US20140048259A1 - Preconditioning for bitumen displacement - Google Patents

Preconditioning for bitumen displacement Download PDF

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Publication number
US20140048259A1
US20140048259A1 US13/934,580 US201313934580A US2014048259A1 US 20140048259 A1 US20140048259 A1 US 20140048259A1 US 201313934580 A US201313934580 A US 201313934580A US 2014048259 A1 US2014048259 A1 US 2014048259A1
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Prior art keywords
well
wells
hydrocarbons
injecting
fluid
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Abandoned
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US13/934,580
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English (en)
Inventor
Wendell P. Menard
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ConocoPhillips Co
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ConocoPhillips Co
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Priority to US13/934,580 priority Critical patent/US20140048259A1/en
Priority to PCT/US2013/049259 priority patent/WO2014028137A1/fr
Assigned to CONOCOPHILLIPS COMPANY reassignment CONOCOPHILLIPS COMPANY ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: MENARD, WENDELL P.
Publication of US20140048259A1 publication Critical patent/US20140048259A1/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
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/20—Displacing by water

Definitions

  • Embodiments of the invention relate to producing hydrocarbons with multiple horizontal wells through which injection processes precondition and displace the hydrocarbons.
  • Bitumen recovery from oil sands presents technical and economic challenges due to high viscosity of the bitumen at reservoir conditions.
  • Steam assisted gravity drainage provides one process for producing the bitumen from a reservoir.
  • steam introduced into the reservoir through a horizontal injector well transfers heat upon condensation and develops a steam chamber in the reservoir.
  • the bitumen with reduced viscosity due to this heating drains together with steam condensate along a boundary of the steam chamber and is recovered via a producer well placed parallel and beneath the injector well.
  • a method of recovering hydrocarbons includes injecting during a first time a conditioning fluid through first and second wells and into a formation along lateral spaced apart and parallel horizontal lengths of the first and second wells. The method further includes producing the hydrocarbons recovered as backflow along the lengths of the first and second wells during a second time after the first time. Then, injecting the conditioning fluid into the formation along the length of the second well while producing the hydrocarbons along the length of the first well alternates with injecting the conditioning fluid into the formation along the length of the first well while producing the hydrocarbons along the length of the second well, thereby establishing fluid communication between the first and second wells. Next, injecting a displacement fluid into the formation along the length of the first well sweeps the hydrocarbons toward the second well and occurs while producing, along the length of the second well, the hydrocarbons being displaced.
  • a method of recovering hydrocarbons includes injecting a conditioning fluid through first and second wells and into a formation at dispersed locations along parallel horizontal lengths of the first and second wells such that the injecting via the first well is offset in a lateral direction from the second well and aligned between the dispersed locations of the second well across from portions of the second well without fluid communication to the formation.
  • Producing the hydrocarbons recovered as backflow at the dispersed locations along the first and second wells occurs after the injecting of the conditioning fluid.
  • injecting a displacement fluid into the formation via the dispersed locations along the first well sweeps the hydrocarbons toward the second well and occurs while producing, at the dispersed locations along the second well, the hydrocarbons being displaced.
  • FIG. 1 is a schematic of three horizontal wells as viewed transverse to their horizontal length within a reservoir, according to one embodiment of the invention.
  • FIG. 2 is a schematic top view of the wells with dispersed flow control along their length and operated in an all injection cycle as depicted by arrows indicating fluid flow direction, according to one embodiment of the invention.
  • FIG. 3 is a schematic of the wells depicted in an all production cycle subsequent to the all injection cycle, according to one embodiment of the invention.
  • FIG. 4 is a schematic of the wells depicted in a first alternating injection and production cycle subsequent to the all injection and the all production cycles, according to one embodiment of the invention.
  • FIG. 5 is a schematic of the wells depicted in a second alternating injection and production cycle opposite and subsequent to the first alternating injection and production cycle, according to one embodiment of the invention.
  • FIG. 6 is a schematic of the wells depicted in a final displacement operation once fluid communication is established between the wells, according to one embodiment of the invention.
  • FIG. 7 is a schematic of the wells with resulting sweep of the reservoir by the final displacement operation shown by areas within dashed lines, according to one embodiment of the invention.
  • methods and systems produce petroleum products with multiple horizontal wells through which injection processes precondition and displace the hydrocarbons in a formation.
  • the wells extend through the formation spaced apart from one another in a lateral direction.
  • cyclic injections and production of resulting backflow initiates conditioning of immobile products. Alternating between injection and production at adjacent wells may then facilitate establishing the fluid communication.
  • a displacement procedure sweeps the hydrocarbons from one of the wells used for injection toward an adjacent one of the wells used for production.
  • FIG. 1 illustrates a formation 100 defining a hydrocarbon reservoir bounded between a bottom layer 101 and a top layer 102 . While methods disclosed herein are applicable even if the formation 100 is greater than 15 meters, the formation 100 in some embodiments extends in height less than 15 meters, thereby limiting commercial applications of processes such as steam assisted gravity drainage.
  • a first well 111 , a second well 112 and a third well 113 each include horizontal lengths that pass through the formation 100 .
  • all the wells 111 , 112 , 113 in some embodiments align in a common horizontal plane or otherwise have the horizontal length in substantial horizontal alignment with one another.
  • a lateral distance of between 5 and 50 meters may separate the wells 111 , 112 , 113 from one another. Costs of cycling depicted and described with respect to FIGS. 2 and 3 and accompanying revenue may influence duration of such cycling with longer durations enabling wider lateral separation, even greater than 50 meters, between the wells 111 , 112 , 113 .
  • the second well 112 extends between and is adjacent the first well 111 and the third well 113 without any additional intervening wells disposed between any of the wells 111 , 112 , 113 .
  • the horizontal lengths of the wells 111 , 112 , 113 may extend parallel to one another.
  • FIG. 2 shows the wells 111 , 112 , 113 operated in an all injection cycle as depicted by arrows indicating fluid flow direction.
  • the all injection cycle may initiate while the wells 111 , 112 , 113 lack fluid communication with one another across the formation and may be an initial operation of the wells 111 , 112 , 113 .
  • the arrows in the all injection cycle indicate simultaneous injection of a conditioning fluid into the formation along the horizontal lengths of each of the wells 111 , 112 , 113 .
  • flow control devices 200 dispersed along the horizontal lengths of the wells 111 , 112 , 113 facilitate uniform or patterned injection and/or production along the horizontal lengths of the wells 111 , 112 , 113 .
  • the flow control devices 200 provide fluid communication from inside the wells 111 , 112 , 113 to the formation and can include orifices, perforations or slots in tubing or liner, well screen or other tortuous flow path assemblies. Valves or other metering devices may control inflow and/or outflow from the flow control devices 200 .
  • Solid wall lined portions 201 of the horizontal lengths of the wells 111 , 112 , 113 may prevent fluid communication from inside the wells 111 , 112 , 113 to the formation.
  • the lined portions 201 without fluid communication to the formation may separate the flow control devices 200 from one another along the horizontal lengths of the wells 111 , 112 , 113 .
  • the flow control devices 200 of the first well 111 align between the flow control devices 200 of the second well 112 and across from the lined portions 201 of the second well 112 .
  • the flow control devices 200 of the third well 113 may also align across from the flow control devices 200 of the first well 111 .
  • the conditioning fluid as referred to herein and used in the all injection cycle can be any fluid capable of reducing viscosity or increasing mobility of the hydrocarbons by dissolving into the hydrocarbons and/or transferring heat to the hydrocarbons.
  • the conditioning fluid may however not rely on any thermal application and may consist of only a solvent for the hydrocarbons. Economics may not support applying heat to the hydrocarbons with the conditioning fluid due to factors such thickness or extent of the formation.
  • the solvent may be a lighter hydrocarbon than contained in the formation and may have 1 to 20 carbon atoms (C 1 -C 20 ) or 1 to 4 carbon atoms (C 1 -C 4 ) per molecule, or any mixture thereof.
  • C 1 to C 4 hydrocarbon solvents include methane, ethane, propane and/or butane.
  • the hydrocarbon solvent used as the conditioning fluid can be introduced into the formation as a gas or as a liquid regardless of its phase under reservoir conditions.
  • Composition of the conditioning fluid may also transition during any injection operation disclosed herein.
  • the all injection cycle may first utilize a liquid hydrocarbon solvent under reservoir conditions, such as diesel, for the conditioning fluid followed by a gaseous solvent under reservoir conditions, such as a mix of propane and carbon dioxide, for the conditioning fluid.
  • a liquid hydrocarbon solvent under reservoir conditions such as diesel
  • a gaseous solvent under reservoir conditions such as a mix of propane and carbon dioxide
  • FIG. 3 illustrates the wells 111 , 112 , 113 operated in an all production cycle during a subsequent time interval to the all injection cycle shown in FIG. 2 .
  • the arrows in the all production cycle indicate simultaneous recovery of the hydrocarbons along the horizontal lengths of each of the wells 111 , 112 , 113 . Since the wells 111 , 112 , 113 still lack fluid communication with one another, the hydrocarbons can only backflow along with accompanying conditioning fluid to each of the wells 111 , 112 , 113 .
  • the flow control devices 200 permit controlled inflow of the hydrocarbons into the wells 111 , 112 , 113 at where dispersed along the horizontal lengths of the wells 111 , 112 , 113 . Processing the hydrocarbons produced to surface during the all production cycle may separate out the conditioning fluid for recycle. In some embodiments, cycling during additional time intervals between the all injection cycle shown in FIG. 2 and the all production cycle illustrated in FIG. 3 continues for multiple times and facilitates even distribution of the conditioning fluid injected into the formation.
  • FIG. 4 shows the wells 111 , 112 , 113 operated in a first alternating injection and production cycle subsequent to the all injection and the all production cycles.
  • injecting the conditioning fluid through the second well 112 and out the flow control devices 200 along the horizontal length thereof occurs while producing the hydrocarbons recovered through the flow control devices of the first and third wells 111 , 113 .
  • the third well 113 mirrors the first well 111 in function and arrangement and just provides a more complete picture of how further alternating well arrangements, i.e., the first well 111 and the second well 112 , could continue to be disposed across the formation.
  • FIG. 5 illustrates the wells 111 , 112 , 113 operated in a second alternating injection and production cycle opposite and subsequent to the first alternating injection and production cycle. Specifically, injecting the conditioning fluid through the first and third wells 111 , 113 and out the flow control devices 200 along the horizontal lengths thereof occurs while producing the hydrocarbons recovered through the flow control devices of the second well 112 . For some embodiments, cycling during additional time intervals between the alternating injection and production cycles shown in FIGS. 4 and 5 continues for multiple times and facilitates establishing fluid communication between the wells 111 , 112 , 113 .
  • FIG. 6 shows the wells 111 , 112 , 113 operated in a final displacement operation once fluid communication is established between the wells subsequent to operations illustrated in FIGS. 2-5 .
  • the arrows for the displacement operation indicate injection of a displacement fluid through the second well 112 and out the flow control devices 200 along the horizontal length thereof while producing the hydrocarbons recovered through the flow control devices of the first and third wells 111 , 113 . While the second well 112 for explanation purposes is selected for injection in the final displacement operation, direction of the arrows in FIG. 6 may match either FIG. 4 or FIG. 5 .
  • displacement fluid examples include gases or liquids capable of pushing the hydrocarbons through the formation.
  • the displacement fluid may in some embodiments also facilitate recovery by further decreasing viscosity of the hydrocarbons in the formation.
  • the displacement fluid may contain like constituents as the conditioning fluid described herein and which may likewise include any constituent described herein for use as the displacement fluid.
  • the displacement fluid includes any combination of gaseous or liquid solvents for the hydrocarbons, water, steam, emulsifiers (e.g., surfactants, alkalis, polymers), air, oxygen and carbon dioxide. Heating any of the fluids used for the displacement fluid enables heat transfer to the hydrocarbons for viscosity reduction. Injection of combustibles, such as air or oxygen, as the displacement fluid enables starting in situ combustion during the displacement operation for recovery, which depends on the fluid communication being established between the wells 111 , 112 , 113 .
  • gaseous or liquid solvents for the hydrocarbons water, steam, emulsifiers (e.g., surfactants, alkalis, polymers), air, oxygen and carbon dioxide.
  • emulsifiers e.g., surfactants, alkalis, polymers
  • FIG. 7 illustrates the wells 111 , 112 , 113 with resulting sweep of the formation by the displacement operation shown by areas within dashed lines.
  • the displacement operation thus drives the hydrocarbons that are now mobile toward the first and third wells 111 , 113 for recovery.
  • the displacement operation recovers the hydrocarbons not produced during the operations shown in FIGS. 2-5 to gain desired cumulative recovery needed for commercial success.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
US13/934,580 2012-08-15 2013-07-03 Preconditioning for bitumen displacement Abandoned US20140048259A1 (en)

Priority Applications (2)

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US13/934,580 US20140048259A1 (en) 2012-08-15 2013-07-03 Preconditioning for bitumen displacement
PCT/US2013/049259 WO2014028137A1 (fr) 2012-08-15 2013-07-03 Pré-conditionnement pour déplacement de bitume

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US201261683373P 2012-08-15 2012-08-15
US13/934,580 US20140048259A1 (en) 2012-08-15 2013-07-03 Preconditioning for bitumen displacement

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Cited By (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20140345861A1 (en) * 2013-05-22 2014-11-27 Total E&P Canada, Ltd. Fishbone sagd
US20150198022A1 (en) * 2014-01-13 2015-07-16 Conocophillips Company Oil recovery with fishbone wells and steam
US10487636B2 (en) 2017-07-27 2019-11-26 Exxonmobil Upstream Research Company Enhanced methods for recovering viscous hydrocarbons from a subterranean formation as a follow-up to thermal recovery processes
US11002123B2 (en) 2017-08-31 2021-05-11 Exxonmobil Upstream Research Company Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation
US11142681B2 (en) 2017-06-29 2021-10-12 Exxonmobil Upstream Research Company Chasing solvent for enhanced recovery processes
US11261725B2 (en) 2017-10-24 2022-03-01 Exxonmobil Upstream Research Company Systems and methods for estimating and controlling liquid level using periodic shut-ins

Families Citing this family (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9163491B2 (en) 2011-10-21 2015-10-20 Nexen Energy Ulc Steam assisted gravity drainage processes with the addition of oxygen
WO2013173904A1 (fr) 2012-05-15 2013-11-28 Nexen Energy Ulc Géométrie sagdox pour réservoirs de bitume altérés

Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4850429A (en) * 1987-12-21 1989-07-25 Texaco Inc. Recovering hydrocarbons with a triangular horizontal well pattern
US20070181299A1 (en) * 2005-01-26 2007-08-09 Nexen Inc. Methods of Improving Heavy Oil Production

Family Cites Families (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4844158A (en) * 1988-12-08 1989-07-04 Mobil Oil Corp. Solvent stimulation of viscous oil via a horizontal wellbore
US8091636B2 (en) * 2008-04-30 2012-01-10 World Energy Systems Incorporated Method for increasing the recovery of hydrocarbons
US9739123B2 (en) * 2011-03-29 2017-08-22 Conocophillips Company Dual injection points in SAGD

Patent Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4850429A (en) * 1987-12-21 1989-07-25 Texaco Inc. Recovering hydrocarbons with a triangular horizontal well pattern
US20070181299A1 (en) * 2005-01-26 2007-08-09 Nexen Inc. Methods of Improving Heavy Oil Production

Cited By (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20140345861A1 (en) * 2013-05-22 2014-11-27 Total E&P Canada, Ltd. Fishbone sagd
US10436000B2 (en) * 2013-05-22 2019-10-08 Conocophillips Resources Corp. Fishbone well configuration for SAGD
US20150198022A1 (en) * 2014-01-13 2015-07-16 Conocophillips Company Oil recovery with fishbone wells and steam
US10385666B2 (en) * 2014-01-13 2019-08-20 Conocophillips Company Oil recovery with fishbone wells and steam
US11142681B2 (en) 2017-06-29 2021-10-12 Exxonmobil Upstream Research Company Chasing solvent for enhanced recovery processes
US10487636B2 (en) 2017-07-27 2019-11-26 Exxonmobil Upstream Research Company Enhanced methods for recovering viscous hydrocarbons from a subterranean formation as a follow-up to thermal recovery processes
US11002123B2 (en) 2017-08-31 2021-05-11 Exxonmobil Upstream Research Company Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation
US11261725B2 (en) 2017-10-24 2022-03-01 Exxonmobil Upstream Research Company Systems and methods for estimating and controlling liquid level using periodic shut-ins

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Owner name: CONOCOPHILLIPS COMPANY, TEXAS

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:MENARD, WENDELL P.;REEL/FRAME:030735/0101

Effective date: 20130207

STCB Information on status: application discontinuation

Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION