new upstream gas treating facilities to maintain lng production plateau
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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.

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Presentation Transcript
slide2
Introduction

Offshore Facilities Description

Onshore Facilities Description

Onshore Facilities Study and FEED

Project Status

Conclusion

Presentation Overview

slide3

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.
slide4

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.
slide5

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

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.
onshore facilities study
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.
onshore facilities study approach 2
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

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 selection1
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
new acid gas removal unit feed
New Acid Gas Removal Unit - FEED

PAGRU Process Scheme with Hot Pre-Flash low BTX Configuration

new acid gas removal unit feed1
New Acid Gas Removal Unit - FEED

PAGRU Process Scheme with Hot Pre-Flash low BTX Configuration

new acid gas removal unit ffed
New Acid Gas Removal Unit - FFED

PAGRU Process Scheme with Hot Pre-Flash low BTX Configuration

slide14

New Acid Gas Removal Unit - FEED

PAGRU Process Scheme with Hot Pre-Flash low BTX Configuration

slide15

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)
slide16

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

slide17

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

slide18

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.
slide19

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. 
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