Shelburne Basin Venture Exploration Drilling Project ... · PDF file6.2.1.2 BOP Intervention...

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Controlled Document

Shelburne Basin Venture Exploration Drilling Project, Canada

Source Control Contingency Plan / Well Containment Plan

Project Shelburne Basin Venture Exploration Drilling Project

Document Title Source Control Contingency Plan/Well Containment Plan

Document Number EP20156205983

DCAF Control ID Number N/A

Document Revision 03A

Document Status FINAL-Redacted

Document Type Emergency Preparedness and Response Plans, Drills and Tests

Owner / Author Lake Johnson (Shell) /Andrew Woltje (Trendsetter)

Issue Date 2016-12-12

Expiry Date None

ECCN EAR 99

Security Classification Unrestricted

Disclosure

Revision History shown on next page

EP201506205983 - 2 - Unrestricted

Revision History

REVISION STATUS

Rev. Date Description Originator Reviewer

01R 2015-04-06 Draft for Review Lake Johnson R.Scherpenseel/

Lake Johnson

02R 2015-06-09 Draft for Review Deepak Gala

Ben Martell/ Greg Krauss/

R.Scherpenseel/ Deepak Gala

03R 2015-09-28 Draft for Approval Lake Johnson R.Scherpenseel/ Steve Burman

03A 2015-10-16 Issued for Use Lake Johnson R.Scherpenseel/ Steve Burman

04A 2016-12-06

No change to redacted version, reissued to align with restricted

version.

Lexy Dalton B. Martell/ S. Burman

Signatures for this revision

Date Role DCAF Authority Role

Name Signature or electronic reference (email)

15/10/2015 Originator - Lake Johnson Approval e-mail

on file

15/10/2015 Reviewer TA2 Roger van Noort Approval e-mail

on file

10/12/2016 Reviewer TA2 Ben Martell

10/12/2016 Approver TA1 Steve Burman

Keywords

Source Control Contingency Plan/Well Containment Plan

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P&T – Projects & Technology Proprietary Information: This document contains proprietary information and may not be partly or wholly reproduced without prior written permission from Shell Projects & Technology


Dispersant, capping, relief well, debris, logistics


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TABLE OF CONTENTS 1.0 PURPOSE AND HIERARCHY OF DOCUMENTS ................................................... 6

2.0 INTRODUCTION AND SCOPE ........................................................................... 8

3.0 REGULATORY ROADMAP ................................................................................. 9 3.1 References ................................................................................................ 9

4.0 SHELBURNE BASIN OVERVIEW ....................................................................... 10 4.1 Exploratory Drilling ................................................................................. 10 4.2 Drilling Roles and Responsibilities ............................................................. 11

4.2.1 Shell Canada Limited (Shell) ......................................................... 11 4.2.2 Drilling Contractor (Stena Drilling Limited) ..................................... 11

5.0 SHELL INCIDENT MANAGEMENT TEAM (IMT) .................................................. 12 5.1 Response Planning Assumptions ............................................................... 12 5.2 Shell Incident Command System ............................................................... 12

5.2.1 Key IMT Decisions Affecting Source Control Operations ................. 14

6.0 SOURCE CONTROL OPERATIONS ................................................................... 19 6.1 Source Control Branch ............................................................................. 20

6.1.1 Simultaneous Operations (SIMOPS) .............................................. 20 6.2 Capping and Subsea Intervention Group ................................................... 20

6.2.1 Site Assessment/Debris Removal Task Force .................................. 22 6.2.1.1 Site Survey and Assessment .......................................................... 22 6.2.1.2 BOP Intervention ......................................................................... 25 6.2.1.3 Debris Clearance ........................................................................ 31 6.2.2 Subsea Dispersant Task Force (TF) ................................................ 36 6.2.3 Capping Stack Task Force ............................................................ 41 6.2.4 Relief Well Task Force ................................................................. 47 6.2.5 Well Control and Blowout Modelling Task Force ............................ 50

7.0 SOURCE CONTROL ORGANIZATIONAL CAPABILITY DEVELOPMENT ................ 52 7.1 Source Control Training ........................................................................... 52 7.2 Drill and Exercise Plan ............................................................................. 52

8.0 SOURCE CONTROL LOGISTICS PLAN .............................................................. 53 8.1 Source Control Logistics Concept of Operations (CONOPS) ........................ 55

8.1.1 Logistics Organization ................................................................. 55 8.1.2 Freight Forwarder ........................................................................ 55

8.2 Source Control Equipment and Mobilization (General Guidelines) ............... 57 8.2.1 Transportation Requirements ........................................................ 57 8.2.2 Subsea Well Intervention System (SWIS) Mobilization .................... 60 8.2.3 OSRL Subsea Incident Response Toolkit Movements ........................ 60 8.2.4 Procurement Unit......................................................................... 70


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8.3 Source Control Mobilization Points ........................................................... 83 8.3.1 Aviation ..................................................................................... 83 8.3.2 Marine ....................................................................................... 85 8.3.3 Land Transportation Companies ................................................... 86

APPENDIX .............................................................................................................. 87 Acronyms ....................................................................................................... 87


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1.0 PURPOSE AND HIERARCHY OF DOCUMENTS

This Source Control Contingency Plan (SCCP) is a supporting plan to the Shelburne Basin Venture Exploration Drilling Project Emergency Response Plan (ERP) and an operational guide for Royal Dutch Shell (RDS) employees and third party contractors responding to a critical well control incident. It is a modular umbrella document (see Figure 1) and contains a variety of links to electronic documentation inside and outside RDS, designed to make it as easy as possible for responders to find the information they need without being required to read large amounts of information. It is not intended as a stand-alone print document.

Fig. 1 ERP- Document Hierarchy

The documents subordinate to and linked from this plan (SCCP) are described as follows:

• Relief Well Plan: this is a well-specific plan or plans intended as guidance in planning and executing one or more relief wells as required.

o Execution by: Relief Well Unit under the Well Control Group

o Where is the document? Stored in Process Safety SharePoint and linked from this document in Section 6.2.4

• Dispersant Plan: this gives specific and general guidance in planning subsea dispersant operations.

Emergency Response Plan

Source Control Contingency Plan

Relief Well Contingency Plan

Subsea Dispersant Plan

Capping Procedure

Various OSRL/Trendsetter

Supporting documents

Logistics Method Statement/Survey

Oil Spill Response Plan (OSRP) Medical ERP


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https://eu001-sp.shell.com/sites/AAAAA9494/Subsea%20Source%20Control%20Site/Source%20Control%20Library/Nova%20Scotia%20Source%20Control%20Plan/Shelburne%20basin%20capping%20procedure.docx


o Execution by: Subsea Dispersant Unit under the Capping and Subsea Deployment

Group

o Where is the document? Stored in Process Safety SharePoint and linked from this document in Section 6.2.2

• Capping Plan: this gives specific and general guidance specific to the capping stack mission (mobilization, deployment, installation, demobilization)

o Execution by: Capping Stack Unit under the Capping and Subsea Deployment Group

o Where is the document? Stored in Process Safety SharePoint and linked here and in Section 6.2.3

• Various Oil Spill Response Limited (OSRL)/Trendsetter Supporting Documents: these are a variety of documents generated by the equipment manufacturer (Trendsetter) or owner (OSRL) that give equipment specifications, instructions for use, mobilization advice, maintenance procedures, engineering assumptions, etc.

o Execution by: most Units under the Source Control Branch

o Where are the documents? Stored in the external OSRL Library and linked from this document throughout

• Logistics Method Statement/Survey: this is a document generated by a freight forwarding contractor that offers more specific instructions for the mobilization of Source Control equipment.

o Execution by: Source Control Branch, Logistics Section and Freight Forwarder contractor

o Where is the document? Stored in the Process Safety SharePoint and linked both from this document here and in Section 8.2.2 and from the Capping Procedure.


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https://eu001-sp.shell.com/sites/AAAAA9494/Subsea%20Source%20Control%20Site/Source%20Control%20Library/Nova%20Scotia%20Source%20Control%20Plan/Method%20Statement%20Norway%20-%2015K%20Capping%20OSRL%20Stack%20Full%20Sea%20Deployment.pdf


2.0 INTRODUCTION AND SCOPE

As Operator of the Shelburne Basin Venture, Shell Canada Limited’s (Shell) top priority is to protect our people, environment, assets and reputation. The aim of this Plan is to coordinate and organize an effective and efficient response to a low-probability/high consequence well control incident while managing risks.

The scope of this plan is Source Control Operations, i.e., recovery from a blowout including capping (and related operations) and relief wells. It does not include:

• activities performed prior to the blowout (i.e., well design, hazard mapping, kick mitigation, subsurface design, BOP reliability, etc.)

• BOP operation performed by the rig in an attempt to stop the blowout, as this effort is assumed to have failed and the rig moved off-station

• flowback operations from an installed capping stack that would be necessary if the cap could not be shut-in due to well integrity concerns.


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3.0 REGULATORY ROADMAP

Throughout the offshore industry, regulatory requirements are being adopted to enhance subsea well control capabilities and improve safety. At the forefront of this changing regulatory environment (and as a result of a multi-year study of well control and intervention practices following the Macondo blowout in the Gulf of Mexico in 2010), the American Petroleum Institute (API) published a Recommended Practice for Subsea Capping Stacks (RP 17W) in July 2014. The Canada-Nova Scotia Offshore Petroleum Board (CNSOPB) has historically required operators to implement specific well control measures (e.g., use of BOPs and development of relief well plans). More recently, Operations Authorizations (OAs) require access to subsea well intervention equipment, specifically identifying access to capping stack systems as a means to mechanically regain well control. These intervention requirements have not yet been integrated into a CNSOPB standard or guideline that is applicable to the offshore industry. Shell meets this enhanced operating requirement by participating in the OSRL consortium, which includes the OSRL Subsea Well Intervention Service (SWIS). Although the regulations governing the installation and use of these intervention systems may be enhanced in the future, regional collaboration currently affords operators preparedness and improved readiness for a low probability, unlikely, yet high consequence event.

3.1 References

The SCCP has incorporated the following applicable legislation, regulatory guidance, industry recommended practices, and corporate policies and procedures: • Nova Scotia Offshore Petroleum Drilling and Production Regulations • CNSOPB Drilling and Production Guidelines • CNSOPB Incident Reporting and Investigation Guidelines • CAPP Standard Practice for Canadian East Coast Offshore Petroleum Industry Safe Lifting

Practices • API Recommended Practice 17W, Recommended Practice for Subsea Capping Stacks • API Standard 53, Blowout Prevention Equipment Systems for Drilling Wells


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4.0 SHELBURNE BASIN OVERVIEW

Shell’s offshore activities are located in the Shelburne Basin, approximately 250 km South of Halifax, Nova Scotia. The purpose of this exploration project is to find and confirm the presence of hydrocarbons in water depths of 1500-3500 m.

4.1 Exploratory Drilling

In March 2012, Shell was awarded Exploration Licences (ELs) covering 13,765 km2 (ELs 2423, 2424, 2425 and 2426) and two additional ELs (ELs 2429 and 2430) in January 2013 in the Shelburne Basin. Shell holds the exclusive right to drill and test for potential hydrocarbons, and to obtain a production licence to develop the licensed areas in order to produce hydrocarbons should the exploratory drilling prove successful. Overall project management of the day-to-day exploration drilling operations will be directed by Shell’s Operations Manager and Drilling Superintendent for the Shelburne Basin Venture Exploration Drilling Project (the Project) located in Halifax, Nova Scotia. Offshore, the management team includes the Shell Senior Drilling Supervisor (DSV), Stena Senior Toolpusher and the Stena Offshore Installation Manager.

Fig. 2 Shelburne Basin Map


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4.2 Drilling Roles and Responsibilities

4.2.1 Shell Canada Limited (Shell)

As the Operator, Shell is responsible for the exploration wells being drilled, under its ELs. In the case of a subsea well control incident, Shell is responsible for planning and implementing an appropriate plan to effectively and efficiently regain control of the well. This Source Control Contingency Plan (SCCP) is considered guidance and does not replace the judgment of Incident leadership.

4.2.2 Drilling Contractor (Stena Drilling Limited)

As the owner and operator of the Stena IceMax drillship which will be used for the Project, Stena conducts all drilling activities in accordance with approved procedures. In the unlikely event of an incident such as uncontrolled blowout, Stena offshore personnel will initiate loss of well control procedures, activate the Blowout Preventer (BOP) Emergency Disconnect sequence, and detach from the Lower Marine Riser Package. After an incident and when detached from the incident well, Stena is responsible for providing technical support to assist in subsea operations related to the survey and assessment, BOP intervention, and capping stack installation.


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5.0 SHELL INCIDENT MANAGEMENT TEAM (IMT)

5.1 Response Planning Assumptions

A variety of emergencies may occur onboard the drillship, some of which may trigger emergency conditions that could result in a subsea well blowout. Determining the cause of the blowout and the conditions of subsea infrastructure will be critically important to organize an effective well control response.

The planning basis assumes the following:

• The drillship is damaged, sunk or otherwise not capable of intervention assistance. A secondary drillship may be made available as per Relief Well Plan to begin drilling a relief well.

Note: Loss of ship is a worst-case scenario. If the drillship is functional, it can potentially be used in a variety of ways in the recovery effort (command post, support vessel, intervention vessel, observation vessel, pump vessel, relief well vessel), but this should not be assumed.

• Immediate emergency response operations are initially undertaken by the drillship, under the direction of the OIM and in accordance with established emergency procedures for emergency disconnect. The OIM are focused on personnel safety aboard the drillship and unable to serve as the On Scene Commander.

• The Shell DSV on-scene will assume the responsibilities of the On Scene Commander, until relieved of OSC responsibilities by a designated Shell Incident Commander.

• Initial attempts to control the well are either unsuccessful or unconfirmed. • Volume of flow is large, which would indicate no sealing ram closure, and it appears BOP did

not function as intended during Emergency Disconnect Sequence, auto shear, or dead man procedure.

Note: Blowouts are highly unpredictable and rare events and it is likely that conditions are not as assumed above; however, some assumptions must be established to create parameters for a plan. Success in a well control incident depends on the expertise and sound judgment of response personnel who must be able to deviate from this plan as conditions warrant.

5.2 Shell Incident Command System

The Incident Command System (ICS) is a proven on-scene all-hazard management system that is appropriate for all types of incidents regardless of size from the time an incident occurs until the requirement for management and operations no longer exists.

The elements of the ICS model were developed and refined from actual incidents. This common approach enables organizations using ICS to integrate their response with other organizations


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that are also using the concepts of the ICS. Shell follows the ICS principles and features that include:

1. Common terminology 2. Modular organization 3. Management functions 4. Management by objectives 5. An Incident Action Plan 6. Manageable span of control 7. Pre-designated incident facilities 8. Comprehensive resource management 9. Unified command 10. Integrated communications

The five major management functions are the foundation upon which the ICS organization develops. These are Command, Operations, Planning, Logistics, and Finance. They are applied during any emergency, when proactively preparing for possible events, or when managing a response to an emergency.

The Source Control Branch for a well incident (as opposed to a pipeline or shipping incident) falls under the Operations Section.

Note: For descriptions and guidelines of ICS roles outside of source control, see the Emergency Response Plan (ERP). The scope of this plan covers only source control operations for a well blowout incident.


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5.2.1 Key IMT Decisions Affecting Source Control Operations

In managing the response to a well blowout, the Incident Management Team (IMT) will be potentially faced with several critical decisions during the response. Some of these decisions may be to:

• Activate Source Control Contingency Plan o Mobilizes Source Control and Logistics response personnel for planning source control

response missions. • Suspend all non-response operations

o Focuses Shell’s Nova Scotia based organization on critical response and makes personnel and other resources available to respond.

• Mobilize OSRL resources o Activates the OSRL Subsea Well Intervention Service (SWIS) and makes available the

Capping Stack System and Subsea Incident Response Toolkit. o Mobilizes the Global Dispersant Stockpile to apply approved STAs subsea at the

wellhead and for surface application of approved STAs as per the local Oil Spill Response Plan.

• Activate regional aid and vessel sharing o Share light intervention vessels to assist with BOP Intervention, debris removal, and

dispersant application. o Make available other critical response equipment that may be necessary to respond,

i.e., Coiled Tubing Unit for dispersant application. o Augment responders with qualified technical and subject matter experts, as required.

• Open an Emergency Authorization for Expenditures (AFE) o Provides funding for air cargo and vessel mobilizations of global equipment. o Mobilizes OSRL and other technical representatives critical to the response located

outside of the Atlantic Region. • Seek emergency regulatory authorizations for response activities

o If the use of dispersants is appropriate, approval will be sought through the CSNOPB to apply approved STAs/dispersants subsea at the wellhead to ensure a safe working environment for response vessels and personnel at the surface.

o Authorization from Canada Border Services Agency (CBSA) for expedited customs and immigration entry for response critical equipment and personnel.

• Designate an Offshore Command and Control Process for SIMOPS Zone o Identify qualified On Scene Commander in accordance with the Emergency Response

Plan to ensure safe operations and risk mitigation in the Simultaneous Operations (SIMOPS) zone around the well site.

• Establish a 24-hour operating period and daily “battle rhythm” for the proactive phase of the response

o Enable response effectiveness, efficiency, and continuous communications by specifying times of recurring meetings and schedule of response deliverables.


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Emergency Phase Source Control Response Actions

Upon the notification of a blowout, the IMT will initiate and oversee critical actions as the incident organization transitions from the emergency to the proactive phase of incident response.

Step Description Responsible Party

1. Prior to well spud the following should be accomplished:

• Create a call-sheet with up to date emergency response contact information for use by Operations Manager or designate

• Make Commencement Notice to OSRL indicating that drilling activities are imminent. Procedure is here and form letter is here. This indicates that an OSRL-covered well is going to drill and indicates to OSRL the authorized persons to call out equipment

• Ensure well information is entered into Trendsetter R360 database to facilitate source control vessel selection. Procedures can be found here.

Shell

2. Contact OSRL Emergency Response - two 24-hour emergency contact numbers, either of which can be called. Equipment activation procedures, including these two numbers can be found in OSRL 0830:

a. UK: <Redacted> b. Singapore: <Redacted>

Operations Manager or other OSRL-authorized Shell employee

3. Verify Capping Procedure assumptions, including using rig BOP drawings and subsea surveys to request proper capping stack configuration, including whether a spacer spool is necessary. Note: Any equipment modifications required to meet the capping stack configuration not requested prior to mobilization have to be made at Halifax supply base in Nova Scotia, as the capping stack cannot be reconfigured at sea.

Operations Manager/ initial Incident Commander


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https://eu001-sp.shell.com/sites/AAAAA9494/Subsea%20Source%20Control%20Site/Source%20Control%20Library/Nova%20Scotia%20Source%20Control%20Plan/OSRL%20Well%20Nomination%20Process.pdf

https://eu001-sp.shell.com/sites/AAAAA9494/Subsea%20Source%20Control%20Site/Source%20Control%20Library/Nova%20Scotia%20Source%20Control%20Plan/OSRL%202009a_Exhibit%20C_LT_V2.docx

https://eu001-sp.shell.com/sites/AAAAA9494/Subsea%20Source%20Control%20Site/Source%20Control%20Library/Nova%20Scotia%20Source%20Control%20Plan/Nova%20Scotia%20vessel%20logistics%20execution%20using%20Trendsetter%20Response360.pptx

https://oilspillresponse.sharefile.com/f/fo775cfe-9e17-4e69-83c9-06acf3d0901d

https://oilspillresponse.sharefile.com/f/fo775cfe-9e17-4e69-83c9-06acf3d0901d


4. Make other notifications as per Operations Manager’s emergency call sheet:

a. In-country regulators and environmental authorities b. Shell Americas Response Team (SART ) c. Well Control Virtual Response Emergency Team

(WCVERT ) for source control specialist assistance. Activation procedure here.

Operations Manager or designate

5. Activate Projects & Technology (PT) personnel to provide Shell Source Control expertise in addition to WCVERT

Capping-SS Intervention Group

6. Contact selected capping stack freight forwarder’s emergency response number to activate logistics plan (includes working with vessel owner to create lashing plan, insurance broker, marine warranty surveyor, lift plan support, air charters if required, crane booking, etc.) Note: this plan uses JAS Method Statement for logistics planning

Logistics Section Chief/ Source Control Branch

7.

Activate AFE (if separate) related to Well Blowout Emergency Incident Commander, Logistics Section & Finance Section Chiefs


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8. Charter Intervention Vessels Activate Trendsetter R360 vessel selection process detailed here. This

is the process that assists in selection of choosing available, capable vessels for cap deployment (and other Source Control activities). Output also includes vessel owner contact information, vessel current contract holder, current location, etc. Work with Shell C&P and Logistics to acquire services of selected vessel via mutual aid and determine what feasibility calculations are required to certify a vessel’s suitability.

Note: R360 is a screening tool only. Final certification of suitability for cap deployment is accomplished after initial screening. Other references: Worldwide Emergency Response Equipment General Installation (OSRL 0903)

Local operations team or capping focal (depending on timing) in conjunction with Shell C&P and Logistics

9. Charter two 747 cargo aircraft for transportation of Subsea Intervention Response Toolkit (SIRT) from Stavanger, Norway (SVG) to Halifax Stanfield International Airport.

References:

Subsea Incident Response Toolkit Mobilization (OSRL 0706)

SIRT System Technical Overview (OSRL 0764)

Procurement Unit/Freight Forwarder

10. Finish completing the four notification/activation forms (OSRL 025, 027, 0829 and 0831) and send to OSRL as per previously referenced OSRL 0830. This will activate two capping stacks, the Subsea Intervention Response Toolkit (SIRT) in Norway and Trendsetter support personnel (Trendsetter personnel will mobilize to the capping stack country of storage to prepare the capping stack for operation and will board the vessel with the capping stack). Partially completed forms used for reference can be found here.

Operations manager or other OSRL-authorized Shell employee

11. Mobilize global dispersant stockpile (approved STAs only). Logistics Section/ Freight Forwarder

12. Charter cargo aircraft for transportation of dispersants to Halifax Stanfield International Airport.

Logistics Section/ Freight Forwarder


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13.

Charter Source Control Response Vessels to support BOP Intervention, Subsea Dispersants, and Debris Clearance.

Logistics Section/ Freight Forwarder

14.

Activate Regional Aid Assistance and Vessel Services Sharing

Incident Commander


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6.0 SOURCE CONTROL OPERATIONS

Figure 3 outlines the structure Shell has selected Shell for its Shelburne Basin Venture Source Control Branch.

Fig. 3 Shelburne Basin Venture Source Control Branch Organizational Chart

Source Control Branch Director <Redacted>

Capping & Subsea Intervention Group

<Redacted>

Site Assessment/Debris Removal Task Force

<Redacted>

Capping Stack Task Force

<Redacted>

Subsea Dispersant Task Force

<Redacted>

Well Control Group <Redacted>

Relief Well Task Force Primary: Henk Van Den

Dool <Redacted>

Well Control , Blowout Modeling Task Force

<Redacted>

Deputy SC Branch Director:

<Redacted>


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6.1 Source Control Branch

Under the responsibility of the Operations Section Chief, the Source Control Branch develops and implements strategies and tactics to regain control of the well, and stop or contain the discharge of hydrocarbons. This strategy includes:

• the development of solutions

• the coordination of engineering safety and operational activities

• the development of task-specific plans and procedures

• the identification of required tools and equipment

• monitoring progress in achieving well control.

The activities of the Source Control Branch will be organized into two primary groups: the Capping and Subsea Deployment Group and the Well Control Group. A “cap only” strategy is based on the assessment that the release of hydrocarbons from the incident well can be safely stopped by a mechanical device, or capping stack, without compromising well integrity. Employing a “cap only” strategy, no collection is required because the well will be mechanically shut in. A “cap and flow” strategy involves reducing the flow using a capping stack and collecting hydrocarbons as they are discharged. If collection is required, the use of open water subsea collection devices, subsea systems, risers, processing, flaring, storing, and offloading and tanker systems may be needed.

Note: The Shelburne Basin Venture structure may include a Deputy Source Control Branch Director to assist the Source Control Branch Director in the performance of his duties.

Note: If flowback and collection operations are performed from the capping stack, consideration should be given to a third Group (Cap and Contain/Flow), which would fall under the Source Control Branch, but this is beyond the scope of this Plan.

6.1.1 Simultaneous Operations (SIMOPS)

At certain points within the Source Control (SC) response, there may be a variety of SC units responding simultaneously (subsurface, surface and air). During such times, or other times by discretion of the Source Control Branch Director, the Director may assign a person or persons to monitor and control response unit traffic within the area of operations. This person should liaise with the SIMOPS unit (if assigned) under the Operations Section, which is overall in charge of simultaneous operations and maintenance of the Common Operating Picture.

6.2 Capping and Subsea Intervention Group

The Capping and Subsea Intervention Group is led by a senior engineer or operations supervisor and organizes tasks leading to the mechanical shut-in of the incident well. The capping strategy involves attaching a capping stack onto the BOP or directly onto the well head to stop and/or


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control the discharge of hydrocarbons. The Capping and Subsea Intervention Group is organized into three task forces which work interdependently to implement the capping strategy. These task forces are:

• Site Assessment/Debris Removal • Subsea Dispersant • Capping Stack.

The response to a well blowout will require an immediate multi-disciplinary response with a heavy reliance on subsea intervention capabilities and expertise. Shell’s subsea operations are routinely planned and organized into task forces to complete a series of subsea intervention tasks. Upon notification of a Tier 3 well control incident (or a Tier 2 incident with the potential of escalation to a Tier 3), the Source Control Branch Director will normally activate the Capping and Subsea Intervention Group. Key Activities: • Determine which capping stack and equipment to deploy into the operational area • Deploy capping stack and all necessary kit into the operational area • Close coordination with the Source Control Branch Director and other group leaders • Coordination of all operations related to deployment, testing and installation of the capping

stack • Ensure mobilization of internal and external support to assist with well containment

operations.


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6.2.1 Site Assessment/Debris Removal Task Force

This task force combines the functions of site assessment, BOP intervention and debris removal (if required).

6.2.1.1 Site Survey and Assessment

Site assessment is the initial and continuing survey of the incident well site to determine the extent of subsea infrastructure damage and the extent of the hydrocarbon discharge. The Task Force (TF) develops plans to locate debris and monitor subsea infrastructure and operations through the use of remotely operated vehicles (ROVs), as illustrated in Figure 4.

Fig. 4 Subsea Site Survey

The TF Leader coordinates team activities and writes operational procedures that are provided to the offshore teams for execution. Safety is a critical consideration for the TF while procedures are being developed that will be used in the field.


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Survey and Assessment Mission

Objective Gather information and data to determine the extent and impact of the incident and provide input for subsequent operations.

Campaign Plan Overview

Assessment includes the initial and ongoing survey of the incident site and equipment to be used in determining what debris can/has to be removed and efforts to create clearance procedures. The TF identifies the hydrocarbon discharge location, the location of subsea debris and associated damage, and develops plans for monitoring through the use of ROVs. Accurate and comprehensive reporting is a critical element of the TF campaign plan.

Required Data Personnel • Identification of onshore personnel for Site Assessment/Debris

Removal Task Force • Identification of personnel to be sent offshore to conduct operations Rig Data • BOP General Assembly Drawing • Tubular Specifications • Riser Specifications Well Data • Location • Water depth • Seafloor composition • Metocean Report • Visual conditions at mud line Logistics Support • Response Hardware

o Locally available Survey Tooling o SIRT - Survey Tooling (In the OSRL Debris Clearance Kit) o Review ROV operating conditions at mud line and determine if

sonar systems (OSRL SIRT or other) are required or if camera survey is adequate

• Vessel & ROV o Minimum requirements for Vessel and ROV operations o Vessel specifications o ROV specifications

Recurring Internal Processes (every operational period)

Data Gathering Analysis and Planning Process Hazard Assessment Work Instruction Development


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Campaign Briefing Documentation

Suggested staffing (per shift)

ROV Operations Specialist; Vessel contract representative; marine engineer for engineering models; subsea engineer

Campaign Plan Critical Tasks

Activation • Initiate 24 hour operations

o Mobilize onshore team o Mobilize and deploy offshore team to include:

Subsea inspections specialists Develop wet storage and laydown plan for Capping mission operations. Work Instruction Development Develop work instructions and provide a daily General Visual Inspection (GVI) and Detailed Visual Inspection (DVI) report. Reports should specifically address the following essential elements of information: • Seafloor condition

o Composition, indications of broaching, etc. • Status of marine riser and joints • Wellhead & BOP structural integrity

o Inclination, damage, leaks, etc. • Debris which would need to be removed to facilitate intervention &

capping o Access to BOP intervention panel o Access to BOP hub/mandrel

• Well flow data o Rate, composition, behaviour, etc.

Complete Process Hazard Assessment and the work instructions developed for each operational period. Complete procedures to conduct continuous air and subsea monitoring to determine VOC and LEL concentrations • Activate contractor to provide equipment in accordance with Oil Spill

Response Plan

Campaign Plan Critical Equipment

Shell will provide the following equipment to conduct the Survey and Assessment mission: • 1x Light Intervention Vessel (or other ROV-capable vessel) • 1x Class I Observation ROV (minimum); plus 1x Class III Work Class

ROV (recommended)


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• Air monitoring equipment (onboard SCRV) • Video monitoring equipment (onboard ROV)

Tools/Resources • Incident Organization Chart • Incident Briefing Schedule • Shelburne Basin Source Control Logistics Plan • Air Monitoring Plan

Outputs (responsible)

• (Onshore Team) Survey and Assessment Work Instruction Plans for Next Operational Period

• (Onshore Team) SIMOPs Form • (Onshore Team) Task Risk Assessment • (Onshore Team) SIMOP Risk Assessment • (Onshore Team) Wet storage and laydown plan • (Onshore Team) Map of debris field for integration into source control

operational planning • (Offshore Team) JSA Worksheets • (Offshore Team) Complete Campaign Daily Update form • (Offshore Team) Provide video grabs and video recording

6.2.1.2 BOP Intervention

The BOP Intervention mission is to prepare procedures and identify equipment and tools needed to restore control of the BOP stack and enable the well to be brought back under control by activation of the existing BOP rams (see Figure 5).


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Fig. 5 BOP Intervention

If this is not possible due to the condition of the BOP equipment, the unit should determine other ways of gaining control and access to BOP components to allow external control of the BOP and/or prepare the BOP for further capping, containment, or kill operations. The Site Assessment/Debris Removal Task Force coordinates activities associated with assessing the condition of, repair of, connecting to, controlling, and closing any flow from the BOP. The TF coordinates with the Planning Section to ensure proper authorizations have been obtained to commence and/or continue operations. Safety is a vital consideration for the TF while procedures are developed that will be used in the field. The team will utilize the Process Hazard Assessment procedure to identify risks and design procedures to mitigate process risk.

BOP Intervention Mission

Objective Restore well control through use of BOP stack.


The BOP Intervention mission is to prepare procedures and source equipment and tools to restore control of the BOP stack to enable the well to be brought back under control by the external activation of the existing BOP rams. If this is not possible due to the condition of the BOP equipment, the TF should determine other ways of gaining control and access to BOP components to allow external control of the BOP and/or


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prepare the BOP for further capping, containment, or kill operations. Safety is an important consideration for the TF while they are developing procedures that may be used by equipment operators. Through Hazard Identification (HAZID) analysis, the BOP Intervention Team develops procedures for responders

Required Data Personnel • Identification of personnel to be sent offshore to conduct operations Rig Data (Stena IceMax) • BOP General Assembly Drawing • Controls Diagram • ROV Panel Specifications • Functional Requirements • Last BOP Report from Rig Well Data • Location • Water depth • Seafloor composition • Metocean Report • Visual conditions at mud line Logistics Support • Response Hardware

a) Local BOP Intervention kit specifications b) SIRT-BOP Intervention kit specifications

• Vessel & ROV a) Minimum requirements for vessel and ROV b) Vessel specifications c) ROV specifications


Data Gathering Analysis and Planning Process Hazard Assessment Work Instruction Development Campaign Briefing Documentation

Competencies Drilling; Subsea Engineering; ROV Pilot/Technician; Safety; Risk Assessment


Activation • Initiate 24-hour operations

o Mobilize onshore team to include: Team Leader (Wells)


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Wells staff engineers Subsea Operations engineers Subsurface Operations engineers Subsea Support Services Contractor ROV operator Rig owner (Stena) BOP technical specialists Risk facilitator

o Mobilize offshore team to include: Drilling engineer BOP technical representatives ROV technical representatives

Planning and Analysis • Intervention Tooling Assessment

o Review BOP Functional Requirements against SIRT equipment capability

o Verify SIRT equipment and vessel capabilities Power, pressure, fluid

o Confirm system interfaces o Confirm requirements for working at well water depth

• Assess BOP condition o Review GVI/DVI reports from Survey and Assessment Team

• Verify that OSRL Subsea BOP Intervention Kit has been mobilized

Work Instruction Development • Identify any debris clearance requirements to access BOP • Develop BOP Intervention procedures, specifically identifying

sequence of closing rams using ROV manually turning valves, and monitoring pressure and diagnostics of BOP

• Assess well integrity • Complete required testing procedures • Complete risk assessment Complete SIMOPS form Conduct briefing for offshore OSC and ROV personnel


Shell will provide the following equipment to operate the OSRL BOP Intervention Equipment: • 1x Light Intervention Vessel (or other ROV-capable vessel) • 1x Class III Work Class ROV and 1x Class I Observation Class ROV

(recommended)


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• Nitrogen for pre-charging 6x100 gal accumulator bottles to the required pressure. Maximum volume required is 600 gal at 7000 psi pressure.

• Stack Magic (or similar fluid) to charge the Subsea Accumulator with the required hydraulic fluid volume. Maximum volume required is 390 gal.

The OSRL BOP Intervention Kit includes: • Subsea Accumulator, Master Unit • Subsea Accumulator, Slave Unit • Subsea Accumulator, Suspended • BOP Intervention Skid (full) • Dual BOP Interface

Tools/Resources • Incident Organization Chart • Incident Briefing Schedule • Campaign Daily Update • Video grabs and video recording capabilities • Wet storage area and subsea laydown plan developed by Survey

and Assessment Team • BOP general arrangement drawings, technical specifications, record

of changes, and installation and maintenance procedures. • SIRT Packing List (OSRL 0045) • BOP Intervention Kit Installation and Operation Manual (OSRL 1138) • SIRT Incident Owner Equipment (OSRL 1136) • Subsea Accumulator Installation and Operation Manual (OSRL

1157) • BOP Skid Installation and Operation Manual (OSRL 1165) • Operation and Maintenance Manual Dual BOP Interface

(970086735-DTS-OMM-001 SWR-OC-UA-MAN-30006) • General Arrangement Drawing Subsea Accumulator (970086734

SWR-OC-UA-DWG-21001) • General Arrangement Drawing Suspended Subsea Accumulator

(970097000 SWR-OC-UA-DWG-21010) • Operation and Maintenance Manual Subsea Accumulator

(970086734-DTS-OMM-001 SWR-OC-UA-MAN-21006) • Chemical Jumper (Flying Lead) Manual (OSRL 1168) • Deployment Rack for Flying Leads Manual (OSRL 1174) • Engineering Calculations Report (including subsea accumulators,

hoses, etc.) (131702-1002-DTS-REP-001 SWR-OC-UA-REP-02004) • Packing and Preparation Manual (131702-1002-DTS-MAN-005

SWR-OC-UA-MAN-02010)

Outputs • (Onshore) BOP Intervention work instructions for Next Operational Period

• (Onshore) SIMOPS Form


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• (Onshore) Task Risk Assessment • (Onshore) SIMOP Risk Assessment • (Offshore) JSA Worksheets


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6.2.1.3 Debris Clearance

Using the information previously obtained, the Debris Clearance mission develops procedures for preparing access to the BOP or to clear debris from the well site to facilitate operations to cap, contain, or kill the well (see Figure 6).

Fig. 6 Debris Removal

Debris clearance includes the development of work procedures, integration of tools and equipment, and the development of procedures to remove debris. Safety will be integrated into the planning and design process through Process Hazard Assessment procedure. A Light Intervention Vessel with a 50 t (metric tons) heave-compensated crane is capable of completing most of the work anticipated in this campaign. However, if more significant lifting is required, a subsea construction vessel with a 250 t heave compensated crane will be chartered to install the capping stack and can complete any remaining debris clearance tasks.

Debris Clearance Mission

Objective Remove damaged equipment, possibly including the BOP, from the incident well so as to enable the installation of a capping stack for soft shut-in.


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Using information provided from earlier work, the Site Assessment/Debris Removal TF develops procedures for preparing access to the BOP and to clear debris or infrastructure from the well site to facilitate further operations like capping, containment, and well kill. The TF Leader coordinates the development of procedures associated with removing the debris around the site for the access to the source. Safety is an important consideration for the TF and the Process Hazard Assessment procedure allows for the systematic evaluation of risk. This campaign will be considered completed when all debris is cleared from the site and the site is appropriately prepared for the installation of the capping stack either onto the BOP or directly onto the wellhead.

Required Data Personnel • Identification of onshore personnel for Debris Clearance mission • Identification of personnel to be sent offshore to conduct Debris

Clearance operations Subsea Equipment • BOP General Assembly Drawing • Tubular Specifications • Riser Specifications Well Data • Location • Water depth • Seafloor composition • Metocean Report • Visual conditions at mud line • Wet storage area and subsea laydown plan Logistics Support • Response Hardware

a) Locally available debris clearance kit b) SIRT – Debris Clearance Toolkit



Data Gathering Analysis and Planning Process Hazard Assessment Work Instruction Development Campaign Briefing


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Documentation


ROV representative; marine engineer; BOP representative; rig specialist; cutting tool equipment specialist (per cutting tool provider)


Activation and Mobilization • Initiate 24-hour operations

o Mobilize onshore team o Mobilize offshore team to include:

Subsea project engineers Subsea construction specialist

Complete Debris Clearance Work Instructions: • Gather data from earlier work regarding status of well site • Obtain debris specifications and drawings (if obstructing access

area) • Confirm crane and ROV capabilities to make desired cuts and lifts. • Confirm that the cutting tools identified in Resource Requirements List

are sufficient to remove potential debris • Ensure LMRP unlatch can be completed remotely • Identify rigging method for LMRP recovery • Cut and remove choke and kill lines • Install rigging on riser, cut, and remove riser sections • Install rigging on LMRP/BOP, unlatch and remove connectors • Clear all other debris that could impede well control operations • Develop a chain of custody process for any debris recovered • Identify and maintain a 'wet store' area Complete required testing procedures for equipment Complete risk assessment Complete SIMOPS form Conduct briefing for offshore OSC and ROV personnel

Campaign Critical Equipment

Shell may provide the following equipment to operate the OSRL Debris Clearance Equipment (may be adjusted depending on debris clearance requirements): • 1x Light Intervention Vessel with 50 t heave-compensated crane,

DPS2 and 550 sq meters deck space • 2x Class III Work Class ROVs


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• Mineral Oil Tellus 22 (or similar hydraulic fluid) for refilling the Hydraulic Power Unit once deployed to seabed. The required volume is about 75 l (20 gal).

• Down line to operate the heavy debris clearance tools like the 60in chop-saw, the 22in chop-saw, the Pipe Grapple Tool and the Rock Grappler. The required length of the Down line will be dependent on the water depth at the incident location, up to a maximum 3000 m.

The debris clearance container is included as part of the Subsea Intervention Response Toolkit (SIRT) transported by air from Norway: • Remote Control Unit • Chopsaw 60in • Chopsaw 22in • Torque Tool Class 1-4 • Test Jig Class 1-4 • Flying Lead Orientation Tool • Linear Valve Override Tool (Type A) • Linear Valve Override Tool (Type C) • Grinder G39 UW • Super Grinder • Multipurpose Cleaning Tool 10in • Diamond Wire Cutter • ROV Operation Kit, Arm-bracket • ROV Operation Kit, Parking • 6in ROV Dredge • Hytorc Stealth • Impact Wrench • Pipe Grapple Tool • Camera Inspection ROV Operated • Manipulator Knife • Hydraulic Power Unit (empty) • 2D Multibeam Imaging Sensor • 3D Multibeam Imaging Sensor • ROV Rock Clamp • Hydraulic Cutter

Tools/Resources • Incident Organization Chart • Incident Briefing Schedule • IRM Campaign Daily Update form • Wet storage area and subsea laydown plan • Video grabs and video recording capabilities • Debris Clearance Operating Manual (OSRL 1139) remote control

unit operation and maintenance manual ( OSRL 1140)


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• Chopsaw 60in operation and maintenance manual ( OSRL 1141) • Chopsaw 22in operation and maintenance manual ( OSRL 1142) • Torque tool class 1-4 operation and maintenance manual ( OSRL

1143) • Test jig class 4 operation and maintenance manual ( OSRL 1144)

flying lead orientation tool operation and maintenance manual ( OSRL 1145)

• Linear valve override tool, type a operation and maintenance manual ( OSRL 1146)

• Linear valve override tool, type c operation and maintenance manual ( OSRL 1147)

• Grinder g39 uw operation and maintenance manual ( OSRL 1148) • Super grinder operation and maintenance manual ( OSRL 1149) • Multipurpose cleaning tool 10in operation and maintenance manual

( OSRL 1150) • Diamond wire cutter operation and maintenance manual ( OSRL

1151) • M6in rov dredge operation and maintenance manual ( OSRL 1153) • Hytorc stealth 22 operation and maintenance manual ( OSRL 1154) • Impact wrench iw16 operation and maintenance manual ( OSRL

1155) • Pipe grapple tool operation and maintenance manual ( OSRL 1156) • Manipulator knife operation and maintenance manual ( OSRL 1159) • Hydraulic power unit operation and maintenance manual ( OSRL

1160) • 2d multibeam imaging sensor operation and maintenance manual (

OSRL 1161) • 3d multibeam imaging sensor operation and maintenance manual (

OSRL 1162) • Rov rock clamp operation and maintenance manual ( OSRL 1163) • Hydraulic cutter operation and maintenance manual ( OSRL 1164) • SIRT Incident Owner Equipment ( OSRL 1136) • Shelburne Basin Source Control Logistics Plan

Outputs • (Onshore) Debris Clearance Work Instructions for Next Operational Period

• (Onshore) SIMOPS Form • (Onshore) Task Risk Assessment Form • (Onshore) SIMOPS Risk Assessment Form • (Offshore) JSA Worksheets


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6.2.2 Subsea Dispersant Task Force (TF)

The Subsea Dispersant TF develops tactics and procedures to inject dispersant from a surface vessel through a surface pump package to the wellhead utilizing a suitable conduit from surface support vessels (see Figure 7). Subsea dispersant applications reduce VOCs and ensure operations are within Lower Explosive Limits (LEL), better facilitating vertical access of capping vessel.

Fig. 7 Subsea Dispersant Application

Dispersants also accelerate bacterial action to break down the oil in the water column. Dispersant application will continue until the hydrocarbon flow has stopped by other means. The Subsea Dispersant kit is available through OSRL and will include the necessary subsea hardware to apply the dispersants. It is the responsibility of Shell to source and access the vessel, approved STAs, pump packages, and reeled hose equipment, and to determine subsea dispersant resource needs.

Inclusion of STAs in the spill contingency plans does not constitute approval of their use during an incident. If the use of dispersants is appropriate, approval will be sought through the CSNOPB.

SUBSEA DISPERSANT SPECIFIC GUIDANCE CAN BE FOUND HERE


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Subsea Dispersant Task Force

Objective To reduce the risks to workers and operations from Volatile Organic Compounds (VOCs) in the safety area around the incident well site by injecting approved STAs at the wellhead or as close as possible to the hydrocarbon discharge point.


The Subsea Dispersant TF develops tactics and procedures to inject approved STAs from a surface vessel through a surface pump package to the wellhead utilizing an appropriate through-water conduit. The application of dispersants at the site of the blowout will minimize the hydrocarbon vapors which may be both harmful to personnel and introduce hazards such as fire. Dispersant applications reduce VOCs and ensure safe operations below LEL. Dispersants also accelerate bacterial action to break down the oil in the water column. Dispersant application continues until hydrocarbon flow has been stopped by the installation of a capping stack or relief well intervention. The OSRL Subsea Intervention Response Toolkit includes subsea hardware to apply the dispersants. It is the responsibility of Shell to source and store the vessel, approved STAs, pump packages, and reeled hose equipment.

Required Data Personnel • Identification of onshore personnel • Identification of personnel to be sent offshore to conduct operations Rig Data (IceMax) • BOP General Assembly Drawing • Controls Diagram • ROV Panel Specifications • Functional Requirements • Last BOP Report from Rig Well Data • Location • Water Depth • Seafloor composition • Metocean Report • Visual conditions at mud line Logistics Support • Response Hardware

a) SIRT – Dispersant System b) Pump/Hose Deployment specifications c) Coiled Tube Unit specifications d) OSRL Global Dispersant Stockpile (GDS)


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Data Gathering Analysis and Planning Process Hazard Assessment Work Instruction Development Campaign Briefing Documentation


ROV Operations specialist; flow engineer; dispersant manufacturer representative; dispersant use specialist x 2; dispersant equipment surface specialist x 2; monitoring equipment specialist x 2; environmental impact specialist x 2.


Activation and Mobilization • Initiate 24-hour operations

o Mobilize onshore team o Mobilize offshore team:

• Mobilize OSRL Subsea Dispersant Kit • Mobilize OSRL Global Dispersant Stockpile • Mobilize vessel and surface equipment (tanks, pumps, CTU or hose) Complete Dispersant Work Instructions • Develop onboard storage procedures for dispersants • Determine dispersant demand schedule based on blowout rate and

resupply schedule • Develop dispersant application procedures and monitoring plan

including sub-sea well discharge information • Configure interfaces to align with Containment System • Provide procedures to Planning for subsea dispersant injection permit

approvals • Complete required testing procedures • Complete risk assessment • Complete SIMOPS • Conduct briefing for offshore OSC and ROV personnel • Conduct monitoring and reporting per approved plan

o Phase 1: confirm dispersant effectiveness near the discharge point and reduction in surface VOCs

o Phase 2: characterize dispersed oil concentrations at depths in water column


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o Phase 3: complete detailed chemical characterization of water samples


Shell will provide the following topside system and equipment to operate the OSRL Subsea Dispersant Toolkit: • 1x Light Intervention Vessel preferably with moonpool • Dispersant resupply vessels as required • 2x Class III Work Class ROVs • LIV onboard tankage of sufficient capacity to store 7 days of

dispersant • Pump • Dispersant: The design rate for the Dispersant Injection System is 110

l/min and this is based on a Dispersant Oil Ratio of 1:100. If the well flow is 50,000 bbls/d, the recommended dispersant injection rate is 55 l/min.

• Note: If the use of dispersants is appropriate, approval will be sought through the CSNOPB.

• Location beacons to mount on the Coiled Tubing Termination Head (CTTH) and the Subsea Dispersant Manifold (SDM) as a minimum. The CTTH can be anchored to the Deployment racks or a stand-alone anchor in order to gain control of the drift of the coil tube with the CTTH attached to it.

• Deployment piping (CTU or flexible hose) along with necessary surface deployment frames and crossovers

The OSRL subsea system for dispersant distribution and injection includes: • One Coiled Tubing Termination Head • Two 1” flexible injection lines for connections from CTTH to the subsea

manifold • One Subsea Manifold for multiple injection lines • Up to five 1” flexible injection lines for connections from manifold to

ROV’s and injection points • Various sized wands for injection directly into flow • High flow hot stabs to perform all the connections • 4 Transportation and subsea deployment racks for flexible injection

lines • One spare 1” flexible injection line

Tools/Resources • Incident Organization Chart • Incident Briefing Schedule • IRM Campaign Daily Update form • Wet storage area and subsea laydown plan • Video grabs and video recording capability • Dispersant Toolbox, System Technical Overview (OSRL 764)


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• Subsea Dispersant System Installation and Operation Manual (OSRL 1135)

• Industry Recommended Subsea Dispersant Monitoring Plan (API Technical Report 1152)

• SIRT Incident Owner Equipment (OSRL 1136) • Coiled Tubing Termination Head Manual (OSRL 1167) • Chemical Jumper (Flying Lead) Manual (OSRL 1168) • Deployment Rack for Flying Leads Manual (OSRL 1174) • Subsea Dispersant Manifold Manual (OSRL 1169) • Dispersant Wand Manual(s) (OSRL 1170, 1171,1173) • SIRT Packing List (OSRL 00045) • Shelburne Basin Source Control Logistics plan • Identified import and customs clearance processes • Shell subsea dispersant guidance

Outputs • (Onshore) Subsea Dispersant Work Instructions for Next Operational Period

• (Onshore) Permit request for subsea dispersant application • (Onshore) SIMOPS Form • (Onshore) Task Risk Assessment • (Onshore) SIMOPS Risk Assessment • (Offshore) JSA Worksheets


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6.2.3 Capping Stack Task Force

The final campaign associated with the well capping strategy is the actual installation and operation of the capping stack (see Figure 8). In the event that shut-in of the well is not attainable due to wellbore integrity issues, the capping stack may serve as the mechanical interface for contingency flowback or assist in mitigating well flow during the relief well operations.

Fig. 8 Capping Stack Installation

The stack will be assembled and tested by Trendsetter Engineering at the OSRL base prior to offshore deployment. Shell will accept responsibility for the capping stack and all associated OSRL equipment at the dockside in Tananger, Norway (primary capping stack) and Angra dos Reis, Brazil (backup capping stack). The stack and associated equipment will be loaded onboard a Shell chartered vessel of opportunity and proceed directly to the well site. Prior to departure from Tananger, Norway, technical representatives from Trendsetter Engineering will embark the subsea construction vessel. Upon arrival at the well site, and once the site is appropriately prepared for installation, the cap will be positioned over the flowing well, and latched to the BOP, LMRP or wellhead connector. Once the integrity of the connection to the BOP is assured, the capping stack valves will be closed in sequence such that flow to the ocean is gradually shut off.

If the integrity of the well bore holds, the Subsea Well Source Control operations are successful and repair operations can continue without further discharge of hydrocarbons. However, should the act of shutting in the well suggest that the downhole well integrity is insufficient to contain the


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full well pressure, the capping stack valves will be re-opened to prevent further damage to the well. This determination regarding the subsurface well integrity is made primarily through observation of the wellhead pressure immediately post initial shut in.

An increase in pressure followed by a drop would indicate that hydrocarbon flow was occurring at some other point, likely through a damaged section of the well beneath the wellhead.

FOLLOW THIS LINK FOR THE SHELBURNE BASIN CAPPING PROCEDURE

The below is general guidance

Capping Stack Task Force Objective Regain well control through the installation and operation of a

capping stack attached to the BOP or directly onto the wellhead. Campaign Plan Overview The final mission associated with the well capping objective is the

actual installation and operation of the capping stack. Onshore preparations are made to the stack that is staged by OSRL in Tananger, Norway. The stack will be assembled and tested by OSRL prior to offshore deployment. Shell, will accept responsibility for the capping stack and all associated OSRL equipment at the dockside in Tananger, Norway. The stack and associated equipment will be loaded onboard a Shell chartered subsea construction vessel and proceed directly to the well site. Prior to departure from Stavanger, Norway, technical representatives from Trendsetter Engineering will embark the subsea construction vessel. Upon arrival at the well site, and once the site is appropriately prepared for installation, the cap will be positioned over the flowing well, and latched to the BOP, LMRP or wellhead connector. Once the integrity of the connection to the BOP is assured, the capping stack valves will be closed in sequence such that flow to the ocean is gradually shut off. If the integrity of the well bore holds, the Subsea Well Source Control operations are successful and repair operations can continue without further discharge of hydrocarbons. However, should the act of shutting in the well suggest that the downhole well integrity is insufficient to contain the full well pressure, the capping stack valves will be re-opened to prevent further damage to the well. This determination regarding the subsurface well integrity is made primarily through observation of the wellhead pressure immediately post initial shut in. An increase in pressure followed by a drop would indicate that hydrocarbon flow was occurring at some other point, likely through a damaged section of the well beneath the wellhead.


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Outputs Capping Stack Intervention Mission Plans Task Risk Assessment

Preceding Campaign Plan

Well Data Collection Well Modelling and Analysis BOP Intervention Debris Clearance

Concurrent Campaign Plans

Survey and Assessment Subsea Dispersant

Internal Processes Activation and Mobilization Process Hazard Assessment Work Procedure Development Campaign Briefing Documentation


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• Activation and Mobilization • Initiate 24-hour operations • Mobilize team • Complete Debris Clearance Work Procedures: • Confirm capping stack can be landed on flow and determine

minimum primary bore sizing (i.e. 18 3/4”) • Confirm that well can be shut-in without well integrity loss • Determine fatigue loading of wellhead/BOP assembly with

Capping Stack installed • Ensure that Capping Stack is configured and installed to

facilitate flow line tie-in • Identify areas for laydown, assembly, testing and load out • Review installation procedure of Capping Stack • Review and update lowering and latching procedures • Update hydraulic accumulator charging plan • Update hydrate mitigation and remediation plans • Modify plan to fill hydrate tanks onboard vessel • Update well shut-in procedures • Develop installation configuration and sequence (vector

connectors) • Determine well structural integrity to contain pressure and

determining if additional measures are needed, such as containment or relief well

• Determine appropriate number of outlets and chokes to facilitate soft shut-in of well

• Complete required testing procedures • Complete risk assessment • Conduct briefing for OSC and ROV personnel

• Deploy and install Capping Stack • Complete debris clearance operations • Complete hydrate remediation • Run capping stack to depth on wire subsea construction

vessel using compensated crane or winch line or other heave compensation system

• Lower capping stack to a predetermined safe lateral distance from and safe working depth above the well to be capped and stop

• Confirm all components in the main bore of the capping stack are fully open and start flushing with chemical injection (hydrate inhibitors) as recommended


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• Move capping stack into the flow immediately above the well to be capped.

• Utilizing ROVs as needed, land capping stack on the well to be capped

• Latch and lock connector to the flowing well via ROV panel. If possible, confirm latch with over pull on running string. Stop chemical injection flushing. Perform external seal pressure test, if applicable.

• Engage secondary lock on the connector if applicable. • Consider releasing the deployment system from the capping

stack; an important consideration if no emergency disconnect feature included.

• Attach any power fluid supply and chemical injection supply flying leads from subsea deployed accumulator package (or ROV fluid/pump skid) to ROV panel(s) on capping stack.

• Operating Procedure to Secure the Well • Function open and confirm by ROV that all diverter valves

and any associated diverter line chokes are in the full open position.

• Close lower main bore element via ROV panel. • Monitor well pressure and compare with expected pressure

response. • Progressively close chokes (or sequentially close diverter

valves) on the diverter lines with ROV. • Monitor well pressure and compare with expected pressure

response. • Move ROV to safe standby position; observe for leaks. • If any leaks are observed from the closed main bore element,

close additional main bore elements, if possible. • Monitor well pressure and compare with expected pressure

response. • If available, run and latch a pressure cap on the capping

stack main bore and, if possible, pressure caps on all the side outlet diverter lines.


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Shell will provide the following equipment to operate the OSRL Capping Stack: Rig or construction vessel sufficient to deploying subsea equipment to

depth 2 Class III Work Class ROVs OSRL Capping Stack System

Suggested Staffing (per shift)

Subsea engineer/SURF specialist, vessel contractor representative; ROV operations specialist; OSRL capping focal; Trendsetter technical advisors; blowout contractor

Capping Stack System Intervention Tools & Resources

Document Number Description Incident Organization Chart Wet storage area and subsea laydown plan Video grabs and video recording

OSRL 0903 Worldwide Emergency Response Equipment General Installation Procedures

OSRL 1536 Installation Procedure for Capping Stacks OSRL 1538 Installation Procedure for Capping Stacks Inclined OSRL 1541 Installation retrieval procedure subsea accumulator module SWR-TE-UA-MAN-00001 Drawdown Tool O&M Manual SWR-TE-UA-MAN-00002 Softland Tool O&M Manual SWR-TE-UA-MAN-00003 5in Gasket Clearance, Installation Tool O&M Manual SWR-TE-UA-MAN-00004 Tooling HPU Operations and Maintenance Manual SWR-TE-UA-MAN-00005 Bore Test HPU O&M Manual SWR-TE-UA-MAN-00006 H4 Test Cap O&M Manual SWR-TE-UA-MAN-00014 ACAMS User Manual SWR-TE-UA-MAN-00026 Spreader Bar O&M Manual SWR-TE-UA-MAN-00043 Inclination Tool O&M Manual SWR-TE-UA-MAN-00050 Class 5 Torque Tool O&M Manual SWR-TE-UA-MAN-00051 Class 4 Torque Tool O&M Manual SWR-TE-UA-PRO-00011 Installation Procedure 16 Line HFL w Cobra Heads SWR-TE-UA-PRO-00013 Recovery Procedure 18 15K Capping Stack SWR-TE-UA-PRO-00018 Recovery Procedure Inclined 18in Capping Stack

SWR-TE-UA-PRO-00021 Installation, Retrieval Procedure of No.5 Choke Connection System

SWR-TE-UA-PRO-00046 Installation, Recovery Procedure of Secondary Ca Capping Stack Interface Options BOP interface Drawing sample


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Well Control Group The Well Control group is led by a Senior Wells Engineer and is responsible to the Source Control Branch Director for all relief well and blowout modeling activities. It consists of two task forces: Relief Well and Well Control/Blowout Modeling.

6.2.4 Relief Well Task Force

A relief well provides a means to intercept and kill a blowout after capping the well or if capping is not possible/successful. It is not uncommon to plan or spud a relief well before or during a capping operation. A relief well is typically drilled as a straight hole down to a planned kickoff point, where it is turned toward the target well using conventional directional technology and tools to get within 100-200 ft of the original well. The aim is to align the two wellbores at an incident angle of 3-4° for the eventual intersect rather than aiming directly at the blowout wellbore. This approach provides the best chance of success for a first-attempt intersect and allows steering of the bit for a repeated attempt instead of plug-back and sidetrack. At this point, the drilling assembly is pulled and a magnetic proximity ranging tool is run on wireline to determine relative distance and bearing from the target well. Directional drilling continues to about half the distance to the planned intersection, and another magnetic ranging run is made to update relative distance and bearing. This process continues until the two wells are very close to intersecting. At this point, a liner is set to provide a positive alignment for penetration into the target well, as well as maximum fracture gradient at the casing seat for the subsequent dynamic kill. The planned weight and volume of kill mud is prepared, and all pumps and fluid systems are in full readiness mode before drilling out of the liner shoe. Dynamic kill commences immediately upon penetration of the target wellbore, and pumping continues until the well is under control.

FOLLOW THIS LINK FOR THE SHELBURNE-BASIN SPECIFIC RELIEF WELL PLANS


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Relief Well Task Force

Objective Provide a means to intercept and provide a conduit to kill a blown out well.

Campaign Plan Overview Using the Relief Well Plan, The Relief Well Group develops tactics and procedures to mobilize drill ships, drill the relief well, intersect the wellbore of the incident well, and kill the well. This will require the technical expertise of various well control contractors such as Wild Well Control, Boots & Coots, and Add energy.

Outputs Relief Well Drilling Plan Task Risk Assessment Permit request for drilling

Preceding Processes Well Data Collection Well Kill Modelling and Analysis


Subsea Survey and Assessment BOP Intervention Debris Clearance Subsea Dispersant Application Capping Intervention



Rig contractor representatives; contractor relief well specialists; contractor ranging specialists; Shell relief well SME; Shell subsurface asset team; Shell drilling team (Engineering and Operations)


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Relief Well Task Force


• Activation and Mobilization • Initiate 24-hour operations • Mobilize team to include:

o Team Leader (Wells) o Wells staff engineers o Reservoir engineers o Directional drilling engineers o Well Control Contractors o Fluid Services Contractor o Risk facilitator (HSEQ)

• Determine surface location of relief wells • Mobilize drilling rigs • Work procedure development • Commence drilling relief well • Perform Ranging • Intersect wellbore • Commence dynamic kill operations


Shell will provide the following equipment to execute the relief well mission: Relief well rig(s) Kill Fluid Supply Vessels Tubulars Stimulation vessels, if available Pumping equipment Drilling Contractor and drilling equipment Ranging equipment Dynamic kill models/calculations AddEnergy Blowout Contingency Study for Monterey Jack AddEnergy Blowout Contingency Study for Cheshire


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6.2.5 Well Control and Blowout Modelling Task Force

This task force is responsible for providing modelling and engineering expertise and services to the Source Control Branch. Tasks may include reservoir modelling, kill modelling, shut-in modelling, hydrate modelling and other flow modelling required during the incident. It may also be required to assist in the design and fabrication of any new equipment that is required. This task force draws heavily on well control contractor personnel and may assign specialists to other task forces as required to complete their missions.

Well Control/Blowout Modelling Task Force

Objective Management and coordination of technical and engineering support services to the Source Control Branch, as needed. The TF helps ensure efficient use of engineering services and data consistency. The TF may place personnel within other Source Control TFs to help with technical expertise such as design review and flow assurance/hydrate modelling.

Outputs Engineering models as required, including blowout modelling, cap shut-in modelling, flowback modelling (if applicable), new equipment design

Preceding Processes Well Data Collection


Subsea Survey and Assessment BOP Intervention Debris Clearance Subsea Dispersant Application Capping Intervention



Shell blowout modelling SME, contractor blowout specialists, contractor modelling specialists; hydrate specialist; draftsmen with fabrication software


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Well Control/Blowout Modelling Task Force


• Activation and Mobilization • Initiate 24-hour operations • Provide engineering and modelling support for other

operational groups • Develop operational storyboard and animation illustrations

to explain operational activities • Oversee design, fabrication and System Integration Tests for

any new equipment • Develop 3D models for schematics to support operational

groups


Shell will provide the following equipment to execute the relief well mission: Modeling staff and contractors with applicable equipment


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7.0 SOURCE CONTROL ORGANIZATIONAL CAPABILITY DEVELOPMENT

7.1 Source Control Training

All personnel assigned to Source Control responsibilities in the Shell Incident Command team are recommended to complete the OSRL Subsea Well Intervention System Appreciation Training. All staff who would likely be involved in a response to an incident are encouraged to take and complete ICS 100 & 200 via the Shell Open University Portal. Key Personnel involved with the incident will have also completed ICS 300 training. Specific training requirements are at the discretion of the Shell Canada Operations Manager.

7.2 Drill and Exercise Plan

It is suggested that Source Control drills and exercises be included as part of overall operational readiness for the Project. The frequency and nature of such drills are at the discretion of Shelburne Basin Venture/Shell Canada management. A major SART (Shell Americas Response Team) exercise, including source control, was completed in April 2015.


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8.0 SOURCE CONTROL LOGISTICS PLAN

Well control incidents normally require the mobilization of large amounts of specialized equipment and vessels to conduct subsea operations. The mobilization of specialized personnel is also required as a critical enabler of an effective response. This logistics plan identifies the logistics concept of operations, organization, processes, requirements, and resources Shell will use to support source control operations. The following references apply to Source Control Logistics support and provide a range of general and specific guidance for the mobilization, transportation, and accountability for source control equipment. Note: This is a general guideline for logistics support. Actual logistics operations will be the responsibility of the Logistics Section in consultation with the Source Control Branch, assisted by OSRL (at point of origin), designated freight forwarder, vessel owner(s) and local logistics organization/contract carriers.

Related Process Document Number

Title

Accountabilities OSRL 0705 Accountability Matrix

Equipment Handover

OSRL 870 Capping Stack Handover Procedure – Sea

Equipment Handover

OSRL 1071 Subsea Intervention Toolkit Handover Procedure for Air Transport

Equipment Handover

OSRL 1072 Subsea Intervention Toolkit Handover Form

Equipment Handover

OSRL 0872 Capping Stack Handover Form

Sea Fastening SWR-TE-UA-REP-00106

Sea Fastening for Capping Stack Sea Fastening

Sea Fastening SWR-TE-UA-PRO-00019

Mobilization and Deck Procedure 18 in. CS


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Mobilization SWR-TE-UA-MAN-00047

Operations Manual Volume 4 – Capping Stack Mobilization and Assembly Procedures

Equipment Inventory OSRL 1698 Norway Stack H4 Stack 0M Sp. Bar (Sea shipment)




Transportation SWR-TE-UA-PLA-00004

Container Plan – SWRP 15K Capping Stack w 14 in. actuators

Equipment Inventory SWR-TE-UA-REP-00026

Capping System Spares List

Equipment Loadout 10012-23371-R-029E

Method Statement for Load Out of BOP with 3 m spacer spool

Export OSRL 0860 Customs export guidelines Norway

Mobilization OSRL 0831 Subsea Response Equipment Selection and Configuration Form

OSRL Logistics OSRL 0850 Logistics Execution Plan Norway

OSRL Logistics OSRL 0853 Logistics Execution Plan Brazil

OSRL Logistics OSRL 0723 Transport and Logistics Philosophy

OSRL Logistics OSRL 0800 Norway Base Overview

OSRL Logistics OSRL 0783 SWIS Base Support Services

Transportation OSRL 0711 Certificate of Non Dangerous Goods Compliance – Accumulator


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8.1 Source Control Logistics Concept of Operations (CONOPS)

The CONOPS for logistics support will enable the flow of critical incident equipment to the well site.

• Mobilization and transport of the Capping Stack System by vessel from the OSRL base in Stavanger, Norway. (Alternate mode of mobilization and transport is by air from the OSRL base in Stavanger, Norway.) Transit directly to incident well site.

• Mobilization and transport of the Subsea Intervention Toolkit by air from the OSRL base in Stavanger, Norway.

• Mobilization and transport of other equipment needed for capping operations by air from various supply locations.

• Mobilization and chartering of suitable vessels for operations and for transportation of equipment not suited for transportation by air.

Note: Backups: Alternate method of mobilization and transport of the Capping Stack System by vessel from the OSRL base in Angra dos Reis, Brazil. Alternate method of mobilization and transport of the SIRT by air from the OSRL base in Angra dos Reis, Brazil.

8.1.1 Logistics Organization

The Logistics Section provides an important aspect of managing resources for the entire incident response. The Logistics section is responsible for the timely and cost-effective procurement, delivery and staging of essential response resources, including: personnel, equipment, supplies, materials and 3rd party contractors to conduct, support and sustain IMT operations for the duration of the incident response. The Logistics Section is also responsible for the efficient support of the response. Responsibilities may include offshore logistics (vessel, aircraft, cargo, and personnel movements), procurement (purchasing, contracting), and administration (catering, accommodation, travel).

8.1.2 Freight Forwarder

The designated freight forwarder is a company that is familiar with source control equipment and requirements, has an emergency response structure that can be activated upon notification of an incident, and is authorized to work with Shell in the Nova Scotia region. A freight forwarder will be responsible for:

1) creating an initial end-to-end survey for transporting capping stack and intervention toolkit,


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2) participating in drills as requested, 3) maintaining contracted emergency response readiness and 4) is capable of the full scope of source control transportation (including: assist OSRL in initial packing and export formalities, air charter, assist in sea charter and associated heavy lifts, lashing plan, marine warranty sign-off, insurance sign-off, route planning, transportation, assist with import formalities, road transport, unpacking and other movement at destination. In short, everything that is described as the responsibility of “incident owner” in OSRL documentation)

The freight forwarder should work in conjunction with the Logistics Section to ensure Source Control equipment, materials and personnel arrive safely and efficiently at the incident site. An initial Capping Stack logistics survey has been performed by JAS Forwarding and is available here. Capping stack equipment summaries can be found in the Capping Stack procedure. Vessel selection assistance is provided by Trendsetter Response360, the procedure of which can be found in the Capping Stack procedure and here. Freight forwarder required scope is listed here


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8.2 Source Control Equipment and Mobilization (General Guidelines)

A key mission of the Logistics Section is to: • Coordinate the transportation of all source control equipment. • Identify transportation requirements for chartering vessels and aircraft. • Ensure response vessels and aircraft comply with Canadian customs and immigration

requirements. • Charter vessels for light intervention operations. • Charter vessel for transport of assembled capping stack system and all other Container

Carrying Teams and loose lifts from handover point. • Charter vessels required for recovery of SWIS equipment. • Provide procurement and contracting services to enable the efficient and time-critical

mobilization and movement of response resources and equipment.

8.2.1 Transportation Requirements

The following information outlines specific requirements for transportation and operations resources to support source control operations.

Light Intervention Vessel Requirements

Supported Mission Requirement

Survey and Assessment

1x Light Intervention Vessel

BOP Intervention 1x Light Intervention Vessel

Subsea Dispersants 1x Light Intervention Vessel with onboard tankage for dispersants

Debris Clearance 1x Light Intervention Vessel with 50 t heave-compensated crane

Recommended Light Intervention Vessel Specifications

Vessel Type: UT722L or similar vessel

Active Heave Compensation Crane

50T

ROV 2x Class III Work Class and associated equipment

Max POB 42

Clear deck area 225 m2


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Usable deck area 320 m2

Standard Crewing 16 Marine / 12 ROV

Maximum Lifting Requirements Weight (air/water) kgs

BOP Intervention System Subsea Accumulator, Suspended

28000/25000

Debris Clearance Chopsaw 60in

690/88

Subsea Dispersants Rack for Flying Leads

4000/3600

Capping Stack System Vessel Requirement

Supported Mission Requirement

Capping Stack Intervention

1x construction vessel or AHTS sufficient to deploying subsea equipment to depth

References: Chapter 8.0, Incident Vessel Selection, (SWR-TE-UA-PRO-00019) Mobilisation & Deck Procedure 18in CS Chapter 1 and 2, Worldwide Emergency Response Equipment General Installation Procedure (OSRL 0903)

Capping Stack System Vessel Recommended Specifications

General • Medium Construction Type vessel • Dynamic Positioning system (DP2/DP3) • Recognized International Association of Classification Society organization class • IMO / SOLAS class • Helideck – S92 certified • Accommodations – Minimum 50-POB


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• Work Class ROV / LARS system

Marine Systems • Anti-roll System • Independent reference system (HiPap / Fan-beam) • 2x 10 ton deck tuggers • Optional 5 m x 5 m moon-pool

Vessel Deck • Large work deck • Deck crane (minimum 2 ton) • Deck length— 48.8 m (160 ft) • Clear deck – 740 m2 • Minimum deck loading of 3,905 kg/m2

Subsea equipment deployment system

General: • A-frame

o 250 ton full motion o 7 m reach o 16 m clearance height

• Crane o 250 ton outboard @ 10,000 ft/ 3,000 m (recommended) o 10 m reach

Heave Compensation Crane option (recommended specs): • Crane line pull: 250 tons at depth • Deck tuggers: 4 to 6 • Deck space: 743 m2 (8000 ft2) • Deck length: 48.8 m (160 ft) Straight wire and HCLS option (recommended specs): • Winch capacity: Dual drum capacity, 7000 ft x 3-1/2 in. wire

each • Winch line pull: 300 tons • Chain locker (minimum of two lockers): 3000 ft x 3-1/4 in.

per locker • Chain welp: 2x 3 in or 2x 3-1/4 in. • Stern roller: 3 m (10 ft) diagonal x 3.7 m (12 ft) long • Shark jaws/kam forks: Dual flush mounted with visual locking

verification (300 ton) • Pop-up pins: 4 inboard/ 2 outboard


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As per Mobilisation & Deck Procedure 18in CS (SWR-TE-UA-PRO-00019), the following tasks shall be performed in selection of a suitable vessel for transportation of the Capping Stack System (CSS):

Step Description

1 Complete vessel survey, determine the deck is a suitable dimension to store all the equipment required offshore and that the deck and its substructure is capable of taking the loads imparted into it by the equipment. Note: Consideration should be made to routes around the equipment, access into and on the equipment, cabling and hoses on deck. Also the routes by which the subsea equipment is to be offloaded during installation and escape routes for those handling the loads during these operations.

8.2.2 Subsea Well Intervention System (SWIS) Mobilization

Mobilization of SWIS resources must be coordinated between the Source Control Branch, Freight Forwarder and the Logistics Section. This will require a designated agent to deploy to the primary SWIS mobilization site in Stavanger, Norway, to receive the Subsea Intervention Toolkit and Capping Stack System on behalf of Shell Canada. • Oversee the handling and transportation of the SWIS equipment from handover point to well

site. • Coordinates export documentation and lifting services with OSRL for delivery at quayside or

at mobilization airport. • Upon completion of CSS on-site testing conducted by Trendsetter Engineering at OSRL

mobilization point, receives complete CSS on behalf of Shell and completes acceptance documentation. Confirms configuration of CSS interface prior to testing.

• Coordinates delivery of secondary CSS transportation skid onto delivery vessel and ensures completion of sea fastening plan which complies with OSRL documentation.

• Authorized to sign OSRL form to transfer custody of the CSS from OSRL to Shell.

8.2.3 OSRL Subsea Incident Response Toolkit Movements

Figure 9 depicts the mobilization and handover process for the Subsea Intervention Response Toolkit (SIRT) by air. This is the preferred method of shipment of the SIRT from the OSRL Stavanger base.


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Fig. 9 SIRT Mobilization Process

The OSRL SIRT is activated and mobilized by the IMT HSE & Liaison Officer by completing the following forms. Figure 9 depicts outlines the SIRT Mobilization Process.

• OSRL Mobilization Authorization (OSRL 025) • OSRL Notification Forms (OSRL 027) • SWIS Equipment Selection form (OSRL 831) • SWIS Deployment Indemnity form (OSRL 0829)


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Step Activity Activity Type Delivery Method

Accountable/Responsible

1. Confirm completion of following forms: OSRL 025: Authorization OSRL 027: Notification OSRL 831: Equipment Selection OSRL 0829: Indemnity

Document Email Operations

2. Notify freight forwarder to mobilize freight forwarding service at Norway

Notify Phone Source Control Branch

3. Confirm that freight forwarder has developed lifting plan to onload SIRT to aircraft

Develop Procedure Logistics/OSRL

4. Onload SIRT onto truck at OSRL Oceaneering Base in Stavanger

Move Crane Logistics/OSRL

5. Transport SIRT to Stavanger Airport

Move Truck Logistics/OSRL


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6. Offload SIRT onto Cargo aircraft

Move Crane Freight Forwarder

7. Complete cargo lashing onboard aircraft

Move Cargo handling service

Freight Forwarder

8. Complete export paperwork

Document OSRL SWIS MU/OSRL

9. Transport SIRT from Stavanger Sola Airport to Halifax Stanfield International Airport

Movement Air Freight Forwarder/Logistics

10. Complete import paperwork for entry into Canada

Documentation Logistics/Shell contracted importer

11. Offload SIRT from aircraft

Movement Freight Forwarder

12. Transport SIRT from airport to staging port

Movement Truck Freight Forwarder

13. Offload SIRT from truck to warehouse or quay

Movement Crane Freight Forwarder

Mobilize OSRL Subsea Dispersant Kit from warehouse to Woodside Staging Port

Step Activity Activity Type Method Accountable Sign off

1. Identify suitable Light Intervention Vessel for Subsea

Notification Phone Subsea dispersant task force


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Dispersant Mission

2. Charter vessel Notification Phone Logistics

3. Mobilize flexible hose system or CTU

Notification Phone Subsea Dispersant Task Force

4. Transport initial approved STA/dispersant load from warehouse to Light Intervention Vessel

Movement Truck Logistics

5. Offload approved STAs for staging at Woodside

Movement Crane Logistics

6. Transport flexible hose or CTU system to Woodside

Movement Truck Logistics

7. Activate marine surveyor

Notification Phone Logistics

8. Provide marine surveyor with technical specifications of all dispersant equipment for sea fastening

Notification Email Subsea Dispersant Task Force

9. Develop sea fastening procedures for SIRT equipment onboard Light Intervention Vessel

Design Procedure Logistics


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10. Transport SIRT to Woodside Marine Base

Movement Truck Freight Forwarder

11. Offload SIRT to Woodside Marine Base for staging

Movement Crane Freight Forwarder

12. Complete sea fastening onboard Light Intervention Vessel

Procedure Procedure Logistics/Freight Forwarder


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The following tasks will be completed by the SWIS Mobilization agent/Freight Forwarder and while overseeing the mobilization of OSRL resources at the OSRL Base.

Figure 10 – CSS Mobilization by Sea

Step Description Accountable 1. Brief Mobilization Team by Team Leader

References: OSRL 870 – Capping Stack Handover Procedure – Sea OSRL 1071 – Subsea Dispersant Toolkit Handover Procedure – Air

Agent

2. Confirm call out of emergency response services for: • Freight Forwarding (Freight Forwarder) • Customs Facilitation (Shell) • Immigration (Shell) • Marine Surveyor (Freight Forwarder) • CSS Technical Testing (Trendsetter Engineering via OSRL) • CSS Tactical Response Services (Trendsetter Engineering) • Craneage to delivery Capping Stack System to vessel at

quayside (Freight Forwarder) • Surface Transportation in Halifax (Freight Forwarder)

Freight Forwarder

3. Confirm Freight Forwarder has reviewed and approved SIRT aviation lifting and loading plans References: OSRL 1035 SIRT Packing and Preparation Manual

Freight Forwarder


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4. Initiate delivery of spare CSS shipping skid to CSS delivery vessel or deliver skid to vessel quayside in Tananger

Freight Forwarder

5. Confirm delivery of CSS shipping skid to CSS vessel Freight Forwarder

6. Notify and activate Marine Surveyor and provide Sea Fastening Procedures and vessel identification to Marine Surveyor References: SWR-TE-UA-REP-00106 Sea Fastening for Capping Stack Sea Fastening SWR-TE-UA-PRO-00019 Mobilization and Deck Procedure 18 in. CS

Freight Forwarder and vessel owner

7. Confirm marine surveyor provide Sea Fastening Plan to CSS delivery vessel References: SWR-TE-UA-PRO-00019 Mobilization and Deck Procedure 18 in. CS

Freight Forwarder and vessel owner


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8. Provide SIRT Lifting and Loading Plans to Freight Forwarder References: SIRT Combined Packing Lists OSRL 1828 BOP Intervention System OSRL 1829 Debris Clearance OSRL 1830 Dispersant System

Freight Forwarder

9. Logistics personnel travel to OSRL mobilization point Logistics

10. Validate export paperwork is complete. References: OSRL 0860 Customs export guidelines Norway

OSRL and freight forwarder

11. Complete SIRT handover form References: OSRL 1072Subsea Intervention Response Toolkit Handover

Logistics

12. Provide Nordic Crane with CSS Lifting Procedures References: OSRL 1548 18 Inch Capping Stack Lift Test Procedure

Freight Forwarder and Logistics

13. Review and approve lifting plans and crane and wire test of Nordic Crane equipment

Freight Forwarder

14. Review and approve CSS test results from OSRL/Trendsetter Engineering. Confirm CSS stack and interface configuration.

Trendsetter/Shell


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15. Complete CSS Norway export paperwork References: Customs export guidelines Norway OSRL 0860 Customs export Guidelines

OSRL and Freight Forwarder

16. Confirm approval of following documents: • Capping Stack System function and pressure testing • Capping Stack System configuration • Capping Stack System Lifting plans • Vessel sea fastening plans • Customs clearance paperwork for export of Capping Stack

System from Norway • Complete OSRL Handover Form: References: OSRL 0872 Capping Stack Handover Form

Shell SURF

17. Transfer Capping Stack System to Shell and verify on load of system to delivery vessel.

Shell SURF

18. Team return travel to Halifax to assist in response operations. Shell SURF


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8.2.4 Procurement Unit

Under the Finance Section Chief, responsible for providing supply chain, including purchasing, receiving, and inventory activities of the source control mission. • Assist in execution of the Freight Forwarder Logistics Plan • Supply Source Control Branch material requirements • Coordinate supply, storage, and resupply of approved STAs. • Provide top-side equipment required for dispersant application. • Supply fluids, nitrogen and compression for charging of accumulators. • Inventory and maintain accountability for all source control equipment, from and to

mobilization point.

Reference (below are listed various local options for Source Control services that may be utilized at the discretion of the ICS organization)

Aviation Transportation

Vendor Description Supported Mission

Contact information: Shell Lead

Freight Forwarder

Freight forwarding; licensed IATA agent; dedicated aircraft charter service

All source control

NA Logistics

Offshore passenger and cargo helicopter operations

Capping Missions

NA Logistics


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Charging Systems

Vendor Options Description Supported Mission


IKM Testing – Canada

Nitrogen for pre-charging 6x100 gal accumulator bottles

BOP Intervention

Phone: <Redacted> Fax: <Redacted> Address: <Redacted> E-mail: <Redacted> Website: <Redacted>

Category Manager, Operations and Subsea

Baker Hughes Nitrogen for pre-charging 6x100 gal accumulator bottles

BOP Intervention

Phone: <Redacted> Address: <Redacted>


Customs, CTA, Immigration Services



PF Collins Contract number 8.5.3.023, effective to 16October2015

Customs brokerage, consulting

All source control missions

Phone: <Redacted> Fax: <Redacted>Mobile Number: <Redacted> Address:<Redacted> Email: <Redacted> Website: <Redacted> Duty schedule: <Redacted>

Category Manager, Marine & Logistics

Dispersants



Oil Spill Response

Corexit EC9500A

Subsea Dispersants

Phone: <Redacted> Fax: <Redacted>

Environm-ental Lead


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Limited Finasol OSR 52 Dasic Slickgone NS

<Redacted> Email: <Redacted>

Environmental Monitoring Equipment



EnviroMed Detection Services

Vessel mounted gas monitoring equipment

Capping Group

Phone: <Redacted> Fax: <Redacted>Toll Free: <Redacted>Address: <Redacted>Email: <Redacted> Website: <Redacted>

HSEQ Environm-ental Advisor


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Fluid Pumping Systems



Baker Hughes Downline, chemical injection systems

Subsea Dispersants

Phone: <Redacted> Address: Baker Hughes 20 Kyle Ave Mt Pearl, NL A1N 4R5 Canada


Schlumberger Coiled Tubing Services

Subsea Dispersants

Phone: <Redacted> Fax: <Redacted> Address: 2 Panther Place Mount Pearl, Newfoundland, A1N 5B Canada


Schlumberger Dispersant Pumps

Subsea Dispersants

Phone: <Redacted> Fax: <Redacted> Address: 2 Panther Place Mount Pearl, Newfoundland, A1N 5B Canada


Hydraulic Fluids



Hyflodraulic Limited

Stack Magic (or similar fluid) to charge the Subsea

BOP Intervention

Phone: <Redacted> Fax: <Redacted> 48 Clyde Avenue Donovan’s Industrial



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Accumulator bottles

Park Mount Pearl, NF A1N 4S1 Email: <Redacted> Website: http://www.hyflodraulic.ca/contact/contact.html

Hyflodraulic Limited

Mineral Oil Tellus 22 (or similar hydraulic fluid) for refilling the Hydraulic Power Team

Debris Clearance

Phone: <Redacted> Fax: <Redacted> 48 Clyde Avenue Donovan’s Industrial Park Mount Pearl, NF A1N 4S1 Email: <Redacted> Website: http://www.hyflodraulic.ca/contact/contact.html


Lifting Services



Nordic Crane Heavy lift services quayside to vessel


Phone: <Redacted> Address: Nordic Crane Stangeland AS Sandnesvegen 80, N-4050 Sola Website: http://www.nordiccrane.com/?selskap=nordic-crane-stavanger-2


Harvey Specialized BOP Phone: <Redacted> Category


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http://www/

http://www.nordiccrane.com/?selskap=nordic-crane-stavanger-2




offshore trucking services

Intervention, Subsea Dispersants, Debris Clearance

Fax: <Redacted> Address: Pier 14, 71 Water St., St. John’s, NL A1C 1A1 E-mail: [email protected] Website: http://www.aharvey.com/marine/

Manager, Marine & Logistics

Marine Surveyors



DNV GL Marine assurance, sea fastening plans for vessel mounted CSS transportation skid


Phone: <Redacted> Telephone: <Redacted> Fax: <Redacted> Address: 504-215 Water St Atlantic Place, St. John’s, Newfoundland and Labrador A1C 6C9 Email: [email protected] Website: http://www.gl-group.com


Remotely Operated Vehicles

ROV Requirement

Supported Mission

Requirement


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mailto:[email protected]


http://www.aharvey.com/marine/

http://www.aharvey.com/marine/



http://www.gl-group.com/

http://www.gl-group.com/


Capping Group ROV Services: 7x Class III Work Class ROVs and 1x Class I Observation ROVs

References: Chapter 3.4. Worldwide Emergency Response Equipment General Installation Procedure (SWR-TE-UA-PRO-00032)

Vendor Description Supported Mission


ROV Services Capping Group

Phone: <Redacted> Address: 23 Dundee Ave, Mount Pearl NL A1N 4R6 Website: http://www.oceaneering.com/

Category Manager, Offshore D&C

Subsea 7 ROV services Capping Group

Phone: <Redacted> Fax: <Redacted> Address: 351 Water Street, 6th Floor, St. John’s, NL A1C 1C2 Website: http://www.subsea7.com/en/contacts/offices.html

Category Manager, Offshore D&C

Recommended ROV Functional Specifications

General • Rate working depth of 10,000’ / 3000 m • Dual 7 function manipulators • Hi resolution sonar • Depth sensor • Altitude sensor • High intensity light

Thrusters • Forward – 1,500 lbs / 680 kg • Reverse – 1,200 lbs / 475 kg • Lateral – 1,000 lbs / 450 kg • Vertical – 1,000 lbs / 450 kg

Video Systems • Color Video • Black and white video • Manipulator mounted video (optional)


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http://www.oceaneering.com/

http://www.subsea7.com/en/contacts/offices.html



• Digital still capture • Digital video recording system

LARS • Self-contained – mobile built-in systems

Other Specifications • Work van • Control Van • Minimum recommended tooling compliment • 2 x API-17D Dual Port Hot stab • 2 x API-17H Dual Port Hot stab • Hi flow hot stab • Class 4 Torque tool • Torque tool test jig • 2 x 5 gallon hydraulic reservoirs • Raw water pump – 200 bar @ 20 lpm • Methanol injection skid • 10k Hydraulic intensifier • Dredge / Jet Pump • Gasket cleaning tool • ROV hooks – assorted sizes • ROV shackles – assorted sizes

Subsea Intervention Equipment



Pennecon Energy Services

Locally maintained BOP Intervention Skid

BOP Intervention

Phone: <Redacted> Fax: <Redacted> Address: 22 Sudbury Street St. John’s, NL A1E 2V1 Email: [email protected] Website: http://www.pennecon.com/Energy/ContactInfo


OSRL OSRL Subsea Well

Capping Corporate: Category Manager,


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http://www.pennecon.com/Energy/ContactInfo



Intervention System, including: BOP Intervention Toolkit, Dispersant Toolkit, Debris Clearance Toolkit, and Capping Stack System

Group Phone: <Redacted> Fax: <Redacted> Address: Lower William Street Southampton SO14 5QE United Kingdom Email: [email protected] SWIS Norway Phone: <Redacted> Address: Risavika Havnering 235, Postboks 250 4098 Tananger, Norway Email: [email protected] Website: http://www.oilspillresponse.com/contact-us

Operations and Subsea

Technip Canada Ltd.

Down line to operate debris clearance tools

Capping Group

Phone: <Redacted> Switchboard: <Redacted> Fax: <Redacted> Mobile: <Redacted> Address: 131 Kelsey Drive, St. John’s, NL A1B 0L2 Website: www.technip.com


Pennecon Energy Services

Down line to operate debris clearance

Debris Clearance

Phone: <Redacted> Fax: <Redacted> Address: 22 Sudbury Street



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http://www.oilspillresponse.com/contact-us

http://www.oilspillresponse.com/contact-us

http://www.technip/


tools. St. John’s, NL A1E 2V1 Email: [email protected] Website: http://www.pennecon.com/Energy/ContactInfo

Fugro Geosurveys

Location beacons for CTTH and Subsea Manifold

Subsea Dispersants

Phone: <Redacted> Fax: <Redacted> Address: 25 Pippy Place St. John’s, NL A1B 3X2 E-mail:[email protected] Website:www.fugro.com



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Technical Services



Trendsetter Engineering, Inc.

Source control planning, Capping Stack System Tactical Response Team support

Capping Group

Phone: <Redacted> Address: 10430 Rodgers Road, Houston, Texas 77070 Website: http://www.trendsetterengineering.com/engineering-services/


Addenergy Modeling; Surface Gas Dispersion, In-Water Plume Analysis, WCD

Capping Group

Phone: <Redacted> Fax: <Redacted> Address: 19500 State Hwy 249, Suite 110, Houston, TX 77070, USA Email: [email protected] Web: www.addenergy.no


Technip Canada Ltd.

Subsea engineering support services

Capping Group

Phone: <Redacted>Switchboard: <Redacted> Fax: <Redacted> Mobile: <Redacted> Address: 131 Kelsey Drive, St. John’s, NL A1B 0L2 Website: www.technip.com


OneSubsea Oil field services, testing, warehousing services

Capping Group

Phone: <Redacted> Address: 14 Corisande Dr St. John's NL



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http://www.addenergy.no/

http://www.technip/


Surface Transportation Service Providers



Specialized offshore trucking services


Trucking services


Vessel Services



Westshore Arctic

Vessel chartering services

All Source Control Missions

Phone: <Redacted> Address: 106 Water St, St. John’s, NL A1C 1A7 Email: [email protected] Website: http://www.westshore.no/contact/canada


Atlantic Towing Supply and LIV vessel services


Phone: <Redacted> Fax: <Redacted> 24/7 Dispatch: <Redacted> Website:



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http://www.westshore.no/contact/canada


http://www.atlantictowing.com/atlantic-towing-contact-us.aspx

Maersk Supply Service

Supply and LIV service


Phone: <Redacted> Address: 100 New Gower Street Suite 803 St. John’s A1C 6K3 Canada Email: [email protected]


Subsea 7 Construction vessel services


Phone: <Redacted> Fax<Redacted> Address: 351 Water Street, 6th Floor, St. John’s, NL A1C 1C2 Website: http://www.subsea7.com/en/contacts/offices.html


Technip Well service vessels


Phone: <Redacted> Fax: <Redacted> Address: 131 Kelsey Drive St. John’s, NL A1B 0L2 Canada Website: http://www.technip.com/en/entities/canada/contact-us



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http://www.technip.com/en/entities/canada/contact-us




8.3 Source Control Mobilization Points

Figure 11 – Shelburne Basin Source Control Staging Dock

8.3.1 Aviation

Airport – Primary

Airport Name: Halifax Stanfield International Airport (YHZ)

Contact Information: Phone: <Redacted> Fax: <Redacted> Address: Halifax Stanfield International Airport Terminal Building 1 Bell Blvd, Enfield, NS B2T 1K2, Canada

Elevation 476’ (145m)

Latitude 44° 52' 47" N

Longitude 63° 30' 37" W


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Runways 5/23: 3200 m X 61 m (10,500’ x 200’)

Runway 14/32: 2,347 m X 61 m (7,700’ x 200’)

Comments: The airport operates 24/7 with no slot restrictions and no noise restrictions. Twenty-four (24) hour customs service is also available. For those cargo packages that require modes of transportation in addition to air travel, the airport location facilitates this.

SWIS Mobilization Air Base – Primary

Airport Name: Stavanger Sola

Contact Information: E-mail: <Redacted> Telephone: <Redacted> Fax: <Redacted> VHF: <Redacted> VHF: <Redacted> SITA: <Redacted> Address: Aviator Norway, Stavanger Lufthavn, Flyplassvegen 230, 4055 Stavanger

Elevation 29’

Latitude 58.88215N

Longitude 005.629197W

Runways 18/36: 8385 ft X 197 ft

Runway 11/29: 8036 ft x 148 ft


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8.3.2 Marine

Capping Stack System Mobilization Base – Primary

Marine Base Name: Tananger

Reference: OSRL 800 Norway Base Overview

Contact Information:

Base Manager: <Redacted>

Address Hovedkontor Risavika Havnering 235 Postboks 250 4098 Tananger, Norway

General Information

Latitude 58-55.43 N ETA Message Required Yes

Longitude 005-35.24 E Medical Facilities Yes

Water Depth

Channel 76+ ft Anchorage 21-25 ft

Cargo Pier 41-45 ft Oil Terminal 36-40 ft

Pilotage

Compulsory Yes Available Yes

Capping Stack System Mobilization Base – Alternate

Marine Base Name: Angra dos Reis

Reference: OSRL 779 Angra dos Reis Base Overview

Contact Information: Base Manager: <Redacted>

Address: Praça Lopes Trovão s/n Parte 1 Centro – Angra dos Reis/RJ CEP: 23900-490 Brazil 400 /370 88000 m2


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Shell Supporting Marine Base – Primary

Base Name: Woodside Staging Port – Mobil Dock


Address:

1 Atlantic Street Dartmouth, NS

Latitude: 44°38'45.0"N

Longitude: 63°32'46.4"W

Low-tide draft: 6.5m

Shell Supporting Marine Base – Alternate

Base Name: IEL Dock (Woodside Industrial Wharf)


Address:

3 Atlantic Street Dartmouth, NS

Latitude: 44°38'50.0"N

Longitude: 63°32'50.4"W

Low-tide draft: 9m Comments: for use in case deeper draft needed. Available: 250T crane, 2x15T forklifts, 1x6T forklift

8.3.3 Land Transportation Companies

These are coordinated by Shell logistics with assistance as required from Freight Forwarder.


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APPENDIX

Acronyms

CNSOPB Canada-Nova Scotia Offshore Petroleum Board CSS Capping Stack System CTTH Coiled Tubing Termination Head CTU Coil Tubing Unit DVI Detailed visual inspection EDS Emergency Disconnect System ERP Emergency Response Plan GVI General visual inspection ICS Incident Command System IMT Incident Management Team IRM Incident Response Management JSA Job Safety Analysis LEL Lower Explosive Limit LMRP Lower Marine Riser Package OIM Offshore Incident Manager OSC On-Scene Commander OSRL Oil Spill Response Limited ROV Remotely Operated Vehicle SART Shell Americas Response Team SCCP Source Control Contingency Plan SDM Subsea Dispersant Manifold SIMOPS Simultaneous Operations SIRT Subsea Intervention Response Toolkit SME Subject Matter Expert SURF Subsea Umbilicals, Risers and Flowlines SWIS Subsea Well Intervention System TEI Trendsetter Engineering VOC Volatile Organic Content WCVERT Well Control Virtual Response Team


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