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

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

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 Existing 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
Feed Gas
From Slug Catcher
AGR 1
AGR 2
AGR 3
Lique. 1
Lique. 2
Lique. 3
620 MMscfd
0.7 % H2S
2.3 % CO2
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
Sour Water
SWS
SRU 4
Stripped Water
To Neutralization
Facilities
TGT By-Pass
Liquid
Sulfur
TGT
Tail
Gas
SULFUR DEGASSING SRU 4
Flue Gas To ATM
Vent Gas
INCINERATOR
SRU 4
Liquid Sulfur To Storage Tanks

17. New Sulfur Recovery Unit – CLAUS Section
Claus Reactors
Feedstock
Pre-heating
Main Combustion
Chamber
1st CLAUS
REACTOR
2nd CLAUS
REACTOR
COMB. AIR
FIRED
HEATER
1st
STEAM
REHEATER
2nd
STEAM
REHEATER
COMB.
AIR
CLAUS
TAIL GAS
COMB. AIR PREHEATER
FUEL GAS
1st SULFUR CONDENSER
2nd 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.