Well Integrity Level 2 - Sales _6360615_01

Well Integrity & Pressure Safety Management Marketing & Sales

Shadi NEKAVAND – WL InTouch

Oil & Gas Industry in the headlines

2 12/8/2013

Source : Shell Process Safety

2

What was the Major root causes of Macando ? The Major Root Cause(s) of Macondo Incident: of Barrier Installation of Barrier Verification & Testing of following a proper Well Control Procedure to decide When to use the (Ultimate defense) - Reaction Time

Are we

in SLB to handle an event like this?

Well profiles are getting more complicated Risk Factors ■

Deepwater Operation

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Sensitive Environment

■

HTHP

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H2S, CO2

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Gas

Why do we need a step change? ■

Well blow outs happened in the past

Oman -2001

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Lives can be lost

■

Environmental damage

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Prosecution & fines

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Reputation loss

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Licence to operate impacted

Colombia - 2005

Algeria - 2006

Schlumberger Well Integrity Project April 2010

Jun 2010

Feb 2011

Macando

WI committee

OFS WI St.

Jul 2011

Sep 2011

Segments WI St. Trainers Trainings

Jan 2012 Cert . Trainings

Jan 2013

Client WI Client drafting WI implementations standard


Develop a clear, Schlumberger-wide well integrity standard
Engage internal & external expertise to identify requirements for all well barriers
Identify & implement improvements to Standards, SOPs
Develope component traceability
Improve maintenance processes
Provide competency requirements for our personnel

2014

Well Integrity Key Elements

People

Process

Equipment

•

Training

•

Job / Well Design

•

Design

•

Competency

•

SOPs

•

Procurement

•

Certification

•

Risk Analysis

•

Traceability

•

Q-Stop

•

Risk Management

•

Certification

•

Management of Change

•

Inspection & Maintenance

•

Repair & Recertification

Certifications & Competency Trainings - People Agenda Well Integrity Certifications

WHE Certifications




Level 1 - SLB-QHSE-S022 - Permanent




Level 1 - Pressure Safety - Permanent




Level 2 - WL-HSE-Well Integrity – 2 years








Level 2 - WL-HSE-Low Pressure – 2 years Level 2 - WL-HSE-WHE 10 K – 2 years Level 2 - WL-HSE-High Pressure – 2 years Level 2 - WL-HSE- WHE Management – 2 years Level 2 - WL-HSE-WHE Maintenance – Permanent




Level 3 - WL-HSE-Well Integrity - Permanent




Level 3 - WL-HSE-Pressure - Permanent

**The list of WLH currently approved WHE & WI Trainers is maintained in InTouch Content ID 3266237** 8 12/8/2013

Industry Recognized Well Control Certifications ■

International Association of Drilling Contractors (IADC) ― ―

Distance learning - Computer-based Online Training Instructor-led class - Accredited Instructor & Training Center
Internal SLB – KLC (Scott Carson)
External – Accredited Training Providers

■

International Well Control Forum (IWFC ) ―

Instructor-led class - Accredited Instructor & Training Center
IWCF Accredited Centers

■

Energy Resources Conservation Board (ERCB) –Canada Only ―

Alberta Energy and Utilities Board (AEUB)

―

Distance learning - Computer-based Online Training Instructor-led class

―

Well Integrity Key Elements

People

Process

Equipment

•

Training

•

Job / Well Design

•

Design

•

Competency

•

SOPs

•

Procurement

•

Certification

•

Risk Analysis

•

Traceability

•

Q-Stop

•

Risk Management

•

Certification

•

Management of Change

•

Inspection & Maintenance

•

Repair & Recertification

Well Integrity 2013 - Process 2012 Process Introduction Revised Standards & POM

2013 Process Integration

Well Control Contingency Tools

WHE Standard Work Instructions

Deepwater WHE Process

Bridging Documents – Major clients

WHE/WI Safety Stand Down

Planning & Engagement rollout New Well Control Action Diagrams Arctic WHE Process

■

2013 integrates well integrity into our SD process ― ―

WHE Standard Work Instruction development and release Systematize client engagement
Bridging documents for major clients well barrier policies
Job risk and contingency planning
New well control action diagrams (hydrates, stranded armor)

―

Arctic WHE process release as POM appendix

Process & Job Planning – well control contingencies ■

When Should you do agree & discuss with the customer on Contingency Planning ?

■

Who is responsible to operate the barriers?

■

Are all secondary barriers able to cut the cable?

■

Will the cable fall below the secondary Barrier if parted by cable cutter sub or at the surface?

Risk Management– Well control contingencies ■

Used during planning phase to develop actions and responsibilities in the event of barrier failure

■

Highlights the potential well control risks associated with Wireline operations

Failure of Primary barrier (Grease Lost Seal)

Continue Operation

Risk Management– Well control contingencies ■

Used during planning phase to develop actions and responsibilities in the event of barrier failure

■

Highlights the potential well control risks associated with Wireline operations

Leak above WL Valve and below grease head

Cut cable and Close Master valve

Client Decision

To be released– stranded armor and hydrate formation action diagrams

Operating Customer Wellheads – Risk Analysis 1

2

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-2

-3

-4

-5

-2

-4

-6

-8

-10

-3

-6

-9

-12

-15

-4

-8

-12

-16

-20

-5

-10

-15

-20

-25

Operating Customer Barriers ■

We interact with the customer wellhead under varying levels of supervision and without sufficient training on the equipment in use

Potential Risk: ■

In the event of a well control incident without customer presence, SLB would face potential liability and media scrutiny

-1 S -2 E V E -3 R I -4 T Y -5

~15 identified. 6 were outside of Green Zone Area Gmkt Location Client LAM MCA MXSR PEMEX-S LAM MCA MXNR PEMEX-N MEA EMG AERM ADCO-NEB EAF ANG Malongo Chevron LAM MCA MXER PEMEX-E 4

Risk Potential -16 -15 -12 -8 -8

3 4 LIKELIHOOD

5

Risk Factors Client presence ■ Fluid type ■ Historical activity ■ Valve type ■

Wellhead pressure ■ Location type ■ Corrosive environment ■ Hydrate potential ■

Multi-Segment Operations ■

Internal Risk Assessment ―

Well Intervention

―

IPM

―

Testing

Well Integrity Key Elements

People

Process

Equipment

•

Training

•

Job / Well Design

•

Design

•

Competency

•

SOPs

•

Procurement

•

Certification

•

Risk Analysis

•

Traceability

•

Q-Stop

•

Risk Management

•

Certification

•

Management of Change

•

Inspection & Maintenance

•

Repair & Recertification

Well Integrity 2013 - Equipment 2012 Equipment Systems WHE Maintenance Traceability

2013 Equipment Compliance

PTB Audit Completed

WHE Critical Seals Traceability

Surface Cutter Development

5-yr Major Certification

Hunting (2nd supplier) Qualification

PTB Roadmap Implementation 3rd Party Approval Process

■

2013 drives compliance and traceability ― ― ― ― ―

Critical seals tracking as part of barcoding project 5-yr Major roadmap including internal certifications Monthly compliance tracking of WHE assets Pressure test bay roadmap release with RWP Detailed 3rd party supplier approval process

Basic Concepts and Definitions


What is Well Integrity? The Condition and Quality of the well structure achieved through the application of technical, operational and organizational solutions, such as the use of competent pressure seals, to reduce the risk of uncontrolled release of formation fluids into another formation, to the surface, or to the environment.


How the Well Integrity is established? By implementing and maintaining well barriers to prevent uncontrolled release of fluids from the formation while performing well operations or while the well is inactive or abandoned

Basic Concepts and Definitions


What is a Well Barrier Element? Any device or element (such as fluid column, casing, BOPs) that alone or in combination with other elements is capable of containing well pressure and preventing uncontrolled flow of fluids or gases from the formation, into another formation, or to the surface or environment Casing Head

Casing Hanger

Casing String

Casing String, Hanger & Well Head

Surface BOP Stack

Rotating Control Device (RCD) for MPD

Slick Line Lubricator

Basic Concepts and Definitions


What is a Well Barrier Envelope ? The combination of barrier elements (such as casing, BOP, well head, mud column, etc.) which working together, form an envelope that prevents uncontrolled flow of fluids or gases from the formation into another formation or to the surface or the environment. Components of barrier envelope: • Last casing set in the well • Cement behind casing, • Formation below casing shoe, • Casing hanger, • Well head assembly, • BOP stack installed at surface.

Basic Concepts and Definitions Several barrier elements may be installed in the well and available to contain pressure or to prevent flow

But they will only serve as a containing barrier when they are interlinked to form a barrier envelope that blocks all possible leaking paths for pressure and flow

If one Barrier Element fails, the whole Barrier Envelope also fails

Properties and Requirements of Well Barriers


What is a Primary Well Barrier Envelope? Element or combination of Barrier Elements in direct (Primary) contact with the potential outflow source, i.e. the elements that “see” pressure during well operations

Conventional drilling

Logging in cased hole

Primary Well Barrier is fluid column which is in direct contact with the outflow source.

Primary Well Barrier is formed by those elements which are in direct contact with pressure in the well: • cemented casing • well head assembly • pressured lubricator • wire line valves

It controls or overcomes the formation pressure

Properties and Requirements of Well Barriers Examples of Primary Well Barrier for Drilling, Production and Well Intervention: Primary Barrier consists of all elements that are in direct contact with formation pressure and prevent flow during well operations. They can be: • • • • •

Drilling or Completion Fluid Column Production Casing or Tubing Well Head Assembly & Valves Casing or Tubing Hangers Lubricator and Pressure Head, etc.

Well Intervention

Drilling the Well

Producing the Well

Properties and Requirements of Well Barriers


What is a Secondary Well Barrier Envelope? Element or combination of Elements defined as the ULTIMATE defense should any of the Primary Barrier Elements fails. It is the LAST and ULTIMATE barrier envelope providing well Integrity to be activated. It is not necessarily barrier number two in a sequence

Properties and Requirements of Well Barriers Secondary Barrier: Redundant Barrier, outside the primary barrier, to be closed as last resort Well Intervention

Examples of Secondary Well Barrier Envelopes for Drilling, Production and Well Intervention For all well operations having potential uncontrolled flow of formation fluids to the surface, a second (external) barrier shall be defined and installed to be activated as the Last Resort for containment of formation pressure and flow. Drilling Well

Well Production

Basic Concepts and Definitions


What is a Well Control ?

The Well Control can be seen as all actions conducted to restore the Primary Well Barrier and to recover the well integrity lost by the activation of well barrier envelopes Well is controlled (static) Formation pressure is contained by the Primary Barrier (fluid column)

When the primary barrier in wellbore is lost The hydrostatic column of fluid is insufficient and formation pressure is traveling up the well bore.

The Secondary Barrier Envelope (production casing, casing hanger, well head, and BOP ) is activated to prevent uncontrolled flow to the surface or to the environment

Properties and Requirements of Well Barriers


What is an Additional (Intermediate) Well Barrier Element? An Alternative Barrier element to be activated when Primary Barrier is Lost,prior to activating the Secondary (Ultimate Barrier)

2. Well Barriers – Definitions and Principles

Properties Requirements of Well Barriers e. The Useand of Barriers in Well Control Operations

Primary Well Barrier intact Fluid acting as Primary Barrier

Primary Barrier is Lost The first remedy would be to install Safety Valve on String and close the Annular BOP (Additional Barrier)

Primary Barrier is Lost If Annular BOP fails, one Pipe Ram would be closed (Additional Barrier element)

Primary Barrier is Lost Ultimate Resource would be cut/drop pipe by closing Shear-Seal Rams (Last / Ultimate Barrier)

Properties and Requirements of Well Barriers


What is a Common Well Barrier Element? A Barrier Element that simultaneously is part of the Primary and the Secondary Well Barrier Envelopes If the common element fails, both barriers will also fail, Primary & Secondary Barriers are not independent

Example : The Master Valve installed in the base of Christmas Tree is a Common Well Barrier Element It is in direct contact with the pressured fluid in the well (PRIMARY BARRIER) and Simultaneously it forms part of the surface equipment that ultimately may contain flow and pressure (SECONDARY BARRIER) Adding more valves on top of well head will only add redundancy to the Master Valve

Properties and Requirements of Well Barriers

For a producer well, the Master Valve is part of the Secondary Barrier and the DHSV part of the Primary Barrier. No common barrier element exits in this case

DHSV

For an abandoned well, the cemented casing, and plug set above the zone form the Primary Barrier while the DHSV is part of the Secondary Barrier. No common barrier element is present

Properties and Requirements of Well Barriers – NORSOK10

Properties and Requirements of Well Barriers “WBAC” or “Well Barrier Element Acceptance Criteria” is the collection of all organizational, technical, and operational requirements and guidelines that need to be fulfilled by a given element to qualify as a well barrier, irrespective of type of activity and operation. When Barrier Elements are provided by SLB, they must comply with the Acceptance Criteria established by the Segment responsible for their design, construction, installation or maintenance The “WBEAC” for each Barrier Element is established by means of 11 “Features”, as follows: A. Description

G. Impairment

B. Function

H. Maintenance

C. Design, Construction & Selection

I. Competency and Training

D. Initial Validation

J. Risk Assessment

E. Use

K. Certification Requirement

F. Monitoring

Properties and Requirements of Well Barriers
A Barrier Element (Envelope) is considered as such ONLY if it can be

Tested

Monitored

Restored

• By applying the “Well Barrier Element Acceptance Criteria” (WBEAC) defined by the Segment Responsible for the installation and maintenance, to verify its integrity

• By direct observation, to establish its condition and working status at all times

• By fixing or replacing the lost barrier when it fails during well operations

Properties and Requirements of Well Barriers Well Activities and Operations SHOULD STOP when: •

Having a weakened, failed / lost well barrier element or well barrier envelope

•

Hydrocarbon gas level in the air exceeds the specified limit applicable or defined

•

There is a HIGH probability of exceeding allowable operating limits of well control equipment or other critical equipment

Apply Q-Stop whenever the ongoing operation is considered unsafe or the level of risk is high or unacceptable

Wireline Well Integrity Standard To promote the two barrier philosophy, SLB Wireline will: ■

Ensure that a primary barrier is available above/in the well

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Identify the secondary barrier mechanism to be activated should the primary barrier fail

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Include a risk assessment and contingency plan for any potential well control situations that may have increased risk as a result of wireline operations

Wireline Stack Requirements

Back up Slides

37

Wireline Pressure Control Equipment

38 12/8/2013

Lack of Barriers Exemption Process

When there is a lack of barriers (ONE BARRIER ONLY ): • A risk analysis and mitigation (HARC), and • An exemption raised and approved (at Segment HQ level) prior to the commencement of the job

When there are NO BARRIERS and the well is capable of discharging hydrocarbons or fluids to the surface or the external environment or if the flow potential of the well is uncertain: • The job in the well cannot be performed • No Segment level exemptions are allowed • Schlumberger Limited level approval required

Wireline Well Integrity & Well Barriers The following situations are acceptable to have fewer than two barriers: No Exemption 1. Operations prior to surface casing installation. Surface casing is the first casing installed on a well for pressure containment. It is set within competent formations and allows the installation of BOPs prior to drilling into potentially hydrocarbon bearing and/or pressure formations

2.

Air filled hole operations Wireline logging in air filled holes with no secondary barrier installed is only allowed under the following conditions: • Only in known land development fields. • Wells classified as No Flow Conditions. • Gas monitors are required at wellsite to ensure Gas concentration around the wellhead is below the level specified by the local regulation or customer.

3.

Fully cased well under the following conditions: • •

Wells are fully cased and have no communication to the formation (i.e. un-perforated and bottom seal/plug tested to customer satisfaction) Customer to agree that these wells are not capable of discharging hydrocarbons or fluids to the surface.

The Wayfroward

To enhance Well Integrity implementation, SLB Wireline will: ■

Ensure well barrier integrity through maintenance and traceability

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Strengthen our well integrity competency and manage customer expectations in regards to well control

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Include job planning for all planned and contingency operations in our service delivery process

Clients Requirement

Frequently Asked Question by the client ■ ■ ■

BOP Closure Time (30 sec ) - API 16 D IADC , IWCF Cable cutting Option – Shear & Seal

Risk Management– Cable Cutting Procedure

■

Contingency plan must include a cable shearing procedure to allow cable removal from sealing secondary barrier elements

WL Barrier Requirements – Shear & Seal

Back up Slides

45

Single RAM Shear & Seal Valve

Single RAM Shear & Seal Valve

Single RAM Single RAM Shear & Shear & Seal Valve Seal Valve

Wireline Pressure Control Equipment The shear and seal rams \must be positioned below the regular WL Valve and as close as possible to the Wellhead to ensure that the sheared cable will fall below the secondary barrier

46 12/8/2013

Appendix

International Association of Drilling Contractors (IADC) ■

Accreditation for an organization by IADC require assessment of ; ― ― ― ― ― ―

■

Training Policy and Procedures Document Identification of Job Positions & defining competencies Training Resources to support the process Assessment System Records System Quality Assessments

An Instructor can apply to be accredited for one or more certs , requires to ; ― ― ― ―

Pass online course & exams IADC requires info about the Training Facility at which instructor organizes the trainings Scott Carson at KLC is IADC certified WellCAP Instructor He can can issue IADC certificates.

International Association of Drilling Contractors (IADC) ■

Certifications ―

WellCAP®



―

WellCAP Plus®


―




Provides training providers accreditation for their custom designed courses and assures that similar courses meet the same minimum standards for design and delivery of training.

Competence Assurance



―

Accredits health, safety & environmental (HSE) and underbalanced operations (UBO) orientation programs. Safety fundamentals relevant to new rig employees.

Drilling Industry Training Accreditation System


―

Advanced well control training program for decision makers (e.G., Drilling superintendents, operations engineers, rig superintendents, and rig managers)

RIG PASS®


―

Drilling and workover activities. Accredited training providers must meet criteria for training materials, facilities, instructor qualifications, simulation exercises, test administration & course management.

Designed to assure that in-house competence programs meet accepted practices for developing and ensuring the skills of personnel. Companies accredited must demonstrate a commitment to have a competent work force through

Ballast Control and Stability



For providers of marine stability training & operated in conjunction with nautical institute, For ballast control operator, barge supervisor, and offshore installation manager licenses.

International Well Control Forum (IWFC ) ■

Certifications ―

Well Intervention Pressure Control



―

Introductory Rotary Drilling Well Control




―

well control critical positions during well intervention operations Two levels are available; – Level 1 – Service Equipment Operators – Level 2 – Well Intervention Supervisors

formal well control training for the first time. Surface BOP operations or Combined Surface and Subsea operations. Programme Content – Primary well control, causes of kicks, normal and abnormal pressures, gas cutting, lost circulation, kicks as a result of surface initiated actions. – Kicks while drilling:- early warning signs, positive kick signs, kicks while tripping. – Shut in procedures. – Well control methods. – Kill sheet exercises. – Well control management

Rotary Drilling Well Control



well control critical positions on drilling installations and onshore roles either Surface BOP operations or Combined Surface and Subsea operations.

Alberta Energy and Utilities Board ■

Alberta Energy and Utilities Board / Energy Resources Conservation Board is an independent agency regulating the safe, responsible, and efficient development of Alberta's energy resources: oil, natural gas, oil sands, coal, and pipelines ―

Well Control Certification Requirement
Well Site Supervisor –

The Well Site Supervisor shall be certified in either Well Service Blowout Prevention or Second Line Supervisors Well Control.


Rig Manager and Driller –

In accordance with existing drilling and servicing regulations, only the driller is required to have valid well control certification. The driller may have either a First Line Supervisors Blowout Prevention or a Well Service Blowout Prevention Certificate.


Coiled Tubing Operators –

The coiled tubing operator will NOT require well control certification,

–

A sub-committee of the Drilling and Completions Committee (DACC) was recently formed by coiled tubing operators with the purpose of developing operating guidelines which may include minimum well control certification.


Wireline* * could not find any requirement for Wireline was listed in the website