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Open resourceIndustrial Gas Plant Feed Air Interfaces
Feed-Air Duty • Pretreatment Boundaries • Generator Interfaces • Product-Gas Separation • Continuity
Engineering position — An industrial gas generator is only as stable as the air utility feeding it. The feed-air compressor, pretreatment system, receiver, distribution, gas-generation skid and product-gas storage must be treated as one controlled interface. Supplier-defined inlet pressure, flow, temperature and contaminant limits govern; plant-wide assumptions must never override the actual gas-generator requirement. |
1. Engineering Intent
Industrial gas plants often sit between two engineering disciplines. The compressed-air team focuses on compressors, dryers, filtration, piping and storage; the gas-generation team focuses on nitrogen, oxygen or another product gas, its purity and delivery pressure. Failures occur at the boundary: the compressor can appear healthy while the generator receives unstable pressure, excess temperature, water, oil carryover or insufficient flow. Conversely, a gas-generation skid can be oversized or incorrectly blamed when the true restriction is the feed-air branch, filter pressure drop, receiver arrangement or control philosophy.
Its purpose is to convert the gas generator vendor’s inlet conditions into a complete feed-air duty, then protect the product-gas side from cross-connection, transient and operating-state errors. The page is deliberately technology-neutral. Pressure-swing adsorption, membrane separation, vacuum/pressure variants and large cryogenic systems do not share identical feed-air requirements, so the governing data must come from the selected equipment supplier and project process design.
The engineering sequence is: define product-gas demand → obtain generator inlet conditions → translate those conditions to compressor FAD/reference conditions → build pressure and temperature budgets → design pretreatment and storage → establish operating-state coincidence → define continuity and shutdown behaviour → commission the feed-air/product-gas boundary with measured evidence.
2. Scope and Utility Boundaries
System / utility | Role | Boundary rule | |
|---|---|---|---|
Feed-air compressor package | Produces compressed air for gas-generation process | Included | Sized to verified generator demand plus justified reserve |
Aftercooler / separator / receiver | Removes heat and bulk liquid; buffers demand | Included | Performance verified at actual ambient and load |
Dryer / filters / drains | Conditions feed air to generator requirement | Included | Selection based on supplier limit, not generic plant target |
Gas-generation skid | Separates / generates product gas | Interface only | Internal process design remains supplier/process responsibility |
Product-gas buffer / receiver | Stabilises product-gas supply | Interface included | Kept physically and functionally separate from feed air |
Plant service air | Tools, workshop, general pneumatic loads | Separate utility | Must not steal feed-air capacity unless intentionally designed |
Instrument / control air | Controls and critical pneumatic devices | Separate/protected utility | No automatic assumption that feed air is suitable |
Nitrogen / oxygen / other product gas | Final gas delivered to process | Downstream boundary | Purity, pressure and application constraints remain process-specific |
3. Required Asset — Feed Air and Product Gas Boundary Schedule
It should be completed before compressor or treatment selection and updated whenever the gas-generator skid, production target, product-gas purity, process pressure or operating schedule changes.
Boundary item | Upstream owner / source | Required data | Downstream acceptance | Evidence / monitor |
|---|---|---|---|---|
Feed-air flow | Compressor system | FAD/reference flow at stated conditions | Generator minimum/maximum inlet flow | Flow meter + operating trend |
Feed-air pressure | Compressor / header | Minimum dynamic pressure and normal band | Generator inlet pressure band | Pressure transmitter at skid inlet |
Feed-air temperature | Aftercooler / room ventilation | Maximum credible inlet temperature | Supplier temperature limit | Inlet temperature trend |
Moisture | Dryer / separator | Pressure dew point or moisture limit | Supplier inlet moisture requirement | Dew-point monitor where required |
Oil / aerosol | Compressor + filtration | Residual contamination basis | Generator supplier limit | Filter status / oil testing if specified |
Particles | Piping + filters | Particle control basis | Supplier filter requirement | Filter DP / inspection |
Drainage | Separators / receivers / filters | Automatic condensate removal | No liquid carryover to skid | Drain function checks |
Generator product flow | Gas-generation skid | Guaranteed product flow at stated purity | Process demand profile | Product flow meter |
Product-gas purity | Gas-generation skid | Specified product quality | Process acceptance band | Gas analyser |
Product-gas pressure | Generator / product receiver | Normal and minimum delivery pressure | Process/user requirement | Product header pressure trend |
Cross-connection control | Project / operations | Physical identification and valve logic | No feed-air/product-gas mix-up | P&ID + tagging + commissioning test |
Boundary rule — Never size or accept the feed-air system using only compressor discharge pressure and nameplate flow. Acceptance belongs at the gas-generator inlet and product-gas outlet under actual operating conditions. |
4. Gas-Generation Technology Changes the Feed-Air Duty
Different gas-generation technologies respond differently to pressure, temperature, moisture and cycling. The correct inlet requirement is the value published or contractually guaranteed for the selected skid. The compressed-air design must then reproduce that condition reliably at the actual site.
Technology family | Feed-air behaviour to check | Interface concern | Engineering action |
|---|---|---|---|
PSA nitrogen | Cyclic adsorption / regeneration creates repeating demand pattern | Pressure fluctuation, valve timing, purity response | Confirm average and instantaneous flow; stabilise inlet pressure |
PSA oxygen | Cyclic adsorber operation with supplier-defined air quality | Moisture/oil sensitivity and inlet stability | Follow supplier pretreatment and pressure band exactly |
Membrane nitrogen | Continuous flow through membrane modules | Pressure strongly affects product flow/purity balance | Protect inlet pressure and temperature; verify compressor turndown |
Vacuum/pressure adsorption variants | Integrated blower/vacuum/compressor interactions | Utility boundary may differ from simple compressed-air feed | Use package-specific process data |
Cryogenic air separation | Very large process-air compression and treatment duty | Not equivalent to standard plant compressed air |
5. Define Product-Gas Demand Before Feed-Air Capacity
The feed-air system should not be selected from a single product-gas nameplate. The process demand profile must distinguish base load, peak load, standby, regeneration or purge demand where applicable, product-buffer refill, start-up and any simultaneous service-air use intentionally connected to the same compressor plant. The gas-generator conversion ratio between feed air and product gas is technology-, purity-, pressure- and supplier-specific.
Demand state | Product-gas condition | Feed-air implication | Design question |
|---|---|---|---|
Normal production | Stable product flow and purity | Base feed-air duty | Can one compressor or efficient combination carry base load? |
Peak production | Higher product-gas flow | Higher feed-air duty or faster receiver drawdown | Is peak sustained or transient? |
Product receiver refill | Temporary extra generator output | Short-duration feed-air increase | Can refill be scheduled off peak? |
Start-up / stabilisation | Generator not yet at normal operating condition | Potential venting / non-product period | What feed-air duty occurs before usable product? |
Standby / low production | Reduced gas demand | Potential compressor low-load inefficiency | Can sequencing or VSD reduce unloaded running? |
Maintenance / bypass | One train unavailable | Remaining train may see higher duty | What degraded operating mode is acceptable? |
6. Convert Generator Requirement to Compressor Duty
Generator vendors may state inlet flow at normal, standard, actual or package-specific reference conditions. Compressor performance may be reported as FAD at another reference condition. The two values are not automatically interchangeable.
For a dry-gas approximation, a reference-flow conversion can be written as: Q₂ = Q₁ × (P₁/P₂) × (T₂/T₁), using absolute pressure and absolute temperature. Real project calculations may need humidity, compressibility and supplier-specific corrections. The objective is not to force one formula onto every project, but to stop reference-condition ambiguity from becoming a sizing error.
Calculation discipline — Write the units and reference conditions beside every flow number. “100 m³/min” without pressure/temperature basis is incomplete engineering data. |
7. Feed-Air Pressure Budget
The minimum dynamic pressure at the gas-generator inlet is the anchor for the pressure budget. Upstream losses through dryers, filters, receivers, non-return valves, headers and local isolation valves are then added. A compressor discharge setpoint should be the result of this budget, not the starting assumption.
Pressure element | Condition to consider | Verification |
|---|---|---|
Generator minimum dynamic inlet pressure | Normal and peak production | Supplier data + measured inlet pressure |
Local inlet valve / strainer / regulator loss | Maximum feed-air flow | Flow curve or measured differential |
Final filter loss | Clean and loaded condition | Filter differential pressure |
Dryer loss | Rated and part-load condition | Supplier pressure-drop data |
Main header / branch loss | Peak coincident flow | Pipe-network calculation + field test |
Receiver / check valve effects | Transient conditions | Trend during cycling |
Control margin | Only justified residual margin | Documented basis |
Illustrative example: if the generator requires 7.0 bar(g) minimum dynamically, the local branch and filter account for 0.25 bar, the dryer and upstream treatment 0.20 bar, and the main header 0.35 bar at peak flow, the compressor control strategy must preserve approximately 7.8 bar at the relevant upstream reference point before any agreed operating margin. Raising the entire plant to 9 or 10 bar simply because the generator sees low pressure wastes energy if the real problem is a restrictive filter or undersized branch.
8. Feed-Air Temperature and Compressor-Room Conditions
Gas-generator performance can change with feed-air temperature because air density, adsorption behaviour, membrane performance and package cooling all depend on thermal conditions. The compressor room, aftercooler, dryer and skid location therefore form one thermal interface. High ambient temperature can reduce compressor capacity, increase dryer load and increase inlet temperature to the gas generator at the same time.
Thermal condition | Possible impact | Engineering response |
|---|---|---|
High summer ambient | Lower compressor mass-flow capability; higher discharge and inlet temperatures | Apply site derating and verify ventilation |
Poor aftercooler performance | More moisture carried into separator/dryer | Monitor approach temperature and separator performance |
Hot compressor room recirculation | Capacity loss and treatment overload | Separate hot exhaust and fresh intake paths |
Long outdoor pipe run | Cooling may create downstream condensate | Check dew point and drainability |
Cold process area | Different downstream condensation risk | Verify minimum pipe temperature against dew point |
9. Pretreatment Architecture
Pretreatment must be driven by the generator inlet specification. A common architecture may include aftercooling, bulk-liquid separation, receiver storage, prefiltration, drying and final filtration, but the exact sequence and quality target vary. Some generator packages include part of this treatment internally; others require a fully conditioned external feed.
Pretreatment element | Primary function | Failure effect at generator | Monitoring / maintenance |
|---|---|---|---|
Aftercooler | Reduces air temperature and condenses bulk water | High inlet temperature; excess dryer load | Outlet temperature / cleanliness |
Moisture separator | Removes condensed liquid | Liquid carryover | Drain function and inspection |
Wet receiver | Buffers compressor cycling and separates additional liquid | Unstable pressure / carryover if poorly drained | Pressure trend + automatic drain |
Prefilter | Protects dryer and downstream equipment | Contaminant loading / pressure drop | Differential pressure |
Dryer | Controls moisture / dew point | Adsorbent/membrane performance risk; condensation | Dew point or supplier-defined check |
Final filter | Controls downstream particles/aerosols | Generator valve/media contamination | Differential pressure + replacement history |
Dry receiver / feed buffer | Stabilises clean-air feed | Pressure cycling if undersized | Pressure trend at generator inlet |
10. Oil, Water and Particle Contamination Boundaries
The phrase “clean dry air” is insufficient unless converted into measurable inlet limits. Water can damage adsorbents, reduce separation performance, corrode piping or freeze in cold sections. Oil aerosol or vapour can foul separation media or create product-quality risk. Particles can damage valves and generate pressure drop. The selected gas-generator supplier should therefore define the required inlet condition, and the feed-air system should be designed and commissioned against that requirement.
Contaminant | Likely source | Potential consequence | Control point |
|---|---|---|---|
Liquid water | Aftercooler/separator/drain failure | Media damage, valve problems, unstable performance | Bulk separation + drains |
Water vapour | Inadequate dryer or wrong dew-point basis | Moisture loading / condensation downstream | Dryer + dew-point verification |
Oil aerosol | Lubricated compressor carryover / separator issue | Media fouling / quality risk | Separation + coalescing filtration as specified |
Oil vapour | Hot compressor conditions / hydrocarbon source | May bypass ordinary aerosol filter | Supplier-specific treatment if required |
Particles / rust | Corroding pipe / disturbed maintenance debris | Valve wear, filter blockage, media contamination | Clean piping + final filtration |
Desiccant dust | Dryer media attrition | Particle loading downstream | Afterfilter where required |
11. Storage Strategy — Feed Air and Product Gas Are Different Buffers
A feed-air receiver and a product-gas receiver solve different problems. Feed-air storage stabilises compressor/generator interaction and can support short air-side transients. Product-gas storage buffers downstream consumption, allows the generator to operate more steadily and may provide short continuity while another train starts. The two should not be conflated.
Storage location | Primary purpose | What it should not be used to hide |
|---|---|---|
Wet receiver | Compressor cycle damping, moisture separation | Sustained compressor undersizing |
Dry feed-air receiver | Stabilise generator inlet pressure | Excessive filter/dryer restriction |
Generator internal vessel | Part of package process cycle | External plant demand variation unless designed for it |
Product-gas receiver | Buffer downstream gas demand and improve generator stability | Persistent generator undersizing |
Local process buffer | Protect critical user transient | Poor main distribution design |
For a short air-side event, an approximate receiver-volume relation is V ≈ Qf × t × P_atm / (P₁abs − P₂abs), where Qf is free-air flow and P values are absolute. This is suitable for preliminary transient checks; final sizing must consider actual temperature, compressor contribution, package control logic and applicable vessel design requirements.
12. Operating-State and Coincidence Model
State | Feed-air compressors | Gas generator | Product receiver | Key risk |
|---|---|---|---|---|
Normal production | Lead/trim efficient sequence | Stable production | Normal operating band | Low risk if pressure stable |
Peak gas draw | Additional compressor/trim as needed | High output | May discharge temporarily | Feed-air pressure sag |
Receiver refill | Higher gas output after peak | Elevated feed demand | Charging | Refill coincides with plant peak |
Compressor trip | Standby start / remaining unit loads | May continue briefly | Provides limited buffer | Generator inlet pressure collapse |
Generator train trip | Feed demand falls suddenly | One train offline | Supplies process if capacity exists | Compressor unload / pressure rise |
Low production | Reduced compressor fleet | Turndown / intermittent operation | High state-of-charge | Unloaded power and cycling |
13. Compressor Capacity, Sequencing and Reserve
A feed-air plant should be sized around guaranteed flow at the required pressure after site derating, not nominal motor power or catalogue displacement. Capacity planning must include treatment losses, ambient correction, fouling allowance where justified, operating reserve and the selected continuity philosophy. Reserve capacity should be expressed as an operating scenario: for example, “one largest compressor unavailable while maintaining one generator train at reduced product output,” rather than a vague percentage.
Capacity question | Required answer |
|---|---|
What is the generator inlet flow at normal and maximum production? | Supplier-verified value at stated reference conditions |
What site derating applies? | Altitude, ambient temperature and cooling conditions |
What is the compressor FAD at required discharge pressure? | Performance data at project pressure |
What losses occur across treatment and piping? | Measured/calculated dynamic pressure budget |
What happens with one compressor unavailable? | Defined degraded production mode |
Can multiple generators start together? | Start/stabilisation coincidence rule |
How is low-load operation controlled? | Sequencing / VSD / shutdown strategy |
14. Distribution and Dedicated Feed-Air Header
When gas generation is production-critical, a dedicated feed-air branch or header is usually easier to control than an uncontrolled connection to a general service-air network. Shared infrastructure can still be engineered successfully, but the branch must be protected from tool use, cleaning blow-off and other loads that create rapid pressure swings.
Measure pressure at the gas-generator inlet, not only at the compressor room.
Provide isolation and maintenance access without trapping condensate or creating dirty dead legs.
Avoid undersized flexible connectors, non-return valves and strainers that become hidden restrictions.
Identify the feed-air branch clearly so temporary users cannot be connected casually.
Where multiple generator trains exist, document cross-tie valve positions and normal operating configuration.
15. Product-Gas Side Boundary
The product-gas side begins at the generator outlet and is not merely “cleaner compressed air.” Its composition, purity, pressure and allowable contaminants are process requirements. Nitrogen, oxygen and other industrial gases must be handled as distinct utilities, with dedicated identification, storage, regulation, monitoring and downstream risk controls.
Boundary | Feed-air side | Product-gas side |
|---|---|---|
Identity | Compressed air | Named industrial gas |
Primary measurement | Pressure, flow, temperature, moisture/contaminants | Product flow, purity/composition, pressure |
Storage purpose | Air-side stability | Process continuity / demand buffering |
Temporary connection | Compressed-air compatible only | Must be product-gas compatible and approved |
Cross-connection risk | May contaminate product or process | Can create serious process/safety consequences |
Acceptance owner | Compressed-air / utility engineering | Process / gas-system owner |
16. Continuity and Recovery Strategy
Feed-air continuity should be tied to the consequence of losing product gas. A nitrogen generator serving inerting, blanketing, packaging or process-purge demand may have a very different continuity requirement from a noncritical utility generator. The continuity design can combine compressor redundancy, multiple generator trains, feed-air storage, product-gas storage, automatic start logic, alternate supply and controlled load shedding. The correct combination depends on process consequence, not on generic N+1 language.
Failure | Immediate effect | Recovery action | Verification |
|---|---|---|---|
Lead compressor trip | Feed-air pressure begins to fall | Start standby / unload noncritical shared loads | Trend generator inlet pressure |
Dryer/filter restriction | Increasing pressure drop | Switch parallel train or service element | DP alarm and bypass procedure |
Generator train trip | Product flow reduces | Use parallel train / product buffer / alternate supply | Product flow and purity trend |
Product receiver low pressure | Reduced continuity time | Restore generator output or shed demand | Low-pressure alarm |
Power interruption | Compressors/generator controls stop | Follow plant restart sequence | Black-start / restart test where required |
Contamination alarm | Feed quality out of limit | Isolate affected path before media/product damage | Quality monitor + root-cause record |
17. Monitoring and Evidence Architecture
Measurement | Why it matters | Minimum interpretation |
|---|---|---|
Compressor discharge pressure | Shows source condition | Not sufficient alone for generator acceptance |
Feed-air header pressure | Shows distribution state | Trend against compressor sequencing |
Generator inlet pressure | Primary interface acceptance point | Must stay inside supplier operating band |
Feed-air flow | Confirms actual generator demand | Compare against product output and operating state |
Feed-air temperature | Shows thermal loading | Check against generator and dryer limits |
Dew point / moisture indicator | Confirms drying performance where specified | Trend, alarm and investigate excursions |
Filter differential pressure | Detects restriction | Avoid compensating with higher plant pressure |
Product-gas flow | Confirms delivered capacity | Correlate with feed-air consumption |
Product purity analyser | Confirms separation performance | Use process-approved measurement strategy |
Product-gas pressure | Shows downstream continuity | Trend against receiver charge/discharge |
18. Energy and Efficiency Optimisation
The largest efficiency gains usually come from correct pressure, correct capacity and stable generator operation. Overpressure on the feed-air side increases compressor energy and leakage. Excessive generator cycling can reduce process efficiency. Oversized treatment can impose unnecessary pressure drop, while undersized treatment forces high compressor setpoints as filters load.
Operate at the lowest compressor pressure that still preserves verified generator inlet pressure under peak conditions.
Separate high-pressure plant users rather than forcing the gas-generator feed header to follow them.
Use product-gas storage and operating logic to smooth short downstream peaks where the process allows it.
Trend feed-air consumed per unit of product gas at comparable purity and operating conditions.
Investigate rising filter/dryer pressure drop before raising compressor setpoints.
Shut down unnecessary compressors during low gas demand instead of accepting prolonged unload running.
19. Troubleshooting Matrix
Symptom | Likely feed-air/interface cause | Check first | Corrective direction |
|---|---|---|---|
Product flow below expected | Low feed-air pressure/flow, high temperature, supplier operating point not met | Generator inlet P/T/flow | Restore inlet conditions before blaming generator |
Product purity unstable | Pressure cycling, moisture/oil issue, overloaded generator | Inlet trend + analyser trend | Stabilise feed air and verify pretreatment |
Generator trips at peak demand | Header sag / filter restriction / insufficient compressor reserve | Peak pressure trace + filter DP | Remove restriction or add justified capacity/storage |
Frequent compressor load/unload | Feed receiver too small or poor sequencing | Compressor state trend | Improve storage/control strategy |
Water at generator inlet | Drain/dryer failure or downstream cooling | Separator drains + dew point | Repair moisture-control chain |
High compressor power | Excessive setpoint / dirty treatment | Pressure budget + DP | Reduce losses then lower setpoint |
Product receiver rarely recovers | Sustained demand exceeds generator output | Product flow vs demand | Correct capacity or demand profile |
One generator train starves another | Shared branch imbalance / control-valve interaction | Individual inlet pressure/flow | Balance branches or separate headers |
20. Worked Integration Scenario — New Nitrogen Generator Train
Assume an existing plant has one nitrogen generator train supplied from a common compressed-air station. A second generator is added to support production expansion. The new vendor data requires a defined inlet pressure band and feed flow at stated reference conditions. The existing compressor station appears to have spare nameplate capacity, but pressure logging shows the gas-generator branch already loses 0.6 bar during simultaneous workshop and packaging peaks.
The correct integration sequence is to separate the gas-generator feed demand from unrelated service-air coincidence, confirm the reference basis of both old and new generator flows, measure actual compressor FAD at the intended discharge pressure, calculate the branch pressure budget, and check dryer/filter capacity at the combined duty. If the existing compressor capacity is adequate but the branch is restrictive, a dedicated larger feed-air header and low-loss final filtration may be more effective than adding another compressor. If product-gas demand is highly peaky, additional product-gas storage may reduce generator and compressor cycling without oversizing continuous feed-air capacity.
Scenario check | Finding to establish | Decision |
|---|---|---|
Combined generator feed flow | Verified at common reference conditions | Sets compressor/treatment capacity basis |
Existing branch pressure loss | Measured at peak combined feed flow | Upgrade branch if excessive |
Dryer/filter residual capacity | Check flow and loaded DP | Parallel/upgrade treatment if required |
Compressor degraded-mode capacity | One unit unavailable case | Defines reserve or reduced-production mode |
Product receiver autonomy | Duration at critical downstream demand | Supports restart/transition strategy |
Service-air interaction | Workshop/packaging effect on feed header | Segregate or load-shed if harmful |
21. Commissioning and Acceptance
Commissioning test | |
|---|---|
No-load / low-load feed-air test | Stable pressure, drains operational, no abnormal restriction |
Maximum expected generator duty | Inlet pressure/flow/temperature within supplier requirement |
Treatment verification | Dryness/contaminant evidence as specified |
Compressor transition test | No unacceptable inlet-pressure collapse during lead/lag change |
Product receiver charge test | Expected charge/recovery behaviour |
Product purity/flow confirmation | Meets supplier/process acceptance basis |
Failure / standby sequence | Defined degraded mode demonstrated where practicable |
Cross-connection inspection | Feed air, product gas and service air clearly identified and isolated |
Trend capture | Baseline P/flow/temp/DP/purity data archived |
22. Expansion and Change Control
Any increase in product-gas purity, product pressure, generator capacity or production schedule can change the feed-air requirement. The same applies to compressor replacement, dryer technology changes, filter upgrades, header extensions, ambient-condition changes and new shared compressed-air users.
Reconfirm gas-generator inlet data whenever the generator or purity setpoint changes.
Recalculate compressor capacity at the actual discharge pressure and site conditions.
Recheck treatment capacity and pressure drop after adding generator trains.
Update the Feed Air and Product Gas Boundary Schedule and P&ID tags.
Repeat peak-condition pressure logging after major plant expansion.
24. Frequently Asked Engineering Questions
Question Watch A short explainer on this topicSlide-by-slide engineering explainers from Reddy Compressors. More in the video library. | Engineering answer |
|---|---|
Can a gas generator use the normal plant compressed-air header? | Yes only if the header can maintain the generator’s required pressure, flow, temperature and air quality under all relevant coincident loads. Critical plants often benefit from a protected or dedicated feed branch. |
Is feed-air receiver storage the same as product-gas storage? | No. Feed-air storage stabilises the air side; product-gas storage buffers downstream gas demand and continuity. They are sized from different operating objectives. |
Should the compressor be set to a much higher pressure for safety margin? | No. Build a dynamic pressure budget from the generator inlet requirement and actual system losses, then use only a justified control margin. |
Can compressor catalogue m³/min be compared directly with generator Nm³/min? | Not until both values are converted to the same reference pressure, temperature and humidity basis. |
What is the most important monitoring point? | The generator inlet pressure under real demand, supported by feed flow, temperature, treatment condition and product-gas flow/purity monitoring. |
No. Product-gas purity is process- and supplier-specific. |
25. Completion Register
Status | |
Feed-air duty translated from generator requirement | COMPLETE |
Feed Air and Product Gas Boundary Schedule | COMPLETE |
Reference-condition flow conversion discipline | COMPLETE |
Dynamic pressure budget | COMPLETE |
Pretreatment and contamination boundaries | COMPLETE |
Feed-air vs product-gas storage separation | COMPLETE |
Continuity and recovery logic | COMPLETE |
Monitoring / energy / troubleshooting | COMPLETE |
Worked expansion scenario | COMPLETE |
Commissioning / change control | COMPLETE |
COMPLETE |