the ground or other hydrocarbon containing locations in matrix form, particularly to reduce the viscosity of the compounds present and/or to reduce the carbon chain length of the compounds present and/or to reduce the level of
• contamination present within those compounds for instance contamination by sulphur and/or chlorides and/or heavy metals and/or water.
• a method for the processing of hydrocarbons within a location including:
• the processing of the hydrocarbons may be to reduce the viscosity of the
• the processing of the hydrocarbons may be to reduce the size of the average hydrocarbon molecule present and/or the size of the larger hydrocarbon molecules present.
• the processing may be to convert one or more of the heavier hydrocarbons present to one or more light hydrocarbons.
• the processing may be to reduce the level of one or more contaminants in the hydrocarbons, such as the sulphur level and/or heavy metal level.
• the location may be a conduit through which hydrocarbons pass after extraction by human activity.
• the conduit may be a pipe.
• the pipe may extend between a first site and a second site.
• the first site and the second site may be at least 1 km apart and may be at least 10 km apart.
• the first site may be a site at which hydrocarbons are extracted from an in-situ location.
• the second site may be a storage site or a processing site for hydrocarbons.
• the one or more electrodes may extend into the pipe, for instance across a part of the cross- section of the pipe.
• the one or more electrodes may be provided as a grid.
• the one or more electrodes may extend across a part of the cross-section of the pipe, potentially in different orientations along the length of the pipe.
• the location may be a naturally occurring location below ground.
• the location may be a geological structure, for instance one or more strata within a geological structure or parts thereof.
• the location may be a location at which hydrocarbons have been formed naturally below ground and/or a location to which naturally formed hydrocarbons have moved after extraction.
• One or more outlets may be provided to allow hydrocarbons to leave the geological structure, for instance one or more drilled extraction wells.
• One or more inlets may be provided to allow one or more materials to be introduced to the geological structure, preferably to assist in the extraction of hydrocarbons.
• the hydrocarbons may be introduced to the location, for instance by being extracted and removed to the location or for instance by being directed to the location by a prior process, such as flowing to the location.
• the hydrocarbons may be already at the location below ground, for instance by being naturally occurring at the location and/or by being found at the location by
• the reduction of the length of the carbon chain for one or more species in the hydrocarbons may cause a change in the API value for the hydrocarbons and/or a change in viscosity for the hydrocarbons.
• the hydrocarbon may have a first API value, for instance at a first time.
• the hydrocarbon may have a second API value, for instance at a second time which is after the first time.
• the time period between the first time and the second time may be between 20 hours and 2000 hours, potentially between 30 hours and 1000 hours, preferably between 60 hours and 400 hours and ideally between 75 hours and 300 hours.
• the second API value may be greater than the first API value.
• the second API value may be at least 25%, possibly at least 50%, potentially at least 75% and preferably at least 100% higher that the first API value.
• the hydrocarbon may have a second API value which is greater than the first API value, without the addition of any further hydrocarbons having a greater API to the hydrocarbon being treated.
• the hydrocarbon may have a second API value which is greater than the first API value, without the hydrocarbon being blended and/or mixed and/or contact with any further hydrocarbons of a different composition.
• the hydrocarbon may have a second API value which causes the hydrocarbon to be classified as a different grade of crude oil compare with the classification caused by the first API value. For instance, an extra heavy crude oil at the first time may be classified as a heavy crude oil at the second time.
• the API considerations are made at the same temperature at the first time and the second time.
• the hydrocarbon may have a first viscosity value, for instance at a first time.
• the hydrocarbon may have a second viscosity value, for instance at a second time which is after the first time.
• the time period between the first time and the second time may be between 20 hours and 2000 hours, potentially between 30 hours and 1000 hours, preferably between 60 hours and 400 hours and ideally between 75 hours and 300 hours.
• the second viscosity value may be less than 60% the first viscosity value.
• the second viscosity value may be less than 30%, possibly less than 20%, potentially less than 15% and preferably at less than 10% of the first viscosity value.
• the hydrocarbon may have a second viscosity value which is less than the first viscosity value, without the addition of any further hydrocarbons having a lower viscosity to the hydrocarbon being treated.
• the hydrocarbon may have a second viscosity value which is less than the first viscosity value, without the hydrocarbon being blended and/or mixed and/or contact with any further hydrocarbons of a different composition.
• the reduction in the sulphur content of the hydrocarbons may arise together with a reduction in the carbon chain length for one or more species in the hydrocarbons.
• the hydrocarbon may have a first sulphur content, for instance at a first time.
• the hydrocarbon may have a second sulphur content, for instance at a second time which is after the first time.
• the time period between the first time and the second time may be between 20 hours and 2000 hours, potentially between 30 hours and 1000 hours, preferably between 60 hours and 400 hours and ideally between 75 hours and 300 hours.
• the second sulphur content may be less than the first sulphur content.
• the second sulphur content may be 25% or more less than, possibly 50% or more less than, potentially 75% or more less than, and preferably 85% or more less than the first sulphur content.
• the hydrocarbon may have a second sulphur content which causes the hydrocarbon to be classified as a sweet crude oil compared with a classification of sour crude oil caused by the first sulphur content value.
• the reduction in the heavy metal content of the hydrocarbons may arise together with a reduction in the carbon chain length for one or more species in the hydrocarbons.
• the heavy metal content may consider, or may further consider in combination with the species above, one or more or all of e content with respect to cadmium, zinc, manganese, iron,
• the hydrocarbon may have a second heavy metal content value which is less than the first heavy metal content value, without the addition of any further hydrocarbons having a lower heavy metal content to the hydrocarbon being treated.
• the hydrocarbon may have a second heavy metal content which is less than the first heavy metal content, without the hydrocarbon being blended and/or mixed and/or contact with any further hydrocarbons of a different composition.
• the two or more electrodes may have a length of over 25m, for instance over 50m, possibly over 100m and potentially over 250m.
• the two or more electrodes, particularly when provided in a naturally occurring location such as a geological structure may have a length of less than 2000m, for instance less than 1000m, possibly less than 500m and potentially less than 250m.
• the two or more electrodes may have a length of over lm, for instance over 2m, possibly over 3m and potentially over 5m.
• the two or more electrodes, particularly when provided in a storage location such as a tank or other container may have a length of less than 20m, for instance less than 10m, possibly less than 7m and potentially less than 5m.
• the two or more electrodes may have a length of over 0.1m, for instance over 0.3m, possibly over 0.5m and potentially over lm.
• the two or more electrodes, particularly when provided in a conduit such as a pipe may have a length of less than 2m, for instance less than lm, possibly less than 0.75m and potentially less than 0.5m.
• the spacing may be lower or higher across the width of the location when compared with the length of the location.
• More electrodes may be provided in one or more parts of the location being treated compared with one or more other parts.
• the one or more parts may include the edges of the location being treated.
• the one or more parts may include the central 30% of the location being treated, considered by volume or considered by distance relative to the distance between one electrode at one extremity of the location and the electrode further away from that electrode.
• the one or more other parts may include the edges of the location being treated.
• the one or more other parts may include the central 30% of the location being treated, considered by volume or considered by distance relative to the distance between one electrode at one extremity of the location and the electrode further away from that electrode.
• the electrodes may have a spacing greater than 25m, for instance greater than 50m, possibly greater than 100m and potentially greater than 250m.
• the electrodes particularly when provided in a naturally occurring location such as a geological structure, may have a spacing less than 5000m, for instance less than 2500m, possibly less than 1000m and potentially less than 500m.
• the electrodes may have a spacing greater than lm, for instance greater than 2m, possibly greater than 5m and possibly greater than 10m.
• the electrodes may have a spacing less than 50m, for instance less than 25m, possibly less than 15m and possibly less than 10m.
• the electrodes may have a spacing greater than 0.1m, for instance greater than 0.5m, potentially greater than 2m and possibly greater than 5m.
• the electrodes particularly when provided in a storage location such as a tank or other container, may have a spacing less than 15m, for instance less than 10m, potentially less than 5m and possibly less than 2m.
• the electrodes may have an extent into the depth, particularly when provided in a naturally occurring location such as a geological structure, of greater than 10m, for instance greater than 50m, possibly greater than 100m and potentially greater than 250m.
• the electrodes may have an extent into the depth, particularly when provided in a naturally occurring location such as a geological structure, of less than 1000m, for instance less than 500m, possibly less than 200m and potentially less than 100m.
• the electrodes may have an extent into the depth for instance greater than 0.7m, possibly greater than 2m and potentially greater than 5m.
• the electrodes may have an extent into the depth of less than 10m, for instance less than 5m, possibly less than 2m and potentially less than lm.
• the electrodes may have an extent into the depth, particularly when provided in a storage location such as a tank or other container, of greater than 0.5m, for instance greater than 1.5m, possibly greater than 4m and potentially greater than 8m.
• the electrodes may have an extent into the depth, particularly when provided in a storage location such as a tank or other container, of less than 20m, for instance less than 10m, possibly less than 5m and potentially less than 2m.
• the electrodes may have an extent into the depth, particularly when provided in a conduit such as a pipe, of greater than 0.1m, for instance greater than 0.5m, possibly greater than lm and potentially greater than 2m.
• the electrodes may have an extent into the depth, particularly when provided in a conduit such as a pipe, of less than 3m, for instance less than 2m, possibly less than lm and potentially less than 0.5m.
• the electrodes may have an extent into the depth of the location which is at least 20% of the depth of the location being treated, more preferably at least 50% of the depth of the location being treated.
• a gap may exist between the top of the electrodes and the surface of the structure they are provided in.
• the gap may be bridged by the electrical conductor, for instance wire, used to connect the electrodes to the surface and/or power supply.
• One or more material may be added to the aperture, before and/or during and/or after drilling or driving or forcing.
• the one or more materials may increase the conductivity between the electrodes and the volume of material compared with the conductivity when the one or more materials are absent.
• the electrodes may be positioned within the volume of material, for instance using gravity, for instance by allowing the electrodes to settle within the location.
• a second set of electrodes may be provided in addition to the first set of electrodes.
• the second set of electrodes may include electrodes extending across the width of the location in a second set of positions, for instance in a row.
• the second set of electrodes may include electrodes extending across the width of the location at a second set of positions, for instance a second row.
• the first and second positions may be such that there are no intervening electrodes from other sets of electrodes.
• the first and second positions may be rows, relative to the length of the location, ideally with no rows of electrodes from one or more other sets of electrodes between them.
• the second set of electrodes may have a first row of electrodes and a second row of electrodes adjacent one another.
• the second set of electrodes may be provided to one side, for instance relative to the length of the location, the first of the still further sets of electrodes may be provided to the other side.
• the various still further sets of electrodes may be provided in equivalent arrangements relative to one another.
• the voltage source may be connected to a mains power supply.
• the voltage source may be connected to a discrete power supply, for instance a power supply specific to the method and/or specific to the geographical location at which the method is conducted.
• the voltage source may be an AC voltage source or a DC voltage source.
• the voltage source may step down the voltage to the level required for the method. A constant voltage output may be provided.
• the voltage controller may determine the voltage applied to the first position electrodes in a second set of electrodes.
• the voltage controller may apply a voltage and/or a polarity to the first position electrodes in the second set of electrodes which is different to the second position electrodes in the first set of electrodes.
• the voltage controller may determine the voltage applied to the first position electrodes in one or more or all of the still further sets of electrodes.
• the voltage controller may apply a voltage and/or a polarity to the first position electrodes in the one or more or all still further sets of electrodes which is different to the second position electrodes in the adjacent set of electrodes.
• one row of electrodes is at a first voltage and/or first polarity, with the adjacent row of electrodes on one or both sides at a second voltage and/or polarity and/or a third voltage and/or polarity respectively.
• the second voltage and/or polarity and the third voltage and/or polarity may be the same.
• a voltage difference and/or polarity difference may be provided between all adjacent position electrodes.
• the first section and the second section are preferably adjacent one another.
• the voltage controller may provide a voltage, particularly a voltage pulse profile, to the one or more pairs of electrodes so as to provide and/or seek to provide a defined current pulse profile.
• the voltage, particularly the voltage pulse profile may be determined through a calibration method, for instance a calibration method according to the third aspect of the invention.
• the second section may have a start current value and an end current value.
• the second section start current value may be the maximum current for the defined current pulse profile.
• the current may decline between the start current value and the end current value.
• the end current value may be a declined current value.
• the declined current value may be the current value which occurs with the prolonged, for instance greater than 500ms, application of the voltage in the corresponding part of the voltage pulse profile.
• the declined current value may be the value the current declines to, from the maximum current value, with the passage of time but represents a steady state current reached after a period of time.
• the decline current value may continue at that declined current value for a fourth section of a current pulse profile, with the fourth section intermediate the second section and the third section of the defined current pulse profile.
• a fourth section may be preferred.
• the fourth section may provide the, or a part of the, pulse section during which the volume of material or a part of the volume of material becomes charged.
• the fourth section may provide the charge which contributes to the second reversed section of the current pulse profile, for instance by contributing to the higher value of the current during the second reversed section of the current pulse profile.
• the fourth section may provide the charge which contributes to the first reversed section of the current pulse profile having a higher maximum current value that the minimum current value of the second reversed section, for instance by contributing to the higher value of the current during the first reversed section of the current pulse profile.
• a fourth reversed section may be preferred.
• the fourth reversed section may provide the, or a part of the, pulse section during which the volume of material or a part of the volume of material becomes charged.
• the fourth reversed section may provide the charge which contributes to the second section of the current pulse profile, for instance by contributing to the higher value of the current during the second section of the current pulse profile.
• the fourth reversed section may provide the charge which contributes to the first section of the current pulse profile having a higher maximum current value that the minimum current value of the second section, for instance by contributing to the higher value of the current during the first section of the current pulse profile.
• the method may promote oxidisation by generating free radicals within the location.
• the method may generate the free radicals at the surface of the solid species within the matrix forming the location, with respect to one or more or all of those solid species within the matrix.
• solids are present in and/or are added to the location and/or the volume of material and/or the hydrocarbons.
• the hydrocarbons are in contact with and/or in proximity with solid material.
• the hydrocarbons contain solid material, for instance solid particles dispersed in the hydrocarbons.
• the method has one or more or all of the following effects upon the matrix and/or one or more of the species between a first time at the start of the method's application and a second time after the method has been applied:
• a voltage controller for applying a voltage of a first polarity to the connections for a first period of time
• the second aspect of the invention includes apparatus and component parts therefore for implementing and/or providing each of the features, options and possibilities defined elsewhere within this document, and in particular within the first aspect of the invention.
• a method of calibrating the operating conditions to be used in a method of processing hydrocarbons within a location including:
• the first reversed section may have the equivalent profile shape but with a reversed current direction compared with the first section.
• the second reversed section may have the equivalent profile shape but with a reversed current direction compared with the second section.
• the third reversed section may have the equivalent profile shape but with a reversed current direction compared with the third section.
• the first section may have a start current value and an end current value.
• the first section start current value may be zero.
• the first section end current value may be the maximum current for the defined current pulse profile.
• the first section may last for a first time period. The first time period may be less than 0.5ms, more preferably less than 0.1ms and ideally less than 0.05ms.
• the first reverse section may be similarly provided.
• the second section may have a start current value and an end current value.
• the second section start current value may be the maximum current for the defined current pulse profile. The current may decline between the start current value and the end current value.
• the end current value may be a declined current value.
• a fourth section may be preferred.
• the fourth section may provide the, or a part of the, pulse section during which the volume of material or a part of the volume of material becomes charged.
• the fourth section may provide the charge which contributes to the second reversed section of the current pulse profile, for instance by contributing to the higher value of the current during the second reversed section of the current pulse profile.
• the fourth section may provide the charge which contributes to the first reversed section of the current pulse profile having a higher maximum current value that the minimum current value of the second reversed section, for instance by contributing to the higher value of the current during the first reversed section of the current pulse profile.
• the first reversed section and/or second reversed section may have a current value in excess of the fourth reversed section current value due to the discharge of the charge provided to the volume or material or a part of the volume of material during the immediately previous fourth section.
• the second section may have a generally elliptical shape, with an initial rapid decrease in current and then decreasing rate of current decline down to the declined current value.
• the second reverse section may be similarly provided. Potentially there is no fourth reverse section between the second reverse section and the third reverse section in the defined current pulse profile.
• the calibration method may vary the voltage to ensure that the declined current value is reached.
• the calibration method may vary one or more of the following when varying the voltage: the duration of one or more of the above defined sections for the voltage pulse profile; the magnitude of the voltage; the polarity of the voltage; the shape of the voltage pulse profile.
• the third section may have a start current value and an end current value.
• the third section start current value may be less than the maximum current for the defined current pulse profile and/or may be the declined current value.
• the third section end current value may be zero.
• the third section may last for a third time period.
• the third time period may be less than 0.5ms, more preferably less than 0.1ms and ideally less than 0.05ms.
• the third reverse section may be similarly provided.
• Figure 1 is a schematic perspective view of a volume of matrix and the hydrocarbon compounds contained therein being treated according to an embodiment of the invention
• the process conditions are most effective when the pH is within certain bounds. Natural redox reactions and/or reactions caused by the operation of the method can cause a decrease in pH around the anode and/or an increase in pH around the cathode. If the pH becomes too low then electro-osmosis at the anode stops which impairs the operation of the process. If the pH becomes too high then that can have deleterious effects on the process. However, it is believed that the process is still effective at lower pH's than can be tolerated in electro-osmotic based processes where transportation is being sought, as the process is seeking to provide oxidation of organic species.
• the square voltage pulse profile features a rapid change from one polarity to the other and then back again.
• regular square shaped pulses are provided rather than a sinusoidal or other gradual form of changing pulse.
• Heavy crude oil is generally considered to be oil with an API gravity of less than 20 (where an API gravity of 10 matches the density of water).
• An API below 10 leads to the oil sinking in water, and may be classified as extra heavy oils.
• the classification of oils as light oils varies with geography, but typically are US originating oils with an API of 37 to 42 and are non-US originating oils with an API of 32 to 42 degrees, such as Brent crude at an API 38.06.
• the process has many beneficial effects upon the matrix and/or upon the
• the process is shown providing in-situ processing of the hydrocarbon within a geological structure 1.
• the process can be used to treat a wide variety of structures or situations where hydrocarbons are present and would benefit from a degree of oxidation.
• the matrices can include soil, groundwater bearing matrices, aquifers or other forms of geological structure containing the hydrocarbons to those described, including oil sand situations. Many or even all of these situations include naturally occurring water within the matrices to be treated. The addition of water, in liquid, gaseous or steam form, before or during the proposed processing is also a possibility.
• the lighter hydrocarbons (red line) formed a relatively small part of the mixture and hence the concentration is low at less than 20,000 mg/kg of mixture. As the process converts the heavier hydrocarbons to lighter hydrocarbons, then this concentration increases. The method increases the concentration to around 10 times its original value.

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• Engineering & Computer Science (AREA)
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• 2014
  • 2014-12-01 GB GBGB1421261.7A patent/GB201421261D0/en not_active Ceased
• 2015
  • 2015-12-01 US US15/532,014 patent/US20170306245A1/en not_active Abandoned
  • 2015-12-01 CA CA2969363A patent/CA2969363A1/en not_active Abandoned
  • 2015-12-01 WO PCT/EP2015/078242 patent/WO2016087459A1/en active Application Filing
  • 2015-12-01 RU RU2017123062A patent/RU2017123062A/ru not_active Application Discontinuation
  • 2015-12-01 EP EP15805139.1A patent/EP3227410A1/en not_active Withdrawn

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