WO2019226854A1 - Dispositif de commande régulateur destiné à être utilisé dans une unité catalytique d'oléfines - Google Patents

Dispositif de commande régulateur destiné à être utilisé dans une unité catalytique d'oléfines Download PDF

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Publication number
WO2019226854A1
WO2019226854A1 PCT/US2019/033665 US2019033665W WO2019226854A1 WO 2019226854 A1 WO2019226854 A1 WO 2019226854A1 US 2019033665 W US2019033665 W US 2019033665W WO 2019226854 A1 WO2019226854 A1 WO 2019226854A1
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WO
WIPO (PCT)
Prior art keywords
regenerator
temperature
bed temperature
determined
setpoint
Prior art date
Application number
PCT/US2019/033665
Other languages
English (en)
Inventor
Javier Vazquez ESPARRAGOZA
Surajit DASGUPTA
Michael Tallman
Priyesh Harilal THAKKER
Original Assignee
Kellogg Brown & Root 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 Kellogg Brown & Root Llc filed Critical Kellogg Brown & Root Llc
Priority to KR1020207033600A priority Critical patent/KR20210003202A/ko
Priority to CN201980034551.0A priority patent/CN112166171B/zh
Priority to EP19808208.3A priority patent/EP3797143A4/fr
Priority claimed from US16/420,350 external-priority patent/US11118117B2/en
Publication of WO2019226854A1 publication Critical patent/WO2019226854A1/fr
Priority to SA520420586A priority patent/SA520420586B1/ar

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Classifications

    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G11/00—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils
    • C10G11/14—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts
    • C10G11/18—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts according to the "fluidised-bed" technique
    • C10G11/182—Regeneration
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G3/00—Production of liquid hydrocarbon mixtures from oxygen-containing organic materials, e.g. fatty oils, fatty acids
    • C10G3/60—Controlling or regulating the processes
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G11/00—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils
    • C10G11/14—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts
    • C10G11/18—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts according to the "fluidised-bed" technique
    • C10G11/187—Controlling or regulating
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G3/00—Production of liquid hydrocarbon mixtures from oxygen-containing organic materials, e.g. fatty oils, fatty acids
    • C10G3/42—Catalytic treatment
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G51/00—Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more cracking processes only
    • C10G51/06—Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more cracking processes only plural parallel stages only
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/1088—Olefins
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/40—Characteristics of the process deviating from typical ways of processing
    • C10G2300/4006—Temperature
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2400/00—Products obtained by processes covered by groups C10G9/00 - C10G69/14
    • C10G2400/20—C2-C4 olefins
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P30/00—Technologies relating to oil refining and petrochemical industry
    • Y02P30/20—Technologies relating to oil refining and petrochemical industry using bio-feedstock

Definitions

  • the present disclosure relates to catalytic olefins conversion. More particularly, the present disclosure relates to regenerator bed temperature control of a catalytic conversion unit
  • Olefins are a class of chemicals such as ethylene, propylene, and butylene.
  • the olefins are building blocks for a wide variety of products such as plastics, rubbers, and solvents. Further, the olefins are produced from natural gas liquids and refinery products such as naphtha, kerosene, and gas oil. A wide variety of processes may be used to produce, recover, and convert the olefins.
  • Olefins may be produced using Olefin producing technologies such as, but not limited to, steam cracking, Fluid Catalytic Cracking (FCC) and catalytic dehydrogenation (CATOFIN®). Further, olefins may be recovered using light olefins recovery technology.
  • FCC Fluid Catalytic Cracking
  • CAFIN® catalytic dehydrogenation
  • Olefins are converted to higher valued products such as, but not limited to, polyethylene, polypropylene, and alkylate. Olefins may be converted using Olefins conversion technology (OCT), ethylene dimerization, and comonomer production technology (CPT).
  • OCT Olefins conversion technology
  • CPT comonomer production technology
  • converter/regenerator bed temperature One factor that plays an important role during an operation of the catalytic olefins technology is converter/regenerator bed temperature.
  • the present disclosure is directed to effective control of regenerator bed temperature.
  • FIG. 1 depicts an illustrative system diagram 100 utilizing an Advanced Process Control (APC)Z Advanced Regulatory Control (ARC) strategy for conversion of catalytic olefins, according to an embodiment
  • FIG. 2 depicts an illustrative block diagram 200 showing functioning of the APC/ARC strategy, according to an embodiment
  • FIG. 3 depicts an illustrative DCS screen interlace 300, according to an embodiment
  • FIG. 4 depicts another illustrative DCS screen interface 400, according to an embodiment.
  • an advanced regulatory controller for a converter of a catalytic olefins unit is described.
  • a catalytic olefins technology described henceforth, may provide a method for converting low value olefins streams to valuable propylene and ethylene products.
  • the low value olefins streams may comprise mixed butenes, pentenes, Fluid Catalytic Cracking (FCC) light gasoline, and coker gasoline.
  • FCC Fluid Catalytic Cracking
  • an FCC type converter i.e., reactor- regenerator
  • die catalytic olefins technology may include innovative heat integration features and may be designed for a regenerator bed temperature control.
  • °C or even 730 °C may be needed to reduce the afterburning.
  • the converter/regenerator bed temperature may swing significantly from disturbances in one or more variables such as feed rate, feed temperature, disengage overhead temperature, and stripper level.
  • feed rate feed temperature
  • disengage overhead temperature and stripper level.
  • the feed rate, feed temperature, reactor temperature or stripper level changes at times, and coke make automatically moves in a correct direction to minimize the impact on the converter/regenerator bed temperature.
  • FCC Fluid Catalytic Converters
  • Embodiments of the present disclosure provide system and method to control regenerator bed temperature.
  • FIG. 1 depicts an illustrative system diagram 100 utilizing an Advanced Process
  • regenerator 110 may receive combustion air
  • the regenerator 110 outputs an effluent 120, which may be a product, and a flue gas 122.
  • the regenerator bed temperature controller 102 and the flow controller 104 may henceforth be referred interchangeably as TIC controller 102 and FIC controller 104 respectively.
  • API Advanced Process Control
  • the controller 1 14 may be a general purpose computer having processors, memory, and algorithms.
  • the APC application may include selectors 116 for controlling a manipulated variable, such as flow of the tail gas 108 or the fuel oil 106 .
  • a manipulated variable such as flow of the tail gas 108 or the fuel oil 106 .
  • an initial setting of the manipulated variable may be used for controlling flow of the fuel oil 106.
  • the APC application may include a controller variable such as a regenerator bed temperature (T) and disturbance variables such as feed rate 118 (i.e., feed flow) to a unit
  • the APC application may further include associated variables such as a flue gas excess oxygen
  • a basic design of the ARC application may be equivalent to a model predictive controller.
  • the model predictive controller may be used to provide a feed forward element to the TIC controller 102, and thus may allow the TIC controller 102 to be more aggressive while retaining robustness of control.
  • a control action may be represented using below provided control equation 1 :
  • Equation 1 “e” denotes model predictive error, i.e., SP - PV*, where PV* represents a model predicted steady state value of a Process Variable (PV).
  • PV* represents a model predicted steady state value of a Process Variable (PV).
  • equation 1 may correspond to a Proportional Integral (P-I) controller.
  • P-I Proportional Integral
  • APC/ARC controller may fall in a general class of controllers, i.eotro a Generalized Predictive Controller (GPC).
  • GPC Generalized Predictive Controller
  • a strategy of the Generalized Predictive Controller (GPC) may be used for small applications and/or for cases where model prediction may be explicitly derived.
  • Strategy of the Generalized Process Controller (GPC) may be further employed, where a basic control strategy may be represented using a below provided equation 2.
  • control strategy may be defined in a discrete form, using a below provided equation 3.
  • a new setpoint for the fuel oil, W F0 may be determined using a below provided equation 4.
  • equation 3 indicates fuel oil setpoint change from
  • manipulated variable denotes an integral time parameter of the controller, and 0
  • Equation 6Further the predicted regenerator bed
  • temperature may be determined as a sum of current measured temperature and a predicted change due to changes in any or all of the disturbance variables, using below mentioned equation 7
  • a current T PV 1 value may be used in place of a previous value, i.e.,
  • AT cal may be considered as a linear function of gains between the regenerator bed temperature and the disturbance variables, as defined below using equation 8.
  • AMF denotes a change in feed flow to the unit i.e. WFI - WFO, from time to to the time ti, where ti > to and (ti - to) define the ARC time period.
  • GF may be calculated as ST/dWp, where GF denotes estimated steady state gain between the regenerator bed temperature and the feed flow.
  • ATF denotes a change in feed temperature to the unit, TFI - TFO, from time to to time ti.
  • GTF may be calculated as 5T/5TU, where GTF denotes estimated steady state gain between the regenerator bed temperature and the feed temperature, ATTD denotes change on the disengager overhead temperature to the unit, TTDI - TTDO, from time to to time ti.
  • GOT denotes estimated steady state gain between the regenerator bed temperature and the disengager overhead temperature, and may be determined as 5T/5TDT.
  • ASL denotes a change on the stripper level in the unit, S u - SLO, from time to to time ti.
  • GSL denotes estimated steady state gain between the regenerator bed temperature and the stripper level, and may be determined as dT/dSi.
  • AWA denotes a change in the combustion air flow rate to the unit, WAI - WAO, from time to to time ti.
  • GA denotes estimated steady state gain between the regenerator bed temperature and the combustion air flow rate, and may be determined as dT/dW A .
  • the ARC application may include the associated variable.
  • the associated variable may comprise flue gas excess oxygen composition (0 PV ) that may constrain change in the flue gas flow rate setpoint. It should be noted that a change in the flue gas excess oxygen composition may be linearly dependent on the combustion air flow rate change and the fuel flow rate change to the regenerator 110. Using the calculated value of the fuel oil 106 change (AWFO), change in the value of the flue gas excess oxygen composition may be determined using below mentioned equation 11 or equation
  • equation 11 and equation denotes expected future change in the flue gas excess oxygen composition due to changes in the disturbance variables.
  • GOA denotes estimated steady state gain between the flue gas excess oxygen composition and the combustion air flow rate, and may be determined using dO/dW A .
  • AWA denotes a change in the combustion air flow rate to the unit, WAI - WAO, from time to to time ti, where ti > to and (ti - to) define the ARC time period.
  • Gro denotes estimated steady state gain between the flue gas excess oxygen composition and the fuel gas flow rate, and may be determined as dO/dWro.
  • AWFO denotes calculated value of the change in fuel gas flow rate from a previous calculation of the fuel gas flow rate.
  • the parameters such as GF, GTF, GOT, GSL, and GA, defined in the equation 9 and equation 10 and the parameters GOA and GFO defined in the equation 12 may be obtained by steady state step tests in the operating unit. The steady state step tests may be described later. Further, upper and lower limits on the flue gas excess oxygen composition may be defined and entered through a DCS field. It should be noted that the fuel supplied to the regenerator 110 may be limited when calculated change in flue gas excess oxygen composition forces the oxygen composition to be outside the limits. Thus, a limit checking may be performed using the below mentioned equation 13.
  • Dqur denotes a difference between the flue gas excess oxygen composition value (Opv) and an upper limit for oxygen composition in the flue gas (Oup)
  • AOLO denotes a difference between the flue gas excess oxygen composition value (Opv) and a lower limit for oxygen composition in the flue gas (OLD).
  • Opv is a process value obtained from an analyzer or from a lab report.
  • a controller i.e., TIC controller 102
  • TIC controller 102 may have high and low setpoint limits which may override the controller action, when the setpoint lies outside the limits.
  • the change on the manipulated variable may have high and low limits, and may require a ramp function to adjust the setpoint smoothly and provide bumpless transfer from a regulatory action.
  • the parameters such as Gp, GTF, GOT, GSL, and GA may be determined by the steady state step tests in the operating unit.
  • GF may be determined using the steady state step tests in the operating unit.
  • GF may be determined as the steady state gain value of DT/AWF, where delta values of the variables may be determined from the steady state step tests on the operating unit or from an operator training simulator system.
  • the steady state step tests may include steady state gains that may be estimated as a ratio of a discrete steady state change in the control variables i.e. the regenerator bed temperature, to a step change in the disturbance variables or the manipulated variable. It should be noted that following method may be used for estimating the steady state gains for GF computed as DT/AWF.
  • the operating unit may be running at a stable steady state. Further, a step change could be made on the feed flow controller. It should be noted that size of the change may be agreed with the operations before the test. Further, values of the variables may be recorded throughout the change in the feed flow 118 and at a steady state (T, WF). Thereafter, an operator may wait until the operating unit reaches a steady state or some stable operation. Successively, a value of new temperature (Tnew) may be recorded after the step change. Further, a value of change in the regenerator bed temperature may be determined. It
  • AWF the value of AWF may be the difference between value of the feed flow
  • FIG. 2 depicts an illustrative block diagram 200 showing functioning of the APC/ARC strategy.
  • a configuration of a controller i.e., TIC controller 102 may be implemented in a DCS system, not requiring an additional hardware or software.
  • the ARC application may receive one or more inputs (i.e., manual inputs) from an operator, at a step 202.
  • the one or more inputs may include an ON/OFF activation of the ARC application, manipulated variable suppression factors Ki and K3 ⁇ 4 constants Ci, C2, C3, C4, and Cs ON/OFF binary variables for inclusion of variables gains in the ARC application, and ON/OFF activation parameter of the flue gas excess oxygen composition calculation to adjusting fuel oil 106 flow rate.
  • steady state gains for GF, GTF, GOT, GSL, GFO, GTG, GOA, and GOF may be determined, at step 204.
  • the steady state gains may be calculated using the steady state step tests in the operating unit.
  • the ARC application may receive one or more process inputs, at step 206.
  • the process inputs may include, but not limited to, the feed rate 118 to the unit, feed temperature, disengager overhead temperature, stripper level, fuel oil flow, tail gas flow, regenerator bed temperature, flue gas excess oxygen composition, and combustion air rate.
  • data may be retrieved at Ti, at step 208.
  • the data at Ti may include WFI, T FI . T DTI . S LI ,
  • data may be retrieved at To, at step 210.
  • the data at To may include
  • ATFI. ATori.andAS L1 may be calculated, at step 212. It should be noted that for each predefined period of time, ti - to, the ARC application may calculate changes in the disturbance variables at the start of the time period (to) and at the end of the time period (ti). Post calculation, the ARC application may load To from Ti.at step 214. Further, the changes in the values of the variables along with the calculated steady state gains and the constants (i.e., Ci, C 2 , C3, C4, and Cs) may be used to determine DTa,i, at step 216. It should be noted that values of the constants may be provided by the operator in order to determine the DT ⁇ *i. Further, the operator may decide which of die disturbance variable gains may be used to calculate the regenerator bed temperature by
  • Values of the constants may be set as
  • a manipulated variable unconstrained move may be calculated, at step 218.
  • the manipulated variable unconstrained move may be calculated based on move suppression parameters and integral time parameter (T).
  • T integral time parameter
  • the manipulated variable unconstrained move may be determined using below mentioned equation 16.
  • a manipulated variable move may be constrained, at step 220. Thereafter, setpoints (i.e., manipulated variable FIC setpoints) may be calculated, at step 222.
  • the setpoints may be determined using below mentioned equation 17 and equation 18.
  • flue gas excess oxygen composition constraint may be retrieved and used as a flag value, at step 224.
  • the flue gas excess oxygen composition may be retrieved based cm inputs such as Opv, OUP, and OLO
  • the flowrate change may be constrained by the flue gas excess oxygen composition calculation before the flowrate change may be applied to the FIC controller 104.
  • the ARC application may transmit the calculated setpoints to a controller 226. It should be noted that ARC selector and a manipulated variable selector may feed to the controller 226. Thereafter, the ARC application may change the flow rate of the fuel oil and the tail gas.
  • the predicted regenerator bed temperature may be compared with the setpoint (TSP) and the difference may be used as an error value to determine the change in the manipulated variable (WF).
  • the suggested ARC run frequency may be once per minute and may be easily tuned to run slower or faster depending on an observed quality of control. Further, in a case, the ARC setpoint may be applied to the flow controller
  • a filter such as a ramp function
  • FIG. 3 depicts an illustrative DCS screen interface 300.
  • the DCS screen interface 300 may be used by the operator to define all variables of the ARC application.
  • the DCS screen interface 300 may be used by the operator to define all variables of the ARC application.
  • DCS screen interface 300 may display variables such as controlled variable 302of the ARC application. Further, the DCS screen interface 300 may display a tag field 304 and a measured value field 306 of the variables.
  • the tag field 304 may be selected from below provided table illustrating DCS Tags associated with variables of the ARC application.
  • the DCS screen interface 300 may further display a target field 308 of the controlled variable 302 that the operator may use to set a target value or a desired value, and a mode field 310.
  • the mode field 310 may indicate which of the variables may be used to control the regenerator bed temperature.
  • the disengager temperature may be replaced by the controller TIC10R01 1 set point.
  • the DCS screen interface 300 may further display manipulated variables 312 and the setpoint 314 of the manipulated variables.
  • the mode may comprise MAN, AUTO, CASCADE, or REMOTE CASCADE, depending on the configuration of die manipulated variables 312.
  • the DCS screen interface 300 may display associated variables 316 and distributed variables 318 with high limits field 320, low limits field 322, unit(s) field 324, and an available field 326.
  • the high limits field 320 and the low limits field 322 may be changed by the operator and a flag constraint may be displayed to the operator as a change of color of the high limits field 320 and the low limits field 322. It should be noted that the flag constraint may be displayed when high limits and low limits may be reached and changed back when die high limits and the low limits are normal.
  • the available field 326 may be changed by die operator i.e., ON/OFF to activate an adjustment of the fuel setpoint by the calculation of the flue gas excess oxygen composition. Further, the available field 326 may be used by the operator when the gain of the associated variable may be active in the ARC temperature calculation.
  • the DCS interface screen 300 may further display an application state field 328 that may be configured as a selector of the ARC application and the regulatory control.
  • the application state field 328 may be used by the operator to set ON/OFF while the ARC application is active or inactive.
  • FIG. 4 depicts another illustrative DCS screen interface 400.
  • the DCS interface screen 400 may be used by the operator to input values of parameters or constants for the ARC application. As shown in FIG. 4, an ARC estimated gains of variables 402 may be entered by the operator using the DCS interface screen 400. Further, the DCS interface screen 400 may include an active field 404 such as ON/OFF fields that may indicate about the flow used as the manipulated variable. The DCS interface screen 400 may further display measured values field 406 of the disturbance variables, the manipulated variables, and the controlled variables along with a setpoint field 408. It should be noted that values of the calculated temperature and the combustion air flowrate may also be displayed to die operator. Further, the DCS interface screen 400 may display adjusting parameters field 410 to the operator. The adjusting parameters field
  • 410 may include suppression factor field 412, an integral action field 414, and AW value field
  • values of the adjusting parameters field 410 may be provided by the operator and thus may be helpful in tuning up the ARC application.
  • the DCS interface screen 400 may further display measured values field, lab input field 418, and a lab/analyzer field 420, of the associated variable.
  • a lab value may be entered by the operator in the lab input field 418.
  • the lab input field 418, and the lab/analyzer field may allow the operator to set the value that may be used by the ARC application in the calculation.
  • a set of values may be selected as a default for gains, constants, and tuning values. The values may be replaced easily or restore with a use of a restore default values field 422.
  • the disclosed embodiments encompass numerous advantages.
  • Various embodiments of an advanced regulatory controller for a converter of a catalytic olefins unit may be disclosed.
  • ARC Advanced Regulatory Control
  • APC Advanced Regulatory Control
  • ARC Advanced Regulatory Control
  • functionality of the ARC application may allow the regenerator bed temperature to be maintained closer to the desired setpoint for low afterburning.
  • system and method may include consideration of critical constraints to fuel combustion. Therefore, such operation of flue gas mechanical system will result in more stable operation and extended life of the flue gas mechanical systems.
  • the method may include the step of feeding at least an olefin feed, a fuel oil, and a tail gas into a regenerator to produce an effluent stream; and operating the regenerator.
  • Operating the generator may include the steps of determining at least one disturbance variable associated with the regenerator, the at least one disturbance variable being selected from one of: (i) an olefin feed rate, (ii) an olefin feed temperature, (iii) a disengager temperature, and (iv) a stripper level; predicting a change in die regenerator bed temperature based on the determined at least one disturbance variable; determining a setpoint for a flow rate of at least one input to a regenerator based on the predicted change in the regenerator bed temperature, wherein the at least one input is selected from one of: (i) a fuel oil, and (ii) a tail gas; feeding the effluent stream to generate the product stream.
  • a Distributed Control System may be implemented to control the regenerator.
  • a DCS is a computer-based control system having control loops. Autonomous controllers are distributed throughout various components and devices making up the system. A central operator supervisory control oversees operation of the autonomous controllers. The autonomous controllers exchange data with the supervisory control using a suitable communication network.
  • the method may include the steps of feeding at least an olefin feed, a fuel oil, and a tail gas into a regenerator to produce an effluent stream; operating the regenerator by: determining at least one disturbance variable associated with the regenerator, the at least one disturbance variable being selected from one of: (i) an olefin feed rate, (ii) an olefin feed temperature, (iii) a disengager temperature, and (iv) a stripper level; predicting a change in the regenerator bed temperature based on the determined at least one disturbance variable; and determining a setpoint for a flow rate of at least one input to a regenerator based on the predicted change in the regenerator bed temperature, wherein the at least one input is selected from one of: (i) a fuel oil, and (ii) a tail

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  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Engineering & Computer Science (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
  • Feedback Control In General (AREA)

Abstract

L'invention concerne un dispositif de commande régulateur avancé pour un convertisseur d'une unité catalytique d'oléfines. Un convertisseur de type craquage catalytique fluide (FCC) (c'est-à-dire, réacteur-régénérateur) est combiné à une extrémité froide de type éthylène pour la récupération de produit. Le dispositif de commande régulateur fonctionne à l'aide d'une application de commandes à régulation avancée (ARC) utilisant des variables, telles qu'une variable réglée, quatre variables de perturbation, une variable associée et une variable manipulée. L'application d'ARC manipule l'huile combustible ou le flux de gaz résiduaire vers un régénérateur en réponse à une valeur d'état stable future attendue d'une température de lit du régénérateur résultant des changements des valeurs d'un ensemble sélectionné de variables.
PCT/US2019/033665 2018-05-23 2019-05-23 Dispositif de commande régulateur destiné à être utilisé dans une unité catalytique d'oléfines WO2019226854A1 (fr)

Priority Applications (4)

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KR1020207033600A KR20210003202A (ko) 2018-05-23 2019-05-23 촉매 올레핀 유닛에서의 사용을 위한 조절 제어기
CN201980034551.0A CN112166171B (zh) 2018-05-23 2019-05-23 用于催化烯烃单元的调节控制器
EP19808208.3A EP3797143A4 (fr) 2018-05-23 2019-05-23 Dispositif de commande régulateur destiné à être utilisé dans une unité catalytique d'oléfines
SA520420586A SA520420586B1 (ar) 2018-05-23 2020-11-19 نظام لتحويل تغذية أولفين إلى تيار منتج

Applications Claiming Priority (4)

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US201862675452P 2018-05-23 2018-05-23
US62/675,452 2018-05-23
US16/420,350 US11118117B2 (en) 2019-05-23 2019-05-23 Regulatory controller for usage in a catalytic olefins
US16/420,350 2019-05-23

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CN116974236A (zh) * 2023-09-22 2023-10-31 江苏保丽洁环境科技股份有限公司 一种设备的智能控制方法及系统

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US6245703B1 (en) * 1998-04-29 2001-06-12 Exxon Mobil Chemical Patents Inc. Efficient method using liquid water to regenerate oxygenate to olefin catalysts while increasing catalyst specificity to light olefins
US20030163010A1 (en) * 2002-01-07 2003-08-28 Teng Xu Reducing temperature differences within the regenerator of an oxygenate to olefin process
US20040069684A1 (en) * 2002-10-10 2004-04-15 Kellogg Brown & Root, Inc. Catalyst recovery from light olefin FCC effluent
US20040192993A1 (en) * 2003-03-28 2004-09-30 Lattner James R. Regeneration temperature control in a catalytic reaction system
US20090192341A1 (en) * 2008-01-30 2009-07-30 Beech Jr James H Method Of Circulating Catalyst Between A Catalyst Regenerator And An External Catalyst Cooler

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* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6245703B1 (en) * 1998-04-29 2001-06-12 Exxon Mobil Chemical Patents Inc. Efficient method using liquid water to regenerate oxygenate to olefin catalysts while increasing catalyst specificity to light olefins
US20030163010A1 (en) * 2002-01-07 2003-08-28 Teng Xu Reducing temperature differences within the regenerator of an oxygenate to olefin process
US20040069684A1 (en) * 2002-10-10 2004-04-15 Kellogg Brown & Root, Inc. Catalyst recovery from light olefin FCC effluent
US20040192993A1 (en) * 2003-03-28 2004-09-30 Lattner James R. Regeneration temperature control in a catalytic reaction system
US20090192341A1 (en) * 2008-01-30 2009-07-30 Beech Jr James H Method Of Circulating Catalyst Between A Catalyst Regenerator And An External Catalyst Cooler

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN116974236A (zh) * 2023-09-22 2023-10-31 江苏保丽洁环境科技股份有限公司 一种设备的智能控制方法及系统
CN116974236B (zh) * 2023-09-22 2023-12-08 江苏保丽洁环境科技股份有限公司 一种设备的智能控制方法及系统

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