UOP Advanced Solutions for Natural Gas Processing Pavel Ryabchenko UOP A Honeywell Company
OGT 2011 16th International Oil & Gas Conference Ashgabat,...
UOP’s Company History from Gas Processing Perspective 1st integrated LNG complex based on UOP feed pretreating technology UOP acquires rights to Amine GuardTM& SelexolTM process technology Joint venture between Union Carbide CAPS division and UOP
2009 2004 1998
Separex membrane system for FPSO
1994 1988 1949 1914
UOP begins to offer Separex membrane systems
Union Carbide develops MOLSIVTM adsorbents
UOP founded UOP 5468-03
UOP Gas Processing Separex Membranes
UOP Gas Processing Separex Membranes Experience
World-Scale Processing Plants Delivered as Modular Packaged Equipment Advanced Pretreatment Demonstrated to Improve Element Life Off-shore Experience
Recent Successes Castor Underground Gas Storage (UGS) ESCAL (Spain) Castor Underground Gas Storage Re-develop the abandoned offshore Amposta reservoir Provide stability and back-up to the gas supplies in periods of high gas demand: 20-40d/year Gas processing (onshore): – 980 MMscfd – 5% to 2.5% CO2 – 50vppm to 10.4vppm H2S
Process selection/Value Proposition – Quick Steady state with Fast startup and high turndown – Reliability, availability – Environmental (H2O) – Process selection to avoid 2nd dehydration onshore – Flexibility / expansion More info:
C2 Acid Gas to SRU (RSH, H2S, COS) Treated Regen Gas
RSH Removal
(Selexol™)
Treated Gas
NGL Recovery
C3
C4
(to pipeline, LNG, GTL)
Regen Gas
RSH Treater (Molecular Sieve) COS & RSH Treater (Molecular Sieve)
C4 C3
UOP 5633-6
Integrated Flow Scheme
Hybride Flow Scheme: Membrane-Amine Treatment Combining the best of two Technologies Amine System Single Stage Membrane
Treated Gas
to Acid Gas Cooler XXX
XXX
To Boiler
xxxx
Separex Membranes Revamp Grassroots Debottleneck existing amine units Bulk-cut with membranes • Increasing feed gas flowrates, or, • Very attractive offshore to allow • Increasing feed gas CO2 content lower metalurgy and reduce transport volume, or, ► membrane will treat the gas to a • Meeting pipeline spec at wellhead CO2 content that is acceptable to and further reducing to LNG spec the existing amine unit downstream Each application has an optimal scheme: Evaluate simplicity & robustness versus performance.
GB Family of Adsorbents Streams Processed/Contaminants Removed
Nat Gas
H2S
Naphtha LNG
COS
Propane
RSH LPG Hg
NGL Propylene
AsH3
GB products process and increase the value of a wide range of hydrocarbons
UOP 5633A-8
GB-220 Case Study: Natural Gas Duty 6-8 ppmv H2S
European Gas Processor Flow 15 MMSm3/Day (530 MMSCFD) Operating temperature 5°C Operating pressure 121 barg
GB-220
Long life achieved despite glycol containing natural gas < 0.1 ppmv H2S
UOP 5633A-9
Why Remove Mercury? 1. Equipment Protection
2. Improving product quality • Mercury found in refinery naphtha • >50% of world’s ethylene plants are naphtha fed 3. Catalyst protection • Many precious metal catalysts are susceptible to mercury poisoning • 1:1 Hg amalgams with Pt, Pd are stable at temperatures > 1.0 mg/m 3 has been measured
In Conclusion: UOP’s complete portfolio of gas treating processes allows for Integration and optimization of individual unit technologies into a systems package UOP’s innovative technologies provide optimization of natural gas treatment for pipeline transportation and further processing Proposed technological solutions are ready for implementation in gas processing industry of Turkmenistan
