IADC C DUAL GRAD DIENT DRILLIN NG WORKSHOP Madrid, Spain M n April 7, 2014 A DGD SSystem Attrib butes PRE‐B BOP POST ‐ BO OP DGD System Mudline P Pumping (Riserlless) Technollogy Name RMR R™ Max Lift Drilling (prreviously SMD) CMP™ CA APM™ EC‐Drill™ EC‐Drill+ Technology prom moting company(ie es) AGR Enh hanced Drilliing C Chevron / GE / Paciific Drilling / AGR AGR Enhancced Drilling Tran nsocean AG GR Enhanced Drilling AGR Enhanced A Drilling Y N N N N N Y Y Y Y Y N (Riser Injection) Y w Seabed (Below Injeection) Y Seabed Pumping Dilution Shallow Hazard M Mitigation Well Construction n Top hole mud & C Cuttings Recovery Ultra‐Deepwater tight pressure margins Abnormal pressures Closed system with RCD? N/A A N/A A N Y Y Y N Normal/Subnorm mal pressures N/A A N N Y Y Y Reduces # of casing strings MECHANICAL Controlled Mud Level Y Y Y N Y N Y Y N Y PRE‐BOP DGD System Mudline Pumping (Riserless) Technology Name RMR™ Top Fluid, Static conditions Top Fluid, Dynamic conditions Well Fluid Pump Location Pump Type Fluid Entry Point Power source Electrical power to pump (and purpose) Riser Modifications POST ‐ BOP Seabed Pumping Max Lift Drilling (previously SMD) Seawater density Seawater density Seawater density Seawater density Higher than conventional density mud Higher than conventional density mud CMP™ EC‐Drill™ EC‐Drill+ Riser full / atmospheric pressure Inert gas atmospheric pressure Inert gas or air Inert gas or air Conventional mud density Higher than conventional density mud Not Applicable Riser (booster line) Electrical Surface mud pumps Electrical Electrical Case Dependent Not Applicable Case Dependent Case Dependent One Modified Riser Joint Two Modified Riser Joints + Riser Annular (gas handler) In‐line above LMRP Head Wellhead Positive Disp. Head Near seabed Riser/Choke line Electrical Surface seawater pump ~100 hp (for HPU’s) Mud return and seawater power lines Controlled Mud Level Suspended or riser fixed 1200ft below sea level Head Riser Near Seabed N/A CAPM™ Seawater, base oil, or Inert gas Diluted well fluid atmospheric pressure Inert gas or air Diluted well fluid Conventional or Higher than higher than conventional density conventional density mud mud Near Seabed/mid riser Case Dependent Dilution One Modified Riser Joint Modified Choke Line Not Applicable Upper Riser Flow Control Equipment Suspended or riser fixed Mid water Head/PD Riser PRE‐BOP DGD System Mudline Pumping (Riserless) Technology Name RMR™ Max Lift Drilling (previously SMD) Standard N (Optional) Standard Surface mud treatment Closed System (RCD in place)? Rotating Control Device location POST ‐ BOP Seabed Pumping Y (desired, but optional) Dilution CMP™ CAPM™ EC‐Drill™ EC‐Drill+ Standard No (Closed Annular BOP circulating Kick out) Centrifuges Standard Y N Standard No (Closed BOP circulating Kick out) At wellhead (if used) Near mudline None N (optional) 5000’ 1200 gpm 14 Y (optional) 10,000’ 1800 gpm 18.5 Y (optional) 5,000‘/All 1600 gpm Depth Dependent Max flow rate @ max WD & MW 1200gpm / 12.5 ppg in 5000’ 850 gpm/18.5 ppg in 10,000’ WD Depth Dependent Minimum Water Depth (functional/practical/economical) 100’ 3,000’ 3000’ N N 2,5" N N None N N/A Y Y Y Y 2.5" Y Y Flow Arresting Valve in BHA? Maximum Water Depth Max flow rate at max WD (gpm) Maximum mud density (ppg) OPERATIONAL Variable interface level Variable top fluid density Cuttings size limit WELL CONTROL Specialized well control required? Is full riser margin restorable? Controlled Mud Level Within Upper Riser Flow Control Equipment Y (optional) 10,000’ 3,000 gpm 18.5 Drilling Fluid: 1,500 gpm / 12‐18 ppg Returns: 3,000 gpm / 9 to 14 ppg 3,000’ 0’ (Below Sea Bed Injection) None None Y (optional) All 1600 gpm 18.5 Y (optional) All 1600 gpm 18.5 Depth Dependent Depth Dependent 300’ 600’ N Y None Y N 2.5" Y N 2.5" Y N N Y Y (case PRE‐BOP DGD System Mudline Pumping (Riserless) Technology Name RMR™ POST ‐ BOP Seabed Pumping Max Lift Drilling (previously SMD) Dilution CMP™ CAPM™ (Riser Injection) Y (Below Sea Bed Injection) WC method (Driller’s, Bullhead, Engineer’s) Kick detection method Direct measurement SIDPP N/A Pump Speed/power N/A N/A All, plus volumetric and dynamic kill All Pump speed if circulating, flow while static if not Pump Speed/power &/or flow meter Control System with delta flow measurement Y, multiple methods N Y N All Closed system, Secure Software & Coriolis Meters WC fluids through pump (y/n) N/A Y Y Y, multiple methods Y (Drillers method) N (Modified Method) Not Applicable How high gas fraction is pumped N/A Slower pump rate 10% (free gas) max Not Applicable N N (ECD compensation) < 2 bbls <2 bbls Use c/k lines for WC (y/n) Y Friction losses seen by well Estimated smallest detectable <2 bbls Y (Drillers method) N (modified method) 1 bbl Controlled Mud Level EC‐Drill™ EC‐Drill+ dependent) N All All Volume control (including riser level) and accurate flow rate out Y Volume control (including riser level) and accurate flow rate out N Y Y (part way) + SS Coke N Not affected in WC events Liquids only Not affected in WC events N (ECD compensation) N (ECD compensation) < 2 bbls < 2 bbls PRE‐BOP DGD System Mudline Pumping (Riserless) Technology Name RMR™ Max Lift Drilling (previously SMD) N/A N/A influx Estimated max kill rate Max circulation rate limitation MATURITY OF SYSTEM DGD Operations and WC Procedures fully developed? DGD Ops/WC schools and simulator fully developed? Number of people trained to date Highest level of equipment testing: (none/component in shop/flow loop/field test components/field test system/well drilled/multiple wells drilled) Estimated first test system deployment date Estimated first commercial deployment date TRAINING PROGRAM MATURITY POST ‐ BOP Seabed Pumping Dilution Controlled Mud Level CMP™ CAPM™ EC‐Drill™ EC‐Drill+ (demonstrated) >10 bpm Case dependent Gas handling Gas handling Method Dependent Friction losses / Gas Handling N/A Depends on procedure Case dependent Depends on procedure Y Y > 20 Y Y Y Y Y Y Y Y Y Y ~ 400 < 10 < 10 Dilution principle – flow loop test Upper riser package – Dry Run on DEN & similar package in use (MPD application from a DP Drillship) Flow Stop Valve – Flow loop and open water tested ~30 < 10 3 DW wells drilled Need SS choke Qualification – other Components same as EC Drill 200 wells drilled Well drilled in 2001. Subsea testing of commercial system ongoing Feb, 2014. Need Pump Qualification Done 2004 10/2001 2013 2015 Done DW 2012 2015 Commercial 2014 2015 2015 Commercial 2016 PRE‐BOP DGD System Mudline Pumping (Riserless) Technology Name RMR™ Basic operations/well control Advanced well control Regulatory/Industry Endorsement Equipment classification/ certification Peer review POST ‐ BOP Seabed Pumping Dilution Controlled Mud Level Max Lift Drilling (previously SMD) CMP™ CAPM™ EC‐Drill™ EC‐Drill+ 5 days (basic + RMR specific) 8 days 3 days introduction, 2 days specific course and 3 day written and simulator course 3 days RMR training + 6 days specific course 5 days general + specific courses N/A 5 days. Written and simulator testing Case specific Written and simulator testing None 3‐5 days Simulator Case‐specific Test Commercial Norsok Z‐015 / DNV Regulatory –endorsed rd 3 party review IADC Accreditation received for Basic DGD Operations and Advanced Well Control Subsea option of WellCAP. Certificate will be required ABS / DNV Regulatory –endorsed rd 3 party review Design reviews, rig owner, Operators Case‐specific Learning Meetings with BSEE Review with Industry SMEs DNV‐OS‐E101 Drilling facility DNV DVR for Equipment Installation will require review dependent on MODU (ABS / DNV) HAZID/HAZOP Operators and DNV Industry Accepted SME – Blade Energy Services Learning Meetings with BSEE 3rd. party review, PETIL + drlg.contr. Learning Meetings with BSEE rd 3 . party review, + drlg.contr. DNV‐OS‐ E101 Drilling facility DNV‐OS‐ E101 Drilling facility DNV per DNV‐ RP‐A203 Qualification of new technology Y PRE‐BOP DGD System Mudline Pumping (Riserless) Technology Name RMR™ Training media E‐Learning / Classroom / Computer POST ‐ BOP Seabed Pumping Max Lift Drilling (previously SMD) Classroom simulator, animations, physical model Sources: RMR: Roger Stave, AGR Enhanced Drilling MaxLift Drilling: Ken Smith, Chevron CMP: John Cohen, AGR Enhanced Drilling CAPM: Iain Sneddon, Transocean EC‐Drill: Roger Stave, AGR Enhanced Drilling EC‐Drill+: Børre Fossli, AGR Enhanced Drilling CMP™ Classroom, animation, simulator, real equipment Dilution CAPM™ Classroom, animations, simulator Controlled Mud Level EC‐Drill™ EC‐Drill+ and HAZID/HAZOP Classroom, simulator, Small‐scale model, real equipment Classroom, simulator, Small‐scale model, real equipment
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