[go: up one dir, main page]

WO2023059896A1 - Chauffage géothermique de réservoirs d'hydrocarbures pour récupération in situ - Google Patents

Chauffage géothermique de réservoirs d'hydrocarbures pour récupération in situ Download PDF

Info

Publication number
WO2023059896A1
WO2023059896A1 PCT/US2022/046082 US2022046082W WO2023059896A1 WO 2023059896 A1 WO2023059896 A1 WO 2023059896A1 US 2022046082 W US2022046082 W US 2022046082W WO 2023059896 A1 WO2023059896 A1 WO 2023059896A1
Authority
WO
WIPO (PCT)
Prior art keywords
heat
geothermal
well section
fluid
zone
Prior art date
Application number
PCT/US2022/046082
Other languages
English (en)
Inventor
Trond Mathisen
Original Assignee
Global Energy Venture Llc
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Priority claimed from CA3133630A external-priority patent/CA3133630A1/fr
Application filed by Global Energy Venture Llc filed Critical Global Energy Venture Llc
Priority to PE2024000686A priority Critical patent/PE20241506A1/es
Publication of WO2023059896A1 publication Critical patent/WO2023059896A1/fr

Links

Classifications

    • 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
    • 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
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F24—HEATING; RANGES; VENTILATING
    • F24T—GEOTHERMAL COLLECTORS; GEOTHERMAL SYSTEMS
    • F24T10/00—Geothermal collectors
    • F24T10/20—Geothermal collectors using underground water as working fluid; using working fluid injected directly into the ground, e.g. using injection wells and recovery wells
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E10/00—Energy generation through renewable energy sources
    • Y02E10/10—Geothermal energy

Definitions

  • the technical field generally relates to recovering hydrocarbons or fluids, such as heavy hydrocarbons, from a subsurface formation, and more particularly to systems and methods for recovering hydrocarbons from a subsurface formation aided by a geothermal well.
  • the technical field also relates to the use of wells for recovering geothermal heat from a subterranean formation for use at surface.
  • the general principle of recovering hydrocarbons, such as heavy hydrocarbons, from a subsurface formation involves heating the heavy hydrocarbons or otherwise reducing the viscosity, thereby facilitating recovery via a production well.
  • Existing thermal processes for recovering heavy hydrocarbons typically require a large surface footprint with significant infrastructure, notably for steam generation.
  • steam-assisted gravity drainage (SAGD) processes require water and natural gas to generate steam at the surface so that the steam can be injected into the injection well for heating the heavy hydrocarbons.
  • SAGD steam-assisted gravity drainage
  • a system for recovering heavy hydrocarbons from a subsurface formation comprising: a geothermal well comprising: a heat-receiving well section extending within a geothermal zone of the formation and being configured to be heated by geothermal heat in the geothermal zone and transmit heat upward; and a heat-transmission well section extending from the heat-receiving well section and extending into at least a heavy hydrocarbon zone of the formation located above the geothermal zone, the heat-transmission well section being configured to receive heat from the heat-receiving well section and transmit heat into the heavy hydrocarbon zone to promote mobilization of the heavy hydrocarbons; and a production well located in the heavy hydrocarbon zone and configured to receive mobilized heavy hydrocarbons for recovery to surface.
  • the heavy hydrocarbons may include heavy hydrocarbons, such as heavy oil, and/or bitumen.
  • the hydrocarbons could also include oil or other hydrocarbon fluids.
  • the geothermal well can include an elongated component located in a corresponding wellbore and composed of a heat conductive material, and the heat is transmitted upward from the heat-receiving well section by conduction.
  • the geothermal well can include a supercritical fluid located in the heat-receiving well section and heat-transmission well section, and the heat is transmitted upward from the heat-receiving well section to the heat-transmission well section by conduction.
  • the geothermal well can include an insulated casing, which can be a vacuum insulated tubing casing.
  • the geothermal well can further include an upper well section that extends from the heat-transmission well section to the surface.
  • the geothermal well can be configured to receive an injection fluid that is injectable downhole from the surface via the upper well section, and enters the heavy hydrocarbon zone via the heat-transmission well section.
  • the injection fluid may be heated in the heat-transmission section and/or heat-receiving well section to form a heated fluid, and the heated fluid is injected into the heavy hydrocarbon zone via the heat-transmission well section.
  • the injection fluid is not preheated at the surface.
  • the injection fluid may include a gas, a liquid, or a mixture thereof.
  • the gas can include steam or CO2, while the liquid can include water.
  • the geothermal well may be configured so that the inj ection fluid is heated the heatreceiving well section to form a heated fluid, the heated fluid being circulated to the heattransmission well section and injected into the heavy hydrocarbon zone via the heat-transmission well section.
  • the geothermal well may be configured to receive a first injection fluid that is injectable downhole from the surface via the upper well section, and is transported to the heatreceiving well section to form a heated first injection fluid, the heated fluid being circulated to the heat-transmission well section; and a second injection fluid that is heated in the heat-transmission to form a heated second injection fluid, and the heated second injection fluid is injected into the heavy hydrocarbon zone via the heat-transmission well section.
  • the first injection fluid may be a supercritical fluid.
  • the geothermal well may be configured such that steam is generated upon heating of the water in the heat-transmission well section, and the steam is injected into the heavy hydrocarbon zone from the heat-transmission well section.
  • the heat-transmission well section includes a tubular liner that includes perforations for injection of the injection fluid into the heavy hydrocarbon zone.
  • the geothermal well may include at least one valve or packer located in a downhole region of the heat-transmission well section to prevent flow of the injection fluid further downhole.
  • the at least one valve or packer may be located at a downhole end of the heat-transmission well section to prevent flow of the injection fluid into the heat-receiving well section.
  • the geothermal well may also include at least one control valve located at an uphole region of the heat-transmission well section or in the upper well section to control the injection fluid entering the heat-transmission well section.
  • the heat-receiving well section may be configured to receive a hot native fluid from the geothermal zone of the formation, and transport the hot native fluid uphole into the heat-transmitting well section.
  • the hot native fluid may be injected into the heavy hydrocarbon zone via the heat-transmission well section.
  • the hot native fluid may include a gas, a liquid, or a mixture thereof.
  • the gas may include steam or CO2, whereas the liquid may include water.
  • the geothermal well may be configured such that lower pressures that are present ascending up the geothermal well cause the water to flash to form steam which is injected into the heavy hydrocarbon zone via the heat-transmission well section.
  • the geothermal well may include at least one stop valve or packer located in an uphole region of the heat-receiving well section to prevent flow of the native fluid further up the geothermal well.
  • the geothermal well may also include a flow control valve that is located at an uphole region of the heat-receiving well section and configured to control flow of the hot native fluid into the heat-transmission well section.
  • the at least one flow control valve may control the amount of the native fluid entering the heat-transmission well section.
  • the heat-receiving well section may be configured to transmit the heat by conduction to the heat-transmission well section, and the heat-transmission well section is configured to transmit the heat into the heavy hydrocarbon zone by conduction, in the absence of fluid injection into the heavy hydrocarbon zone.
  • the heat-receiving well section may be configured to prevent flow of a native fluid from the geothermal zone of the formation uphole into the heat-transmission well section.
  • the heat-transmission well section may be horizontal and overly at least a portion of the production well.
  • the heat-transmission well section may also be parallel with and vertically spaced apart from the production well.
  • the heat-receiving well section may substantially be perpendicular with respect to the heat-transmission well section.
  • the heat-receiving well section may be generally vertical.
  • the heat-receiving well section may also be generally inclined.
  • the heavy hydrocarbon zone and the geothermal zone are vertically separated from each other by at least one barrier zone of the formation.
  • the heat-receiving well section may have branched well sections or may be a linear well section.
  • a plurality of the production wells may also be associated with the geothermal well.
  • a method for recovering heavy hydrocarbons from a subsurface formation comprising: heating a heavy hydrocarbon zone of the formation and mobilizing heavy hydrocarbons contained therein with geothermal heat obtained from a geothermal zone of the formation, wherein the geothermal heat is obtained by a geothermal well comprising: a heat-receiving well section extending within the geothermal zone of the formation, and being configured to be heated by geothermal heat in the lower geothermal zone and transmit heat upward; a heat-transmission well section extending from the heat-receiving well section and extending into at least the heavy hydrocarbon zone of the formation located above the geothermal zone, the heat-transmission well section being configured to receive heat from the heat-receiving well section and transmit heat into the heavy hydrocarbon zone to promote mobilization of the heavy hydrocarbons; and recovering the mobilized heavy hydrocarbons to surface.
  • the heating and the recovering are performed simultaneously; or wherein the heating is performed as a pretreatment step prior to recovering the mobilized heavy hydrocarbons from the subsurface formation.
  • the heating of the heavy hydrocarbon zone may be performed by conduction of the geothermal heat through the heat-receiving well section and the heattransmission well section and into the heavy hydrocarbon zone in the absence of fluid injection into the geothermal well.
  • the heating of the heavy hydrocarbon zone may be performed by conduction of the geothermal heat from the heat-receiving well section to the heat-transmission well section, and by downhole injection of an injection fluid that is heated in the heat-transmission well section and then injected into the heavy hydrocarbon zone.
  • the heating of the heavy hydrocarbon zone may include introducing a circulation fluid downhole into the geothermal well, wherein the circulation fluid is circulated through the heat-receiving well section to be heated to form a heated fluid, and then the heated fluid is transported to the heat-transmission well section for injection into the heavy hydrocarbon zone or for indirect heating of the heavy hydrocarbon zone.
  • the circulation fluid may include a gas, a liquid, or a mixture thereof.
  • the gas may include steam or CO2, whereas the liquid may include water.
  • steam may be generated as the heated fluid upon heating of the water in the heat-receiving well section, and the steam is injected into the heavy hydrocarbon zone from the heat-transmission well section.
  • the heating of the heavy hydrocarbon zone may be performed by conduction of the geothermal heat from the heat-receiving well section to the heat-transmission well section, and by injection of a hot native fluid that is received from the geothermal zone of the formation through heat-receiving well section, transported uphole to the heat-transmission well section, and then injected into the heavy hydrocarbon zone.
  • the native fluid may include a gas, a liquid, or a mixture thereof.
  • the gas may include steam or CO2, whereas the liquid may include water.
  • lower pressures that are present ascending up the geothermal well cause the water to flash to form steam which is injected into the heavy hydrocarbon zone via the heat-transmission well section.
  • the recovering of the mobilized heavy hydrocarbons may be performed by gravity drainage.
  • a method for recovering hydrocarbons from a subsurface formation comprising transferring geothermal heat from a geothermal zone of the formation to a hydrocarbon zone located above the geothermal zone by conduction to promote mobilization of the hydrocarbons for production thereof to surface.
  • the hydrocarbons may include heavy hydrocarbons.
  • a method for recovering hydrocarbons from a subsurface formation comprising transferring geothermal heat from a geothermal zone of the formation to a hydrocarbon zone located above the geothermal zone without transferring the geothermal heat to surface to promote mobilization of the hydrocarbons for production thereof to the surface.
  • the hydrocarbons may include heavy hydrocarbons.
  • a method for heating and recovering a fluid in a subsurface formation comprising: heating a fluid-containing zone of the formation with geothermal heat obtained from a geothermal zone of the formation, wherein the geothermal heat is obtained by a geothermal well comprising: a heat-receiving well section extending within the geothermal zone of the formation, and being configured to be heated by geothermal heat in the lower geothermal zone and transmit heat upward; a heat-transmission well section extending from the heat-receiving well section and extending into at least the fluid-containing zone of the formation located above the geothermal zone, the heat-transmission well section being configured to receive heat from the heat-receiving well section and transmit heat into the fluid-containing zone to heat fluids contained therein; and recovering heated fluid to surface.
  • a system for recovering hydrocarbons from a subsurface formation comprising: a geothermal well comprising: a heat-receiving well section extending within a geothermal zone of the formation and being configured to be heated by geothermal heat in the geothermal zone and transmit heat upward; a heat-transmission well section extending from the heat-receiving well section and extending into at least a hydrocarbon zone of the formation located above the geothermal zone, the heat-transmission well section being configured to receive heat from the heat-receiving well section and transmit heat into the hydrocarbon zone to promote mobilization of the hydrocarbons; and a production well located in the hydrocarbon zone and configured to receive mobilized hydrocarbons for recovery to surface.
  • a method for recovering hydrocarbons from a subsurface formation comprising: heating a hydrocarbon zone of the formation and mobilizing hydrocarbons contained therein with geothermal heat obtained from a geothermal zone of the formation, wherein the geothermal heat is obtained by a geothermal well comprising: a heat-receiving well section extending within the geothermal zone of the formation, and being configured to be heated by geothermal heat in the lower geothermal zone and transmit heat upward; a heat-transmission well section extending from the heat-receiving well section and extending into at least the hydrocarbon zone of the formation located above the geothermal zone, the heat-transmission well section being configured to receive heat from the heat-receiving well section and transmit heat into the hydrocarbon zone to promote mobilization of the hydrocarbons; and recovering the mobilized hydrocarbons to surface.
  • a geothermal well comprising: a heat-receiving well section extending within a geothermal zone of the formation and being configured to be heated by geothermal heat in the geothermal zone and transmit heat upward; a heat-transmission well section extending from the heat-receiving well section and extending into at least a heavy hydrocarbon zone of the formation located above the geothermal zone, the heat-transmission well section being configured to receive geothermal heat from the heat-receiving well section and transmit a first portion of the geothermal heat into the heavy hydrocarbon zone to promote mobilization of the heavy hydrocarbons; an upper well section extending from the heat-transmission well section to the surface, the upper well section being configured to receive a second portion of the geothermal heat from the heat-transmission well section for recovery to the surface; and a production well located in the heavy hydrocarbon zone and configured to receive mobil
  • the geothermal well may include an elongated component located in a corresponding wellbore and composed of a heat conductive material, and the geothermal heat is transmitted upward from the heat-receiving well section by conduction.
  • the geothermal well may include a supercritical fluid located in the heat-receiving well section and heat-transmission well section, and the heat is transmitted upward from the heatreceiving well section to the heat-transmission well section by conduction.
  • the geothermal well may include an insulated casing, which may be a vacuum insulated tubing casing.
  • the geothermal well may be configured such that the heat-receiving well section is configured to receive a hot native fluid from the geothermal zone of the formation, and transport the hot native fluid uphole into the heat-transmission well section and to the surface.
  • the geothermal well may be configured such that a first portion of the hot native fluid is transported into the heat-transmission well section and injected into the heavy hydrocarbon zone; and a second portion of the hot native fluid is transported into the heat-transmission well section and further into the upper well section for recovery to the surface.
  • the hot native fluid may include a gas, a liquid, or a mixture thereof.
  • the gas may include steam or CO2.
  • the liquid may include water.
  • the geothermal well may be configured such that the second portion of the hot native fluid comprises steam that is used for generating electricity at or just below the surface.
  • the geothermal well may be configured such that the geothermal heat recovered to the surface is used for generating electricity and/or steam.
  • a system for recovering geothermal heat and/or a hot native fluid from a subsurface formation comprising: a geothermal well comprising: a heat-receiving well section extending within a geothermal zone of the formation and being configured to transport the geothermal heat and/or hot native fluid in the geothermal zone upward; and an upper well section extending from the heat-receiving well section to the surface, the upper well section being configured to receive the geothermal heat and/or hot native fluid from the heat-receiving well section for recovery to the surface.
  • the geothermal well may include an elongated component located in a corresponding wellbore and composed of a heat conductive material, and the geothermal heat is transmitted upward from the heat-receiving well section by conduction.
  • the geothermal well may include a supercritical fluid located in the heat-receiving well section and heat-transmission well section, and the heat is transmitted upward from the heatreceiving well section to the heat-transmission well section by conduction.
  • the geothermal well may include an insulated casing, which may be a vacuum insulated tubing casing.
  • the hot native fluid may include a gas, a liquid, or a mixture thereof.
  • the gas may include steam or CO2.
  • the liquid may include water.
  • the geothermal well may be configured such that the hot native fluid comprises steam that is used for generating electricity at or just below the surface.
  • the geothermal well may be configured such that the geothermal heat recovered to the surface is used for generating electricity and/or steam.
  • a method for recovering hydrocarbons, geothermal heat, and/or hot native fluid from a subsurface formation comprising: heating a hydrocarbon zone of the formation and mobilizing hydrocarbons contained therein with geothermal heat and/or hot native fluid obtained from a geothermal zone of the formation, wherein the geothermal heat and/or hot native fluid is obtained by a geothermal well comprising: a heat-receiving well section extending within the geothermal zone of the formation, and being configured to be heated by geothermal heat and/or hot native fluid in the lower geothermal zone and transmit heat upward; a heat-transmission well section extending from the heat-receiving well section and extending into at least the hydrocarbon zone of the formation located above the geothermal zone, the heat-transmission well section being configured to receive geothermal heat and/or hot native fluid from the heat-receiving well section and transmit a first portion of the geothermal heat and/or hot native fluid into the hydrocarbon
  • a method for recovering geothermal heat and/or hot native fluid from a subsurface formation comprising: obtaining geothermal heat and/or hot native fluid contained within a geothermal zone of the subsurface formation, wherein the geothermal heat and/or hot native fluid is obtained by a geothermal well comprising: a heat-receiving well section extending within the geothermal zone and being configured to transport the geothermal heat and/or hot native fluid in the geothermal zone upward; and an upper well section extending from the heat-receiving well section to the surface, the upper well section being configured to receive the geothermal heat and/or hot native fluid from the heat-receiving well section for recovery to the surface; using the geothermal heat and/or hot native fluid at the surface.
  • a method for recovering geothermal heat and/or hot native fluid from a subsurface formation comprising: obtaining geothermal heat and/or hot native fluid contained within a geothermal zone of the formation, wherein the geothermal heat and/or hot native fluid is obtained by an abandoned well, and wherein the abandoned well is configured to receive the geothermal heat and/or the hot native fluid from the geothermal zone; and recovering at least a portion of the geothermal heat and/or at least a portion of the hot native fluid to the surface.
  • At least a downhole portion of the abandoned well is located in the geothermal zone of the formation.
  • the method further comprises drilling downhole into the abandoned well to extend the abandoned well and reach the geothermal zone of the formation.
  • the abandoned well receives an elongated component composed of a heat conductive material, and the geothermal heat is transmitted uphole in the well by conduction through the elongated component.
  • the abandoned well comprises a supercritical fluid, and the geothermal heat is transmitted uphole in the well by conduction.
  • the abandoned well comprises an insulated casing, which may be a vacuum insulated tubing casing.
  • the abandoned well receives a hot native fluid from the geothermal zone of the formation, and transports the hot native fluid uphole in the well to the surface.
  • the hot native fluid may include a gas, a liquid, or a mixture thereof.
  • the gas may include steam or CO2.
  • the liquid may include water.
  • the abandoned well is an abandoned production well or and abandoned injection well.
  • the hot native fluid comprises steam that is used for generating electricity at or just below the surface.
  • the geothermal heat recovered to the surface is used for generating electricity and/or steam.
  • geothermal heat recovered by the system defined herein or by the method defined herein for generating electricity and/or steam, or for reinjection into a geothermal well for recovering heavy hydrocarbons from the subsurface formation and/or a second subsurface formation.
  • a system for geothermally heating and recovering an injection fluid comprising: a geothermal well comprising: a heat-receiving well section extending within a geothermal zone of a subsurface formation and being configured to transport the injection fluid in the geothermal zone downward; and an upper well section extending from the heat-receiving well section to the surface, the upper well section being configured to receive an injection fluid that is injectable downhole from the surface via the upper well section; wherein the geothermal well is configured so that the injection fluid is heated in the geothermal zone to form a geothermally-heated fluid and wherein the heat-receiving well section is configured to receive the geothermally-heated fluid for recovery to the surface.
  • a method for geothermally heating and recovering an injection fluid comprising: injecting an injection fluid into a geothermal well comprising: a heat-receiving well section extending within a geothermal zone of a subsurface formation and being configured to transport the injection fluid in the geothermal zone downward; and an upper well section extending from the heat-receiving well section to the surface, the upper well section being configured receive the injection fluid that is injectable downhole from the surface via the upper well section; wherein the geothermal well is configured so that the injection fluid is heated in the geothermal zone to form a geothermally-heated fluid and wherein the heatreceiving well section is configured to receive the geothermally-heated fluid for recovery to the surface; and recovering the geothermally-heated fluid at the surface.
  • geothermally-heated injection fluid recovered by the system defined herein or by the method defined herein, for generating electricity and/or steam, or for reinjection into a geothermal well for recovering heavy hydrocarbons from the subsurface formation and/or a second subsurface formation.
  • a method for recovering hydrocarbons from one or more subsurface formations comprising: injecting an injection fluid into a geothermal well comprising: a heat-receiving well section extending within a geothermal zone of a subsurface formation and being configured to transport the injection fluid in the geothermal zone downward; and an upper well section extending from the heat-receiving well section to the surface, the upper well section being configured receive the injection fluid that is injectable downhole from the surface via the upper well section; wherein the geothermal well is configured so that the injection fluid is heated in the geothermal zone to form a geothermally-heated fluid and wherein the heatreceiving well section is configured to receive the geothermally-heated fluid for recovery to the surface; recovering the geothermally-heated fluid at the surface; and inj ecting the geothermally-heated fluid into one or more geothermal wells or production wells for recovering heavy hydrocarbons from the subsurface formation and/or a
  • Fig. 1 is a side view schematic of a system for recovering heavy hydrocarbons according to one example implementation.
  • the system comprises a geothermal well comprising a heat-receiving well section and a heat-transmitting well section, where the geothermal well heats the heavy hydrocarbons by conduction (wavy lines) of heat from a hot geothermal zone up to the heavy hydrocarbon zone. Heated heavy hydrocarbons are then recovered to the surface via a production well.
  • Fig. 2 is a side view schematic of the system for recovering heavy hydrocarbons according to a second example implementation.
  • the system comprises a geothermal well comprising a heat-receiving well section and a heat-transmitting well section, where the geothermal well heats the heavy hydrocarbons by conduction of heat from a hot geothermal zone up to the heavy hydrocarbon zone, as well as by injection of a fluid (dashed arrows; white arrows represent colder fluid and black arrows represent heated fluid) from the surface that is heated in heat-transmitting well section and injected into the heavy hydrocarbon zone. Heated heavy hydrocarbons are then recovered to the surface via a production well.
  • a fluid dasheated heavy hydrocarbons
  • Fig. 3 is a side view schematic of the system for recovering heavy hydrocarbons according to a third example implementation.
  • the system comprises a geothermal well comprising a heat-receiving well section and a heat-transmitting well section, where the geothermal well heats the heavy hydrocarbons by conduction of heat (solid arrows) from a hot geothermal zone up to the heavy hydrocarbon zone.
  • a hot native fluid (dashed arrows) from the hot geothermal zone flows into the geothermal well and is transported from the heat-receiving well section up to the heat-transmission well section for injection into the heavy hydrocarbon zone. Heated heavy hydrocarbons are then recovered to the surface via a production well.
  • Fig. 4 is a close-up side view schematic of the heat-receiving well section, according to one example implementation.
  • FIG. 5 is a close-up side view schematic of the upper well receiving section, according to one example implementation.
  • FIG. 6 is a close-up side view schematic of the heat-transmitting well section, according to one example implementation.
  • Fig. 7 is a close-up side view schematic of the heat-transmitting well section, according to one example implementation.
  • Fig. 8 is a side view schematic of the system of Figs. 1 to 3, whereby the hot native fluid (dashed arrows from the hot geothermal zone) from the hot geothermal zone and injection of a fluid (dashed arrows from the surface; white arrows represent colder fluid and black arrows represent heated fluid) from the surface is transported to the heat-transmitting well section and injected into the heavy hydrocarbon zone.
  • Fig. 9 is a side view schematic of the system of Fig. 2 and 3, whereby the hot native fluid (dashed arrows from the hot geothermal zone) from the hot geothermal zone and/or injection of a fluid (dashed arrows from the surface; white arrows represent colder fluid and black arrows represent heated fluid) from the surface is transported to the heat-transmitting well section and injected into the heavy hydrocarbon zone, in the absence of conduction.
  • Fig. 10 is a side view schematic of the system of Fig. 2, wherein injection of a fluid (dashed arrows from the surface; white arrows represent colder fluid and black arrows represent heated fluid) from the surface is transported to the heat-receiving well section for heating in the geothermal zone, circulated to the heat-transmission well section, and injected into the heavy hydrocarbon zone, in the absence of conduction.
  • Fig. 11 is a side view schematic of the system of Fig. 1, wherein the geothermal well includes supercritical fluid (wavy arrows) that conducts geothermal heat from the heatreceiving well section to the heat-transmission well section, in the absence of an elongated component.
  • Fig. 12 is a side view schematic of the system of Fig. 1, wherein the geothermal well includes supercritical fluid (wavy arrows) that conducts geothermal heat and/or a hot native fluid (dashed arrows from the hot geothermal zone) from the heat-receiving well section to the heat-transmission well section, in the absence of an elongated component. Hot native fluid is then injected into the hydrocarbon zone via the heat-transmission well section.
  • Fig. 13 is a side view schematic of the system of Fig. 2, wherein the geothermal well includes supercritical fluid (wavy arrows) that conducts geothermal heat from the heatreceiving well section to the heat-transmission well section, in the absence of an elongated component.
  • Injection of an injection fluid (dashed arrows from the surface; white arrows represent colder fluid and black arrows represent heated fluid) from the surface is transported into the heattransmission well section to be heated and injected into the heavy hydrocarbon zone.
  • Fig. 14 is a side view schematic of the system of Fig. 2, wherein injection of a supercritical fluid (wavy arrows) from the surface is transported to the heat-receiving well section for heating in the geothermal zone, circulated to the heat-transmission well section, in the absence of an elongated component. Injection of another fluid (dashed arrows from the surface; white arrows represent colder fluid and black arrows represent heated fluid) from the surface is transported into the heat-transmission well section to be heated by the circulating supercritical fluid and injected into the heavy hydrocarbon zone.
  • a supercritical fluid dashexane
  • Fig. 15 is a side view schematic of the system of Fig. 1 and 3 whereby geothermal heat (solid arrows) and/or hot native fluid (dashed arrows) from the hot geothermal zone up is further transported to the surface.
  • Fig. 16 is a side view schematic of the system of Fig. 12, whereby supercritical fluid (wavy arrows) and/or hot native fluid (dashed arrows) from the hot geothermal zone up is further transported to the surface, in the presence of conduction with a supercritical fluid (wavy arrows),.
  • FIG. 17 is a side view schematic of the system for recovering geothermal heat (solid arrows) and/or hot native fluid (dashed arrows) from a subsurface formation, in the presence or absence of conduction with an elongated component, using a geothermal well or an abandoned well.
  • Fig. 18 is a side view schematic of the system for recovering geothermal heat and/or hot native fluid (dashed arrows) from a subsurface formation, in the presence of conduction with a supercritical fluid (wavy arrows), using a geothermal well or an abandoned well.
  • Fig. 19 is a side view schematic of the system for recovering geothermally-heated injection fluid from a subsurface formation, wherein injection of a fluid (dashed arrows from the surface; white arrows represent colder fluid and black arrows represent heated fluid) from the surface is transported to the heat-receiving well section for heating in the geothermal zone, circulated to the heat-transmission well section, and recovered to the surface, using a geothermal well or an abandoned well.
  • the present description relates to systems and methods for recovering heavy hydrocarbons from a subsurface formation, as shown for example in Figs. 1-4, as well as systems and methods for retrieving heat from a subterranean formation and using the heat at surface and/or in a subterranean zone.
  • the systems and methods described herein leverage the use of a geothermal well to obtain geothermal heat from a low zone of the formation and transport that heat up to a heavy hydrocarbon zone to heat and mobilize the hydrocarbons to facilitate recovery.
  • the geothermal heat can be sent directly from the geothermal zone to the heavy hydrocarbon zone by conduction via completion equipment in the well and/or by allowing hot native fluid to flow up through the well for inj ection into the heavy hydrocarbon zone.
  • a fluid can be injected from surface and can be heated by the geothermal heat and injected into the reservoir.
  • the system can include a geothermal well that brings heat from the hot geothermal zone up to the heavy hydrocarbon zone for heating the heavy hydrocarbons, thereby reducing the viscosity of the heavy hydrocarbons for facilitated recovery to the surface by a nearby production well.
  • the systems and methods described herein harness geothermal heat for directly heating hydrocarbons, and therefore provide enhancements in terms of efficiency and environmental sustainability.
  • the present technology relates to a system 10 for recovering heavy hydrocarbons 12 from a subsurface formation.
  • the system 10 includes a geothermal well 14 that includes a heat-receiving well section 16 and a heat-transmission well section 18, and the system 10 also includes a production well 20.
  • the heat-receiving well 16 section extends within a geothermal zone 22 of the formation and is configured to be heated by geothermal heat in the geothermal zone 22 and to transmit the heat upward.
  • the heat-transmission well section 18 extends from the heat-receiving well section 16 into at least a heavy hydrocarbon zone 24 of the formation located above the geothermal zone 22.
  • the heat-transmission well section 18 is configured to receive heat from the heat-receiving well section 16 and to transmit the heat into the heavy hydrocarbon zone 24 to promote mobilization of the heavy hydrocarbons 12.
  • the production well 20 is located in the heavy hydrocarbon zone 24 and is configured to receive mobilized heavy hydrocarbons 12 for recovery to the surface 26.
  • hydrocarbons may refer to any hydrocarbon that is present in a subsurface formation for recovery to the surface.
  • the hydrocarbons may in include “heavy” hydrocarbons having a relatively high viscosity that would create difficulties for in situ recovery.
  • Heavy hydrocarbons may include heavy oil, crude oil and bitumen, for example. Hydrocarbons may be localized in subsurface formations termed “hydrocarbon zones” or reservoirs.
  • heavy hydrocarbons have a low API (American Petroleum Institute) gravity.
  • the heavy hydrocarbons have an API gravity that is lower than 30, 25, 20, 15, or 10.
  • the heavy hydrocarbons can be recovered as oil-water emulsions, due to native water or injected water or steam.
  • present technology may be useful for the recovery and/or production of various hydrocarbon fluids, including light crude oil, shale oil, or vapour phase hydrocarbons such as natural gas, where geothermal heating can provide one or more benefits. It is also possible to apply the techniques described herein to heat other types of fluids that are present in formations, such as water, brine, and the like.
  • subsurface formation As used herein, the terms “subsurface formation”, “underground reservoir”, and “subterranean zone” may be used interchangeably.
  • the subsurface formations described herein may be localized offshore or onshore and at any depth.
  • Subsurface formations may include hydrocarbons and hydrocarbon zones.
  • subsurface formations may include geothermal zones containing geothermal heat.
  • the term “surface” may refer to the uppermost level of land (ground) or sea, or to a region just below the surface (i.e., near surface).
  • the term “supercritical fluid” may refer to a single or a mixture of different fluids.
  • the term “mobilized” refers to hydrocarbons that have a reduced viscosity for facilitated recovery. Heating, for example, may be one method for reducing the viscosity of hydrocarbons and promoting their mobilization. In some implementations, heating hydrocarbons to at least 100°C may be sufficient for promoting mobilization. Optimal temperature ranges for mobilization may be at least within 150°C to 300°C, however, in areas of higher pressure, a lower temperature ( ⁇ 100°C) may be sufficient to heat and mobilize the hydrocarbons.
  • the resulting viscosity of mobilized hydrocarbons is preferably less than about 1000 cP (centipoise), less than about 750 cP, less than about 500 cP, less than about 250 cP, less than about 100 cP, or less than about 50 cP.
  • the subsurface formations including the heavy hydrocarbon zones 24 may be located at various distances from a geothermal zone 22, and may be separated by one or more barriers. Barrier layers may include a low-permeability stratum in the formation, and may be formed of shale or mud, for example.
  • the geothermal well 14 may be configured to increase or decrease the length of the heat-receiving well section 16 and/or the heat-transmission well section 18 depending on the position of the heavy hydrocarbon zone 24 with respect to the geothermal zone 22. In some cases, the heavy hydrocarbon zone 24 and the geothermal zone 22 are vertically separated from each other. Alternatively, the heavy hydrocarbon zone 24 and the geothermal zone 22 are horizontally separated from each other.
  • the heat-receiving well section 16 is generally perpendicular with respect to the heat-transmission well section 18, especially when the heattransmission well section 18 is generally horizontal and the heat-receiving well section 16 is generally vertical.
  • the heat-receiving well section 16 may be generally vertical or generally inclined, horizontal, or directional.
  • the heat-receiving well section 16 has branched well sections or is an unbranched well section.
  • the heat-transmission well section 18 is horizontal and overlies at least a portion of the production well 20. In some cases, the heat-transmission well 18 section is parallel with and vertically spaced apart from the production well 20, and forms a well pair configuration with the production well 20.
  • the heat-transmitting well section 18 may also have branched well sections or may be an unbranched well section. While the well pair confirmation is shown in the figures, it is also noted that the heat-transmission well section 18 can be located above one or more production wells 20 and oriented at various angles rather than being directly above and parallel with the production well 20.
  • the geothermal well 14 includes an upper well section 28 that extends from the heat-transmission well section 18 to the surface 26.
  • the upper well section 28 is formed during the initial drilling of the geothermal well 14 and may simply be kept as a wellbore access. In some cases, the upper well section 28 is used to inject an injection fluid 32 downhole into the heat-transmitting well section 16, as will be described in further detail below.
  • the system includes a plurality of geothermal wells 14 associated with one or more production wells 20.
  • the geothermal wells 14 can be provided in various arrangements and patterns with respect to each other and with respect to the production wells 20.
  • the system may include a combination of different geothermal wells, as shown by different implementations herein, associated with one or more production wells 20.
  • one geothermal well 14 can be configured for fluid injection, while another geothermal well 14 can be configured to transfer geothermal heat by conduction without fluid injection.
  • systems, methods, or geothermal wells described herein may be partially or completely combined with existing in situ recovery systems and methods for recovering heavy hydrocarbons, such as but not limited to the SAGD process.
  • one or more SAGD well pairs could be located close to and associated with one or more of the geothermal wells 14.
  • Fig. 1 illustrates the system 10 that includes the geothermal well 14 which heats the heavy hydrocarbons 12 by conduction of heat from the hot geothermal zone 22 to the heavy hydrocarbon zone 24 where fluid does not flow into the heat-transmission section 18 from the surface or from the heat-receiving section 16.
  • the geothermal well 14 includes an elongated component 30 located in the wellbore of the geothermal well and composed of a heat conductive material, and the heat is transmitted upward (or “uphole” as depicted by the arrows in Fig. 1) from the heat-receiving well section 16 by conduction.
  • the elongated component 30 may be, but is not limited to, a rod, a cable or a tubular.
  • the elongated component 30 can be constructed so as to promote heating from the geothermal zone, conducting heat up to the heat-transmission section 18, and then releasing the heat into the heavy hydrocarbon zone 24.
  • the elongated component 30 can have an outer surface that is in direct contact with the inner wall of the wellbore at locations where heat is transported into the hydrocarbon zone 24, and it can be insulated from the formation in locations where heat transmission to the outer formations is to be minimized (e.g., through barrier zones or any zones that are in between the geothermal zone and the heavy hydrocarbon zone).
  • the heat conductive material may be a metal, such as to steel.
  • the elongated component 30 may extend between a lower part of the heat-receiving well section 16 to an upper part of the heat-transmitting well section 18, although it can have various dimensions and constructions depending on the application. Heat released by the heat-transmitting well section 18 into the reservoir is depicted as wavy lines in Fig. 1.
  • the geothermal well 14 may further include an insulated casing.
  • the insulating casing may enclose the elongated component 30 to prevent heat loss in certain locations.
  • the insulated casing may be a vacuum insulated tubing (VIT) casing.
  • VIT vacuum insulated tubing
  • the insulated casing surface may therefore be in direct contact with the inner wall of the wellbore at locations where heat is transported into the hydrocarbon zone 24, to minimize heat loss from the wellbore to the outer formation. The insulation can thus be provided in between the heat-receiving and heat-releasing sections of the geothermal well.
  • the geothermal well 14 also includes the upper well section 28 that extends from the heat-transmission well section 18 to the surface 26.
  • the upper well section 28 is formed during drilling and may be completed in various ways depending on the desired use.
  • the upper well section 28 may simply be a wellbore access (e.g., for inspection, maintenance or measurements) and thus is not equipped for injection or production.
  • the upper well section 28 could also be completed so that little to no geothermal heat or fluid can travels up from the heat-transmission well section 18, and therefore could be provided with appropriate equipment for this purpose.
  • Fig. 2 illustrates the system 10 which includes the geothermal well 14 which heats the heavy hydrocarbons 12 by conduction of heat from the hot geothermal zone 22 to the heavy hydrocarbon zone 24, and in this sense is similar to the system 10 according to the first implementation, but it also involves providing an injection fluid 32 from the surface 26.
  • the injection fluid 32 is provided from the surface 26 downhole and into the heat-transmitting well 18 section.
  • the injection fluid 32 is heated by the heat-transmitting well 18 section, which has received geothermal heat, and is injected into the heavy hydrocarbon zone 24.
  • This implementation therefore includes geothermal heating as well as fluid injection from the surface to help mobilize the heavy hydrocarbons 12.
  • the injection fluid 32 is introduced via the upper well section 28 and flows down into the heat-transmitting well section 18.
  • the upper well section 28 may therefore be coupled to injection equipment at surface 26 which can be configured depending on the type and state of the injection fluid (e.g., vapor, liquid, heated, ambient).
  • the injection fluid 32 is then heated by the heat-transmitting well section 18, which is heated geothermally by conduction as described herein.
  • the heated injection fluid 32 is then injected into the heavy hydrocarbon zone 24 to help mobilize the heavy hydrocarbons 12.
  • the heavy hydrocarbons 12 may therefore be heated by conduction of geothermal heat from the heattransmitting well section 18 into the hydrocarbon zone, as well as by contact with the heated injection fluid 32 entering the hydrocarbon zone 24.
  • the injection fluid 32 can help mobilize the heavy hydrocarbons by heating and also be other mechanisms as some injection fluids can mix with the hydrocarbons and help reduce viscosity.
  • the heat-transmitting well section 18 is configured to allow the injection fluid to flow into the heavy hydrocarbon zone 24, and thus provides fluid communication between the wellbore and the surrounding reservoir.
  • the heattransmitting well section 18 may include perforations 34 for releasing the heated injection fluid 32 into the heavy hydrocarbon zone 24, as shown in Fig. 6.
  • the perforations 34 can be provided through a tubular liner that facilitates transmission of the geothermal heat.
  • the heat-transmitting well section 18 may include flow control devices 35 or other completion systems to enable injection of the heated injection fluid 32 into the heavy hydrocarbon zone 24, as shown schematically in Fig. 7.
  • the heat-transmitting well section 18 may include a steel tubing that is perforated for injection of the injection fluid 32.
  • the injection fluid 32 can be delivered from surface using a pump or a compressor, for example, depending on the type of injection fluid introduced into the geothermal well.
  • the injection fluid 32 may include a gas, liquid, or a mixture of gas and liquid.
  • the gas may include steam or CO2.
  • the liquid may include water.
  • the injection fluid 32 is not preheated prior to downhole injection.
  • the injection fluid 32 is a liquid (e.g., liquid comprising water) which is introduced as a liquid and is heated in the heat-transmitting well section 18 and is thus converted partially or completely into a gas (e.g., steam) which is injected into the heavy hydrocarbon zone 24.
  • This downhole vaporization of the injection fluid is enabled by the geothermal heat in the heat-transmitting well section 18.
  • the injection fluid can be in liquid phase when introduced into the geothermal well and also when injected into the reservoir.
  • the production fluid can include hydrocarbons, injection fluid as well as other native fluids such as water and light gases.
  • the production fluid is treated at surface.
  • Heavy hydrocarbons 12 may be separated from the other components of the production fluid by various methods, such as by using separators (e.g., gas separator, oil/water separator, vapor/liquid separators, etc.).
  • separators e.g., gas separator, oil/water separator, vapor/liquid separators, etc.
  • the produced water and/or gas/CCb that is separated from the hydrocarbons may be treated and reused as part of the injection fluid 32.
  • the production fluid can be treated to remove the injection fluid for reuse in the system 10.
  • the geothermal well 14 can be equipped to allow the injection fluid to pass from the surface, into the heat-transmission well section, and into the reservoir without flowing further down the geothermal well 14.
  • the geothermal well can have a packer, valve or another device that prevents fluid flow from the heat-transmission well section 18 down into the heat-receiving well section 16.
  • the flow prevention device can be deployed at a downhole end of the heat-transmission well section 16, for example. Examples of such a packer 40 and valve 38 are schematically illustrated in this arrangement in Fig. 6.
  • Fig. 3 illustrates the system 10 which includes the geothermal well 14 that heats the heavy hydrocarbons 12 by conduction of heat from the hot geothermal zone 22 to the heavy hydrocarbon zone 24, and in this sense is similar to the system 10 according to the first implementation, but it also involves allowing a hot native fluid to flow from the geothermal zone 22 through the geothermal well 14 and into the heavy hydrocarbon zone 24.
  • the hot native fluid 36 is obtained from the hot geothermal zone 22 and is transported uphole from the heat-receiving well section 16 into the heat-transmission well section 18 for injection into the heavy hydrocarbon zone 24.
  • the hot native fluid 36 is fluid that is originally present in hot geothermal zone 22.
  • the heat-receiving well section 16 may comprise a fluid inlet 41 (see Fig. 4) that receives the hot native fluid 36 from the hot geothermal zone 22 and due to pressure differential the hot native fluid 36 flows up to the heat-transmitting well section 18.
  • the fluid inlet 41 could be configured to be operable between an open position and a closed position to control whether the hot native fluid can enter the geothermal well 14.
  • the fluid inlet 41 may be configured to work independently or in conjunction with the elongated component 30 (heat conductive material).
  • the native fluid is at a higher pressure compared to the heat-transmitting well section 18 and thus the heat-receiving well section 16 provides a conduit for passage of the native fluid to the lower pressure region.
  • the hot native fluid 36 may then be injected into the heavy hydrocarbon zone 24 via the perforations 34 or other flow control devices 35of the heattransmitting well section 18.
  • the heavy hydrocarbons 12 may therefore be heated by conduction of geothermal heat via the heat-transmitting well 18 section, and by injecting the hot native geothermal fluid 36 that is transported uphole into the heat-transmitting well section 18.
  • the hot native fluid 36 may include gas, liquid, or a mixture of gas and liquid, depending on the fluids native to the particular geological formation. Due to lower pressures that are present ascending up the geothermal well 14, the hot native fluid 36, which may begin as a liquid (e.g., water), may flash to form a gas (e.g., steam) which is injected into the heavy hydrocarbon zone 24 via the heat-transmission well section 18.
  • the hot native fluid 36 may include steam from its initial phase within the hot geothermal zone 22 and be injected as steam and/or hot water in the heat-transmission well section 18. In some instances, the hot native fluid 36 is kept hot or is further heated by simultaneous conduction of geothermal heat in the heat-receiving well section 16 and heat-transmitting well section 18, as described in the first implementation.
  • native fluid When native fluid is allowed to flow up and into the hydrocarbon zone, it can form a mixture with the mobilized heavy hydrocarbons 12, which is then recovered as the production fluid.
  • the production fluid can include hydrocarbons, native fluid from the geothermal zone, as well as native fluids from the hydrocarbon zone.
  • the production fluid is treated at surface.
  • Heavy hydrocarbons 12 may be separated from the other components of the production fluid by various methods, such as by using separators (e.g., gas separator, oil/water separator, vapor/liquid separators, etc.).
  • separators e.g., gas separator, oil/water separator, vapor/liquid separators, etc.
  • the produced water and/or gas/CCh that is separated from the hydrocarbons may be treated and disposed of or used as injection fluid in another well.
  • the geothermal well 14 can be equipped to allow the hot native fluid to pass from the geothermal zone, up through the heat-receiving well section, into the heat-transmission well section, and then into the reservoir without flowing further up the geothermal well 14.
  • the geothermal well can have an uphole packer 40a, an uphole valve 38a or another device that prevents fluid flow from the heat-transmission well section 18 up the upper section of the geothermal well.
  • the flow prevention device can be deployed at an uphole end of the heat-transmission well section 16, for example. Examples of such a packer 40a and valve 38a are schematically illustrated in this arrangement in Fig. 7.
  • a geothermal well 14 could be initially operated according to the first implementation with no fluid injection from the surface or the geothermal zone, and then the geothermal well could be subsequently operated according to the second or third implementation by allow the appropriate fluid flow and injection.
  • the geothermal well could be equipped with valves that could be operated manually or remotely in an open or closed position to allow fluid to flow from surface or from the geothermal zone into the heat-transmission well section and then into the hydrocarbon zone.
  • the geothermal well could also be recompleted to switch operation to another implementation.
  • the geothermal well 14 could be operated with fluid injection from the surface where the uphole valve 38a is open and the downhole valve 38 is closed; and then the operating mode could be switched by ceasing fluid injection from the surface, closing the uphole valve 38a, opening the downhole valve 38, and opening the fluid inlet 41 to allow native fluid flow into the geothermal well 14. It may be of interest to begin the hydrocarbon recovery process using the third implementations to leverage the hot native fluids present in the geothermal zone, and then if or when the hot native fluids become depleted the process can switch to fluid injection from the surface. In this manner, the operating mode of the geothermal well 14 could be modified between the first, second and third implementations, if desired.
  • Fig. 8 describes a combination of the systems according to the first, second and third implementations, whereby geothermal heat is transmitted by conduction (with the elongated component 30) and transmission of a hot native fluid 36, and whereby an injection fluid 32 is provided from the surface 26.
  • pressures in the heat-receiving well section 16/geothermal zone 22 and upper well section 28 must be higher than the pressure in the heat-transmission well section 18/hydrocarbon zone 24.
  • Fig. 9 generally discloses systems in which the geothermal well is configured to provide geothermal heat to a target subterranean zone (e.g., hydrocarbon zone 24), via a hot native fluid 36 and/or injection fluid 32, in the absence of conduction.
  • the hot native fluid 36 e.g., air or steam
  • the hot native fluid 36 may travel from the heat-receiving well section 16 to the heat-transmission well section 18 to be injected into the subterranean zone, such as for mobilization of the hydrocarbons 12.
  • the injection fluid 32 may flow into the heat-transmission well section 18 for injection into the subterranean zone.
  • the injection fluid 32 is heated downhole in the subterranean zone.
  • the injection fluid 32 may be transported downhole into the heat-receiving well section 16 to be heated by the geothermal zone 22, and subsequently circulated to the heat-transmission well section 18 for injection (Fig. 10).
  • the injection fluid 32 is released into the hot geothermal zone 22, and is heated and recovered by the heat-receiving well section 16 (Fig. 10).
  • supercritical fluid 42 may be used to conduct geothermal heat and/or hot native fluid in the geothermal well 14, such as in the systems of Fig. 11-14.
  • the heat-receiving 16 and heat-transmission 18 well sections of the geothermal well 14 may be filled with the supercritical fluid 42 to conduct geothermal heat from the heat-receiving well section 16 to the heat-transmission well section 18 (Fig. 11).
  • a hot native fluid 36 may be transported from the heat-receiving well section 16 to the heat-transmission well section 18 for injection into the hydrocarbon zone (Fig. 12).
  • an injection fluid 32 from the surface 26 may then be injected and transported into a reservoir within the heattransmission well section 18 that is surrounded by the supercritical fluid 42 to be heated, and then injected into the hydrocarbon zone 24 for mobilization of the hydrocarbons 18, as described in Fig. 13.
  • the supercritical fluid 42 may be circulated in the geothermal well for heating the injection fluid 32.
  • described in Fig. 14 is a system 10, wherein injection of the supercritical fluid 42 from the surface 26 is transported to the heat-receiving well section 16 for heating in the geothermal zone, and is then circulated to the heat-transmission well section 18.
  • injection of the injection fluid 32 from the surface 26, optionally in a separate compartment than the supercritical fluid 42, is transported into the heat-transmission well section to be heated by the circulating supercritical fluid 42 and is injected into the hydrocarbon zone 24 for mobilization of hydrocarbons 12.
  • the systems described herein may also be used alone or in combination with other conventional systems used for heating and/or recovery of heavy hydrocarbons.
  • the systems described herein do not utilize surface boilers or steam as an injection fluid.
  • the systems described herein preferably minimize the use of non-renewable energy sources for heating and/or recovering heavy hydrocarbons.
  • the system 10 according to the first implementation is used alone. Therefore, the heat-receiving well section 16 is configured to transmit the heat by conduction to the heat-transmission well section 18, and the heat-transmission well section 18 is configured to transmit the heat into the heavy hydrocarbon zone 24 by conduction, in the absence of fluid injection (either of hot native fluid 36 or injection fluid 32) into the geothermal well 14 and the heavy hydrocarbon zone 24.
  • the geothermal well 14 may include one more valves and/or packers, or other completion devices, to control uphole or downhole flow of fluids.
  • the one or more valves and/or packers may be located at various points of the heat-receiving well section 16, heat-transmitting well section 18, and/or the upper well section 28, as shown in Figs. 4-7.
  • the geothermal well 14 may include at least one downhole valve 38 or packer 40 located in a downhole region of the heat-transmission well section 18 to prevent flow of the injection fluid 32 further downhole.
  • the at least one downhole valve 38 or packer 40 may be located at a downhole end of the heat-transmission well section 18 to prevent flow of the injection fluid 32 into the heat-receiving well section 16. It is also possible to provide multiple downhole isolation devices, such as valves or packers, at various locations along the heat-transmission well section 18 and/or the heat-receiving well section 18, and to operate the downhole isolation devices to achieve desired fluid injection effects.
  • the geothermal well 14 may include at least one control valve or uphole valve 38a located at an uphole region of the heat-transmission well section 18 or in the upper well section 28.
  • the control valve 38a can be configured and operated to control the injection fluid 32 entering the heat-transmission well section 18. Control of the injection fluid can also be achieved using the surface equipment to control injection rate or pressure of the fluid.
  • the downhole and/or uphole valves 38/38a or the downhole and/or uphole packers 40/40a can be configured to prevent fluid flow further up the geothermal well 14, which may be desired to stop transfer of heat and/or hot native fluid 36 from the heat-receiving well section 16 or heat-transmitting well section 18 further uphole or for well control purposes.
  • the downhole/uphole valves 38/38a and/or the downhole/uphole packers 40/40a can be located in various parts of the heat-transmission well section 18, as shown in Figs. 6 and 7 for example.
  • the geothermal well 14 may include a fluid circulation system that allows fluid to circulate without being injected into the reservoir.
  • the geothermal well may be configured such that hot circulation fluid is circulated from the surface down into the heattransmission well section 18 to provide additional heat to the reservoir.
  • the circulation fluid could be steam, but since the steam is not injected into the reservoir the condensate does not require substantial water treatment before being reused to generate additional steam. It is also possible to configure the fluid circulation system to receive the hot native fluid and allow it pass up and through the heat-transmission well section 18 without being injected into the reservoir.
  • the downhole and/or uphole valves 38/38a or the downhole and/or uphole packers 40/40a can also be configured to prevent hot native fluid 36 backflow or injection fluid 32 flow downhole into the geothermal well 14. This may be desired to stop transfer of heat and/or fluid from the heat receiving well section 16 or heat-transmitting well section 18 further downhole, or for well control purposes.
  • the downhole/uphole valves 38/38a and/or the downhole/uphole packers 40/40a can be located in various parts of the heat-receiving well section 16 or the heattransmission well section 18, as shown in Figs. 5-7 for example.
  • a method for recovering heavy hydrocarbons 12 from a subsurface formation comprising transferring geothermal heat from a geothermal zone 22 of the formation to a heavy hydrocarbon zone 24 located above the geothermal zone 22 by conduction to promote mobilization of the heavy hydrocarbons 12 for recovery thereof to surface 26.
  • a method for recovering heavy hydrocarbons 12 from a subsurface formation comprising transferring geothermal heat from a geothermal zone 22 of the formation to a heavy hydrocarbon zone 24 located above the geothermal zone 22 without transferring the geothermal heat to surface 26 to promote mobilization of the heavy hydrocarbons 12 for recovery thereof to the surface 26.
  • a method for recovering heavy hydrocarbons 12 from a subsurface formation includes heating a heavy hydrocarbon zone 24 of the formation and mobilizing heavy hydrocarbons 12 contained therein with geothermal heat obtained from a geothermal zone 22 of the formation, wherein the geothermal heat is obtained by a geothermal well 14.
  • the geothermal well 14 includes a heat-receiving well section 16 extending within the geothermal zone 22 of the formation, and is configured to be heated by geothermal heat in the lower geothermal zone 22 and transmit heat upward.
  • the geothermal well 14 also includes a heat-transmission well section 18 extending from the heat-receiving well section 16 and extending into at least the heavy hydrocarbon zone 24 of the formation located above the geothermal zone 22, the heat-transmission well section 18 being configured to receive heat from the heat-receiving well section 16 and transmit heat into the heavy hydrocarbon zone 24 to promote mobilization of the heavy hydrocarbonsl2.
  • the method further includes recovering the mobilized heavy hydrocarbons 12 to surface 26.
  • the methods described herein may utilize the systems 10 or geothermal wells 14 according to the example implementations described herein, either alone or in combination.
  • Recovering mobilized heavy hydrocarbons 12 may involve the use of one or more production wells 20 located nearby or distant to the geothermal wells 14.
  • the recovering of the mobilized heavy hydrocarbons 12 is performed by gravity drainage.
  • the heating and the recovering are performed simultaneously.
  • the heating is performed as a pretreatment step prior to recovering the mobilized heavy hydrocarbons 12 from the subsurface formation.
  • the geothermal heating methods can be used for starting up a well pair or a well to be used for injection.
  • the geothermal heating methods can be used where the geothermal well operates in conjunction with various other wells and in situ recovery methods, such as SAGD and CSS, where the geothermal well is located above, beside, below or offset with respect to another well that recovers production fluid.
  • the heating of the heavy hydrocarbon zone 24 is performed by conduction of the geothermal heat through the heat-receiving well section 16 and the heat-transmission well section 18 and into the heavy hydrocarbon zone 24 in the absence of fluid injection into the geothermal well 14 and/or heavy hydrocarbon zone 24.
  • the heating of the heavy hydrocarbon zone 24 is performed by conduction of the geothermal heat from the heat-receiving well section 16 to the heat-transmission well section 18, and by downhole injection of an injection fluid 32 that is heated in the heat-transmission well section 18 and then injected or released into the heavy hydrocarbon zone 24.
  • the heating of the heavy hydrocarbon zone 24 is performed by conduction of the geothermal heat from the heat-receiving well section 16 to the heat-transmission well section 18, and by injection of a hot native fluid 36 that is received from the geothermal zone 22 of the formation through heat-receiving well section 16, transported uphole to the heat-transmission well section 18, and then injected into the heavy hydrocarbon zone 24.
  • the heating of the heavy hydrocarbon zone 24 includes a circulation fluid downhole into the geothermal well 14, wherein the circulation fluid is circulated through the heat-receiving well section 16 to be heated to form a heated fluid 32, and then the heated fluid is transported to the heat-transmission well section 18 for injection into the heavy hydrocarbon zone 24 or for indirect heating of the heavy hydrocarbon zone 24.
  • Fig. 15 and 16 generally discloses systems in which the geothermal well is configured and operated to not only provide geothermal heat to a target subterranean zone, such as the hydrocarbon zone 24, but also to bring a portion of the heat and/or hot native fluid 36to surface.
  • the geothermal heat brought to surface could then be used for various purposes, including steam generation for surface or subterranean applications, electricity generation, and/or other uses.
  • Fig. 15 and 16 illustrates the system 10 that includes the geothermal well 14 which may transport geothermal heat by conduction from the hot geothermal zone 22 for recovery to the surface 26.
  • the geothermal well 14 would thus be appropriately completed with equipment for enabling heat conduction into the hydrocarbon zone 24 and up to the surface 26.
  • the geothermal well 14 can include the elongated component 30 or using a supercritical fluid 42, as previously described, located in the wellbore of the geothermal well and composed of a heat conductive material, and the heat is transmitted upward (or “uphole” as depicted by the arrows in Fig. 8) from the heat-receiving well section 16 to the surface 26 by conduction.
  • the elongated component 30 is constructed so as to promote heating from the geothermal zone, conducting heat into the hydrocarbon zone 24 and also uphole to the surface 26. The elongated component 30 may therefore further extend into the upper well section 28 and up to the surface 26.
  • the insulated casing or other insulation equipment may be present in the upper well section 28 of the geothermal well 14 to limit heat loss to the formation that is uphole of the hydrocarbon zone 24 before the heat reaches the surface.
  • the insulation can be provided where heat loss is to be minimized and not in the regions where heat is to be received and delivered.
  • different segments of the elongated component 30 could be insulated while others are exposed to promote heat transfer with the formation or surface equipment.
  • the elongated component 30 may be replaced by a supercritical fluid 42 which is used to conduct geothermal heat from the heatreceiving well section 16 to the heat-transmission well section 18 and further to upper- well section 28 for recovery to the surface 22.
  • the system 10 also involves allowing a hot native fluid 36 to flow from the geothermal zone 22 through the geothermal well 14 to the surface 26, as also depicted in Fig. 15 and 16.
  • the hot native fluid 36 may be the hot native fluid as previously described.
  • the hot native fluid as well as heat conducted from the geothermal zone would be brought up to the hydrocarbon zone for heating.
  • a portion of the heat can then be conducted up to the surface and/or at least a portion of the hot native fluid can be brought up to surface.
  • the heat that is in the hot native fluid and/or obtained through conduction, can then be used at surface for various applications.
  • the system 10 involves allowing a hot native fluid 36 to flow from the geothermal zone 22 through the geothermal well 14 to the surface 26, in the absence of conduction through a solid medium. Therefore, according to this implementation, the geothermal well 14 may not include the elongated component 30.
  • the geothermal heat and/or hot native fluid 36 recovered to the surface 26 may be utilized as thermal energy and/or utilized to produce electrical energy.
  • geothermal heat may be used directly for heating, such as for heating homes or for heating nearby or distant oil pipelines to maintain a low oil viscosity at the surface.
  • geothermal heat may also be used to generate electricity, such as for example by first heating water using the recovered geothermal heat to generate steam, and powering steam turbines. Steam can then be used for heating, as described above.
  • Steam and electricity may be produced at the surface, optionally using steam insulated tanks to prevent cooling of the steam.
  • steam is directly obtained from the geothermal well 14 as the hot native fluid 36 from the geothermal zone.
  • the vacuum insulated tubing may be extended in regions of the geothermal well 14, such as in the upper well section 28, to prevent cooling of the hot native fluid 36 (e.g., steam).
  • geothermal heat obtained by embodiments of the system described herein may be used to power a thermoelectric generator to generate electricity..
  • injection fluid 32 may be injected into the geothermal well and is heated by the hot geothermal zone. This geothermally-heated injection fluid may then be recovered to the surface for use as thermal energy, electrical energy, and/or for injection (or reinjection) into a nearby or distant heavy hydrocarbon zone (Fig. 19).
  • the recovered geothermal heat, hot native fluid 36, and/or geothermally-heated injection fluid 12 may be recirculated or reinjected into a nearby or distant heavy hydrocarbon zone 24 for heating and recovery of heavy hydrocarbons.
  • the recovered geothermal heat and/or hot native fluid is recirculated or reinjected into the same geothermal well 14.
  • the recovered geothermal heat and/or hot native fluid is recirculated or reinjected into one or more nearby or distant geothermal wells as described herein, or abandoned, previously used, or repurposed wells (e.g., injection or production well).
  • the recovered recovered geothermal heat, hot native fluid 36, and/or geothermally-heated injection fluid can therefore be re-injected into a geothermal well or production well for recovering heavy hydrocarbons from the same subsurface formation and/or a second nearby or distant subsurface formation.
  • the systems described herein may not employ the use of a boiler and/or a heat exchanger at the surface to maintain the temperature of the geothermal heat, hot native fluid, or geothermally-heated injection fluid.
  • the temperature of recovered geothermal heat, hot native fluid, or geothermally-heated injection fluid may be maintained using known thermal insulation techniques and tubing
  • a portion of the geothermal heat can be used in a surface facility to generate steam. It is also possible to use a portion of the geothermal heat for steam generation using a near-surface steam generator, as well as steam insulated tanks, located underground but close to the surface (i.e., near surface).
  • the geothermal well 14 could be operated in different heat recovery modes over time. For example, the geothermal well could initially be operated in one heat recovery mode where geothermal heat is only brought up to the hydrocarbon zone, and then at a later phase in operations the geothermal well could be switched to operate in another heat recovery mode in which geothermal heat is only brought to surface or is delivered to the hydrocarbon zone and the surface.
  • the operation of the geothermal well could be modified over time depending on heat requirements and end-uses. For example, after the hydrocarbon recovery process for a given reservoir has been completed, the geothermal well could be converted to a heat-to-surface well to continue delivering heat to the surface.
  • the systems in which the geothermal well 14 is configured and operated to bring geothermal heat from a hot geothermal zone to the surface may be configured and operated in the absence of recovery of hydrocarbons, as depicted in Fig. 17 and 18. Therefore, the geothermal well 14 may not include the heating of a target subterranean zone (e.g., hydrocarbon zone) for the purpose of enhancing recovery of fluid from the zone.
  • geothermal heat may be recovered to the surface, or near-surface, by conduction (e.g., with the use of the elongated component 30 [Fig. 17] or a supercritical fluid 42 [Fig. 18]).
  • a hot native fluid 36 (e.g., steam) from a subterranean zone may be recovered to the surface, or near-surface, in the presence or absence of conduction (i.e., absence of the elongated component 30).
  • the system may include any one of the geothermal wells including one or more the sections described herein. For example, if geothermal heat and/or hot naive fluid is not being delivered into a hydrocarbon zone, the heat-transmission well section may not be necessary and may be configured differently (e.g., it may be insulated to discourage heat transmission into that zone). Recovered fluid and/or heat may be used at surface to generate electricity and/or steam, as previously described.
  • the system that is configured and operated to bring geothermal heat from a hot geothermal zone to the surface in the absence of recovery of hydrocarbons may include the use of offshore wells or onshore wells, and such wells may be abandoned or previously-used.
  • Such wells may include production wells, such as oil production wells and/or injection wells, and may or may not be further drilled into to reach deeper and/or hotter geothermal zones.
  • At least a downhole portion of the abandoned well may be located in the geothermal zone of the formation. Initial temperature readings of abandoned wells may be obtained to determine whether the well is suitable for recovering geothermal heat to the surface.
  • Abandoned wells may be configured with the elongated component 30, supercritical fluid 42, and/or insulated tubing, as previously described, extending downhole for recovery of geothermal heat by conduction.
  • a hot native fluid 36 e.g., steam
  • Recovered fluid and/or heat may be used to generate electricity and/or steam, as previously described.
  • shut-in well When abandoned or shut-in well are used, the wells can be recompleted to provide completion equipment suitable for retrieving the geothermal heat.
  • a shut-in well could be recompleted by running in an elongated component with predetermined segments that are insulated and exposed to promote conduction of heat from hot zones up to the surface while inhibiting heat loss to the formation.
  • the elongated component in the upper vertical section of the wells could be insulated, for example, while the deeper parts of the elongated component are exposed to receive geothermal heat.
  • shut-in wells could be leveraged without completion with an elongated component but are configured so that heat that transfers up to the surface is captured and utilized. This could involve surface equipment that is connected to the wellhead to capture heat that is transferred via conduction and/or convection to surface.
  • the method includes recovering geothermal heat obtained by a geothermal well and transporting the geothermal heat by conduction and/or transporting a hot native fluid 36 from the geothermal zone 22, to the surface 26.
  • the method utilizes the systems 10 or geothermal wells 14 according to example implementations described herein, either alone or in combination.
  • the method may include heating a heavy hydrocarbon zone 24 of the formation and mobilizing heavy hydrocarbons 12 contained therein with a portion of geothermal heat, and optionally a portion of the hot native fluid 36, obtained from the geothermal zone 22 of the formation, for recovery of the mobilized heavy hydrocarbons 12 to the surface 26 by a nearby production well 20, as previously described.
  • a method for recovering geothermal heat from a subsurface formation using an abandoned well e.g., production or injection well.
  • At least a downhole portion of the abandoned well may be located in the geothermal zone of the formation.
  • Initial temperature readings of abandoned wells may therefore be obtained to determine whether the well is suitable for recovering geothermal heat to the surface, or near-surface.
  • the method may therefore include an initial step of determining suitable wells to be used as geothermal wells, and the determining step can include temperature sensing.
  • the temperature sensing can use equipment that exists in the well, or instrumentation that is deployed into the abandoned well to obtain temperature and/or pressure readings.
  • the method may also include drilling downhole into the abandoned well to reach a geothermal zone of the formation to extend the well and reach more elevated temperatures.
  • the abandoned well may be configured to receive the elongated component 30 or a supercritical fluid 42, as previously described, to reach the geothermal zone and transmit geothermal heat uphole in the well by conduction. Insulated casing may be applied at any point in the well to prevent heat loss.
  • the abandoned well may be configured to receive a hot native fluid 36 from the geothermal zone of the formation, and transport the hot native fluid uphole in the well to the surface.
  • the words “comprising” (and any form of comprising, such as “comprise” and “comprises”), “having” (and any form of having, such as “have” and “has”), “including” (and any form of including, such as “includes” and “include”) or “containing” (and any form of containing, such as “contains” and “contain”) are inclusive or open- ended and do not exclude additional, unrecited elements or method steps.

Landscapes

  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Physics & Mathematics (AREA)
  • Geochemistry & Mineralogy (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Sustainable Energy (AREA)
  • General Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • Combustion & Propulsion (AREA)
  • Chemical & Material Sciences (AREA)
  • Sustainable Development (AREA)
  • Hydrology & Water Resources (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)

Abstract

La présente description concerne un système et un procédé de récupération d'hydrocarbures ou de fluides, tels que des hydrocarbures lourds, à partir d'une formation de sous-sol, et plus particulièrement, un système et un procédé de récupération d'hydrocarbures à partir d'une formation souterraine comprenant un puits géothermique. Le système comprend un puits géothermique et un puits de production, le puits géothermique comprenant généralement une section de puits de réception de chaleur et une section de puits de transmission de chaleur. En outre, l'invention décrit des systèmes et des procédés de récupération de chaleur géothermique et/ou de fluide natif chaud à partir d'une formation de sous-sol pour une utilisation en surface.
PCT/US2022/046082 2021-10-08 2022-10-07 Chauffage géothermique de réservoirs d'hydrocarbures pour récupération in situ WO2023059896A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
PE2024000686A PE20241506A1 (es) 2021-10-08 2022-10-07 Calentamiento geotermico de yacimientos de hidrocarburos para su recuperacion in situ

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
CA3133630A CA3133630A1 (fr) 2021-10-08 2021-10-08 Chauffage geothermique de reservoirs d'hydrocarbures pour la recuperation sur place
CA3,133,630 2021-10-08
CA3136916A CA3136916A1 (fr) 2021-10-08 2021-11-02 Chauffage geothermique de reservoirs d'hydrocarbures pour la recuperation sur place
CA3,136,916 2021-11-02

Publications (1)

Publication Number Publication Date
WO2023059896A1 true WO2023059896A1 (fr) 2023-04-13

Family

ID=84329581

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2022/046082 WO2023059896A1 (fr) 2021-10-08 2022-10-07 Chauffage géothermique de réservoirs d'hydrocarbures pour récupération in situ

Country Status (3)

Country Link
CA (1) CA3177047A1 (fr)
PE (1) PE20241506A1 (fr)
WO (1) WO2023059896A1 (fr)

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2625053A (en) * 2022-11-30 2024-06-12 James Sowers Hank Feed water system, water processing system, and associated systems & methods
US20240328398A1 (en) * 2023-03-29 2024-10-03 Abu Dhabi National Oil Company System and method for generation and extraction of fossil fuel and hydrogen from a geologic formation with increased energy efficiency

Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3679264A (en) * 1969-10-22 1972-07-25 Allen T Van Huisen Geothermal in situ mining and retorting system
US20150159917A1 (en) * 2011-12-16 2015-06-11 Gtherm Inc. Method and apparatus of using heat generated by single well engineered geothermal system (swegs) to heat oil laden rock or rock with permeable fluid content for enhance oil recovery
CN107143313B (zh) * 2017-07-14 2018-11-16 中国石油大学(华东) 一种注水同时开发地热能和水合物藏的井结构设计与方法

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3679264A (en) * 1969-10-22 1972-07-25 Allen T Van Huisen Geothermal in situ mining and retorting system
US20150159917A1 (en) * 2011-12-16 2015-06-11 Gtherm Inc. Method and apparatus of using heat generated by single well engineered geothermal system (swegs) to heat oil laden rock or rock with permeable fluid content for enhance oil recovery
CN107143313B (zh) * 2017-07-14 2018-11-16 中国石油大学(华东) 一种注水同时开发地热能和水合物藏的井结构设计与方法

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
LIU YONGGE ET AL: "Technical and economic feasibility of a novel heavy oil recovery method: Geothermal energy assisted heavy oil recovery", ENERGY, ELSEVIER, AMSTERDAM, NL, vol. 181, 15 August 2019 (2019-08-15), pages 853 - 867, XP085733049, ISSN: 0360-5442, [retrieved on 20190601], DOI: 10.1016/J.ENERGY.2019.05.207 *

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2625053A (en) * 2022-11-30 2024-06-12 James Sowers Hank Feed water system, water processing system, and associated systems & methods
US20240328398A1 (en) * 2023-03-29 2024-10-03 Abu Dhabi National Oil Company System and method for generation and extraction of fossil fuel and hydrogen from a geologic formation with increased energy efficiency

Also Published As

Publication number Publication date
CA3177047A1 (fr) 2023-04-08
PE20241506A1 (es) 2024-07-19

Similar Documents

Publication Publication Date Title
US11788393B2 (en) Thermal energy delivery and oil production arrangements and methods thereof
CA2760967C (fr) Procede in situ et systeme pour l'extraction de petrole a partir de schiste argileux
JP5611962B2 (ja) 地表下地層を処理するために使用される循環熱伝導流体システム
US7147057B2 (en) Loop systems and methods of using the same for conveying and distributing thermal energy into a wellbore
US8464792B2 (en) Conduction convection reflux retorting process
CN102007266B (zh) 用于处理地下含烃地层的系统和方法
US8733437B2 (en) Apparatus and methods for recovery of hydrocarbons
RU2601626C1 (ru) Способ и системы для поставки тепловой энергии в горизонтальный ствол скважины
CA2867873C (fr) Procedes et systemes pour energie thermique de fond de trou pour puits de forage verticaux
WO2023059896A1 (fr) Chauffage géothermique de réservoirs d'hydrocarbures pour récupération in situ
CN114482955B (zh) 利用井下原油裂解改质提高深层稠油开采效率的方法
CA3136916A1 (fr) Chauffage geothermique de reservoirs d'hydrocarbures pour la recuperation sur place

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 22800926

Country of ref document: EP

Kind code of ref document: A1

WWE Wipo information: entry into national phase

Ref document number: 000686-2024

Country of ref document: PE

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 22800926

Country of ref document: EP

Kind code of ref document: A1