WO2010064919A1 - A downhole pressure and vibration measuring device integrated in a pipe section as a part of a production tubing - Google Patents

A downhole pressure and vibration measuring device integrated in a pipe section as a part of a production tubing Download PDF

Info

Publication number
WO2010064919A1
WO2010064919A1 PCT/NO2009/000399 NO2009000399W WO2010064919A1 WO 2010064919 A1 WO2010064919 A1 WO 2010064919A1 NO 2009000399 W NO2009000399 W NO 2009000399W WO 2010064919 A1 WO2010064919 A1 WO 2010064919A1
Authority
WO
WIPO (PCT)
Prior art keywords
production tubing
measuring device
sensor housing
strain gauges
pipe section
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.)
Ceased
Application number
PCT/NO2009/000399
Other languages
French (fr)
Inventor
Egil Eriksen
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.)
Tool Tech AS
Original Assignee
Tool Tech AS
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
Family has litigation
First worldwide family litigation filed litigation Critical https://patents.darts-ip.com/?family=42233421&utm_source=google_patent&utm_medium=platform_link&utm_campaign=public_patent_search&patent=WO2010064919(A1) "Global patent litigation dataset” by Darts-ip is licensed under a Creative Commons Attribution 4.0 International License.
Application filed by Tool Tech AS filed Critical Tool Tech AS
Priority to AU2009323067A priority Critical patent/AU2009323067B2/en
Priority to US13/132,072 priority patent/US8701480B2/en
Priority to BRPI0916469-3A priority patent/BRPI0916469B1/en
Priority to EP09830626.9A priority patent/EP2352902B1/en
Publication of WO2010064919A1 publication Critical patent/WO2010064919A1/en
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

Links

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
    • E21B47/01—Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
    • 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 invention relates to a downhole pressure and vibration measuring device integrated in a pipe section as part of a production tubing, as defined in the introduction of the accompanying claim 1.
  • Downhole instrumentation is used to acquire measuring data in production wells and is an important tool for the optimal control of the production.
  • the reliability of the downhole meters is poor in high temperatures, typically 110 0 C or higher.
  • a rule of thumb says that the error rate is doubled for every ten degrees 1 increase in temperature.
  • Modern measuring systems are typically silicone, sapphire or quartz sensors with electronics.
  • a large number of downhole electronic measuring systems have been installed during the last twenty years, and many studies have been carried out to evaluate the reliability of this type of equipment.
  • Measuring instruments with capillary tubes are used primarily for pressure measuring with inert gas, like nitrogen and helium, and in combinations with optical -fibre temperature measurement. Faults may arise by particles blocking bubble tubes, for example through gas leakages, and when pressure chambers are undersized, so that oil will enter gas tubes.
  • the invention of the application is substantially different from the two mentioned above, with respect to object, embodiment as well as function.
  • the present application relates to a downhole pressure and vibration measuring device integrated in a pipe section as part of a production tubing, and the measuring device is characterized by the characteristics set forth in claims.
  • the object of the invention is to provide a system which is robust in relation to temperature and vibration and has the following functionality:
  • Figure 1 shows a strain gauge monitoring system which is mounted on a pipe section inserted as part of a production tubing 20 in an oil or gas well, sensing the surface strain from pressure inside the production tubing and surface strain from external pressure in the annulus between the production tubing and the casing in the well.
  • Figure IA is a 3D drawing which, viewed from the outside, shows the measuring device installed.
  • Figure IB shows a longitudinal section of the measuring device.
  • Figure 1C is a 3D detail of the insides of a sensor housing.
  • Figure ID shows a longitudinal section of a cable termination in detail.
  • the main parts of the measuring device are a pipe section 1 with a conical part which is joined to a sensor housing 2 and a two-part clamp 3 on the upper end, which protects at least four, and preferably six, glass penetrators 4 connecting corresponding strain gauges 7 and 8 to cable connections inside cable tubes 9A extending up along the production tubing 20 in a multi -conductor cable connection 10 to electrical bushings in the tubing hanger 21 of the well.
  • the sensor housing 2 forms a tight annular space 5 filled through a filling channel 6 with an inert gas, preferably nitrogen, in the annular space 5 between the external sensor housing 2 and the pipe section 1.
  • the sensor housing 2 protects strain gauges 7, 8 evenly spaced radially on the inside of the sensor housing.
  • the strain gauges 7, 8 are preferably fixed with glue that can stand at least 250 0 C on the inside wall of the sensor housing 2 and the outside wall of the production tubing section 1, respectively, so that both the internal pressure and the external pressure acting on the production tubing 20 are measured.
  • a temperature measurement device may be integrated and signals be carried to the control equipment 11, 12 in a manner corresponding to that of the strain gauge measurements .
  • the measuring device is connected to the control unit 11 for signal amplification via electrical conductors encased in cable tubes 9A, which are clamped to the production tubing 20 downhole and terminated in the tubing hanger 21 of the well equipment with an electrical multi -conductor cable connection 10 to an electronics unit in the control equipment 11, connected to a control and communication module in the control unit 12 on the outside of the wellhead equipment.
  • the glass penetrators 4 are provided with an external threaded portion and are screwed in through threaded holes in the top of the sensor housing 2, so that external gaskets 4B seal against the material of the upper end of the sensor housing 2 when screwed all the way in.
  • An external tube nut 9C is threaded onto each of the cable tubes 9A before short tube subs 9B with collars on their tubes are welded to the end of the respective tubes 9A by EB (electron beam) welds.
  • the cable tubes 9A come on drums and are terminated on the glass penetrators 4 of the measuring device as part of the installation.
  • Cable termination means that the conductors projecting at each cable tube end 9B are soldered to the pins 4C of the corresponding glass penetrators 4.
  • the tube sub 9B is inserted into the upper end of the glass penetrator 4 until the collar of the tube sub 9B rests on the upper edge of the glass penetrator 4. Gaskets 4D internally at the top of the glass penetrator 4 seal against the tube end 9B.
  • the tube nut 9C is screwed onto the external threaded portion at the top of the glass penetrator 4 until it presses the collar of the tube sub 9B against the abutment surface on the top of the glass penetrator 4, the cable tube 9A thereby being anchored to the glass penetrator 4.
  • the pressure- measurement signals received from the strain-gauge-based sensors are processed, also to measure vibration in the production tubing 20.
  • Figure 2 shows a schematic side view of a subsea production well, in which a production tubing 20 with a strain-gauge- based measuring device in a sensor housing 2 and a downhole safety valve 22 extends up to a horizontal wellhead 23.

Landscapes

  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Mining & Mineral Resources (AREA)
  • Geophysics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Measuring Fluid Pressure (AREA)
  • Geophysics And Detection Of Objects (AREA)
  • Measurement Of Mechanical Vibrations Or Ultrasonic Waves (AREA)

Abstract

The invention relates to a downhole pressure- and vibration- measuring device integrated in a pipe section (1) as part of a production tubing (20). The sensor housing (2) of the measuring device with sensors has a two-part clamp (3) on the upper part of the sensor housing (2), from where an electrical multi- conductor cable connection (10) from at least four, preferably six, nipples in a tube (9) is clamped along the production tubing (20) with bushings through equipment installed in the wellhead to sensors with an electronics and control unit (12) above the wellhead. Evenly- spaced radially in an annular space (5) are a first set of strain gauges (7) attached to the outside wall of the production tubing (20) and a second set of strain gauges (8) attached on the inside of the external wall of the sensor housing (2). Strain gauges (7, 8) are connected by glass penetrators (4) of electrical conductors in cable tubes (9A) terminated in the tubing hanger (21) to an electronics unit (11) and a control unit (12). For the measuring of temperatures, a thermometer will be integrated. Pressure -measurement signals also measure vibration in the production tubing (20).

Description

A DOWNHOLE PRESSURE AND VIBRATION MEASURING DEVICE INTEGRATED IN A PIPE SECTION AS A PART OF A PRODUCTION TUBING
The invention relates to a downhole pressure and vibration measuring device integrated in a pipe section as part of a production tubing, as defined in the introduction of the accompanying claim 1.
Downhole instrumentation is used to acquire measuring data in production wells and is an important tool for the optimal control of the production. The reliability of the downhole meters is poor in high temperatures, typically 110 0C or higher. A rule of thumb says that the error rate is doubled for every ten degrees1 increase in temperature.
The reduced life of downhole instrumentation in oil and gas wells because of high temperatures is a large problem. In practice, the expenses of a well intervention are too large for malfunctioning downhole instrumentation to be replaced. This is true for subsea wells in particular. Over time, a loss of this instrumentation function may have economic consequences in that the control of the well is not optimal.
Modern measuring systems are typically silicone, sapphire or quartz sensors with electronics. A large number of downhole electronic measuring systems have been installed during the last twenty years, and many studies have been carried out to evaluate the reliability of this type of equipment. One evaluation revealed that only 88 % of the installations were still functioning after four years in operation, and a trend showed a drop of 3 % per year, indicating that 1/3 of the wells would have lost their downhole monitoring by the end of the well's life.
Other downhole measuring systems are optical -fibre measuring instruments, which can stand high temperatures but are attacked by hydrogen, which blackens the fibres. Measuring instruments with capillary tubes are used primarily for pressure measuring with inert gas, like nitrogen and helium, and in combinations with optical -fibre temperature measurement. Faults may arise by particles blocking bubble tubes, for example through gas leakages, and when pressure chambers are undersized, so that oil will enter gas tubes.
From the patent literature are cited as the background art:
- US 5,226,494 disclosing a downhole tool, in which strain gauges are to register applied forces to initiate a downhole function without using ports in the production tubing or the work string, a method being sought for the reliable activation of the function from the surface. Changes in signals from the strain gauges mounted on a tubular part included in the tool on mechanical influence may be recorded by downhole electronics, and when an activating sequence of influence is recognized, the electronics will release energy stored in the tool, which performs a desired tool . function.
- US 6,384,738 disclosing an invention with the same object.
The invention of the application is substantially different from the two mentioned above, with respect to object, embodiment as well as function.
The present application relates to a downhole pressure and vibration measuring device integrated in a pipe section as part of a production tubing, and the measuring device is characterized by the characteristics set forth in claims.
The object of the invention is to provide a system which is robust in relation to temperature and vibration and has the following functionality:
- measuring internal pressure in the production tubing
- measuring pressure in the annulus between the production tubing and casing of the well
- measuring temperature - measuring vibration
Figure 1 shows a strain gauge monitoring system which is mounted on a pipe section inserted as part of a production tubing 20 in an oil or gas well, sensing the surface strain from pressure inside the production tubing and surface strain from external pressure in the annulus between the production tubing and the casing in the well.
Figure IA is a 3D drawing which, viewed from the outside, shows the measuring device installed.
Figure IB shows a longitudinal section of the measuring device.
Figure 1C is a 3D detail of the insides of a sensor housing; and
Figure ID shows a longitudinal section of a cable termination in detail.
The main parts of the measuring device are a pipe section 1 with a conical part which is joined to a sensor housing 2 and a two-part clamp 3 on the upper end, which protects at least four, and preferably six, glass penetrators 4 connecting corresponding strain gauges 7 and 8 to cable connections inside cable tubes 9A extending up along the production tubing 20 in a multi -conductor cable connection 10 to electrical bushings in the tubing hanger 21 of the well.
With seals 2A/B, the sensor housing 2 forms a tight annular space 5 filled through a filling channel 6 with an inert gas, preferably nitrogen, in the annular space 5 between the external sensor housing 2 and the pipe section 1. The sensor housing 2 protects strain gauges 7, 8 evenly spaced radially on the inside of the sensor housing. The strain gauges 7, 8 are preferably fixed with glue that can stand at least 250 0C on the inside wall of the sensor housing 2 and the outside wall of the production tubing section 1, respectively, so that both the internal pressure and the external pressure acting on the production tubing 20 are measured.
A temperature measurement device may be integrated and signals be carried to the control equipment 11, 12 in a manner corresponding to that of the strain gauge measurements .
The measuring device is connected to the control unit 11 for signal amplification via electrical conductors encased in cable tubes 9A, which are clamped to the production tubing 20 downhole and terminated in the tubing hanger 21 of the well equipment with an electrical multi -conductor cable connection 10 to an electronics unit in the control equipment 11, connected to a control and communication module in the control unit 12 on the outside of the wellhead equipment.
There are wires extending between the strain gauges 7, 8 and the pins 4A of the glass penetrators 4 which extend through the upper end of the sensor housing 2.
The glass penetrators 4 are provided with an external threaded portion and are screwed in through threaded holes in the top of the sensor housing 2, so that external gaskets 4B seal against the material of the upper end of the sensor housing 2 when screwed all the way in. An external tube nut 9C is threaded onto each of the cable tubes 9A before short tube subs 9B with collars on their tubes are welded to the end of the respective tubes 9A by EB (electron beam) welds. The cable tubes 9A come on drums and are terminated on the glass penetrators 4 of the measuring device as part of the installation.
Cable termination means that the conductors projecting at each cable tube end 9B are soldered to the pins 4C of the corresponding glass penetrators 4. The tube sub 9B is inserted into the upper end of the glass penetrator 4 until the collar of the tube sub 9B rests on the upper edge of the glass penetrator 4. Gaskets 4D internally at the top of the glass penetrator 4 seal against the tube end 9B. Finally, the tube nut 9C is screwed onto the external threaded portion at the top of the glass penetrator 4 until it presses the collar of the tube sub 9B against the abutment surface on the top of the glass penetrator 4, the cable tube 9A thereby being anchored to the glass penetrator 4.
By means of a special piece of software, the pressure- measurement signals received from the strain-gauge-based sensors are processed, also to measure vibration in the production tubing 20.
There is no form of electronics placed in the well.
Figure 2 shows a schematic side view of a subsea production well, in which a production tubing 20 with a strain-gauge- based measuring device in a sensor housing 2 and a downhole safety valve 22 extends up to a horizontal wellhead 23.

Claims

C l a i m s
1. A downhole pressure and vibration measuring device integrated in a pipe section (1) as part of a production tubing (20) , the measuring device being constituted by a sensor housing (2) with sensors and a two-part clamp (3) on the upper part of the sensor housing (2) , from where an electrical multi -conductor cable connection (10) from at least four, preferably six, nipples in cable tubes (9A) is clamped along the production tubing (20) with bushings through equipment installed in the wellhead to an electronics/amplifier unit (11) and a control unit (12) above the wellhead, c h a r a c t e r i z e d i n that the sensor housing (2) forms an annular space (5) around the pipe section (1) and is filled with an inert gas, preferably nitrogen; that evenly spaced radially in the annular space (5) are a first set of strain gauges (7) attached to the outside wall of the production tubing (20) and a second set of strain gauges (8) attached to the inside of the external wall of the sensor housing (2); that the strain gauges (7, 8) are connected by glass penetrators (4) to electrical conductors in cable tubes (9A), which are terminated in the tubing hanger (21) of the well equipment, to an electronics unit (11) and a control unit (12) .
2. The downhole pressure and vibration measuring device according to claim 1, c h a r a c t e r i z e d i n that for the measurement of temperatures, a thermometer will be integrated, and that vibration in the production tubing will be measured through the pressure-measurement signals.
PCT/NO2009/000399 2008-12-02 2009-11-20 A downhole pressure and vibration measuring device integrated in a pipe section as a part of a production tubing Ceased WO2010064919A1 (en)

Priority Applications (4)

Application Number Priority Date Filing Date Title
AU2009323067A AU2009323067B2 (en) 2008-12-02 2009-11-20 A downhole pressure and vibration measuring device integrated in a pipe section as a part of a production tubing
US13/132,072 US8701480B2 (en) 2008-12-02 2009-11-20 Downhole pressure and vibration measuring device integrated in a pipe section as a part of a production tubing
BRPI0916469-3A BRPI0916469B1 (en) 2008-12-02 2009-11-20 VIBRATION AND PRESSURE MEASUREMENT DEVICE IN A WELL INTEGRATED IN A SECTION OF THE TUBE AS PART OF A PRODUCTION PIPING
EP09830626.9A EP2352902B1 (en) 2008-12-02 2009-11-20 A downhole pressure and vibration measuring device integrated in a pipe section as a part of a production tubing

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
NO20085042 2008-12-02
NO20085042A NO334024B1 (en) 2008-12-02 2008-12-02 Nedihull's pressure and vibration measuring device integrated in a pipe section as part of a production pipe

Publications (1)

Publication Number Publication Date
WO2010064919A1 true WO2010064919A1 (en) 2010-06-10

Family

ID=42233421

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/NO2009/000399 Ceased WO2010064919A1 (en) 2008-12-02 2009-11-20 A downhole pressure and vibration measuring device integrated in a pipe section as a part of a production tubing

Country Status (6)

Country Link
US (1) US8701480B2 (en)
EP (1) EP2352902B1 (en)
AU (1) AU2009323067B2 (en)
BR (1) BRPI0916469B1 (en)
NO (1) NO334024B1 (en)
WO (1) WO2010064919A1 (en)

Families Citing this family (41)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2014100274A1 (en) 2012-12-19 2014-06-26 Exxonmobil Upstream Research Company Apparatus and method for detecting fracture geometry using acoustic telemetry
WO2014100262A1 (en) 2012-12-19 2014-06-26 Exxonmobil Upstream Research Company Telemetry for wireless electro-acoustical transmission of data along a wellbore
WO2014100269A1 (en) 2012-12-19 2014-06-26 Exxonmobil Upstream Research Company Apparatus and method for evaluating cement integrity in a wellbore using acoustic telemetry
WO2014100272A1 (en) 2012-12-19 2014-06-26 Exxonmobil Upstream Research Company Apparatus and method for monitoring fluid flow in a wellbore using acoustic signals
US9631485B2 (en) 2012-12-19 2017-04-25 Exxonmobil Upstream Research Company Electro-acoustic transmission of data along a wellbore
US10100635B2 (en) 2012-12-19 2018-10-16 Exxonmobil Upstream Research Company Wired and wireless downhole telemetry using a logging tool
US9121261B2 (en) * 2013-02-20 2015-09-01 Halliburton Energy Services, Inc. Coiled tubing system with multiple integral pressure sensors and DTS
US10132149B2 (en) 2013-11-26 2018-11-20 Exxonmobil Upstream Research Company Remotely actuated screenout relief valves and systems and methods including the same
US9777557B2 (en) * 2014-05-14 2017-10-03 Baker Hughes Incorporated Apparatus and method for operating a device in a wellbore using signals generated in response to strain on a downhole member
CA2955381C (en) 2014-09-12 2022-03-22 Exxonmobil Upstream Research Company Discrete wellbore devices, hydrocarbon wells including a downhole communication network and the discrete wellbore devices and systems and methods including the same
CN104316280B (en) * 2014-11-17 2016-10-26 合肥江航飞机装备有限公司 The rolling of the plug-in auxiliary fuel tank of aircraft is shaken test fixture
US9932815B2 (en) * 2014-12-05 2018-04-03 Schlumberger Technology Corporation Monitoring tubing related equipment
US9863222B2 (en) 2015-01-19 2018-01-09 Exxonmobil Upstream Research Company System and method for monitoring fluid flow in a wellbore using acoustic telemetry
US10408047B2 (en) 2015-01-26 2019-09-10 Exxonmobil Upstream Research Company Real-time well surveillance using a wireless network and an in-wellbore tool
WO2018026348A1 (en) * 2016-08-01 2018-02-08 Halliburton Energy Services, Inc. Instrumented tube for measuring flow from a wellbore blowout
US10364669B2 (en) 2016-08-30 2019-07-30 Exxonmobil Upstream Research Company Methods of acoustically communicating and wells that utilize the methods
US10697287B2 (en) 2016-08-30 2020-06-30 Exxonmobil Upstream Research Company Plunger lift monitoring via a downhole wireless network field
US10590759B2 (en) 2016-08-30 2020-03-17 Exxonmobil Upstream Research Company Zonal isolation devices including sensing and wireless telemetry and methods of utilizing the same
US10344583B2 (en) 2016-08-30 2019-07-09 Exxonmobil Upstream Research Company Acoustic housing for tubulars
US10415376B2 (en) 2016-08-30 2019-09-17 Exxonmobil Upstream Research Company Dual transducer communications node for downhole acoustic wireless networks and method employing same
US10526888B2 (en) 2016-08-30 2020-01-07 Exxonmobil Upstream Research Company Downhole multiphase flow sensing methods
US10465505B2 (en) 2016-08-30 2019-11-05 Exxonmobil Upstream Research Company Reservoir formation characterization using a downhole wireless network
US10487647B2 (en) 2016-08-30 2019-11-26 Exxonmobil Upstream Research Company Hybrid downhole acoustic wireless network
US10697288B2 (en) 2017-10-13 2020-06-30 Exxonmobil Upstream Research Company Dual transducer communications node including piezo pre-tensioning for acoustic wireless networks and method employing same
WO2019074657A1 (en) 2017-10-13 2019-04-18 Exxonmobil Upstream Research Company Method and system for performing operations using communications
CA3079020C (en) 2017-10-13 2022-10-25 Exxonmobil Upstream Research Company Method and system for performing communications using aliasing
US11035226B2 (en) 2017-10-13 2021-06-15 Exxomobil Upstream Research Company Method and system for performing operations with communications
US10837276B2 (en) 2017-10-13 2020-11-17 Exxonmobil Upstream Research Company Method and system for performing wireless ultrasonic communications along a drilling string
CA3078824C (en) 2017-10-13 2022-08-16 Exxonmobil Upstream Research Company Method and system for performing hydrocarbon operations with mixed communication networks
AU2018367388C1 (en) 2017-11-17 2022-04-14 Exxonmobil Upstream Research Company Method and system for performing wireless ultrasonic communications along tubular members
US12000273B2 (en) 2017-11-17 2024-06-04 ExxonMobil Technology and Engineering Company Method and system for performing hydrocarbon operations using communications associated with completions
US10690794B2 (en) 2017-11-17 2020-06-23 Exxonmobil Upstream Research Company Method and system for performing operations using communications for a hydrocarbon system
US10844708B2 (en) 2017-12-20 2020-11-24 Exxonmobil Upstream Research Company Energy efficient method of retrieving wireless networked sensor data
US11156081B2 (en) 2017-12-29 2021-10-26 Exxonmobil Upstream Research Company Methods and systems for operating and maintaining a downhole wireless network
AU2018397574A1 (en) 2017-12-29 2020-06-11 Exxonmobil Upstream Research Company (Emhc-N1-4A-607) Methods and systems for monitoring and optimizing reservoir stimulation operations
WO2019156966A1 (en) 2018-02-08 2019-08-15 Exxonmobil Upstream Research Company Methods of network peer identification and self-organization using unique tonal signatures and wells that use the methods
US11268378B2 (en) 2018-02-09 2022-03-08 Exxonmobil Upstream Research Company Downhole wireless communication node and sensor/tools interface
US11952886B2 (en) 2018-12-19 2024-04-09 ExxonMobil Technology and Engineering Company Method and system for monitoring sand production through acoustic wireless sensor network
US11293280B2 (en) 2018-12-19 2022-04-05 Exxonmobil Upstream Research Company Method and system for monitoring post-stimulation operations through acoustic wireless sensor network
NO347015B1 (en) * 2021-05-21 2023-04-03 Nor Oil Tools As Tool
DE102024118834A1 (en) 2024-07-03 2026-01-08 Ifm Electronic Gmbh Clamp-on pressure gauge

Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6055213A (en) * 1990-07-09 2000-04-25 Baker Hughes Incorporated Subsurface well apparatus
US6435030B1 (en) * 1999-06-25 2002-08-20 Weatherford/Lamb, Inc. Measurement of propagating acoustic waves in compliant pipes

Family Cites Families (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3713334A (en) * 1971-01-25 1973-01-30 R Vann Downhole recorder device for logging boreholes
US4144768A (en) * 1978-01-03 1979-03-20 The Boeing Company Apparatus for analyzing complex acoustic fields within a duct
US4805449A (en) * 1987-12-01 1989-02-21 Anadrill, Inc. Apparatus and method for measuring differential pressure while drilling
US5343963A (en) * 1990-07-09 1994-09-06 Bouldin Brett W Method and apparatus for providing controlled force transference to a wellbore tool
US5226494A (en) * 1990-07-09 1993-07-13 Baker Hughes Incorporated Subsurface well apparatus
EP1523607B1 (en) * 2002-07-23 2011-08-24 Welldynamics, B.V. Subterranean well pressure and temperature measurement
US6957574B2 (en) * 2003-05-19 2005-10-25 Weatherford/Lamb, Inc. Well integrity monitoring system
US6802215B1 (en) * 2003-10-15 2004-10-12 Reedhyealog L.P. Apparatus for weight on bit measurements, and methods of using same
US20050103123A1 (en) * 2003-11-14 2005-05-19 Newman Kenneth R. Tubular monitor systems and methods
US7878266B2 (en) * 2007-08-24 2011-02-01 Halliburton Energy Services, Inc. Downhole force measurement

Patent Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6055213A (en) * 1990-07-09 2000-04-25 Baker Hughes Incorporated Subsurface well apparatus
US6435030B1 (en) * 1999-06-25 2002-08-20 Weatherford/Lamb, Inc. Measurement of propagating acoustic waves in compliant pipes

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
See also references of EP2352902A4 *

Also Published As

Publication number Publication date
EP2352902A4 (en) 2017-03-29
BRPI0916469A2 (en) 2019-11-05
BRPI0916469B1 (en) 2020-09-15
NO334024B1 (en) 2013-11-18
US8701480B2 (en) 2014-04-22
EP2352902A1 (en) 2011-08-10
AU2009323067B2 (en) 2013-01-24
US20120024052A1 (en) 2012-02-02
EP2352902B1 (en) 2018-01-31
NO20085042L (en) 2010-06-03
AU2009323067A1 (en) 2011-07-07

Similar Documents

Publication Publication Date Title
EP2352902B1 (en) A downhole pressure and vibration measuring device integrated in a pipe section as a part of a production tubing
US4976142A (en) Borehole pressure and temperature measurement system
AU2012325240B2 (en) Methods for installing and retrieving a well monitoring apparatus
US5163321A (en) Borehole pressure and temperature measurement system
CN107290233B (en) Oil-gas well explosion perforating string mechanical experiment device and experiment method
CN205605197U (en) Downhole near-bit multi-parameter measuring device
US20100212396A1 (en) Downhole sensor apparatus and method
US9932815B2 (en) Monitoring tubing related equipment
CN105352635B (en) Underground coal and rock space built-in type three-dimensional stress monitoring system and monitoring method
US20150323700A1 (en) In-Situ System Calibration
US9121261B2 (en) Coiled tubing system with multiple integral pressure sensors and DTS
CN101025083A (en) Experiment method for packer working performance and apparatus thereof
CN114109351B (en) Downhole drilling pressure torque measurement tool
CN202832497U (en) Pressure-holding diagnostic apparatus of pumping unit well system
CN209308680U (en) A kind of compound logging sensor of optical fiber-electronics
CN210264664U (en) Direct-reading and storage integrated noise logging instrument
JPH04189998A (en) Well pressure and temperature measuring device
CN118148624A (en) Sapphire optical fiber sensor for underground temperature and pressure measurement
CN114325816A (en) A downhole detection device
CN218324841U (en) A Downhole Temperature and Pressure Monitoring System Based on Sapphire Optical Fiber Sensor
AU2010365399B2 (en) Sensing shock during well perforating
JPH03161608A (en) Measuring device for multistage type boring-pit inside pressure
CN119195730A (en) A drilling-while-drilling engineering parameter measurement system for coal mines
CN120968581A (en) Underground storage type pressure and temperature monitoring device
CN115853499A (en) Well completion pipe string for gas storage injection and production well

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 09830626

Country of ref document: EP

Kind code of ref document: A1

WWE Wipo information: entry into national phase

Ref document number: 2009830626

Country of ref document: EP

NENP Non-entry into the national phase

Ref country code: DE

WWE Wipo information: entry into national phase

Ref document number: 2009323067

Country of ref document: AU

ENP Entry into the national phase

Ref document number: 2009323067

Country of ref document: AU

Date of ref document: 20091120

Kind code of ref document: A

WWE Wipo information: entry into national phase

Ref document number: 13132072

Country of ref document: US

REG Reference to national code

Ref country code: BR

Ref legal event code: B01E

Ref document number: PI0916469

Country of ref document: BR

Free format text: COMPROVE QUE O SIGNATARIO ALBA ROSA LOPEZ PARADA DA PETICAO NO 018110019836 DE 27/05/2011 TEM PODERES PARA ATUAR EM NOME DO DEPOSITANTE, UMA VEZ ESTE NAO FOI CONSTITUIDO E NOMEADO NA PROCURACAO APRESENTADA E QUE BASEADO NO ARTIGO 216 DA LEI 9.279/1996 DE 14/05/1996 (LPI) OS ATOS PREVISTOS NESTA LEI SERAO PRATICADOS PELAS PARTES OU POR SEUS PROCURADORES, DEVIDAMENTE QUALIFICADOS .

ENPW Started to enter national phase and was withdrawn or failed for other reasons

Ref document number: PI0916469

Country of ref document: BR

ENPZ Former announcement of the withdrawal of the entry into the national phase was wrong

Ref document number: PI0916469

Country of ref document: BR

Kind code of ref document: A2

Free format text: EM ATENDIMENTO A DECISAO RECURSAL PUBLICADA NA RPI 2511, DE 19/02/2019, FICA ANULADA A PUBLICACAO DO CODIGO 1.2 DA RPI NO 2421, DE 30/05/2017.

ENP Entry into the national phase

Ref document number: PI0916469

Country of ref document: BR

Kind code of ref document: A2

Effective date: 20110527