0
Maintaining FLNG Operations
in Rough Seas
Tony Purcell
UOP LLC, A Honeywell Company

The FLNG Forum
December 3-4, 2013
Per...
Take-away from This Presentation
UOP has a complete portfolio of Gas Processing
Technologies also applicable for FLNG
UOP ...
Overall Agenda
 Introduction
 Specifications

 Unique Design Challenges
– Space and Weight Considerations
– Motion Effe...
Honeywell’s Businesses
 $37.6 billion in revenues in 2012, 50% outside of U.S.
 Nearly 122,000 employees operating in 10...
UOP Company Profile
Serving the Gas Processing, Refining & Petrochemical Industries
Profile — Significant Technology Posit...
Honeywell
FPSO Solutions

Others
 Integrated sub-sea
controls
 Simulator
 RMG Controls
 Enraf Tankage

Scope
• Design
...
UOP Natural Gas Solutions Flow Scheme
Acid Gas

Sulfur Recovery

Sulfur

Liquids
Recovery

UOP Offerings

Dry Sweet Gas

D...
Overall Agenda
 Introduction
 Specifications

 Unique Design Challenges
– Space and Weight Considerations
– Motion Effe...
FLNG Pretreatment Requirements
Typical Gas Composition
Australia

Middle
East

Gas Quality
for
Liquefaction

5 - 200

2 - ...
Overall Agenda
 Introduction
 Specifications

 Unique Design Challenges
– Space and Weight Considerations
– Motion Effe...
Space and Weight Considerations
Land Based
 Use Economies of Scale for larger plant
– Units over 1 BCFD (7MMTPA)

 Large...
Land Based LNG & NGL Integrated Approach
UOP World Scale Experience
Capacity,
Project Location MMSCFD Technologies
Indones...
UOP LNG Experience

UOP 6195-13

13
FLNG Motion Effect
on Column Performance
 Uniform countercurrent gas and
liquid flow is disturbed by motion leading
to re...
Effect of Mal-distribution
on Column Performance
Outlet CO2 Concentration

5%
4%
3%
2%

Outlet CO2 spec = 3%

1%

Outlet C...
CO2 Concentration in Treated Gas

Increasing Solvent Rate to Overcome the Effect
of Mal-distribution: Solvent Circulation ...
UOP Design Procedure
for Offshore Amine Units

• Motion amplitude
• Period
• Permanent tilt angle
Motion/tilt Data
For the...
MolSiv Adsorber under Tilt Condition
Adsorber

Amine Column
Tilt Angle
α

Tilt Angle
α

Liquid
Level

Low Liquid
Flow

Hig...
Overall Agenda
 Introduction
 Specifications

 Unique Design Challenges
– Space and Weight Considerations
– Motion Effe...
Conventional Pretreatment Scheme
UOP GB™ Adsorbent
Mercury Removal Unit

UOP Amine Guard FS™
Process Unit

Feed
Gas

UOP M...
Hybrid Pretreatment Scheme
UOP Separex UOP Amine Guard FS™
UOP GB™ Adsorbent
Mercury Removal Unit Membrane System
Process ...
Solvent-free Pretreatment Scheme
UOP Separex UOP Amine Guard FS™
UOP GB™ Adsorbent
Mercury Removal Unit Membrane System
Pr...
Solvent-free Pretreatment Scheme
UOP Separex UOP Amine Guard FS™
UOP GB™ Adsorbent
Mercury Removal Unit Membrane System
Pr...
Adsorbents in LNG Service & Off-shore
 UOP Molsiv Adsorbents have been used in > 1,400 units
for dehydration and acid gas...
UOP’s Offshore Separex Experience
Location

Type of
Unit

MMSCFD

CO2
Removal

Stages

Pretreatme
nt

Thailand

Platform

...
Overall Agenda
 Introduction
 Specifications

 Unique Design Challenges
– Space and Weight Considerations
– Motion Effe...
Heavy Hydrocarbon Removal from Lean Gas
 Heavy hydrocarbon removal is desirable, but light
hydrocarbon removal is not
– K...
Technical Solutions for Hydrocarbon Removal
Current commercial Process
Cryogenic separation
expander or JT
distillation co...
Cryogenic Distillation Options
Condenser
Cold Box
Scrub Column

LNG

• Poor separation due to high
pressure scrub column
•...
UOP SeparSIV Process/System
Clean Gas

Adsorbing
Bed

Regen Gas
Blower
Regen
Heater
Regen Gas
Cooler

Feed
Filter
Coalesce...
Technical Approach

Remove C8 and above and BTX, trace water
(capable of bulk water removal)

Remove C6 and below, water t...
Hydrocarbon to be removed
carbon number

Heavy Hydrocarbon Management Options
9
8

SeparSIV layered adsorbents

7
6

Separ...
Cost Comparison*
$MM

SeparSIV

Cryogenic

CAPEX

1.0

1.5

OPEX (annual)

1.0

4.8

Lifecycle Cost

1.0

2.0

Economic Ba...
Conclusions
UOP’s Integrated FLNG Pretreatment
• Flexible
‒ Multiple technology building blocks to meet varied feed
proper...
UOP 6195-35

35
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Tony Purcell, Honeywell UOP: Maintaining FLNG operations in rough seas

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Tony Purcell, Sales Director - South Asia, Gas Processing & Hydrogen, Honeywell UOP
delivered this presentation at the 2013 FLNG Forum in Perth. The two day conference brings attendees key insights into the technology and concepts that will unlock Australia’s stranded gas reserves. This event brings together case studies, keynote and technical presentations from the experts at the forefront of the Floating LNG projects. For more information about the forum, please visit the event website: http://www.informa.com.au/flngforum2013

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Transcript of "Tony Purcell, Honeywell UOP: Maintaining FLNG operations in rough seas"

  1. 1. Maintaining FLNG Operations in Rough Seas Tony Purcell UOP LLC, A Honeywell Company The FLNG Forum December 3-4, 2013 Perth, Western Australia © 2013 UOP LLC. All rights reserved. UOP 6195-1
  2. 2. Take-away from This Presentation UOP has a complete portfolio of Gas Processing Technologies also applicable for FLNG UOP Integrated FLNG Pretreatment  Multiple technology building blocks to meet varied feed properties over the life of the gas field  Optimized pretreatment scheme designed to minimize weight and space with flexible operation  Provided as modules to load on ship  Multiple execution models to meet client needs  One Honeywell approach to capture value UOP UOP Integrated Offerings Reduce Schedule and Lifecycle Costs6195-2 2
  3. 3. Overall Agenda  Introduction  Specifications  Unique Design Challenges – Space and Weight Considerations – Motion Effects  Gas Pretreatment Solutions for FLNG  Heavy Hydrocarbon Removal from Lean Gas UOP 6195-3 3
  4. 4. Honeywell’s Businesses  $37.6 billion in revenues in 2012, 50% outside of U.S.  Nearly 122,000 employees operating in 100 countries  19,000 engineers and scientists  A Fortune 100 company with Morristown, NJ global corporate headquarters Aerospace Automation & Control Solutions Performance Materials & Technologies Transportation Systems UOP 6195-4 4
  5. 5. UOP Company Profile Serving the Gas Processing, Refining & Petrochemical Industries Profile — Significant Technology Position Sales: Breakdown Business Units: • • • • Gas Processing and Hydrogen (GP&H) Process Technology & Equipment (PT&E) Catalysts, Adsorbents & Specialties (CA&S) Renewable Energy and Chemicals (RE&C) Products Equipment 35% Products Equipment 45% Services Offering: • • Technology, catalyst & services to the refining, petrochemical and gas processing industries Supplier of molecular sieve adsorbents to process and manufacturing industries UOP Facilities — Global Footprint Services Licensing Licensing 13% 7% Sales: Geographic Worldwide Headquarters Des Plaines, Illinois (suburban Chicago) 3,500+ Employees Asia Pacific 19% Global Customers • • • • 20 Offices 17 Countries 12 Manufacturing Facilities 5 Engineering Centers Middle East China 9% 12% South America North America 9% 32% UOP Offices UOP Manufacturing Sites E&A 9% India 5% CIS 5% UOP 6195-5 5
  6. 6. Honeywell FPSO Solutions Others  Integrated sub-sea controls  Simulator  RMG Controls  Enraf Tankage Scope • Design • Engineering • Fabrication  Staging  Commissioning Honeywell is uniquely situated to provide a full suite of technology solutions for the FPSO vessel. Our Technology employed can provide significant increase In yield and operational efficiency to the owners/ operators. “Input from Honeywell during the design phase of our FPSO resulted in a significant reduction of labor costs.” Well/Reservoir Monitoring & Control • Production Well Monitoring & Choke Control • Gas Lift Control • Gas/Water Injection Well Monitor & Choke Control • Down-hole Monitoring Advanced Applications • Production Optimization • Power Management • Gas Lift Optimization Acid Gas Treating and Dehydration • Membrane CO2 Removal Systems • Bulk, selective or trace acid gas removal • Gas Dehydration Systems • Mercury Removal Power Applications • Power management • Load Shedding • Turbo Generator Control Helipad Applications & Others • Guidance and obstruction lighting –Mike Baker Project C&I Lead Texaco Captain FPSO Successful Projects Captain FPSO Laminaria Esso Norge Jotun FPSO FPSO Cidade de Angra dos Reis (MODEC) FPSO Cidade de Sao Paulo (MODEC) FPSO Replicants (Petrobras) FPSO Cessao Onerosa (Petrobras) UOP has been selected for 100% of Petrobras pre salt FPSOs tendered (Cidade de Angra dos Reis, São Paulo, Replicants and Cessão Onerosa) Source: Honeywell • (Condition-based Maintenance) Business and Other Applications • Well Test Accounting • Production Accounting • Data Warehousing • Equipment Health Management • Operator Training Other Systems • Personnel Address • Drilling • Communications Safety Systems • Process Shutdown • Security • Emergency Shutdown • Fire and Gas detection • Heating, Ventilation and Air Conditioning Topside Process Control • Gas Processing Control • Flow Control & Metering • Compressor Control • Gas/Oil Pipeline Monitor & Control • Turbo Generator Control • Gas/Oil/Water Separation Control • Well Test Control Marine Systems • Water Treatment Control • Propulsion & Dynamic Positioning • Loading Computer • Aero • Cargo & Ballast Control • • UOP Automation & Control Solutions 6
  7. 7. UOP Natural Gas Solutions Flow Scheme Acid Gas Sulfur Recovery Sulfur Liquids Recovery UOP Offerings Dry Sweet Gas Dehydration Mercury Removal Natural Gas Extraction Liquefaction Acid Gas Removal (CO2, H2S) LNG Fractionation Raw Natural Gas Liquids Ethane  UOP Equipment  MOLSIV™   UOP Equipment Adsorbents  Separex™ Membrane Systems  Propane UOP Equipment   Amine Guard™ FS Process   Selexol™ Process  Twister™ Supersonic Separator Mixed Butanes Ortloff Processes Natural Gasoline SeparSIV ™ UOP Petrochemical technology to further convert / upgrade NGLs UOP Has Solutions to Help Maximize Gas Monetization UOP 6195-7 7
  8. 8. Overall Agenda  Introduction  Specifications  Unique Design Challenges – Space and Weight Considerations – Motion Effects  Gas Pretreatment Solutions for FLNG  Heavy Hydrocarbon Removal from Lean Gas UOP 6195-8 8
  9. 9. FLNG Pretreatment Requirements Typical Gas Composition Australia Middle East Gas Quality for Liquefaction 5 - 200 2 - 50 1000 - 2900 <2 - 4 5 - 1000 5 - 250 2 - 60 0 - 400 RSH 1 - 40 COS < 10 - 50 CO2, % 2 - 55 9 - 50 2 - 30 2-7 < 50 ppmv Hg, μg/Nm3 0 - 100 200 - 2000 50 - 200 0 - 50 < 0.01 H2O, ppmv Saturated Saturated Saturated Saturated < 0.1 C5+ Varies Varies Varies Varies < 0.1 mole% South America South East Asia H2S, ppmv 5 - 1000 Total Sulfur, ppmv Mooring System & Inlet Separation FLNG Pretreatment UOP Gas Processing Liquefaction & Unloading UOP 6195-9 9
  10. 10. Overall Agenda  Introduction  Specifications  Unique Design Challenges – Space and Weight Considerations – Motion Effects  Gas Pretreatment Solutions for FLNG  Heavy Hydrocarbon Removal from Lean Gas UOP 6195-10 10
  11. 11. Space and Weight Considerations Land Based  Use Economies of Scale for larger plant – Units over 1 BCFD (7MMTPA)  Large Footprint  No major Weight Considerations Floating  Minimal footprint  Smaller Capacities – Ship Size limitations 1 to 4 MMTPA  Minimize Weight – Additional Weight Requires Buoyancy – Additional Buoyancy Reduces On-Board Storage UOP 6195-11 11
  12. 12. Land Based LNG & NGL Integrated Approach UOP World Scale Experience Capacity, Project Location MMSCFD Technologies Indonesia Adgas Adgas RasGas RasGas Dolphin Gasco Gasco QatarGas RasGas RasGas QatarGas Gasco (SGD) RasGas (Barzan) 4 x 625 2 x 225 550 3 x 750 750 4 x 800 2 x 625 2 x 400 2 x 1400 2 x 1500 1600 2 x 1400 2x900 3x980 B, M3 B, M3 B, M3 A, M, S, O (I) A, M3, S, O (I) A2, M3 A, O A, O M3, S, O (I) A, M3, S, O (I) A, M4, S, O (I) M3, S, O (I) M, S, O (I) A, M, S, O (I) Application S/U Date LNG+NGL LNG+NGL LNG+NGL LNG SG SG+NGL SG+NGL SG+NGL LNG+NGL LNG+NGL SG+NGL LNG+NGL SG+NGL SG+NGL 80’s 85 95 04/05/06 05 07/08 08/09 09 08/09 09 09 09/10 12/15 12/15 26.69 Bcfd A - UOP Amine Guard FS Unit M - UOP Molecular Sieve System B – UOP Benfield Unit O – Ortloff NGL Unit S - UOP Selexol Unit I – Integrated UOP 6195-12 12
  13. 13. UOP LNG Experience UOP 6195-13 13
  14. 14. FLNG Motion Effect on Column Performance  Uniform countercurrent gas and liquid flow is disturbed by motion leading to reduced heat and mass transfer efficiency  Column efficiency drops for distillation/absorption have been documented in the literature  Column performance suffers with motion and permanent tilt  Column efficiency decreases at very long or very short period List angle α  The taller the bed height, or H/D ratio, the higher the loss in efficiency Significant concerns to meet 50 ppm CO2 product spec for FLNG pretreatment when amine process applied UOP 6195-14 14
  15. 15. Effect of Mal-distribution on Column Performance Outlet CO2 Concentration 5% 4% 3% 2% Outlet CO2 spec = 3% 1% Outlet CO2 spec = 1% 0% 0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 Maldistribution Factor The lower the CO2 product spec required, the more sensitive the amine column to mal-distribution, or motion For FLNG pretreatment 50 ppmv CO2 spec is required for FLNG (very sensitive to mal-distribution) UOP 6195-15 15
  16. 16. CO2 Concentration in Treated Gas Increasing Solvent Rate to Overcome the Effect of Mal-distribution: Solvent Circulation Margin 8.E-04 Land Based 10% Margin 23% Margin 7.E-04 6.E-04 5.E-04 4.E-04 3.E-04 Margin: The extra solvent circulation rate applied above land base amine design 2.E-04 1.E-04 0.E+00 0 0.05 0.1 0.15 0.2 0.25 0.3 Maldistribution Factor • At high liquid rates the absorber is less sensitive to mal-distribution • Design margin in solvent circulation rate needs to be added for offshore service Right design margin is applied to guarantee treated gas meeting 50 ppmv CO2 spec UOP 6195-16 16
  17. 17. UOP Design Procedure for Offshore Amine Units • Motion amplitude • Period • Permanent tilt angle Motion/tilt Data For the Project Land Based Design CFD Simulations Maldistribution Parameters AGRU Design <50 ppm CO2 • Set the feed basis and solvent circulation rate from land based design Pilot Plant Data For Rocking Column • Worst case maldistribution sets the design case Rigorous Heat & Mass Transfer Model We have developed a design procedure for marinization of amine unit UOP 6195-17 17
  18. 18. MolSiv Adsorber under Tilt Condition Adsorber Amine Column Tilt Angle α Tilt Angle α Liquid Level Low Liquid Flow High Liquid Flow Solid Level Uniform Gas Flow • In amine units, liquid level will stay horizontal, and not perpendicular to the flow path, resulting in flow mal-distribution • In MolSiv units, solid adsorbent will stay perpendicular to the flow path resulting in uniform gas flow. UOP 6195-18 18
  19. 19. Overall Agenda  Introduction  Specifications  Unique Design Challenges – Space and Weight Considerations – Motion Effects  Gas Pretreatment Solutions for FLNG  Heavy Hydrocarbon Removal from Lean Gas UOP 6195-19 19
  20. 20. Conventional Pretreatment Scheme UOP GB™ Adsorbent Mercury Removal Unit UOP Amine Guard FS™ Process Unit Feed Gas UOP MOLSIVTM Adsorbent Dehydration Unit Treated Gas to LNG XXXX Sour Gas CO2 + H2S Water  Large solvent system in off-shore environment – Logistics (permanent solvent/water make-up) – HSE issues related to use of amines  Limited flexibility – For variations in feed over life of field – Limit on CO2 content of feed gas due to limit on size of unit  Impact of rocking motion has to be accounted for UOP 6195-20 20
  21. 21. Hybrid Pretreatment Scheme UOP Separex UOP Amine Guard FS™ UOP GB™ Adsorbent Mercury Removal Unit Membrane System Process Unit UOP MOLSIVTM Adsorbent Dehydration Unit Conventional Scheme Feed Gas Treated Gas to LNG XXXX Sour Gas CO2 + H2S Hybrid Scheme Feed Gas Water Treated Gas to LNG XXXX Permeate Gas Sour Gas CO2 + H2S Water  Smaller amine unit  More flexible for variation over life of field  System can handle gas streams with higher CO2 content UOP 6195-21 21
  22. 22. Solvent-free Pretreatment Scheme UOP Separex UOP Amine Guard FS™ UOP GB™ Adsorbent Mercury Removal Unit Membrane System Process Unit UOP MOLSIVTM Adsorbent Dehydration Unit Conventional Scheme Feed Gas Treated Gas to LNG XXXX Water Sour Gas CO2 + H2S Hybrid Scheme Feed Gas Treated Gas to LNG XXXX Permeate Gas Sour Gas CO2 + H2S Water Final FLNG pretreatment lay-out depends on feed gas composition UOP 6195-22 22
  23. 23. Solvent-free Pretreatment Scheme UOP Separex UOP Amine Guard FS™ UOP GB™ Adsorbent Mercury Removal Unit Membrane System Process Unit Adsorbent-Only UOP MOLSIVTM Adsorbent Acid Gas Removal/ Dehydration Unit Feed Gas Treated Gas to LNG Membranes + Adsorbents Regeneration Gas Water, CO2 & H2S Feed Gas Treated Gas to LNG Water Permeate Gas Water, CO2 & H2S  Solvent-free eliminates motions effects  Permeate Gas (Membranes) or Regeneration Gas (MolSiv) can be used to meet the ship’s utility needs UOP 6195-23 23
  24. 24. Adsorbents in LNG Service & Off-shore  UOP Molsiv Adsorbents have been used in > 1,400 units for dehydration and acid gas removal  Extensive Experience in CO2 Removal for LNG Pretreatment – 30 + references in LNG Peak Shavers – Pipeline Quality Gas (2-3%) to LNG Quality Gas (50 ppmv)  UOP Molsiv Adsorbents have been used in off-shore units (Brasil, Thailand, Indonesia, Nigeria, Angola, Australia…) Molsiv Adsorbents can also be used for CO2 removal in FLNG pretreatment UOP 6195-24 24
  25. 25. UOP’s Offshore Separex Experience Location Type of Unit MMSCFD CO2 Removal Stages Pretreatme nt Thailand Platform 32 50% - 20% 1 MG Malaysia Platform 680 44% - 8% 2 MG Thailand Platform 580 40% - 23% 1 MG Thailand FPSO 11 28% - 3% 1 J-T Thailand Platform 480 35% - 23% 1 MG Brazil FPSO 176 25% - 5% 2 J-T Brazil FPSO 176 35% - 5% 1 C3R by courtesy of Talisman by courtesy of Petrobras UOP is extending its land based experience to offshore UOP 6195-25 25
  26. 26. Overall Agenda  Introduction  Specifications  Unique Design Challenges – Space and Weight Considerations – Motion Effects  Gas Pretreatment Solutions for FLNG  Heavy Hydrocarbon Removal from Lean Gas UOP 6195-26 26
  27. 27. Heavy Hydrocarbon Removal from Lean Gas  Heavy hydrocarbon removal is desirable, but light hydrocarbon removal is not – Keep C2-C4 in the LNG to raise BTU value  Concern: – Heavy hydrocarbons freezing in LNG exchangers – Desirable to remove BTEX and heavier components – May not have enough hydrocarbon for a typical NGL cryogenic recovery scheme – not enough reflux in the demethanizer  Potential Solution(s): – Using cryogenic distillation to remove hydrocarbons – Using a highly selective multilayer adsorbent system to remove sulfur species and hydrocarbons SeparSiv can remove C6+ to less than 1 ppmv UOP 6195-27 27
  28. 28. Technical Solutions for Hydrocarbon Removal Current commercial Process Cryogenic separation expander or JT distillation column compressor Water Feed UOP MOLSIV dehydration TSA Hydrocarbons Product to Liquefaction Cryogenic temperature achieved by gas expansion Recompression of the gas is generally needed after liquefaction UOP’s SeparSiv Process Feed UOP MOLSIV dehydration TSA Water SeparSIV Process Product to Liquefaction Hydrocarbons For the SeparSIV Process, hydrocarbons and water are removed from a gas/liquid separator after cooling the regeneration gas UOP 6195-28 28
  29. 29. Cryogenic Distillation Options Condenser Cold Box Scrub Column LNG • Poor separation due to high pressure scrub column • Lower scrub column temp to provide reflux – condense C1, C2 Feed – less efficient Precool • Add fractionation columns to provide reflux Dehydration Fractionation – add CAPEX Compressor Cold Box Scrub Column LNG • Better separation due to low pressure scrub column • Need expander-compressor – add CAPEX and OPEX Feed • This integrated NGLliquefaction option is believed to be more efficient than the option above Precool Expander Dehydration NGL Cryo requires low pressure and temperature to meet spec which increases CAPEX and OPEX UOP 6195-29 29
  30. 30. UOP SeparSIV Process/System Clean Gas Adsorbing Bed Regen Gas Blower Regen Heater Regen Gas Cooler Feed Filter Coalescer Particle Filter Regen Gas Separator Regenerating Bed Liquids UOP 6195-30 30
  31. 31. Technical Approach Remove C8 and above and BTX, trace water (capable of bulk water removal) Remove C6 and below, water to <0.1 ppm With a vast inventory of adsorbents and a library of control 31 UOP - requirements of your application schemes, UOP can match theCONFIDENTIAL 31 UOP 6195-31 File Number
  32. 32. Hydrocarbon to be removed carbon number Heavy Hydrocarbon Management Options 9 8 SeparSIV layered adsorbents 7 6 SeparSIV layered adsorbents Cryogenics 5 GPM < 2 2 GPM > 2 Product specification also affects process selection GPM = gallons of liquefiable hydrocarbons per 1,000 cubic feet of natural gas • The UOP SeparSIV Process can be used for pipeline gas dew point specification or before liquefaction after an AGRU to remove water and hydrocarbon compounds that freeze. UOP 6195-32 32
  33. 33. Cost Comparison* $MM SeparSIV Cryogenic CAPEX 1.0 1.5 OPEX (annual) 1.0 4.8 Lifecycle Cost 1.0 2.0 Economic Basis: 810 MMSCFD Rich Feed (1.8 GPM) Lifecycle Cost = CAPEX + (4 * OPEX) *Estimated Savings derived from • Compression required in the cryogenic scheme while SeparSIV only has a blower • Cryogenic BTEX removal requires more pressure drop and lower temperatures, which drive up CAPEX and OPEX • *Cryo only considers compressor power Cryogenic system better suited for higher GPM and loose *product specifications Over how many years? UOP 6195-33 33
  34. 34. Conclusions UOP’s Integrated FLNG Pretreatment • Flexible ‒ Multiple technology building blocks to meet varied feed properties over life of the gas field • Proven Technology ‒ Technology used in applications on land and offshore for past 30 years ‒ Low lifecycle costs • Multiple Execution Models ‒ Provided as single or multi-lift equipment modules ‒ Licensed with key mechanical equipment ‒ Licensed only UOP 6195-34 34
  35. 35. UOP 6195-35 35
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