New Upstream Gas Treating Facilities To New Upstream Gas Treating Facilities To

Maintain LNG Production PlateauMaintain LNG Production Plateau

• Introduction• Offshore Facilities Description• Onshore Facilities Description• Onshore Facilities Study and FEED• Project Status• Conclusion

Presentation OverviewPresentation Overview

IntroductionIntroduction

• 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.

Offshore FacilitiesOffshore 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.

Offshore Facilities 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.

Onshore Facilities Onshore Facilities

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

LNG Train 2

LNG Train 3LNG Train 1

Onshore Facilities StudyOnshore 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.

Onshore Facilities Study (approach 2)Onshore Facilities Study (approach 2)

AGR 1

AGR 2

AGR 3

0.7 % H2S2.3 % CO2

AGE 1

AGE 2

SRU 1

SRU 2

Lique. 1

Lique. 2

Lique. 3

PAGRU

Feed Gas From Slug Catcher

1720 MMscfd2.07 % H2S3.30 % CO2

0.0

6 %

H2

S

1.8

% C

O2

Ac

id G

as

Acid Gas

Sulfur

Sulfur

LNG

1100 MMscfd

620 MMscfd

: Solid line denotes new facilities

Existing Facilities

AGR 4 SRU 4Sulfur 880 t/d

Onshore Facilities Study – Process Selection 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.

Onshore Facilities Study – Process SelectionOnshore 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

New Acid Gas Removal Unit - FEEDNew Acid Gas Removal Unit - FEED

PAGRU Process Scheme with Hot Pre-Flash low BTX Configuration

SourGas

SRU

To Incinerator

Pre-treatedGas

Absorber

Tail Gas Absorber

Regenerator

Hot Pre-FlashColumn

Tail Gas

FlashedAcid Gas

FlashGas

AcidGas

New Acid Gas Removal Unit - FEEDNew Acid Gas Removal Unit - FEED

PAGRU Process Scheme with Hot Pre-Flash low BTX Configuration

SourGas

SRU

To Incinerator

Pre-treatedGas

Absorber

Tail Gas Absorber

Regenerator

Hot Pre-FlashColumn

Tail Gas

FlashedAcid Gas

FlashGas

AcidGas

Semi-lean solvent fromTG Absorber is

partially Recycled to HP Absorber

Total solvent flow Reduced by 20%

New Acid Gas Removal Unit - FFEDNew Acid Gas Removal Unit - FFED

PAGRU Process Scheme with Hot Pre-Flash low BTX Configuration

SourGas

SRU

To Incinerator

Pre-treatedGas

Absorber

Tail Gas Absorber

Regenerator

Hot Pre-FlashColumn

Tail Gas

FlashedAcid Gas

FlashGas

AcidGas

Hot Pre-Flash liberatesSelectively CO2 with

Most of the BTX

PAGRU Process Scheme with Hot Pre-Flash low BTX Configuration

New Acid Gas Removal Unit - FEEDNew Acid Gas Removal Unit - FEED

SourGas

SRU

To Incinerator

Pre-treatedGas

Absorber

Tail Gas Absorber

Regenerator

Hot Pre-FlashColumn

Tail Gas

FlashedAcid Gas

FlashGas

AcidGas

Acid gas enrichmentCan be achieved by:-Pre-flash pressure- Acid gas recycling

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)

New Sulfur Recovery Unit - FEEDNew Sulfur Recovery Unit - FEED

New Sulfur Recovery Unit - FEEDNew Sulfur Recovery Unit - FEED

CLAUS

SRU 4

TGT

SRU 4SWS

SRU 4

SULFUR DEGASSING

SRU 4

INCINERATOR

SRU 4

Acid Gas from AGR 4

Liq

uid

Su

lfur

Rich Amine to AGR 4

LP Flash Gas from AGR 4

Lean Amine from AGR 4

Sour Water

CLAUS Tail Gas

TGT By-Pass

Stripped Water

To NeutralizationFacilities

TG

T

Ta

il G

as

Vent Gas

Liquid Sulfur To Storage Tanks

Flue Gas To ATM

New Sulfur Recovery Unit – CLAUS SectionNew Sulfur Recovery Unit – CLAUS Section

ACID GAS

1stSTEAM

REHEATER

SULFUR

THERMAL REACTOR

WASTE HEAT BOILER

1st SULFUR CONDENSE

R

2ndSTEAM

REHEATER

1st CLAUSREACTOR

2nd CLAUSREACTOR

2nd SULFUR

CONDENSER

3rd SULFUR CONDENSE

R

SULFUR SULFUR

CLAUSTAIL GAS

ACID GAS PREHEATER

COMB.

AIR COMB. AIR PREHEATER

CLAUSBURNER

FUEL GAS

COMB. AIRFIRED

HEATER

FeedstockPre-heating

Main Combustion

Chamber

Claus Reactors

Sulfur Condensers

Project StatusProject 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.

ConclusionConclusion

• 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.