US20050173112A1 - Annulus plugging detection using a pressure transmitter in gas-lift oil production - Google Patents

Annulus plugging detection using a pressure transmitter in gas-lift oil production Download PDF

Info

Publication number
US20050173112A1
US20050173112A1 US11/050,637 US5063705A US2005173112A1 US 20050173112 A1 US20050173112 A1 US 20050173112A1 US 5063705 A US5063705 A US 5063705A US 2005173112 A1 US2005173112 A1 US 2005173112A1
Authority
US
United States
Prior art keywords
pressure
annulus
pressure transmitter
outer annulus
parameter
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
US11/050,637
Other languages
English (en)
Inventor
Kadir Kavaklioglu
Marcos Peluso
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.)
Rosemount Inc
Original Assignee
Rosemount Inc
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 Rosemount Inc filed Critical Rosemount Inc
Priority to US11/050,637 priority Critical patent/US20050173112A1/en
Assigned to ROSEMOUNT INC. reassignment ROSEMOUNT INC. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: KAVAKLIOGLU, KADIR, PELUSO, MARCOS
Publication of US20050173112A1 publication Critical patent/US20050173112A1/en
Abandoned legal-status Critical Current

Links

Images

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
    • E21B43/12—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
    • E21B47/00—Survey of boreholes or wells
    • E21B47/06—Measuring temperature or pressure

Definitions

  • the present invention is related to gas-lift oil production operations. More particularly, the present invention is related to improved annulus plugging detection in such operations.
  • the gas-lift method of lifting crude oil is used in many of the world's oil wells. Indeed, in fields where significant quantities of associated gas are present and produced solids are involved, it is the preferred method of augmenting the natural reservoir pressure and thus increasing production.
  • FIG. 1 is diagrammatic view of a typical gas-lift oil well.
  • Central pipe 10 defines a passageway 12 through which crude oil flows in the direction of arrow 14 up to the ground and ultimately to one or more collection stations.
  • the middle section includes middle conduit 16 disposed preferably, concentrically, about pipe 10 to define an inner annulus 17 between conduit 16 and pipe 10 .
  • Pressurized gas is injected into inner annulus 17 and travels down, in the direction of arrow 18 , to the bottom of the piping.
  • the pressurized gas then enters the middle section that contains the crude oil through a special section. This creates lift for the crude oil to ascend via pipe 10 to the surface.
  • inner annulus 17 is highly pressurized and often has temperatures exceeding that of ambient.
  • An outer shell 20 defines an outer annulus 22 between shell 20 and conduit 16 .
  • Outer annulus 22 and shell 20 help protect the environment against leaks and any thermal impacts of the pumping operation.
  • the pressure within outer annulus 22 is slightly below atmospheric pressure and would not have any materials, such as oil or gas, disposed therein.
  • outer annulus 22 may become pressurized due to leaks from inner annulus 17 or cracks in conduit 16 defining the barrier between inner annulus 17 and outer annulus 22 .
  • the pressure within outer annulus may sometimes reach levels on the order of 2000 pounds per square inch. In these cases, a special permit may be required from the state, or other suitable regulatory authority, to operate the well. In such situations, the pressure within outer annulus 22 must be monitored to comply with regulations.
  • a pressure transmitter such as transmitter 24 is sometimes operably coupled to outer annulus 22 in order to monitor the pressure therein.
  • the well temperature may be around 160° F., which is induced by the relatively high-pressure gas injection to the system. Due to various reasons, the well may stop operation occasionally. In this case, the well temperature close to ground and well head above ground will drop in temperature to that of ambient. In these cases, the material inside outer annulus 22 can freeze creating a plug in annulus 22 and/or instrument piping 26 . When this happens, pressure measurements taken using transmitter 24 will no longer reflect the actual pressures in outer annulus 22 . When the well starts to operate again, the temperature in the well starts to rise. This temperature rise will cause expansion of the material in the bottom sections of annulus 22 . Since there may be a frozen plug at the top section, significant increases in pressure in annulus 22 below the plug can occur.
  • Outer annulus plugging detection is provided for gas-lift oil wells.
  • the outer annulus detection is effected using a pressure transmitter.
  • the pressure transmitter provides an indication of pressure within an outer annulus of the oil well.
  • a parameter related to a plurality of outer annulus pressure readings is used to provide an indication of annulus plugging. Examples of the statistical parameter include mean and standard deviation.
  • FIG. 1 is diagrammatic view of a typical gas-lift oil well.
  • FIG. 2 is diagrammatic view of a pressure transmitter operably coupled to an outer annulus in accordance with an embodiment of the present invention.
  • FIG. 3 shows results from a test performed in accordance with an embodiment of the present invention.
  • FIG. 4 shows the standard deviation as a function of time for the same test cases as that of FIG. 3 .
  • FIG. 2 is diagrammatic view of a pressure transmitter 100 operably coupled to outer annulus 22 .
  • Pressure sensor 102 of transmitter 100 is fluidically coupled to annulus 22 and has an electrical characteristic that varies with the pressure in annulus 22 .
  • Pressure sensor 102 can be a capacitive-type pressure sensor, a resistance-based strain gauge-type sensor, or any other suitable type of sensor.
  • Pressure sensor 102 is electrically coupled to analog to digital converter 104 .
  • Converter 104 converts an analog signal from sensor 102 into a digital value that it provides, via line 106 , to controller 108 . Additionally, in accordance with one embodiment of the invention, converter 104 may provide an auxiliary output 110 , illustrated in phantom, that simply reflects a digital bitstream indicative of the analog reading.
  • a digital bitstream allows higher resolution, which is useful for some types of statistical processing.
  • a traditional analog to digital converter may provide digital conversions on line 106 at approximately 22 times per second, the frequency of the digital bitstream on line 110 may be over 100 kHz.
  • Power module 112 can include any suitable circuitry for receiving and conveying power to the components of transmitter 100 .
  • Module 112 is coupled to all components requiring power as indicated at line 114 .
  • Module 112 may include an energy storage cell, or may include suitable circuitry to couple to a source of energy. It is known for some process industry standard protocols to provide operating power. Examples of such protocols include HART, and FOUNDATIONTM Fieldbus.
  • Power module 112 may also include one or more suitable transducers for converting potential energy into electrical energy for transmitter 100 .
  • module 112 may include one or more solar cells, for example.
  • Communications module 116 is coupled to controller 108 and allows transmitter 100 to communicate to one or more external devices.
  • module 116 will be suitably adapted.
  • Transmitter 100 can provide a first signal indicative of pressure within annulus 22 , and a second signal indicative of annulus plugging.
  • Known protocols allow such signals to be provided over the same communication lines. For example, one signal could be provided in analog format, and the second signal could be a superimposed digital signal.
  • Controller 108 is preferably a microprocessor. Controller 108 could be part of transmitter 100 , or may reside in a remote location from transmitter 100 . Controller 108 may include internal memory (not separately illustrated) and/or may be coupled to external memory 120 . Using internal memory, external memory 120 , or any combination thereof, controller 108 will store pressure measurement data related to readings from pressure sensor 102 over time. In accordance with embodiments of the present invention, it has been determined that secondary calculations based upon a plurality of temporally spaced readings related to pressure sensor 102 can reveal the plugging of annulus 22 . Much of the remainder of the description will focus upon the use of statistical parameters. However, embodiments of the present invention can be practiced using other analytical techniques such as fuzzy logic, neural networks, learning techniques, trend analysis, and any other suitable methods, or any combination thereof.
  • FIG. 3 shows results from one of the test performed. This plot presents the mean parameter as a function of time.
  • the normal operating pressure in outer annulus 22 is approximately 426 pounds per square inch. Every time that a valve was closed to simulate annulus plugging, the mean parameter pressure reading showed a significant drop in value compared to normal operating pressure. It has been concluded that the temperature changes and pipe/valve leaks contribute to this change as a result of plugging. Accordingly, pressure transmitter 100 can be characterized, or otherwise calibrated to a known non-plugged condition. Then, if the mean of the pressure sensor readings deviates beyond an allowable threshold from the baseline “good” condition, an alarm, or other suitable indication, is provided from pressure transmitter 100 indicating annulus plugging.
  • FIG. 4 shows the standard deviation as a function of time for the same test cases of that of FIG. 3 .
  • the standard deviation parameter presents a significantly more distinctive signature for plugging indications. Each time the system was plugged, a peak was observed in the standard deviation. As is apparent from the results illustrated in FIG. 4 , standard deviation may be used alone, or in combination with the mean to provide annulus plugging detection.
  • pressure transmitter 100 is provided with a notification regarding pumping operations, either stopping, starting, or both. Thus, when pressure transmitter 100 receives a notification that pumping is starting again, it may wait a pre-selected duration before expecting measurements to be acceptable.
  • embodiments of the present invention can be practiced by accessing the outer annulus pressure at selected intervals, or even in response to technician requests. However, sufficient numbers of pressure measurements must be taken by pressure sensor 102 in order to provide statistical computations.

Landscapes

  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (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)
  • Measuring Fluid Pressure (AREA)
  • Earth Drilling (AREA)
  • Pipeline Systems (AREA)
US11/050,637 2004-02-05 2005-02-03 Annulus plugging detection using a pressure transmitter in gas-lift oil production Abandoned US20050173112A1 (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
US11/050,637 US20050173112A1 (en) 2004-02-05 2005-02-03 Annulus plugging detection using a pressure transmitter in gas-lift oil production

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US54218504P 2004-02-05 2004-02-05
US11/050,637 US20050173112A1 (en) 2004-02-05 2005-02-03 Annulus plugging detection using a pressure transmitter in gas-lift oil production

Publications (1)

Publication Number Publication Date
US20050173112A1 true US20050173112A1 (en) 2005-08-11

Family

ID=34860271

Family Applications (1)

Application Number Title Priority Date Filing Date
US11/050,637 Abandoned US20050173112A1 (en) 2004-02-05 2005-02-03 Annulus plugging detection using a pressure transmitter in gas-lift oil production

Country Status (8)

Country Link
US (1) US20050173112A1 (ru)
EP (1) EP1711681B1 (ru)
JP (1) JP2007520656A (ru)
CN (1) CN1910338A (ru)
CA (1) CA2547974A1 (ru)
DE (1) DE602005009493D1 (ru)
RU (1) RU2359117C2 (ru)
WO (1) WO2005078237A1 (ru)

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20100011869A1 (en) * 2007-07-20 2010-01-21 Rosemount Inc. Differential pressure diagnostic for process fluid pulsations
US7765873B2 (en) 2007-07-20 2010-08-03 Rosemount Inc. Pressure diagnostic for rotary equipment
US7949495B2 (en) * 1996-03-28 2011-05-24 Rosemount, Inc. Process variable transmitter with diagnostics
US20110259095A1 (en) * 2008-12-16 2011-10-27 Mcmiles Barry J Hydraulic Signature Tester

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN110185415B (zh) * 2018-05-09 2024-05-03 中国科学院深海科学与工程研究所 石油管道疏通系统及疏通方法

Citations (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2678605A (en) * 1950-08-07 1954-05-18 Shell Dev Gas-lift apparatus for producing multiple zone wells
US2704980A (en) * 1950-11-22 1955-03-29 Stanolind Oil & Gas Co Well-producing apparatus
US5272646A (en) * 1991-04-11 1993-12-21 Farmer Edward J Method for locating leaks in a fluid pipeline and apparatus therefore
US5462120A (en) * 1993-01-04 1995-10-31 S-Cal Research Corp. Downhole equipment, tools and assembly procedures for the drilling, tie-in and completion of vertical cased oil wells connected to liner-equipped multiple drainholes
US5741980A (en) * 1994-11-02 1998-04-21 Foster-Miller, Inc. Flow analysis system and method
US6017143A (en) * 1996-03-28 2000-01-25 Rosemount Inc. Device in a process system for detecting events
US20020029130A1 (en) * 1996-03-28 2002-03-07 Evren Eryurek Flow diagnostic system
US20020169582A1 (en) * 2001-05-14 2002-11-14 Evren Eryurek Diagnostics for industrial process control and measurement systems
US6601005B1 (en) * 1996-11-07 2003-07-29 Rosemount Inc. Process device diagnostics using process variable sensor signal
US6654697B1 (en) * 1996-03-28 2003-11-25 Rosemount Inc. Flow measurement with diagnostics
US6820702B2 (en) * 2002-08-27 2004-11-23 Noble Drilling Services Inc. Automated method and system for recognizing well control events
US20040238178A1 (en) * 2001-08-17 2004-12-02 Laureano Marcio P Annulus monitoring system

Family Cites Families (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
DE60029196T2 (de) * 1999-02-25 2007-06-28 Rosemount Inc., Eden Prairie Strömungsmessung mit diagnostischen mitteln

Patent Citations (14)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2678605A (en) * 1950-08-07 1954-05-18 Shell Dev Gas-lift apparatus for producing multiple zone wells
US2704980A (en) * 1950-11-22 1955-03-29 Stanolind Oil & Gas Co Well-producing apparatus
US5272646A (en) * 1991-04-11 1993-12-21 Farmer Edward J Method for locating leaks in a fluid pipeline and apparatus therefore
US5462120A (en) * 1993-01-04 1995-10-31 S-Cal Research Corp. Downhole equipment, tools and assembly procedures for the drilling, tie-in and completion of vertical cased oil wells connected to liner-equipped multiple drainholes
USRE38642E1 (en) * 1993-01-04 2004-11-02 Halliburton Energy Services, Inc. Downhole equipment, tools and assembly procedures for the drilling, tie-in and completion of vertical cased oil wells connected to liner-equipped multiple drainholes
US5741980A (en) * 1994-11-02 1998-04-21 Foster-Miller, Inc. Flow analysis system and method
US20020029130A1 (en) * 1996-03-28 2002-03-07 Evren Eryurek Flow diagnostic system
US6654697B1 (en) * 1996-03-28 2003-11-25 Rosemount Inc. Flow measurement with diagnostics
US6017143A (en) * 1996-03-28 2000-01-25 Rosemount Inc. Device in a process system for detecting events
US6907383B2 (en) * 1996-03-28 2005-06-14 Rosemount Inc. Flow diagnostic system
US6601005B1 (en) * 1996-11-07 2003-07-29 Rosemount Inc. Process device diagnostics using process variable sensor signal
US20020169582A1 (en) * 2001-05-14 2002-11-14 Evren Eryurek Diagnostics for industrial process control and measurement systems
US20040238178A1 (en) * 2001-08-17 2004-12-02 Laureano Marcio P Annulus monitoring system
US6820702B2 (en) * 2002-08-27 2004-11-23 Noble Drilling Services Inc. Automated method and system for recognizing well control events

Cited By (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US7949495B2 (en) * 1996-03-28 2011-05-24 Rosemount, Inc. Process variable transmitter with diagnostics
US20100011869A1 (en) * 2007-07-20 2010-01-21 Rosemount Inc. Differential pressure diagnostic for process fluid pulsations
US7765873B2 (en) 2007-07-20 2010-08-03 Rosemount Inc. Pressure diagnostic for rotary equipment
US7770459B2 (en) 2007-07-20 2010-08-10 Rosemount Inc. Differential pressure diagnostic for process fluid pulsations
US20110259095A1 (en) * 2008-12-16 2011-10-27 Mcmiles Barry J Hydraulic Signature Tester
US8240199B2 (en) * 2008-12-16 2012-08-14 Mcmiles Barry James Hydraulic signature tester
US20120283966A1 (en) * 2008-12-16 2012-11-08 Mcmiles Barry James Hydraulic Signature Tester
US9631479B2 (en) * 2008-12-16 2017-04-25 Barry James McMiles Hydraulic signature tester

Also Published As

Publication number Publication date
WO2005078237A1 (en) 2005-08-25
EP1711681A1 (en) 2006-10-18
CN1910338A (zh) 2007-02-07
RU2006131692A (ru) 2008-03-10
EP1711681B1 (en) 2008-09-03
RU2359117C2 (ru) 2009-06-20
CA2547974A1 (en) 2005-08-25
DE602005009493D1 (de) 2008-10-16
JP2007520656A (ja) 2007-07-26

Similar Documents

Publication Publication Date Title
US5201212A (en) Line leak detector and method
US10753820B2 (en) Integrity monitoring of conduits
CA2634472C (en) Downhole measurement system and method
CN103726834A (zh) 一种环空带压诊断装置及方法
EP1711681B1 (en) Annulus plugging detection using a pressure transmitter in gas-lift oil production
CN205719497U (zh) 一种安全阀性能测试及在线校验仪校验装置
EP0733892B1 (en) Method of testing pipes for leakage and leakage testing device
CN202926319U (zh) 一种环空带压诊断装置
US11604128B1 (en) Self drilling pressure simulation test device and method for formation containing natural gas hydrate
CN204153470U (zh) 基于次声波传感器和压力传感器的输气管道监控系统
CN105736953A (zh) 一种基于压力感应的带包覆层的液氨管道泄漏检测系统及其方法
KR101783563B1 (ko) 산업용 설비의 안전변 테스트 장치
JPS632458B2 (ru)
US8200048B2 (en) Measuring apparatus, venturi and venturi insertion tool
CN209603978U (zh) 一种用于深水钻井的井下测试短节
CN102392940B (zh) 埋地燃气管道严密性试验方法和系统
CN106996851A (zh) 组合式密闭容腔气压传感器标定装置
CN101113673A (zh) 防喷器安全信息数据采集装置
CN107448191A (zh) 一种煤层气井的温度和压力同步监测系统
US6840110B2 (en) Apparatus to measure differential pressure with settable pressure reference
CN202432247U (zh) 埋地燃气管道严密性试验系统
CN206876223U (zh) 一种矿用二氧化碳爆破装置测试系统
US6148854A (en) System for leak detection from underground and aboveground fuel storage tanks
CN105937391A (zh) 一种无杆泵采油井动液面自动监测装置
CN202628081U (zh) 液面仪

Legal Events

Date Code Title Description
AS Assignment

Owner name: ROSEMOUNT INC., MINNESOTA

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:KAVAKLIOGLU, KADIR;PELUSO, MARCOS;REEL/FRAME:016436/0898;SIGNING DATES FROM 20050318 TO 20050402

STCB Information on status: application discontinuation

Free format text: ABANDONED -- AFTER EXAMINER'S ANSWER OR BOARD OF APPEALS DECISION