EP2431567A2 - Procédés de production d'huile et/ou de gaz - Google Patents

Procédés de production d'huile et/ou de gaz Download PDF

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Publication number
EP2431567A2
EP2431567A2 EP11181541A EP11181541A EP2431567A2 EP 2431567 A2 EP2431567 A2 EP 2431567A2 EP 11181541 A EP11181541 A EP 11181541A EP 11181541 A EP11181541 A EP 11181541A EP 2431567 A2 EP2431567 A2 EP 2431567A2
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EP
European Patent Office
Prior art keywords
well
gas
formation
oil
oil recovery
Prior art date
Legal status (The legal status 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 status listed.)
Withdrawn
Application number
EP11181541A
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German (de)
English (en)
Other versions
EP2431567A3 (fr
Inventor
Rouhollah Frajzadeh
Leonardus Bartholomeus Maria Wassing
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Shell Internationale Research Maatschappij BV
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Shell Internationale Research Maatschappij BV
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Publication date
Application filed by Shell Internationale Research Maatschappij BV filed Critical Shell Internationale Research Maatschappij BV
Publication of EP2431567A2 publication Critical patent/EP2431567A2/fr
Publication of EP2431567A3 publication Critical patent/EP2431567A3/fr
Withdrawn legal-status Critical Current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
    • E21B43/166—Injecting a gaseous medium; Injecting a gaseous medium and a liquid medium
    • E21B43/168—Injecting a gaseous medium

Definitions

  • the present disclosure relates to methods for producing oil and/or gas.
  • EOR Enhanced Oil Recovery
  • thermal thermal
  • chemical/polymer chemical/polymer
  • gas injection gas injection
  • Thermal enhanced recovery works by adding heat to the reservoir.
  • the most widely practiced form is a steam-drive, which reduces oil viscosity so that it can flow to the producing wells.
  • Chemical flooding increases recovery by reducing the capillary forces that trap residual oil.
  • Polymer flooding improves the sweep efficiency of injected water.
  • Miscible injection works in a similar way to chemical flooding. By injecting a fluid that is miscible with the oil, trapped residual oil can be recovered.
  • System 100 includes underground formation 102, underground formation 104, underground formation 106, and underground formation 108.
  • Production facility 110 is provided at the surface.
  • Well 112 traverses formations 102 and 104, and terminates in formation 106.
  • the portion of formation 106 is shown at 114.
  • Oil and gas are produced from formation 106 through well 112, to production facility 110.
  • Gas and liquid are separated from each other, gas is stored in gas storage 116 and liquid is stored in liquid storage 118.
  • PCT Patent Application WO 2010/40202 discloses a Steam-Over-Solvent Injection in Fractured Reservoirs (SOS-FR) carried out by treating a fractured hydrocarbon bearing formation penetrated by a well with a first phase of injecting a formation compatible aqueous fluid into the fractured hydrocarbon bearing formation through the well, a second phase of injecting a hydrocarbon solvent into the fractured hydrocarbon bearing formation through the well and at least a third phase of repeating the first phase after the second phase.
  • SOS-FR Steam-Over-Solvent Injection in Fractured Reservoirs
  • U.S. Patent Application Publication 2009/0260809 discloses methods of generating subsurface heat for treatment of a hydrocarbon containing formation. Methods include providing steam to at least a portion of a hydrocarbon containing formation from a plurality of locations in a wellbore. The steam is hotter than a temperature of the portion. The steam is heated in the wellbore by combusting a stream comprising hydrogen sulfide in the wellbore. Heat from the combustion transfers to the steam. The steam provided the portion at a first location in the wellbore is hotter than steam provided at a second location in the wellbore along the length of the wellbore, where the first location is further from a surface of the formation than the second location along the length of the wellbore.
  • U.S. Patent Application Publication 2009/0260809 is herein incorporated by reference in its entirety.
  • U.S. Patent Application Publication 2009/0056941 discloses method for producing oil and/or gas comprising a method for producing oil from an underground formation comprising injecting an enhanced oil recovery formulation and a gas into a first well in the formation; forming a mixture comprising the enhanced oil recovery formulation and the oil in the formation; forming a gas cap with the injected gas; forcing the formulation and oil mixture towards a second well in the formation; and producing the formulation and oil mixture from the second well.
  • U.S. Patent Application Publication 2009/0056941 is herein incorporated by reference in its entirety.
  • U.S. Patent 4,232,741 discloses that portions of a subterranean reservoir are temporarily plugged by injecting an aqueous liquid solution which contains nitrogen gas-generating reactants, a foaming surfactant and a pH controlling system arranged so that the solution remains relatively unreactive within the well but forms a relatively immobile foam within the pores or other openings within the reservoir formation.
  • U.S. Patent 4,232,741 is herein incorporated by reference in its entirety.
  • the invention provides a method for producing oil from an underground formation comprising injecting an enhanced oil recovery formulation into a first well in the formation, the enhanced oil recovery formulation comprising a foam; floating the foam on top of the oil, in order to force the oil towards a second well in the formation; and producing the oil and/or gas from the second well.
  • Array 200 includes well group 202 (denoted by horizontal lines) and well group 204 (denoted by diagonal lines).
  • Each well in well group 202 has horizontal distance 230 from the adjacent well in well group 202.
  • Each well in well group 202 has vertical distance 232 from the adjacent well in well group 202.
  • Each well in well group 204 has horizontal distance 236 from the adjacent well in well group 204.
  • Each well in well group 204 has vertical distance 238 from the adjacent well in well group 204.
  • Each well in well group 202 is distance 234 from the adjacent wells in well group 204.
  • Each well in well group 204 is distance 234 from the adjacent wells in well group 202.
  • each well in well group 202 is surrounded by four wells in well group 204. In some embodiments, each well in well group 204 is surrounded by four wells in well group 202.
  • horizontal distance 230 is from about 5 to about 1000 meters, or from about 10 to about 500 meters, or from about 20 to about 250 meters, or from about 30 to about 200 meters, or from about 50 to about 150 meters, or from about 90 to about 120 meters, or about 100 meters.
  • vertical distance 232 is from about 5 to about 1000 meters, or from about 10 to about 500 meters, or from about 20 to about 250 meters, or from about 30 to about 200 meters, or from about 50 to about 150 meters, or from about 90 to about 120 meters, or about 100 meters.
  • horizontal distance 236 is from about 5 to about 1000 meters, or from about 10 to about 500 meters, or from about 20 to about 250 meters, or from about 30 to about 200 meters, or from about 50 to about 150 meters, or from about 90 to about 120 meters, or about 100 meters.
  • vertical distance 238 is from about 5 to about 1000 meters, or from about 10 to about 500 meters, or from about 20 to about 250 meters, or from about 30 to about 200 meters, or from about 50 to about 150 meters, or from about 90 to about 120 meters, or about 100 meters.
  • distance 234 is from about 5 to about 1000 meters, or from about 10 to about 500 meters, or from about 20 to about 250 meters, or from about 30 to about 200 meters, or from about 50 to about 150 meters, or from about 90 to about 120 meters, or about 100 meters.
  • array of wells 200 may have from about 10 to about 1000 wells, for example from about 5 to about 500 wells in well group 202, and from about 5 to about 500 wells in well group 204.
  • array of wells 200 is seen as a top view with well group 202 and well group 204 being vertical wells spaced on a piece of land. In some embodiments, array of wells 200 is seen as a cross-sectional side view with well group 202 and well group 204 being horizontal wells spaced within a formation.
  • the recovery of oil and/or gas with array of wells 200 from an underground formation may be accomplished by any known method. Suitable methods include subsea production, surface production, primary, secondary, or tertiary production. The selection of the method used to recover the oil and/or gas from the underground formation is not critical.
  • oil and/or gas may be recovered from a formation into a well, and flow through the well and flowline to a facility.
  • enhanced oil recovery with the use of an agent for example steam, water, a surfactant, a gas, a foam, a polymer flood, and/or a miscible agent, may be used to increase the flow of oil and/or gas from the formation.
  • an enhanced oil recovery agent is injected into well group 202, and oil is recovered from well group 204.
  • well group 202 may be used for injecting a enhanced oil recovery agent, and well group 204 may be used for producing oil and/or gas from the formation for a first time period; then well group 204 may be used for injecting a enhanced oil recovery agent, and well group 202 may be used for producing oil and/or gas from the formation for a second time period, where the first and second time periods comprise a cycle.
  • multiple cycles may be conducted which include alternating well groups 202 and 204 between injecting a enhanced oil recovery agent, and producing oil and/or gas from the formation, where one well group is injecting and the other is producing for a first time period, and then they are switched for a second time period.
  • a cycle may be from about 12 hours to about 1 year, or from about 3 days to about 6 months, or from about 5 days to about 3 months.
  • oil as present in the formation prior to the injection of any enhanced oil recovery agents has a viscosity of at least about 100 centipoise, or at least about 500 centipoise, or at least about 1000 centipoise, or at least about 2000 centipoise, or at least about 5000 centipoise, or at least about 10,000 centipoise. In some embodiments, oil as present in the formation prior to the injection of any enhanced oil recovery agents has a viscosity of up to about 5,000,000 centipoise, or up to about 2,000,000 centipoise, or up to about 1,000,000 centipoise, or up to about 500,000 centipoise.
  • Releasing at least a portion of the enhanced oil recovery agent and/or other liquids and/or gases may be accomplished by any known method.
  • One suitable method is injecting the enhanced oil recovery formulation into a single conduit in a single well, allowing the formulation to soak, and then pumping out at least a portion of the the formulation with gas and/or liquids.
  • Another suitable method is injecting the enhanced oil recovery formulation into a first well, and pumping out at least a portion of the enhanced oil recovery formulation with gas and/or liquids through a second well.
  • the selection of the method used to inject at least a portion of the enhanced oil recovery formulation and/or other liquids and/or gases is not critical.
  • the enhanced oil recovery formulation and/or other liquids and/or gases may be pumped into a formation at a pressure up to the fracture pressure of the formation.
  • System 400 includes underground formation 402, formation 404, formation 406, and formation 408.
  • Production facility 410 is provided at the surface.
  • Well 412 traverses formation 402 and 404 has openings at formation 406. Portions of formation 414 may be optionally fractured and/or perforated.
  • Gas and liquid may be separated, and gas may be sent to gas storage 416, and liquid may be sent to liquid storage 418.
  • Production facility 410 is able to produce and/or store enhanced oil recovery formulation, which may be produced and stored in production / storage 430.
  • Enhanced oil recovery formulation is pumped down well 432, to portions 434 of formation 406.
  • Enhanced oil recovery formulation traverses formation 406 to aid in the production of oil and gas, and then the enhanced oil recovery formulation, oil and/or gas may all be produced to well 412, to production facility 410.
  • Enhanced oil recovery formulation may then be recycled, by re-injecting the formulation into well 432.
  • a quantity of enhanced oil recovery formulation or enhanced oil recovery formulation mixed with other components may be injected into well 432, followed by another component to force enhanced oil recovery formulation or enhanced oil recovery formulation mixed with other components across formation 406, for example air; water in gas or liquid form; carbon dioxide; nitrogen; water mixed with one or more salts, polymers, and/or surfactants; carbon dioxide; other gases; other liquids; and/or mixtures thereof.
  • well 412 which is producing oil and/or gas is representative of a well in well group 202
  • well 432 which is being used to inject enhanced oil recovery formulation is representative of a well in well group 204.
  • well 412 which is producing oil and/or gas is representative of a well in well group 204
  • well 432 which is being used to inject enhanced oil recovery formulation is representative of a well in well group 202.
  • System 500 includes underground formation 502, formation 504, formation 506, and formation 508.
  • Production facility 510 is provided at the surface.
  • Well 512 traverses formation 502 and 504 has openings at formation 506.
  • Gas and/or a gas containing foam may be injected into and then trapped in the upper portions of formation 506, which may include dome structure 514, for example since the gas is floating on a denser oil in the formation.
  • Gas and liquid may be separated, and gas may be sent to gas storage 516, and liquid may be sent to liquid storage 518.
  • Production facility 510 is able to produce and/or store enhanced oil recovery formulation, which may be produced and stored in production / storage 530.
  • Enhanced oil recovery formulation is pumped down well 512, to portions 514 of formation 506.
  • Enhanced oil recovery formulation is lighter than the oil and/or gas in formation 506, and due to the buoyancy of the oil recovery formulation, oil and/or gas is trapped in the lower portions 534 of formation 506.
  • Enhanced oil recovery formulation traverses formation 506 to aid in the production of oil and gas, and then the oil and/or gas in formation 506 and enhanced oil recovery formulation may all be produced to well 532, to production facility 510.
  • Enhanced oil recovery formulation may then be recycled, by re-injecting the formulation into well 512.
  • enhanced oil recovery formulation includes gas, gas mixed with water and a surfactant to form a foam, or other light gases or liquids, for example natural gas, methane, carbon dioxide and/or nitrogen.
  • well 532 which is producing oil and/or gas is representative of a well in well group 202
  • well 512 which is being used to inject enhanced oil recovery formulation is representative of a well in well group 204.
  • well 532 which is producing oil and/or gas is representative of a well in well group 204
  • well 512 which is being used to inject enhanced oil recovery formulation is representative of a well in well group 202.
  • System 600 includes underground formation 602, formation 604, formation 606, and formation 608.
  • Production facility 610 is provided at the surface.
  • Well 612 traverses formation 602 and 604 has openings at formation 606.
  • the oil and/or gas may be trapped in the upper portions of formation 606, which may include dome structure 614, for example since the oil and/or gas is floating on a denser enhanced oil recovery formulation.
  • Gas and liquid may be separated, and gas may be sent to gas storage 616, and liquid may be sent to liquid storage 618.
  • Production facility 610 is able to produce and/or store enhanced oil recovery formulation, which may be produced and stored in production / storage 630.
  • Enhanced oil recovery formulation is pumped down well 632, to portions 634 of formation 606.
  • Enhanced oil recovery formulation is denser than the oil and/or gas in dome 614, and causes a buoyancy for oil and/or gas to trap it in the upper portions of formation 606, including dome 614.
  • Enhanced oil recovery formulation traverses formation 606 to aid in the production of oil and gas, and then the enhanced oil recovery formulation may all be produced to well 612, to production facility 610.
  • Enhanced oil recovery formulation may then be recycled, by re-injecting the formulation into well 632.
  • enhanced oil recovery formulation includes water, water with additives such as polymers, alkalis, and/or surfactants, or other dense liquids, for example carbon disulfide or carbon disulfide formulations.
  • well 612 which is producing oil and/or gas is representative of a well in well group 202
  • well 632 which is being used to inject enhanced oil recovery formulation is representative of a well in well group 204.
  • well 612 which is producing oil and/or gas is representative of a well in well group 204
  • well 632 which is being used to inject enhanced oil recovery formulation is representative of a well in well group 202.
  • System 700 includes underground formation 702, formation 704, formation 706, and formation 708.
  • Production facility 710 is provided at the surface.
  • Well 712 traverses formation 702 and 704 has openings at formation 706.
  • Portions of formation 706 form dome 714, which may trap liquids and/or gases.
  • Formation 706 has fractures, karsts, and/or vugs 707 which provide a low resistance fluid path from well 712 to well 732, and vice versa.
  • Gas and liquid may be separated, and gas may be sent to gas processing / storage 716, and liquid may be sent to liquid processing / storage 718.
  • Production facility 710 is able to produce and/or store enhanced oil recovery formulation, which may be produced and stored in production / storage 730.
  • a first enhanced oil recovery formulation is pumped down well 712, to portions 734 of formation 706.
  • Enhanced oil recovery formulation traverses formation 706 to aid in the production of oil and/or gas from fractures, karsts, and/or vugs 707, and then the enhanced oil recovery formulation and oil and/or gas may all be produced to well 732, to production facility 710.
  • Enhanced oil recovery formulation may then be recycled, for example by re-injecting the formulation into well 712.
  • a second enhanced oil recovery formulation which is denser than oil and/or gas in formation 706 is injected at the bottom of well 712, near the interface of formations 706 and 708.
  • the enhanced oil recovery formulation injection rate may be adjusted to be near the imbibition rate of the formulation into the matrix surrounding the fractures, karsts, and/or vugs 707.
  • the formulation and oil and/or gas are produced from a middle portion of well 712 in between the first enhanced oil recovery formulation with a low density and the second enhanced oil recovery formulation with a high density. Since oil and/or gas is denser than the first enhanced oil recovery formulation, the oil and/or gas sinks below the first enhanced oil recovery formulation. In addition, since oil and/or gas is lighter than the second enhanced oil recovery formulation, the oil and/or gas floats above the second enhanced oil recovery formulation
  • a first enhanced oil recovery formulation which is less dense than oil and/or gas in formation 706 is injected at the top portion of well 712 in dome 714, near the interface of formations 706 and 704.
  • the enhanced oil recovery formulation injection rate may be adjusted to be near the imbibition rate of the formulation into the matrix surrounding the fractures, karsts, and/or vugs 707.
  • the formulation and oil and/or gas are produced from a bottom of well 732, near the interface of formations 706 and 708. Since oil and/or gas is less dense than formulation, formulation causes the oil and/or gas to sink. Oil and/or gas naturally sinks below formulation from upper elevation near injection at well 712, to lower elevation production at well 732.
  • well 732 which is producing oil and/or gas is representative of a well in well group 202
  • well 712 which is being used to inject enhanced oil recovery formulation is representative of a well in well group 204
  • well 732 which is producing oil and/or gas is representative of a well in well group 204
  • well 712 which is being used to inject enhanced oil recovery formulation is representative of a well in well group 202.
  • oil and/or gas produced may be transported to a refinery and/or a treatment facility.
  • the oil and/or gas may be processed to produced to produce commercial products such as transportation fuels such as gasoline and diesel, heating fuel, lubricants, chemicals, and/or polymers.
  • Processing may include distilling and/or fractionally distilling the oil and/or gas to produce one or more distillate fractions.
  • the oil and/or gas, and/or the one or more distillate fractions may be subjected to a process of one or more of the following: catalytic cracking, hydrocracking, hydrotreating, coking, thermal cracking, distilling, reforming, polymerization, isomerization, alkylation, blending, and dewaxing.
  • a method for producing oil from an underground formation comprising injecting an enhanced oil recovery formulation into a first well in the formation, the enhanced oil recovery formulation comprising a foam; floating the foam on top of the oil, in order to force the oil towards a second well in the formation; and producing the oil and/or gas from the second well.
  • the first well further comprises a first array of wells
  • the second well further comprises a second array of wells, wherein a well in the first array of wells is at a distance of 10 meters to 1 kilometer from one or more adjacent wells in the second array of wells.
  • the underground formation is beneath a body of water.
  • the foam is injected into one or more fractures in the formation.
  • the method also includes injecting a second enhanced oil recovery formulation into the formation, the second enhanced oil recovery formulation being denser than the oil, further comprising floating the oil on the second enhanced oil recovery formulation.
  • the first array of wells comprises from 5 to 500 wells
  • the second array of wells comprises from 5 to 500 wells.
  • the enhanced oil recovery formulation comprises gas and a surfactant.
  • the enhanced oil recovery formulation comprises a gas selected from nitrogen, carbon dioxide, natural gas, and other hydrocarbon gases having from one to four carbon atoms.
  • the second enhanced oil recovery formulation comprises a carbon disulfide formulation.
  • the underground formation comprises a oil having a viscosity from 100 to 5,000,000 centipoise.
  • the enhanced oil recovery formulation is less dense than the oil.
  • the oil floats on the enhanced oil recovery formulation.

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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)
  • Lubricants (AREA)
  • Manufacture Of Porous Articles, And Recovery And Treatment Of Waste Products (AREA)
EP11181541A 2010-09-17 2011-09-16 Procédés de production d'huile et/ou de gaz Withdrawn EP2431567A3 (fr)

Applications Claiming Priority (1)

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US38412110P 2010-09-17 2010-09-17

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EP2431567A2 true EP2431567A2 (fr) 2012-03-21
EP2431567A3 EP2431567A3 (fr) 2012-04-04

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Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10012064B2 (en) 2015-04-09 2018-07-03 Highlands Natural Resources, Plc Gas diverter for well and reservoir stimulation
US10344204B2 (en) 2015-04-09 2019-07-09 Diversion Technologies, LLC Gas diverter for well and reservoir stimulation
US10982520B2 (en) 2016-04-27 2021-04-20 Highland Natural Resources, PLC Gas diverter for well and reservoir stimulation

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MX2015014231A (es) * 2013-04-12 2016-10-14 Schlumberger Technology Bv Recuperacion mejorada de petroleo usando muestra digital de nucleo.
US11913302B2 (en) * 2021-11-30 2024-02-27 Halliburton Energy Services, Inc. Gas hydrate well control

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Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10012064B2 (en) 2015-04-09 2018-07-03 Highlands Natural Resources, Plc Gas diverter for well and reservoir stimulation
US10344204B2 (en) 2015-04-09 2019-07-09 Diversion Technologies, LLC Gas diverter for well and reservoir stimulation
US10385257B2 (en) 2015-04-09 2019-08-20 Highands Natural Resources, PLC Gas diverter for well and reservoir stimulation
US10385258B2 (en) 2015-04-09 2019-08-20 Highlands Natural Resources, Plc Gas diverter for well and reservoir stimulation
US10982520B2 (en) 2016-04-27 2021-04-20 Highland Natural Resources, PLC Gas diverter for well and reservoir stimulation

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Publication number Publication date
US20120067571A1 (en) 2012-03-22
EP2431567A3 (fr) 2012-04-04

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