WO2017129523A1 - Procédé et système d'ajustement automatisé de propriétés de boue de forage - Google Patents

Procédé et système d'ajustement automatisé de propriétés de boue de forage Download PDF

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Publication number
WO2017129523A1
WO2017129523A1 PCT/EP2017/051329 EP2017051329W WO2017129523A1 WO 2017129523 A1 WO2017129523 A1 WO 2017129523A1 EP 2017051329 W EP2017051329 W EP 2017051329W WO 2017129523 A1 WO2017129523 A1 WO 2017129523A1
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WO
WIPO (PCT)
Prior art keywords
mud
optimization
properties
control loop
primary
Prior art date
Application number
PCT/EP2017/051329
Other languages
English (en)
Inventor
Patricia ASTRID
Jan-Jette BLANGÉ
Svetlana Viktorovna HAGERAATS-PONOMAREVA
Timothy Engelbertus SCHUIT
Original Assignee
Shell Internationale Research Maatschappij B.V.
Shell Oil Company
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 Shell Internationale Research Maatschappij B.V., Shell Oil Company filed Critical Shell Internationale Research Maatschappij B.V.
Priority to AU2017213036A priority Critical patent/AU2017213036B2/en
Priority to EP17700864.6A priority patent/EP3408491B1/fr
Priority to US16/071,976 priority patent/US20190055797A1/en
Priority to CA3010427A priority patent/CA3010427A1/fr
Publication of WO2017129523A1 publication Critical patent/WO2017129523A1/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/06—Arrangements for treating drilling fluids outside the borehole
    • E21B21/062—Arrangements for treating drilling fluids outside the borehole by mixing components
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/06—Arrangements for treating drilling fluids outside the borehole
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/08—Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/10—Valve arrangements in drilling-fluid circulation systems
    • E21B21/106—Valve arrangements outside the borehole, e.g. kelly valves
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B44/00—Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP 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
    • E21B49/08—Obtaining fluid samples or testing fluids, in boreholes or wells
    • E21B49/087—Well testing, e.g. testing for reservoir productivity or formation parameters
    • E21B49/0875—Well testing, e.g. testing for reservoir productivity or formation parameters determining specific fluid parameters

Definitions

  • the present invention relates to a method and system for automated adjustment of drilling mud properties in a mud recirculation system of a rig for drilling an
  • drilling mud a drilling fluid, generally known as drilling mud, is circulated in downward direction through the interior of the drill string and then in upward direction through the surrounding annulus to lift drill cuttings to the surface, to clean and cool the drill bit, to stabilize the borehole, to lubricate the rotating drill string and to provide hydrostatic head for preventing well kicks.
  • the drill cuttings are removed from the drilling mud in a mud cleaning assembly and the mud volume is adjusted by adding fresh mud and the composition of the re-injected mud is adjusted by adding mud additives in a mud treatment assembly to generate desired mud properties, such as mud density, viscosity and pH.
  • a fluid handling system is described in WO 97/42395 Al, specifically for underbalanced drilling operations.
  • a control unit determines or computes values of a number of operating parameters of the fluid handling system and controls the operation of the various devices based on such parameters according to programs and models provided to the control unit.
  • the control unit which receives signals from sensors, is coupled to the various devices in the system for controlling the operations of the devices, including control valves. The control unit periodically or
  • a method for automated adjustment of drilling mud properties in a mud recirculation system of a rig for drilling an underground wellbore comprising inducing hierarchal primary and secondary optimization and control loops to adjust injection rates of mud additives into a circulated mud stream flowing through an automated mud treating assembly, to continuously keep mud properties, comprising density, viscosity, pH and optionally other mud properties, within specifications set by a model-based tertiary optimization and control loop.
  • a system for automated adjustment of drilling mud properties in a mud recirculation system of a rig for drilling an underground wellbore comprising hierarchal primary and secondary optimization and control loops to adjust injection rates of mud additives into a mud
  • circulation conduit in an automated mud treating assembly arranged to continuously keep mud properties, comprising density, viscosity, pH and optionally other mud properties, within specifications set a model-based tertiary
  • Such mud recirculation system may form part of a drilling assembly for excavating an
  • the mud recirculation system may be applied on a rig for drilling an underground formation.
  • hierarchal primary and secondary optimization and control loops are induced to control an automated mud treating assembly which injects additives that continuously keep density
  • a tertiary model-based optimization and control loop may be run to set the specifications.
  • the tertiary optimization and control loop determines specifications for mud properties comprising density, viscosity, pH and optionally other mud properties on the basis of a model which optimizes desired downhole properties of the injected mud for assessed downhole drilling conditions.
  • the secondary optimization and control loop determines the required additives to achieve the desired setpoint mud properties.
  • the required additives as computed by the secondary loop then become the setpoints for the primary control loops, which open additive injection valves to achieve the required additives.
  • the tertiary optimization and control loop may also determine setpoints of flow rate of the circulated mud stream, which may be fed directly to the pump control system without intervention by the secondary and primary optimization and control loops.
  • the mud properties may be measured by a sensor assembly that measures density, viscosity, pH and/or other
  • sensor assembly may comprise an upstream sensor assembly comprising primary and secondary untreated mud property sensors for monitoring the
  • the primary untreated mud flux property sensor may be arranged in the mud recirculation system between the secondary untreated mud flux property sensor and the mud treating assembly.
  • the automated mud treating assembly may comprise additive injection control devices, suitably injection control valves, that are controlled by the primary
  • the primary, secondary and tertiary optimization and control loops operate at different time scales and hierarchies, whereby:
  • the tertiary optimization and control loop is the master of the secondary optimization and control loop and operates at the highest time scale or lower sampling rate; and - the secondary optimization and control loop is governed by, also called the slave of, the tertiary optimization and control loop and operates at the lower time scale or higher sampling rate than the tertiary optimization and control loop but higher time scale and lower sampling rate than the primary optimization and control loop which is governed by, also called the slave of, the secondary optimization and control loop.
  • the tertiary optimization and control loop may comprise an optimization module that determines the ranges or the setpoints of the primary treated mud properties given the objective functions of the tertiary optimization and control loop such as ensuring sufficient cutting transport, wellbore mechanical stability and given estimates of:
  • the ranges of the mud property values as determined by the optimization module of the tertiary loop may suitably be included as the desired ranges to be honoured by a multivariable control algorithm in the secondary control loop.
  • the multivariable control algorithm suitably provides a setpoint for the injection rate of each one of the injected mud additives.
  • the multivariable control algorithm may be a Model Predictive Controller (MPC) algorithm that casts the multivariable control problem as an optimal control problem with an objective function of minimizing the deviation of the primary treated mud properties from the desired ranges given the minimum and maximum amount of additives to be added at each cycle and the models between mud properties to be controlled and additives as well as the drilling and mud flux circulation rates, which casts the mud properties control problem into a multivariable optimization solution with constraints over a selected time horizon that take into account the amount of time required for the mud to be circulated through the borehole and back to the drilling rig at earth surface.
  • MPC Model Predictive Controller
  • the multivariable control MPC algorithm may be provided with models identifying mathematical relationships between the additives, mud properties and measured variations in drilling rates that affect variations in drill cuttings concentration .
  • the proposed method may be implemented in a system for automated adjustment of drilling mud properties in the mud recirculation system.
  • Figure 1 shows a drilling assembly 1
  • Drilling mud 6 is pumped down through the drill string 3 as illustrated by arrows 7 and up through the surrounding annulus 8 as illustrated by arrow 9 to lift drill cuttings 10 to the earth surface 11, where the drill cuttings are removed from the returned mud 6 in a mud shaker and filter assembly 12.
  • the cleaned mud 6 is subsequently transported via a mud recirculation conduit 13 and a top drive swivel 14 back into the drill string 3. Even though the mud is
  • the mud share and filter assembly 12 is taken to be "the end" of the mud recirculation cycle, which is considered to be the most "downstream” end of the cycle.
  • the most "upstream” end of the cycle is the transition from the mud share and filter assembly 12 into the mud
  • the mud recirculation conduit 13 is connected to a mud mixing tank 15 in which additional mud can be added from a mud tank 16 and in which the mud is mixed by a mixer 17 to homogenize the mud 6 before it is pumped back into the drill string 3 by a mud pump assembly 17,18.
  • the mud mixing tank 15 may be referred to as untreated mud mixing tank 15, as it is located upstream of a mud treating assembly 20 to which the mud recirculation conduit 13 is furthermore connected. In this mud treating assembly 20 mud additives
  • 21-24 are injected into the mud, to ultimately adjust mud properties, such as density, viscosity and pH.
  • the mud treating assembly 20 is suitably equipped with an automated additive injection control system 25 that automatically adjusts the injection rates of each of the mud additives 21-24 on the basis of measurements of the properties of untreated mud 6 upstream of the treating assembly 20 by primary and secondary untreated mud property sensors 26-27 and measurements of the treated mud 6 downstream of the treating assembly 20 by primary and secondary treated mud property sensors 28-29.
  • An untreated mud mixing tank 15 may be arranged in the mud recirculation system 13 between the primary and secondary untreated mud property sensors 26-27.
  • the primary and secondary untreated and treated mud property sensors 26-27 and 28-29 form part of a
  • Hierarchical closed loop control system which contains two closed loops 30-31, where loop 30 is configured as a primary or master control loop and the other loop 31 is configured as a secondary or slave control loop.
  • Both closed loop 30-31 make use of assemblies of substantially similar mud property sensors 26-29, located in predefined positions upstream and downstream of the mud treating assembly 20, providing necessary data for mud property monitoring and control.
  • the automated mud treating system 25 may comprise an additive injection optimization module comprising a computer programmed with algorithms known as Wells Advanced Kernels (WAKs) and a mathematical optimization module to provide the secondary multivariable control loop (for example the MPC alogrithm) with specifications for mud properties such as density, viscosity, pH and optionally other mud properties based on advanced drilling parameters modelling and real time data.
  • WAKs Wells Advanced Kernels
  • MPC alogrithm multivariable control loop
  • Setpoints for circulation flow rate which may also be computed, may be fed directly to the rig mud pump assembly 17,18.
  • the secondary multivariable control loop then computes the required mud additives 21-24.
  • the required mud additives 21-24 as computed by the secondary optimization and control loop become the set points for the primary closed loop control system 30, which adjusts the valve openings accordingly to meet the setpoints of each of the mud additives 21-24.
  • the automated drilling mud treating system 20, 25 is able to adjust mud properties more accurately than manually controlled drilling fluid additive systems that may still be present on the drilling rig 33 for start-up and/or as a back-up in case of malfunctioning of the automated mud treating system 20,25.
  • the automated additive injection control system 20,25 automatically adjusts during at least part of the drilling operations the drilling fluid additive injection rates to adjust the mud properties to a desired set-point based on a predefined reference signal.
  • the mud treating system 20 is arranged in an additives and mud mixing tank 34, which is designed in such a way to ensure sufficient mixing quality and appropriate response time to bring the mud properties back to a desired
  • the size of the mixing tank 34 may suitably be determined by taking into account the following aspects:
  • the flow rates of the mud additives 21-24 into the additives and mud mixing tank 34 are regulated by the automated additive injection control system 25, which uses the data generated by the mud flux property sensor
  • the automated mud treating system 20,25 may furthermore be provided with an MPC algorithm, which casts the mud properties control problem into a multivariable
  • the MPC algorithm is a control approach that takes the time horizon and input constraints into account .
  • the MPC algorithm may be provided with models
  • One option is to correct the model by adding a filter, for example a Kalman Filter, that corrects and updates the model continuously based on measurement data.
  • a filter for example a Kalman Filter
  • Another option is to use an automatic model-rebuilding mechanism if the amount of updates from the Kalman Filter is too big.
  • the automatic model-rebuilding mechanism is carried out by varying the additive signals systematically in such a way that meaningful mathematical relationships can still be derived without disturbing the drilling operations. The input signals and measured mud properties resulting from this systematic variation is then used to derive a new model for the control algorithm.
  • the required mud property specification and associated additive injection setpoints in the automated mud treating system 20,25 can be updated automatically by means of an optimization algorithm.
  • the Wells Advanced Kernels may provide a prediction of the cutting transport state, the equivalent circulating density, and, optionally, the torque and drag profile along the borehole 5 and, also optionally, the elastic borehole stability.
  • mathematical models between the mud properties and these parameters can be derived by feeding the kernels with mud property values and fit models between the mud properties and the cuttings transport, drill string torque and drag and borehole stability.
  • the selected mathematical model (s) and operational ob ective (s ) such as maximize borehole cleaning and maximize borehole stability and applying a linear or nonlinear optimization algorithm, the appropriate setpoints for the mud additive injection rates can be derived automatically from the selected model (s) .

Abstract

Selon la présente invention, les propriétés de boue de forage dans un système de recirculation de boue (13) d'un ensemble de forage de puits de pétrole et/ou de gaz (1) sont automatiquement ajustées par un ensemble de traitement de boue automatisé (20, 25) qui est contrôlé par des boucles d'optimisation et de commande primaires et secondaires hiérarchiques (30, 31) qui maintiennent en continu la masse volumique, la viscosité, le pH et d'autres propriétés de la boue dans des spécifications définies par une boucle d'optimisation et de commande tertiaire à base de modèle afin de garantir que les propriétés de la boue conduisent à un transport de sédiments de forage, une stabilité de trou de forage, des caractéristiques hydrauliques de trépan suffisants, et un couple et une traînée de frottement minimaux.
PCT/EP2017/051329 2016-01-25 2017-01-23 Procédé et système d'ajustement automatisé de propriétés de boue de forage WO2017129523A1 (fr)

Priority Applications (4)

Application Number Priority Date Filing Date Title
AU2017213036A AU2017213036B2 (en) 2016-01-25 2017-01-23 Method and system for automated adjustment of drilling mud properties
EP17700864.6A EP3408491B1 (fr) 2016-01-25 2017-01-23 Procédé et système de réglage automatique des propriétés de la boue de forage
US16/071,976 US20190055797A1 (en) 2016-01-25 2017-01-23 Method and system for automated adjustment of drilling mud properties
CA3010427A CA3010427A1 (fr) 2016-01-25 2017-01-23 Procede et systeme d'ajustement automatise de proprietes de boue de forage

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
EP16152522.5 2016-01-25
EP16152522 2016-01-25

Publications (1)

Publication Number Publication Date
WO2017129523A1 true WO2017129523A1 (fr) 2017-08-03

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PCT/EP2017/051329 WO2017129523A1 (fr) 2016-01-25 2017-01-23 Procédé et système d'ajustement automatisé de propriétés de boue de forage

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US (1) US20190055797A1 (fr)
EP (1) EP3408491B1 (fr)
AU (1) AU2017213036B2 (fr)
CA (1) CA3010427A1 (fr)
WO (1) WO2017129523A1 (fr)

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GB2582841A (en) * 2019-08-19 2020-10-07 Clear Solutions Holdings Ltd Automated fluid system

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US10989046B2 (en) * 2019-05-15 2021-04-27 Saudi Arabian Oil Company Real-time equivalent circulating density of drilling fluid
US11428099B2 (en) 2019-05-15 2022-08-30 Saudi Arabian Oil Company Automated real-time drilling fluid density
US20210017847A1 (en) * 2019-07-19 2021-01-21 Baker Hughes Oilfield Operations Llc Method of modeling fluid flow downhole and related apparatus and systems
US20220234010A1 (en) * 2021-01-25 2022-07-28 Saudi Arabian Oil Company Automated recycled closed-loop water based drilling fluid condition monitoring system
US11655690B2 (en) 2021-08-20 2023-05-23 Saudi Arabian Oil Company Borehole cleaning monitoring and advisory system
CN114233220B (zh) * 2022-01-13 2022-06-03 东北石油大学 一种降低高有害固相含量水基钻井液泥饼摩阻的方法

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US3473368A (en) * 1967-12-27 1969-10-21 Mobil Oil Corp Method and apparatus for continuously monitoring properties of thixotropic fluids
WO1997042395A1 (fr) 1996-05-03 1997-11-13 Baker Hughes Incorporated Systeme de manutention de fluides en boucle fermee utilise au cours du forage de puits
WO2002050398A1 (fr) * 2000-12-18 2002-06-27 Impact Engineering Solutions Limited Systeme de gestion de liquide en circuit ferme pour forage de puits
WO2010085401A1 (fr) * 2009-01-23 2010-07-29 Nch Corporation Procédé de surveillance de propriétés de boue de forage
WO2013074878A1 (fr) * 2011-11-18 2013-05-23 M-I L.L.C. Procédés et systèmes de mélange pour fluides

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3473368A (en) * 1967-12-27 1969-10-21 Mobil Oil Corp Method and apparatus for continuously monitoring properties of thixotropic fluids
WO1997042395A1 (fr) 1996-05-03 1997-11-13 Baker Hughes Incorporated Systeme de manutention de fluides en boucle fermee utilise au cours du forage de puits
WO2002050398A1 (fr) * 2000-12-18 2002-06-27 Impact Engineering Solutions Limited Systeme de gestion de liquide en circuit ferme pour forage de puits
WO2010085401A1 (fr) * 2009-01-23 2010-07-29 Nch Corporation Procédé de surveillance de propriétés de boue de forage
WO2013074878A1 (fr) * 2011-11-18 2013-05-23 M-I L.L.C. Procédés et systèmes de mélange pour fluides

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2582841A (en) * 2019-08-19 2020-10-07 Clear Solutions Holdings Ltd Automated fluid system
WO2021032750A1 (fr) * 2019-08-19 2021-02-25 CLEAR SOLUTIONS (HOLDINGS) lIMITED Système de fluide automatisé
GB2582841B (en) * 2019-08-19 2021-09-08 Clear Solutions Holdings Ltd Automated fluid system
CN114502818A (zh) * 2019-08-19 2022-05-13 清晰解决方案(控股)有限公司 自主式流体系统

Also Published As

Publication number Publication date
EP3408491B1 (fr) 2020-04-29
AU2017213036A1 (en) 2018-07-12
AU2017213036B2 (en) 2019-08-01
EP3408491A1 (fr) 2018-12-05
US20190055797A1 (en) 2019-02-21
CA3010427A1 (fr) 2017-08-03

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