6 waters impact on dri
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Process Overview DRI Water Systems
Specific Water Issues Typical Challenges Recommendations
Water Quality Microbiological Solids Balance
Take Away Items
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Direct Reduced Iron Midrex & HYL: > 75% of DRI produced
Reaction occurs above iron melting point Oxygen removal process
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Typically cracked natural gas (CH4)
Lump/Pellet/Hot briquetted
(HBI)
Fixed chemistry Reduced tramp elements Combined carbon Increase EAF efficiency
Lower CO2 vs. Coal based processes Operational Flexibility
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Natural Gas Costs Driving factor for DRI locations
Historically located in Middle East, Asia, and Southern Caribbean
Decades low prices Shale supplies North American competitive advantage
A ma or g o a stee pro ucers are eva uat ng DRI production options
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Tenova/Danieli Energiron HYL DRI PlantTenova/Danieli Energiron HYL DRI Plant
Water Quality Tenova Company Mar eting wit Danie i 32 Modules in operation Operating Pressure: 45 Bars
ncrease 2 concen ra on Smaller foot print
Less fines
Steam reforming (HYL3)
Water/CO 2 generation Selective elimination
CO2 absorption & capture Mechanical seals
Lock hoppers & Double Valves
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DRI PlantCooling Water Systems
MachineryClosed Cooling
1.) Reactor Jacket Cooling2.) Bottom Flow Feeders3.) Gas Compressor Cooling
Direct ContactCooling Water
Non ContactCooling Water
. as er oo ers
1.) Heat Exchangers2.) Air Compressors3.) Lube Oil Cooler4.) Alternative to
1. Process Gas Scrubber2.) Cooling Gas Scrubber3.) Dust Collection Scrubbers4.) Quench Orifice/Venturis
Closed MachineCooling5.) Quench Tower6.) Cooling Tower / HX7.) Ammonia Scrubber8.) Clarifier
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Cooling TowerOr
Heat Exchan er
Top Gas ScrubberCooling Gas ScrubberSeal Gas CoolerDust Collection Scrubbers
Ammonia Scrubber Blow down
ClassifierClarifierot e
SludgeDewatering
Dewatered Sludge
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Top Reducing Gas Reuse (Top Gas) Cools process gas for reuse Cleaned by wet scrubbers
Gas exits
reactor
at
~ 400
oC
(Counter
flow)
1/3 of gas used for reformer burner fuel 2 3 of as re in ected throu h reformer
Reducing gas or seal gas system makeup
Cooling Gas oo s o oun er ow Reduces re oxidation potential Helps to define Fe3C (Carbon content)
Cooled, compressed, recycled Made up with natural gas
Auxiliary (Product/Oxide handling)
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FROM DUST
Removes iron particulates, lime and
other solids from the gas streams
PICK-UP POINT
SEPARATOR
TO SCRUBBERFAN SUCTION
ean ry gas s nee or op m za on Spray and Swirl water Provides gas cooling
SPRAYNOZZLE
VENTURI
CHEVRON MISTELIMINATOR
MESH PAD
INLETBOX
WATER INLET
Water returned to process clarifier Minimize water carryover
INSERT
THROAT AIR
DISTRIBUTIONPLATE
LEVELGAUGE
WATER INLET
ELBOW
SUMP PUMP
TO SCRUBBERCLARIFIER
WATER INLET
ACTUATOR
CENTRIFUGAL
LCV
PUMP
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ar er Removal targets
Iron articulate
Soluble Iron
Mineral precipitants
Typical solids loading Influent 500 2500 ppm Effluent 20 40 ppm
Treatment chemistry
pH Control
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Proper c ar er operat on w t so s mass a ance is critical for plant operations
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Gas Compressors 2stage Process & Cooling Gas Compressors Seal Gas Compressors
Direct Water Injection Reduces heat of compression Rinses lobe surfaces Minimizes pressure loss Reduce gas volume Corrosion
Rack DrainOr
CompressorDrain
Compressor seal failures Erosion/Corrosion lobes
Reuse
Damage to heat recovery bundles Reforming catalyst poisoning
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High temperatures Gas velocity (Erosion potential)
RO or Softener
CO2 / Sulfur
pH
depression Wet/Dry potential StorageSodiumHydroxide
High quality spray water Drain water monitoring
CorrosionInhibitor
Iron Corrosion rate
Compressors
Compressors
Corrosion Corrosion
Online digital probes Flow
ac
DrainOr
Reuse
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Foaming Tendancy Catalyst Poisons
Scrubber Operations Limited Standardization
Limited Disspersion
Reducing Gas Suspended Solids
Benchmarking
ompos on an Consistancy
Oxide Coatings
Microbiological
Chlorides
Intermitant Ops Remet additon
CO2 & Sulfur
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Impact on DRI Process Elevated Microbio Activit
Process Water Contaminants Soluble Iron Clarifier Post Precipitation
Increased TSS
loading
Fouling
potential Corrosion potential
CO2 stripping pH increase Insoluble Iron fouling
equipment / piping wear
Increased chemical demand
Oxide Coating
Lump Iron vs. Pellets Increased energy usage
Cooling tower fouling Reduced
u ur 2 con am na on Ammonia generation
Increased Cleaning Frequency Reduced Gas Cleaning ata yst o son ng
Moisture Carryover
to
off
gas
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Clarifier pH adjustment (8.0 8.3)
Soluble Iron
Comineral precipitants Caustic or lime
Strip CO2 pH increase Oxidize Soluble Iron
Air Lance Peroxide
Chemical Program Chemistry/Prep/Location
Avoid dispersants Evaluate sludge recirculation Evaluate sludge bed depth
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Iron Management
Know the system (TSS/Iron) Dont recycle solids from sludge
Solids in
must
balance
with
out Chemical
clarifier and sludge dewatering
pH to remove soluble iron CO stri in
Mechanical Limit lump iron use Limit & Control Remet use Consider alternatives for
auxiliary scrubbers
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Process Challenges Process Challenges Plugged Spray NozzlesPlugged Spray Nozzlese uce cru er er ormance
Increased Packing Fouling
ncrease op as ue emp Results in increased moisture Higher flue gas volume
Less Water
thus
increased
fouling
Microbial potential
Increased burner natural gas rate Increased ejector stack fan
electricity
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Process Challenges Process Challenges Fouled EquipmentFouled Equipment
Mineral Scale Oxide Coatings
Increased pH & Alkalinity CO2 Stripping
Increased pH Caustic Addition Iron removal
Increased pH
Mechanical Seal Lowers Tower Cycles Water Balance
Consider pH adjustment
Acid or CO2 re injection Organic phosphate scale inhibitor
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Microbial Monitoring Sessile & Planktonic Di slides / ATP / Cultures Multiple Monitor Points
Bulk Water Treatment on ox zers on y rex Low foaming Plant Trip
Correct biocide selection Localized Treatment
TGS & CGS
Greatly Increase Iron Fouling Potential
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Cooling Tower or Heat Exchangers Post precipitation of iron Sus ended solids Mineral scale Microbiological
Increased gas temperature Reduced process efficiency
High tower maintenance, cleaning costs, & fill replacement
Cooling tower fans Gas compressors
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Both processes generate NH4 Local limits may be exceeded
20 40 ppm Blow down treatment
95% removal at pH > 11.5
pH increases scaling potential Highly susceptible to fouling Decreased removal efficiency Increased maintenance costs Redundancy or increased down time
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DRI Process Water DRI Process Water Key Performance Key Performance
Average Good
Coolin Tower Cleanin 1 ear 2 ears
HX Cleaning
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DRI DRI Leading IndicatorsLeading Indicators
Average Good
Sus ended Solids TSS < 40 m < 20 m
Chlorides (as Cl) < 100 ppm < 75 ppm5 4
Sessile Microbio < 10 6 cfu/cm 2 < 10 5 cfu/cm 2
RSI / LSI 5.0 6.5 / 0 1.5
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Steel Corrosion: < 5 mpy
System Soluble Iron: < 1.0 ppm
Correct treatment chemicals (Midrex)
No phosphate/Bleach/Bromine
Process Cooling WaterProcess Cooling Water
TSS < 25 ppm Ideal < 20 ppm
System Chlorides: < 100 ppm as Cl
Monitor both lanktonic and sessile bacteria
Do not use disspersants
Equipment inspections are critical
Dont underestimate im act of CO and
pH control is critical for Iron removal
pH is critical for system scale and corrosion
sulfur on process performance
Trend individual flow rates vs time and
design specifications as important as correct product
Organic phosphate is required for high LSI system with oxide coating application
RSI/LSI/scale monitoring should be part of service plan
Consider impact of makeup water
Consider multiple feed points for both organic phosphate and microbiocide
Microbiocides must be low foaming
Complete frequent water and TSS balances
Monitor KPIs to provide ecomomic ustification for s stem treatment
improvements
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