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US20120125625A1 - System and method for intermittent gas lift - Google Patents

System and method for intermittent gas lift Download PDF

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Publication number
US20120125625A1
US20120125625A1 US13/381,111 US201013381111A US2012125625A1 US 20120125625 A1 US20120125625 A1 US 20120125625A1 US 201013381111 A US201013381111 A US 201013381111A US 2012125625 A1 US2012125625 A1 US 2012125625A1
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US
United States
Prior art keywords
string
gas
annulus
flow
liquid
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
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US13/381,111
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English (en)
Inventor
James Robert Brewer
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 USA Inc
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Individual
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Filing date
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Priority to US13/381,111 priority Critical patent/US20120125625A1/en
Assigned to SHELL OIL COMPANY reassignment SHELL OIL COMPANY ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: BREWER, JAMES ROBERT
Publication of US20120125625A1 publication Critical patent/US20120125625A1/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
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E21B43/121—Lifting well fluids
    • E21B43/122—Gas lift
    • 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
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E21B43/121—Lifting well fluids
    • E21B43/13—Lifting well fluids specially adapted to dewatering of wells of gas producing reservoirs, e.g. methane producing coal beds

Definitions

  • the present invention relates to a system and apparatus for removing water from a deep gas well.
  • Hydrocarbon gas from subsurface earth formations is initially produced by the inherent formation pressure of the gas in the formation. Over time, however, water vapor in the gas stream condenses on the way to surface. As production rates decline, the velocity is no longer able to lift fluids to the surface. Water droplets coalesce, run down tubulars, and collect at the bottom of the wellbore. Eventually, the fluid level rises above the level of the well perforations. This increases bottom hole flowing pressure and restricts production. When this occurs, it is advantageous to remove the liquids from the well in order to increase the gas flow rate.
  • FIGS. 1-2 A common practice is to use a plunger to intermittently lift the liquids.
  • a system 10 is used that comprises a wellbore 12 , gas lift tubing string 14 , and an inner tubing string 16 .
  • Wellbore 12 may be cased. It will be understood that the Figures are not drawn to scale and that the total depth of the well may be several thousand feet.
  • An annulus 22 is defined between the wellbore or casing and gas lift tubing string 14 .
  • a gas production valve 32 , gas lift inlet valve 34 , and gas lift outlet valve 36 control the flow of fluids at the upper ends of annulus 22 , tubing string 14 , and inner string 16 , respectively.
  • a standing valve 38 controls the flow of fluid into tubing string 14 through an opening 28 .
  • One or more perforations 42 enhance the flow of fluids out of the formation and into the wellbore.
  • plunger 40 sealingly engages the inside of inner string 16 .
  • Plunger 40 is designed to allow fluids to flow up through or around the plunger and into inner string 16 until plunger 40 starts moving upward, whereupon plunger changes shape such that it forms a seal with the inside of inner string 16 .
  • plunger 40 may comprise chevron type seals that allow the fluid to flow past in one direction, but tend to prevent fluid from flowing past in the other direction.
  • gas coming out of the formation flows up annulus 22 and out through valve 32 .
  • water enters the well from the formation and/or condenses and falls to the bottom of the well.
  • water collecting at the bottom of the well enters gas lift tubing string 14 through opening 28 .
  • the lift gas vents until hydrostatic pressure at the bottom of the well is sufficient to open the standing valve and the cycle repeats. While fluids enter the tubing, the plunger falls back to bottom.
  • intermittent gas lift techniques are that they lift fluids without putting any backpressure on the formation. While useful in shallow wells, conventional intermittent gas lift techniques require produced gas to flow up the annulus. Flowing gas up the annulus is acceptable in shallow low pressure gas applications; however, issues such as high pressure, hydrogen sulfide, sulphur deposition, paraffin deposition, and local regulations may prohibit flow up the annulus. Thus, there remains a need for an effective technique for removing water from deep gas wells.
  • a system and technique are provided for removing water from deep gas wells.
  • the system may be an intermittent gas-lift apparatus for use in a well that produces gas and liquid, in which liquids accumulate in a liquid zone in the wellbore.
  • the system may comprise a first string extending into the liquid zone and having an upper end and a lower end, a second string surrounding the first string and defining an annulus therewith, the second string extending a predetermined axial distance from the first string lower end such that said annulus has an upper end and a lower end, the annulus being closed at its upper and lower ends so as to define a chamber, the chamber being in fluid communication with the inside of the first string, a check valve controlling the flow of liquid into from the wellbore into the lower end of said annulus, a gas valve allowing the flow of gas from the first string into the upper end of the chamber, and a valve for controlling the flow of gas into the upper end of the first string.
  • the first string may comprise coiled tubing and the second string may comprise production tubing.
  • the system includes an optional plunger slidably disposed in the first string.
  • the invention comprises a method for producing gas from a well that produces gas and liquid, in which liquids accumulate in a liquid zone in the wellbore.
  • the method may comprise the steps of: a) providing in the well an apparatus comprising: a first string extending into the liquid zone and having an upper end and a lower end, a second string surrounding the first string and defining an annulus therewith, said second string extending a predetermined axial distance from the first string lower end, such that said annulus has an upper end and a lower end, said annulus being closed at its upper and lower ends so as to define a chamber, said chamber being in fluid communication with the inside of said first string, a check valve controlling the flow of liquid into from the wellbore into the lower end of said annulus, a gas valve allowing the flow of gas from the first string into said chamber, and a valve for controlling the flow of gas through the upper end of said inner string; b) allowing liquid to flow from the wellbore into the annulus; c) pumping gas into the annulus via
  • FIGS. 1 and 2 are schematic illustrations of two modes of a prior art system
  • FIGS. 3-5 are schematic illustrations of three modes of a system constructed in accordance with an embodiment of the invention.
  • FIG. 6 is a schematic illustration of a system constructed in accordance with an alternative embodiment of the invention.
  • FIG. 1 illustrates a system that is designed for use in a hydrocarbon production well. Positions of equipment are illustrated relative to the top of the well (the earth's surface) or the bottom of the well, but such illustration is schematic only. The Figures are not to scale and the distance between the top and bottom of the well may be several thousand feet.
  • a system 100 is positioned in a wellbore 12 .
  • the system 100 includes a production string 114 and an inner string 116 .
  • Inner string 116 preferably but not necessarily comprises coiled tubing.
  • a production valve 124 controls the flow of fluids out of production string 114 and a lift gas inlet valve 126 and a lift gas vent valve 128 control the fluid into and out of, respectively, inner string 116 .
  • Lift gas is preferably provided to lift gas inlet valve 126 via a high pressure lift gas feed line (not shown).
  • a packer 115 is preferably set at the bottom of production string 114 so as to isolate the portion of the annulus above that point.
  • the system preferably includes a crossover 130 that is preferably located several thousand feet from the bottom of the hole. Below crossover 130 , a concentric outer string 118 surrounds inner string 116 , forming an annulus 117 therebetween.
  • a gas check valve 144 is preferably disposed in the wall of inner string 116 near crossover 130 .
  • An unloading valve 146 is preferably disposed in the wall of outer string 118 near the bottom of string 118 .
  • a standing valve 129 controls the flow of fluids from the borehole into the bottom of outer string 118 .
  • One or more passageways 123 provide fluid communication between the inside of outer string 118 and the inside of inner string 116 .
  • lift gas inlet valve 126 is normally closed and vent valve 128 is open. Water flows accumulates at the bottom of the wellbore and flows into the concentric tubing through standing valve 129 , and produced gas flows out through production string 114 , as indicated by arrow 145 .
  • vent valve 128 closes and lift gas inlet valve 126 opens. This allows pressurized gas to flow down through inner string 116 .
  • Standing valve 129 closes as a result of the pressure differential between the inside of outer string 118 and the wellbore and gas check valve 144 allows high pressure lift gas to pass from the coiled tubing into annulus 117 . Because the system is closed, the pressure inside inner string 116 and annulus 117 will rise until it reaches line pressure, i.e. the pressure in the high pressure lift gas feed line.
  • Vent valve 128 opens, allowing gas inside the coiled tubing to flow back to the surface and decreasing the pressure in inner string 116 .
  • Check valve 144 prevents the pressurized gas in annulus 117 from flowing back into inner string 116 , with the result that the pressurized gas trapped in annular space 117 expands toward the bottom of the well and up through inner string 116 .
  • the expanding gas from annulus 117 flows up through inner string 116 , it pushes a slug of liquid 150 ahead of it to the surface, thereby reducing the amount of liquid in the bottom of the well.
  • the lift gas continues to vent through valve 128 until the pressure inside the tubing equals the vent pressure.
  • valve 146 at the bottom of the concentric string may be included and used for initial unloading of downhole liquids.
  • An advantage of the present invention is that produced gas is able to flow out of the formation and up though production string 114 without restriction throughout the entire lift cycle, as indicated by arrow 145 .
  • Standing valve 129 ensures that all lift gas is confined within the inner and outer tubing 116 , 118 .
  • water can be removed from the well without changing the bottom hole flowing pressure.
  • conventional systems which put additional backpressure on the formation during lift cycles or require the well to be shut in in order to build up sufficient downhole pressure to intermittently lift fluids.
  • the well will continue to flow at normal rates with the normal bottom hole flowing pressure.
  • a further advantage of the present system is that it does not require the installation of concentric tubing strings extending the full depth of the well.
  • the system shown in FIGS. 1 and 2 requires concentric tubing strings from the surface to the bottom of the well.
  • the amount of gas required to be injected in order to perform a gas lift operation using the system of FIG. 1 would be significant.
  • the present system avoids the need for a downhole pump or similar equipment.
  • the suitable pressures for application to annulus 117 during the pressurization portion of the cycle range between 400 psig and 1,400 psig, depending on the volume of water per lift, depth, and the axial length of annulus 117 .
  • the length of annulus 117 can be determined using the expected line pressure and the ratio of the annulus volume to the total tubing volume. In some embodiments, it may be desirable to design the system such that the ratio of the volume of the gas in the pressured annulus, when expanded to vent pressure, to the volume of inner string 116 is in the range of 5 to 15.
  • the Figures are not to scale.
  • the distance between crossover 130 and the bottom of inner string 116 is likely to be several thousand feet.
  • a 10,000′ well might have a production string packer 115 at around 6,000′, crossover 130 at 6,500′, and the bottom of standing valve 129 at 9,990′, with casing perforations in stages from 7,000′ to 9,500′.
  • the axial length of annulus 117 may, in various embodiments, be less than 75%, less than 67%, less than 50%, less than 40%, or even less than 25% of the total length of inner string 116 .
  • liquid in the well may accumulate in a liquid zone that is not at the remote end of the wellbore. It will be understood that references to a liquid accumulation zone include any such zone, regardless of whether it is at the end of the wellbore.
  • such a system preferably includes a production string 214 and packer 115 as described above.
  • an inner tubing string 216 extends through the production string 214 .
  • Both inner tubing string 216 and production string 214 terminate near the bottom of the hole.
  • An annulus 217 is defined between inner tubing string 216 and production string 214 .
  • the upper and lower ends of annulus 217 are preferably sealed by a packer 215 and a seating assembly 219 , respectively.
  • a standing valve 229 controls the flow of fluids into the bottom of inner string 216 .
  • Fluid passageways 222 through the wall of inner string 216 allow fluids to flow between annulus 217 and the inside of inner tubing string 216 .
  • Passageways 224 through the wall of production tubing 114 allow produced gas to flow from the wellbore into annulus 217 .
  • valve 229 controls the flow of fluids into annulus 217 .
  • FIG. 6 functions in the same manner as the system of FIG. 3 .
  • pressurized gas is supplied to annulus 217 via inner tubing string 216 and the expansion of that gas is used to propel a slug of liquid up out of the well.
  • An optional plunger may be included within inner string 216 to keep lift gas from over-riding the fluid.
  • standing valve 129 and gas valve 244 can be maintained with wireline.
  • an intermediate-diameter conventional tubing string may be hung from a flow-through tubing hanger disposed between the production tubing and an inner string.
  • the inner string may comprise coiled tubing or conventional tubing.
  • a seal is provided between the intermediate string and the inner string so that the annulus therebetween can receive and contain the pressurized gas. Once the annulus has reached line pressure, the pressure in the inner string is released, the check valve closes to prevent backflow, and the gas in the annulus expands, propelling a slug of liquid upward.
  • the upper and lower ends of the inner and outer string, the annulus, and the standing valve could be configured differently, so long as a chamber is defined and liquids can flow into the chamber, gas can be pumped into the chamber, and the expanding gas can be used to propel a slug of liquid from the chamber to the surface or a predetermined outflow point.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • General Chemical & Material Sciences (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Chemical & Material Sciences (AREA)
  • Physical Or Chemical Processes And Apparatus (AREA)
  • Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
  • Feeding, Discharge, Calcimining, Fusing, And Gas-Generation Devices (AREA)
  • Pipe Accessories (AREA)
US13/381,111 2009-06-29 2010-06-29 System and method for intermittent gas lift Abandoned US20120125625A1 (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
US13/381,111 US20120125625A1 (en) 2009-06-29 2010-06-29 System and method for intermittent gas lift

Applications Claiming Priority (3)

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US22116909P 2009-06-29 2009-06-29
PCT/US2010/040311 WO2011008522A2 (en) 2009-06-29 2010-06-29 System and method for intermittent gas lift
US13/381,111 US20120125625A1 (en) 2009-06-29 2010-06-29 System and method for intermittent gas lift

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US (1) US20120125625A1 (pt)
EP (1) EP2449209A4 (pt)
CN (1) CN102472089A (pt)
AU (1) AU2010273768B2 (pt)
BR (1) BRPI1011900A2 (pt)
CA (1) CA2766786A1 (pt)
WO (1) WO2011008522A2 (pt)
ZA (1) ZA201200156B (pt)

Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20140360732A1 (en) * 2013-06-11 2014-12-11 Lufkin Industries, Inc. Bottle Chamber Gas Lift Systems, Apparatuses, and Methods Thereof
US20160130920A1 (en) * 2013-05-28 2016-05-12 Lifteck International Inc. Downhole pumping apparatus and method
WO2016156187A1 (en) * 2015-03-27 2016-10-06 Shell Internationale Research Maatschappij B.V. Method and system for operating a gas well
CN112539047A (zh) * 2020-12-22 2021-03-23 西安荣达石油工程有限公司 能保护油气层且实现高效气举排液的工艺管柱及工艺
CN119266777A (zh) * 2023-07-07 2025-01-07 中国石油天然气股份有限公司 一种适用于水平井连续油管柱塞排液工具及排液方法

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* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN102747993B (zh) * 2012-06-27 2015-01-28 中国石油大学(华东) 一种液态起泡剂注入方法
CA2971753C (fr) 2014-12-22 2019-11-12 Total Sa Dispositif d'evacuation de liquides accumules dans un puits
CN106592692A (zh) * 2016-10-31 2017-04-26 北京建工环境修复股份有限公司 一种地下流体气提装置及工艺
CN107558962A (zh) * 2017-07-21 2018-01-09 山西晋城无烟煤矿业集团有限责任公司 同心管式间歇型气举排水工艺
CN109025911A (zh) * 2018-08-23 2018-12-18 山西晋城无烟煤矿业集团有限责任公司 一种煤层气井气举排水储层保护装置及排水方法
CN116104456B (zh) * 2023-04-14 2023-06-30 陕西航天德林科技集团有限公司 一种排水采气系统及排水采气方法

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BR9404096A (pt) * 1994-10-14 1996-12-24 Petroleo Brasileiro Sa Método e aparelho para produção intermitente de petróleo com interface mecânica
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CN2639520Y (zh) * 2003-08-15 2004-09-08 中国石油化工股份有限公司中原油田分公司采油工程技术研究院 导流式气举阀

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Cited By (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20160130920A1 (en) * 2013-05-28 2016-05-12 Lifteck International Inc. Downhole pumping apparatus and method
US10066468B2 (en) * 2013-05-28 2018-09-04 Lifteck International Inc. Downhole pumping apparatus and method
US20140360732A1 (en) * 2013-06-11 2014-12-11 Lufkin Industries, Inc. Bottle Chamber Gas Lift Systems, Apparatuses, and Methods Thereof
US9725995B2 (en) * 2013-06-11 2017-08-08 Lufkin Industries, Llc Bottle chamber gas lift systems, apparatuses, and methods thereof
WO2016156187A1 (en) * 2015-03-27 2016-10-06 Shell Internationale Research Maatschappij B.V. Method and system for operating a gas well
CN112539047A (zh) * 2020-12-22 2021-03-23 西安荣达石油工程有限公司 能保护油气层且实现高效气举排液的工艺管柱及工艺
CN119266777A (zh) * 2023-07-07 2025-01-07 中国石油天然气股份有限公司 一种适用于水平井连续油管柱塞排液工具及排液方法

Also Published As

Publication number Publication date
CA2766786A1 (en) 2011-01-20
EP2449209A4 (en) 2014-03-19
AU2010273768A1 (en) 2012-02-09
ZA201200156B (en) 2012-09-26
EP2449209A2 (en) 2012-05-09
CN102472089A (zh) 2012-05-23
BRPI1011900A2 (pt) 2017-06-27
WO2011008522A3 (en) 2011-03-31
AU2010273768B2 (en) 2014-06-05
WO2011008522A2 (en) 2011-01-20

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Owner name: SHELL OIL COMPANY, TEXAS

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:BREWER, JAMES ROBERT;REEL/FRAME:027670/0868

Effective date: 20120110

STCB Information on status: application discontinuation

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