Subsea Well Control for Drilling Operations

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Canada-Newfoundland and Labrador

Offshore Petroleum Board

Subsea Well Cont rol for Dr il ling

Operat ions and Oil Spi llReadiness

C-NLOPB Technical Br ief ing forMedia June 2, 2010


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Legislat ive Requirement s

Regulations Drilling and Production Regulations Certificate of Fitness Oil and Gas Debris and Spills Liability

Petroleum Installations

Guidance Drilling and Production Guidelines

Drilling Programs Safety Plans Incident Reporting and Investigation Environmental Protection Plan Physical Environmental Programs Data Acquisition and Reporting Financial Responsibility Requirements

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Environmental Assessment

Strategic Environmental Assessment

Conducted by C-NLOPB prior to issuing exploration

licences Reviewed by federal and NL agencies, including

fisheries, environment

Draft report published for public comment Report available on C-NLOPB Web site

Includes overview of blowout risk and consequences

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Environmental Assessment

Project Specific Environmental Assessment

Conducted in accordance with Canadian EnvironmentalAssessment Act

Documents published on C-NLOPB Web site in near-realtime

Assessment documents reviewed by staff of C-NLOPB,

environment and fisheries agencies of federal and NLgovernments

Includes potential effects due to accidental events,

including blowouts

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Traj ectory ModelResult s: Orphan Basin

From original assessmentusing typical basin releasepoint

Model simulate onerelease per day for 40years using actual wind

data No trajectories reached

shore

Figure indicates area with

> 1% probability ofhaving oil present overthis period

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Aut horizat ion Requirement s

Operations Authorization (OA) Safety Plan Environmental Assessment Environmental Protection Plan

Contingency Plans Offshore and Onshore Emergency Response Plans Oil Spill Response Plan Ice Management

Relief Wells Certificate of Fitness Operators Declaration of Fitness Letter of Compliance Financial Responsibility C-NL Benefits Plan

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Approval Requirement s

Approval to Drill a Well (ADW) Formation Pressure and Fracture Gradient Evaluation

Barrier analysis to confirm two barriers at all times

Casing Program Cementing Program

Drilling Fluids

Casing and Wellhead Pressure Testing

Formation Leak-Off Tests

BOP Configuration

BOP Pressure and Function Testing

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Safet y Plans

Hazard Identification Risk Management

Training and Competency of Personnel

Details of Systems and Equipment, includingMaintenance/Inspection/Testing

Operational Procedures and Processes

JOHSC Incident Reporting and Investigation

Management Oversight/Monitoring

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Oversight of Dr il ling Operat ions

At Operations Application Level

At ADW Submission/Review

During Operations Daily Drilling, Geologist and Log Reports

Reviewed by a number of C-NLOPB Staff

Copies provided to NL Dept of Natural Resourcesfor Exploration and Delineation Wells

Inspections

Audits

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Offshore Petroleum Board10


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Format ion Pressures

Abnorm al Form at ion

Pressure

Normal FormationPressure = Hydrost atic

Gradient of Wat er

Hydrost at ic Pressure

of Mud

Normal Pressure Gradient

Onshore: 9.8 kPa/ m

Off shore: 10.25 kPa/ m

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Well Barr iers

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BOP Specif ic Requirement s

BOP Stack Configuration and Operating Limits

Capacity and Redundancy in BOP Control System

Deepwater considerations

Hydrates

Cold Temperature

Pressure and Function Test Procedures and Frequency

Test Verification via review of Daily Report Informationand records review during Audits

Modes of Activation

1 of 3 backup systems in shallow water (anchoredvessel)

2 of 3 systems in deep water (dynamically positioned

vessel)

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Riser Specif ic Requirements

Drillsite specific Riser Analysis and Weak PointAssessment

Riser Margin

Emergency and Planned Disconnect Procedures

Drift-Off Management

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Stena Carron

Dual-mast, ultra-deepwater,dynamically-positioned drillship

Drilling water depth of 10,000 ft

Total drilling depth of up to35,000 ft

3 backup systems for BOPactivation

Length of 748 ft.

Variable Deck Load: 15,000tonnes

Maximum P.O.B.: 180 Man

Accomodation

3 Electric HydraulicKnuckleboom Cranes

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Stena Carron - BOP Stack

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Sample Relief Well Dr il ling Program

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Source: htt p:/ / w w w .deepwat erhorizonresponse.com/ go/ doctype/ 2931/ 54691/ HorizonMay 24, 2010 Update


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I RF and NSOAF Best Pract ices

International Regulators Forum CNLOPB part of IRF

IRF committee activity Upcoming IRF conference (program changes) and IRF

meeting

North Sea Offshore Authorities Forum Wells WorkingGroup Well Operations Engineering meeting in Norway

Member country responses to GoM (not enough infoavailable to define immediate and root causes aboutwhat happened)

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BOP Back-up Systems on Mobile

Dr ill ing I nst allat ions in NL Offshore Stena Carron

ROV intervention

Automode Function

Acoustic System

GSF Grand Banks ROV intervention

Henry Goodrich ROV intervention

Henry Goodrich

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Product ion I nstallat ions

Drilling activity regulated same as

exploration wells Different systems in place for production

Two Barriers Production Tree

Downhole Safety Valve

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Operators Responsible forEmergency Response

Lead government agency for

dril l ing, product ioninstallat ions on sit e, e.g.: Hibernia, Terra Nova, White

Rose production platforms,subsea installations, loading

systems Drilling units on site (e.g., StenaCarron at Lona O-55)

Resource agency in all ot hercases, e.g.: Drilling unit off-site Supply vessels Shuttle tankers

C-NLOPB Spil l Response Role

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Accord Act paragraph 46 (1) :

The Board shall, t o ensure eff ect ive coord inat ion and avoidduplicat ion of w ork and act ivit ies, conclude w it h t he

appropr iate depart ments and agencies . . . Memoranda ofunderstanding in relat ion t o (a) environmental regulat ion; (b)emergency measures; . . . and ( f ) such other mat ters as areappropriate.

I nt eract ion w it h Other Agencies

MOUs concluded in late 1980s with environment,fisheries, energy departments of Canada & NL

Environment MOU acknowledges and cites the roleof Regional Environmental Emergency Team(REET)

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Formed by federal Cabinet directive following 1970Arrowtankerspill

REET provides consolidated environmental advice to leadagency and/or incident command

Chaired by Environment Canada

Members from federal, provincial agencies with environmentalemergency related responsibilities

Separate REET in each region of Canada

Each REET meets annually in workshop mode

REET can be activated in an emergency, with active participantsdrawn from membership

Regional Environment al Emergencies

Team (REET)

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S ill R R i t


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All spills prohibited Contingency plans required

- Also annual field countermeasures exercise

Operator must report spills to C-NLOPB

Operator must take all reasonable measures to respond to andmitigate spill

Operator financially responsible for all actual loss or damage resulting

from spill- Up to prescribed limit, without proof of fault or negligence

- Unlimited liability where fault or negligence proved

C-NLOPB Chief Conservation Officer has authority to intervene inresponse

Spi l l Response Requirement s

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Financial Responsibili t ies

Requirements

Polluter Pays (Clean-up and Compensation)

$30 M direct access $70 M available

$250 M financial capability

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Spil l Response Typical


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Tiered Response St ruct ure Tier 1: In-field / at-site resources

Tier 2: NL / regional resources (e.g., ECRC, CCG NL) Tier 3: National/international resources (e.g., OSRL)

Comm and/ Cont rol St ructure

Communicat ions/ Not if icat ion Procedures I dent if icat ion of Resource Personnel and

Organizations

Provision for Personnel Training Resource Sharing Arrangement s w it h Other

Operators

Spil l Response TypicalPlanning Element s

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Oil Spill Response: Tier 1

All Support Vessels: Exploration and Production

100+ m Sorbent Boom

GPS/Satellite spill tracking buoys Spill sampling kit

In-Field Resources, Each Production Site

Single-Vessel Side Sweep (SVSS) system

60 m of 2.1m boom

Weir skimmer [100 m3/hr capacity (15,000 bbl/d)]

Outrigger arm

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Tier 1: Exploration and ProductionSorbent Boom System

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Tier 1: Product ion


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Single-Vessel Side Sw eepSystem

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Oil Spi l l Response: Tier 2 and 3

Tier 2: Regional Capacity ECRC Donovans - available 24/7/365

CCG Donovans - available 24/7/365

LargeCapacity Skimmer Systems Transrec 150 and 200 at ECRC, CCG

53,000 bbl/d fluid throughput each

Unsheltered-Waters Boom Systems

400 m Norlense 3.4 m boom (at ECRC) 370 m NOFI 2.4 m boom (at ECRC)

Tier 3 Canada, International Example: OSRL depot in Southampton, UK

Capable of responding anywhere in the world via cargo aircraft

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Tier 2: Explorat ion and Product ion


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Norlense Boom

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Tier 2: Explorat ion and Product ion


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Tier 2: Explorat ion and Product ionTransrec Skim mer System

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I f t i Di l


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I nformat ion Disclosure

Public Disclosure of Information

Oil Spill Tombstone Data

Per incident, for spills >1 liter*

Quarterly, for spills


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www.cnlopb.nl.ca

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Subsea Well Control for Drilling Operations

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