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SUPPLEMENT Well Control for Drilling Operations – Workover & Completion for Drillers

Core Curriculum and Related Learning Objectives

Form WSP-02-DO-SU-WOC-D© Revision 0

13 February 2015

Core Curriculum and Related Learning Objectives for Drilling Operations

SUPPLEMENT: Workover & Completion for Drillers

SUPPLEMENT: Workover & Completion for Drillers Page 2 of 13 Revision 0 Last updated: 13 February 2015

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Contents 1.0 Course Overview .......................................................................................................................................................................... 3

2.0 Curriculum ............................................................................................................................................................................................................ 4

2.1 Introduction to Workover and Completions for Drilling Operations ..................................................................................................... 4

2.2 Completion and Workover Fluids .............................................................................................................................................................. 5

2.3 Well Completion and Workover Equipment ............................................................................................................................................ 6

2.4 Workover Well Control Practices and Kill Methods................................................................................................................................ 9

2.5 Complications ............................................................................................................................................................................................ 12




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1.0 Course Overview

The purpose of this course core curriculum is to identify the well control body of knowledge and set of job skills needed by drilling personnel who may be engaged in completion and workover operations. The curriculum is designed to supplement the Drilling Operations’ Driller-level course.

Acceptable Delivery Methods: Instructor-led training for the initial and repeat delivery of this Supplement is required, along with a knowledge assessment. Simulator or live well exercises are also required; however, simulator assessment is not required for this supplement.

Minimum Course Length: Eight (8) hours are required for teaching the core curriculum. Course length includes simulator exercises, but excludes the knowledge assessment time. Maximum knowledge assessment time is forty-five (45) minutes.

Course Curriculum Notes: The curriculum that follows includes four components: Sub-modules, AIM, Learning Topics, and Learning Objectives and Assessment Guidelines.

AIM: The AIM letters indicate the level of knowledge and skills required at the job level. The codes used in the AIM column are as follows:

A = Awareness of Learning Topic

I = Implementation of the Learning Topic at this job level; needs an increased level of knowledge because they may have to take action on some task related to the topic.

M = Mastery of Learning Topic at this job level; needs a full knowledge because they have to take action, perhaps unsupervised, on some task related to the topic.

Learning Topics: This section provides guidance for instructors on what the trainee should learn.

Learning Objectives and Assessment Guidelines: This section defines what trainees should be able to do at the conclusion of the training and gives guidance on the assessment process, whether theoretical or practical, by providing examples of assessment content and expectations.




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2.0 Curriculum

2.1 Introduction to Workover and Completion for Drilling Operations

Module Name: 2.1 Introduction to Workover and Completion for Drilling Operations Sub-Modules AIM Learning Topics Learning Objectives and Assessment Guidelines

The instructor will impart knowledge on: The trainee will be able to:

Introduction to Workover and Completions

A Objectives of workover and completion operations.

Describe the purpose of conducting a workover or completion (for example, initiates, improves, or restores production).

A Different workover activities and types.

Describe the different types of activities that may occur during a workover in order to accomplish the objective (for example, wellbore activities: acidizing, fracking, sand clean out and removal, recompleting in new reservoir, scale, or paraffin removal, control water, sidetrack or deepen, plug and abandon; equipment activities: removal or addition of tools, mechanical repair of worn or damaged equipment, pump change, clean perforation, or skin damage).

A Completion activities and types.

Describe the different types of activities that may occur during a completion in order to accomplish the objective (for example, perforating, fracking, acidizing, flowing, reservoir test, openhole vs. cased-hole completion techniques).

Differences Between Drilling Operations and Workover / Completion Operations

M Differences in workover and drilling activities that could result in a loss of containment.

Describe the primary differences between workover/completions and drilling (for example, fluid differences, downhole equipment (plugs, packers, flow-through valves), shut-in considerations, formation pressures, depleted reservoirs, damage to tubing/casing, open hydrocarbon reservoir, fluid column characteristics).




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2.2 Completion and Workover Fluids

Module Name: 2.2 Completion and Workover Fluids Sub-Modules AIM Learning Topics Learning Objectives and Assessment Guidelines


Friction

I Friction loss in the different well sections.

Describe frictional losses in different well sections (slimhole, tight tubing/casing clearances). Explain how downhole tools/equipment affect friction and fluid flow.

I Reverse Circulation method. Describe the friction losses in the circulating system and the resulting well pressures when reverse circulating.

I Effect of friction on bottomhole pressure.

Explain the effect on bottomhole pressure when circulating with tools, equipment.

Completion and Workover Fluids

I Types of fluid. Describe the different types of brine and completion fluids (water-based, oil-based mud/synthetic based mud).

M Purpose of fluid. Describe the purpose and characteristics of fluids that make them suitable for workover and completions (for example, compatibility with the zone; pressure control).

I Purpose of packer fluid. Describe the purpose of packer fluid in a completion.

Brine Characteristics

M Solids carrying capacity.

Explain solids carrying capacity of brines with viscosifiers and without viscosifiers (for example, brines without viscosifiers have poor solids transport capacity, lower than that of drilling fluids).

M Gas migration in brines. Explain gas migration in brines (for example, gas migrates at a much higher rate in brine than in viscous drilling fluid).

A Density and composition. Explain how various salt compositions affect the density range (for example, sodium chloride brine solutions can be weighted up to 10.0 ppg before saturation is reached.

A Temperature and pressure. Describe the effect of temperature and pressure on brine density.

A Crystallization. Explain the causes of brine density loss and the effect on the well.




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Module Name: 2.2 Completion and Workover Fluids Sub-Modules AIM Learning Topics Learning Objectives and Assessment Guidelines


A Saturation. Describe brine saturation and the limitations of different salts used.

2.3 Well Completion and Workover Equipment

Module Name: 2.3 Well Completion and Workover Equipment Sub-Modules AIM Learning Topics Learning Objectives and Assessment Guidelines


Barrier Management M

Surface equipment. Show how the wellhead, tubing hanger, and Christmas tree act as a barrier to flow.

BOP or Christmas tree removal. Identify the steps and barriers used to isolate the well prior to removing a BOP or Christmas tree.

Christmas Tree (Valves, Tees, Gauge Panels, Tree Caps, Chokes, Surface Safety Valves)

M Christmas tree components.

Identify primary components of a Christmas tree and their purpose (for example, tree-cap; why use of a secondary master valve is important). Choose the appropriate locations of the equipment.

I Pressure testing.

Identify pressure-sealing components and explain when these components should be tested as a barrier (for example, explain why a wing valve may need to hold pressure during a Bullhead).

I Pressure limitations. Identify the pressure rating, mechanical limits, and limits based on the condition of equipment. Summarize how equipment may be degraded after service exposure.

A Metallurgical composition. Recall that different trim types have different service limits (for example, AA is a trim type).




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I Ring seals and O-ring seals.

Describe the type of seal created by: 1. a ring gasket between connections, and 2. O-ring seals between other components (for example, ring gasket seals provide a metal-to-metal seal and require compression; O-ring seals do not require compression and typically have shorter service life).

Tubing Hangers and Wellhead Bowls

I

Tubing hangers and wellhead bowls.

Explain the purpose of a tubing hanger and wellhead bowl (for example, access to the annulus for pressure monitoring, chemical injection, barrier to flow for the annulus and possible barrier to the tubing).

Testing tubing hanger seals. Identify test ports and voids that are tested to verify a tubing hanger seal.

Types of tubing hanger and wellhead bowl annulus seals.

Name types of tubing hanger and wellhead bowl annulus seals, and identify the correct uses of each (for example, elastomer seals; metal to metal seals).

Control lines, electric submersible pump cables and other components penetrating tubing hangers.

Indicate where tubing hangers must hold pressure (including around this external equipment).

Subsurface Equipment

I Downhole equipment recognition. Match downhole equipment to the correct name.

M Pressure isolation.

Identify various downhole components that provide pressure isolation (packers, subsurface safety valve (SSSV), plugs, completion equipment, retrievable bridge plug (RBP), surface controlled subsurface safety valve (SCSSSV), wireline plugs, tubing, etc.). Explain how subsurface equipment provide pressure isolation (for example, SCSSSV retains tubing flow when the wellhead is damaged by shutting a flapper).

I Testing of downhole equipment. Give examples of how to test downhole equipment to confirm it is a competent barrier. Identify limitations of downhole tests.




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A Working pressure. Identify factors that affect working pressure ratings and limitations of subsurface equipment (for example, corrosion, wear, degradation, and burst rating).

A Subsurface complications.

Describe where hazards may be present with downhole equipment (for example, trapped pressure under retrievable plugs; variation of thread types and correct matching of threads; correct rental equipment selection to match rig and completion equipment; testing limitations). Identify how to mitigate hazards.

Removable Wellhead Equipment

I

Definition of removable wellhead equipment. Define removable wellhead equipment.

Removable wellhead equipment. Explain what valve removal plugs, two-way checks, and backpressure valves are and where they are located on a tree or wellhead.

Applications. State reasons for using removable wellhead equipment; state when it could be used versus should not be utilized.

Lubricator tools. Describe the key components of a lubricator and how a lubricator may be used to pull or retrieve removable wellhead equipment.

Safe removal of wellhead equipment. Identify when trapped pressure may be present prior to removal of wellhead equipment and demonstrate the ability to check for trapped pressure.




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2.4 Workover Well Control Practices and Kill Methods

Module Name: 2.4 Workover Well Control Practices and Kill Methods Sub-Modules AIM Learning Topics Learning Objectives and Assessment Guidelines


Practices I

Maintaining a fluid column. Identify reasons why keeping the hole full in workover or completion may not always be an option.

Hole fill and fluid loss.

Choose the correct action to take if filling the hole does not maintain enough hydrostatic (for example, losses of 10 bbl/hr are acceptable but any losses above 60 bbl/hr on a certain job may require a lost circulation material pill).

Tracking fluid loss. Explain the importance of tracking losses when unable to maintain fluid level.

Shut-in procedures for tree components. Demonstrate the ability to shut in the tree at the proper location (for example, using the crown valve to isolate wireline lubricator).

Shut-in procedures. Choose correct procedures for shutting in on downhole equipment and completions (for example, kill stand, blind shear ram, drop the string).

Bullheading

I

Reasons for using the Bullheading method.

Identify conditions when Bullheading may be preferred to circulation (for example, toxic gas present; unable to handle influx at surface; potential to exceed equipment limitations if circulated to surface).

Basic principles. Describe the basic principles of Bullheading (for example, push the formation fluid back into the formation).

Effect of gas migration. Explain how the rate of gas migration affects the chosen Bullhead rate (for example, circulating rates must overcome the rate of migration).

A Formation limitations.

Describe how a Bullheading operation can fracture the formation (for example, hydrostatic pressure plus surface pressure can exceed formation strength and thereby fracture the formation).




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I Mechanical limitations.

Determine the weakest mechanical link in a Bullheading operation Summarize how to mitigate a mechanical issue (for example, place pressure on the annulus to assist in burst).

I Calculating Bullhead volume. Calculate the volume needed to Bullhead and kill the well.

I Determining if Bullheading was a success. Explain the difference between trapped pressure post Bullhead and a well in which hydrostatic is not sufficient to kill the well.

M Flow paths and barriers. Identify the flow paths of kill fluid during a Bullhead operation and the barriers restricting flow elsewhere.

A Detecting initial injection (break over) and Kill Mud Weight (KMW) hitting the perforations.

Distinguish between rising surface pressure and injection. Demonstrate the ability to respond to lack of injection and KMW hitting the perforations.

Volumetric Techniques and Lubricate (Lube) and Bleed

I

Applying the Volumetric technique to a workover kill.

Explain the main differences between the Volumetric technique during drilling phase and during workover (for example, fluids in the well, gas migration rates, well configuration, potential leak paths).

Applying the Lube and Bleed technique to a workover kill.

Explain the main differences between a Lube and Bleed technique during drilling phase and during workover (for example, fluids in the well, well configuration, reducing pressure to a level for Bullheading).




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Constant Bottomhole Pressure Methods (Forward and Reverse Circulation)

I

Applying Normal Circulation method to a workover kill.

Explain the main differences between a normal circulation kill technique during drilling phase and during workover (for example, potential for greater friction, uncertainty of a clear flow path, integrity of circulating path, different wellbore fluids).

Applying Reverse Circulation method to a workover kill.

Explain the main differences between a normal circulation kill technique during drilling phase and a reverse circulating technique during workover (for example, position of choke in the circulating path, startup procedure, tubing string friction, different fluids in the well, integrity of circulating path).




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2.5 Complications

Module Name: 2.5 Complications Sub-Modules AIM Learning Topics Learning Objectives and Assessment Guidelines


Workover Complications I

Trapped pressure. Explain the occurrence of trapped pressure in a workover operation and give examples of where this may occur.

Workover issues resulting from mechanically degraded equipment.

Explain and give examples of common failed barriers and mechanical parts occurring during workover. Explain and give examples of how to mitigate failed barriers and mechanical parts (for example, a hole in the tubing that leads to formation communication between the tubing/casing annulus; seals or packer leak; poor cement condition or placement).

Accuracy of well records.

Explain the importance of accurate well records to the workover operation (development and execution of the plan); List potential data issues with well records and how these inaccuracies can affect the workover plan and execution (for example, lost sinker bars; wireline or other tools left in the hole and never reported; incorrect depth correlation; perforations out of zone or in the wrong place; bridge plugs or cement dumped in the wrong place; debris; inaccurate old surveys).

Importance of proven barriers.

Explain the importance of proving a barrier has pressure-retaining capability (for example, never assume a well barrier has integrity until tested; well conditions or data accuracy can mislead rig crews into believing they have barrier integrity; having contingency plans if the barriers installed are not holding pressure or fail during a workover; understanding of maximum pressure that could be trapped below a shallow plug if a lower plug fails).




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Module Name: 2.5 Complications Sub-Modules AIM Learning Topics Learning Objectives and Assessment Guidelines


A

Hydrates – their formation and hazards.

Indicate where hydrates may form, how pressure and temperature influence hydrate formation, and the hazards they present (for example, trapped pressure, equipment blockage).

Paraffin / Asphaltenes.

Describe where paraffin / asphaltenes are found and the problems they can cause (for example, commonly found in older oil producing wells; prevent wireline tools from being run in the hole; plug up valves and surface equipment).

Scale. Explain the problems scale can cause and the potential for contamination and other associated risk.

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