Conocophillips · NYSE:COP

Conocophillips — Technical Presentation (September 2019)

19 slides from Conocophillips's technical presentation, Sep 19, 2019

  1. Slide 1: Design Suite to Remove Heavy Hydrocarbons from a Comprehensive Range of LNG Feed Gas Compositions

    Design Suite to Remove Heavy Hydrocarbons from a Comprehensive Range of LNG Feed Gas Compositions ©2019 ConocoPhillips Company Optimized Cascade® is a registered trademark of ConocoPhillips Company in the United States and certain countries

  2. Slide 2: Feed Characterization – Lumping & Grouping

    Feed Characterization – Lumping & Grouping  Lumping/Grouping Components  C6+  C6+ Split 60/30/10  C9+  C9+ Split 60/30/10  C14 Extended  Hydrocarbon Dew Point Difference  58°C (104°F) Herring – “Hydrocarbon Dew Point is a Critical Consideration for Pipeline Operations”, Pipeline & Gas Journa

  3. Slide 3: Retrograde Condensation Within Predicted Phase Envelope

    Retrograde Condensation Within Predicted Phase Envelope Two-Phase Hale, S. 2008. Determination of Hydrocarbon Dew Point Using a Gas Chromatograph. Emerson Process Management.

  4. Slide 4: Gas Pressure Drop Outside of Retrograde Condensation Region

    Gas Pressure Drop Outside of Retrograde Condensation Region Two-Phase Hale, S. 2008. Determination of Hydrocarbon Dew Point Using a Gas Chromatograph. Emerson Process Management.

  5. Slide 5: Same Pressure Drop Within Actual Phase Envelope

    Same Pressure Drop Within Actual Phase Envelope Two-Phase Hale, S. 2008. Determination of Hydrocarbon Dew Point Using a Gas Chromatograph. Emerson Process Management.

  6. Slide 6: Improper Feed Characterization – Feed Pretreatment

    Improper Feed Characterization – Feed Pretreatment  Feed Pretreatment  Liquid Formation in Pipeline or Feed Piping Slugging into Amine Contactor  Inability to Route Unexpected Liquid Formation to NGL Stabilizer and/or Treatment  Liquid Condensing in Amine Contactor • Foaming in Contactor • Foami

  7. Slide 7: Improper Feed Characterization – Liquefaction

    Improper Feed Characterization – Liquefaction  Upstream of Heavies Removal System  Heavies Removal System NGL Columns  Liquid Formation & Collection in Low Points  More Liquid Than Expected • Slugging Into Downstream Equipment • Increased Tray/Packing Loadings • Increased Thermal & Physical Stre

  8. Slide 8: Feed Characterization – Freezing Point

    Feed Characterization – Freezing Point  Similar Molecules  C14H26 – Same Molecular Weight  Freezing Point Difference  130°C (234°F) Boiling Freezing MW Density Point Point Component Formula g/mol o C g/cm3 o C 1, 1-dicyclohexylethane C14H26 194.36 271.17 0.8897 -20.82 1, 2-dicyclohexylethane C14

  9. Slide 9: Heavy Hydrocarbon Removal – Two Column Configuration

    Heavy Hydrocarbon Removal – Two Column Configuration  First Column – “Heavies Removal Column”  High Pressure Operation  Removes Freezing Components to Low (ppm) & (ppb) Range  Second Column – DeC2 or NGL Stabilizer  Lower Pressure Operation  Returns Lighter Components to LNG Process  Deethani

  10. Slide 10: Heavies Removal Column - High Pressure Fractionation

    Heavies Removal Column - High Pressure Fractionation Proper feed characterization is vitally important when operating at or near the retrograde region 10

  11. Slide 11: Heavies Removal Column – No Reflux

    Heavies Removal Column – No Reflux  A Heavies Removal Column Without Reflux May be Installed When There Are  NGL Components to Remove  No Freezing Components To Remove  No Reflux is Typically Applicable For  Upstream Gas Processing  Lean Reservoir Gas (No freezing Components) 11

  12. Slide 12: Heavies Removal Column – Lean Reflux

    Heavies Removal Column – Lean Reflux  Lean Reflux is Utilized When There Are  NGL Components to Remove  Freezing Components Must be Removed  Insufficient C2-C5 Components for Rich Reflux  Ethane Recovery Requirements  Lean Reflux May Originate From  Condensing a Portion of the Column Overhead

  13. Slide 13: Heavies Removal Column – Rich Reflux

    Heavies Removal Column – Rich Reflux  Rich Reflux May be Used When There Are  LPG/NGL Components to Remove  Deep LPG Recovery is Required (Optional)  Freezing Components to Remove  Sufficient C2-C5 Components Present in the Feed to Establish Rich Reflux  Rich Reflux May Originate From  An Ove

  14. Slide 14: Internal Solvent Recovery & Circulation

    Internal Solvent Recovery & Circulation  Internal Solvent Recovery & Circulation To LNG Process May be Used When There Are  Freezing Components to Remove  Freezing May Occur Upstream of Lean Reflux Internal Heavies Removal Column Solvent  Insufficient C2-C5 Components in Feed Chilling Condensing

  15. Slide 15: External Solvent Injection, Recovery & Circulation

    External Solvent Injection, Recovery & Circulation To LNG Process  External Solvent Circulation May be Used When There Are  Freezing Components to Remove  Freezing May Occur Upstream of Solvent Condensing Heavies Removal Column Injection Feed Duty  Insufficient C2-C5 Components in Condensing Fee

  16. Slide 16: Expander & Compander Options

    Expander & Compander Options To LNG Process  Gas Expanders May be Used When There Is  High Feed Gas Pressure Reflux  LPG/NGL Components to Remove  Lean/Rich/No Heavies Removal Reflux Condensing  Internal or External Reflux Duty Feed To LNG Process  Companders May be Used When There is  High F

  17. Slide 17: Generalized Heavy Hydrocarbon Removal System Selection

    Generalized Heavy Hydrocarbon Removal System Selection 17

  18. Slide 18: Optimized Cascade® Process - The Heavies Removal Advantage

    Optimized Cascade® Process - The Heavies Removal Advantage  Focused  Targeted Recovery and/or Removal of Identified Components  Simple  Easy to Operate  Easy to Construct & Modularize  Cost-Effective  Lower Complexity Leads to Lower Capital Costs  Efficient  Efficient Heat Integration Leads

  19. Slide 19: Discussion

    Discussion Ree Be CASCADE"PROCESS

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