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
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
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
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
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
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
Surface BOP StackCasing String,
Hanger & Well Head
Casing
Head
Casing
Hanger
Casing
StringRotating 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.
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
Basic Concepts and Definitions
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.
Properties and Requirements of Well Barriers
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
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
Properties and Requirements of Well Barriers
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
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
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)
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
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
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
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
Properties and Requirements of Well Barriers
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
Properties and Requirements of Well Barriers
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
Properties and Requirements of Well Barriers
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
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 certifiedWellCAP Instructor
He can can issue IADC certificates.
International Association of Drilling Contractors (IADC)
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
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