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WO2018175508A1 - Système et méthodologie de surveillance distribuée de flux entrant - Google Patents

Système et méthodologie de surveillance distribuée de flux entrant Download PDF

Info

Publication number
WO2018175508A1
WO2018175508A1 PCT/US2018/023449 US2018023449W WO2018175508A1 WO 2018175508 A1 WO2018175508 A1 WO 2018175508A1 US 2018023449 W US2018023449 W US 2018023449W WO 2018175508 A1 WO2018175508 A1 WO 2018175508A1
Authority
WO
WIPO (PCT)
Prior art keywords
completion
recited
inductive coupler
heating
control line
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/US2018/023449
Other languages
English (en)
Inventor
Benoit Deville
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.)
Schlumberger Canada Ltd
Services Petroliers Schlumberger SA
Schlumberger Technology BV
Schlumberger Technology Corp
Original Assignee
Schlumberger Canada Ltd
Services Petroliers Schlumberger SA
Schlumberger Technology BV
Schlumberger Technology Corp
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 Schlumberger Canada Ltd, Services Petroliers Schlumberger SA, Schlumberger Technology BV, Schlumberger Technology Corp filed Critical Schlumberger Canada Ltd
Publication of WO2018175508A1 publication Critical patent/WO2018175508A1/fr
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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
    • E21B43/2401—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection by means of electricity
    • 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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/02—Couplings; joints
    • E21B17/028—Electrical or electro-magnetic connections
    • E21B17/0283—Electrical or electro-magnetic connections characterised by the coupling being contactless, e.g. inductive
    • 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
    • E21B36/00—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
    • E21B36/04—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones using electrical heaters
    • 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
    • E21B47/07—Temperature
    • 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
    • E21B47/10—Locating fluid leaks, intrusions or movements
    • E21B47/113—Locating fluid leaks, intrusions or movements using electrical indications; using light radiations

Definitions

  • Hydrocarbon fluids e.g. oil and natural gas
  • Recovery of the hydrocarbon fluids may involve drilling a well and deploying a completion system downhole in the well to facilitate the recovery process.
  • the completion system may comprise sand screen assemblies, pumping systems, well treatment systems, and/or various other systems which are deployed downhole and work in cooperation to enable the recovery of the hydrocarbon fluids.
  • a system and methodology are provided for facilitating recovery of hydrocarbon fluids such as oil.
  • a completion system is constructed for deployment downhole in a wellbore.
  • the completion system may have an upper completion, a lower completion, and an inductive coupler.
  • the overall well system may comprise a sensor system, e.g. a distributed temperature sensor system having a fiber routed along the upper completion and the lower completion to monitor temperature along at least the lower completion.
  • the well system also may comprise a heating element system, e.g. a heating cable, having an upper portion coupled to the inductive coupler and a lower portion coupled to the inductive coupler.
  • the lower portion of the heating element system may be deployed along the lower completion to provide heating along the lower completion. Based on data obtained from the distributed sensor system, adjustments may be made to the heating system and/or other downhole components to facilitate hydrocarbon recovery.
  • Figure 1 is an illustration of an example of a well system utilizing a distributed sensor system and a heating system, according to an embodiment of the disclosure
  • Figure 2 is an illustration of an example of a control line system having control line segments coupled together by a control line wet mate connector to facilitate deployment and use of the distributed sensor system, according to an embodiment of the disclosure.
  • FIG. 3 is an illustration of another example of a control line system having control line segments coupled together by a fiber wet mate connector to facilitate deployment and use of the distributed sensor system, according to an embodiment of the disclosure.
  • an overall well system has a completion system constructed for deployment downhole in a wellbore.
  • the completion system may comprise many types of completion components.
  • the completion system comprises sand screen assemblies having sand screens which may be used in combination with, for example, a gravel pack to filter particulates from inflowing well fluid, e.g. oil.
  • the completion system also may comprise at least one pumping system, e.g. at least one electric submersible pumping system, operated to pump the inflowing well fluid to a surface collection location.
  • the completion system may comprise a variety of additional or other components deployed in vertical wells or deviated wells, e.g.
  • the completion system may have an upper completion, a lower completion, and an inductive coupler.
  • the lower completion may comprise sand screen assemblies as discussed above.
  • the overall well system may comprise a sensor system, e.g. a distributed temperature sensor system or other distributed sensor system having a fiber routed along the completion system.
  • the fiber may be routed adjacent the upper completion and the lower completion.
  • the sensor system may be operated to monitor a desired parameter or parameters, e.g. temperature, along portions of the completion system.
  • a distributed sensor system may be used to monitor the desired parameter or parameters along at least the lower completion.
  • the well system also may comprise a heating element system having an upper portion coupled to the inductive coupler and a lower portion coupled to the inductive coupler.
  • the lower portion is constructed to enable the application of heat along, for example, the lower completion.
  • the heating element system comprises a heating cable having an upper portion and a lower portion.
  • the lower portion of the heating cable may be deployed along the lower completion to provide heating along the lower completion. Based on data, e.g. temperature data, obtained from the distributed sensor system, e.g. distributed
  • the distributed sensor system enables distributed inflow monitoring with respect to inflowing fluids to obtain data which may be used to determine appropriate adjustments to the system, e.g. applying increased electrical power for additional heating of inflowing oil.
  • a well system 20 is illustrated as having a completion system 22 deployed in a wellbore 24.
  • the wellbore 24 may comprise a generally vertical wellbore section 26 and a deviated wellbore section 28, e.g. a horizontal wellbore section.
  • completion system 22 comprises an upper completion 30, a lower completion 32 coupled with the upper completion 30, and an inductive coupler 34.
  • the well system 20 further comprises a sensor system 36, e.g. a distributed temperature sensor system or other distributed sensor system having a fiber 38 coupled with a control system 40.
  • the control system 40 may be a surface control system, and the fiber 38 may be routed down along the completion system 22.
  • the fiber 38 may be located within a tubular control line 42 or other suitable, protective structure.
  • other types of sensor systems may utilize a plurality of sensors deployed along the completion system 22, e.g. along the lower completion 32.
  • the well system 20 also may comprise a heating element system 44 to provide heat along, for example, lower completion 32.
  • heating system 44 comprises a heating cable 46 coupled with a power supply 48, e.g. a high-voltage power supply which is able to provide high-voltage electrical power through the heating cable 46.
  • the heating cable 46 may comprise an upper portion 50 coupled to the inductive coupler 34 and a lower portion 52 coupled to the inductive coupler 34.
  • the upper portion 50 may comprise a large gauge monocable and the lower portion 52 may be constructed as a heating element to generate a desired heat output along, for example, the lower completion 32.
  • heating cable 46 may be constructed in a variety of configurations and its lower portion 52 may comprise many types of heating elements. The heating cable 46 may be integrated into other components of completion system 22 or it may be a separate component coupled with or otherwise positioned along completion system 22.
  • the heating cable lower portion 52 may be deployed along the lower completion 32 to operate in cooperation with the distributed temperature sensor system 36 (or other suitable sensor system).
  • the heating system 44 may be operated to provide heating based on temperature data obtained from the distributed temperature sensor system 36.
  • the lower completion 32 comprises screen assemblies 54 which have screens through which well fluid flows into the lower completion 32 from a surrounding geologic formation 56.
  • the lower portion 52 may be positioned along the screen assemblies 54 to provide heat as the well fluid flows into the screen assemblies.
  • the distributed sensor system 36 may be configured for monitoring additional or other types of parameters which can be used to determine a desired heat input to be applied via the lower portion/heating element 52 [0019]
  • the power supply 48 may be operated to provide suitable electrical power through heating cable 46 so as to appropriately heat the inflowing well fluid.
  • the inflowing fluid may be heated to facilitate pumping of the well fluid to a desired collection location.
  • the distributed temperature sensor system 36 may be used to continually monitor temperature data during an operation in which heat is applied downhole via heating system 44. Continuous monitoring of the temperature of inflowing fluid also may facilitate decisions regarding other actions that may be taken to enhance the production operation.
  • the upper completion 30 may comprise various features, such as a tubing 58 combined with a feed- through packer 60 which may be set against a surrounding casing 62 or other suitable surface.
  • the upper completion 30 may be coupled with lower completion 32 via a suitable connector system 64.
  • the components of upper completion 30 (as well as lower completion 32) may be selected according to the environment and objectives of a given operation.
  • inductive coupler 34 is positioned proximate the connection between upper completion 30 and lower completion 32, e.g. proximate connector system 64.
  • the inductive coupler 34 enables the wireless transfer of electrical power and/or other electrical signals between the upper and lower completions 30, 32.
  • the wireless transfer of electrical power may be achieved via an inductive coil or coils, e.g. the illustrated inductive coils 65 and 66, of inductive coupler 34.
  • the inductive coupler 34 is able to function as a transformer and the coils 65 and 66 may serve as primary and secondary sides of the transformer.
  • the number of turns used in the respective coils 65, 66 may be different to provide, for example, a step down or step up transformer at inductive coupler 34.
  • the inductive coupler 34 may be constructed to provide a desired transformer ratio between the primary and secondary sides.
  • the heating cable upper portion 50 may be connected with inductive coupler 34 via an electrical dry mate connector 68 or other suitable connector.
  • the heating cable lower portion 50 may be connected with inductive coupler 34 via a separate electrical dry mate connector 68 or other suitable connector.
  • the tubular control line 42 of the distributed temperature sensor system 36 may be assembled via connected control line portions.
  • the tubular control line 42 comprises an upper control line portion 70 coupled with a lower control line portion 72 via control line connectors 74.
  • connectors 74 may be part of a control line wet mate (CLWM) connector system, such as CLWM systems available from Schlumberger.
  • CLWM control line wet mate
  • the fiber 38 may then be pumped through the connected control line 42.
  • the control line connectors 74 may be located in or proximate connector system 64 or at another suitable location.
  • the tubular control line 42 may be constructed as a loop formed via adjacent control line tubes coupled with a fiber U-turn 76, as further illustrated in Figure 1.
  • the fiber 38 e.g. optical fiber, may be blown down through one control line tube of the tubular control line 42, through the fiber U-turn 76, and back up through the adjacent control line tube of tubular control line 42.
  • tubular control line 42 again comprises upper control line portion 70 coupled with lower control line portion 72.
  • the control line portions 70, 72 are constructed with internal fiber and coupled via a different type of control line connectors 77.
  • the control line portions 70, 72 each contain a corresponding portion of the fiber 38 which terminates at the corresponding connector 77.
  • the connectors 77 are constructed to provide a fiber wet mate connector able to couple both the segments of fiber 38 and the surrounding tubing of control line portions 70, 72.
  • the sections of fiber 38 are prepackaged in corresponding control line portions 70, 72 and then connected via the fiber wet mate connector system when joining control line portions 70 and 72.
  • the control line connectors 77 may be located in or proximate connector system 64 or at another suitable location.
  • the distributed temperature sensor control system 40 also may comprise a light signal source 78 for directing light signals through the optical fiber 38 and a light signal receiver 80 for receiving the returning light signals.
  • the returning light signals are then processed via control system 40 to evaluate a given parameter or parameters, e.g. temperature.
  • the control system 40 may be used to process data indicating temperature and temperature changes along the optical fiber 38.
  • the power supply 48 may be operated to provide the desired electrical power and thus the desired heat at locations downhole, e.g. along lower completion 32.
  • control system 40 and heating system 44 may be operatively coupled to enable automated adjustments.
  • the control system 40 may process data obtained from sensor system 36 and, based on that processed data, perform automatic adjustments with respect to the downhole heating and/or with respect to operation of other downhole devices. Automatic adjustments to the electrical power delivered to lower portion 52 (and thus to the heat applied via lower portion 52) may be based on, for example, the temperatures monitored via distributed temperature sensor system 36.
  • the heating cable 46 may be terminated to the completion system 22 via a heating cable termination 82.
  • the heating cable 46 may be grounded to lower completion 32 or to another suitable portion of completion system 22 via termination 82.
  • the termination may be achieved by forming the heating cable 46 with multiple cables routed through U-turns.
  • inductive couplers 34 may be constructed to enable the wireless transfer of electrical power between sections of the completion system 22, e.g. between the upper completion 30 and the lower completion 32.
  • the inductive coupler 34 may have different numbers of turns at the primary and secondary to allow, for example, stepping down of the voltage while having more current circulating in the heating cable 46.
  • the power supply 48 also may be constructed to supply suitable voltages for a given heating operation, e.g. voltages above 1000 V, above 2000 V, above 3000 V, or at other suitable voltages.
  • the heating cable 46 may be selected according to the environment in which it is utilized and according to the power/voltage supplied downhole via power supply 44. In some applications, the impedance of the heating cable 46 may determine the choice of voltage suitable for the inductive coupler 34, e.g. suitable for an inductive coupler secondary. Additionally, the sensor system 36, e.g. distributed temperature sensor system, and the heating system 44 may be used in cooperation to achieve various types of control over well operations, e.g. control over flow in production operations. Various types of optical fibers, tubular control lines, connectors, terminations, and/or other components may be selected according to the parameters of a given operation.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (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)
  • Mechanical Engineering (AREA)
  • Measuring Temperature Or Quantity Of Heat (AREA)

Abstract

Cette invention concerne une technique qui facilite la récupération de fluides hydrocarbonés tels que le pétrole. Un système de puits comprend un système de complétion ayant une complétion supérieure, une complétion inférieure et un coupleur inductif. De plus, le système de puits dans son ensemble peut comprendre un système de capteur, par exemple un système de capteur distribué ayant une fibre acheminée le long de la complétion supérieure et de la complétion inférieure pour surveiller la température et/ou d'autres paramètres. Le système de puits peut également comprendre un système de chauffage ayant une partie supérieure couplée au coupleur inductif et une partie inférieure couplée au coupleur inductif. La partie inférieure peut être déployée le long de la complétion inférieure pour fournir de la chaleur. Sur la base de données, par exemple des données de température, obtenues à partir du système de capteur, des réglages peuvent être apportés au système de chauffage et/ou à d'autres composants de fond de trou pour faciliter la récupération d'hydrocarbures.
PCT/US2018/023449 2017-03-21 2018-03-21 Système et méthodologie de surveillance distribuée de flux entrant Ceased WO2018175508A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201762474425P 2017-03-21 2017-03-21
US62/474,425 2017-03-21

Publications (1)

Publication Number Publication Date
WO2018175508A1 true WO2018175508A1 (fr) 2018-09-27

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Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2024192396A3 (fr) * 2023-03-15 2025-09-12 Halliburton Energy Services, Inc. Système de puits comprenant une chaîne de complétion inférieure dotée d'une pluralité de capteurs répartis le long d'au moins une partie de celle-ci

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6497279B1 (en) * 1998-08-25 2002-12-24 Sensor Highway Limited Method of using a heater with a fiber optic string in a wellbore
US6564011B1 (en) * 2000-08-23 2003-05-13 Fmc Technologies, Inc. Self-regulating heat source for subsea equipment
US20100101786A1 (en) * 2007-03-19 2010-04-29 Schlumberger Technology Corporation Method and system for placing sensor arrays and control assemblies in a completion
US20120138310A1 (en) * 2010-12-07 2012-06-07 Baker Hughes Incorporated Stackable multi-barrier system and method
US20150013962A1 (en) * 2013-04-12 2015-01-15 Pablo Javier INVIERNO Heating cable for extraction pipes of viscous hydrocarbons or paraffinic in conventional wells and type tight wells, vertical or directional, with flooded annular in casual or permanent form, suitable for use between low and high fluid pressures ranges

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6497279B1 (en) * 1998-08-25 2002-12-24 Sensor Highway Limited Method of using a heater with a fiber optic string in a wellbore
US6564011B1 (en) * 2000-08-23 2003-05-13 Fmc Technologies, Inc. Self-regulating heat source for subsea equipment
US20100101786A1 (en) * 2007-03-19 2010-04-29 Schlumberger Technology Corporation Method and system for placing sensor arrays and control assemblies in a completion
US20120138310A1 (en) * 2010-12-07 2012-06-07 Baker Hughes Incorporated Stackable multi-barrier system and method
US20150013962A1 (en) * 2013-04-12 2015-01-15 Pablo Javier INVIERNO Heating cable for extraction pipes of viscous hydrocarbons or paraffinic in conventional wells and type tight wells, vertical or directional, with flooded annular in casual or permanent form, suitable for use between low and high fluid pressures ranges

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2024192396A3 (fr) * 2023-03-15 2025-09-12 Halliburton Energy Services, Inc. Système de puits comprenant une chaîne de complétion inférieure dotée d'une pluralité de capteurs répartis le long d'au moins une partie de celle-ci

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