Preface A Note on Notation Chapter 1 – Introduction 1.1. What is MPD? 1.2. MPD Variants, Terminology & Classification 1.3. Brief History and Overview of MPD Variants 1.3.1. General Introduction 1.3.2. Continuous Circulation 1.3.3. Surface Back Pressure MPD 1.3.4. Riserless and Dual-Gradient Drilling 1.3.5. Mud Cap Drilling 1.3.6. Managed Pressure Cementing and Completions 1.4. Main Benefits & Advantages of MPD 1.5. The Stakeholder Case for Action – Why Adopt MPD? 2. Fundamentals & Essential Background 2.1. Introduction 2.2. Hydraulics 2.2.1. Hydraulics Introduction 2.2.2. Hydrostatics 2.2.2.1. Definitions 2.2.2.2. Density – Ideal and Non-Ideal Mixing 2.2.2.3. Incompressible Fluids 2.2.2.4. Compressible Fluids 2.2.2.5. Effect of Hole Cleaning and Barite Sag on Density 2.2.2.6. Multiple Fluid Gradients & Unbalanced U-Tube Effects 2.2.3. Hydrodynamics 2.2.3.1. Pump Pressure, Frictional Pressure Loss & ECD 2.2.3.2. Hydraulics Models 2.2.3.3. Hydraulic Modeling: Calculating Frictional Pressure Losses during Circulation 2.2.3.4. Transient Effects: Surge & Swab 2.2.3.5. Transient Effects: Mud Gelation and Pump Startups 2.2.3.6. Hole Cleaning 2.2.3.7. Bit Pressure Drop 2.2.3.8. Other Hydraulic Pressure Losses 2.2.3.9. Uncertainty in Hydraulic Modeling 2.3. Rock Mechanics and the Drilling Margin 2.3.1. Drilling Margin Introduction 2.3.2. Pore Pressure 2.3.2.1. Pore Pressure Introduction 2.3.2.2. Pore Pressure Regimes 2.3.2.3. Deepwater Pore Pressure – Effect of Water Depth 2.3.2.4. Pore Pressure Indicators 2.3.2.5. Pore Pressure Evaluation and Prediction 2.3.3. Fracture Gradient 2.3.3.1 Fracture Gradient Introduction 2.3.3.2. Formation Integrity & Leak-Off Testing, Dynamic MPD Testing 2.3.3.3. Fracture Gradient Considerations 2.3.3.4. Ballooning / Losses & Gains / Wellbore Breathing 2.3.3.5. Fracture Gradient Evaluation and Prediction 2.3.4. Effect of Depletion on Pore Pressure and Fracture Gradient 2.3.5. Borehole Stability 2.3.5.1. Borehole Stability Introduction 2.3.5.2. Stress Tensor & Subsurface Stress Regimes 2.3.5.3. Subsurface Stress and Rock Failure 2.3.5.4. Near-Wellbore Stresses & Failure Orientation 2.3.5.5. Mud Weight for Borehole Stability – Avoiding Shear Failure 2.3.5.6. Mud Weight to Prevent Tensile Failure & Induced Fracturing 2.3.5.7. Wellbore Trajectory and the Drilling Margin 2.3.5.8. Obtaining Borehole Stability Modeling Input Variables 2.3.5.9. Borehole Stability Modeling Recommendations 2.3.6. Extending the Drilling Margin: Artificial Wellbore Strengthening 2.4. Well Control 2.4.1. Well Control Introduction 2.4.2. Definitions 2.4.3. Conventional Kick Detection 2.4.4. Wellbore Breathing Detection & Flowback Fingerprinting 2.4.5. Conventional Well Shut-In, SIDPP & SICP 2.4.6. MAASP/MASP & MAWP 2.4.7. Kick Intensity (KI) & Kick Tolerance (KT) 2.4.8. Casing Point Selection 2.4.9. Phase-Behavior of Gases 2.4.10. Gas Solubility 2.4.11. Conventional Well Control Methods 2.4.11.1. Driller’s Method 2.4.11.2. Wait & Weight Method 2.4.11.3. Bullheading / Annular Injection 2.4.11.4. Subsea Well Control 2.4.11.5. Riser Margin and Emergency Riser Disconnects 2.4.12. Mud Gas Separator (MGS) Sizing 2.4.12.1. Gas Separation Capacity 2.4.12.2. Maximum Allowable Internal Pressure and Gas Flow Rate 2.5. Speed of Sound 2.6. Temperature Effects 2.6.1. Introduction 2.6.2. Temperature Regimes, HPHT Classification 2.6.3. Temperature Modeling 2.6.4. Effect of Temperature on Fluid Properties 2.6.5. Effect of Temperature on Wellbore Stability and Lost Circulation 2.6.6. Effect of Temperature on MAASP and Kick Tolerance 2.6.7. Effect of Temperature during Non-Circulatory Periods / Connections 2.7. Pipe Light Conditions 2.8. Recommended Reading 3. MPD Benefits and Risks 3.1. Introduction – How MPD Changes the Game and Adds Value 3.2. Improved Safety 3.2.1. Early Kick Detection (EKD), Early Kick & Loss Detection (EKLD) 3.2.2. Improved Pressure Control and Influx Management 3.2.3. Dynamic Pore Pressure, Formation Integrity and Leak Off Testing (DPPT, DFIT, DLOT) 3.3. Well Design Optimization 3.4. NPT Avoidance 3.4.1. Lost Circulation and Wellbore Breathing Prevention and Mitigation 3.4.2. Wellbore Instability and Stuck Pipe Prevention 3.4.3. Differential Sticking and Stuck Pipe Prevention 3.4.4. Remedial Cementing Avoidance through Managed Pressure Cementing 3.4.5. Optimized Completions 3.5. Invisible Lost Time (ILT) Avoidance & ROP Enhancement 3.6. Reduced Reservoir Damage and Production Optimization 3.7. Reduced Carbon Footprint of Well Construction Operations 3.9. Risks and Drawbacks of MPD 3.10. Techno-Economical Justification of MPD 4. MPD Equipment, Software and Operational Implementation 4.1. Introduction 4.2. MPD Equipment 4.2.1. Rotating / Non-Rotating Control Devices (RCD/ACD) 4.2.1.1. Passive RCD Systems 4.2.1.2. Active RCD Systems 4.2.1.3. Active Closing Device (ACD) Systems 4.2.1.4. Hybrid RCD Systems 4.2.1.5. Integrated Pressure Management Device (PMD) 4.2.1.6. RCD Sealing Element Life 4.2.2. Chokes & Choke Manifolds 4.2.3. Flow Metering 4.2.4. Non-Return Valves (NRV) 4.2.5. Pressure Relief Valves (PRV), Pressure Relief Chokes (PRC), Pressure Control Valves (PCV) 4.2.6. Junk / Debris Catchers 4.2.7. Distribution / Buffer Manifolds 4.2.8. Piping, Hoses and Flowlines 4.2.9. Special Downhole Valves 4.2.9.1. Casing Isolation Valve (CIV) / Downhole Isolation Valve (DIV) 4.2.9.2. Drill String Valve (DSV) / Hydrostatic Control Valve (HCV) 4.2.10. Back-Pressure Pumps 4.2.11. Mud Gas Separator (MGS) 4.2.12. Riser Equipment & Configurations, Integrated Riser Joint (IRJ) 4.2.13. Downhole Measurements & Telemetry 4.2.14. Programmable Logic Controllers 4.3. MPD Operational Implementation 4.3.1. Piping and Instrumentation Diagrams (P&ID), Process Flow Diagrams (PFD) 4.3.2. MPD Certification, Commissioning and Classification 4.3.3. MPD Fingerprinting 4.3.4. MPD Rig Integration 4.3.4.1. General Considerations 4.3.4.2. Land Rigs 4.3.4.2. Offshore Rigs – Jack-Ups & Platform Rigs 4.3.4.3. Offshore Rigs – Deepwater MODUs 4.3.5. Pressure Operations Directive 4.4. MPD Software and Data-Acquisition 4.5. Recommended Reading 5. Continuous Circulation (CC) 5.1. Introduction 5.2. Unique Systems, Equipment and Methods 5.2.1. Continuous Circulation System (CCS) 5.2.2. Continuous Circulation Valves (CCV) 5.2.2.1. Eni Circulation Device (e-cdTM) 5.2.2.2. Non-Stop Driller (NSDTM) 5.2.2.3. Continuous Flow System (CFSTM) 5.2.2.4. Rotating Continuous Circulation Tool (RCCT) 5.3. Kick Detection and Well Control 5.4. Tripping 5.5. Case Histories 5.5.1. CCS 5.5.2. CCV 5.6. Recommended Reading 6. Surface Back Pressure (SBP) 6.1. Introduction 6.2. Drilling Margin Management 6.2.1. Adding Back-Pressure to Control Annulus / Bottom-Hole Pressures 6.2.2. Anchor Point Selection & Management 6.2.3. Basis of Design (BOD) 6.2.4. Dynamic Pore Pressure, Formation Integrity and Leak Off Testing (DPPT, DFIT, DLOT) 404 6.2.5. Tripping, Compensating for Swab & Surge Pressures 6.2.6. Heave Compensation 6.3. Pressure Control & Influx Management 6.3.1. Introduction 6.3.2. Early Kick & Loss Detection (EKLD) 6.3.3. Influx Management 6.3.3.1. Primary & Secondary Barrier Operations 6.3.3.2. MPD Operations Matrix 6.3.3.3. MPD Influx Management Envelope (IME) 6.3.3.4. MPD Influx Management Decision Tree (IMDT) 6.3.4. SMAASP & DMAASP 6.3.5. Mud Weight and SBP Selection using SMAASP & DMAASP 6.3.6. Kick Tolerance and Well Design / Casing Point Optimization 6.3.7. Riser Gas Handling (RGH) to Prevent Riser Gas Unloading (RGU) Events 6.3.7.1. Introduction 6.3.7.2. RGH / RGU Experimentation, Riser Gas Migration Monitoring 6.3.7.3. RGH / RGU Modeling 6.3.7.4. Gas Hydrates 6.3.7.5. IADC Riser Gas Handling Guidelines 6.3.7.6. Riser Gas Handling Equipment 6.3.7.7. Influx Management Envelope (IME) for Riser Gas Handling Events 6.3.7.8. Handling Gas-in-Riser with Back-Pressure and Dilution Control 6.4. SBP Methods and Systems 6.4.1. Manual Approach with Trapped Back-Pressure 6.4.2. Automated Approach with Trapped Back-Pressure 6.4.3. Automated Approach with Added Back-Pressure 6.5. SBP-MPD for Challenging Wells 6.5.1. (Ultra-)Deepwater Wells 6.5.2. High Pressure High Temperature (HPHT) Wells 6.5.3. Extended Reach Drilling (ERD) Wells 6.6. SBP Case Histories 6.7. Recommended Reading 7. Dual Gradient Drilling (DGD) 7.1. General Introduction 7.2. Riserless Drilling (RD) – Weighted Mud Discharge at the Seafloor 7.2.1. RD Introduction 7.2.2. RD Systems, Equipment and Operation 7.2.3. RD Case Histories Intermezzo – Road to RMR: Cuttings Transport System (CTS) 7.3. Riserless Mud Recovery (RMR) 7.3.1. RMR Introduction 7.3.2. RMR Systems and Equipment 7.3.3. RMR Operation 7.3.3. RMR Case Histories Intermezzo – Road to CML 7.4. Controlled (Annular) Mud Level (CML / CAML) 7.4.1. CML Introduction Intermezzo – ECD Management Toolbox 7.4.2. CML Systems, Equipment and Operation 7.4.3. CML Operation 7.4.4. CML Kick Detection & Well Control 7.4.4.1. CML Kick Detection Intermezzo – CMP Well Control Trials Using the CML System 7.4.4.2. CML Well Control 7.4.5. CML+SBP 7.4.6. CML Case Histories 7.5. Inactive Systems 7.5.1. Seabed Pumping 7.5.1.1. Subsea Mudlift Drilling (SMD) 7.5.1.2. DeepVision 7.5.1.3. Shell Subsea Pumping System (SSPS) 7.5.2. Riser Dilution 7.5.2.1. Dilution with Gas 7.5.2.2. Dilution with Hollow Spheres – Maurer JIP 7.5.2.3. Dilution with Light Fluid - Continuous Annular Pressure Management (CAPM) 7.5.3. Mid-Level Riser Pumping 7.5.3.1. Low Riser Return System (LRRS) 7.5.3.2. DeltaVision / Pumped Riser System (PRS) 7.5.4. Miscellaneous DGD Methods 7.5.4.1. Dual Drillstring - Reelwell 7.5.4.2. E-duct Return (EdR) 7.6. Recommended Reading 8. Mud Cap Drilling (MCD) 8.1. Introduction 8.2. MCD Subvariants 8.2.1. Floating Mud Cap Drilling (FMCD) 8.2.2. Pressurized Mud Cap Drilling (PMCD) 8.2.3. Dynamic Mud Cap Drilling (DMCD) 8.2.4. Controlled Mud Cap Drilling (CMCD) 8.2.5. Variant Selection and Comparison: FMCD vs. PMCD 8.3. Gas Migration in MCD Operations 8.4. Planning and Executing PMCD Operations 8.4.1. Planning and Preparation 8.4.2. Equipment 8.4.3. Pit layout & fluid management 8.4.4. Transitioning between MCD and Conventional or SBP-MPD Operations 8.4.5. Well control 8.4.6. Drilling 8.4.7. Tripping 8.5. PMCD Wireline and Coring Operations 8.6. Case Histories 8.6.1. FMCD Field Cases 8.6.2. PMCD & DMCD Field Cases 8.7. Recommended Reading 9. Managed Pressure Cementing (MPC), Managed Pressure Completions (MPComp), Managed Pressure Casing/Liner/Completion Running 9.1. General Introduction 9.2. Managed Pressure Cementing (MPC) 9.2.1. MPC Introduction 9.2.2. MPC with SBP 9.2.2.1. Equipment 9.2.2.2. Workflow – Planning & Execution 9.2.2.3. Casing vs. Liner MPC Considerations 9.2.2.4. Risks 9.2.3. MPC with RMR & CML 9.2.4. MPC Modeling & Control 9.2.5. MPC Case Histories 9.3. Managed Pressure Completions (MPComp) 9.4. Downhole Measurements during MPC & MP Completions 9.5. Recommended Reading 10. Miscellaneous Methods: RMD, Multi-Phase MPD, Reelwell 10.1. Introduction 10.2. RMD / RCD-Only / HSE Method 10.3. Multi-Phase MPD 10.3.1. Equipment & Preparation 10.3.2. Modeling & Simulation 10.3.3. Direct Injection vs. Concentric Injection 10.3.4. Well Control, Connections and Tripping 10.3.5. Case Histories 10.4. Reelwell Pipe-in-Pipe Technology 10.5. Recommended Reading 11. MPD Event Detection, Automation and Control 11.1. General Introduction 11.2. Introduction to Drilling and MPD Automation 11.2.1. Drivers for Automation 11.2.2. Levels of Automation (LOA) 11.2.3. Current State of Drilling Automation & MPD Automation 11.2.3.1. Drilling Automation 11.2.3.2. MPD Automation 11.2.4. Human Factors (HF) & Situational Awareness (SA) 11.3. Event Detection 11.3.1. Artificial Intelligence (AI) and Machine Learning (ML) Introduction 11.3.2. AI & ML Methods Overview 11.3.3. Simple Rule-Based Event Detection 11.3.4. AI & ML-Based Event Detection 11.3.5. AI & ML-Based MPD Risk and Reliability Assessment 11.3.6. AI & ML-Based Advisory at the Rigsite 11.4. Automated MPD Control 11.4.1. Closed-Loop vs. Open-Loop Control 11.4.2. Process and Control Variables, Disturbances 11.4.3. Manual and Automated Control 11.4.3.1. Manual Control 11.4.3.2. Two-Position On/Off Control 11.4.3.3. Proportional (P), Integral (I) and Derivative (D) Control 11.4.3.4. Model-Predictive Control (MPC) 11.4.3.5. Other Control Approaches 11.4.4. Models for Estimation and Control 11.4.4.1. Introduction 11.4.4.2. Simple ODE Control Approach 11.4.4.3. RDFM Control Approach 11.4.4.4. Control Switching: Pressure, Flow and Solubility Control 11.4.5. Automated Tripping Advisory and Control 11.4.6. Automated Heave Control 11.4.7. Automated Fluid Monitoring 11.4.8. Automated Well Control 11.5. Digital Twinning & Hybrid Modeling 11.5.1. Digital Twinning 11.5.2. Hybrid Modeling: Combining Physics-Based and Data-Driven Modeling 11.6. Recommended Reading 12. MPD Planning, Implementation and Risk Management 12.1. Well Construction Process (WCP) 12.1.1. WCP Phases and Structure 12.1.2. WCP Risk Register 12.1.3. WCP Roles and Responsibilities 12.1.4. WCP Value Creation, Erosion or Missed Opportunity 12.1.5. WCP Cost Estimating 12.1.6. WCP Key Performance Indicators (KPIs) & Benchmarking 12.1.6.1. Safety 12.1.6.2. Drilling Time & Cost 12.1.6.3. Trouble and Inefficiency Time and Cost: NPT & ILT 12.1.6.4. Production Added 12.1.6.5. Sustainability Indicators 12.1.6.6. Staffing 12.1.6.7. Performance Benchmarking 12.2. MPD Project Management 12.2.1. Introduction. 12.2.2. Project Scoping 12.2.2.1. MPD Candidate Selection 12.2.2.2. Technical Feasibility 12.2.2.3. Economic Feasibility 12.2.3. Front End Engineering & Design (FEED) 12.2.4. Implementation 12.2.7.3. Knowledge Management: After Action Review (AAR) 12.2.7.4. Management of Change (MOC) 12.3. MPD Risk Assessment 12.3.1. Introduction 12.3.2. IADC Well Classification System 12.3.3. HAZID/HAZOP 12.3.4. FMEA/FMECA 12.3.5. LOPA/SIL 12.3.6. HSE Risk Matrix 12.3.7. HSE Risk Register 12.3.7. Cause and Effect Diagram and Table 12.3.8. Bow-Tie Analysis and Diagrams 12.3.9. Fault Tree Analysis (FTA) 12.3.10 Event Tree Analysis (ETA) 12.3.11 Linkage between Risk Assessment Approaches and HSE Management System 12.4. Training & Competency Assessment 12.5. Regulatory Approval 12.6. Summary: Key Documents, Events and Success Measures 12.7. Recommended Reading 13. Future Outlook 13.1. Introduction – MPD Projected Growth 13.2. Talent Attraction, Retention & Training 13.3. Technology Maturation & Continuous Improvement 13.4. Collaborative Regulatory Environment 13.5. Managed Pressure Engineering (MPE) 13.6. Rig Integration and Standardization 13.7. Riser Gas Handling & Riser Well Control 13.8. Automation, Data-Analysis, ML & AI, Digital Twinning, Hybrid Models, Remote Operations 13.9. Data Sharing and Collaboration 13.10. Environmental Benefits 13.11. Future Applications 13.12. Conclusion Appendix A – Drift Flux Model (DFM) and Reduced Drift Flux Model (RDFM) A.1. DFM Formulation A.2. RDFM Formulation A.3. Numerical Simulation Appendix B – Hydraulics & Hole Cleaning Addendum B.1 Estimation of Pressure Losses in Annuli using the Finite Difference Method B.2. Modeling Thixotropic Fluid Behavior and Estimating Pressure Transients During Flow Initiation B.3. Modeling Cuttings Transport using Local Fluid Velocities B.3.1. Calculation of Velocity Profile in the Annulus using the Narrow Slot Approximation B.3.2. Calculation of Local Critical Velocity Appendix C – Rock Mechanics Addendum C.1. Modified Lade, Modified Wiebols-Cook and Mogi-Coulomb Criteria C.2. Physico-Chemical Effects on Wellbore Stability C.3. Rock Strength Anisotropy Effects Appendix D – Kick Tolerance Calculations D.1. KT Formula Derivation – Conventional Drilling D.2. KT Formula Derivation – SBP-MPD Appendix E - Gas Solubility Example List of Acronyms Nomenclature Variables Greek letters Subscripts & Superscripts References

Demonstrates the value in safety improvement, time and cost savings, sustainability and reduced carbon footprint that adoption of MPD brings to well construction. Delivers a fundamental collection on managed pressure drilling equipment, methods, procedures, best practices, and field cases.  Presents a balance of information that ranges from historical details and background theory to practical application Includes multiple critical chapters dealing with all major MPD variants, MPD event detection, control systems and automation, how to plan and risk MPD, where MPD fits in the well delivery process, and its future outlook.