5. BENEFITS
• Reduces turnaround time
• Reduces labor costs
• Reduces air emissions
• Reduces danger of explosive and toxic vapors - lowers H2S & TEL
levels
• Restores equipment efficiency/capacity
6. BENEFITS
• Minimizes waste
• Provides virtually oil-free
surfaces and gas-free environment ready for entry
• Water has no impact on wastewater treatment plant
• Water has low BOD, COD, and TOC levels (dependent on sludge
characteristics)
7. MECHANICAL SUPPLIER
• Experience working with independent mechanical and turnaround
contractors in various regions.
• Experience in coordinating and running projects with customer
specific maintenance contractors
8. MECHANICAL CONTRACTOR
REQUIREMENTS
• Equipment specifically designed for chemical cleaning
• Capability to perform several circulation loops within one unit
• Self-contained equipment
• Equipment meets all customer requirements
• Closed-loop circulation
• Ability to process sample during circulation
10. TRADITIONAL METHODS-SLUDGE
REMOVAL
• Shovel or vacuum truck
• Front end loader
• Remote mechanical devices
• Power spray nozzle
11. TRADITIONAL METHODS-
HYDROCARBON RECOVERY
• Move to another crude tank
• Mix with crude in vat
• Belt press
• Centrifuge
• Separation tank
12. CWI CAPABILITIES
• Storage Tank Cleaning
• Patented Warm Water Method
• Proven experience
• Storage Tank Degassing
• Patented degassing chemistry
• Proven experience
13. TANK CLEANING-ONES APPROACH
PATENTED WARM WATER METHOD
EVALUATION
• Obtain representative sample
• Determine job requirements
• Determine limitations
• Tank cleaning beaker simulation
• Customized cleaning program
14. CRITERIA FOR SUCCESS
• Obtain a representative sample
• Apply proper heat and chemistry
• Develop processes to separate recovered hydrocarbon, water, and
solids
15. LABORATORY TESTING FOR THE
HYDROCARBON RECOVERY AND WASTE
MINIMIZATION PROCESS
BEAKER WITH SLUDGE
16. LABORATORY TESTING FOR THE
HYDROCARBON RECOVERY AND WASTE
MINIMIZATION PROCESS
ADDITION OF SOLUTION
17. LABORATORY TESTING FOR THE
HYDROCARBON RECOVERY AND WASTE
MINIMIZATION PROCESS
ADDITION OF DILUENT, START TEST
18. LABORATORY TESTING FOR THE
HYDROCARBON RECOVERY AND WASTE
MINIMIZATION PROCESS
BEAKER SIMULATION IN PROGRESS
19. LABORATORY TESTING FOR THE
HYDROCARBON RECOVERY AND WASTE
MINIMIZATION PROCESS
END OF OF BEAKER SIMULATION
20. APPLICATION METHOD - CRUDE
STORAGE TANK
• Pump crude from tank
• Floating Roof - Lower roof to lowest level
• Add equal volumes of water-chemical solution, and diluent
• Floating Roof - Allow roof to float (2 ft)
• Heat and circulate the cleaning solution
• When complete, initiate customized recovery program
21. MONITORING
• In Process Monitoring
• Emulsification Progress
• Temperatures
• Suspended Solids
• Free Oil
• Water-Wet Solids
22. CRUDE STORAGE TANK - FIXED OR
FLOATING ROOF
IDENTIFY EXISTING
PUMPS & HEATING SLUDGE
SOURCES
PUMP TANK TO LOWEST LEVEL
USING EXISTING DRAIN LINES
23. CRUDE STORAGE TANK - FIXED OR
FLOATING ROOF
CLEANING
DILUENT
SOLUTION
SLUDGE
ADD WATER, CHEMICAL, AND DILUENT
24. CRUDE STORAGE TANK - EXTERNAL
CIRCULATION
DILUENT
CLEANING SOLUTION
WATER CUTS
CHANNEL
SLUDGE
30. CRUDE STORAGE TANK - CLEANING
CONFIGURATION
POSSIBLE TANK CIRCULATION AND HEATING ARRANGEMENTS
31. CRUDE STORAGE TANK - CLEANING IN
PROGRESS
CUTTER OIL
SLUDGE LIFTING
FROM TANK FLOOR
PENETRATING
CLEANING
SOLUTION
CHEMICAL PENETRATES THE SLUDGE
AND LIFTS IT OFF THE FLOOR
36. CRUDE STORAGE TANK - END OF
PROCESS
RECOVERED OIL
READY FOR
PROCESSING
SOLIDS ARE RECOVERED HYDROCARBON INITIATE RECOVERY
HYDROCARBON AND DILUENT PROCESS
FREE
SPENT CLEANING SOLUTION
SOLIDS
37. CASE STUDY #1
Tank Capacity - 500,000 bbl
Tank Diameter - 273 ft
Sludge Volume - 5.5 ft (60,000 bbl)
38. CRUDE STORAGE TANK SLUDGE SAMPLE
Component % by Volume
Hydrocarbon 73.3
Water 24.6
Sediment 2.1
Recoverable Oil = 44,000 bbl
42. CASE STUDY #2
Tank Capacity - 400,000 bbl
Tank Diameter - 224 ft
Sludge Volume - 5 ft (35,900 bbl)
43. CASE STUDY #2 - CUSTOMER GOALS
• Eliminate crude unit upsets
• Restore storage tank capacity
• Monitor crude deliveries
• Three week window
44. CASE STUDY #2 - CUSTOM PROCEDURE
• Sludge sample obtained
• Sample tested using beaker simulation
• Located existing pumps and exchangers
• Light cycle oil used as diluent
45. CASE STUDY #2 -TANK BOTTOM SLUDGE
COMPOSITION
Component % by Volume
Hydrocarbon 92
Water 6.7
Sediment 1.3
Recoverable Oil = 33,000 bbl
46. CASE STUDY #2 - RESULTS
• Back in service in 17 days
• Average 1” solids on bottom (75 bbl)
• Tank entry not required
• 33,000 bbl of oil recovered
• 99.9% recovery
47. CASE STUDY #2 - ECONOMIC RESULTS
Improved technique (Dollars)
Item/Basis
495,000
Income
0
0
Recovered Hydrocarbon: 3,000
13,200
33,000 bbl at 15$/bbl 74,800
1,500
Expenses 17,800
Sludge Disposal - None 0
$103,100
$391,900
Tank Downtime - None
Manpower - Estimate
49. TRADITIONAL METHODS FOR
DEGASSING
OPEN MANWAYS
• Produces vapors
• Several weeks to degas
• Environmentally unsound
50. APPLICATION METHOD - DEGASSING
• Pump out the tank
• Remove the access doors
• Apply cleaning/degassing solution
• Use degassing solution EC9008A
• PORTA-FEED Jr. per 100,000 bbl tank capacity
• Monitor the process
51. MONITORING
• In Process Monitoring
• Emulsification Progress
• Temperatures
• Suspended Solids
• Free Oil
• Water-Wet Solids
56. DEGASSING CASE STUDY - PROBLEM
• Large Gulf Coast Refiner needed to enter a 180,000 barrel crude
storage tank.
• Previously required taking the tank out of service to clean with
conventional methods
• Air ventilation was taking a significant amount of time
57. DEGASSING CASE STUDY - PROCESS
• Site review from the local team resulted in applying the following
process:
• Tank drained of HC and filled with several feet of water to float
excess HC for removal.
• Flush water drained from tank
• Opening of many ways showed 3-4% of HC present in the tank
atmosphere.
58. DEGASSING CASE STUDY - PROCESS
• ONES implemented the use of a special feed system to apply a
solution of the ONES degassing chemical.
• Spray nozzle was used for the chemical application.
• Walls, roof, internal support and structures were thoroughly rinsed
from each of the manways
59. DEGASSING CASE STUDY - RESULTS
• After 6 hours the solution was drained to the API separator
• No additional cleaning was necessary
• Atmosphere within the tank was completely free of Hydrocarbon
vapors in less than ONE day. Therefore providing a SAFE environment
• Refiner able to begin immediate maintenance
• Reduced total cleaning costs
• No waste water problems were encountered