US20130112408A1 - Ported packer - Google Patents

Ported packer Download PDF

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Publication number
US20130112408A1
US20130112408A1 US13/671,391 US201213671391A US2013112408A1 US 20130112408 A1 US20130112408 A1 US 20130112408A1 US 201213671391 A US201213671391 A US 201213671391A US 2013112408 A1 US2013112408 A1 US 2013112408A1
Authority
US
United States
Prior art keywords
packer
well
well casing
tubing string
ports
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.)
Abandoned
Application number
US13/671,391
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English (en)
Inventor
John A Oxtoby
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.)
Imperial Oil Resources Ltd
ExxonMobil Upstream Research Co
Original Assignee
Imperial Oil Resources Ltd
ExxonMobil Upstream Research Co
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Imperial Oil Resources Ltd, ExxonMobil Upstream Research Co filed Critical Imperial Oil Resources Ltd
Publication of US20130112408A1 publication Critical patent/US20130112408A1/en
Assigned to IMPERIAL OIL RESOURCES LIMITED reassignment IMPERIAL OIL RESOURCES LIMITED ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: OXTOBY, JOHN A.
Assigned to EXXONMOBIL UPSTREAM RESEARCH COMPANY reassignment EXXONMOBIL UPSTREAM RESEARCH COMPANY ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: IMPERIAL OIL RESOURCES LIMITED
Abandoned legal-status Critical Current

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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
    • E21B47/00—Survey of boreholes or wells
    • 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
    • E21B47/00—Survey of boreholes or wells
    • E21B47/06—Measuring temperature or pressure
    • 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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs

Definitions

  • the present disclosure relates generally to the field of well completions for use in the recovery of in situ hydrocarbons from a subterranean reservoir.
  • Viscous oil such as heavy oil or bitumen, residing in reservoirs that are too deep for commercial mining may be recovered by in situ processes.
  • viscous oil is produced from subterranean reservoirs using in situ recovery processes that reduce the viscosity of the oil enabling it to flow to the wells; otherwise, an economic production rate would not be possible.
  • in situ viscous oil recovery processes the temperature or pressure is modified or a solvent is added to reduce the viscosity or otherwise enhance the flow of the viscous oil within the reservoir.
  • SAGD Steam Assisted Gravity Drainage
  • a dedicated injection well and a dedicated production well are used.
  • the SAGD process involves injecting steam into the formation through an injection well or wells at a rate which forms a steam chamber and maintains a near constant operating pressure in the steam chamber. Steam at the edges of the steam chamber condenses as it heats the adjacent non-depleted formation. The mobilized oil and steam condensate flow via gravity to a separate production well located at the base of the steam chamber.
  • An example SAGD is described in U.S. Pat. No. 4,344,485 (Butler).
  • CSS Cyclic Steam Stimulation
  • cycles of steam injection, soak, and oil production are employed. Once the production rate falls to a given level, the well is put through another cycle of injection, soak, and production.
  • An example of CSS is described in U.S. Pat. No. 4,280,559 (Best).
  • Steam Flood involves injecting steam into the formation through an injection well to provide stream drive. Steam moves through the formation, mobilizing oil as it flows toward the production well. Mobilized oil is swept to the production well by the steam drive.
  • An example of steam flooding is described in U.S. Pat. No. 3,705,625 (Whitten).
  • SA-SAGD Solvent-Assisted Steam Assisted Gravity Drainage
  • VAPEX Vapour Extraction
  • LASER Liquid Addition to Steam for Enhanced Recovery
  • SAVEX combined Steam and Vapour Extraction Process
  • Completing a well typically includes casing the well, which means inserting a casing into a drilled section of the borehole.
  • the casing is typically held in place by cement.
  • Completion also typically includes inserting a tubing string within the casing, in the injection or production section of the well.
  • the tubing string is typically sealed off from the casing with a packer.
  • packers are used to provide a downhole seal between the tubing string and the surrounding casing in order to prevent the flow of fluids through a portion of a wellbore annulus defined between the tubing string and the casing.
  • Packers are desirable for a number of uses, including providing a seal or barrier such that fluid may be selectively injected to or at a desired level in the wellbore to a desired zone within the surrounding formation.
  • a casing integrity test is a pressure test of the casing.
  • a service rig is required to remove the tubing to pressure test the well.
  • the service rig is moved on the well and the well is killed.
  • the pump and rod are then removed from the well.
  • the tubing is removed and a scraper and drift assembly is run to clean the casing and test for anomalies.
  • a packer is run and set and the casing is pressure tested.
  • the tubing is run back into the well and then the pump and rod are run back in.
  • the present disclosure describes a packer that is ported to provide fluid communication through the packer between the wellbore annulus above the packer and the wellbore annulus below the packer.
  • a ported packer can be used to allow for pressure testing the casing and/or for controlling a failed well.
  • the present disclosure provides a method of pressure testing a well casing, the well casing having disposed therein a packer and a tubing string, the packer having ports for providing fluid communication through the packer between a wellbore annulus above the packer and a wellbore annulus below the packer, the method comprising:
  • the present disclosure provides a method of controlling a failed well having a well casing, the well casing having disposed therein a packer and a tubing string, the packer having ports for providing fluid communication through the packer between a wellbore annulus above the packer and a wellbore annulus below the packer, the method comprising:
  • FIG. 1 illustrates a ported packer in accordance with a disclosed embodiment.
  • viscous oil as used herein means a hydrocarbon, or mixture of hydrocarbons, that occurs naturally and that has a viscosity of at least 10 cP (centipoise) at initial reservoir conditions. Viscous oil includes oils generally defined as “heavy oil” or “bitumen”. Bitumen is classified as an extra heavy oil, with an API gravity of about 10° or less, referring to its gravity as measured in degrees on the American Petroleum Institute (API) Scale. Heavy oil has an API gravity in the range of about 22.3° to about 10°. The terms viscous oil, heavy oil, and bitumen are used interchangeably herein since they may be extracted using similar processes.
  • “In situ” is a Latin phrase for “in the place” and, in the context of hydrocarbon recovery, refers generally to a subsurface hydrocarbon-bearing reservoir.
  • An in situ hydrocarbon recovery technique is one that recovers hydrocarbons from a reservoir within the earth.
  • the packer described herein is ported to provide fluid communication through the packer between the wellbore annulus above the packer and the wellbore annulus below the packer.
  • a ported packer can be used to allow for pressure testing the casing and/or controlling a failed well.
  • FIG. 1 illustrates a ported packer in accordance with one embodiment.
  • the packer 100 is disposed within a casing 102 and holds a tubing string 104 in place.
  • Regular collars 106 a and 106 b, a NoGo collar 108 , and a shaved and beveled collar 110 are also shown.
  • Regular and shaved and beveled collars are standard equipment for joining jointed tubing together in a well.
  • a shaved and beveled collar is a modified regular collar that has some material removed from its outside diameter and ends by turning it on a lathe to make it pass through restrictions in the wellbore more easily and with less chance of catching on sharp edges.
  • a NoGo collar is a collar with a larger outside diameter that is larger than a restriction in the well so the tubing cannot pass that point.
  • the packer 100 comprises a top sub 112 and a bottom sub 114 .
  • the subs 112 and 114 are attached to the top and bottom of the packer and include top ports 120 a and bottom ports 120 b.
  • the ports 120 a and 120 b allow the annular flow to bypass the packer 100 .
  • the subs 112 and 114 are threaded on their ends for attachment to the packer 100 and the seal bore.
  • a top seal bore 116 is attached to the top of the top sub 112 .
  • a bottom seal bore 118 is attached to the bottom of the bottom sub 114 .
  • the seal bores are tubular sections of pipe that are polished inside to allow seals to move up and down inside making a seal while preventing (or mitigating) wear of the seals.
  • a stringer assembly 105 is part of the tubing string 104 and holds the seals that seal inside the seal bores 116 and 118 and allow thermal movement of the tubing string without loss of the ability to isolate the annulus above the packer 100 from the annulus below the packer 100 .
  • the top sub 112 includes the top ports 120 a and the bottom sub 114 includes the bottom ports 120 b to provide fluid or gas communication through the packer 100 between the wellbore annulus above the packer 100 and the wellbore annulus below the packer 100 .
  • the size of the ports 120 a and 120 b could be, for instance, half an inch in diameter to three quarters an inch in diameter.
  • the size of the ports could be larger, depending on the size of the packer.
  • the ports may be circular in cross-section or may be another shape.
  • the number of ports may be, for instance, between 4 and 16 , but the number may vary depending on the size of the packer and the desired pressure drop across the packer.
  • the packer would be to remove the seal bores 116 and 118 and the stinger assembly 105 and replace them with a thermal tubing expansion joint above the packer. The packer would then be attached to the tubing string 104 and thermal expansion of the tubing would take place within the expansion joint.
  • the tubing expansion joint is a tubular device which allows thermal growth or compression of the tubing string but maintains pressure containment between the tubing and the annulus.
  • fluid and soluble perforation ball sealers are injected down the casing having a ported packer.
  • a pressure pumping truck may be used to pump the fluid.
  • the fluid may be water or another non-compressible fluid.
  • Soluble perforation ball sealers are known in the art, and an example are BioBallsTM, which are available from Santrol Oil and Gas Stimulation Products (Fresno, Tex., United States).
  • the ball sealers should be soluble in the liquid used to pressure test the casing and should dissolve in a manner that leaves only minimal residue behind.
  • the balls should be stable at the temperatures experienced in the wellbore at the depth of the ported packer yet dissolve in a short length of time so as not to have the well shut in for a long period of time.
  • the balls plug the top ports in the top sub.
  • the pressure is raised to a predetermined point to test the casing and is then released.
  • the well is shut in until it goes on vacuum indicating that the balls have dissolved.
  • the well is then put back on production.
  • Such a ported packer may have the added advantage of being able to control a high-pressure casing failure.
  • a well fails meaning that the casing can no longer retain pressure
  • reservoir fluid starts flowing to and out the break above the packer.
  • a pump After a well fails, one would land a pump, pressure up the tubing, and create an aperture in the well tubing.
  • a common way to create such an aperture is to blow the burst.
  • the burst is a window style pressure relief tool that, at a predetermined pressure, shears a rectangular hole out the side of the tubing giving access to the annulus from the tubing and relieves high pressure in the tubing before it gets high enough to burst the tubing.
  • floating solid ball sealers are pumped down the tubing with a fluid which could be hot water or another stable non-compressible fluid with a specific gravity low enough to ensure that the balls float.
  • the balls are pumped out the burst.
  • the casing pressure is bled off until the ball sealers plug the bottom ports in the bottom sub.
  • the casing pressure drops, the casing is bled off to below fracture pressure at the break.
  • the casing is then kept below the fracture pressure at the break until the well is at a low enough pressure to be worked on.
  • the balls can be circulated out during casing repair.
  • the solid floating ball sealers should be capable of floating in the pumped fluids and be stable at the high temperatures experienced in a thermal oil well.
  • the balls should be capable of withstanding temperatures of over 300° C.
  • This assembly could be run in a well after its first casing integrity check, for instance in cycle six or seven.
  • a cycle is defined as the period of time from when steam is injected in the well to when steam is again injected into a well and includes the soaking period after steam but before production and the production period. This would allow for an analysis of the wellbore and pad damage. Subsequent casing checks could be replaced with pressure tests using a ported packer as described herein.
  • the ported packer and methods described herein may be used in a variety of hydrocarbon recovery processes, including those described in the background section. As described in the background section, in recovery processes involving high-pressure steaming of wells, such as in CSS, it is necessary to periodically conduct a casing integrity test prior to steam injection to ensure that the well will survive steaming.
  • ported packer By using this type of ported packer, one has the ability to control a casing failure in a high-pressure regime.
  • the conventional operating procedure in response to a high pressure casing failure consists of killing the well with heavy mud. This procedure can take roughly 2 days, whereas the ported packer well control procedure may take approximately one half day.

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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)
  • Geophysics (AREA)
  • Earth Drilling (AREA)
US13/671,391 2011-11-08 2012-11-07 Ported packer Abandoned US20130112408A1 (en)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
CA2757950 2011-11-08
CA2757950A CA2757950C (fr) 2011-11-08 2011-11-08 Garniture d'admission

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CA (2) CA2833992C (fr)

Cited By (13)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN105178904A (zh) * 2015-09-08 2015-12-23 大庆宏测技术服务有限公司 生产测井集流封隔器
CN105484698A (zh) * 2014-10-11 2016-04-13 中国石油天然气股份有限公司 一种复合桥塞
WO2019094106A1 (fr) * 2017-11-08 2019-05-16 Geodynamics, Inc. Bouchon de dérivation contrôlée et procédé
US10427191B2 (en) 2017-04-06 2019-10-01 Henry Crichlow Deep geologic disposal of nuclear waste
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
US10692618B2 (en) 2018-06-04 2020-06-23 Deep Isolation, Inc. Hazardous material canister
US10878972B2 (en) 2019-02-21 2020-12-29 Deep Isolation, Inc. Hazardous material repository systems and methods
US10943706B2 (en) 2019-02-21 2021-03-09 Deep Isolation, Inc. Hazardous material canister systems and methods
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
US11158434B2 (en) 2018-12-18 2021-10-26 Deep Isolation, Inc. Radioactive waste repository systems and methods
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
CN114526030A (zh) * 2021-12-30 2022-05-24 王占强 套变组合密封器

Citations (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3373805A (en) * 1965-10-14 1968-03-19 Exxon Production Research Co Steam lifting of heavy crudes
US4778008A (en) * 1987-03-05 1988-10-18 Exxon Production Research Company Selectively releasable and reengagable expansion joint for subterranean well tubing strings
US4881599A (en) * 1986-10-03 1989-11-21 Petroleo Brasileiro S.A. - Petrobras Mechanical system for diversion in the acidizing treatment of oil formations
US6186227B1 (en) * 1999-04-21 2001-02-13 Schlumberger Technology Corporation Packer
US20070181224A1 (en) * 2006-02-09 2007-08-09 Schlumberger Technology Corporation Degradable Compositions, Apparatus Comprising Same, and Method of Use
US7510016B2 (en) * 2004-05-05 2009-03-31 Specialised Petroleum Services Group Limited Packer
US7748459B2 (en) * 2007-09-18 2010-07-06 Baker Hughes Incorporated Annular pressure monitoring during hydraulic fracturing
US20120175108A1 (en) * 2011-01-07 2012-07-12 Weatherford/Lamb, Inc. Test packer and method for use
WO2013062566A1 (fr) * 2011-10-28 2013-05-02 Halliburton Energy Services, Inc. Ensemble de garniture de fond de trou ayant une dérivation de fluide sélective et procédé pour son utilisation

Patent Citations (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3373805A (en) * 1965-10-14 1968-03-19 Exxon Production Research Co Steam lifting of heavy crudes
US4881599A (en) * 1986-10-03 1989-11-21 Petroleo Brasileiro S.A. - Petrobras Mechanical system for diversion in the acidizing treatment of oil formations
US4778008A (en) * 1987-03-05 1988-10-18 Exxon Production Research Company Selectively releasable and reengagable expansion joint for subterranean well tubing strings
US6186227B1 (en) * 1999-04-21 2001-02-13 Schlumberger Technology Corporation Packer
US7510016B2 (en) * 2004-05-05 2009-03-31 Specialised Petroleum Services Group Limited Packer
US20070181224A1 (en) * 2006-02-09 2007-08-09 Schlumberger Technology Corporation Degradable Compositions, Apparatus Comprising Same, and Method of Use
US7748459B2 (en) * 2007-09-18 2010-07-06 Baker Hughes Incorporated Annular pressure monitoring during hydraulic fracturing
US20120175108A1 (en) * 2011-01-07 2012-07-12 Weatherford/Lamb, Inc. Test packer and method for use
WO2013062566A1 (fr) * 2011-10-28 2013-05-02 Halliburton Energy Services, Inc. Ensemble de garniture de fond de trou ayant une dérivation de fluide sélective et procédé pour son utilisation

Non-Patent Citations (2)

* Cited by examiner, † Cited by third party
Title
Alboudwarej, Hussein. "Highlighting Heavy Oil." Oilfield Review 1 June 2006: 34-35. Print. Online at: http://www.slb.com/resources/publications/industry_articles/oilfield_review/2006/or2006sum03_highlighting_heavyoil.aspx *
Alnoaimi, Khalid. "Heavy Oil Recovery: Definitions and Means." Stanford University, 23 Oct. 2010. Web. 19 Nov. 2014. . *

Cited By (17)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN105484698A (zh) * 2014-10-11 2016-04-13 中国石油天然气股份有限公司 一种复合桥塞
CN105178904A (zh) * 2015-09-08 2015-12-23 大庆宏测技术服务有限公司 生产测井集流封隔器
US10427191B2 (en) 2017-04-06 2019-10-01 Henry Crichlow Deep geologic disposal of nuclear waste
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
US10871048B2 (en) 2017-11-08 2020-12-22 Geodynamics, Inc. Controlled bypass plug and method
WO2019094106A1 (fr) * 2017-11-08 2019-05-16 Geodynamics, Inc. Bouchon de dérivation contrôlée et procédé
US10692618B2 (en) 2018-06-04 2020-06-23 Deep Isolation, Inc. Hazardous material canister
US11158434B2 (en) 2018-12-18 2021-10-26 Deep Isolation, Inc. Radioactive waste repository systems and methods
US10878972B2 (en) 2019-02-21 2020-12-29 Deep Isolation, Inc. Hazardous material repository systems and methods
US10943706B2 (en) 2019-02-21 2021-03-09 Deep Isolation, Inc. Hazardous material canister systems and methods
US11289230B2 (en) 2019-02-21 2022-03-29 Deep Isolation, Inc. Hazardous material canister systems and methods
US11488736B2 (en) 2019-02-21 2022-11-01 Deep Isolation, Inc. Hazardous material repository systems and methods
US11842822B2 (en) 2019-02-21 2023-12-12 Deep Isolation, Inc. Hazardous material canister systems and methods
CN114526030A (zh) * 2021-12-30 2022-05-24 王占强 套变组合密封器

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Publication number Publication date
CA2833992A1 (fr) 2013-05-08
CA2757950C (fr) 2014-06-03
CA2833992C (fr) 2015-06-30
CA2757950A1 (fr) 2013-05-08

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Owner name: EXXONMOBIL UPSTREAM RESEARCH COMPANY, TEXAS

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:IMPERIAL OIL RESOURCES LIMITED;REEL/FRAME:033135/0696

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