US20140343908A1 - Method and system for using tracer shots for estimating influx volumes of fluids from different influx zones to a production flow in a well - Google Patents

Method and system for using tracer shots for estimating influx volumes of fluids from different influx zones to a production flow in a well Download PDF

Info

Publication number
US20140343908A1
US20140343908A1 US14/354,328 US201114354328A US2014343908A1 US 20140343908 A1 US20140343908 A1 US 20140343908A1 US 201114354328 A US201114354328 A US 201114354328A US 2014343908 A1 US2014343908 A1 US 2014343908A1
Authority
US
United States
Prior art keywords
influx
tracer
release
well
production
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
US14/354,328
Other languages
English (en)
Inventor
Fridtjof Nyhavn
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.)
Resman AS
Original Assignee
Resman 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
Application filed by Resman AS filed Critical Resman AS
Assigned to RESMAN AS reassignment RESMAN AS ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: NYHAVN, FRIDTJOF
Publication of US20140343908A1 publication Critical patent/US20140343908A1/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
    • 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
    • E21B47/11—Locating fluid leaks, intrusions or movements using tracers; using radioactivity

Definitions

  • Resman has a patent on a specific method and device for installing a polymer carrier for a chemical tracer material wherein the polymer carrier is formed as thin rods placed in a cavity within the well completion tubing outside the central tube.
  • a polymer carrier is arranged for long-time release of the tracer materials and is not desirable to use in the present method, as it is an advantage to have a “clean shot” release of the chemical tracer material.
  • the experience gained with tracer flowback from more than 50 wells with such polymer carriers has been a necessary basic for this new invention.
  • the tracer carriers illustrated in FIG. 4 may be polymer carriers with long-term release of tracer material.
  • Annular wetting is fluids from the annular space entering through a screen, wetting the tracer carrier, and leaving to the annular space without local passage to the central production tube.
  • Tubing wetting is fluid arriving through central pipe and deviating through a screen in the tubing out to a closed sub enveloping a tracer carrier, and returning with tracer material back through the internal screen to the production tubing.
  • Combined wetting may be obtained using a sub with a screen for allowing influx from the annulus space and also allowing passage through a screen from and to the central production pipe, with a tracer carrier arranged between the central tubing screen and the annulus screen.
  • a downhole tracer release rate changes, preferably in short pulses, while the well flow rate is constant over time (or where the well flow rate changes slowly relative to the short pulses of tracer release.
  • Mechanical tracer release chambers may be the source of such. If several chambers release synchronously in a well the situation may be good as a basis for extracting downhole inflow profile. This may correspond to the situation of FIG. 1.2 , with a mechanically or otherwise controlled instantaneously released tracer at a given point of time. This may prove advantageous if the different influx zones have different influx pressures. If different influx pressures exist, it is not feasible to create the “shots” illustrated in FIGS. 1.2 and 1 . 3 by shutting in the well because cross-flow between the zones may arise during shut-in.
  • Groups of distinct tracer materials are released in selected influx zones e.g. 4 different tracers at a time fired in each their separate zone. Then one may calculate an image of the relative influx rates based on sampling of a well flow which may have arisen such as illustrated in FIG. 1 . The total flux is expected to be measured topside. Subsequently the same set of tracers, or a different set of tracers, may be fired from other positions in the well at a later time. This results in that one may do with a reduced number of unique tracers than the number of influx zones.
  • Another advantage using mechanical release according to the invention is that it may take place at a desired point of time at a desired place in the well.
  • the installation of the completion may take several days.
  • a polymer carrier will usually start releasing tracer immediately when in contact with the well fluids, and tracer will be smeared out along the entire well during the completion installation.
  • the invention is a method for estimating influx volumes (q i ) of fluids to a production flow (F) in a well (W r ) with two or more influx locations ( 3 ) along the well
  • the invention may also be defined as a system for estimating influx volumes (q i ) of fluids to a production flow (F) in a well (W r ) with two or more influx locations ( 3 ) along the well, comprising
  • An advantage of the invention over prior art is that as the chemical tracer according to the invention is released over a short period of time compared to the characteristic time constants of the physics to be monitored or the physics to be exploited during the monitoring process.
  • the tracer is released over a short period generally less than one minute and in practice probably in about 10 seconds.
  • the tracer may advantageously be released under steady state flow of the fluids in the well, and thus the method of the invention incurs no or little disturbance to the well flow and that information extraction may be done during relevant operating rate condition. Thereby it is easier to understand details of the well flow such as estimating the differences between different influx zones' contribution to the total flow. If the calculation of the different contributions to the well flow differ from what is a desired flow pattern in the well, the operator may use the calculated contributions from each influx zones as one of several parameters for determining adjustments to the control of the well.
  • FIG. 1 shows a series of diagrams to visualize how the tracer concentrations shots can be introduced in the production stream and how the shots change as they are transported across the reservoir interval.
  • the downstream piping system and well path to the topside equipment is not illustrated.
  • FIGS. 1-1 to 1 - 9 illustrate the technique.
  • Each frame is a time step and describe how the tracer shots move after being built up as a result of a tracer shot.
  • the diagrams represents a horizontal well with four tracers of generally instant release, installed at positions labelled A, B, C, D. For simplicity in this example the distances between each subsequent tracer position along the wellbore are equal.
  • the tracer release devices are exposed to the well fluids either from the outside of the completion or inside depending on the carrier system.
  • the tracers are released to the fluids at a given instant. When released as illustrated in FIG. 1-2 , then the fluids immediately surrounding the tracer develop a high concentration of the tracer.
  • Such volumes are referred to as a “tracer shot” and typically start off as equal volumes.
  • each vertical arrow in this example represent a given flow for example 1000 bopd (barrels of oil per day).
  • the volume and hence time difference between the arrival of slug C and D will be longer than between A and B due to the fact that there will be three times more wellbore fluids that are entering in between the two tracer slugs C and D. This is visually represented in the FIGS. 1-6 , 1 - 7 , 1 - 8 and 1 - 9 . Also the concentration of tracer slug D will become more diluted and spread out as a result of this higher influx, this is also visualized in FIGS. 1-6 to 1 - 9 .
  • FIG. 2 is an idealised illustration of concentration of identified tracers sampled topside, with time or cumulative production volume (since the injection) as the abscissa.
  • FIG. 3 is an illustration of an approach for matching the unknown downhole influx rates in the downhole production zones with the modelled influx rates.
  • the model influx rates are adjusted until the calculated concentrations of model tracers compare well with the measured concentrations of identified tracers.
  • FIG. 4 gives a few rough examples of well fluids wetting tracers generally according to prior art.
  • FIG. 5 a is a simplified section through a petroleum well. Influx volumes of fluids enters from the reservoir rocks to end up in a production flow in a central production pipe in the well provided with two or more separate influx locations. In this situation the influx zones may not be precisely known and it is not taken for granted that the tracers are placed where the influx exactly occurs.
  • FIG. 5 b is a simplified section through a petroleum well wherein packers are arranged for mutually isolating the influx zones. In this situation the tracers are also placed each in its separate influx zone. There may be many more influx zones and tracer carriers than what is illustrated in FIGS. 5 a and b.
  • FIG. 6 comprises illustrations of embodiments of the invention.
  • the injection of the tracer shot performed during steady-state flow so only the tracer forms a transient in time, and the fluids with the tracer is eventually flushed out from the isolated zone's completion void.
  • FIG. 6 a illustrates one insulated influx zone insulated by a lower (right) and an upper (left) packer defining a zone of influx of petroleum fluids (and/or water) entering the annulus about the production tubing, the fluids passing a mechanical tracer release sub, (not yet released) and the fluids with more or less tracer material leaving the annulus space through apertures in the central production tube to the production flow which passes towards the topside.
  • a steady state flow rate is advantageous.
  • FIG. 6 b illustrates the same setup, now with the mechanical tracer release triggered and tracer material released into the annulus space. A tracer shot of short temporal duration is created. The dispersion of the tracer material will be a function of turbulence and flow geometry in the annulus space.
  • FIG. 6 c illustrates the subsequent step wherein the fluids with the tracer shot with a more or less distributed tracer material is flushed out the annulus space through apertures in the central production tube to the production flow which passes towards the topside. Again, a steady state flow rate is advantageous.
  • FIG. 7 shows curves of tracer shot release into the base pipe from the annulus void of FIG. 6 c into the central production pipe (base pipe) as a function of time.
  • the “rate 2Q” curve indicates a twice as high influx rate as the “rate Q” curve, both washing out the same amounts of tracer delivered by equal shots. Please notice that the area under the 2Q and Q rate curves are equal. Please also notice that both curves approach nil concentration as the doses released are finite at the short term. The higher rate will flush out fastest and die out faster, while the lower influx rate will wash out at a lower rate and sustain at a detectable level for longer.
  • FIG. 8 comprises illustrations of a possible problem.
  • the tracer shot is built over time from the tracer leak-out from polymers into still shut-in fluids.
  • the flow-back of the shot to surface is then done during production ramp-up.
  • not only the tracer forms a transient in time, but there may also occur a cross-flow of fluid from the shown zone to another zone during the build-up of the shot, which will complicate the backflow pattern and obscur the measurements obtained.
  • FIG. 8 a illustrates a situation similar to what is illustrated in FIG. 6 a , with the difference that tracer is released more or less at a constant rate over long time, e.g. tracers from a polymer rod arranged in the annular space outside the central production tube.
  • the fluid carries tracer with it at a generally even rate with the production flow.
  • FIG. 8 b illustrates the result of a shut-in downstream (topside) in order to build a concentration in the annulus space, called to build a “shot”.
  • This method may work well in case there is no cross flow, but the method of using a continuous release of tracer is sensitive to crossflow between zones (this is one zone) through the central production pipe, if a downstream (topside) shut-in is used. If the shut-in occurs downhole between all influx zones and the production pipe, this is not a problem, but requires a more elaborate well control apparatus.
  • FIG. 8 c illustrates that the tracer concentrated fluid (the “shot”) is flushed out with resumption of the production by opening the topside valve, and the partially leaked-out shot will be flushed out as a longer pulse than strictly desirable because of the potentially non-ideal build-up of the shot.
  • the tracer concentrated fluid the “shot”
  • FIG. 9 shows ideal curves of tracer shot release into the base pipe from the annulus void of FIG. 6 c into the central production pipe (base pipe) as a function of time, in the situation described for FIG. 8 c , but without cross-flow, i.e. it is the best imaginable situation of shut-in with long term release of tracer. Please notice that both curves cannot approach nil concentration as the doses are continually released. The higher rate will flush out fastest and die out faster, while the lower influx rate will wash out at a lower rate, but both may be at a detectable level for very long time.
  • FIG. 10 illustrates a mechanical tracer release sub according to an aspect of the invention and for use with the method according to the invention.
  • a tracer dose is in this case arranged in a breakable ampoule, e.g. in a glass bulb and to release through holes open to the central production pipe.
  • a release mechanism comprising such as a small explosive charge or a puncturing needle is arranged for breaking the breakable ampoule controlled by a timer of an electronic unit.
  • the electronic unit please see section B-B, is preferably provided its own electric battery and is preferably arranged to trigger the release mechanism at a given date and time of day.
  • each ampoule predestined to break at long intervals, such as one each month, each six months, or more.
  • the entire release sub may be provided with end rings such as friction slip rings for being mounted into the central production tubing and inserted with the completion into the production zone.
  • the setup in FIG. 10 will typically be used in the context described in FIG. 1 where venting towards the central base pipe is needed.
  • FIG. 11 shows a similar embodiment of the mechanical tracer release sub according to a slightly different embodiment of the invention, for use with the method according to the invention.
  • the tracer doses are arranged in breakable ampoules which are arranged with vent holes of the sub open to the annulus space and not to the production pipe directly. Otherwise the mechanical release sub is similar to what is described under FIG. 10 .
  • This mechanical embodiment thus releases into the void outside the central production pipe and should be used in the context shown in FIG. 6 with flush-out from the insulated zone in the annulus void in the completion, and will work along the lines of FIG. 7 .
  • FIG. 12 illustrates this mechanical embodiment which releases into the void outside the central production pipe and used in the context shown in FIG. 6 with flush-out from the insulated zone in the annulus void in the completion.
  • FIG. 13 relates to a setup with tracer shots being injected into the central base pipe, as also explained in FIG. 1 .
  • FIG. 13 shows curves of tracer concentrations as function of cumulative production volume topside.
  • zone 1 two parallel production zones
  • zone 1 & 5 two wells on the same tie-back, leading to the same topsides sampling site.
  • the vertical coloured lines are the positions of tracers in insulated influx zones to the two branches.
  • the different coloured lines in the curves indicate measured concentrations (interpolated).
  • the vertical bars of same colours indicate peak arrivals (as function of cumulative volume) if even influx rates had existed and this is calculated from models.
  • zone 1 and zone 1 & 5 arrive almost as predicted from the even rate model, but that the toe marker of zone 1 arrives far too early and its influx must be higher than presumed, and the nearer toe of zone 1 & 5 arrives far too late and must be due to a lower influx than presumed. This indicates that the influx model should be adjusted significantly.
  • FIG. 14 shows the same measured curves and well models as for FIG. 13 above.
  • a general scheme of comparison between the Real World and the model world as shown in FIG. 3 may be used. The difference is that here the influx model of “zone 1 ” and “zone 1 & 5 ” are heavily corrected to indicate influx rates downhole “zone 1 ” of 18%, only 1%, and as high as 43% contributions to the combined total flow topside, and for zone 1 & 5 contributions of 9% at the heel, 10%, and 18% at the toe.
  • the middle production zone of “zone 1 ” contributes insignificantly and may be shut down or considered as a candidate for an overhaul.
  • the predicted peak arrivals coincide with the actual peaks.
  • the invention is a method for estimating influx volumes (q i ) of fluids to a production flow (F) in a well (W r ), please see FIG. 5 .
  • the well is provided with two or more separate influx locations ( 3 , 31 , 32 , 33 ) along the well.
  • the actual positions of the influx locations are not necessarily precisely known.
  • Tracer sources ( 4 , 41 , 42 , 43 ) with distinct tracer materials ( 4 m, 41 m, 42 m, 43 m ) are arranged upstream/downstream said influx zones ( 3 , 31 , 32 , 33 ).
  • Each said tracer material ( 4 m ) has a predefined, comparatively short, quickly released dose (V t4 ) (short release time dose) to the fluids in the well.
  • comparatively short we here mean significantly short compared to subsequent sampling intervals, compared to the time required for the well flow's transit time from the influx zones to the topside of the well, compared to possibly the leak-out time constant from the annulus to the central production pipe if the tracer is released into an external void in the well completion and compared to the characteristic time constant of the physics we are monitoring.
  • the influx zone furthest from the topside is called the “toe” and the nearest influx zone is called the “heel”.
  • the method aims at extracting information from tracer transients in the petroleum fluid (or water) flowback of tracers to the surface.
  • the tracer sources ( 4 , 41 , 42 , 43 ) are according to the invention allowed to release the tracer material ( 4 m, 41 m, 42 m, 43 m ) to the fluids each belonging zone at a given release instant (t R ).
  • the tracer sources according to the invention are arranged to release the tracers at a given instant in time in order for the subsequent topsides sampling to be conducted rationally. In an embodiment of the invention this is done by providing each tracer source downhole with a timer which is set for triggering the release at a given date and time. The release may be repeated at one or more later given date and time in order to conduct further measurement series.
  • samples (c 1 , c 2 , c 3 , . . . ) of the production flow (F) are consecutively collected at the topside.
  • the sampling may simply be conducted by tapping small amounts of the petroleum flow (F) at registered times.
  • An alternative to sampling as a function of time is to collect sample at intervals based on cumulative petroleum volumes (f 1 , f 2 , f 3 , f 4 ), if the flow is not a steady-state flow. (One may collect samples at regular time intervals and plot and analyze the measurements as a function of cumulative productin.)
  • the samples (c 1 , c 2 , c 3 , . . . ) are analysed for identifying the types of one or more tracer material ( 4 m, 41 m, 42 m, 43 m ) and their corresponding concentrations ( 4 c, 41 c, 42 c, 43 c ) of the identified tracer materials.
  • the analysis is conducted on site during the sampling period using field analysis instruments topside in order to provide results rapidly.
  • the analysis may be conducted in a chemical laboratory in order to provide more precise measurements or for verifying or refining field measurements.
  • the well geometry comprises the sequence and positions of the separate influx zones, and the length and geometry such as pipe diameters corresponding lengths of the sections of production pipe, possibly including tie-back pipes, all the way from the influx zones to the topside sampling point.
  • the calculated influx volumes (q i ) are used as parameters for comparison indirectly with the real measurements so as for controlling changes to the production flow, such as increasing or decreasing the total flow topside or adjusting the influx from the separate influx zones using valves between the influx zones and the central production pipe, or adjusting the flux ratios from well branches' production pipes into a main well.
  • a model of the well may be established.
  • the model may be adjusted with regard to influx volumes in the distinct zones until there is correspondence in the measured concentration curves and the modeled calculation curves.
  • the well operator will usually not decide on controlling the well flow only based on the estimates of influx volumes, but use additional relevant parameters such as pressure and fluid composition and other operational parameters.
  • each tracer source ( 4 ) arranged for releasing preferably simultaneously, at least in groups, at a given release instant (t R ) in time.
  • the release dose (V t4 ) is released during less than one minute, preferably less than 10 seconds.
  • the release time rather short so that the release of tracer is a pulse compared with characteristic time constants of the flow events that we are monitoring, and, in case we have a delay chamber, significantly shorter than the characteristic time constant of the delay chamber.
  • the given release instant (t R ) is an advance determined instant in time.
  • the release instant may be set while installing the mechanical release sub in the completion, before the entire completion is inserted into the well production zone.
  • the mechanical release sub may be provided with a self-powered timer in a tracer release unit so as for to avoid any external power supply, and also for avoiding control lines from the surface: one knows the date and time the tracers are released, and sampling must be conducted in a required number of samples through a sufficiently long time after the release, and one will have a good set of samples to analyze.
  • the given release instant (t R ) may be being one of a series of release instants.
  • all the release instants may be predetermined before assembly and installation of the production pipe assembly.
  • the given release instant (t R ) may be commanded from the surface.
  • a signal transmitter at the topside may be arranged to send a “request to release” signal to the sub containing a corresponding signal receiver in the mechanical tracer dose release unit of the invention.
  • the actual tracer release point of time may still be set in the electronic control module in the sub to be delayed to a predefined hour, minute and second, so one may be certain that the tracer is released at an exactly known point in time.
  • the method is conducted in a well wherein the two or more influx locations are separated by e.g. packers, so as for the influx locations to be mutually isolated in the annulus around the production pipe.
  • the two or more influx locations are separated by e.g. packers, so as for the influx locations to be mutually isolated in the annulus around the production pipe.
  • the tracer sources are arranged in fluid communication with the influx zones. More specifically, the tracer sources are preferably, if possible, each arranged within or very near its corresponding influx zone so as to have a relatively short flux path from the influx zone, past the tracer source, and out through vents to the production pipe, such as illustrated particularly in FIG. 8 and FIG. 12 .
  • the real positions are unknown, but may be varied in the model well in order to better match the modelled tracer arrivals topside.
  • the sampling is conducted after said predefined release instant (t R ), after a time reasonably comparable to the minimum transit time for a first of the tracers to reach the sampling site. This is in order to avoid starting sampling before the first tracer may actually arrive through e.g. the tie-back length of several kilometres of pipe to the topside location.

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)
  • Physical Or Chemical Processes And Apparatus (AREA)
  • Indicating Or Recording The Presence, Absence, Or Direction Of Movement (AREA)
  • Complex Calculations (AREA)
  • Aerodynamic Tests, Hydrodynamic Tests, Wind Tunnels, And Water Tanks (AREA)
US14/354,328 2011-10-28 2011-10-28 Method and system for using tracer shots for estimating influx volumes of fluids from different influx zones to a production flow in a well Abandoned US20140343908A1 (en)

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/NO2011/000305 WO2013062417A1 (en) 2011-10-28 2011-10-28 Method and system for using tracer shots for estimating influx volumes of fluids from different influx zones to a production flow in a well

Publications (1)

Publication Number Publication Date
US20140343908A1 true US20140343908A1 (en) 2014-11-20

Family

ID=45444709

Family Applications (1)

Application Number Title Priority Date Filing Date
US14/354,328 Abandoned US20140343908A1 (en) 2011-10-28 2011-10-28 Method and system for using tracer shots for estimating influx volumes of fluids from different influx zones to a production flow in a well

Country Status (8)

Country Link
US (1) US20140343908A1 (de)
EP (1) EP2771543B1 (de)
AU (1) AU2011380070A1 (de)
BR (1) BR112014010067B1 (de)
CA (1) CA2852630A1 (de)
MX (1) MX2014004899A (de)
NO (1) NO2771543T3 (de)
WO (1) WO2013062417A1 (de)

Cited By (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
NO20160274A1 (en) * 2016-02-16 2017-08-01 Wellstarter As A method and system for real-time fluid flow monitoring in a wellbore
CN108104801A (zh) * 2017-12-30 2018-06-01 中国石油天然气股份有限公司 一种水平井示踪剂产液剖面测试管柱及方法
CN109025976A (zh) * 2018-08-29 2018-12-18 西安石油大学 一种缓释型示踪剂测水平井产液剖面实验装置及实验方法
US10465502B2 (en) * 2014-06-30 2019-11-05 Schlumberger Technology Corporation Reservoir effluent auto sampler and detection system for tracers
US10865637B2 (en) 2017-12-28 2020-12-15 Resman As Real time radioactive
US11326440B2 (en) 2019-09-18 2022-05-10 Exxonmobil Upstream Research Company Instrumented couplings
US11492897B2 (en) * 2017-02-03 2022-11-08 Resman As Targeted tracer injection with online sensor

Families Citing this family (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9416651B2 (en) 2013-07-12 2016-08-16 Saudi Arabian Oil Company Surface confirmation for opening downhole ports using pockets for chemical tracer isolation
NO343025B1 (no) 2014-12-23 2018-10-08 Resman As Fremgangsmåte og apparat for online monitorering av tracere

Citations (29)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5047632A (en) * 1989-05-27 1991-09-10 Schlumberger Technology Corporation Method for determining dynamic flow characteristics of multiphase flows
US5168927A (en) * 1991-09-10 1992-12-08 Shell Oil Company Method utilizing spot tracer injection and production induced transport for measurement of residual oil saturation
US5256572A (en) * 1989-07-31 1993-10-26 Exxon Production Research Company Method for determining residual oil saturation of a watered-out reservoir
US20010036667A1 (en) * 2000-04-26 2001-11-01 Davoud Tayebi Reservoir monitoring
US20030056952A1 (en) * 2000-01-24 2003-03-27 Stegemeier George Leo Tracker injection in a production well
US20030131991A1 (en) * 2000-05-31 2003-07-17 Hartog Floor Andre Tracer release method for monitoring fluid flow in a well
US20060052251A1 (en) * 2004-09-09 2006-03-09 Anderson David K Time release multisource marker and method of deployment
US20070061093A1 (en) * 2005-08-27 2007-03-15 Schlumberger Technology Corporation Time-of-flight stochastic correlation measurements
US20080092666A1 (en) * 2004-12-23 2008-04-24 Statoil Asa Tracer Measurement In Multiphase Pipelines
US20080133193A1 (en) * 2006-12-01 2008-06-05 Halliburton Energy Services, Inc. Methods for estimating properties of a subterranean formation and/or a fracture therein
US20080283242A1 (en) * 2007-05-11 2008-11-20 Clearwater International, Llc, A Delaware Corporation Apparatus, compositions, and methods of breaking fracturing fluids
US20090087912A1 (en) * 2007-09-28 2009-04-02 Shlumberger Technology Corporation Tagged particles for downhole application
US7560690B2 (en) * 2004-06-30 2009-07-14 Resman As System for delivery of a tracer in fluid transport systems and use thereof
US20090211754A1 (en) * 2007-06-25 2009-08-27 Turbo-Chem International, Inc. WirelessTag Tracer Method and Apparatus
US20100139386A1 (en) * 2008-12-04 2010-06-10 Baker Hughes Incorporated System and method for monitoring volume and fluid flow of a wellbore
US20100307744A1 (en) * 2009-06-03 2010-12-09 Schlumberger Technology Corporation Use of encapsulated chemical during fracturing
US20100307745A1 (en) * 2009-06-03 2010-12-09 Schlumberger Technology Corporation Use of encapsulated tracers
US20110257887A1 (en) * 2010-04-20 2011-10-20 Schlumberger Technology Corporation Utilization of tracers in hydrocarbon wells
US20120325464A1 (en) * 2011-06-24 2012-12-27 Lars Kilaas Early verification of a production well
US20130091943A1 (en) * 2010-10-19 2013-04-18 Torger Skillingstad Tracer Identification of Downhole Tool Actuation
US20130245948A1 (en) * 2010-10-29 2013-09-19 Resman As Extracting downhole flow profiles from tracer flowback transients
US20140209384A1 (en) * 2013-01-31 2014-07-31 Chevron U.S.A. Inc. Method and system for detecting changes in drilling fluid flow during drilling operations
US20140212986A1 (en) * 2010-02-12 2014-07-31 Fluidion Sas Passive Micro-vessel and Sensor
US20140377871A1 (en) * 2012-01-09 2014-12-25 Sinvent As Method and system for wireless in-situ sampling of a reservoir fluid
US20150041121A1 (en) * 2012-03-15 2015-02-12 Chevron U.S. A. Inc Outward venting of inflow tracer in production wells
US20150130468A1 (en) * 2013-10-17 2015-05-14 Weatherford/Lamb, Inc. Apparatus and method for monitoring a fluid
US20150176396A1 (en) * 2012-07-02 2015-06-25 Resman As Monitoring of multilayer reservoirs
US20150377021A1 (en) * 2014-06-30 2015-12-31 Schlumberger Technology Corporation Reservoir Effluent Auto Sampler & Detection System for Tracers
US20160047231A1 (en) * 2013-04-07 2016-02-18 Resman As Gas well inflow detection method

Family Cites Families (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US7337660B2 (en) * 2004-05-12 2008-03-04 Halliburton Energy Services, Inc. Method and system for reservoir characterization in connection with drilling operations

Patent Citations (29)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5047632A (en) * 1989-05-27 1991-09-10 Schlumberger Technology Corporation Method for determining dynamic flow characteristics of multiphase flows
US5256572A (en) * 1989-07-31 1993-10-26 Exxon Production Research Company Method for determining residual oil saturation of a watered-out reservoir
US5168927A (en) * 1991-09-10 1992-12-08 Shell Oil Company Method utilizing spot tracer injection and production induced transport for measurement of residual oil saturation
US20030056952A1 (en) * 2000-01-24 2003-03-27 Stegemeier George Leo Tracker injection in a production well
US20010036667A1 (en) * 2000-04-26 2001-11-01 Davoud Tayebi Reservoir monitoring
US20030131991A1 (en) * 2000-05-31 2003-07-17 Hartog Floor Andre Tracer release method for monitoring fluid flow in a well
US7560690B2 (en) * 2004-06-30 2009-07-14 Resman As System for delivery of a tracer in fluid transport systems and use thereof
US20060052251A1 (en) * 2004-09-09 2006-03-09 Anderson David K Time release multisource marker and method of deployment
US20080092666A1 (en) * 2004-12-23 2008-04-24 Statoil Asa Tracer Measurement In Multiphase Pipelines
US20070061093A1 (en) * 2005-08-27 2007-03-15 Schlumberger Technology Corporation Time-of-flight stochastic correlation measurements
US20080133193A1 (en) * 2006-12-01 2008-06-05 Halliburton Energy Services, Inc. Methods for estimating properties of a subterranean formation and/or a fracture therein
US20080283242A1 (en) * 2007-05-11 2008-11-20 Clearwater International, Llc, A Delaware Corporation Apparatus, compositions, and methods of breaking fracturing fluids
US20090211754A1 (en) * 2007-06-25 2009-08-27 Turbo-Chem International, Inc. WirelessTag Tracer Method and Apparatus
US20090087912A1 (en) * 2007-09-28 2009-04-02 Shlumberger Technology Corporation Tagged particles for downhole application
US20100139386A1 (en) * 2008-12-04 2010-06-10 Baker Hughes Incorporated System and method for monitoring volume and fluid flow of a wellbore
US20100307745A1 (en) * 2009-06-03 2010-12-09 Schlumberger Technology Corporation Use of encapsulated tracers
US20100307744A1 (en) * 2009-06-03 2010-12-09 Schlumberger Technology Corporation Use of encapsulated chemical during fracturing
US20140212986A1 (en) * 2010-02-12 2014-07-31 Fluidion Sas Passive Micro-vessel and Sensor
US20110257887A1 (en) * 2010-04-20 2011-10-20 Schlumberger Technology Corporation Utilization of tracers in hydrocarbon wells
US20130091943A1 (en) * 2010-10-19 2013-04-18 Torger Skillingstad Tracer Identification of Downhole Tool Actuation
US20130245948A1 (en) * 2010-10-29 2013-09-19 Resman As Extracting downhole flow profiles from tracer flowback transients
US20120325464A1 (en) * 2011-06-24 2012-12-27 Lars Kilaas Early verification of a production well
US20140377871A1 (en) * 2012-01-09 2014-12-25 Sinvent As Method and system for wireless in-situ sampling of a reservoir fluid
US20150041121A1 (en) * 2012-03-15 2015-02-12 Chevron U.S. A. Inc Outward venting of inflow tracer in production wells
US20150176396A1 (en) * 2012-07-02 2015-06-25 Resman As Monitoring of multilayer reservoirs
US20140209384A1 (en) * 2013-01-31 2014-07-31 Chevron U.S.A. Inc. Method and system for detecting changes in drilling fluid flow during drilling operations
US20160047231A1 (en) * 2013-04-07 2016-02-18 Resman As Gas well inflow detection method
US20150130468A1 (en) * 2013-10-17 2015-05-14 Weatherford/Lamb, Inc. Apparatus and method for monitoring a fluid
US20150377021A1 (en) * 2014-06-30 2015-12-31 Schlumberger Technology Corporation Reservoir Effluent Auto Sampler & Detection System for Tracers

Non-Patent Citations (3)

* Cited by examiner, † Cited by third party
Title
BAKHSHI, ALI KHALID, PETER SCAIFE, AND IAN JOHN MICKELBURGH. "Using Chemical Tracers for Flow Profiling a Subsea Horizontal Well with an Open Hole Gravel Pack Lower Completion: Field Results." In SPE Asia Pacific Oil and Gas Conference and Exhibition. Society of Petroleum Engineers, 2008. *
NYHAVN, F., & DYRLI, A. D. (2010, September 22). Permanent Tracers Embedded in Downhole Polymers Prove Their Monitoring Capabilities in a Hot Offshore Well. Society of Petroleum Engineers. doi:10.2118/135070-MS *
WILLIAMS, B., & NYHAVN, F. (2012, April 30). Wireless Reservoir Surveillance Using Intelligent Tracers. Offshore Technology Conference. doi:10.4043/23282-MS *

Cited By (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10465502B2 (en) * 2014-06-30 2019-11-05 Schlumberger Technology Corporation Reservoir effluent auto sampler and detection system for tracers
NO20160274A1 (en) * 2016-02-16 2017-08-01 Wellstarter As A method and system for real-time fluid flow monitoring in a wellbore
WO2017131530A1 (en) 2016-02-16 2017-08-03 Wellstarter As A real-time fluid monitoring system and method
NO342159B1 (en) * 2016-02-16 2018-04-09 Wellstarter As A method and system for real-time fluid flow monitoring in a wellbore
GB2563544A (en) * 2016-02-16 2018-12-19 Wellstarter As A real-time fluid monitoring system and method
GB2563544B (en) * 2016-02-16 2020-06-24 Wellstarter As A real-time fluid monitoring system and method
US10697291B2 (en) 2016-02-16 2020-06-30 Wellstarter As Real-time fluid monitoring system and method
US11492897B2 (en) * 2017-02-03 2022-11-08 Resman As Targeted tracer injection with online sensor
US10865637B2 (en) 2017-12-28 2020-12-15 Resman As Real time radioactive
CN108104801A (zh) * 2017-12-30 2018-06-01 中国石油天然气股份有限公司 一种水平井示踪剂产液剖面测试管柱及方法
CN109025976A (zh) * 2018-08-29 2018-12-18 西安石油大学 一种缓释型示踪剂测水平井产液剖面实验装置及实验方法
US11326440B2 (en) 2019-09-18 2022-05-10 Exxonmobil Upstream Research Company Instrumented couplings

Also Published As

Publication number Publication date
AU2011380070A1 (en) 2014-05-01
CA2852630A1 (en) 2013-05-02
NO2771543T3 (de) 2018-02-24
BR112014010067B1 (pt) 2020-11-24
WO2013062417A1 (en) 2013-05-02
BR112014010067A2 (pt) 2017-06-13
EP2771543A1 (de) 2014-09-03
EP2771543B1 (de) 2017-09-27
BR112014010067A8 (pt) 2017-06-20
MX2014004899A (es) 2014-08-01

Similar Documents

Publication Publication Date Title
EP2771543B1 (de) Verfahren und system zur verwendung von tracer-injektionen zur schätzung des zustromvolumens von flüssigkeiten aus verschiedenen zustrombereichen zu einem produktionsfluss in einem bohrloch
US11674382B2 (en) Method for extracting downhole flow profiles from tracer flowback transients
US7055604B2 (en) Use of distributed temperature sensors during wellbore treatments
WO2018084871A1 (en) Real-time model for diverter drop decision using das and step down analysis
US11215048B2 (en) System and method for monitoring and controlling fluid flow
EP3268582A1 (de) Verfahren zum durchführen von bohrlochtestoperationen mit stickstoffhub, produktionsprotokollierung und aufbautest auf einem einzelnen gewickelten rohrstrang
CA3205295A1 (en) Hydraulic integrity analysis
WO2010059060A1 (en) Real time downhole intervention during wellbore stimulation operations
NO20140495A1 (no) Fremgangsmåte og system for tracer-basert bestemmelse av fluid-innstrømningsvolumer til en brønn-produksjonsstrøm fra to eller flere innstrømningslokasjoner langs brønnen
Grubert et al. Making sense of unconventionals with DAS
EP3433466B1 (de) Systeme und verfahren zur überwachung der integrität von bohrlochbarrieren
Kluth et al. Fiber-optic DTS flow profiling installed in advanced MRC well
Williams et al. Intelligent Inflow Tracers Obtain Information With Less Risk, Cost
NO20131514A1 (no) Ekstrahering av nedihulls strømningsprofiler fra tracer-tilbakestrømningstransienter

Legal Events

Date Code Title Description
AS Assignment

Owner name: RESMAN AS, NORWAY

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:NYHAVN, FRIDTJOF;REEL/FRAME:032833/0132

Effective date: 20140429

STPP Information on status: patent application and granting procedure in general

Free format text: NON FINAL ACTION MAILED

STCB Information on status: application discontinuation

Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION