US20130008651A1 - Method for hydrocarbon recovery using sagd and infill wells with rf heating - Google Patents

Method for hydrocarbon recovery using sagd and infill wells with rf heating Download PDF

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Publication number
US20130008651A1
US20130008651A1 US13/176,778 US201113176778A US2013008651A1 US 20130008651 A1 US20130008651 A1 US 20130008651A1 US 201113176778 A US201113176778 A US 201113176778A US 2013008651 A1 US2013008651 A1 US 2013008651A1
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Prior art keywords
infill
injector
well
wells
producer
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Abandoned
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US13/176,778
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English (en)
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Mark Alan Trautman
Daniel SULTENFUSS
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Harris Corp
ConocoPhillips Co
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Harris Corp
ConocoPhillips Co
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Priority to US13/176,778 priority Critical patent/US20130008651A1/en
Assigned to HARRIS CORPORATION reassignment HARRIS CORPORATION ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: TRAUTMAN, MARK ALAN
Assigned to CONOCOPHILLIPS COMPANY reassignment CONOCOPHILLIPS COMPANY ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: SULTENFUSS, Daniel
Priority to PCT/US2012/045478 priority patent/WO2013006660A2/fr
Priority to CA2841792A priority patent/CA2841792A1/fr
Priority to BR112014000103A priority patent/BR112014000103A2/pt
Publication of US20130008651A1 publication Critical patent/US20130008651A1/en
Abandoned legal-status Critical Current

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    • 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
    • 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
    • E21B36/00—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
    • E21B36/04—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones using electrical heaters
    • 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
    • E21B43/2406—Steam assisted gravity drainage [SAGD]
    • E21B43/2408—SAGD in combination with other methods

Definitions

  • the present invention relates to the field of hydrocarbon resource recovery, and, more particularly, to hydrocarbon resource recovery using RF heating.
  • SAGD Steam-Assisted Gravity Drainage
  • the heavy oil is immobile at reservoir temperatures and therefore the oil is typically heated to reduce its viscosity and mobilize the oil flow.
  • pairs of injector and producer wells are formed to be laterally extending in the ground.
  • Each pair of injector/producer wells includes a lower producer well and an upper injector well.
  • the injector/producer wells are typically located in the payzone of the subterranean formation between an underburden layer and an overburden layer.
  • the upper injector well is used to typically inject steam
  • the lower producer well collects the heated crude oil or bitumen that flows out of the formation, along with any water from the condensation of injected steam.
  • the injected steam forms a steam chamber that expands vertically and horizontally in the formation.
  • the heat from the steam reduces the viscosity of the heavy crude oil or bitumen which allows it to flow down into the lower producer well where it is collected and recovered.
  • the steam and gases rise due to their lower density so that steam is not produced at the lower producer well and steam trap control is used to the same affect.
  • Gases such as methane, carbon dioxide, and hydrogen sulfide, for example, may tend to rise in the steam chamber and fill the void space left by the oil defining an insulating layer above the steam. Oil and water flow is by gravity driven drainage, into the lower producer well.
  • SAGD may produce a smooth, even production that can be as high as 70% to 80% of the original oil in place (OOIP) in suitable reservoirs.
  • the SAGD process may be relatively sensitive to shale streaks and other vertical barriers since, as the rock is heated, differential thermal expansion causes fractures in it, allowing steam and fluids to flow through.
  • SAGD may be twice as efficient as the older cyclic steam stimulation (CSS) process.
  • Oil sands may represent as much as two-thirds of the world's total petroleum resource, with at least 1.7 trillion barrels in the Canadian Athabasca Oil Sands, for example.
  • Canada has a large-scale commercial oil sands industry, though a small amount of oil from oil sands is also produced in Venezuela.
  • Oil sands now are the source of almost half of Canada's oil production, although due to the 2008 economic downturn work on new projects has been deferred, while Venezuelan production has been declining in recent years. Oil is not yet produced from oil sands on a significant level in other countries.
  • U.S. Published Patent Application No. 2010/0078163 to Banerjee et al. discloses a hydrocarbon recovery process whereby three wells are provided: an uppermost well used to inject water, a middle well used to introduce microwaves into the reservoir, and a lowermost well for production.
  • a microwave generator generates microwaves which are directed into a zone above the middle well through a series of waveguides. The frequency of the microwaves is at a frequency substantially equivalent to the resonant frequency of the water so that the water is heated.
  • U.S. Published Application No. 2010/0294489 to Wheeler, Jr. et al. discloses using microwaves to provide heating. An activator is injected below the surface and is heated by the microwaves, and the activator then heats the heavy oil in the production well.
  • U.S. Published Application No. 2010/0294488 to Wheeler et al. discloses a similar approach.
  • U.S. Pat. No. 5,046,559 to Glandt discloses a method for producing oil from tar sands by electrically preheating paths of increased injectivity between an injector well and a pair of producer wells arranged in a triangular pattern. The paths of increased injectivity are then steam flooded to produce the hydrocarbon resources.
  • SAGD may not efficiently permit recovery of the hydrocarbon resources in a wedge region between adjacent pairs of injector/producer wells as disclosed, for example, in U.S. Pat. No. 7,556,099 to Arthur et al. While the steam chambers of adjacent pairs of injector/producer wells will typically grow into hydraulic communication with one another, there is still typically the lower area between adjacent injector/producer well pairs (the wedge region) from which the hydrocarbon resources are not recovered.
  • the Arthur et al. patent discloses adding an infill well in the wedge region between adjacent pairs of injector/producer wells. A mobilizing fluid in the form of steam is injected into the infill well until fluid communication is established between the adjacent steam chamber and the infill well. The infill well is then produced by a gravity controlled recovery process. Unfortunately, this approach requires additional energy and water input, and may produce additional wastewater.
  • a method for hydrocarbon resource recovery in a subterranean formation comprising forming a plurality of spaced apart injector/producer well pairs in the subterranean formation, with each injector/producer well pair comprising a laterally extending producer well and a laterally extending injector well spaced thereabove.
  • the method also includes forming a plurality of laterally extending infill wells in the subterranean formation, with each infill well being located between respective adjacent injector/producer well pairs.
  • the method includes recovering hydrocarbon resources from the producer wells based upon Steam Assisted Gravity Drainage (SAGD) via the injector/producer well pairs.
  • SAGD Steam Assisted Gravity Drainage
  • the method includes recovering hydrocarbon resources from the infill wells based upon RF heating regions of the subterranean formation surrounding the respective infill wells. Accordingly, the hydrocarbon resources in the wedge region between adjacent injector/producer well pairs can be recovered. In addition, less overall energy may be used to heat the formation, and less water may be used in the recovery process. Faster oil recovery can also be achieved.
  • recovering hydrocarbon resources from the producer wells based upon SAGD typically creates a respective steam chamber associated with each injector/producer well pair.
  • recovering hydrocarbon resources from the infill wells based upon RF heating may comprise creating hydraulic communication between each pair of adjacent steam chambers and an associated infill well therebetween.
  • recovering hydrocarbon resources from the infill wells based upon RF heating may further comprise using SAGD to provide pressure support in the regions of the subterranean formation surrounding the infill wells.
  • the RF heating may be delivered from the infill wells themselves. More particularly, the method may include positioning at least one respective RF antenna within each of the infill wells, and wherein the RF heating comprises supplying RF energy to the RF antennas.
  • each infill well may be positioned midway between respective adjacent injector/producer well pairs.
  • each infill well may be positioned below a level of respective adjacent injector wells and closer to a level of adjacent producer wells.
  • the method may further comprise using a steamflood drive after using SAGD to recover further hydrocarbon resources.
  • the subterranean formation may comprise an oil sand formation, for example.
  • FIG. 1 is a flowchart for the method in accordance with the invention.
  • FIG. 2 is a schematic cross-section of a portion of a hydrocarbon bearing subterranean formation in accordance with the present invention.
  • FIG. 3 is a schematic cross-section similar to FIG. 2 and shown at a later time during the hydrocarbon recovery process.
  • FIGS. 4A and 4B are schematic diagrams illustrating simulations of the expanding steam chambers at different times using the method in accordance with the invention.
  • FIGS. 4C and 4D are schematic diagrams illustrating simulations of the expanding steam chambers at different times using only conventional SAGD as in the prior art.
  • FIG. 5 is a graph of cumulative oil recovery versus time for various simulated embodiments of the method in accordance with the present invention and compared against a simulation using only conventional SAGD as in the prior art.
  • FIG. 6 is a graph of energy usage versus cumulative oil recovered for a simulated embodiment of the method in accordance with the invention.
  • FIG. 7 is a graph of energy usage versus cumulative oil recovered for a simulated embodiment of using only conventional SAGD as in the prior art.
  • FIG. 8 is a graph of water-to-oil ratio versus cumulative oil recovered for a simulated embodiment of the method in accordance with the invention.
  • FIG. 9 is a graph of water-to-oil ratio versus cumulative oil recovered for a simulated embodiment of using only conventional SAGD as in the prior art.
  • FIG. 10 is a table of comparative results of simulations of an embodiment of the method of the present invention and using only conventional SAGD as in the prior art.
  • the method is for hydrocarbon resource recovery in a subterranean formation 40 and comprises, at Block 24 , forming a plurality of spaced apart injector/producer well pairs 41 a, 42 a, 41 b, 42 b in the subterranean formation.
  • the subterranean formation 40 includes a payzone 45 between an underburden layer 46 and an overburden layer 47 , as will be appreciated by those skilled in the art.
  • the subterranean formation 40 may comprise an oil sand formation, for example.
  • a typical payzone 45 may be 15 to 30 meters in thickness, for example.
  • the overall field may occupy a region of one by twenty kilometers, for example, although other sizes are also possible.
  • the first injector/producer well pair comprises a laterally extending producer well 42 a and a laterally extending injector well 41 a spaced thereabove.
  • a typical vertical spacing may be about 5 meters, for example.
  • the second injector/producer well pair comprises a laterally extending producer well 42 b and a laterally extending injector well 41 b spaced thereabove.
  • a plurality of laterally extending infill wells 43 are formed in the payzone 45 of the subterranean formation 40 , with each infill well being located between respective adjacent injector/producer well pairs in the so-called wedge region 44 .
  • a typical lateral spacing is 50 meters from the infill well 43 to each adjacent injector producer well pair.
  • more than one infill well 43 may be provided between respective adjacent injector/producer well pairs as will be appreciated by those skilled in the art.
  • the method includes recovering hydrocarbon resources from the producer wells 42 a, 42 b based upon Steam Assisted Gravity Drainage (SAGD) via the injector/producer well pairs (Block 28 ).
  • the method includes at Block 30 recovering hydrocarbon resources from the infill wells 43 based upon RF heating regions of the payzone 45 of the subterranean formation 40 surrounding the respective infill wells before stopping at Block 32 .
  • the hydrocarbon resources in the wedge region 44 between adjacent injector/producer well pairs 42 a, 41 a, 42 b, 41 b can be recovered.
  • Blocks 28 and 30 are illustrated as separate steps for clarity of explanation in the flowchart 20 they are typically performed at a same time as will be appreciated by those skilled in the art. And, as will be described in greater detail below, less overall energy may be used to heat the formation 40 , and less water may be used in the recovery process.
  • recovering hydrocarbon resources from the producer wells 42 a, 42 b based upon SAGD illustratively creates a respective growing steam chamber 53 a, 53 b associated with each injector/producer well pair 41 a, 42 a, 41 b, 42 b as seen perhaps best in FIG. 3 .
  • the two steam chambers 53 a, 53 b may eventually join together in an upper middle region above the wedge region 44 .
  • recovering hydrocarbon resources from the infill well 43 based upon RF heating may further comprise using SAGD to provide pressure support in the region of the subterranean formation surrounding the infill well.
  • SAGD SAGD
  • arrows 54 a, 54 b indicate a direction of the gravity drive oil path in each respective steam chamber 53 a, 53 b; and arrows 55 a, 55 b indicate the steamflood drive oil path toward the infill well 43 as will be appreciated by those skilled in the art.
  • the RF heating is delivered from the antenna 51 within the infill well 43 .
  • This is a particularly advantageous arrangement, since only the infill well 43 need be drilled which can serve to facilitate the antenna positioning and which can also be used as a producer for the wedge region 44 via a coaxial arrangement.
  • it may be desirable to position one or more RF antennas differently in the subterranean formation 40 so long as heat can be effectively provided to at least the regions surrounding the infill well 43 so that oil can be recovered from the wedge region 44 .
  • the method may include positioning at least one respective RF antenna 51 within each infill well in the payzone 45 of the subterranean formation 40 , and supplying RF energy from the RF source 50 to the RF antenna 51 .
  • the RF heating mobilizes the oil between adjacent steam chambers 53 a, 53 b and the infill well 43 ; establishes hydraulic communication between the chambers and the infill well; allows oil to drain to the infill well via gravity drainage with pressure support from the steam chambers; and later in the well's life, steamflood can provide additional drive to recover unproduced by gravity drainage.
  • the steamflood drive is a displacement drive, not a gravity drive, therefore, the recovery rates are less affected by the thickness of the payzone 45 .
  • each infill well 43 may be positioned midway between respective adjacent injector/producer well pairs 41 a, 42 a, 41 b, 42 b. Each infill well 43 may also be positioned below a level of respective adjacent injector wells 41 a, 41 b and closer to a level of adjacent producer wells 42 a, 42 b.
  • the RF heating may be started prior to the injection of steam into the injector wells 41 a, 41 b, while in other embodiments the RF heating may be performed simultaneously with or after the injection of steam into the injector wells 41 a, 41 b. In addition, once hydraulic communication is established it may be desirable to turn off the RF heating to thereby save energy.
  • the injection of steam through a single well may sometimes be difficult due to low fluid injectivity of a cold formation and the desire to maintain a sufficiently low pressure so as to avoid fracturing the adjacent formation structure. Accordingly, steam is typically injected cyclically into a traditional steam well.
  • the significant advantage of using RF heating in the wedge region 44 is that the RF energy input does not need cycling since the RF energy is basically absorbed as heat by the water or moisture in the surrounding areas.
  • the RF heating effectively and efficiently establishes hydraulic communication with the infill well 43 by heating the oil to a sufficient temperature. This hydraulic communication permits pressure support from the steam chambers 53 a, 53 b to encourage the flow of oil from the payzone 45 into the infill well 43 .
  • Heating of the wedge region 44 using other techniques such as with gas or water injection may not be effective because of the relatively low injectivity as will be appreciated by those skilled in the art.
  • the energy input requirement for the steam for SAGD may also be reduced. Accordingly, the combination of SAGD and RF heating provides efficient use of electrical and other energy inputs.
  • the infill wells 43 can be added after SAGD has been performed on the payzone 45 ; however, in such embodiments the ground may already be heated which may make well boring more difficult. Accordingly, it is typically more beneficial to form the infill wells 43 at the same time the other wells 41 a, 41 b, 42 a, 42 b are being formed in the payzone 45 of the subterranean formation 40 .
  • the production of hydrocarbon resources also from the wedge regions 44 provides more efficient use of the available land area available.
  • an RF susceptor in addition to water could be added to the payzone 45 to convert the RF energy into heat as will be appreciated by those skilled in the art.
  • the typical timescale of recovery using SAGD alone is typically largely determined by the reservoir conditions and the payzone 45 thickness, with thicker being better. There have been few ways to accelerate recovery using SAGD. There may be a high heat loss to the overburden layer 47 due to the relatively long production cycle. There may also be startup issues and water usage raises potential environmental and cost concerns.
  • FIGS. 4A-4D a comparison of the described embodiments versus traditional SAGD alone is now explained. More particularly, FIG. 4A shows a simulation of the steam chamber progress after three months using the combined SAGD and RF infill heating of the present invention, and FIG. 4B shows the simulation after three years. In contrast, FIG. 4C shows a simulation of steam chamber progress based upon conventional SAGD alone, and FIG. 4D continues that simulation at three years. It can be readily seen that the steam chamber has progressed significantly further in accordance with the invention at the six month date.
  • the horizontal plot 60 is at a 70% of the original oil-in-place (OOIP) for a simulation of a five meter length axial segment of a well.
  • OOIP oil-in-place
  • Full scale well results can be extrapolated by using a ratio of the well length to the five meter length simulation.
  • Plot 66 represents simulated recovery of oil using only SAGD.
  • the other plots are for SAGD plus RF heating (at 200 Khz) for nine months 61 , twelve months 62 , fifteen months 63 , twelve months 64 , and twenty-one months 65 . Again it can be seen that the recovery is accelerated compared to conventional SAGD alone, and the RF heating permits trading of RF energy costs versus recovery time.
  • FIG. 6 shows a plot of RF energy input per barrel of recovered oil 71 , along with the steam energy input 72 and the total energy input 73 , with the 70% OOIP value indicated by the vertical line 74 , and these are also for the five meter length axial segment simulation.
  • FIG. 7 shows a corresponding plot of the total energy input 75 for a convention SAGD process alone, and vertical line 76 is the 70% OOIP value.
  • the SAGD plus RF infill heating uses 1.35 GJ/bbl at a 70% recovery for the five meter length axial segment simulation, while conventional SAGD along uses 1.94 GJ/bbl; and the RF infill has a relatively low electricity energy requirement of 0.11 GJ/bbl.
  • the water-to-oil ratio for the invention is given by plot 81 and the steam-to-oil ratio is given by plot 82 , while the 70% OOIP value is given by plot 83 of FIG. 8 .
  • the water-to-oil ratio for the use of conventional SAGD only is given by plot 85 and the steam-to-oil ratio is given by plot 84 , while the 70% OOIP value is given by plot 86 of FIG. 9 .
  • the water-to-oil-ratio for the method including SAGD plus the RF heating as in the invention is 2.9 at 70% OOIP, and the corresponding value is 4.5 for SAGD alone.
  • the corresponding recovery time for the SAGD and RF heating of the invention reduces the normalized time down to 0.54.
  • the corresponding ratio for the SAGD and RF heating of the invention is reduced down to 2.9.
  • the corresponding energy input for the SAGD and RF heating of the invention is reduced down to 1.36.
  • the RF energy used by the invention is only 0.11 GJ/bbl.

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  • Engineering & Computer Science (AREA)
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  • Geochemistry & Mineralogy (AREA)
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US13/176,778 2011-07-06 2011-07-06 Method for hydrocarbon recovery using sagd and infill wells with rf heating Abandoned US20130008651A1 (en)

Priority Applications (4)

Application Number Priority Date Filing Date Title
US13/176,778 US20130008651A1 (en) 2011-07-06 2011-07-06 Method for hydrocarbon recovery using sagd and infill wells with rf heating
PCT/US2012/045478 WO2013006660A2 (fr) 2011-07-06 2012-07-05 Procédé permettant une récupération d'hydrocarbure à l'aide d'un drainage par gravité au moyen de vapeur (sagd) et de puits de remplissage dotés d'un chauffage par radiofréquence (rf)
CA2841792A CA2841792A1 (fr) 2011-07-06 2012-07-05 Procede permettant une recuperation d'hydrocarbure a l'aide d'un drainage par gravite au moyen de vapeur (sagd) et de puits de remplissage dotes d'un chauffage par radiofrequence(rf)
BR112014000103A BR112014000103A2 (pt) 2011-07-06 2012-07-05 método de recuperação de recurso de hidrocarbonetos em uma formação

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US13/176,778 US20130008651A1 (en) 2011-07-06 2011-07-06 Method for hydrocarbon recovery using sagd and infill wells with rf heating

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Cited By (7)

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US20140014324A1 (en) * 2012-07-13 2014-01-16 Harris Corporation Method of recovering hydrocarbon resources while injecting a solvent and supplying radio frequency power and related apparatus
US20140102700A1 (en) * 2012-10-16 2014-04-17 Conocophillips Company Mitigating thief zone losses by thief zone pressure maintenance through downhole radio frequency radiation heating
WO2014172533A1 (fr) * 2013-04-18 2014-10-23 Conocophillips Company Accélération de la récupération de pétrole lourd à travers un chauffage par rayonnement à radiofréquence de fond de trou
WO2015066796A1 (fr) * 2013-11-06 2015-05-14 Nexen Energy Ulc Procédés de production d'hydrocarbures dans un réservoir
US20190112907A1 (en) * 2016-05-12 2019-04-18 Nexen Energy Ulc Processes for producing hydrocarbons from a reservoir
US10370949B2 (en) 2015-09-23 2019-08-06 Conocophillips Company Thermal conditioning of fishbone well configurations
US10704371B2 (en) 2017-10-13 2020-07-07 Chevron U.S.A. Inc. Low dielectric zone for hydrocarbon recovery by dielectric heating

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DE102012014656A1 (de) * 2012-07-24 2014-01-30 Siemens Aktiengesellschaft Vorrichtung und Verfahren zur Gewinnung vonkohlenstoffhaltigen Substanzen aus Ölsand

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US20060283598A1 (en) * 2005-06-20 2006-12-21 Kasevich Raymond S Method and apparatus for in-situ radiofrequency assisted gravity drainage of oil (RAGD)
US7556099B2 (en) * 2006-06-14 2009-07-07 Encana Corporation Recovery process
US20100096126A1 (en) * 2008-10-17 2010-04-22 Sullivan Laura A Low pressure recovery process for acceleration of in-situ bitumen recovery

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US7975763B2 (en) * 2008-09-26 2011-07-12 Conocophillips Company Process for enhanced production of heavy oil using microwaves
US8555970B2 (en) 2009-05-20 2013-10-15 Conocophillips Company Accelerating the start-up phase for a steam assisted gravity drainage operation using radio frequency or microwave radiation
CA2704689C (fr) 2009-05-20 2015-11-17 Conocophillips Company Amelioration in situ du petrole brut lourd d'un puits de production par hyperfrequence et catalyseur

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US5109927A (en) * 1991-01-31 1992-05-05 Supernaw Irwin R RF in situ heating of heavy oil in combination with steam flooding
US20060283598A1 (en) * 2005-06-20 2006-12-21 Kasevich Raymond S Method and apparatus for in-situ radiofrequency assisted gravity drainage of oil (RAGD)
US7556099B2 (en) * 2006-06-14 2009-07-07 Encana Corporation Recovery process
US20100096126A1 (en) * 2008-10-17 2010-04-22 Sullivan Laura A Low pressure recovery process for acceleration of in-situ bitumen recovery

Cited By (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20140014324A1 (en) * 2012-07-13 2014-01-16 Harris Corporation Method of recovering hydrocarbon resources while injecting a solvent and supplying radio frequency power and related apparatus
US9103205B2 (en) * 2012-07-13 2015-08-11 Harris Corporation Method of recovering hydrocarbon resources while injecting a solvent and supplying radio frequency power and related apparatus
US10260325B2 (en) 2012-07-13 2019-04-16 Harris Corporation Method of recovering hydrocarbon resources while injecting a solvent and supplying radio frequency power and related apparatus
US20140102700A1 (en) * 2012-10-16 2014-04-17 Conocophillips Company Mitigating thief zone losses by thief zone pressure maintenance through downhole radio frequency radiation heating
WO2014172533A1 (fr) * 2013-04-18 2014-10-23 Conocophillips Company Accélération de la récupération de pétrole lourd à travers un chauffage par rayonnement à radiofréquence de fond de trou
US9719337B2 (en) 2013-04-18 2017-08-01 Conocophillips Company Acceleration of heavy oil recovery through downhole radio frequency radiation heating
WO2015066796A1 (fr) * 2013-11-06 2015-05-14 Nexen Energy Ulc Procédés de production d'hydrocarbures dans un réservoir
US10041341B2 (en) 2013-11-06 2018-08-07 Nexen Energy Ulc Processes for producing hydrocarbons from a reservoir
US10370949B2 (en) 2015-09-23 2019-08-06 Conocophillips Company Thermal conditioning of fishbone well configurations
US20190112907A1 (en) * 2016-05-12 2019-04-18 Nexen Energy Ulc Processes for producing hydrocarbons from a reservoir
US10704371B2 (en) 2017-10-13 2020-07-07 Chevron U.S.A. Inc. Low dielectric zone for hydrocarbon recovery by dielectric heating

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WO2013006660A2 (fr) 2013-01-10
WO2013006660A3 (fr) 2013-11-28
CA2841792A1 (fr) 2013-01-10

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