Formulas and Calculations for Drilling, Production, and Workover, 4th Edition

Formulas and Calculations for Drilling, Production, and Workover, All the Formulas You Need to Solve Drilling and Production Problems, Fourth Edition provides a convenient reference for oil field workers who do not use formulas and calculations on a regular basis, aiming to help reduce the volume of materials they must carry to the rig floor or job site. View more >

• Features a new chapter focused on cementing
• Includes on-the-job answers and formulas for today’s hydraulic fracturing methods
• Provides extra utility with an online basic equation calculator for 24/7 problem-solving access
• Covers topics such as drilling fluids, pressure control, engineering calculations, and air and gas calculations

Petroleum Engineers, Production Engineers, Drilling Engineers, Completion Engineers, Operations Engineers, Drilling Managers, Operations Managers, Project Production Engineers, and Graduate-level Petroleum Engineering Students

• Preface
• Chapter One: Basic Equations
  • Abstract
  • 1.1 Terminology
  • 1.2 Mud Weight MW (lb/ft.3), Mud Weight MW (ppg), and Specific Gravity (SG) [USCS/British]
  • 1.3 Density ρ (kg/m3 or kg/liter), Mud Weight MW (N/m3 or N/liter), and Specific Gravity (SG) [SI-Metric]
  • 1.4 Hydrostatic Pressure (P) and (p) [USCS/British]
  • 1.5 Hydrostatic Pressure (P) and (p) [SI-Metric]
  • 1.6 Pressure Gradient ∇ (psi/ft.), G (ppg) [USCS/British]
  • 1.7 Pressure Gradient G (SG) [SI-Metric]
  • 1.8 Mud Pump Output q (bbl/stk) and Q (gpm) [USCS/British]
  • 1.9 Hydraulic Horsepower
  • 1.10 Estimated Weight of Drill Collars in Air
  • 1.11 Open Hole and Tubular Capacity and Displacement Formulas
  • 1.12 Amount of Cuttings Drilled per Foot of Hole Drilled
  • 1.13 Annular Velocity (AV)
  • 1.14 Pump Output Required in GPM for a Desired Annular Velocity, ft./min
  • 1.15 Pump Pressure/Pump Stroke Relationship (the Roughneck’s Formula)
  • 1.16 Buoyancy Factor (BF)
  • 1.17 Formation Temperature (Tf)
  • 1.18 Temperature Conversion Formulas
• Chapter Two: Rig Calculations
  • Abstract
  • 2.1 Accumulator Capacity
  • 2.2 Slug Calculations
  • 2.3 Bulk Density of Cutting Using the Mud Balance
  • 2.4 Drill String Design
  • 2.5 Depth of a Washout
  • 2.6 Stuck Pipe Calculations
  • 2.7 Calculations Required for Placing Spotting Pills in an Open Hole Annulus
• Chapter Three: Pressure Control: Kill Sheets and Related Calculations
  • Abstract
  • 3.1 Normal Kill Sheet
  • 3.2 Calculations for the Pressure Chart
  • 3.3 Formation Pressure Tests
  • 3.4 Fracture Gradient
  • 3.5 Kick Tolerance
  • 3.6 Kick Analysis
  • 3.7 Gas Cut Mud Weight Measurement Calculations
  • 3.8 Gas Migration in a Shut-In Well
  • 3.9 Hydrostatic Pressure Decrease at TD Caused by Gas-Cut Mud
  • 3.10 Maximum Pressures When Circulating Out a Kick (Moore Equations)
  • 3.11 Gas Flow into the Wellbore
  • 3.12 Pressure Analysis
  • 3.13 Stripping/Snubbing Calculations
  • 3.14 Subsea Considerations
  • 3.15 Workover Operations
  • 3.16 Controlling Gas Migration
  • 3.17 Gas Lubrication
  • 3.18 Annular Stripping Procedures
  • 3.19 Barite Plug
• Chapter Four: Drilling Fluids
  • Abstract
  • 4.1 Mud Density Increase and Volume Change
  • 4.2 Mud Weight Reduction with Base Liquid Dilution
  • 4.3 Mixing Fluids of Different Densities
  • 4.4 Oil-Based Mud Calculations
  • 4.5 Solids Analysis
  • 4.6 Solids Fractions (Barite Treated Muds)
  • 4.7 Dilution of Mud System
  • 4.8 Evaluation of Hydrocyclones
  • 4.9 Evaluation of Centrifuge
• Chapter Five: Cementing Calculations
  • Abstract
  • 5.1 Cement Additive Calculations
  • 5.2 Water Requirements
  • 5.3 Field Cement Additive Calculations
  • 5.4 Weighted Cement Calculations
  • 5.5 Calculations for the Number of Sacks of Cement Required
  • 5.6 Calculations for the Number of Feet to Be Cemented
  • 5.7 Setting a Balanced Cement Plug
  • 5.8 Differential Hydrostatic Pressure Between Cement in the Annulus and Mud Inside the Casing
  • 5.9 Hydraulicing Casing
• Chapter Six: Well Hydraulics
  • Abstract
  • 6.1 System Pressure Losses
  • 6.2 Equivalent Circulating “Density” ECD (ppg) [USCS/British]
  • 6.3 Surge and Swab Pressure Loss
  • 6.4 Critical Velocity and Pump Rate
  • 6.5 Equivalent Spherical Diameter for Drilled Cuttings Size Used in Slip Velocity Equations
  • 6.6 Slip Velocity of Cuttings in the Annulus
  • 6.7 Carrying Capacity Index
  • 6.8 Pressure Required to Break Circulation
  • 6.9 Initial Gel Strength Guidelines for Top Hole Drilling in High Angle Wells (After Zamora)
  • 6.10 Bit Nozzle Selection—Optimized Hydraulics
  • 6.11 Hydraulic Analysis
  • 6.12 Minimum Flowrate for PDC Bits
  • 6.13 Critical RPM: RPM to Avoid Due to Excessive Vibration (Accurate to Approximately 15%)
• Chapter Seven: Drilling and Completion Calculations
  • Abstract
  • 7.1 Control Drilling: Maximum Drilling Rate (MDR) When Drilling Large Diameter Holes (14¾ in. and Larger) in ft./h
  • 7.2 Mud Effects on Rate of Penetration
  • 7.3 Cuttings Concentration % by Volume
  • 7.4 “d ” Exponent
  • 7.5 Cost per Foot
  • 7.6 Rig Loads
  • 7.7 Ton-Mile (TM) Calculations
  • 7.8 Hydrostatic Pressure Decrease When Pulling Pipe Out of the Hole
  • 7.9 Loss of Overbalance Due to Falling Mud Level
  • 7.10 Lost Circulation
  • 7.11 Core Analysis Techniques
  • 7.12 Temperature Correction for Brines
  • 7.13 Tubing Stretch
  • 7.14 Directional Drilling Calculations
• Chapter Eight: Air and Gas Calculations
  • Abstract
  • 8.1 Static Gas Column
  • 8.2 Direct Circulation: Flow Up the Annulus (from Annulus Bottomhole to Exit)
  • 8.3 Direct Circulation: Flow Down the Inside of the Drill Pipe (from the Bottom of the Inside of the Drill String to the Injection at the Top of the Drill String)
  • 8.4 Reverse Circulation: Flow Up the Inside of Tubing String
  • 8.5 Reverse Circulation: Flow Down the Annulus
  • 8.6 Reverse Circulation: Adjusting for Reservoir Pressure
• Appendix A
  • A.1 Tank Capacity Determinations
• Appendix B
• Appendix C: Average Annual Atmospheric Conditions