1 / 19

New Upstream Gas Treating Facilities To Maintain LNG Production Plateau

New Upstream Gas Treating Facilities To Maintain LNG Production Plateau. Introduction Offshore Facilities Description Onshore Facilities Description Onshore Facilities Study and FEED Project Status Conclusion. Presentation Overview. Introduction.

winifred-foster
Télécharger la présentation

New Upstream Gas Treating Facilities To Maintain LNG Production Plateau

An Image/Link below is provided (as is) to download presentation Download Policy: Content on the Website is provided to you AS IS for your information and personal use and may not be sold / licensed / shared on other websites without getting consent from its author. Content is provided to you AS IS for your information and personal use only. Download presentation by click this link. While downloading, if for some reason you are not able to download a presentation, the publisher may have deleted the file from their server. During download, if you can't get a presentation, the file might be deleted by the publisher.

E N D

Presentation Transcript

  1. New Upstream Gas Treating Facilities To Maintain LNG Production Plateau

  2. Introduction Offshore Facilities Description Onshore Facilities Description Onshore Facilities Study and FEED Project Status Conclusion Presentation Overview

  3. Introduction • The Qatargas 1 LNG facility is divided into two sections: • Upstream facilities (offshore facilities, onshore receiving and condensate loading facilities). • Downstream facilities (LNG Plants). • There are now 4 Qatargas LNG ventures and this project relates only to Qatargas 1. • Qatargas 1 shareholders are; Qatar Petroleum (QP), Total, ExxonMobil, Marubeni and Mitsui. • LNG Trains 1 & 2 started in 1996 and Train 3 in 1998, • The LNG plant also produces condensate and sulfur.

  4. Offshore Facilities • Reservoir: North Field (Khuff) reserve > 900 TSCF • 2 production platforms accommodate 3 Trains • 1 Living Quarter platform • 3 Wellhead platforms with a total of 20 wells & 1 Flare • platform.

  5. Offshore Facilities • To maintain the present LNG production plateau, it requires • drilling 4 new wells and re-completion 2 existing wells. • The new wells have higher H2S content and it will result in 2.0 % mol of H2S in the combined feed gas to onshore • Drilling of new wells are implemented in 2007 and 2011.

  6. Onshore Facilities LNG Train 2 LNG Train 1 LNG Train 3 • Existing Facilities: • 3 LNG Trains, 2 Acid Gas Enrichment Units, 2 Sulfur Recovery Units. • 4 LNG storage tanks and utilities.

  7. Onshore Facilities Study • A Study was conducted to determine the impact of • increasing H2S in the feed from its original design of 0.8 % mol • to 2.0 % mole. • Two approaches were studied: 1- Revamp existing AGRU by adding pre-Absorbers. 2- Avoid revamping existing AGRU, provide Pretreatment Acid Gas Removal Unit (PAGRU) as a new unit. • Approach 2 was selected based on safety, construction, cost, • schedule and plot plan utilization.

  8. Onshore Facilities Study (approach 2) Existing Facilities AGE 1 SRU 1 Sulfur Acid Gas AGE 2 SRU 2 Sulfur AGR 1 AGR 2 AGR 3 Feed Gas From Slug Catcher Lique. 1 Lique. 2 Lique. 3 0.7 % H2S 2.3 % CO2 620 MMscfd LNG 1720 MMscfd 2.07 % H2S 3.30 % CO2 0.06 % H2S 1.8 % CO2 Acid Gas Sulfur 880 t/d AGR 4 SRU 4 1100 MMscfd PAGRU : Solid line denotes new facilities

  9. Onshore Facilities Study – Process Selection • The objective is to select the most suitable process for the new • AGRU in terms of technology, experience, and process guarantee. • Other criteria are selectivity in removing H2S from 2.07 % mol to • 600 ppm mol and removing CO2 from 3.3 % mol to 1.8 % mol. • Also, selective H2S removal from tail gas from new SRU to have • H2S < 250 ppmV in treated tail gas. • One third of feed gas will bypass the PAGRU. Treated gas from • PAGRU is mixed with one third of raw feed gas. The recombined • gas stream will contain 0.8 % H2S and 2.3 % mol CO2 • (same level as current feed gas quality). • Four process Licensors were evaluated. Process scheme • proposed by Prosernat met the above objectives, criteria and • minimum solvent circulation rates.

  10. Onshore Facilities Study – Process Selection • Qatargas selected the AdvAmine™ MDEAmax process, developed • by Total and licensed by Prosernat for the Acid Gas Removal Unit. • KTI technology was used for the new Sulfur Recovery Unit and • Tail Gas Treatment Unit. • New SRU require H2S in acid gas of 54 % (min.) and also • minimal aromatics present in the acid gas. Prosernat proposed • modified process configuration (hot pre-flash low BTX scheme) • consist of: • High Pressure Absorption Section • Hot Pre-Flash Column • Tail Gas Absorption Section • Amine/MDEA Regeneration Section

  11. New Acid Gas Removal Unit - FEED PAGRU Process Scheme with Hot Pre-Flash low BTX Configuration

  12. New Acid Gas Removal Unit - FEED PAGRU Process Scheme with Hot Pre-Flash low BTX Configuration

  13. New Acid Gas Removal Unit - FFED PAGRU Process Scheme with Hot Pre-Flash low BTX Configuration

  14. New Acid Gas Removal Unit - FEED PAGRU Process Scheme with Hot Pre-Flash low BTX Configuration

  15. New Sulfur Recovery Unit - FEED • The Sulfur Recovery and Tail Gas Treatment Unit Consist of: • Claus Section • Tail Gas Treatment Section • Thermal Incinerator Section • Liquid Sulfur Degassing Section • Sour Water Stripper (SWS)

  16. New Sulfur Recovery Unit - FEED Rich Amine to AGR 4 LP Flash Gas from AGR 4 Lean Amine from AGR 4 CLAUS Tail Gas Acid Gas from AGR 4 CLAUS SRU 4 TGT SRU 4 SWS SRU 4 Sour Water Stripped Water To Neutralization Facilities TGT By-Pass Liquid Sulfur TGT Tail Gas Flue Gas To ATM SULFUR DEGASSING SRU 4 INCINERATOR SRU 4 Vent Gas Liquid Sulfur To Storage Tanks

  17. New Sulfur Recovery Unit – CLAUS Section Claus Reactors Main Combustion Chamber Feedstock Pre-heating 1st CLAUS REACTOR 2nd CLAUS REACTOR COMB. AIR FIRED HEATER 1st STEAM REHEATER 2nd STEAM REHEATER COMB. AIR CLAUS TAIL GAS COMB. AIR PREHEATER 2nd SULFUR CONDENSER FUEL GAS 1st SULFUR CONDENSER 3rd SULFUR CONDENSER CLAUS BURNER THERMAL REACTOR WASTE HEAT BOILER SULFUR SULFUR SULFUR ACID GAS ACID GAS PREHEATER Sulfur Condensers

  18. Project Status • FEED work will complete in September 2008 • Engineering Procurement Construction (EPC) will be developed after • Contractor selection • Project completion date in the first half of 2012 • Long Lead Items (LLI) procurement will be initiated 4 months • prior to EPC award.

  19. Conclusion • The installation of pretreatment acid gas removal unit and related • sulfur unit will  limit the H2S content in feed gas to the existing • trains at the current levels (approx 0.8 % mol). • This will enable Qatargas to  continue to saturate the  LNG plant • capacity and maintain its current  LNG production  rates  plateau. 

More Related