Boiler Control TRIZ Cases

See how a master boiler controller merges external control functions and network communication

See how a master boiler uses wireless communication and self-configuring controllers to elimina

See how failure sign detection adjusts main apparatus usage time to prevent simultaneous failur

See how independently operable heat exchangers with recirculation loops reduce scale buildup, e

Maintaining saturated vapor in a heated tank enables precise mass flow control at lower temperatures, reducing energy use and contamination.

An outlet pressure-loss section balances boiler water-wall flow from partial to rated load without moving parts, helping stabilize steam and tube temperatures.

Field-based AI selects the optimal number and combination of industrial boilers as loads and unit performance change, cutting energy use.

Real-time boiler data drives model-based control that cuts exhaust gas and NOx while sustaining combustion efficiency in coal-fired plants.

A reverse compensation channel and flexible gain control stabilize boiler combustion during deep peak regulation while maintaining load and throttle pressure.

AI-based boiler control models combustion in real time to balance stable operation, higher efficiency, and lower emissions.

Level-sensor feedforward valve control cuts feedwater waste and suppresses start-up oscillations in once-through evaporators.

A kiln steam sparger offsets pressure-driven flow differences to expose moving material more uniformly throughout the muffle.

A heater and gas-inducing loop keeps the heat recovery boiler hot during standby, reducing thermal stress and enabling faster combined-cycle restart.

PLC-based control system maintains steam quality and injection pressure through segmented primary and secondary feedback loops.

A control system dispatches a single steam flow command to multiple elements based on priority and responsiveness.

Machine learning models predict exhaust gas concentrations and component faults in real time, replacing expensive physical sensors to lower monitoring costs.

Switching evaporator control modes adjusts feed water flow to discharge thermal energy as immediate power reserves.

A control circuit adjusts feedwater flow and valve openings to manage steam superheating and subcooling in once-through generators.

Automated learning system generates boiler combustion models using real-time operational data to optimize energy efficiency.

A once-through evaporator system uses dynamic feedforward signals to regulate feedwater flow and stabilize steam temperatures during operation.

Monitoring temperature difference between steam drum and discharge pipe detects incipient overheating, preventing evaporator tube damage from water shortages.

Pre-computed emissions data guides steam temperature adjustments during transient operations, reducing harmful output without real-time calculation delays.

A correction factor based on the temporal derivative of flow medium density compensates for storage effects, maintaining stable enthalpy during load changes.

A multi-circulation heat recovery steam generator uses an internally partitioned steam drum to separate clean and dirty water circuits.

A steam boiler control system optimizes liquid discharge timing to reduce thermal energy waste during blowdown operations.

A steam turbine starting control device segments startup constraints into distinct prediction periods to optimize thermal stress and differential expansion management.

A boiler combustion model uses artificial neural networks to optimize combustion efficiency while reducing nitrogen oxide emissions.

Closed-loop power system converts thermal energy into mechanical work using supercritical carbon dioxide flowing through a rotary engine.

Predictive thermal stress limits enable rapid steam turbine startup by adjusting heat medium supply before exceeding safe expansion thresholds.

Controlling burner firing power according to separator fill levels minimizes water discharge into superheater tubes while maintaining evaporator tube cooling.

A bypass steam suppressor system redirects feed water flow to modulate steam production in heat recovery steam generators.

A once-through boiler maintains stable operation at low loads by adjusting control valve pressure and water supply temperature.

A pre-control signal calculation anticipates mass and energy storage changes in evaporator heating surfaces to stabilize feedwater flow.

A direct evaporator heat exchange tube transfers thermal energy from high-temperature gas to organic Rankine cycle working fluid.

Parallel cycle heat engine segments heat recovery into independent organic Rankine cycles, reducing equipment complexity while maximizing power generation.

Dynamic control valves adjust feed water mass flow to specific heating zones, minimizing temperature imbalances across varying load ranges.

Regulates oxygen density in oxyfuel boilers using recirculated exhaust gas and air separation unit output to maintain stable combustion conditions.

A controller predicts transient water level changes in a steam drum using plant characteristics to generate a sliding setpoint for feedwater adjustment.

A once-through waste heat steam generator increases feedwater mass flow to coordinate with supplementary firing for enhanced system flexibility.

Predictive bypass control using upstream gas turbine power prevents steam formation at the evaporator inlet during rapid load changes.

A secondary burner wind box maintains higher pressure than the combustion vessel to isolate the component from primary flame heat.

A fuel limiting system restricts auxiliary burner input to prevent heat-transfer pipe damage in steam generators.

An energy control computing device adjusts steam flow parameters to maximize power output in combined cycle plants.

Regulating direct oxygen supply to burners maintains stable combustion while controlling NOx density and unburned combustibles.

Density error correction adjusts liquid level signals to resolve measurement inaccuracies caused by steam boiler density discrepancies.

A control method for heat recovery steam generators determines feedwater mass flow setpoints by calculating evaporator heat absorption.

A boiler controller stabilizes water level detection before initiating foam algorithms to prevent false alarms.

Dynamic harp valves adjust pressure drop to stabilize flow and thermal conditions, reducing tube failures caused by steam buildup at partial loads.

A steam generation control system adjusts feedwater flow to maintain injection pressure.

A once-through steam generator adjusts feed and circulating mass flows to maintain evaporator tube cooling.

A boiler pressure-loss adjusting section in outlet connection tubes manages fluid flow distribution across furnace walls.

Bottom-up filling stabilizes water level for accurate measurement, preventing chaotic mixing and thermal damage during start-up.

Segmenting control modules by rate of change stabilizes fluid levels during shrinking and swelling conditions, reducing plant trips.

A controller regulates primary recirculating exhaust gas flow to pulverized coal mass using a defined G/C ratio.