# US 11,047,573 B2 · Flare monitoring and control method and apparatus

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- Number: US 11,047,573 B2
- Document ID: US11047573B2
- Status: Granted
- Kind: B2
- Application number: 16/262,445
- Filed: 2019-01-30
- Published: 2019-08-08
- Granted: 2021-06-29
- Earliest claimed: 2018-02-05
- Assignees: Chevron Phillips Chemical Company LP
- Applicants: Chevron Phillips Chemical Company LP
- Inventors: Charles F. Fisher; Lee N. Green; Gregory G. Hendrickson; Thomas A. Lessard; Kenneth B. Moore; Daniel W. Peneguy
- Web page: https://patentgrep.com/patent/US11047573B2

## CPC

- F23G 7/085: {in stacks}
- F23L 7/005: {Evaporated water; Steam}
- F23G 2207/10: Arrangement of sensing devices
- F23G 2207/102: for pressure
- F23G 2207/103: for oxygen
- F23G 2207/108: for hydrocarbon concentration
- F23G 2207/112: for waste supply flowrate
- F23G 2207/20: Waste supply
- F23G 2209/14: Gaseous waste or fumes
- F23G 2900/55011: Detecting the properties of waste to be incinerated, e.g. heating value, density
- F23K 2900/05001: Control or safety devices in gaseous or liquid fuel supply lines
- F23K 2900/05004: Mixing two or more fluid fuels
- F23G: CREMATION FURNACES; CONSUMING WASTE PRODUCTS BY COMBUSTION
- F23L: SUPPLYING AIR OR NON-COMBUSTIBLE LIQUIDS OR GASES TO COMBUSTION APPARATUS IN GENERAL ({air-supply arrangements for fluent fuels F23C;} firebridges with means for feeding air or steam F23M3/04; baffles or shields with air supply passages F23M9/04); VALVES OR DAMPERS SPECIALLY ADAPTED FOR CONTROLLING AIR SUPPLY OR DRAUGHT IN COMBUSTION APPARATUS {(dampers and throat restrictors for open fire-places F24; air inlet valves for open fire fronts F24)}; INDUCING DRAUGHT IN COMBUSTION APPARATUS; TOPS FOR CHIMNEYS OR VENTILATING SHAFTS; TERMINALS FOR FLUES
- F23K: FEEDING FUEL TO COMBUSTION APPARATUS (fuel feeders specially adapted for fluidised bed combustion apparatus F23C10/22)

## Abstract

Disclosed herein are embodiments of a flare control method and a flare apparatus for automatically controlling, in real-time, the flow of one or more of fuel, steam, and air to a flare. The disclosed embodiments advantageously allow for automated control over a wide spectrum of operating conditions, including emergency operations, and planned operations such as startup and shutdown.

## Claims

### Claim 1

A method comprising:
measuring a concentration of at least one hydrocarbon of a vent gas in a vent gas stream upstream of a combustion zone of a flare;
feeding the vent gas in the vent gas stream to the flare; and
controlling, in real-time based at least in part on the concentration of the at least one hydrocarbon, a flow of steam or air to the flare.

### Claim 2 (depends on 1)

The method of claim 1, wherein the flow of steam to the flare is controlled, wherein the step of controlling a flow of steam to the flare comprises:
calculating a molecular weight of the vent gas in the vent gas stream using the concentration of the at least one hydrocarbon and a molecular weight of the at least one hydrocarbon;
measuring a velocity of the vent gas in the vent gas stream;
calculating a mass flow rate of the vent gas in the vent gas stream using the measured vent gas velocity, a molar volume of 385.3 SCF/LB-MOL, and the calculated molecular weight;
determine a current flow rate of steam to the flare;
calculating a total steam:vent gas mass ratio for smokeless operation of the flare using the concentration of the at least one hydrocarbon in the vent gas stream multiplied by a standard steam:hydrocarbon ratio required for smokeless operation of the flare for the at least one hydrocarbon;
calculating a required steam flow rate for the flow of steam to the flare using the total steam:vent gas mass ratio and the vent gas mass flow rate; and
adjusting the flow of steam to the flare to the required steam flow rate.

### Claim 3 (depends on 1)

The method of claim 1, wherein the flow of air to the flare is controlled, wherein the step of controlling a flow of air to the flare comprises:
calculating a molecular weight of the vent gas in the vent gas stream using the concentration of the at least one hydrocarbon and a molecular weight of the at least one hydrocarbon;
measuring a velocity of the vent gas in the vent gas stream;
calculating a volumetric flow rate of the vent gas in the vent gas stream using the calculated velocity;
calculating a total air:vent gas mole ratio for smokeless operation of the flare using the concentration of the at least one hydrocarbon in the vent gas stream multiplied by a standard air:hydrocarbon ratio required for smokeless operation of the flare for the at least one hydrocarbon;
calculating a required air flow rate for the flow of air to the flare by multiplying the total air:vent gas mole ratio by the volumetric flow rate of the vent gas in the vent gas stream; and
adjusting a flow of air to the flare to the required air flow rate.

### Claim 4 (depends on 1)

The method of claim 1, further comprising:
controlling, in real-time based at least in part on the concentration of the at least one hydrocarbon, a flow of natural gas or fuel gas into the vent gas stream.

### Claim 5 (depends on 4)

The method of claim 4, wherein controlling a flow of natural gas or fuel gas comprises:
calculating a net heating value of the vent gas in the vent gas stream using the concentration of the at least one hydrocarbon and a net heating value for the at least one hydrocarbon;
calculating a first flow rate for the natural gas or fuel gas that is required to change the net heating value of the vent gas in the vent gas stream to meet a first setpoint value, wherein the first setpoint value is defined as equal to or greater than a minimum net heating value for a vent gas specified by regulation;
calculating a net heating value in a combustion zone of the flare using the flow rate of the vent gas in the vent gas stream, a flow rate of steam to the flare, and the net heating value for the vent gas;
calculating a second flow rate for the natural gas or fuel gas that is required to change the net heating value in the combustion zone to meet a second setpoint value, wherein the second setpoint value is optionally defined as equal to or greater than a minimum net heating value for a combustion zone specified by regulation;
determining and selecting which one of the net heating value of the vent gas in the vent gas stream and the net heating value in the combustion zone is a selected net heating value that requires more natural gas or fuel gas to meet the respective setpoint value (or alternatively stated, determining which one of the first flow rate and the second flow rate is greater, and identifying the greater one as a selected flow rate); and
adjusting a flow of the natural gas or fuel gas to the selected flow rate.

### Claim 6 (depends on 4)

The method of claim 4, wherein controlling a flow of natural gas or fuel gas comprises:
calculating a net heating value of the vent gas in the vent gas stream using the concentration of the at least one hydrocarbon and a net heating value for the at least one hydrocarbon;
calculating a first flow rate for the natural gas or fuel gas that is required to change the net heating value of the vent gas in the vent gas stream to meet a first setpoint value, wherein the first setpoint value is defined as equal to or greater than a minimum net heating value for a vent gas specified by regulation;
calculating a net heating value dilution parameter in a combustion zone of the flare using the flow rate of the vent gas in the vent gas stream, a flow rate of air to the flare, the net heating value for the vent gas, and a diameter of a tip of the flare;
calculating a second flow rate for the natural gas or fuel gas that is required to change the net heating value dilution parameter of the combustion zone to meet a second setpoint value, wherein the second setpoint value is defined as equal to or greater than a minimum net heating value dilution parameter for a combustion zone specified by regulation;
determining and selecting which one of the net heating value of the vent gas in the vent gas stream and the net heating value dilution parameter for the combustion zone is a selected net heating value that requires more natural gas or fuel gas to meet the respective setpoint value (or alternatively stated, determining which one of the first flow rate and the second flow rate is greater, and identifying the greater one as a selected flow rate); and
adjusting the flow of the natural gas or fuel gas to the selected flow rate.

### Claim 7 (depends on 4)

The method of claim 4, wherein controlling a flow of natural gas or fuel gas comprises:
calculating a first net heating value of the vent gas in the vent gas stream using the concentration of the at least one hydrocarbon that is received from a first gas analyzer and a net heating value for the at least one hydrocarbon;
calculating a second net heating value of the vent gas in the vent gas stream using the concentration of the at least one hydrocarbon that is received from a second gas analyzer and a net heating value for the at least one hydrocarbon;
multiplying the first net heating value of the vent gas by a ratio of the second net heating value of the vent gas to the first net heating value of the vent gas to obtain a reconciled net heating value of the vent gas;
calculating a first flow rate for the natural gas or fuel gas that is required to change the reconciled net heating value of the vent gas in the vent gas stream to meet a first setpoint value, wherein the first setpoint value is defined as equal to or greater than a minimum net heating value for a vent gas specified by regulation;
calculating a first net heating value dilution parameter in a combustion zone of the flare using the flow rate of the vent gas in the vent gas stream, a flow rate of steam to the flare, and the first net heating value for the vent gas calculated using the concentration of the at least one hydrocarbon that is received from the first gas analyzer;
calculating a second net heating value dilution parameter in the combustion zone of the flare using the flow rate of the vent gas in the vent gas stream, a flow rate of steam to the flare, and the second net heating value for the vent gas calculated using the concentration of the at least one hydrocarbon that is received from the second gas analyzer;
multiplying the first net heating value dilution parameter by a ratio of the second net heating value dilution parameter to the first net heating value dilution parameter to obtain a reconciled net heating value dilution parameter in the combustion zone;
calculating a second flow rate for the natural gas or fuel gas that is required to change the reconciled net heating value dilution parameter in the combustion zone to meet a second setpoint value, wherein the second setpoint value is defined as equal to or greater than a minimum net heating value dilution parameter for a combustion zone specified by regulation;
determining and selecting which one of the reconciled net heating value of the vent gas in the vent gas stream and the reconciled net heating value dilution parameter in the combustion zone is a selected net heating value that requires more natural gas or fuel gas to meet the respective setpoint value (or alternatively stated, determining which one of the first flow rate and the second flow rate is greater, and identifying the greater one as a selected flow rate); and
adjusting a flow of the natural gas or fuel gas to the selected flow rate.

### Claim 8 (depends on 7)

The method of claim 7, further comprising:
determining the net heating value of the vent gas calculated using information from the first gas analyzer and/or the second gas analyzer is less than a first target value, wherein the first target value is a minimum net heating value for a vent gas specified by regulation;
adjusting the first setpoint value to a higher vent gas setpoint value that is greater than the first setpoint value;
calculating a third flow rate for the natural gas or fuel gas that is required to change the net heating value of the vent gas in the vent gas stream to meet the higher vent gas setpoint value;
determining the net heating value in the combustion zone is less than a second target value, wherein the second target value can be a minimum net heating value in the combustion zone specified by regulation;
adjusting the second setpoint value to a higher combustion zone setpoint value that is greater than the second setpoint value;
calculating a fourth flow rate for the natural gas or fuel gas that is required to change the net heating value in the combustion zone to meet the higher combustion zone setpoint value;
determining which one of the third flow rate and the fourth flow rate is greater;
identifying the greater one as a selected flow rate; and
adjusting the flow of the natural gas or fuel gas to the selected flow rate.

### Claim 9 (depends on 4)

The method of claim 4, wherein controlling a flow of natural gas or fuel gas comprises:
calculating a first net heating value of the vent gas in the vent gas stream using the concentration of the at least one hydrocarbon that is received from a first gas analyzer and a net heating value for the at least one hydrocarbon;
calculating a second net heating value of the vent gas in the vent gas stream using the concentration of the at least one hydrocarbon that is received from a second gas analyzer and a net heating value for the at least one hydrocarbon;
multiplying the first net heating value of the vent gas by a ratio of the second net heating value of the vent gas to the first net heating value of the vent gas to obtain a reconciled net heating value of the vent gas;
calculating a first flow rate for the natural gas or fuel gas that is required to change the reconciled net heating value of the vent gas in the vent gas stream to meet a first setpoint value, wherein the first setpoint value is defined as equal to or greater than a minimum net heating value for a vent gas specified by regulation;
calculating a first net heating value dilution parameter in a combustion zone of the flare using the flow rate of the vent gas in the vent gas stream, a flow rate of air to the flare, and the first net heating value for the vent gas calculated using the concentration of the at least one hydrocarbon that is received from the first gas analyzer;
calculating a second net heating value dilution parameter in the combustion zone of the flare using the flow rate of the vent gas in the vent gas stream, a flow rate of air to the flare, a diameter of a tip of the flare, and the second net heating value for the vent gas calculated using the concentration of the at least one hydrocarbon that is received from the second gas analyzer;
multiplying the first net heating value dilution parameter by a ratio of the second net heating value dilution parameter to the first net heating value dilution parameter to obtain a reconciled net heating value dilution parameter in the combustion zone;
calculating a second flow rate for the natural gas or fuel gas that is required to change the reconciled net heating value dilution parameter in the combustion zone to meet a second setpoint value, wherein the second setpoint value is defined as equal to or greater than a minimum net heating value dilution parameter for a combustion zone specified by regulation;
determining and selecting which one of the reconciled net heating value of the vent gas in the vent gas stream and the reconciled net heating value dilution parameter in the combustion zone is a selected net heating value that requires more natural gas or fuel gas to meet the respective setpoint value (or alternatively stated, determining which one of the first flow rate and the second flow rate is greater, and identifying the greater one as a selected flow rate); and
adjusting a flow of the natural gas or fuel gas to the selected flow rate.

### Claim 10 (depends on 9)

The method of claim 9, further comprising:
determining the net heating value of the vent gas calculated using information from the first gas analyzer and/or the second gas analyzer is less than a first target value, wherein the first target value can be a minimum net heating value for a vent gas specified by regulation;
adjusting the first setpoint value to a higher vent gas setpoint value that is greater than the first setpoint value;
calculating a third flow rate for the natural gas or fuel gas that is required to change the net heating value of the vent gas in the vent gas stream to meet the higher vent gas setpoint value;
determining the net heating value dilution parameter in the combustion zone is less than a second target value, wherein the second target value can be a minimum net heating value dilution parameter in the combustion zone specified by regulation;
adjusting the second setpoint value to a higher combustion zone setpoint value that is greater than the second setpoint value;
calculating a fourth flow rate for the natural gas or fuel gas that is required to change the net heating value dilution parameter in the combustion zone to meet the higher combustion zone setpoint value;
determining which one of the third flow rate and the fourth flow rate is greater;
identifying the greater one as a selected flow rate; and
adjusting the flow of the natural gas or fuel gas to the selected flow rate.

### Claim 11 (depends on 1)

The method of claim 1, wherein the concentration of the at least one hydrocarbon is measured using an online tunable infrared absorption based gas analyzer, and wherein the concentration of the at least one hydrocarbon is additionally measured using gas chromatography.

### Claim 12 (depends on 1)

The method of claim 1, further comprising:
measuring a hydrogen concentration in the vent gas stream; and
controlling, in real-time based at least in part on the hydrogen concentration in the vent gas stream, the flow of steam or air to the flare.

### Claim 13 (depends on 1)

The method of claim 1, wherein the step of measuring is performed by an online tunable infrared absorption based gas analyzer configured to analyze the vent gas in a sample stream taken from the vent gas stream or configured to analyze the vent gas in a flow path of the vent gas in the vent gas stream at a location between a knockout pot and the combustion zone of the flare.