John Hollowell – Deepwater operations

ROYAL DUTCH SHELL PLC

INVESTING FOR SUSTAINABLE GROWTH

1 Copyright of Royal Dutch Shell plc 29 November 2011

HOUSTON/SHREVEPORT

November 2011

JOHN HOLLOWELLEXECUTIVE VICE PRESIDENT DEEPWATER

DEFINITIONS AND CAUTIONARY NOTE

Resources: Our use of the term “resources” in this presentation includes quantities of oil and gas not yet classified as SEC proved oil and gas. Resources are consistent with the Society of Petroleum Engineers 2P and 2C definitions.

The companies in which Royal Dutch Shell plc directly and indirectly owns investments are separate entities. In this presentation “Shell”, “Shell group” and “Royal Dutch Shell” are sometimes used for convenience where references are made to Royal Dutch Shell plc and its subsidiaries in general. Likewise, the words “we”, “us” and “our” are also used to refer to subsidiaries in general or to those who work for them. These expressions are also used where no useful purpose is served by identifying the particular company or companies. ‘‘Subsidiaries’’, “Shell subsidiaries” and “Shell companies” as used in this presentation refer to companies in which Royal Dutch Shell either directly or indirectly has control, by having either a majority of the voting rights or the right to exercise a controlling influence. The companies in which Shell has significant influence but not control are referred to as “associated companies” or “associates” and companies in which Shell has joint control are referred to as “jointly controlled entities”. In this presentation, associates and jointly controlled entities are also referred to as “equity-accounted investments”. The term “Shell interest” is used for convenience to indicate the direct and/or indirect (for example, through our 24% shareholding in Woodside Petroleum Ltd.) ownership interest held by Shell in a venture, partnership or company, after exclusion of all third-party interest.

This presentation contains forward-looking statements concerning the financial condition, results of operations and businesses of Royal Dutch Shell. All statements other than statements of historical fact are, or may be deemed to be, forward-looking statements. Forward-looking statements are statements of future expectations that are based on management’s current expectations and assumptions and involve known and unknown risks and uncertainties that could cause actual results, performance or events to differ materially from those expressed or implied in these statements. Forward-looking statements include, among other things, statements concerning the potential exposure of Royal Dutch Shell to market risks and statements expressing management’s expectations, beliefs, estimates, forecasts, projections and assumptions. These forward-looking statements


Dutch Shell to market risks and statements expressing management’s expectations, beliefs, estimates, forecasts, projections and assumptions. These forward-looking statements are identified by their use of terms and phrases such as ‘‘anticipate’’, ‘‘believe’’, ‘‘could’’, “scheduled”, ‘‘estimate’’, ‘‘expect’’, ‘‘goals’’, ‘‘intend’’, ‘‘may’’, ‘‘objectives’’, ‘‘outlook’’, ‘‘plan’’, ‘‘probably’’, ‘‘project’’, ‘‘risks’’, ‘‘seek’’, ‘‘should’’, ‘‘target’’, ‘‘will’’ and similar terms and phrases. There are a number of factors that could affect the future operations of Royal Dutch Shell and could cause those results to differ materially from those expressed in the forward-looking statements included in this presentation, including (without limitation): (a) price fluctuations in crude oil and natural gas; (b) changes in demand for Shell’s products; (c) currency fluctuations; (d) drilling and production results; (e) reserves estimates; (f) loss of market share and industry competition; (g) environmental and physical risks; (h) risks associated with the identification of suitable potential acquisition properties and targets, and successful negotiation and completion of such transactions; (i) the risk of doing business in developing countries and countries subject to international sanctions; (j) legislative, fiscal and regulatory developments including regulatory measures addressing climate change; (k) economic and financial market conditions in various countries and regions; (l) political risks, including the risks of expropriation and renegotiation of the terms of contracts with governmental entities, delays or advancements in the approval of projects and delays in the reimbursement for shared costs; and (m) changes in trading conditions. All forward-looking statements contained in this presentation are expressly qualified in their entirety by the cautionary statements contained or referred to in this section. Readers should not place undue reliance on forward-looking statements. Additional factors that may affect future results are contained in Royal Dutch Shell’s Annual Presentation / Form 20-F for the year ended December 31, 2010 (available at www.shell.com/investor and www.sec.gov ). These factors also should be considered by the reader. Each forward-looking statement speaks only as of the date of this presentation, 29 November 2011. Neither Royal Dutch Shell nor any of its subsidiaries undertake any obligation to publicly update or revise any forward-looking statement as a result of new information, future events or other information. In light of these risks, results could differ materially from those stated, implied or inferred from the forward-looking statements contained in this presentation.

We may have used certain terms in this presentation that United States Securities and Exchange Commission (SEC) strictly prohibits us from including in our filings with the SEC, such as resources and oil in place. U.S. Investors are urged to consider closely the disclosure in our Form 20-F, File No 1-32575, available on the SEC website www.sec.gov. You can also obtain these forms from the SEC by calling 1-800-SEC-0330.

DEEPWATER DEVELOPMENT HISTORY

2011Tobago


Development concept

MARS-B (GULF OF MEXICO) BC-10 PHASE 2 (CAMPOS, BRAZIL)

GROWTH DELIVERY

DEEPWATER UNDER CONSTRUCTIONCARDAMOM (GULF OF MEXICO)

Phase 1 FPSO Surface System and Subsea View


� TLP design capacity ~100 kboe/d

� West Boreas + South Deimos

� Water depth 950 meters

� Shell 72% (operator)

� Expected peak production ~30 kboe/d

� Argonauta O-North field

� Water depth 1,600 meters


� Expected peak production ~50 kboe/d

� Tie back to Auger platform

� Water depth 830 meters


Part of >250 kboe/d deepwater production under construction

PROGRESS IN GULF OF MEXICO

Cardamom Deep�Auger TLP extended reach

W. Boreas, S. Deimos�>150 million boe resources� Tie-back to Mars B�Shell 72% (operator)

Mars B� FID for new TLP, Shell 72% (operator)

�~100 kboe/d

Vito �>200 million boe resources�~100 kboe/d potential�Shell 55% (operator)

Brutus

NakikaMars

UrsaAuger

SHELL GOM DEEPWATER PRODUCTION

0

250

500

'15+0

250

500

'94 '98 '02 '06 '10

Kboe/d


SHELL LEASEHOLD

�Auger TLP extended reach discovery & appraisal

�> 100 million boe resources�50 kboe/d�Shell 100% (operator)

Stones�Assessing development options�Shell 35% (operator)

NEW HUB EXISTING PRODUCTION HUB

Caesar/Tonga�~50 kboe/d�2009 FID�Shell 22.5%

Perdido

Appomattox�~100 kboe/d hub potential �> 250 million boe resources�Shell 80% (operator)

2010 production ~230,000 boe/d

>250,000 boe/d new potential for Shell

Brutus

Holstein

Auger

0 200 KM

CURRENT RIG LOCATIONS

50

100

Kboe/d

SEISMIC OVERVIEW

NEW GROWTH AT AUGER: CARDAMOM DEEP

PRODUCTION

AugerPlatform

AugerNorth

AugerMain

50

100


0'15+

Cardamom

Main

� Shell 100% (operator) Auger TLP & Cardamom

� Auger 1993: 1st application of a Tension Leg Platform in deepwater (820 meters water depth)

� Cardamom Deep discoveries in 2009/10(>100 million boe resources)

� FID 2011: 50 kboe/d expected peak production

Discovered First OilFirst TLP

1987 1993 2009/10

Deep Cardamomdiscoveries

1999-2004

Subsea-FieldsMacaroniSerranoOreganoHabanaro

Llano

2011

Deep Cardamom Subsea system

FID

~2014

Firstproduction

0'94 '96 '98 '00 '02 '04 '06 '08 '10

PERDIDO –TECHNOLOGY LEADER

� Shell 33.3% (operator); Peak production ~100 kboe/d

� Substantial oil in place > 3 billion boe

� We expect recoverable resources > 400 million boe …… upside from technology development

� First oil in March 2010

� Industry first production in Lower Tertiary

� Development drilling planned for 5+ years

� New world record deepest drilling and production system

RESERVOIR VIEW


system

Seismic overview of Great White

4.8 km5 KM

OVERVIEW SHELL POSITIONS

SHELL BRAZIL PRODUCTION

BRAZIL GROWTH POTENTIAL

Parque das Conchas BC-10 • Start-up phase -1 2009• Phase 2 FID 2010

Gato do Mato BMS-54 Campos

Sao Francisco exploration

EspiritoSanto Basin

Bijupira-Salema


UPSTREAM PRODUCTION

UPSTREAM POTENTIAL

2011-12 KEY WELLS

Gato do Mato BMS-54 discovery• multi-well drilling program in 2011&’12

Santos Basin

Campos Basin

Salema

Divested BMS-8

BC-10 FPSO

Stena Drillmax – Gato do Mato well

PLANS SUBMITTED REQUIRING EAS AND NEW APDS - BY PLAN

GOM: PERMITTING STILL A CHALLENGE

21 4329 29

30

58

31

5565

51 29

47

30 51 51

5224

5

60

33

250

300

350

400

450

Plans: Operator submission to "Deemed Submitted" Plans: "Deemed Submitted" to Final Action (Approval)

Plan Approved to First APD Total time for Plan Approval, 5 Plan Trend

Days

SeptemberAugustJulyJuneMay


DEEPWATER PLANS WITH EA., APDS TARGETING HYDROCARBONS ONLY,

9

92

170

119

171

121

213192

43

107

203191 199

219 219

182 187 190176

232

204

231

203 204

73

158

76

122

62

133 126

238248

98

51

173

146

100

273

126

92

300288 288

173

52

40

47

46

25

2146

27

28

43

41 31

29 29

3031 28

28

58 55

17

46

35

33

50

35 42

24

74

29

30

7648

34

54

9

5224

1

5

73

13

21

165

0

50

100

150

200

Permitting averaging >150 days; 50 pre-Macondo

SAFE AND RELIABLE OPERATIONS

SAFETY CASE ‘BOW TIE’ MODEL: PREVENTION AND RECOVERY – INDUSTRYOUR APPROACH

� Global Standards

� Multiple Barriers

� Well Design

� Training

� Remote Monitoring

Control Control & Barriers& BarriersControl Control & Barriers& Barriers

IncidentIncidentIncidentIncidentResponse & Response & RecoveryRecoveryResponse & Response & RecoveryRecovery

Control Control & Barriers& Barriers

IncidentIncidentResponse & Response & RecoveryRecovery

HAZA

RD

CONSE

QUEN

CES


PREVENTATIVE BARRIERS MINIMIZE LIKELIHOOD OF AN INCIDENT

Technical standards & procedures

Competent staff &

contractors; rigorous drills

Equipment testing &

certification

Safety Case management

of major hazards

Minimum two tested & independent

barriers

Human behaviours & culture

Zero process safety

incidents

+ + + + + =

� Safety Case Approach

� Leadership & Safety CultureMinimize Likelihood

Mitigate Consequences

CONSE

QUEN

CES

STANDARD ASSET INTEGRITY MANAGEMENT INTERNATIONAL RESPONSE

BLOWOUT PREVENTION & CONTAINMENT CAPABILITY


� Founding & permanent Board Member of the Marine Well Containment Company (MWCC)

� MWCC will own & deploy the system in US GOM

� Subsea containment equipment designed for GOM

• Interim system was available Feb 2011

• Expanded system available 2012

� 9 participating members, Shell operator

� Near term the project team will:

• Design a capping toolbox & additional hardware for the subsea injection of dispersant

• Further assess the need for and feasibility of a containment system for shared use

• Assess deployment options

ALASKA – CHUKCHI & BEAUFORT SEA

Chukchi Sea

Beaufort Sea

0 100 SHELL LEASEHOLD

� Preparing for two rig, 2012 drilling program

• up to three Chukchi wells, including Burger

appraisal; up to two Beaufort wells

� Current focus on operational readiness and

securing necessary permits


Burger1990

Crackerjack1991

Klondike1989

CHUKCHI

X-SECTION� Successful leasing in 2005-2008

• #1 Alaska position, 2.4 mln acres

� Proven petroleum province

• well understood North Slope geology

� Multi-billion boe potential in existing Chukchi

& Beaufort Sea discoveries

ROYAL DUTCH SHELL PLC

Q&A


HOUSTON/SHREVEPORT

NOVEMBER 2011

Investor Relations

John Hollowell – Deepwater operations