Stuck Pipe Prevention & Recovery - Aberdeen

Toolpushers

Drillers and assistant drillers

Drilling supervisors

Office-based well engineers

Classify the three overall stuck pipe mechanisms—geometry, pack-off, and differential sticking—based on their defining characteristics.

Analyze the five prevalent geometry-related sticking problems by describing their causes, identifying early indicators, and evaluating preventive measures.

Explain the mechanism of pack-off, its contributing factors, warning signs, and strategies for prevention.

Analyze how pulling out of hole (POOH) in a wellbore with cutting beds can result in pack-off events, and identify contributing conditions.

Evaluate differential sticking by identifying its causes and indicators and assessing strategies to prevent its occurrence.

Calculate the differential sticking force using input variables such as mud weight, formation pressure, and contact area.

Determine the most likely sticking mechanism in a given operational scenario using the ‘Stuck Pipe Worksheet’ and justify your conclusion.

Explain the concept of friction and apply the relevant formula to calculate friction force.

Compare static and dynamic friction and interpret their significance in downhole operations.

Evaluate the impact of friction factors—including mud type, hole condition, and well design—on torque and drag behavior.

Describe hookload and interpret how it is measured in various operational contexts.

Analyze the relationship between tensile load, allowable load, and Maximum Over Pull (MOP) and how they influence equipment limits.

Evaluate how mechanical limitations—such as pipe strength, torque, and hoisting capacity—affect allowable hookload.

Analyze the interaction between torque and drag and evaluate how tool joint limitations constrain torque capacity.

Evaluate the effects of combined torque and pull on mechanical limits and operational decision-making.

Interpret combined torque and pull graphs to determine safe operating envelopes.

Classify different types of buckling and explain their triggering conditions.

Assess the operational consequences of buckling and recommend strategies to mitigate it.

Explain the concept of Equivalent Circulating Density (ECD), analyze its role during drilling operations, and calculate ECD using representative data.

Evaluate key parameters influencing ECD and justify their relevance for wellbore pressure management.

Categorize the key mud properties that influence well control and stuck-pipe prevention, and describe their operational significance.

Evaluate the importance of maintaining mud weight within the safe window and predict the consequences of deviation.

Compare common rheology models and differentiate between laminar and turbulent flow regimes.

Explain the concept of viscosity and demonstrate its measurement using rig-site instruments.

Demonstrate the use of a Fann viscometer to obtain viscosity and gel-strength readings, and interpret their relevance for drilling performance.

Analyze gel-strength characteristics and evaluate their impact on hole cleaning and suspension.

Differentiate shear-thinning from thixotropy and assess their relevance to drilling hydraulics and cuttings transport.

Analyze fluid-loss mechanisms and filter-cake formation, and relate their effects to wellbore stability and differential sticking risk.

Classify solids into high-gravity and low-gravity types, and provide examples of each, including other common drilling solids.

Differentiate between cuttings, fines, and cavings based on their origin and shape.

Analyze the formation of fines and evaluate their impact on drilling fluid properties and solids control efficiency.

Interpret the relationship between hole size, rate of penetration (ROP), and cuttings volume, and assess its implications for solids handling.

Identify key components of solids control equipment and describe their function within the drilling fluid system.

Describe how in-situ rock stress is represented using the three orthogonal principal stresses, and interpret their relevance for wellbore stability.

Analyze naturally fractured formations by identifying their causes and indicators, and evaluate strategies to mitigate drilling risks.

Analyze how drilling induces hoop stress and assess how appropriate mud weight selection can prevent wellbore instability.

Evaluate the interaction between water-based mud (WBM) and shale formations, focusing on pore pressure transmission and wellbore instability.

Analyze shale swelling mechanisms in response to WBM systems, and evaluate the associated causes, symptoms, and mitigation strategies.

Assess the impact of drill string vibration on borehole integrity, including mechanisms leading to cavings and overgauge holes.

Analyze the forces acting on drill cuttings, describe their directional components, and evaluate which parameters can be adjusted to influence these forces.

Evaluate hole cleaning challenges in low-angle wellbore sections and propose effective operational solutions.

Assess hole cleaning limitations in intermediate-angle sections and recommend strategies to enhance cuttings transport.

Evaluate hole cleaning performance in high-angle wellbores and enlarged hole sections, and design strategies to optimize cuttings transport.

Analyze how hole enlargements create cuttings traps and assess the associated risk of stuck pipe during tripping operations.

Describe the principles of Crew Resource Management and its role in improving operational safety and team performance.

Define situational awareness and demonstrate techniques to build and maintain it during well operations.

Evaluate the importance of decision-making under pressure and identify key factors that influence decision quality in unexpected or hazardous situations.

Explain the core functions of leadership in well operations and analyze what a team leader must prioritize to ensure task completion.

Differentiate between one-way and two-way communication and identify four key areas for improving communication effectiveness.

Define the concept of a team and outline a structured, team-based approach to executing operational tasks.

Identify two key performance factors, define acute stress, and assess the operational impact of fatigue on individual and team performance.

Describe the function of a jar and classify the three main types: hydraulic, mechanical, and hydraulic-mechanical.

Compare the operating principles of hydraulic and mechanical jars.

Analyze the limitations of hydraulic jars, focusing on the role of detent load in their performance.

Define jar pump open force, calculate it using relevant inputs, and describe the concept of jar internal friction.

Evaluate common causes for jar misfiring and recommend appropriate troubleshooting actions.

Describe the function and operating principle of a jar accelerator and its role in increasing jarring effectiveness.

Explain the physical principles behind the forces generated by a drilling jar, including the application of Newton’s Second Law and basic kinematic relationships.

Identify and explain the key data required to plan and execute effective jarring operations.

Calculate the required hookloads for cocking the jar and for executing upward and downward jarring operations using operational data.

Describe the initial response steps for addressing geometry-related sticking.

Describe the initial response actions for resolving pack-off or bridge-related sticking.

Describe the appropriate first response when differential sticking is suspected.

Apply classroom knowledge and skills to perform operational tasks in a simulated environment, demonstrating readiness for real-world scenarios.

Identify key Bottom Hole Assembly (BHA) design criteria that reduce the risk of stuck pipe and enhance pipe recovery.

Evaluate key factors influencing jar placement in the BHA and justify their operational importance.

Evaluate best practices for making connections and identify potential risks associated with connections at different hole inclinations.

Explain and evaluate best practices for tripping and back reaming to minimize operational risks.

Explain the role of trip monitoring in identifying early signs of wellbore instability and preventing stuck pipe incidents.

Calculate the free point location using data from a stretch test.

Describe the procedure for using a wireline free point indicator in stuck pipe evaluation.

Evaluate the benefits and risks of reducing hydrostatic head as a method to release differentially stuck pipe.

Describe how spotting pills can assist in freeing differentially stuck pipe and outline key considerations.

Explain the procedures for backing off pipe both with and without the use of a string shot.

Identify two common pipe cutting methods used in stuck pipe recovery.