WO2019018292A1 - Procédés et systèmes de cimentation et de suspension de colonne perdue automatisées - Google Patents

Procédés et systèmes de cimentation et de suspension de colonne perdue automatisées Download PDF

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Publication number
WO2019018292A1
WO2019018292A1 PCT/US2018/042300 US2018042300W WO2019018292A1 WO 2019018292 A1 WO2019018292 A1 WO 2019018292A1 US 2018042300 W US2018042300 W US 2018042300W WO 2019018292 A1 WO2019018292 A1 WO 2019018292A1
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WO
WIPO (PCT)
Prior art keywords
well completion
completion operation
iii
parameter
further characterized
Prior art date
Application number
PCT/US2018/042300
Other languages
English (en)
Inventor
Petter Andre STROMME
Ingo Forstner
Original Assignee
Baker Hughes, A Ge Company, Llc
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 Baker Hughes, A Ge Company, Llc filed Critical Baker Hughes, A Ge Company, Llc
Priority to CA3070403A priority Critical patent/CA3070403A1/fr
Priority to BR112020001111-8A priority patent/BR112020001111A2/pt
Priority to EP18834406.3A priority patent/EP3655624A4/fr
Publication of WO2019018292A1 publication Critical patent/WO2019018292A1/fr

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
    • E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
    • 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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
    • E21B33/14—Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
    • 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
    • E21B43/02—Subsoil filtering
    • E21B43/10—Setting of casings, screens, liners or the like in 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
    • E21B47/005—Monitoring or checking of cementation quality or level
    • 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
    • E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
    • E21B23/06—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
    • 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
    • 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
    • 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
    • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells

Definitions

  • TITLE METHODS AND SYSTEMS FOR AUTOMATED
  • the present invention generally relates to systems and methods for intelligent and autonomous / semi-autonomous control of cementing and liner hanging operations.
  • a well e.g., for production, is generally completed by placing a casing (also referred to herein as a "liner" or “tubular") in the wellbore.
  • the spacing between the liner and the wellbore inside, referred to as the "annulus,” is then filled with cement.
  • the liner and the cement may be perforated to allow the hydrocarbons to flow from the reservoirs to the surface via a production string installed inside the liner.
  • the present disclosure provides a method for controlling a well completion operation
  • the method may include conducting the well completion operation, estimating at least one operation parameter while conducting the well completion operation using at least one sensor, using a controller to determine at least one parameter adjustment relating to the well completion operation, and generating a command relating to the well completion operation.
  • the parameter adjustment determination may be done using the at least one model and the at least one estimated operating parameter.
  • the command generation may be based on the determined at least one parameter adjustment.
  • the present disclosure provide an apparatus for controlling a well completion operation
  • the apparatus may include a completion system configured to conduct the well completion operation, at least one sensor configured to estimate at least one parameter while conducting the well completion operation, and a controller.
  • the controller may have access to at least one model configured to determine a parameter relating to the well completion operation.
  • the controller may be configured to determine at least one parameter adjustment relating to the well completion operation using the at least one model and the at least one estimated parameter and generate a command relating to the well completion operation based on the determined_at least one parameter adjustment relating to the well completion operation.
  • FIG. 1 shows a schematic diagram of a well with an illustrative completion system according to the present disclosure
  • FIG. 2 is a flow chart illustrating one method according to the present disclosure
  • FIG. 3 schematically illustrates a completion assembly during cementing
  • FIG. 4A illustrates an exemplary torque versus height graph that may be used in conjunction with a model to control cementing operations according to one method according to the present disclosure
  • FIG. 4B illustrates an exemplary slow pump pressure (SPP) versus height graph that may be used in conjunction with a model to control cementing operations according to one method according to the present disclosure.
  • SPP slow pump pressure
  • the present disclosure provides methods and related systems that intelligently guide, in an automated or semi-automated fashion, the various steps of completing a well by hanging and cementing a liner. Cementing can be a complicated procedure where the amount of cement, placement of the cement, and quality of the cement bond are important considerations.
  • Embodiments of the present disclosure use a pre-defined process for such operations.
  • a feedback loop may compare modeling versus real-time measurements to optimize the overall process. Additionally, operating parameters may be adjusted minute-by-minute and potential issues may be identified concurrently.
  • Embodiments of the present disclosure use detailed preplanning and real-time information to advise on what step(s) to take and what, if any, adjustments must be made to operating parameters. These actions may be fully automated, with human interaction only in case of unforeseen challenges. Alternatively, the systems may provide prompts / guidance that assist human operators.
  • the entire completion process from liner hanging to cementing and clean up, may be optimized: from the simple timing of dropping darts that pressure-activate downhole tools and switching pumps off / on to complicated rotational speed (aka revolutions per minute, RPM)/axial movement variations along the process to accommodate varying geological or geometrical environments along the well path.
  • Illustrative systems may compare simulation / modeling data with real-time sensor and offset data and adjust the procedures on the fly. It will be appreciated that such systems not only enhance the quality of the outcome, but also help to evaluate the final completion in view of certain quality goals such as cement channeling or completeness of a cleanup.
  • Embodiments of the present disclosure may be used in conventional cementing/liner hanging operations, or in conjunction with a "one-trip" liner hanging and cementing tools.
  • a completion system 10 for performing liner hanging and cementing operations The teachings of the present disclosure may be utilized in land, offshore or subsea applications.
  • a laminated earth formation 12 is intersected by a borehole 14.
  • a completion assembly 16 is conveyed via a work string 18 into the borehole 14.
  • the completion assembly 16 includes a liner hanger assembly 20, which was run in using a suitable running tool (not shown) and installed.
  • the work string 18 may be jointed drill pipe or coiled tubing, which may include conductors (not shown) for power and / or data for providing signal and / or power communication between the surface and downhole equipment.
  • the completion assembly 16 may be configured in a conventional manner to flow cement 38 into an annulus 22 surrounding a liner 24 of the liner hanger assembly 20.
  • the liner hanger assembly 20 may include a swivel to allow rotation, anchoring equipment, and actuating devices for activating the anchoring equipment.
  • the completion system 10 may also include conventional rig equipment such as a mud pump 30, cement supply 32, a rotary power source 34 for rotating the work string 18, etc.
  • a controller 50 may be used in connection with the liner hanging and / or cementing activity.
  • the controller 50 uses preprogrammed algorithms, historical data, and real-time information in order to advise personnel on action(s) to take and / or automatically send commands to take such actions. These action may include, but are not limited to, varying RPM, pump rates, timing of dart insertion, and spacer sizes.
  • the controller 50 may include conventional components such as microprocessors, a memory controller, a main memory, a network interface, a transceiver, etc. Near realtime or real-time information may be obtained using sensors that are distributed at surface and downhole locations. Surface sensors are labeled with numeral 52 and downhole sensors are labeled with numeral 54.
  • Non-limiting examples of sensors 52, 54 include pressure sensors, temperature sensors, flow rate sensors, pump rate sensors, RPM sensors, vibration sensors, load sensors, e.g. hook load sensors, torque sensors, weight sensors, etc.
  • a suitable communication system 56 may be used to transfer data and command signals.
  • the communication system 56 may utilize wired pipe, optical fibers, EM signals, RF signals, acoustic signals, pressure pulses (e.g., mud pulses), etc.
  • a flow chart 70 illustrating one non-limiting method of the present disclosure. While the steps are serially arranged, it should be understood that some steps may be taken in parallel and that the order of certain steps can be varied.
  • a database is formed using historical information obtained during seismic surveys, logging-while drilling, lab results, wireline logging, etc.
  • historical it is meant that the information is obtained prior to commencement of the liner hanging or cementing operation.
  • the information in the database can relate to the formation (e.g.
  • the database can also include information pertaining to equipment and materials used during the liner hanging and / or cementing operations; e.g. , cement properties, spacer fluid properties, properties of equipment such as rubber, equipment behavior such as pressure spikes when darts seal are set, etc.
  • real-time or near real-time information relating to one or more operating parameters is acquired.
  • real-time or “near real-time,” it is meant that such information is collected while liner hanging or cementing operations are ongoing.
  • the operating parameters may be for surface and / or downhole equipment.
  • Illustrative surface parameters include, but are not limited to, pump flow rates (e.g. , drilling mud, spacer fluid, cement, etc.), pressure (e.g. , bore pressure, annulus pressure, etc.), pressure, temperature, flow rate sensors, pump rate, RPM, vibration, load, e.g. hook load sensors, torque sensors, weight sensors, etc. and properties of returning fluids and/or entrained material such as mud cake or cement.
  • Illustrative downhole parameters include, but are not limited to, pressure, temperature, flow rate, pump rate, RPM, vibration, load, e.g. hook load, torque, weight, etc..
  • the measurements of such parameters sensors 52, 54 may provide absolute values and also the basis for estimating fluctuations or rates of change (e.g., for torque).
  • the fluid returning to the surface may be analyzed to determine the quality / quantity of the cement slurry and the composition may be analyzed to determine the nature of the returning fluid (e.g., spacer fluid vs. drilling mud).
  • the information from the database and acquired real-time information is used to build one or more models that may utilize algorithms to determine one or more subsequent process steps such as identifying a parameter or process step for adjustment.
  • the models are configured to estimate the condition or behavior of the completion equipment and / or wellbore environment and determine a course of action to optimize subsequent activity.
  • the output of this set may be advice, command signals, and / or alarms.
  • the term "advice” is information communicated to a human operator
  • a "command signal” is a message that can be understood by a machine to perform or stop performing a given task or to adjust or otherwise amend a parameter that is used to perform a task
  • an "alarm” is a special category of "advice” that indicates that an "out of norm” condition may be present.
  • the model may comprise formation models, geo-mechanical models, hydraulics models, cement setting speed models, and models estimating the risk of channeling and stand-off annulus distribution.
  • Such model generally are mathematically based algorithms and / or data maps providing one, two, or three dimensional distributions of a particular parameter in space or time that is either based on calculated data, measured data, or both.
  • the environment and dynamics being simulated is shown in FIG. 3.
  • FIG 3 schematically illustrates a liner hanger assembly 20 and a liner 24 at a well bottom 34 that traverses a formation having a weak zone 36.
  • Cement 38 is shown being pumped out of the completion assembly 16 and into the annulus 22 between the outer surface of the completion assembly 16 and a borehole wall.
  • several parameters influence the cementing operation, including rotation 40 of the liner assembly, a height 42 of the column of cement 38, the strength of the weak zone 36, and equivalent circulation density (ECD), which corresponds to the pressure of the fluid when circulating.
  • ECD equivalent circulation density
  • FIGS. 4A, B Two non-limiting examples of relationships that may be incorporated into a model are shown in FIGS. 4A, B.
  • torque Tq
  • An envelope 94 defines a set of values 96 for acceptable combinations of cement column height and torque.
  • SPP stand pipe pressure
  • An envelope 104 defines a set of values 106 for acceptable combinations of cement column height and SPP.
  • the models may use these envelopes and values in conjunction with real time information from sensors to determine whether changes should be made to operating parameters (e.g., pressure, temperature, flow rate, pump rate, RPM, vibration, load, e.g. hook load, torque, weight, etc.) to improve efficiency, quality, speed, etc.
  • operating parameters e.g., pressure, temperature, flow rate, pump rate, RPM, vibration, load, e.g. hook load, torque, weight, etc.
  • the outputs are constructed to optimize timing, reduce operational risks such as stuck pipe, and enable efficient excess cement removal.
  • the models may use mathematical relationships, data sets, tables, etc. to characterize acceptable and / or unacceptable behavior, operating characteristics, or operations under pre-determined circumstances.
  • the string / liner is rotated at low speeds.
  • the selection of rotation speed is a balance between (i) keeping ECD low enough for the formation not to fracture (by keeping pump rate and RPM below certain thresholds), (ii) keeping cement channeling low by keeping pump rate at optimum rate which is usually high and RPM low or vice versa, (iii) and minimizing time spent by keeping pump rate high, especially given the cement setting speed. While a higher pump rate generally helps with channeling, by manipulating RPM and flow, one can influence the channeling effect by reducing or increasing these parameters independently. Other considerations may include fatigue of liner connection when experiencing too many total revolutions at a certain local hole curvature. The appropriate RPM, and other operating parameters, can change gradually over the course of the cement pumping procedure.
  • a relatively simple model may be used to control torque applied to the rotating liner. As cement sets, the rotating torque increases as the viscosity increases.
  • the model may set a torque limit at which the running string must be pulled out to prevent the running string from being stuck in the well. In this particular case, the model may comprise not more than a single torque threshold value.
  • More complex models may be used to optimize and evaluate the actual cleanup effectiveness.
  • a model would comprise parameters such as RPM, time, and/or the axial movement speed of the running string / liner, depth range, and number of repetitions of movement of a running string / liner.
  • This model would make particular use of measurements of pressure and torque, and possibly require downhole sensing in the annulus.
  • a communication system 56 at the top of the liner 20 may be utilized to communicate pressure, temperature, flow rate, pump rate, RPM, vibration, load, e.g. hook load, torque, weight, etc..
  • surface returns can be evaluated. The evaluation would primarily be used to characterize the nature of the returns and the distribution over time of the returns of cement slurry.
  • Illustrative tools and sensor for such evaluation include a cuttings catcher, a measurement system for density, chemical or mineralogical composition, or similar devices (not shown).
  • Exemplary models may also be configured for cement channeling prediction. Rotating at low RPM may result in the cement not fully encircling the liner (i. e. , no full circumference), which is due to low friction / low torque. Rotating at increasing RPM while evaluating torque changes can help predict gaps in cement column and when they are filled.
  • the torque when rotating at different rpms with the cement in the annulus is a function of the amount of circumference of the liner in contact with cement.
  • the narrow annulus on the lowside frequently is not filled with the viscous cement, but needs rotation of a certain speed to squeeze the cement fully around the narrow lowside. This would show as an increase in torque that can be observed downhole or on surface.
  • a non-limiting test may involve initiating a sequence of rotations at 10, 20, 30, and 40 RPM for a few minutes each, recording the torque increase and comparing the increases to modeled or offset torque curves of offset wells or earlier times with different location of the cement slurry. The visualized curves in comparison then may indicate the area of liner surface covered with cement.
  • Exemplary models may also be configured for mud cake removal prediction.
  • the efficiency of spacer fluids in removing mud cake is influential for a cementing operation.
  • a model may provide real time analysis of spacer fluid mud cake content volume / quality. This can be evaluated in realtime by checking the mud cake weight over time in the returns; e.g. by using a cuttings catcher. The evaluation may be inputted into the model to identify the depths at which residual mud cake exists.
  • this may then trigger the decision to extend or abbreviate the spacer pumping or to change quality or quantity of the cement pumped.
  • illustrative input parameters include: open hole volume, formation integrity, cement volume, cement rheology, pump efficiencies, acceptable pump rates, acceptable rotation rates, and pressures (e.g., stand pipe pressure (SPP)), downhole pressure.
  • SPP stand pipe pressure
  • These inputs may be used to automate critical operational parameters for cementing liners and casing downhole based on real-time simulations (RPM, SPP, flow rate).
  • the models may simulate or predict relationships between RPM and flow rate, predict cement / spacer interface, predict cement column height (e.g., using torque and pressure), and / or estimate formation strength to manage flow rate (e.g., using equivalent circulating density).
  • Illustrative actions may include starting / stopping rotation of the liner, when to apply weight or pull up the liner, when to actuate downhole mechanisms (e.g., dropping a dart).
  • command signals may be sent to actuators for downhole devices such as pumps, mixing equipment, valves, heaters, packers, top drive (or other surface rotary power source), etc.
  • Command signal may include activation commands to activate actuators for such devices.
  • command signals may include an activation command to activate an actuator that is configured to allow pressurization of a packer or packer element in order to set the packer.
  • Other downhole devices include communication modules, electrical power sources, and or hydraulic power sources.
  • human operators may be given the opportunity to stop or modify the action(s) to be taken.
  • the controller 50 presents a proposed course of action(s) to human operators, who then decide whether or not implement such action(s).

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  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Quality & Reliability (AREA)
  • Geophysics (AREA)
  • Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
  • Earth Drilling (AREA)
  • General Engineering & Computer Science (AREA)
  • Operations Research (AREA)

Abstract

Un procédé de commande d'une opération de complétion de puits peut consister à fournir un accès de contrôleur à un modèle qui détermine un paramètre de processus relatif à l'opération de complétion de puits et à estimer un paramètre d'opération tout en menant l'opération de complétion de puits à l'aide d'un capteur. Un réglage de paramètre relatif à l'opération de complétion de puits peut être déterminé au moyen du contrôleur à l'aide du modèle et du paramètre de fonctionnement estimé. Le contrôleur peut générer une instruction relative à l'opération de complétion de puits sur la base du réglage de paramètre déterminé relatif à l'opération de complétion de puits. Un appareil associé peut comprendre un système de complétion permettant d'effectuer l'opération de complétion de puits, un capteur permettant d'estimer le paramètre d'opération, et un contrôleur permettant de générer l'instruction tel que décrit ci-dessus.
PCT/US2018/042300 2017-07-19 2018-07-16 Procédés et systèmes de cimentation et de suspension de colonne perdue automatisées WO2019018292A1 (fr)

Priority Applications (3)

Application Number Priority Date Filing Date Title
CA3070403A CA3070403A1 (fr) 2017-07-19 2018-07-16 Procedes et systemes de cimentation et de suspension de colonne perdue automatisees
BR112020001111-8A BR112020001111A2 (pt) 2017-07-19 2018-07-16 métodos e sistemas para cimentação automatizada e suspensão de liner
EP18834406.3A EP3655624A4 (fr) 2017-07-19 2018-07-16 Procédés et systèmes de cimentation et de suspension de colonne perdue automatisées

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US15/654,164 2017-07-19
US15/654,164 US20190024485A1 (en) 2017-07-19 2017-07-19 Methods and systems for automated cementing and liner hanging

Publications (1)

Publication Number Publication Date
WO2019018292A1 true WO2019018292A1 (fr) 2019-01-24

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PCT/US2018/042300 WO2019018292A1 (fr) 2017-07-19 2018-07-16 Procédés et systèmes de cimentation et de suspension de colonne perdue automatisées

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US (1) US20190024485A1 (fr)
EP (1) EP3655624A4 (fr)
BR (1) BR112020001111A2 (fr)
CA (1) CA3070403A1 (fr)
WO (1) WO2019018292A1 (fr)

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US10954729B2 (en) 2015-08-31 2021-03-23 Helmerich & Payne Technologies, Llc System and method for estimating cutting volumes on shale shakers
GB201522713D0 (en) * 2015-12-23 2016-02-03 Optasense Holdings Ltd Determing wellbore properties
WO2020086594A1 (fr) * 2018-10-22 2020-04-30 Motive Drilling Technologies, Inc. Systèmes et procédés pour opérations de forage de champ de pétrole utilisant la vision artificielle
US11566514B2 (en) * 2020-10-19 2023-01-31 Halliburton Energy Services, Inc. Bottomhole choke for managed pressure cementing

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US20060173625A1 (en) * 2005-02-01 2006-08-03 Smith International, Inc. System for optimizing drilling in real time
US20140180658A1 (en) * 2012-09-04 2014-06-26 Schlumberger Technology Corporation Model-driven surveillance and diagnostics
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Also Published As

Publication number Publication date
EP3655624A1 (fr) 2020-05-27
EP3655624A4 (fr) 2021-03-17
BR112020001111A2 (pt) 2020-07-21
CA3070403A1 (fr) 2019-01-24
US20190024485A1 (en) 2019-01-24

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