The document discusses Royal Dutch Shell's efforts to reduce flaring of natural gas in Nigeria. It summarizes Shell's flaring reduction program in Nigeria, which has invested over $3 billion to gather 60% of associated natural gas production since 2000. The program aims to spend an additional $4 billion on oil and gas projects to gather another 35% of associated gas by 2014-2015. This would reduce Shell's flaring intensity in Nigeria below the global average. The document also notes that sustained investment in gas infrastructure and deregulated gas pricing are needed to significantly grow Nigeria's domestic gas industry.

1. ROYAL DUTCH SHELL PLC
SPDC FLARES REDUCTION
PORT HARCOURT
OCTOBER 10, 2012
Copyright of Royal Dutch Shell plc 10 October, 2012 1

2. SPDC FLARES REDUCTION PROGRAMME
MUHAMMAD SHITTU
GM FLARED GAS
Copyright of Royal Dutch Shell plc 10 October, 2012 2

3. CAUTIONARY NOTE
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 23% 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 are identified by their use of terms and phrases such as „„anticipate‟‟, „„believe‟‟, „„could‟‟, „„estimate‟‟, „„expect‟‟,
„„intend‟‟, „„may‟‟, „„plan‟‟, „„objectives‟‟, „„outlook‟‟, „„probably‟‟, „„project‟‟, „„will‟‟, „„seek‟‟, „„target‟‟, „„risks‟‟, „„goals‟‟, „„should‟‟ 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 potential litigation and regulatory measures as a result of climate changes; (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 20-F for the year ended 31 December, 2011 (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, 10 October 2012. 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. There can be no assurance that dividend payments will match or exceed those set out in this
presentation in the future, or that they will be made at all.
We use certain terms in this presentation, such as resources, that the United States Securities and Exchange Commission (SEC) guidelines strictly prohibit us from
including in filings with the SEC. 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.
Copyright of Royal Dutch Shell plc 10 October, 2012 3

4. NIGERIA NATURAL GAS PRODUCTION AND
UTILISATION
EXPORT LNG
3.2 bcf/d
41% (Shell operated 56%: 1.8bcf/d)
RE-INJECTION & OTHER
OPERATIONAL USAGE
32%
2.5 bcf/d
(Shell operated 4%: 0.1bcf/d)
GAS FLARING
1.2 bcf/d
15%
GAS WELLS (Shell operated 18%: 0.2bcf/d)
PRODUCTION
7.8 bcf/d
(Shell operated 35%: DOMESTIC CONSUMPTION
2.8 bcf/d) 12% 0.9 bcf/d (power & industries)
(Shell operated 67%: 0.6bcf/d)
Copyright of Royal Dutch Shell plc 10 October, 2012 4

5. IMPROVEMENTS IN FLARING PERFORMANCE
SPDC JV FLARE VOLUMES & INTENSITY FLARING PERFORMANCE
MMscf per day Mscf/bbl MMscf per day
900 1.20 300
1.00
600 0.80 200
0.60
300 0.40 100
0.20
0 0.00 0
2010 2011 2012
ACTUAL ACTUAL YTD
Historical associated gas flared (MMscf/d) Active associated gas gathering Non associated gas
Flaring intensity Inactive associated gas gathering EA (Sea eagle)
No associated gas gathering facilities
Copyright of Royal Dutch Shell plc 10 October, 2012 5

6. SOUTHERN SWAMP ASSOCIATED GAS (AG)
/DOMESTIC GAS
PROJECT SCOPE/DEVELOPMENT PLAN
 AG compression systems in 4 flow stations (75
MMscf/d)
 Gas gathering pipelines
 Gas processing plant at Tunu
 70 MMscf/d central compression system
 160 MMscf/d dew pointing and export system
 Offshore pipeline to riser platform A
 Drilling and completion of 2 NAG wells Proposed gas plant at Tunu
 Drilling and completion of 18 Oil wells To
Forcados
Terminal
BENISEDE60Mbpd
PRODUCTION 20MMScf /d
70 kbbl/d of oil to Forcados via Trans Ramos
OGBOTOBO 12” x 16 km
 45 Mbpd
10MMScf /d
pipeline 8” x 16 km
E BRASS CREEK
MANIFOLD
 100 mmscf/d to domestic gas market 12” x 24 km
OPUKUSHI
Dodo N.
90 Mbp
TUNU 10” x 10 km
30MMScf /d
80MMscfd AG
CPF
FID 2012
120 MMScf/d NAG Slug
Catcher
160 MMScf/d HCDP
16”x 32 km 15MMScf /d
With provision of bays for future
expansion)
EA RISER PLATFORM
ONSTREAM 2014/2015 EXISTING OIL PIPELINES
NEW GAS GATHERING LINE
EXPORT PIPELINE TO OGGS
DISUSED LINES
Copyright of Royal Dutch Shell plc 10 October, 2012 6

7. FORCADOS YOKRI INTEGRATED PROJECT
LOCATION
KANTU
ORIGINAL SCOPE
C/ S
74,75,78,87
YOKRI
M ANI FOLD
ADD. ACQ SI I O
UI T N
LI VI NG ACCO M ARE
M. A
CO PRE STN
M
ALT. SI TE3
CO PRE. SN
M T
NORTH BANK
ALT. SI TE2 HELI PAD
4 new flow stations with gas gathering
K
F/ S
76,85
79

J
CO PRESSO SN
M RT
BUFFER ZONE 77,108
115,116
FS, FLB &
Asisagbene I
H
F/ L TRACE
51A
E
Yokri Egbe
CCP/CPF
G
Central processing facility (CPF)
113
FORC-51,72,73,90 F
 FORC-103,104,105,106,107
Sokobolo
D
C F/ S
52A
8" FORC. N.
25 wells
BANK D/ L
FORC-95,97,98,101 B
FORC-53 FORC-21 A GROUNDBED

FORC-52,64,65,68 Guogbene
Bi gh t o f Beni n FORC-67 FORC-18,20,43,44 45,46,47 Obotobo
FORC-9,54,55,56
6 new platforms in estuary
FORC-31,48.49,50

FORC-69,70,71,82,83
5A
FORC-10
JA / JB
FORC-93,94
FORC-5,22,23,24
FORC-42,60,61,62
FORC-120
FORC-30,57,58,5963 FORC-12
FORC-121,122,123,124
FORC-3,25,26,66
3A
FORC-4,32,33,34 FORC-2,27,28,29
128
FORC-11,39,40,41,91,92
FO R CADO S R I V ER
FORC-1,37,38,89
ADDITIONAL SCOPE NEW ESTUARY 13,14,17,19
80
FLOW STATION
LO TERM - SO PRO CTI N M SURS
NG H RE T O E E
E A
SCHO L
O
15
Switch from LNG to domestic gas market
H
Ogulaha
F/ S CAM P SI TE SHORELI NE 138- 6
- 7
APRON

JUNI O STAFFCLU
R B
SOUTH 3
4
2
FORCADOS
JETTY 6
BANK
7 8
GROUNDED SI TE
1 non-associated gas wells
AGI P FACI LI I E
T S
CABLE RUN SI E
T
1
I N- LI NE DEYDRATO SI E
H I NT
 TERMINAL
5 GROUNDED SI TEUNI - 1
T
RE - LOCATI ON
9
10
FORCADOS TERMI NAL AREA
 Renew estuary platforms & subsea bulk lines
PRODUCTION
 90 kbbl/d to Forcados terminal
 60 mmscf/d to domestic gas
FID 2012
ONSTREAM 2014/2015
Partially Completed North Bank CCP/CPF
Copyright of Royal Dutch Shell plc 10 October, 2012 7

8. FLARING SUMMARY
SUBSTANTIAL PROGRESS MADE
 SPDC JV committed to reduce continuous flaring in
Nigeria, and complies with Nigerian laws and
regulations on flaring
 Flaring and flare intensity dropped by ~60% since
2002
 SPDC JV spent >$3bln to gather ~60% of its
associated gas (AG) production since 2000
 Closing in high gas to oil ratio wells
 Further ~$4bln on oil & gas projects, gathering a
further 35% by 2014/2015, taking SPDC JV
flaring intensity below current global average
 Sustained funding, security and investment in gas
infrastructure and deregulated gas pricing are
required in order to significantly grow domestic
gas industry
Partially Completed North Bank CCP/CPF
Copyright of Royal Dutch Shell plc 10 October, 2012 8

9. SPDC FLARES REDUCTION
QUESTIONS & ANSWERS
Copyright of Royal Dutch Shell plc 10 October, 2012 9