Overview of Liwan 3-1 Deepwater Subsea Tieback Gas Development Weiqiang Liu, Chief Engineer South China Sea Deep Water Gas Development PMT CNOOC Limited
CONTENTS Introduction to Liwan 3-1 Deepwater Gas Development Selection of Deepwater Development Concepts Liwan 3-1 Development Progress Report 2 2
The Geographical Location of LW3-1 Gas Field Pan Yu 34-1/35-2/35-1 Water Depth 200-378m Pan Yu 30-1 & Hui Zhou 21-1 (Existing) Water Depth 200m Liu Hua 29-1 Future Tieback Water Depth 720m Li Wan 3-1 Water Depth 1500m Liu Hua 34-2 Future Tieback Water Depth 1146m LW3-1 deepwater field subsea tieback to a shallow water central production platform; A large processing capacity reserved for future tieback developments in the vicinity. 3 3
The Geographical Location of LW3-1 Gas Field The Continental Shelf o Approximately 250km distance from shore to the water depth of 200m, small slope; o Less than 100km from the water depth of 200m to 1500m, deep slope. Gas Resources o Li Wan 3-1 Deepwater Field o Pan Yu34-1/35-1/35-2 Shallow Water Fields o Liu Hua 29-1/34-2 Deepwater Fields o Short Tieback Distance between all the fields above 4 4
Introduction to Liwan 3-1 Gas Development The Liwan 3-1 Gas Field located in South China Sea, the first deepwater development in China CNOOC & Husky Production Sharing Contract (PSC) for Block 29/26 signed in 2004 The Gas Field discovered in 2006 and located approximately 310 km Southeast of Hong Kong The subsea facilities lie in water depths ranging from 1,350 to 1,500 meters and subsea tie-back 79km to a shallow-water central production platform located in 189.5m water depth then further tieback 261km to an onshore gas plant The deepwater subsea facilities operated by Husky China while the shallow water and onshore facilities operated by CNOOC The First Gas Production targeted for 4 th Quarter 2013 for Liwan 3-1 Gas Field and 3 rd Quarter 2014 for Panyu 34-1/35-1/35-2 Gas Fields 5 5
Potential Resources in the Vicinity of LW3-1 Field 6 6
Phase Developments & Process Capacity Operator-CNOOC Facilities Design Process Capacity Gaolan Onshore Terminal in Zhuhai LW3-1 Central Phase 1 Process: 8.0 BCM/Year Boosting: 10.0BCM/Year Platform Phase 2 Process: 12.0 BCM/Year Export Shallow Export: 12.0 BCM/Year PY34-1 Central Platform LW3-1 Central Platform Pipeline Onshore Gas Plant Water Phase 1 Phase 2 Future (BCM = Billions Cubic Meters) Process: 8.0 BCM/Year Process: 12.0 BCM/Year Process: 20.0 BCM/Year PY35-1 Subsea Operator - Husky LH29-1 Future Operator - CNOOC LW3-1 Subsea LH34-2 Future 7 7
Liwan 3-1 Subsea Tieback Gas Development 10 Subsea wells in water depth ranging from 1,350 to 1,500 meters 2 Manifolds and 1 PLEM 2 ø22 79 km Main Deepwater Flowlines and 79 km Subsea Umbilical & MEG Supply Line from PLEM to Platform 1 ø30 261km shallow-water export pipeline to onshore gas plant 1 Central Production Platform w/separation, Gas Dehydration, Compression & MEG Systems, 200 Person Living Quarters, located in water depth of 189.5m 1 Onshore Gas Plant with an area of 1.45 millions m 2 located at the Gaolan Island in Zhuhai next to Macao Onshore Gas Plant Central Platform (CEP) Pipeline End Manifold Main Flowlines (PLEM) Liuhua 34-2 West Manifold East Manifold 8 8
PY34-1/35-1/35-2 Subsea Tieback Gas Development The Pan Yu 34-1 Central Production Platform located in water depth of 190.2m 14ˮ 31.3 km shallow water subsea pipeline to receive mixed fluids consisting of dry gas and dewatering condensate from PY34-1 Platform Panyu 35-1 and 35-2 with 7 subsea wells tied back to PY34-1 Platform LW3-1 Platform receives and boost dry gas from PY34-1 Platform. 9 9
Typical Deepwater Gas Development Scenarios in GOM The Subsea Mensa Field in 1610m water depth tie-back 109km to a platform at West Delta 143 in 112m water depth; The Red Hawk Cell Spar in 1615m water depth tie-back 96km to Baldpate Platform, designed as a floating alternative to a long-distance tieback; The Canyon Express Fields, TLP Ram-Powell tieback to Platform Virgo, Neptune Spar & TLP Marlin tieback to Canyon Express Pipeline. 10 10
Deepwater Development Scenarios for LW3-1 Gas Field Scenario A: Spar/TLP/SEMI to Shallow Water Platform then export to Onshore Gas Plant Scenario B: Subsea Facilities tieback to Shallow Water Platform then export to Onshore Gas Plant Scenario C: Spar/TLP/SEMI directly export to Onshore Gas Plant Scenario D: Subsea Facilities directly tie-back to Onshore Gas Plant 11 11
Criteria for Selection of Scenarios Gas Sale Market and Production Rate Location Selection for Shallow Water Platform Location Selection for Onshore Gas Plant Flow Assurance from Subsea Wells to Surface Facilities Investment and Development Schedule Future Developments in the vicinity 12 12
Options of Floating Production Units (FPU) TLP Tension Leg Platform SEMI Semisubmersible Platform Spar Deep Draft Caisson Vessel 13 13
Main Driving Factors for LW3-1 Gas Development Avoid a long distance tie back, therefore subsea tieback to a shallow water platform Use mature and reliable technology of subsea facilities and shallow water jacket platform A short development period about 3 years An easy tieback to future developments of the gas fields in the vicinity. 14 14
Final Selection of Liwan 3-1 Subsea Tieback Gas Development LW 3-1 Field: 10 Subsea Wells, 1 PLEM, 2 Manifolds, etc. Central Production Platform: o Located in Water Depth of 190m; o Phase I: 8.0 billion m 3 /a o Phase II: 12.0 billion m 3 /a Deepwater Tieback: o 2 22 79km main flowlines o 1 7 79km umbilical o 1 6 79km MEG supply line Shallow Water Export: o 1 30 261km export line o 12.0 billion m 3 /a including future developments 15 15
Gaolan Onshore Gas Plant Under Construction Mechanical Completion: September 2013 Commissioning with Gas: October 2013 Gas Commercial Sale: End of 2013 16 16
Gaolan Onshore Gas Plant Under Construction Gas Processing Area / Spherical Tanks Main Process Area Condensate (30,000m 3 ) / Firewater Tanks (10,000m 3 ) Slug Catcher (175m x 85m); 7,000m 3 Jetty (415m Long) Seawall (1km) Enclosing EL+6.0m Platform 17 ISOPE-2013 17 Anchorage 17
Completion of Laying ø30 261km Shallow Water Export Pipeline COOEC s Shallow Water Pipe-Lay Vessel HYSY202 Slope Section at Gaolan Landfall at EL+50m Platform Global s Newbuilt Shallow Water Pipe-Lay Vessel G1201 Normand Clough to Complete SSIV and SP on Jul 28, 2013 18
Marine Spread for Deepwater Pipelay & Construction FDS2 to lay 2 nd 22 Main Flowline, CRA Infield Lines. PLEM, Manifolds, etc. HYSY 201 to lay 6 MEG Line FDS1 to lay 1 st 22 Main Flowline & CRA Infield Lines, etc. Normand Cutter to Lay Umbilical, Jumpers, Flying Leads, etc. Normand Baltic to Perform Pipeline Testing & Commissioning, etc. 19 19
32,000Te LW3-1 CEP Jacket Construction & Installation Jacket Fabrication from Dec 2010 to Jul 2012 Loadout onto T-Shaped Launch Barge HYSY229 July 18, 2012 HYSY229 w/ CEP Jacket Sailaway July 27, 2012 Jacket Launch August 30, 2012 20 ISOPE-2013 Anchorage 20 20
26,000Te LW3-1 CEP Topsides Construction & Floatover Installation with 4,888Te Deck Support Frame (DSF) Topsides Fabrication from Jun 2011 to April 2013 Loadout onto T-Shaped Launch Barge HYSY229 April 10, 2013 HYSY229 w/ CEP Topsides Sailaway on May 5, 2013 The Most Challenging Floatover Installation May 23, 2013 21 ISOPE-2013 21 Anchorage 21
Concluding Remark Safety: 28 Millions manhours so far; Schedule: Gas Commercial Sale by end of 2013; Cost: within ODP Budget; OSHA incident rate: 0.042 0 Death 5 Lost time accidents 15 Near Miss Quality: No major quality issues. 6341 Safety Observations 22 ISOPE-2013 Anchorage 22 22
Thank You! Any Question? 23 ISOPE-2013 Anchorage 23 23
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