GB2511019A - Estimating flow rates from multiple hydrocarbon reservoir layers into a production well - Google Patents

Estimating flow rates from multiple hydrocarbon reservoir layers into a production well Download PDF

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Publication number
GB2511019A
GB2511019A GB1410602.5A GB201410602A GB2511019A GB 2511019 A GB2511019 A GB 2511019A GB 201410602 A GB201410602 A GB 201410602A GB 2511019 A GB2511019 A GB 2511019A
Authority
GB
United Kingdom
Prior art keywords
annulus
fluid
temperature
production well
central tubing
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.)
Withdrawn
Application number
GB1410602.5A
Other versions
GB201410602D0 (en
Inventor
Andrew William Woods
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.)
BP Exploration Operating Co Ltd
Original Assignee
BP Exploration Operating Co Ltd
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 BP Exploration Operating Co Ltd filed Critical BP Exploration Operating Co Ltd
Publication of GB201410602D0 publication Critical patent/GB201410602D0/en
Publication of GB2511019A publication Critical patent/GB2511019A/en
Withdrawn legal-status Critical Current

Links

Classifications

    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
    • G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
    • G01F1/68—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by using thermal effects
    • G01F1/684—Structural arrangements; Mounting of elements, e.g. in relation to fluid flow
    • G01F1/688—Structural arrangements; Mounting of elements, e.g. in relation to fluid flow using a particular type of heating, cooling or sensing element
    • G01F1/6884—Structural arrangements; Mounting of elements, e.g. in relation to fluid flow using a particular type of heating, cooling or sensing element making use of temperature dependence of optical properties
    • 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
    • E21B47/02—Determining slope or direction
    • E21B47/026—Determining slope or direction of penetrated ground layers
    • 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
    • E21B47/103—Locating fluid leaks, intrusions or movements using thermal measurements
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
    • G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
    • G01F1/704—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow using marked regions or existing inhomogeneities within the fluid stream, e.g. statistically occurring variations in a fluid parameter
    • G01F1/7044—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow using marked regions or existing inhomogeneities within the fluid stream, e.g. statistically occurring variations in a fluid parameter using thermal tracers
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
    • G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
    • G01F1/704—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow using marked regions or existing inhomogeneities within the fluid stream, e.g. statistically occurring variations in a fluid parameter
    • G01F1/708—Measuring the time taken to traverse a fixed distance
    • G01F1/7084—Measuring the time taken to traverse a fixed distance using thermal detecting arrangements
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01F—MEASURING VOLUME, VOLUME FLOW, MASS FLOW OR LIQUID LEVEL; METERING BY VOLUME
    • G01F1/00—Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
    • G01F1/74—Devices for measuring flow of a fluid or flow of a fluent solid material in suspension in another fluid

Landscapes

  • Physics & Mathematics (AREA)
  • Fluid Mechanics (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • General Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Geophysics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Measuring Temperature Or Quantity Of Heat (AREA)
  • Geophysics And Detection Of Objects (AREA)

Abstract

There is provided a computer-implemented method for estimating flow of fluid into a production well extending into a reservoir comprising fluid, the well comprising a central tubing and an annulus surrounding the central tubing. The annulus is connected to the reservoir so as to receive fluid at one or more inflow locations. The central tubing has at least one inlet, arranged to allow fluid to flow from the annulus into the central tubing, and is located downstream of the one or more inflow locations. The production well further comprises one or more devices arranged to measure a temperature of fluid within the annulus at a plurality of points along the length of the annulus. The method comprises: receiving temperature data from the one or more devices indicative of a temperature of fluid at a plurality of points along the length of the annulus; identifying a change in temperature of fluid flowing within the annulus on the basis of the received temperature data at the plurality of points; using a model to estimate heat transfer from the central tubing to fluid flowing within the annulus, said model being configured such that the heat transfer is assumed to be substantially constant along the length of the tubing; and estimating a rate at which fluid flows into the annulus from the reservoir at a first inflow location on the basis of the identified change in temperature between the points and the estimated heat transfer.
GB1410602.5A 2011-12-20 2012-12-20 Estimating flow rates from multiple hydrocarbon reservoir layers into a production well Withdrawn GB2511019A (en)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GBGB1122027.4A GB201122027D0 (en) 2011-12-20 2011-12-20 Estimating flow in production well
PCT/EP2012/076479 WO2013092909A1 (en) 2011-12-20 2012-12-20 Estimating flow rates from multiple hydrocarbon reservoir layers into a production well

Publications (2)

Publication Number Publication Date
GB201410602D0 GB201410602D0 (en) 2014-07-30
GB2511019A true GB2511019A (en) 2014-08-20

Family

ID=45572807

Family Applications (2)

Application Number Title Priority Date Filing Date
GBGB1122027.4A Ceased GB201122027D0 (en) 2011-12-20 2011-12-20 Estimating flow in production well
GB1410602.5A Withdrawn GB2511019A (en) 2011-12-20 2012-12-20 Estimating flow rates from multiple hydrocarbon reservoir layers into a production well

Family Applications Before (1)

Application Number Title Priority Date Filing Date
GBGB1122027.4A Ceased GB201122027D0 (en) 2011-12-20 2011-12-20 Estimating flow in production well

Country Status (4)

Country Link
US (1) US20140365130A1 (en)
GB (2) GB201122027D0 (en)
NO (1) NO20140899A1 (en)
WO (2) WO2013092906A2 (en)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10280722B2 (en) 2015-06-02 2019-05-07 Baker Hughes, A Ge Company, Llc System and method for real-time monitoring and estimation of intelligent well system production performance

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US10808521B2 (en) 2013-05-31 2020-10-20 Conocophillips Company Hydraulic fracture analysis
RU2531499C1 (en) * 2013-08-23 2014-10-20 Шлюмберже Текнолоджи Б.В. Method of determining fluid movement profile of stacked pools in well
RU2537446C1 (en) * 2013-10-18 2015-01-10 Шлюмберже Текнолоджи Б.В. Method of determination of filtration rate of formation fluids
EP2985410A1 (en) * 2014-08-12 2016-02-17 Services Petroliers Schlumberger Methods and apparatus for determining downhole fluid parameters
WO2016118802A1 (en) * 2015-01-23 2016-07-28 Schlumberger Canada Limited Control system and method of flowback operations for shale reservoirs
WO2017052523A1 (en) * 2015-09-23 2017-03-30 Schlumberger Canada Limited Temperature measurement correction in producing wells
US10890058B2 (en) 2016-03-09 2021-01-12 Conocophillips Company Low-frequency DAS SNR improvement
US10095828B2 (en) * 2016-03-09 2018-10-09 Conocophillips Company Production logs from distributed acoustic sensors
US10458228B2 (en) 2016-03-09 2019-10-29 Conocophillips Company Low frequency distributed acoustic sensing
US10260331B2 (en) * 2016-11-03 2019-04-16 Nabors Drilling Technologies Usa, Inc. Autodrilling control with annulus pressure modification of differential pressure
EP3619560B1 (en) 2017-05-05 2022-06-29 ConocoPhillips Company Stimulated rock volume analysis
US11255997B2 (en) 2017-06-14 2022-02-22 Conocophillips Company Stimulated rock volume analysis
WO2019079481A2 (en) 2017-10-17 2019-04-25 Conocophillips Company Low frequency distributed acoustic sensing hydraulic fracture geometry
AU2019243434A1 (en) 2018-03-28 2020-10-08 Conocophillips Company Low frequency DAS well interference evaluation
EP3788515A4 (en) 2018-05-02 2022-01-26 ConocoPhillips Company Production logging inversion based on das/dts
AU2020247722B2 (en) 2019-03-25 2024-02-01 Conocophillips Company Machine-learning based fracture-hit detection using low-frequency DAS signal
CN113191101A (en) * 2021-05-08 2021-07-30 王昌益 Fluid running flow and stagnation unified law measurement and research method
CA3225345A1 (en) 2021-07-16 2023-01-19 Conocophillips Company Passive production logging instrument using heat and distributed acoustic sensing

Citations (3)

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Publication number Priority date Publication date Assignee Title
US20070213963A1 (en) * 2003-10-10 2007-09-13 Younes Jalali System And Method For Determining Flow Rates In A Well
US20080065362A1 (en) * 2006-09-08 2008-03-13 Lee Jim H Well completion modeling and management of well completion
US20080201080A1 (en) * 2007-02-20 2008-08-21 Schlumberger Technology Corporation Determining fluid and/or reservoir information using an instrumented completion

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US20060131016A1 (en) * 2004-06-12 2006-06-22 Ivan Snoga Apparatus and method for determining the dip of an underground formation in a cased or uncased borehole
EP2397649A1 (en) * 2010-06-10 2011-12-21 BP Exploration Operating Company Limited Method and system for determining relative mass fluxes

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20070213963A1 (en) * 2003-10-10 2007-09-13 Younes Jalali System And Method For Determining Flow Rates In A Well
US20080065362A1 (en) * 2006-09-08 2008-03-13 Lee Jim H Well completion modeling and management of well completion
US20080201080A1 (en) * 2007-02-20 2008-08-21 Schlumberger Technology Corporation Determining fluid and/or reservoir information using an instrumented completion

Non-Patent Citations (3)

* Cited by examiner, † Cited by third party
Title
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OUYANG L-B ET AL:"Flow profiling bydistributed temperature sensor(DTS)system - expectation and reality",SPE PRODUCTION & OPERATIONS :AN OFFICIALPUBLICATION OF THE SOCIETY OF PETROLEUM ENGINEERS, SPE SOCIETY OF PETROLEUMENGINEERS,USA,vol.21,no.2,1 May 2006(2006-05-01),pages 269 *
WANG X ET AL:"Modeling flow profileusing Distributed Temperature Sensor (DTS) system",INTELLIGENT ENERGY CONFERENCE ANDEXHIBITION:INTELLIGENT ENERGY 2008;20080225 TO 20080227; AMSTERDAM, NETHERLANDS, SPE SOCIETY OF PETROLEUMENGINEERS,USA,vol.1,1 January 2008(2008-01-01),pages100 *

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10280722B2 (en) 2015-06-02 2019-05-07 Baker Hughes, A Ge Company, Llc System and method for real-time monitoring and estimation of intelligent well system production performance

Also Published As

Publication number Publication date
WO2013092909A1 (en) 2013-06-27
NO20140899A1 (en) 2014-09-17
GB201122027D0 (en) 2012-02-01
US20140365130A1 (en) 2014-12-11
GB201410602D0 (en) 2014-07-30
WO2013092906A2 (en) 2013-06-27
WO2013092906A3 (en) 2014-05-15

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WAP Application withdrawn, taken to be withdrawn or refused ** after publication under section 16(1)