The Matterhorn project Presentation at the Marine Technology Society Luncheon April 22, 2004 Émetteur
Agenda General Project Overview Development architecture Key challenges Execution highlights Conclusions 2
General overview 0 25 50 100 Louisiana Texas Houston Galveston Brazos High Island Miles West Cameron East Cam. Verm. SMI New Orleans West Delta SP Matterhorn Eugene Ship GI Island Shoal South Timbalier Mississippi Canyon BS Main Pass MO Virgo Aconcagua VK VK 200 m EW MU 1000 m East Breaks Garden Banks Green Canyon Atwater Alaminos Canyon 2000 m 3000 m Keathley Canyon Walker Ridge Lund Total Properties Exploration Production 3
Key Time line Discovery early 1999: 2800 ft water-depth, Multi-layered reservoir Decision to develop: July 2001 Start development drilling: December 2001 Installation: August 2003 Start well completion: September 2003 First oil: November 2003 4
The platform : a SeaStar TLP Surface piercing structure (TLP or SPAR) w/ dry tree chosen due to reservoir complexity (Multi-levels). Atlantia chosen after design competition with an EPCI Lump Sum Contract. Hull : draft 104, height 125, dia. 84 weight 5,500 T. 9 slots for production risers and dry trees (spacing 10 x10 ) Mooring : 6 x 32 tendons, 6 x 96 piles (tension 2,800 klbs per tendon). 1,000 HP W/O rig (separate contract). 10 Gas and 8 Oil Export SCR s, WI flexible Provisions for future subsea tie-backs ABS Class FOI 5
Topsides general Overview 140 x140, 3 decks 11,000kips dry, 12,600 kips operating 33,000 bopd, 55 MMscfd, 20,000bwpd 100 MMscfd gas drying, WI 30,000 bwpd 2 Cranes: 45 t and 75t 2x 4.5 MW turbines (2x50%);1.2 MW e-gen Gas engine driven recip. compressors 3 survival capsules, 50 pax each LQ: 22 pax permanent, 78 temporary Blast &fire wall 6 Helideck: 56 x56 for Bell 412, Sik 76
Risers and pipelines Export by two 16 miles pipelines (8 and 10 ), 8 owned by Chevron. Hot-tap tie-in points to trunklines 7
SCR Overview (first Total SCR s) NOT TO SCALE MWL 1300 FT. HELICAL STRAKES 16D X 0.25DHELICAL STRAKE SCALE: NONE 10" GAS EXPORT (SCR) 10.75" O.D x 0.625" W.T PIPE L catenary = 3248 ft. L catenary = 3508 ft. 1300' STRAKE LENGTH L catenary = 3823 ft. 15 HANG -OFF ANGLE WD @ TLP = 2811 ft. SCR TOUCH DOWN (MEAN) 3 SEA BED SLOPE SCR TOUCH DOWN (FAR) MUDLINE EL.(-) 2706 ft. SCR TOUCH DOWN (NEAR) MUDLINE @ CL TLP 1499' HORIZONTAL DISTANCE TO TDP (NEAR) 1955' HORIZONTAL DISTANCE TO TDP (MEAN) 2464' HORIZONTAL DISTANCE TO TDP (FAR) 8 MATTERHORN
Development architecture screening process PHASE 1: SCREENING STUDY DRILLING/COMPLETION COST PRE-SIZING AND COST OF 12 CONCEPTS (Summer 1999) PHASE II: DEVELOPMENT OPTIONS DRY TREE OR SUBSEA? CONCEPTS SELECTION PHASE III: TOPSIDES DESIGN PROCESS DESIGN LAYOUT DRAWINGS (Nov 1999 April 2000) PHASE IV: CONCEPT COMPETITION FINAL PROPOSALS / SELECT ONE CONCEPT (March 2000 to June 2001) PHASE V: PROJECT July 2001 - November 2003 (FIRST OIL) 9
oncepts Considered in Phase I (Screening Study) Dry Tree Atlantia Sea Star Modec Moses ABB TLP and Mini-TLP Spars Classic Spar and Truss Spar Kvaerner DDF Technip TPG 3300 Mustang Compliant Tower Hutton TLP Sub-Sea Atlantia Sea Star Cal Dive EGB Semi-Submersible Oceaneering Converted Semi-Submersible Intec Remote Subsea ( Taylor MC 20 Platform) 10
he retained concepts 11
Key Project Technical Challenges Drilling: Deviated wells with shallow kick-off and shallow water flow Biggest mono-hull TLP and first with dry risers Met-Ocean: consideration of Cold core current profile Production risers with Surface Xmas trees: Keel joint development Reeled SCR s 12
Challenge: biggest mono-hull TLP + dry trees 13
Challenges: Drilling of High Angle wells 0 0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 MC199#1 7 Dry Tree 1 Wet Tree (A6) 1,000 A5 A6 2,000 A2 3,000 MC243#2 4,000 7 Dry Tree 1 Wet Tree (A6) A3 A4 MC243#1 A1 2000' 5,000 A7 6,000 Conoco #1 4000' A9 6000' 7,000 A4 A2 A5 A6 8,000 A1 A9 A3 MC243#3 9,000 10,000 A7 14 11,000
#1 #2 #3 #2 #3 #4 #5 #6 #7 A-6 WATER INJECTION UMBILICAL #1 #8 Challenges: Consideration of Cold Core Current (CCE) 0 6" WATER INJECTION SCR FUTURE SCR FUTURE SCR FUTURE SCR 10" GAS EXPORT 8" OIL EXPORT FUTURE SCR #4 #5 #6 #7 #8 FUTURE SCR 500 1000 1500 Before UMBILICALS Water Depth (ft) 2000 100yr Loop Cold-Core Eddy 2500 3000 15 ORIGINAL RISER ARRANGEMENT QTY - 1 OIL EXPORT 8" SCR QTY GAS EXPORT 10" SCR QTY WATER INJECTION 6" SCR QTY - 1 FUTURE WATER INJECTION 6" SCR QTY - 4 FUTURE PRODUCTION 6" SCRs FUTURE FLEXIBLE RISER FUTURE UMBILICAL FUTURE FLEXIBLE RISER FUTURE SCR 10" GAS EXPORT 8" OIL EXPORT FUTURE UMBILICAL 0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1 Fatigue: FUTURE SCR design life at 10 x recorded event A-6 WATER INJECTION RISER Need fairings to 1500 FUTURE WATER INJECTION UMBILICAL FUTURE WATER INJECTION RISER Platform offset Non-Dimensionalised Current Speed (1=max) CURRENT RISER ARRANGEMENT Riser/tendon interference QTY - 1 OIL EXPORT 8" SCR QTY - 1 GAS EXPORT 10" SCR QTY 1 WATER INJECTION 6" SCR / FLEXIBLE QTY - 2 FUTURE FLEXIBLES QTY 1 FUTURE WATER INJECTION SCR QTY - 2 FUTURE PRODUCTION SCRs After
Challenges: Production riser keel joint 16
Project Highlights Drilling Construction Installation Production risers SCR s 17
Drilling: pre-drilling of 7 wells, seabed spacing 25ft ENSCO 7500 Tropical Storm Hanna 18
Hull construction by Keppel/Fels - Singapore 19
Topsides Construction by Gulf Marine Fabricators 20
Tendons fabrication by Kiewitt Offshore Tendon main body sections with fairings Bottom connector 21
Hull transport on the Tai an Kou 22
HULL Load-on Transportship 23
Installation by HMC Hermod Installed piles in March 03. Tendon Installation started on June 3, 03. Went on Stand by during tendon installation on June 10 due to high current (Eddie Current >1.5 knts) and two tropical storms. Resumed work on July 16 after 34 days stand-by Deck was set on August 3. Platform was habitable on Aug 5. 24
Eddy Currents 25
Pile and tendon Installation Tendon spacer Buoyancy cans 26
Hull Installation 27
Topsides lift: 5800 t 28
Production risers Keel joint centraliser PRT s Well bay 29
Pipelines & sub sea Multi-contract &PO approach Pipelines were installed in April May 2003 by the reel-ship Deep Blue (Technip) before platform installation and picked up by the crane barge Hermod. Commissioning by Stolt Subsea injection well completion and connection to be performed in May-June 2004. 30
SCR Results Installed Within Tolerance Both Lines Have Been Pigged CP Inspection Results OK Touchdown Point Trenching As Predicted 31
Conclusions 3.2 Million manhours LTIF <1 24 months between sanction and deck mating 27 months to first oil 4 wells producing to-date 32