well integrity level 2 - sales _6360615_01

Shadi NEKAVAND WL InTouch

Well Integrity & Pressure Safety Management

Marketing & Sales

212/8/20132

Oil & Gas Industry in the headlines

Source : Shell Process Safety

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

Sensitive Environment

HTHP

H2S, CO2

Gas

Why do we need a step change?

Well blow outs happened in the past

Lives can be lost

Environmental damage

Prosecution & fines

Reputation loss

Licence to operate impacted

Colombia - 2005 Algeria - 2006 Oman -2001

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

Schlumberger Well Integrity Project

Jun 2010 Feb 2011 Jul 2011 2014Sep 2011 Jan 2012April 2010

WI committee OFS WI St. Segments WI St. Trainers Trainings Cert . Trainings Macando

Jan 2013

Client drafting WI

standard

Client WI

implementations

Well Integrity Key Elements

EquipmentProcessPeople

Training

Competency

Certification

Q-Stop

Job / Well Design

SOPs

Risk Analysis

Risk Management

Management of Change

Design

Procurement

Traceability

Certification

Inspection & Maintenance

Repair & Recertification

812/8/2013

Agenda

Certifications & Competency Trainings - People

Well Integrity Certifications

Level 1 - SLB-QHSE-S022 - Permanent

Level 2 - WL-HSE-Well Integrity 2 years

Level 3 - WL-HSE-Well Integrity - Permanent

WHE Certifications

Level 1 - Pressure Safety - Permanent

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-Pressure - Permanent

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

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



Training

Competency

Certification

Q-Stop

Job / Well Design

SOPs

Risk Analysis

Risk Management


Design

Procurement

Traceability

Certification



Well Integrity 2013 - Process

2012 Process Introduction

Revised Standards & POM

Well Control Contingency Tools

Deepwater WHE Process

WHE/WI Safety Stand Down

2013 Process Integration

WHE Standard Work Instructions

Bridging Documents Major clients

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

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?

Process & Job Planning well control contingencies

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

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

To be released stranded armor and

hydrate formation action diagrams

Leak above WL Valve

and below grease

head

Cut cable and

Close Master

valve

Client

Decision

Risk Management Well control contingencies

Operating Customer Wellheads Risk Analysis

Operating Customer Barriers We interact with the customer wellhead under

varying levels of supervision and withoutsufficient training on the equipment in use

Potential Risk: In the event of a well control incident without

customer presence, SLB would face potentialliability and media scrutiny

4

1 2 3 4 5

-1 -1 -2 -3 -4 -5

-2 -2 -4 -6 -8 -10

-3 -3 -6 -9 -12 -15

-4 -4 -8 -12 -16 -20

-5 -5 -10 -15 -20 -25

LIKELIHOOD

S

E

V

E

R

I

T

Y

Risk Factors

Client presence

Fluid type

Historical activity

Valve type

Wellhead pressure

Location type

Corrosive environment

Hydrate potential

~15 identified. 6 were outside of Green Zone Risk

Area Gmkt Location Client Potential

LAM MCA MXSR PEMEX-S -16

LAM MCA MXNR PEMEX-N -15

MEA EMG AERM ADCO-NEB -12

EAF ANG Malongo Chevron -8

LAM MCA MXER PEMEX-E -8

Multi-Segment Operations

Internal Risk Assessment

Well Intervention

IPM

Testing



Training

Competency

Certification

Q-Stop

Job / Well Design

SOPs

Risk Analysis

Risk Management


Design

Procurement

Traceability

Certification



Well Integrity 2013 - Equipment

2012 Equipment Systems

WHE Maintenance Traceability

PTB Audit Completed

Surface Cutter Development

Hunting (2nd supplier) Qualification

2013 Equipment Compliance

WHE Critical Seals Traceability

5-yr Major Certification

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


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

Surface BOP StackCasing String,

Hanger & Well Head

Casing

Head

Casing

Hanger

Casing

StringRotating Control

Device (RCD) for MPD Slick Line Lubricator


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.

Several barrier elements may be installed in the well and available to contain pressure or to

prevent flow

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


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

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

Primary Well Barrier is

fluid column which is in

direct contact with the

outflow source.

It controls or overcomes

the formation pressure

Logging in cased hole

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

Examples of Primary Well Barrier Primary Well Barrier Primary Well Barrier Primary Well Barrier for Drilling, Production and Well Intervention:

Drilling the Well Drilling the Well Drilling the Well Drilling the Well Producing the WellProducing the WellProducing the WellProducing the Well

Well Intervention Well Intervention Well Intervention 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.



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

Secondary Barrier: Redundant Barrier, outside the primary barrier, to be closed as last resort

Drilling Well Drilling Well Drilling Well Drilling Well Well ProductionWell ProductionWell ProductionWell Production


For all well operations having potential

uncontrolled flowflowflowflow ofofofof formationformationformationformation fluidsfluidsfluidsfluids 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.

Examples of Secondary Well Barrier

Envelopes for Drilling, Production and Well

Intervention

Well Intervention Well Intervention Well Intervention Well Intervention


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


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

e. The Use 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)


If Annular BOP fails, one Pipe

Ram would be closed

(Additional Barrier element)


Ultimate Resource would be

cut/drop pipe by closing

Shear-Seal Rams

(Last / Ultimate Barrier)



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

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

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

DHSV


Properties and Requirements of Well Barriers NORSOK10

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.

The WBEAC for each Barrier Element is established by means of 11 Features, as follows:

A. Description

B. Function

C. Design, Construction & Selection

D. Initial Validation

E. Use

F. Monitoring

G. Impairment

H. Maintenance

I. Competency and Training

J. Risk Assessment

K. Certification Requirement

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


Tested

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

Monitored

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

Restored

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


A Barrier Element (Envelope) is considered as such ONLY if it can be

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


To promote the two barrier philosophy, SLB Wireline will:

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

Identify the secondary barrier mechanism to be activated should the primary

barrier fail

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 Well Integrity Standard

37

Back up Slides

Wireline Stack Requirements

38

12/8/2013

Wireline Pressure Control Equipment

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

Lack of Barriers Exemption Process

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 operationsWireline 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.

Wireline Well Integrity & Well Barriers

The Wayfroward

To enhance Well Integrity implementation, SLB Wireline will:

Ensure well barrier integrity through maintenance and traceability

Strengthen our well integrity competency and manage customer expectations in regards

to well control

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

45

Back up Slides

WL Barrier Requirements Shear & Seal

Single RAM

Shear &

Seal Valve

Single RAM

Shear &

Seal Valve

Single RAM

Shear &

Seal Valve

Single RAM

Shear &

Seal Valve

46

12/8/2013

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

Appendix


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 certifiedWellCAP Instructor

He can can issue IADC certificates.


Certifications

WellCAP

Drilling and workover activities.

Accredited training providers must meet criteria for training materials, facilities, instructor qualifications,

simulation exercises, test administration & course management.

WellCAP Plus

Advanced well control training program for decision makers (e.G., Drilling superintendents, operations

engineers, rig superintendents, and rig managers)

RIG PASS

Accredits health, safety & environmental (HSE) and underbalanced operations (UBO) orientation

programs.

Safety fundamentals relevant to new rig employees.

Drilling Industry Training Accreditation System

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

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 well control critical positions during well intervention operations

Two levels are available;

Level 1 Service Equipment Operators

Level 2 Well Intervention Supervisors

Introductory Rotary Drilling Well Control 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