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Royal Dutch Shell plc third quarter 2018 results webcast presentation

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Royal Dutch Shell plc webcast presentation slides for the third quarter 2018 results.
More information on http://www.shell.com/results

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Royal Dutch Shell plc third quarter 2018 results webcast presentation

  1. 1. Royal Dutch Shell November 1, 2018 Royal Dutch Shell plc November 1, 2018 Third quarter 2018 results Delivering a world-class investment case #makethefuture
  2. 2. Royal Dutch Shell November 1, 2018 Jessica Uhl Chief Financial Officer Royal Dutch Shell
  3. 3. Royal Dutch Shell November 1, 2018 3 Definitions & cautionary note Operating costs are defined as underlying operating expenses, which are operating expenses less identified items. Organic free cash flow is defined as free cash flow excluding inorganic capital investment and divestment proceeds. ROACE (Return on Average Capital Employed) is defined as the sum of CCS earnings attributable to shareholders excluding identified items for the current and previous three quarters, as a percentage of the average capital employed for the same period. Capital employed consists of total equity, current debt and non-current debt. Capital investment comprises capital expenditure, exploration expense excluding well write-offs, new investments in joint ventures and associates, new finance leases and investments in Integrated Gas, Upstream and Downstream equity securities, all of which on an accruals basis. Divestments comprises proceeds from sale of property, plant and equipment and businesses, joint ventures and associates, and other Integrated Gas, Upstream and Downstream investments, reported in “Cash flow from investing activities (CFFI)”, adjusted onto an accruals basis and for any share consideration received or contingent consideration recognised upon divestment, as well as proceeds from the sale of interests in entities while retaining control (for example, proceeds from sale of interest in Shell Midstream Partners, L.P.). This presentation contains the following forward-looking Non-GAAP measures: Organic Free Cash Flow, Free Cash Flow, Capital Investment, CCS Earnings less identified items, Operating Expenses, ROACE, Capital Employed and Divestments. We are unable to provide a reconciliation of the above forward-looking Non-GAAP measures to the most comparable GAAP financial measures because certain information needed to reconcile the above Non-GAAP measure to the most comparable GAAP financial measure is dependent on future events some which are outside the control of the company, such as oil and gas prices, interest rates and exchange rates. Moreover, estimating such GAAP measures with the required precision necessary to provide a meaningful reconciliation is extremely difficult and could not be accomplished without unreasonable effort. Non-GAAP measures in respect of future periods which cannot be reconciled to the most comparable GAAP financial measure are calculated in a manner which is consistent with the accounting policies applied in Royal Dutch Shell plc’s financial statements. The forward-looking break-even prices (BEP) presented are calculated based on all forward-looking costs associated from FID. Accordingly, this typically excludes exploration and appraisal costs, lease bonuses, exploration seismic and exploration team overhead costs. The forward-looking breakeven price is calculated based on our estimate of resources volumes that are currently classified as 2p and 2c under the Society of Petroleum Engineers’ Resource Classification System. As the projects are expected to be multi-decade producing the per barrel projection will not be reflected either in earnings or cash flow in the next five years. The financial measures provided by strategic themes represent a notional allocation of ROACE, capital employed, capital investment, free cash flow, organic free cash flow and underlying operating expenses of Shell’s strategic themes. Shell’s segment reporting under IFRS 8 remains Integrated Gas, Upstream, Downstream and Corporate. The companies in which Royal Dutch Shell plc directly and indirectly owns investments are separate legal 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 Royal Dutch Shell plc and subsidiaries in general or to those who work for them. These terms are also used where no useful purpose is served by identifying the particular entity or entities. ‘‘Subsidiaries’’, “Shell subsidiaries” and “Shell companies” as used in this presentation refer to entities over which Royal Dutch Shell plc either directly or indirectly has control. Entities and unincorporated arrangements over which Shell has joint control are generally referred to as “joint ventures” and “joint operations”, respectively. Entities over which Shell has significant influence but neither control nor joint control are referred to as “associates”. The term “Shell interest” is used for convenience to indicate the direct and/or indirect ownership interest held by Shell in an entity or unincorporated joint arrangement, after exclusion of all third-party interest. This presentation contains forward-looking statements (within the meaning of the U.S. Private Securities Litigation Reform Act of 1995) 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 “aim”, “ambition”, ‘‘anticipate’’, ‘‘believe’’, ‘‘could’’, ‘‘estimate’’, ‘‘expect’’, ‘‘goals’’, ‘‘intend’’, ‘‘may’’, ‘‘objectives’’, ‘‘outlook’’, ‘‘plan’’, ‘‘probably’’, ‘‘project’’, ‘‘risks’’, “schedule”, ‘‘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. No assurance is provided that future dividend payments will match or exceed previous dividend payments. 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 risk factors that may affect future results are contained in Royal Dutch Shell’s 20-F for the year ended December 31, 2017 (available at www.shell.com/investor and www.sec.gov ). These risk factors also expressly qualify all forward-looking statements contained in this presentation and should be considered by the reader. Each forward-looking statement speaks only as of the date of this presentation, November 1, 2018. Neither Royal Dutch Shell plc 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, such as resources, in this presentation that the United States Securities and Exchange Commission (SEC) strictly prohibits us from including in our 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.
  4. 4. Royal Dutch Shell November 1, 2018 4 Summary Divestments: headline. Methane emissions target covers all oil and gas assets for which Shell is the operator. Key messages  Cash flow delivery Cash flow from operations excluding working capital of $14.7 billion Free cash flow of $8 billion  Financial framework $25 billion share buyback programme ongoing 1st tranche completed, 2nd tranche of up to $2.5 billion announced Gearing further reduced to 23.1%  Reshaping the portfolio Final investment decision on LNG Canada Divestments completed and announced >$30 billion  Energy transition & license to operate Target to maintain methane emissions intensity below 0.2% by 2025 Thrive in the energy transition World-class investment case Strong license to operate
  5. 5. Royal Dutch Shell November 1, 2018 5 Portfolio & projects LNG Canada IRR defined as the discount rate that results in an NPV of zero for future after-tax cash flows expected from investment in upstream, midstream and trading, at LNG price of $8.5/MMBtu (Tokyo DES, real terms 2018).  Consistent with strategy and disciplined approach to capital investment  LNG demand growth driven by Asia, supply gap expected in early 2020s  Capital investment included within existing $25-30 billion guidance  Estimated integrated project IRR ~13%  Upside with trains 3 & 4  Competitive cost of supply into Asia  Support from local communities, First Nations and Canadian Government Emerging LNG supply-demand gap Million tonnes per annum (DES) LNG Canada – future site view Right project, in the right place, at the right time 0 100 200 300 400 500 600 2000 2005 2010 2015 2020 2025 2030 2035 LNG supply in operation LNG supply under construction Demand forecasts
  6. 6. Royal Dutch Shell November 1, 2018 6 Portfolio & projects Thriving in the Energy Transition Source graph: Embassy of the USA – Beijing, China; National Bureau of Statistics of China; Beijing Gas Group Co. Ltd. 2018E based on H1 2018 extrapolation. LNG Canada – competitive low carbon footprint BCM Beijing – gas as a cleaner alternative to coal LNG resilient in the Energy Transition Low upstream emissions in the Montney LNG plant clean power import Low CO2 LNG technology TransCanada methane principles Coastal Gas Link (CGL) efficient compression British Columbia Alberta Canada μg/m3 Particulate matter PM2.5 (RHS)Beijing area gas demand 0 20 40 60 80 100 120 0 2 4 6 8 10 12 14 16 18 20 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018E
  7. 7. Royal Dutch Shell November 1, 2018 7 Q3 2018 Other portfolio developments  Nigeria Epu near field discovery – 823 net feet of new hydrocarbon bearing pay  Brazil bid round – awarded Saturno pre-salt block as operator, increasing Brazilian offshore acreage to 2.7 million acres  Mauritania entry – 23,675 square kilometres of new exploration acreage  First production from Lula Extreme South P-69 FPSO – with capacity to produce up to 150 thousand barrels of oil per day, Shell interest 25%  Start-up of solvent deasphalter unit in Pernis – increasing the production of cleaner transport fuels ahead of IMO 2020 regulation  First ship-to-ship LNG bunkering – completed in port of Rotterdam  Denmark Upstream – announced sale for consideration of $1.9 billion  Argentina Downstream – completed sale for consideration of $0.9 billion Shell’s interest in the Lula field is subject to unitisation agreements. Portfolio & projects Portfolio highlights Exploration Project delivery Divestments
  8. 8. Royal Dutch Shell November 1, 2018  Of which $7.5 billion organic free cash flow  More than covers dividend, interest and share buybacks Disciplined cash allocation Cash generation 8 Q3 2018 Financial highlights: summary Dividend distributed to RDS shareholders; Buybacks: subject to further progress with debt reduction and oil price conditions. First tranche of $2 billion, of which $1.4 billion completed in Q3 2018, $0.6 billion in Q4 2018; Earnings and ROACE on CCS basis, excluding identified items. Q3 2018 average Brent price: $75/bbl  $5.6 billion earnings Net debt reduction Share buybacks Capital investment $14.7 billion  Highest since Q2 2008 when Brent averaged >$120/bbl for the quarter $8.0 billion Cash flow from operations excl. working capital Free cash flow ROACE 7.1% Returns $1.7 billion  23.1% gearing $2.0 billion $5.8 billion  Estimated to be ~$25 billion in 2018  First tranche completed in October  Second tranche of up to $2.5 billion announced  Intention to purchase $25 billion by the end of 2020
  9. 9. Royal Dutch Shell November 1, 2018 9 Q3 2018 Financial highlights: earnings Earnings and ROACE on CCS basis, excluding identified items. $ billion Earnings Q3 2017 to Q3 2018$ billion Q3 2017 Q3 2018 Integrated Gas 1.3 2.3 Upstream 0.6 1.9 Downstream (CCS) 2.7 2.0 Corporate & non-controlling interest (0.4) (0.6) CCS earnings 4.1 5.6 CCS earnings, $ per share 0.50 0.68 ROACE (%) 4.6 7.1 4.1 5.6 2.5 (0.1) 0.3 (0.8) (0.2) (0.1) 0 2 4 6 8
  10. 10. Royal Dutch Shell November 1, 2018 10 Q3 2018 Financial highlights: cash flow Dividend distributed to RDS shareholders. $ billion CFFO excl. working capital Q2 2018 to Q3 2018 11.6 14.7 0.6 0.6 0.8 0.5 0.6 0 4 8 12 16 $ billion Q2 2018 Q3 2018 Integrated Gas 3.0 3.3 Upstream 5.5 6.7 Downstream 1.0 1.0 Corporate 0.0 1.1 Cash flow from operations 9.5 12.1 Cash flow from operations excl. working capital 11.6 14.7 Cash flow from investing activities 0.0 (4.1) Free cash flow 9.5 8.0 Dividend (3.9) (3.9) Interest paid (0.9) (0.9) Share buybacks - (1.4)
  11. 11. Royal Dutch Shell November 1, 2018 11 Earnings and ROACE on CCS basis, excluding identified items; Pricing assumption 2020: $60 per barrel real terms 2016, mid-cycle Downstream; Divestments: headline, cash proceeds in 2016, 2017 and Q1-Q3 2018: $24.3 billion (in CFFI), $2.1 billion related to Shell Midstream Partners, L.P. (in CFFF). $ billion -5 5 15 25 -5 5 15 25 2014 2015 2016 2017 18Q3 4Q rolling Earnings & ROACE (4Q rolling) $ billion -15 0 15 30 45 2014 2015 2016 2017 18Q3 4Q rolling Cash flow (4Q rolling) $ billion 15 20 25 30 50 55 60 65 70 75 80 16Q1 16Q2 16Q3 16Q4 17Q1 17Q2 17Q3 17Q4 18Q1 18Q2 18Q3 Gearing  $20 billion earnings  ROACE increased to 7.1%  On track to deliver 10% ROACE in 2020  $29 billion free cash flow  $17 billion organic free cash flow  More than $30 billion divestments completed or announced since 2016  On track to deliver 2020 outlook  $8.3 billion of net debt reduction since Q3 2017  Gearing reduced from 23.6% to 23.1% in the quarter  Line of sight to 20% gearing Q3 2018 (4Q rolling) average Brent price: $69/bbl % % Upstream ROACE (RHS) Downstream Integrated Gas Corporate + NCI CFFO CFFI FCF Net debt Gearing (RHS) Q3 2018 Financial highlights: trend
  12. 12. Royal Dutch Shell November 1, 2018 12 Outlook Four powerful levers 2019 capital investment outlook excludes IFRS 16 impact; Divestments: headline, cash proceeds in 2016, 2017 and Q1-Q3 2018: $24.3 billion (in CFFI), $2.1 billion related to Shell Midstream Partners, L.P. (in CFFF); CFFO from new projects 2018 and 2020: compared with 2014, at $60 per barrel real terms 2016. Q3 2018 year-to-date at $72 per barrel average Brent.  $30 billion divestment programme: ▪ Argentina Downstream completed ▪ $28 billion completed to date ▪ Further $4 billion announced – including $1.9 billion for Denmark Upstream  >$5 billion per annum in 2019 and 2020  $25-30 billion per annum until 2020  Disciplined & efficient capital allocation  Material savings post-FID  2018 full year outlook: ~$25 billion  2019 outlook: within the $25-30 billion range  4-quarters rolling underlying operating expenses of $38.7 billion  Drive simplification, standardisation and digitalisation  Leveraging the Shell Business Operations shared services model Operating expenses Capital investment Divestments New projects  CFFO from new projects: ▪ $9 billion year-to-date ▪ +$10 billion by end 2018 ▪ +$15 billion by end 2020  New projects provide oil price upside
  13. 13. Royal Dutch Shell November 1, 2018 13 Outlook Projects delivery Pricing assumption 2018E-2021E and 2018 YTD estimate: $60 per barrel real terms 2016. Brazil accumulations are subject to unitisation agreements. $ billion Cash contribution from new projects Selected key projects Selected key projects to contribute 2018-2020: ▪ >400 kboe/d peak production ▪ >$7 billion CFFO 2018E 2019E 2020E 0 10 20 2018 YTD estimate Brazil (8 FPSOs) Gulf of Mexico (Cardamom, Mars, Stones, Kaikias) Malikai Gumusut Kakap Ph1 Brazil - Lula North (P-67) Appomattox Permian QCLNG Gorgon Prelude Kashagan Schiehallion redevelopment Clair Ph2     Nanhai China Chemicals Geismar AO4 Pernis SDA Scotford   Start-up   Q3 2019 Q4 2018 Q4 2018 Q4 2018  Q4 2018 2017-2020   Deep- water Integrated Gas Conventional Oil & Gas Shales Chemicals Oil Products
  14. 14. Royal Dutch Shell November 1, 2018 17 0 5 10 15 20 25 30 35 Q32018 4QR Normalisation to$60/bblRT16 Q32018 4QR,normalised CFFOfrom keynewprojects 2020outlook 14 Outlook Organic free cash flow 2020 outlook at $60 per barrel real terms 2016, mid-cycle Downstream. Organic free cash flow normalised to stable $60 per barrel real terms 2016 oil price environment in 2020, assuming no working capital or margining movements. Price effect between current Brent price and 2020 outlook is indicative, calculated using rule-of-thumb. $ billion Organic free cash flow Q3 2018 to 2020 Outlook Focus on free cash flow growth  On track to deliver 2020 outlook of $25-30 billion organic free cash flow  Normalised organic free cash flow excludes effects of margining and working capital movements  New projects provide free cash flow growth 25-30>7 (3) ~24 ~21 Organic free cash flow Working capital movement and IG margining
  15. 15. Royal Dutch Shell November 1, 2018 Capital investment Buybacks Divestment proceeds CFFO Surplus CFFO 15 Financial framework Cash allocation 2019 capital investment outlook excludes IFRS 16 impact; 20% gearing as a proxy for AA equivalent credit metrics.  Intention to purchase $25 billion by the end of 2020  Subject to further progress with debt reduction and oil price conditions  $25-30 billion p.a., organic & inorganic  ~$25 billion in 2018 and within the range in 2019  $3.5-4 billion expected in 2018  23.1% as of Q3 2018  $3.9 billion cash payment in Q3 2018Dividend Interest Net debt reduction to 20% gearing
  16. 16. Royal Dutch Shell November 1, 2018 16 Summary Divestments: headline. Methane emissions target covers all oil and gas assets for which Shell is the operator. Key messages  Cash flow delivery Cash flow from operations excluding working capital of $14.7 billion Free cash flow of $8 billion  Financial framework $25 billion share buyback programme ongoing 1st tranche completed, 2nd tranche of up to $2.5 billion announced Gearing further reduced to 23.1%  Reshaping the portfolio Final investment decision on LNG Canada Divestments completed and announced >$30 billion  Energy transition & license to operate Target to maintain methane emissions intensity below 0.2% by 2025 Thrive in the energy transition World-class investment case Strong license to operate
  17. 17. Royal Dutch Shell November 1, 2018 Questions & Answers Jessica Uhl Chief Financial Officer Royal Dutch Shell November 1, 2018 17
  18. 18. Royal Dutch Shell November 1, 2018
  19. 19. Royal Dutch Shell November 1, 2018 0.5 1.1 0.9 2.6 0 2 4 6 8 Inventories - price effect Inventories - volume effect AP/AR movement Total working capital movement 19 RDS working capital movements $ billion Working capital movements Q2 2018 to Q3 2018 $ billion Working capital movements Q3 2017 to Q3 2018 ~300 million boe in Downstream inventory at end Q3 2018 – materially unchanged from Q3 2017 5.6 0.6 1.3 7.5 0 2 4 6 8 Inventories - price effect Inventories - volume effect AP/AR movement Total working capital movement
  20. 20. Royal Dutch Shell November 1, 2018 Outlook Q4 2018 Outlook Q4 – Q4 OUTLOOK: Year-ago baseline reflects Shell’s earnings seasonality  Integrated gas  Production volumes: 0-40 thousand boe/d lower, mainly due to divestments  Liquefaction volumes: up to 0.3 million tonnes higher, mainly due to increased feed gas availability and lower maintenance  Upstream  Production volumes: 80-120 thousand boe/d higher, mainly due to lower maintenance activity and growth from new fields more than offsetting the impacts of field decline and divestments  Downstream  Refinery availability to increase, as a result of lower maintenance activity  Chemicals availability to increase, as a result of lower maintenance activity  Oil products sales volumes: 40-70 thousand boe/d lower, mainly as a result of the divestment of the Downstream business in Argentina 2018 OUTLOOK:  Corporate segment: net charge of $350-400 million in Q4, excluding the impact of currency exchange rate effects  IFRS 16: updates will be communicated in Q1 2019 20
  21. 21. Royal Dutch Shell November 1, 2018 Q3 2018 Prices & margins $/barrel Shell oil & gas realisations $/barrel Industry refining margins $/tonne Industry chemicals margins 0 1 2 3 4 5 6 0 20 40 60 80 17Q3 17Q4 18Q1 18Q2 18Q3 0 3 6 9 12 15 18 17Q3 17Q4 18Q1 18Q2 18Q3 0 200 400 600 800 1000 17Q3 17Q4 18Q1 18Q2 18Q3 US ethane Western Europe naphtha NE/SE Asia naphtha US West Coast US Gulf Coast coking Rotterdam complex Singapore Oil Gas (RHS) 21 $/mscf
  22. 22. Royal Dutch Shell November 1, 2018 1.3 2.3 1.2 0.1 (0.2) (0.1) ~(0) 0 1 2 3 22 Q3 2018 Integrated Gas results $ billion Earnings Q3 2017 to Q3 2018 Environment Choice Earnings on CCS basis, excluding identified items
  23. 23. Royal Dutch Shell November 1, 2018 0.6 1.9 1.8 0.1 0.1 0.1 0.1 (0.8) (0.1) 0 1 2 3 23 Q3 2018 Upstream results $ billion Earnings Q3 2017 to Q3 2018 Environment Choice Earnings on CCS basis, excluding identified items
  24. 24. Royal Dutch Shell November 1, 2018 2.7 2.0 (0.3) (0.1) (0.1) (0.1) ~(0) 0 1 2 3 24 Q3 2018 Downstream results Earnings on CCS basis, excluding identified items $ billion Earnings Q3 2017 to Q3 2018 $ billion Earnings mix 0 5 10 2015 2016 2017 18Q3 4Q rolling Marketing Refining & Trading Chemicals
  25. 25. Royal Dutch Shell November 1, 2018 Start-up Project Country Shell share % Peak production 100% kboe/d LNG 100% capacity mtpa Products Legend Theme Shell operated 2018-19 Appomattox United States 79 175  Deep water P Atapu South (P-70)* Brazil 25 150  Deep water Berbigão and Sururu SW (P-68)* Brazil 25 150  Deep water Clair Ph2 United Kingdom 28 120  Conventional oil + gas Forcados Yokri Integrated Project (FYIP) Nigeria 30 40  Conventional oil + gas P Geismar AO4 United States 100 425 ktpa AO  Chemicals P Gumusut-Kakap Ph2 Malaysia 29 50  Deep water P Lula North (P-67)* Brazil 25 150  Deep water Permian + Fox Creek ** United States & Canada various ~200  Shales P Prelude FLNG Australia 68 131 3.6 1.7 mtpa NGLs  Integrated Gas P Rabab Harweel Integrated Project Oman 34 35  Conventional oil + gas Southern Swamp AG Nigeria 30 40  Conventional oil + gas P    Tempa Rossa Italy 25 50  Conventional oil + gas WDDM 9B Egypt 50 52  Conventional oil + gas 2020+ FPSO P-71* Brazil 25 150  Deep water Bakong / Gorek / Larak (SK408) Malaysia 30 75  Conventional oil + gas P Changbei II China 100 TBD  Integrated Gas P KBB Ph2 Malaysia 30 75  Conventional oil + gas LNG Canada T1-2 Canada 40 14  Integrated Gas Mero 1* Brazil 20 180  Deep water Pegaga Malaysia 20 95  Conventional oil + gas Penguins Redevelopment United Kingdom 50 45  Conventional oil + gas P Pennsylvania cracker United States 100 1.5 mtpa C2  Chemicals P Troll Ph3 Norway 8 255  Conventional oil + gas Tyra Future*** Denmark 37 80  Conventional oil + gas Vito United States 63 100  Deep water P * The Brazil accumulations are subject to unitisation agreements which impacts onstream, under construction, and pre-FID projects; production shown is FPSO oil capacity as per operator ** Fox Creek and Permian production represents Shell entitlement share of production and is the production growth expected between 2016 peak to 2018 peak production *** Subject to completion of Denmark Upstream divestment 25 Projects under construction 2018-19 Shell share: ▪ >600 kboe/d ▪ 2.4 mtpa LNG ▪ 0.4 mtpa AO 2020+ Shell share: ▪ >250 kboe/d ▪ 5.6 mtpa LNG ▪ 1.5 mtpa ethylene
  26. 26. Royal Dutch Shell November 1, 2018 Phase Project Country Shell share % Peak production 100% kboe/d LNG 100% capacity mtpa Products Legend Theme Shell operated Define Arrow Surat Australia 50 TBD  Integrated Gas Assa North Nigeria 30 60  Conventional oil + gas P Bonga South West Nigeria 43 175  Deep water P Gbaran Ph3 Nigeria 30 50  Conventional oil + gas P Lake Charles LNG United States TBD 16.8  Integrated Gas Uzu Development Nigeria 30 45  Conventional oil + gas P Val d'Agri Future Development Italy 39 65  Conventional oil + gas Assess / Bonga Main Life Extension & Upgrade Project Nigeria 55 75  Deep water P Select Clair South United Kingdom 28 60  Conventional oil + gas HI Development Nigeria 40 75  Conventional oil + gas P Jackdaw United Kingdom 74 40  Conventional oil + gas P Jerun Malaysia 30 95  Conventional oil + gas Kalamkas Kazakhstan 17 55  Conventional oil + gas Kashagan CFP Kazakhstan 17 65  Conventional oil + gas KGK Expansion Project Ph1 Kazakhstan 29 40  Conventional oil + gas Mero 2* Brazil 20 180  Deep water Mero 3* Brazil 20 180  Deep water Mero 4* Brazil 20 180  Deep water LNG Canada T3-4 Canada 40 14  Integrated Gas Marjoram/Rosmari Malaysia 75 60  Conventional oil + gas P Ormen Lange Late Life Recovery Norway 18 50  Conventional oil + gas P Pearls Khazar Kazakhstan 55 40  Conventional oil + gas Pierce Depressurisation United Kingdom 93 25  Conventional oil + gas P Powernap United States 100 35  Deep water P Sakhalin T3 Russia 28 5.4  Integrated Gas Salym Southern Hub Project Russia 50 65  Conventional oil + gas * The Brazil accumulations are subject to unitisation agreements which impacts onstream, under construction, and pre-FID projects; production shown is FPSO oil capacity as per operator 26 Pre-FID options Shell share potential: ▪ ~600 kboe/d ▪ >7 mtpa LNG

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