RPSEA UDW Forum June 22 & 23, 2010 Secure Energy for America
PROJECT TEAM RPSEA Operator Advisory Committee Anadarko Chevron Shell ConocoPhillips Subcontractors IntecSea NOV CTES General Marine Contractors GE Vetco Tidewater Huisman University of Tulsa Industry Advisors Halliburton Baker Hughes Inteq
RPSEA 1502 Coiled Tubing from a Small Vessel June 2010 Update Presentation Topics Project Objectives Background and Status Level Of Readiness System Configuration CT Capabilities Modeling Efforts to date Features & Advantages
The Search for a Cost Effective Deep Water Intervention System has been Going on for Years Riserless intervention systems have evolved around a subsea lubricator for electric and wireline intervention Aker Oilfield Services Light Well Intervention Vessel Seafloor intervention systems for coiled tubing have been investigated, but found too complex and expensive Coiled tubing intervention from dry trees (for deep water) has been increasing Other deep water intervention, requiring circulation, is done using MODUs
RPSEA Project: Coil Tubing Drilling and Intervention System (CTIS) Using Cost Effective Vessels This project is an approach that would go from conceptual feasibility, to the actual field test design and construction of necessary components, concluding a field test demonstration Establish intervention systems to reduce cost by 50% compared to MODU intervention for GoM Full coiled tubing capability same as from a Jack Up or on land Establish reliable hardware and operating scenarios Optimize for work in 1500 to 2000 meters of water, suitable for 3000 meter Strong emphasis on safety and environmental safeguards
FOLLOW ON OBJECTIVES Detail Design & Fabrication Demonstrate CT with Self Supporting Riser Simple Tasks on an Available Well Vessel of Opportunity Commercialize Safe Low Cost Deep Water CT Suitable for Central Gulf of Mexico Half the Cost of a MODU Work With Existing Service Contractors Dedicated Vessels if Justified Reusable Rental Risers Risers on Standby for Callout
Project 1502 uses a self standing riser (SSR) which we believe is an enabling technology for deep water well intervention to allow the cost effective use of coiled tubing.
RISER ELEMENTS Buoyancy Keel joint Premium joints with strakes Standard joints Stress joint Tieback connector Wellhead on suction pile
ALL THE TECHNOLOGY EXISTS TODAY Small vessels to handle using drilling and coiled tubing drilling and to run SSR Casing drilling, mud motors, cementing, etc. Self standing risers, shear rams, BOPs Coiled tubing intervention and drilling Mono bore completion with coil tubing Damp trees, subsea shallow separators SSR support platform for separator and storage of liquids
Reasons CT Not Being Used in Deep Water 1. Deck space Requirements for CT footprint too large for MODU s Thus too expensive (without costly modifications) 2. Riser required for majority of applications Safety Circulation Buckling Etc. 3. MODU s are in high demand and very expensive Is there a way to eliminate the need for an expensive MODU?
LEVEL OF READINESS Self supporting riser is established technology Prototype of Nautilus design has been installed in 3400 foot depth Now incorporating experiences with prototype CT is established technology Next step demonstrate CT using the self supporting riser
STATUS Building on Anadarko SSR Program Computer Simulations Wave Tank Validation Prototype Installed in 3400 Depth In 2006 Complete RPSEA Phase 1 in 2010
SSR TECHNOLOGY FIELD TRIAL
PHASE 1 WORK Adapt Riser for Retrieval & Reuse Easy Installation And Recovery Small Low Cost Vessels Smaller Buoyancy For Small Moon Pools Low Cost Stress Joints and Riser Pipe Simplify Design Of Variable Buoyancy Interface To Available CT Equipment Optimize For 1500 to 2000 Meter Depth Suitable For 3000 Meter Water Depth
RISER INSTALLATION VESSEL Typical SSR Installation Vessel 180 To 200 Feet Long DP 2 15 Ft Moon Pool 75 Ton Crane ROV
RISER READY FOR INTERVENTION VESSEL Selected BOP functions including shear & isolation SELF SUPPORTING RISER AS FOUND BY INTERVENTION VESSEL Maximum water depth 10,000 feet Shear & Reservoir Isolation Tree
DOWN HOLE INTERVENTION CONFIGURATION TYPICAL INTERVENTION VESSEL 180 TO 200 FEET LONG DP 2 10 FT MOON POOL 10 TON CRANE FOR TUBING & TOOLS ROV CT CONTRACTOR S CT reel STANDARD CT EQUIPMENT Injector Stabilized platform Diverter/wiper Selected BOP functions
Key CT Modeling Conclusions By NOV CTES CT Strings Can be Designed to Perform Interventions in Most Subsea Wells Straight Wall String Designs can Reach > 33,000 TD With available 120kpsi material Tapered String Designs can Reach 40,000 + Using reasonable buoyancy & pressures Optimum CT Size to Balance Pump Pressure and Fatigue Life is: 2 3/8 to 2 7/8
Maximum Well Depth Max Allowable Stress = 80% of Yield Stress Max Allowable Force = Force in CT @ Max Allowable Stress Incl. Margin of Overpull (MOP) = 10% of Max Allowable Force Same Fluid Inside & Outside the CT Fluid Density Grade of CT = Yield Stress (Kpsi) PPG 70 80 90 100 110 120 130 0 14,841 16,961 19,081 21,201 23,322 25,442 27,562 2 15,309 17,496 19,683 21,871 24,058 26,245 28,432 4 15,808 18,067 20,325 22,583 24,842 27,100 29,358 6 16,341 18,675 21,010 23,344 25,678 28,013 30,347 8 16,910 19,326 21,742 24,158 26,573 28,989 31,405 10 17,521 20,024 22,527 25,030 27,533 30,036 32,539 12 18,178 20,775 23,371 25,968 28,565 31,162 33,759 14 18,885 21,583 24,281 26,979 29,677 32,375 35,073 16 19,650 22,458 25,265 28,072 30,879 33,686 36,494 Maximum CT Depth (ft) RPSEA Project #1502-01 20
Tapered String Design Example: 1 3/4, 120 grade CT 6000 psi CT pressure, 5000 psi wellhead pressure 10 ppg fluid in CT, 8.5 ppg fluid in wellbore Margin Of Overpull = 10% of max allowable force Provides limit on thinnest wall at TD Result of Tapered String Design 10 CT Sections OD Remains constant, ID of tubing changes Thickest at surface to support CT hanging weight RPSEA Project #1502-01 21
CT Grade Tapered String (vs. Max Well Depth) RPSEA Project #1502-01 22
Pressure Drop & CT Fatigue Modeling Modeling Background & Assumptions Simulated Both a 5 & 7 Well Modeled w/10, 12, 14, & 16 ppg Drilling Fluid CT Sizes from 1 1/2 to 3 1/2 Pressure Drop Data Obtained for: Turbine mud motor PDM motor BHA Data Entered into Model RPSEA Project #1502-01 23
Example: Pressure Drop vs. CT Size Smaller Wellbores Have Significant Annular Pressure Losses with Larger CT Sizes 3500 Modeling Parameters: 5 Well 15,000 TD 10 PPG Mud 100 GPM Pump Rate 425 PSI Pressure Drop Across Bit 3000 2500 2000 1500 1000 500 0 Annular Losses (psi) CT Losses (psi) 2 3/8 2 5/8 2 7/8 3 1/4 3 1/2 CT Size (in.) Surface CT Pressure (psi) RPSEA Project #1502-01 24
Example: Fatigue Life vs. CT Size Low Trip Life for 3 1/4 + CT Makes it unattractive for this type application Modeling Parameters: 5 Well 15,000 TD 10 PPG Mud 100 GPM Pump Rate 425 psi Pressure Drop Across Bit CT Size (in.) CT Trips RPSEA Project #1502-01 25
Example: Reel Size & Weight vs. CT Size CT Outside Diameter (in) 1 1/2 1 3/4 2 2 3/8 Reel core diameter (in) 72.0 84.0 96.0 114.0 Width between flanges 96 96 126 126 Number of turns per wrap 64.0 54.9 63.0 53.1 Number of wraps 21 21 17 17 Length of CT possible 36,417 36,417 36,450 36,450 Flange Diameter (in) 138 161 168 200 Est. weight of empty reel (lb) 22,000 25,000 30,000 32,000 Estimated reel width (ft) 11.5 11.5 14.0 14.0 Estimated reel length (ft) 16.0 17.5 18.0 20.5 Estimated reel height (ft) 13.0 14.5 15.0 17.5 Total weight with dry CT (lb) 90,270 110,871 137,468 168,960 Total weight with wet CT (lb) 112,198 141,812 178,681 229,585
CT Diameter Tapered String
SYSTEM WILL INCORPORATE THESE FEATURES SSR can be pre installed on existing tree SSR is left ready for intervention vessel SSR has control umbilical for tree Redundant CT shear & reservoir isolation functions At seafloor & near surface Provisions for vessel emergencies Fast emergency disconnection, easy reengagement
SYSTEM WILL INCORPORATE THESE FEATURES No compromise in safety Personnel safety Asset protection Redundant reservoir isolation Risers on standby for callout Less than half the cost of MODU intervention
Questions? Nautilus International LLC www.nautilus int.com