WO2014028137A1 - Pré-conditionnement pour déplacement de bitume - Google Patents
Pré-conditionnement pour déplacement de bitume Download PDFInfo
- Publication number
- WO2014028137A1 WO2014028137A1 PCT/US2013/049259 US2013049259W WO2014028137A1 WO 2014028137 A1 WO2014028137 A1 WO 2014028137A1 US 2013049259 W US2013049259 W US 2013049259W WO 2014028137 A1 WO2014028137 A1 WO 2014028137A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- well
- wells
- hydrocarbons
- injecting
- fluid
- Prior art date
Links
- 238000006073 displacement reaction Methods 0.000 title claims abstract description 32
- 239000010426 asphalt Substances 0.000 title description 11
- 239000012530 fluid Substances 0.000 claims abstract description 80
- 229930195733 hydrocarbon Natural products 0.000 claims abstract description 64
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract description 64
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 40
- 230000003750 conditioning effect Effects 0.000 claims abstract description 39
- 238000002347 injection Methods 0.000 claims abstract description 36
- 239000007924 injection Substances 0.000 claims abstract description 36
- 238000000034 method Methods 0.000 claims abstract description 36
- 238000004519 manufacturing process Methods 0.000 claims abstract description 23
- 238000004891 communication Methods 0.000 claims abstract description 21
- 239000002904 solvent Substances 0.000 claims description 14
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims description 8
- 239000007788 liquid Substances 0.000 claims description 7
- 239000004215 Carbon black (E152) Substances 0.000 claims description 6
- 230000001351 cycling effect Effects 0.000 claims description 6
- 239000000470 constituent Substances 0.000 claims description 5
- 239000003570 air Substances 0.000 claims description 4
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 claims description 4
- 229910002092 carbon dioxide Inorganic materials 0.000 claims description 4
- 239000001569 carbon dioxide Substances 0.000 claims description 4
- 239000001301 oxygen Substances 0.000 claims description 4
- 229910052760 oxygen Inorganic materials 0.000 claims description 4
- 125000004432 carbon atom Chemical group C* 0.000 claims description 3
- 239000003995 emulsifying agent Substances 0.000 claims description 3
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 3
- 230000000977 initiatory effect Effects 0.000 claims 1
- 230000008569 process Effects 0.000 abstract description 7
- 125000004122 cyclic group Chemical group 0.000 abstract description 3
- 239000003209 petroleum derivative Substances 0.000 abstract description 2
- 238000011084 recovery Methods 0.000 description 8
- ATUOYWHBWRKTHZ-UHFFFAOYSA-N Propane Chemical compound CCC ATUOYWHBWRKTHZ-UHFFFAOYSA-N 0.000 description 6
- 238000010796 Steam-assisted gravity drainage Methods 0.000 description 5
- 239000007789 gas Substances 0.000 description 3
- 239000000203 mixture Substances 0.000 description 3
- 239000001294 propane Substances 0.000 description 3
- 230000008901 benefit Effects 0.000 description 2
- 238000010438 heat treatment Methods 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 238000012546 transfer Methods 0.000 description 2
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 description 1
- 230000004075 alteration Effects 0.000 description 1
- 230000000712 assembly Effects 0.000 description 1
- 238000000429 assembly Methods 0.000 description 1
- 230000004888 barrier function Effects 0.000 description 1
- 239000001273 butane Substances 0.000 description 1
- 238000002485 combustion reaction Methods 0.000 description 1
- 238000009833 condensation Methods 0.000 description 1
- 230000005494 condensation Effects 0.000 description 1
- 230000001186 cumulative effect Effects 0.000 description 1
- 230000003247 decreasing effect Effects 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 238000011549 displacement method Methods 0.000 description 1
- 238000011065 in-situ storage Methods 0.000 description 1
- IJDNQMDRQITEOD-UHFFFAOYSA-N n-butane Chemical compound CCCC IJDNQMDRQITEOD-UHFFFAOYSA-N 0.000 description 1
- OFBQJSOFQDEBGM-UHFFFAOYSA-N n-pentane Natural products CCCCC OFBQJSOFQDEBGM-UHFFFAOYSA-N 0.000 description 1
- 229920000642 polymer Polymers 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
- 239000004094 surface-active agent Substances 0.000 description 1
- 230000007704 transition Effects 0.000 description 1
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
- E21B43/16—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.
- SAGD Steam assisted gravity drainage
- 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.
- Figure 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.
- Figure 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.
- Figure 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.
- Figure 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.
- Figure 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.
- Figure 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.
- Figure 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.
- Figure 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 Figures 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. As visible in Figures 2-7, the horizontal lengths of the wells 111, 112, 113 may extend parallel to one another.
- Figure 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 -C4) per molecule, or any mixture thereof.
- Ci 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
- Figure 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 Figure 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 backfiow 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
- Processing the hydrocarbons produced to surface during the all production cycle may separate out the conditioning fluid for recycle.
- cycling during additional time intervals between the all injection cycle shown in Figure 2 and the all production cycle illustrated in Figure 3 continues for multiple times and facilitates even distribution of the conditioning fluid injected into the formation.
- Figure 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
- Figure 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 Figures 4 and 5 continues for multiple times and facilitates establishing fluid communication between the wells 111, 112, 113.
- Figure 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 Figures 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 Figure 6 may match either Figure 4 or Figure 5.
- Examples of the displacement fluid 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. [0034] Figure 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 Figures 2-5 to gain desired cumulative recovery needed for commercial success.
- gaseous or liquid solvents for the hydrocarbons water, steam, emulsifiers
Landscapes
- 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)
Abstract
L'invention porte sur des procédés et des systèmes pour produire des produits pétroliers à l'aide de multiples puits horizontaux par lesquels les procédés d'injection pré-conditionnent et déplacent les hydrocarbures présents dans une formation. Les puits s'étendent à travers la formation espacée les uns des autres dans une direction latérale. Avant qu'une communication fluidique soit établie entre les puits, des injections et productions de reflux résultant cycliques amorcent le conditionnement de produits immobiles. L'alternance entre l'injection et la production au niveau de puits adjacents peut ensuite faciliter l'établissement de la communication fluidique. Après que la communication fluidique est établie, une opération de déplacement balaye les hydrocarbures de l'un des puits utilisé pour l'injection vers l'un des puits adjacent utilisé pour la production.
Applications Claiming Priority (4)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US201261683373P | 2012-08-15 | 2012-08-15 | |
US61/683,373 | 2012-08-15 | ||
US13/934,580 US20140048259A1 (en) | 2012-08-15 | 2013-07-03 | Preconditioning for bitumen displacement |
US13/934,580 | 2013-07-03 |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2014028137A1 true WO2014028137A1 (fr) | 2014-02-20 |
Family
ID=50099245
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2013/049259 WO2014028137A1 (fr) | 2012-08-15 | 2013-07-03 | Pré-conditionnement pour déplacement de bitume |
Country Status (2)
Country | Link |
---|---|
US (1) | US20140048259A1 (fr) |
WO (1) | WO2014028137A1 (fr) |
Cited By (2)
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 |
US9803456B2 (en) | 2011-07-13 | 2017-10-31 | Nexen Energy Ulc | SAGDOX geometry for impaired bitumen reservoirs |
Families Citing this family (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2014189555A1 (fr) * | 2013-05-22 | 2014-11-27 | Total E&P Canada, Ltd. | Sagd en arêtes de poisson |
CA2877640C (fr) * | 2014-01-13 | 2021-12-14 | John A. Stanecki | Extraction de petrole au moyen de puits en arete et de vapeur |
CA2972203C (fr) | 2017-06-29 | 2018-07-17 | Exxonmobil Upstream Research Company | Solvant de chasse destine aux procedes ameliores de recuperation |
CA2974712C (fr) | 2017-07-27 | 2018-09-25 | Imperial Oil Resources Limited | Methodes ameliorees de recuperation d'hydrocarbures visqueux d'une formation souterraine comme etape qui suit des procedes de recuperation thermique |
CA2978157C (fr) | 2017-08-31 | 2018-10-16 | Exxonmobil Upstream Research Company | Methodes de recuperation thermique servant a recuperer des hydrocarbures visqueux d'une formation souterraine |
CA2983541C (fr) | 2017-10-24 | 2019-01-22 | Exxonmobil Upstream Research Company | Systemes et methodes de surveillance et controle dynamiques de niveau de liquide |
Citations (4)
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 |
US4850429A (en) * | 1987-12-21 | 1989-07-25 | Texaco Inc. | Recovering hydrocarbons with a triangular horizontal well pattern |
US8091636B2 (en) * | 2008-04-30 | 2012-01-10 | World Energy Systems Incorporated | Method for increasing the recovery of hydrocarbons |
US20120247760A1 (en) * | 2011-03-29 | 2012-10-04 | Conocophillips Company | Dual injection points in sagd |
Family Cites Families (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CA2494391C (fr) * | 2005-01-26 | 2010-06-29 | Nexen, Inc. | Methodes d'amelioration de la production du petrole brut |
-
2013
- 2013-07-03 US US13/934,580 patent/US20140048259A1/en not_active Abandoned
- 2013-07-03 WO PCT/US2013/049259 patent/WO2014028137A1/fr active Application Filing
Patent Citations (4)
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 |
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 |
US20120247760A1 (en) * | 2011-03-29 | 2012-10-04 | Conocophillips Company | Dual injection points in sagd |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US9803456B2 (en) | 2011-07-13 | 2017-10-31 | Nexen Energy Ulc | SAGDOX geometry for impaired bitumen reservoirs |
US9163491B2 (en) | 2011-10-21 | 2015-10-20 | Nexen Energy Ulc | Steam assisted gravity drainage processes with the addition of oxygen |
Also Published As
Publication number | Publication date |
---|---|
US20140048259A1 (en) | 2014-02-20 |
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