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Gas Market Outlook & LNG Business Fundamentals

The document provides an outlook on the natural gas market and the fundamentals of the LNG business, emphasizing the rising demand for gas which is expected to grow faster than overall energy demand until 2035. It highlights LNG as the fastest-growing segment, especially in Asia, and discusses the complexities and risks associated with LNG projects in Alaska. Additionally, it covers strategies for Alaska's participation in LNG projects, including pricing negotiation and state involvement in the value chain.

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Natural Gas Market Outlook & Fundamentals of LNG Business Prepared for the Alaska State Legislature Juneau, Alaska › January 28, 2014 ! Janak Mayer, Partner › janak.mayer@enalytica.info Nikos Tsafos, Partner › nikos.tsafos@enalytica.info http://enalytica.info enalytica Data. Analytics. Solutions. in Energy
Executive Summary !2 gas market outlook › LNG business fundamentals › implications for Alaska Gas and LNG Market Fundamentals are strong Gas makes up a rising share of the world’s energy mix Demand for energy expected to rise by 1.2% a year through 2035, but gas grows faster at 1.6% Gas supplies 23.7% of total energy in 2035 (vs. 21.3% in 2011) Gas makes up 31% of growth in energy demand through 2035 LNG is the fastest growing part of the gas market LNG demand has grown 4x faster than overall gas demand in last decade LNG trade expected to grow by as much as 3.8% annually to 2030 Asia is the prize in terms of demand growth (75+% of total) and pricing Multiple supply options create downward pressure on pricing — suppliers must compete In gas pricing, micro (rather than macro) is still what matters enalytica Data. Analytics. Solutions. in Energy
Executive Summary !3 gas market outlook › LNG business fundamentals › implications for Alaska LNG Projects are Big, Complex and Multi-layered LNG projects take years (even decades) from first discovery to commercial production They require a large capital commitment upfront—but deliver long-term revenue thereafter No such thing as a “standard” project structure that Alaska can “adopt” Complexity means that value creation and distribution is often a product of negotiation States’ participation varies from not at all to fully involved throughout the value chain LNG projects are often used to unlock stranded gas that is also supplied to local markets LNG projects face many risks—but have established mechanisms for risk-management and mitigation Third-party finance, marketing integration and pricing bands can reduce exposure/volatility Price review clauses allow counter-parties to provide reprieve to grave imbalances LNG projects tend to be partnerships between many private and state-owned enterprises enalytica Data. Analytics. Solutions. in Energy
Executive Summary !4 gas market outlook › LNG business fundamentals › implications for Alaska Alaska HAs Many Ways to Participate in LNG Project State’s Gas gas in value: Key question is how to negotiate a “fair” transfer price gas in Kind Agency marketing (Companies Sell gas on Alaska’s Behalf) State markets Gas in-state Sales FOB (Buyers Do Shipping) CIF (Alaska Does Shipping) equity across chain Agency marketing or state markets gas Agency marketing or state markets gas Gas in value state taxes and regulates enalytica Active engagement with project operations Data. Analytics. Solutions. in Energy
‣ ‣ ‣ ‣ Natural gas market outlook fundamentals of LNG business Implications for Alaska Appendices enalytica Data. Analytics. Solutions. in Energy
Energy › Gas › LNG › Gas Pricing › conclusions !6 energy supply-demand matrix in 2011 › energy demand drivers › energy demand forecast Energy demand has more than tripled since 1960 Oil provides 31% of total energy and is chiefly a transportation fuel Coal provides 29%, chiefly for power; gas makes up 21.3% of total energy (of which 40% for power) Nuclear and hydro provide a total of 7.5% all in power; biomass (10%) still large in residential use Coal Primary Supply Power/Heat Other Trnsfr Industry Transport Res/Comm/Agr Non-Energy % Total 3,776.1 (2,365.6) 506.8 728.9 3.4 132.1 39.2 28.8% Oil & Products 4,136.0 (283.5) 219.2 323.2 2,265.2 436.1 608.8 31.5% Energy Matrix in MMTOE (2011) Natural Biofuels & Nuclear Hydro Gas Waste 2,787.0 674.0 300.2 1,312.2 (1,118.2) (674.0) (300.2) (134.6) 288.3 65.8 506.4 198.2 92.5 58.6 610.2 855.0 171.4 21.3% 5.1% 2.3% 10.0% Other Total 128.1 2,143.5 383.1 800.1 25.2 1,063.1 1.0% 13,113.4 (2,732.7) 1,463.2 2,556.8 2,444.9 3,096.4 819.4 100% Source: International energy agency, Key world Energy Statistics 2013 enalytica Data. Analytics. Solutions. in Energy
Energy › Gas › LNG › Gas Pricing › conclusions !7 energy supply-demand matrix in 2011 › energy demand drivers › energy demand forecast strong fundamentals support higher energy usE +0.9% p.a. +1.8 billion 51% › 61% +1.75 billion +3.6% p.a. +240% Total +2.6% p.a. +90% Total -2.2% P.A. +1.25% p.a. non-oecd driven 43% Less Energy 2.5x 2.5x 2x 2x 1.5x 1.5x 1x 1x 0.5x 0.5x Population Urbanization Real GDP 2010 2015 GDP/capita 2020 2025 2030 Energy Use Energy Intensity 2035 Source: UN Population Prospects (2012); UN, World Urbanization Prospects (2011) ; IEA, world Energy Outlook; OECD, Long-term GDP Projections (June 2013) enalytica Data. Analytics. Solutions. in Energy
Energy › Gas › LNG › Gas Pricing › conclusions !8 energy supply-demand matrix in 2011 › energy demand drivers › energy demand forecast IEA Forecasts Energy to Grow at 1.2% By 2035 Gas accounts for 31% of energy growth (1.6% annual growth); share of total energy from 21.3% to 23.7% Coal plateaus in the 2020s and its share of total energy shrinks to 25.5% (vs. 28.8% in 2010) Percent of fossil fuels declines from 81.6% in 2010 to 76% in 2035 Energy Supply by Fuel 20,000 mmtoe Coal 18,000 Oil Gas Nuclear Hydro Biomass Other 16,000 14,000 12,000 10,000 8,000 6,000 4,000 2,000 0 2011 2020 2025 2030 2035 Source: International energy agency, World Energy Outlook 2013 (November 2013) enalytica Data. Analytics. Solutions. in Energy
Energy › Gas › LNG › Gas Pricing › conclusions !9 units › regional balances › trade corridors › gas demand forecast gas units and conversions bbl barrel (oil) 1 bbl = 6 thousand cubic feet (6 mcf) $/bbl dollars per barrel (oil) $6/bbl = $1/mcf ≃ $1/mmbtu mmbtu million British thermal units $1/mmbtu ≃ $1/mcf mmcf/d million cubic feet per day 1,000 mmcf/d = 7.8 mmtpa = 10.3 bcm/yr bcf/d billion cubic feet per day 1 bcf/d = 7.8 mmtpa = 10.3 bcm/yr bcm billion cubic meters 1 bcm/y = 0.73 mmtpa = 96.7 mmcf/d mmtpa million tons per annum (LNG) 1 mmtpa = 1.37 bcm = 48.37 bcf/y = 132 mmcf/d mmtoe million tons of oil equivalent 1 mmtoe = 1.11 bcm = 39.2 bcf = 107.4 mmcf/d enalytica Data. Analytics. Solutions. in Energy
Energy › Gas › LNG › Gas Pricing › conclusions !10 units › regional balances › trade corridors › gas demand forecast Only 30% of global gas Is traded (vs. 64% of Oil) Europe and Asia are deficit regions (71% of imports); FSU is the largest surplus region (26% of exports) North America is the biggest producer (27% of global) and consumer (27% of global); it is in small deficit 68% of gas trade by pipeline; 32% as liquefied natural gas (LNG) N. America S. America Europe FSU Middle East Africa Asia Pacific Total Production bcf/d % 86.5 27% 17.1 5% 25.5 8% 74.4 23% 52.9 16% 20.9 6% 47.3 15% 324.6 100% Regional Balances (2012) in BCF/D Exports Imports bcf/d % bcf/d % 12.5 13% 13.6 14% 4.0 4% 3.1 3% 19.9 20% 43.2 43% 26.1 26% 8.9 9% 15.4 15% 3.3 3% 9.7 10% 0.6 1% 12.4 12% 27.3 27% 99.9 100% 99.9 100% Net bcf/d -1.0 0.9 -23.3 17.2 12.1 9.1 -15.0 0.0 Demand bcf/d 87.5 15.9 48.0 56.5 39.7 11.8 60.3 319.8 % 27% 5% 15% 18% 12% 4% 19% 100% Source: BP Statistical Review of World Energy (June 2013) enalytica Data. Analytics. Solutions. in Energy
Energy › Gas › LNG › Gas Pricing › conclusions !11 units › regional balances › trade corridors › gas demand forecast More than Half (58%) of gas trade within regions Intra-regional trade patterns Intra-European trade accounts for 19.5% of the volumes traded internationally Intra-North America and Intra-Asia Pacific make up another 12.5% each Intra-FSU trade makes up 9% of total trade, mostly originating from Russia Inter-regional trade patterns Trade from FSU to Europe is the largest inter-regional trade route (13% of global) Middle East and Africa into Europe almost as big (10.3% of global trade) Middle East to Asia (9%) and FSU to Asia (3.5%) other major routes Source: BP Statistical Review of World Energy (June 2013) enalytica Data. Analytics. Solutions. in Energy
Energy › Gas › LNG › Gas Pricing › conclusions !12 units › regional balances › trade corridors › gas demand forecast IEA puts Gas Demand Growth at 1.6% through 2035 OECD accounts for 18% of demand growth; non-OECD 82% Asia accounts for 44% of incremental demand; Middle East follows by 19.5% OECD North America grows faster than OECD Europe / OECD Asia due to cheaper gas prices Gas Demand by Region 600 BCF/d N. America Latin America Europe FSU Asia Mid East 500 400 Africa 481 bcf/d 326 bcf/d 300 200 100 0 2011 2020 2025 2030 2035 Source: International energy agency, World Energy Outlook 2013 (November 2013) enalytica Data. Analytics. Solutions. in Energy
Energy › Gas › LNG › Gas Pricing › conclusions !13 regional overview › suppliers › consumers › demand outlook › supply outlook LNG Market was 31.7 bcf/d in 2012 Middle East is largest surplus region (+12.3 bcf/d); Asia is largest deficit region (-11.5 bcf/d) Around 70% of LNG went to Asia and 21% to Europe South America and Middle East are recent importers (since 2008); they took in 6% of demand in 2012 Middle East (40%) and Asia Pacific (33.2%) were the largest suppliers of LNG Africa is the next largest supplier (Algeria, Nigeria, Eq. Guinea, Egypt) with 16.5% of exports Middle East Africa S. & C. America N. America Europe Asia Pacific Total LNG Imports and Exports in 2012 Imports Exports bcf/d % Total bcf/d 0.4 1.4% 12.7 0.0 0.0% 5.2 1.5 4.6% 2.4 1.1 3.5% 0.1 6.7 21.1% 0.8 22.0 69.3% 10.5 31.7 100% 31.7 % Total 40.1% 16.5% 7.6% 0.2% 2.4% 33.2% 100% Net bcf/d 12.3 5.2 0.9 -1.0 -5.9 -11.5 0.0 Source: BP Statistical Review of World Energy (June 2013) enalytica Data. Analytics. Solutions. in Energy
Energy › Gas › LNG › Gas Pricing › conclusions !14 regional overview › suppliers › consumers › demand outlook › supply outlook Qatar is by far Largest LNG Exporter (32.6% Total) Five countries (Qatar, Malaysia, Australia, Nigeria, Indonesia, Trinidad) make up 73% of supply Russia, Peru, and Yemen have all started to export after 2008. Angola started exports in 2013 90 80 LNG Exports (2012) mmtons % Total 32.6% 35% 30% 70 25% 60 50 20% 40 15% 8.7% 8.4% 20 7.6% 6.1% 10% 4.6% 4.6% 10 3.4% 2.9% 2.3% 2.2% 2.1% 1.6% 1.6% 1.4% Norway Eq. Guinea Peru Egypt Yemen UAE Brunei Oman Russia Algeria Trinidad Indonesia Nigeria Australia Malaysia Qatar 0 0.1% 5% 0% USA 9.7% 30 Source: international gas union, World LNG Report 2013 (June 2013) enalytica Data. Analytics. Solutions. in Energy
Energy › Gas › LNG › Gas Pricing › conclusions !15 regional overview › suppliers › consumers › demand outlook › supply outlook LNG Demand concentrated among few buyers Two markets (Japan and Korea) account for 50% of demand Six countries (Japan, Korea, China, Spain, India, Taiwan) make up 75% of demand 15 countries import less than 2% of global demand each — but more and more countries importing LNG % Total 36.7% 40% 35% 30% 25% 20% 15.5% 15% 6.2% 6.0% 5.9% 5.4% 4.4% 3.1% 2.4% 2.2% 1.6% 1.5% 1.4% 1.3% 1.1% 0.9% 0.8% 0.7% 0.5% 0.5% 0.5% 0.4% 0.4% 0.4% 10% 5% Dom. Rep. Puerto Rico Thailand Greece UAE Canada Portugal Belgium Kuwait Brazil Chile USA Mexico Argentina Italy Turkey France UK Taiwan India Spain China Korea 0% Japan 100 90 80 70 60 50 40 30 20 10 0 LNG Imports (2012) mmtons Source: international gas union, World LNG Report 2013 (June 2013) enalytica Data. Analytics. Solutions. in Energy
Energy › Gas › LNG › Gas Pricing › conclusions !16 regional overview › suppliers › consumers › demand outlook › supply outlook LNG demand to grow 3.8% a year to 2030 Asia has been and remains the dominant market for LNG and accounts for 75+% of demand growth Demand for LNG in Americas flat; shale shrinks N. America’s needs but S. America grows Europe flat through 2020 but growth thereafter driven by resource maturity Middle East and Africa fastest growing markets but volumetrically make bigger impact post 2020 LNG Imports in MMTPA 2010 2015 2020 2030 Δ: 10-30 Δ: 10-30 Americas 21 20 16 19 -2 -0.3% Europe 64 28 60 98 34 6.5% Mid East/Africa 3 6 10 38 35 9.7% Asia 129 200 256 377 248 3.2% Total 217 254 342 532 315 3.8% Source: Wood Mackenzie LNG Forecast (Data from Cheniere IR Presentation in January 2014) enalytica Data. Analytics. Solutions. in Energy
Energy › Gas › LNG › Gas Pricing › conclusions !17 regional overview › suppliers › consumers › demand outlook › supply outlook Many possible Suppliers, Many Risks to manage Over 34 tcf in north slope but Uncertain Fiscal terms/ project economics Large Scale Resources But technical risks Sizable stranded gas but high costs Ample possible Shale Gas but need for infrastructure and commercial viability Cheap Gas, but Slow permitting process and possible Price volatility Over 30 tcf but significant political risks Much Associated gaS but local markets take priority Qatar / Iran huge resource; local markets priority, Economics, politics Sizable undeveloped gas But Local market take priority Much Associated gas But local markets take priority Over 100 tcf But high cost of entry, low government capacity, High infrastructure needs enalytica Sizable remaining resources but exorbitant costs Data. Analytics. Solutions. in Energy
Energy › Gas › LNG › Gas Pricing › conclusions !18 pricing structures › regional spreads › intra-region spreads › intra-country spreads › outlook GAs Pricing structures highly variable Gas pricing can be either cost-plus or market netback Gas is usually priced in any of four alternative ways; some deals could include a mixture of all four Market-Based (Hubs) Pricing references a marker; e.g. Henry Hub in the United States or National Balancing Point (NBP) in the United Kingdom Alternative Fuels (e.g. Pricing references a competing fuel to retain competitiveness of gas; e.g. LNG into Japan priced against Japan Customs Cleared (JCC) price; pipe gas Oil, Oil Products, Coal) in Europe vs. HFO/diesel end-products (e.g. Pricing references a final product price; e.g. EOG in Trinidad sells gas to electricity, chemicals) local consumers at a price linked to exported methanol/ammonia FLAT RATE enalytica The price negotiated does not reference any external marker, except perhaps inflation; e.g. The Alba gas field in Equatorial Guinea sells to the LNG and a methanol plant at a flat rate Data. Analytics. Solutions. in Energy
Energy › Gas › LNG › Gas Pricing › conclusions !19 pricing structures › regional spreads › intra-region spreads › intra-country spreads › outlook No Such Thing as a “Global Gas” Price There has always been a major disparity between regional prices In 2012, Henry Hub in the United States averaged $2.76/MMBtu; the price in Japan was $16.75/MMBtu European pricing was somewhere in the middle: $9.46/MMBtu in the UK to $11.03/MMBtu in Germany ! 18 Gas Prices in Select Markets $/MMBtu Japan 16 14 12 Germany 10 UK 8 6 4 United States 2 0 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 Source: BP Statistical Review of World Energy (June 2013) enalytica Data. Analytics. Solutions. in Energy
Energy › Gas › LNG › Gas Pricing › conclusions !20 pricing structures › regional spreads › intra-region spreads › intra-country spreads › outlook No Such Thing even as an “Asian” Gas Price LNG prices in Asia ranged from $17.81/mcf on average in Japan to $11.52/mcf on average in China China and India have cheaper average prices due to some lower priced contracts signed in early 2000s From 2003 to 2008, Japan had lower prices than Korea and Taiwan; since 2010, it has had higher prices Gas Prices in Select Markets 20 $/mcf Japan Taiwan Korea 18 16 14 India China 12 10 8 6 4 2 0 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 Source: National Statistical Agencies, UN Comtrade, BP Statistical Review of World Energy (June 2013) enalytica Data. Analytics. Solutions. in Energy
Energy › Gas › LNG › Gas Pricing › conclusions !21 pricing structures › regional spreads › intra-region spreads › intra-country spreads › outlook pricing can vary even within countries For example, Korea paid $15.88/mcf for LNG in 2013 But bilateral prices ranged from $19.25/mcf (Norway) to $6.40/mcf (Russia) Individual contract terms can matter more than the destination country in general Korea LNG Supply Curve (2013) $/mcf 20 Oman 18 Qatar Brunei 16 14 Indonesia 12 Malaysia 10 Yemen 8 Russia 6 4 2 0 0 1 2 3 4 5 billion cubic feet / Day 6 Source: Korea International Trade Association (KITA), http://Kita.org (Accessed January 2014) enalytica Data. Analytics. Solutions. in Energy
Energy › Gas › LNG › Gas Pricing › conclusions !22 pricing structures › regional spreads › intra-region spreads › intra-country spreads › outlook Gas Pricing is Undergoing Fundamental Changes Gas pricing tends to go through cycles Surplus: prices tend to fall to the marginal cost of supply (cost-plus): $8-12/MMBtu Shortage: prices move to cost of alternative fuels or demand destruction (netback): $16-18/MMBtu Timing is everything — but pricing formulae can change Current market conditions pushing pricing towards cost-plus (e.g. US Gulf Coast) LNG pricing post 2020 will be driven by: How quickly will proposed projects move forward (turning possible supply into real supply)? The strategies of importers: will they create new supply and not renew old contracts? How will existing suppliers (e.g. Qatar) respond? Will they try to undercut new suppliers? How quickly will gas hubs develop (e.g. Singapore, Tokyo)? enalytica Data. Analytics. Solutions. in Energy
Energy › Gas › LNG › Gas Pricing › conclusions !23 Gas and LNG Market Fundamentals are strong Gas makes up a rising share of the world’s energy mix Demand for energy expected to rise by 1.2% a year through 2035, but gas grows faster at 1.6% Gas supplies 23.7% of total energy in 2035 (vs. 21.3% in 2011) Gas makes up 31% of growth in energy demand through 2035 LNG is the fastest growing part of the gas market LNG demand has grown 4x faster than overall gas demand in last decade LNG trade expected to grow by as much as 3.8% annually to 2030 Asia is the prize in terms of demand growth (75+% of total) and pricing Multiple supply options create downward pressure on pricing — suppliers must compete In gas pricing, micro (rather than macro) is still what matters enalytica Data. Analytics. Solutions. in Energy
‣ ‣ ‣ ‣ Natural gas market outlook Fundamentals of LNG Business Implications for Alaska Appendices enalytica Data. Analytics. Solutions. in Energy
Basics › structures › development risks › operations › Risk mitigation › conclusions !25 economic rationale › milestones › LNG sales and purchase agreements (SPAs) › domestic gas allocation Big, Upfront investment, Long-term revenue LNG projects take 4-5 years to build but run for 20-50 years with low maintenance / upkeep costs Majority of LNG projects have been expanded and/or taken gas from new fields Subpar rate of return tends to be bigger risk than outright “losing money” LNG Plant Cash Flow: Typical Plant 8 6 US$ billion 4 2 0 -2 -4 CAPEX Revenue -6 -4 enalytica -2 0 2 4 Liquefaction OPEX Government Take 6 8 10 12 Upstream OPEX Cash Flow 14 16 years 18 20 22 24 Data. Analytics. Solutions. in Energy
Basics › structures › development risks › operations › Risk mitigation › conclusions !26 economic rationale › milestones › LNG sales and purchase agreements (SPAs) › domestic gas allocation LNG projects move on many parallel fronts Upstream Delineate resource base, certify reserves, define production plan Midstream Define pipeline path, secure right-of-way, environmental permits Liquefaction Define project size, processing / gas quality, project structure Shipping Decide whether to own, lease or outsource shipping to buyers Marketing Define commercialization plan, secure buyers, sign contracts Financing Define financing plan, secure in-house and third-party lending Permitting Secure permits to construct facility, export gas Partners conduct front-end engineering and design studies (pre-FEED and FEED) They then sign engineering, procurement and construction (EPC) contracts Construction starts with final investment decision (FID); usually less than 10% of CAPEX spent before FID enalytica Data. Analytics. Solutions. in Energy
Basics › structures › development risks › operations › Risk mitigation › conclusions !27 economic rationale › milestones › LNG sales and purchase agreements (SPAs) › domestic gas allocation Pricing Pricing will refer to some alternative fuel (usually crude oil or oil products) and/or a gas marker (e.g. Henry Hub, NBP in the United Kingdom, etc.) Duration & Start For new projects, contracts are usually 15-20 years. Contracts will also specific start date (month / year) Destination clauses Destination clauses, which restrict which markets the LNG can be sold at, are increasingly out of favor—and are illegal in Europe. However, producers dislike when their gas is resold to third parties without any upside to them. LNG in Atlantic Basin is generally destination-free, Qatari equity marketed gas is flexible, and Pacific LNG has territorial restrictions. Volume quantity Contracts are typically take-or-pay: buyers can typically buy 10-20% more or less of their annual take-or-pay volumes— & Flexibility but they have to pay for LNG whether they lift it or not. Schedule & Logistics Estimated schedule for delivering cargoes (e.g. seasonality patterns) and logistics for delivery (e.g. tanker size) Gas Quality Specifications for gas, including any treatment of liquids Profit Sharing Some contracts allow the original seller to share the profit in case a cargo is diverted from its original source, but such provisions are illegal in Europe (they are considered to inhibit competition) Non-Compliance Penalties can involve non-delivery, delays, off-spec gas (different gas quality) Renegotiation Most contracts will allow price reviews every 3-4 years but usually within a band. Most contracts will also allow a onetime review clauses for extraordinary circumstances. Arbitration is usually required when parties cannot agree Title Transfer Specification of when the LNG transfers ownership from buyer to seller (e.g. FOB, CIF, DES) enalytica Data. Analytics. Solutions. in Energy
Basics › structures › development risks › operations › Risk mitigation › conclusions !28 economic rationale › milestones › LNG sales and purchase agreements (SPAs) › domestic gas allocation LNG exports Often linked to Domestic Gas sales LNG projects could either seek to scale up existing producing assets or may unlock stranded gas In cases where there is no existing production, LNG exports often serve as foundation for a local market The prospect of exports often incentivizes further exploration that benefits local and export markets Some jurisdictions (Indonesia, Western Australia) have explicit domestic gas reservation policies ! Examples Angola LNG will deliver 125 mmcf/d to the local market Bintulu LNG (Malaysia) makes possible gas consumption in the remote areas of Sarawak (east Malaysia) Donggi Senoro LNG (Indonesia) will couple exports with sales to local ammonia and power plants North West Shelf (Australia) started to supply local market 5 years before exports started (1984 / 1989) Yemen LNG sources gas from gas Marib Area—1 tcf of 9.15 has been allocated to local market Sources: Company press releases and Industry Press enalytica Data. Analytics. Solutions. in Energy
Basics › structures › development risks › operations › Risk mitigation › conclusions !29 integrated › merchant › tolling › trade-offs › state participation Integrated Projects distribute Value Internally Same companies own upstream and midstream—value driven by sales price (FOB/CIF) Distribution of value between upstream and midstream is an internal transfer question Transfer price may or may not be public Russia Qatar Algeria Upstream Liquefaction Sales Gas produced across Algeria Piped to shore Sonatrach 100% owned facilities FOB: $11.50/mcf Various LNG SPAs & direct marketing Gas produced from the North Field Varying ownerships Qatargas & RasGas Varying ownerships FOB: $11.36/mcf LNG pricing ranging from China: $20 North America >$3 Gas produced and piped across Sakhalin Island (500 miles of pipe) Sakhalin-2 LNG project Both trains same ownership FOB: $6.18/mcf Various SPAs Japan (76%): $15.40 Korea (20%): $8.10 Source: Company financial reports and country import statistics enalytica Internal Transaction | Third-Party Transaction Data. Analytics. Solutions. in Energy
Basics › structures › development risks › operations › Risk mitigation › conclusions !30 integrated › merchant › tolling › trade-offs › state participation Infrastructure owner drives pricing Infrastructure owner buys gas and sells LNG—value in differential between upstream and downstream FOB price does not need to be linked to upstream price (e.g. Equatorial Guinea) Upstream Liquefaction Sales Eq. Guinea Noble Energy: Alba Field 235 mmcf/d (2012) % sold to LNG $0.25/MMBtu Marathon-Operated: EG LNG T1 90% * Henry Hub linked FOB price: $2.57 FOB cost: under $1 BG Group LNG Sales to Japan (76%): $18.65 Korea (10%): $15.04 Taiwan: (5%): $20.38 Malaysia Murphy Oil: SK 309 and SK 311 174 mmcf/d (2012) 50% * LNG export price $7.50/mcf PETRONAS: Malaysia LNG Oil-linked pricing Various contracts (mostly cif) FOB: $15.64 LNG Sales to Japan (62%): $19.07 Korea (18%): $11.69 Taiwan: (12%): $19.11 Sabine Pass Upstream price can be netback (e.g. Malaysia LNG) or cost-plus (e.g. Sabine Pass) No single supplier Gas sourced from the market Henry Hub prompt month in 2013 $3.73/MMBtu Source: Company financial reports and country import statistics enalytica Cheniere Energy: Sabine Pass LNG SPAs 16-18 mmtpa BG Group, Gas Natural Fenosa 115% * Henry Hub + $2.25 to $3 GAIL, KOGAS FOB: $6.54 to $7.29 Companies can resell LNG for any price Internal Transaction | Third-Party Transaction Data. Analytics. Solutions. in Energy
Basics › structures › development risks › operations › Risk mitigation › conclusions !31 integrated › merchant › tolling › trade-offs › state participation LNG Akin to Pipeline: Pay a Fee to use Facility In a tolling structure, the supplier or buys pays the liquefaction owner a usage fee The infrastructure owner takes no ownership of the gas Liquefaction Sales Egyptian LNG BG Group (50%) and PETRONAS (50%) West Delta Deep Marine Conduct SPAs with off-takers Pay liquefaction plant a fee T1: BG 35.5%, PETRONAS 35.5% EGPC 12% EGAS 12%, GDF SUEZ 5% T2: BG 38%, PETRONAS 38% EGPC 12% EGAS 12% Train 1 sales 100% to GDF SUEZ Train 2 sales 100% to BG Group Various suppliers e.g. BG and partners 28.9% of gas supply Pay liquefaction plant a fee (est. $1/mcf) Upstream pricing is netback from FOB T4 : BP 38%, BG 29%, Shell 22%, NGC 11% FOB price (est. $5.16/mcf) Off-take proportional to gas supply Some suppliers may sell gas FOB Henry Hub pricing and profit sharing e.g. Japan ($13.63/mcf) Cameron Upstream Trinidad The relevant pricing is between supplier and buyer; infrastructure owner is “irrelevant” No single supplier Gas sourced from the market Source: Company financial reports and country import statistics enalytica ! Sempra 50.2% Mitsubishi, Mitsui and GDF SUEZ Mitsubishi 16.6% Pay LNG facility a tolling fee Mitsui 16.6% They also procure their own gas GDF SUEZ 16.6% Internal Transaction | Third-Party Transaction Data. Analytics. Solutions. in Energy
Basics › structures › development risks › operations › Risk mitigation › conclusions !32 integrated › merchant › tolling › trade-offs › state participation There is No “Right” Project Structure Type of resource base is often a major driver (size of initial resource, expansion potential, new fields) The partners risk appetite and desire to commit capital is another main driver Expansion prospects and competitive landscape is a third driver (# of companies that could supply gas) Advantages Integrated plants are simple—the only relevant point is Integrated the sales price to the off-take Disadvantages Integrated projects work when there is high partner alignment, a steady (not variable) source of gas and where all partners are equally interested in any expansions Project can accommodate new supply sources. Especially Multiple transaction points can cause tensions and/or Merchant useful to allow companies varying participation along the delays in the project. chain and to enable projects to tap new resources Tolling enalytica Very adaptable and able to accomodate changes in upstream supply. Easily scalable. Setting tolling fee can be a challenge, particularly in cases where the upstream players have a bias towards using their own supplies Data. Analytics. Solutions. in Energy
Basics › structures › development risks › operations › Risk mitigation › conclusions !33 integrated › merchant › tolling › trade-offs › state participation State Participation in LNG Projects varies Greatly Several states take no equity stake in LNG projects—they merely regulate and tax Most countries have some equity—but their involvement varies from passive to very active Equity stakes are held through national oil companies—Brunei and Norway (Petoro) are exceptions equity across chain Algeria, Malaysia, Qatar Angola Brunei Nigeria Australia, Canada, Indonesia (Tangguh), Peru, Russia (Yamal), USA state taxes and regulates Russia (Sakhalin-2), Indonesia (Bontang) Norway Eq. Guinea Egypt Yemen Abu Dhabi Oman Trinidad Active engagement with project operations Source: Ownership from GIIGNL, The LNG Industry in 2012, http://www.giignl.org/sites/default/files/publication/giignl_the_lng_industry_2012.pdf enalytica Data. Analytics. Solutions. in Energy
Basics › structures › development risks › operations › Risk mitigation › conclusions !34 delays to sanction project › partner drag › delays and cost overruns LNG Takes Time, often decades from First Discovery LNG projects are big, complex, multi-stakeholder agreements and they often take years to put together Challenges include offtake, capital, permits, partner commitment, or overcoming technical problems Several existing projects were stuck for a long-period of time in the planning phase ! Examples The Camisea complex (Peru) discovered in early 1980s, online in 2004 and exported LNG in 2010 The Gorgon gas field (Australia) discovered in 1981 with LNG exports starting in 2015 North Field (Qatar) was discovered in 1971, but LNG exports started in 1996 Shtokman (Russia) discovered in 1988, but still lacks a development path Snøhvit (Norway) was discovered in 1984 and LNG started in 2007 Atlantic LNG (Trinidad) project first mulled in 1970s, then again early 1980s; first LNG started in 1999 Sources: Company press releases and Industry Press; ViktoR, et. Al, “Natural Gas and Geopolitics” enalytica Data. Analytics. Solutions. in Energy
Basics › structures › development risks › operations › Risk mitigation › conclusions !35 delays to sanction project › partner drag › delays and cost overruns Partner alignment crucial for LNG Development Many LNG projects were developed by a different set of companies that first proposed the LNG project Partners with low portfolio fit and/or risk appetite can slow down project development Getting new partners is often a precondition for an LNG project to move forward ! Examples ExxonMobil pulled out of Angola LNG; Eni acquired stake soon thereafter Atlantic LNG (Trinidad) T2-3 needed new shareholding deal as Cabot and NGC did not want to participate Kitimat LNG (Canada) started off as Apache/EOG, then EnCana joined; now Chevron / Apache (50:50) PTT (Thailand) acquired Cove Energy to access gas that could supply an LNG project in Mozambique North Field (Qatar) discovered by Shell; Shell and later BP left; LNG developed by Mobil (now ExxonMobil) Marathon and McDermott sold out of Sakhalin Energy (Sakhalin-2 LNG in Russia) Sources: Company press releases and Industry Press; ViktoR, et. Al, “Natural Gas and Geopolitics” enalytica Data. Analytics. Solutions. in Energy
Basics › structures › development risks › operations › Risk mitigation › conclusions !36 delays to sanction project › partner drag › delays and cost overruns Project Sanctioned Target Date Actual Date DElay Budget BN Cost BN % Overrun Snøhvit (Norway) Egyptian LNG T1 Mar-02 Sep-02 2006 Aug-05 Sep-07 May-05 1.5 years 3 months early NOK39.50 $1.1 NOK48.00 on budget 21.5% 0% Sakhalin-2 (Russia) May-03 2007 Mar-09 2 years $10.0 $22.0 120.0% Atlantic LNG T4 (Trinidad) Jun-03 2005 Dec-05 on time $1.2 on budget 0% Egyptian LNG T2 Jul-03 Jun-06 Sep-05 9 months early $0.6 on budget 0% Equatorial Guinea Jun-04 Late 2007 May-07 6 months early $1.5 on budget 0% North West Shelf (Australia) Jun-05 2008 Sep-08 on time AUS$2 AUS$2.6 30.0% Yemen Aug-05 Dec-08 Nov-09 1 year $3.7 $4.5 21.6% Peru Jan-07 mid 2010 Jun-10 on time $3.8 $3.9 2.6% Pluto Jun-07 Early 2011 May-12 1.5 years AUS$11.2 AUS$14.9 33.0% Skikda LNG (Algeria) Jun-07 2011 Mar-13 2 years $2.8 ? ? Angola Dec-07 Early 2012 Jun-13 1.5-2 years ? $10.0 ? Gorgon (Australia) Sep-09 2014 n/a n/a $37.0 $54.0 45.9% Papua New Guinea Dec-09 2014 n/a n/a $15.0 $19.0 26.7% Queensland Curtis (Australia) Nov-10 2014 n/a n/a $15.0 $20.5 36.7% Gladstone LNG (Autralia) Jan-12 2015 n/a n/a $16.0 $18.5 15.6% Source: Company press releases and Industry Press enalytica Data. Analytics. Solutions. in Energy
Basics › structures › development risks › operations › Risk mitigation › conclusions !37 outages › domestic gas diversion › natural decline › demand shock: volume › demand shock: price Technical challenges can lead to frequent outages Historically, the LNG industry has operated plants at high utilization rates (85-90%) However, as projects become more technically complex, outages are a real risk For example, Snøhvit (Norway) has experienced frequent outages (2-3 months) since start-up in 2007 Outages 600 Outages Outages 700 Snøhvit LNG Plant (Norway): GAs Production MMCf/d 500 400 300 200 100 0 Sep-07 Mar-08 Sep-08 Mar-09 Sep-09 Mar-10 Sep-10 Mar-11 Sep-11 Mar-12 Sep-12 Mar-13 Sep-13 Source: Norwegian petroleum Directorate, Factpages, Production Monthly by Field (Accessed January 2014) enalytica Data. Analytics. Solutions. in Energy
Basics › structures › development risks › operations › Risk mitigation › conclusions !38 outages › domestic gas diversion › natural decline › demand shock: volume › demand shock: price supplying local markets can divert gas from LNG Indonesia has seen exports from its oldest facilities (Arun and Bontang) decline over time At issue is a combination of resource depletion and a need to divert gas to local markets Arun has been shut down and is being converted to an import terminal Arun and Bontang LNG Plants (Indonesia): GAs Exports 3.5 3.0 bCf/d 3.15 3.26 3.04 3.01 3.05 3.03 2.81 2.96 2.81 2.80 Bontang Arun 2.67 2.54 2.5 2.0 2.24 1.75 1.62 1.5 1.03 1.0 0.95 0.97 0.87 0.65 0.46 0.5 0.53 0.44 0.40 0.34 0.30 0.18 0.14 0.0 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 Sources: Pengkajian Energi Universitas Indonesia, Indonesia Energy Outlook & Statistics 2006, Ministry of Energy and Natural Resources, “Statistik Gas Bumi 2012” enalytica Data. Analytics. Solutions. in Energy
Basics › structures › development risks › operations › Risk mitigation › conclusions !39 outages › domestic gas diversion › natural decline › demand shock: volume › demand shock: price Feedstock Maturity Can Lead to Rapid Decline Kenai was the second LNG project in the world and it supplied Japan continuously since 1969 As production matured, however, exports faced a precipitous decline: from 2007 to 2012 fell 25% a year Matching the production profile to LNG sales contracts is essential to mitigate any penalties LNG Exports from Alaska to Japan 200 MMCf/d 180 178 160 140 120 100 80 60 40 20 26 0 1975 1977 1979 1981 1983 1985 1987 1989 1991 1993 1995 1997 1999 2001 2003 2005 2007 2009 2011 Source: US Energy Information Administration,Alaska Liquefied Natural Gas Exports to Japan (Accessed January 2014) enalytica Data. Analytics. Solutions. in Energy
Basics › structures › development risks › operations › Risk mitigation › conclusions !40 outages › domestic gas diversion › natural decline › demand shock: volume › demand shock: price Demand Shock led to output losses— But long ago Algeria experienced two waves of LNG output contraction in the 1980s and early 1990s Both were driven by declines in demand for Algerian LNG from the United States (and, less so, France) But the depth of the current LNG market has meant that producers face price but not output risk LNG Exports from Algeria ! 2,500 mmcf/d For example, Snøhvit (Norway) has experienced frequent outages since coming online in 2007 2,002 2,000 1,872 1,903 1,948 1,800 1,709 1,548 1,500 1,198 1,250 1,768 1,485 1,222 1,003 1,000 644 500 1,382 USA Total 235 743 359 101 151 1981 1982 99 65 - 1984 1985 1986 0 1980 1983 - 48 116 1987 1988 1989 231 1990 224 174 118 1991 1992 1993 139 1994 49 1995 Sources: US Energy Information Administration,U.S. LNG Imports From Algeria (Accessed January 2014), Ministère de l’Energie et des Mines, Energy Balance 1980-2004 enalytica Data. Analytics. Solutions. in Energy
Basics › structures › development risks › operations › Risk mitigation › conclusions !41 outages › domestic gas diversion › natural decline › demand shock: volume › demand shock: price Price Risk More Important than Volume Risk Market fundamentals affect price rather than volume (2012 utilization was over 100%) Qatar earns vastly different prices across markets: $20/mcf in China to sub-$3/mcf in North America Lower prices reflect contracts linked to low benchmarks (e.g. Belgium) or LNG “pushed into” markets 25 Qatar: LNG Price Curve (2012) (markets Accounting for 89% of total sales) $/mcf China 20 Korea Japan Italy 15 10 India United Kingdom 5 billion cubic feet / Day 0 0 1 2 3 4 5 6 7 8 9 10 Sources: international gas union, World LNG Report 2013 (June 2013), UN Comtrade Database (Accessed January 2014) enalytica Data. Analytics. Solutions. in Energy
Basics › structures › development risks › operations › Risk mitigation › conclusions !42 marketing integration › third-party financing › pricing bands › renegotiation Buyers Often Take Equity | Partners off-take LNG In half of the world’s LNG capacity, a share of the LNG is sold to equity partners Such deals can mitigate risk by aligning supplier-buyer interests (e.g. output shortfall) Buyers get sense of supply security, and these deals often open up the project to third-party financing PErcent Of LNG Capacity Sold to Equity Partners Projects Online in 2012 % LNG Sold to Partners 100% 90% Partners take all the LNG 80% 70% Share of LNG Sold to Partners 60% 50% 40% 30% 20% buyers have no Equity 10% 0% 0% 10% 20% 30% 40% 50% 60% 70% % LNG Capacity 80% 90% 100% Source: Based on GIIGNL, The LNG Industry in 2012, http://www.giignl.org/sites/default/files/publication/giignl_the_lng_industry_2012.pdf enalytica Data. Analytics. Solutions. in Energy
Basics › structures › development risks › operations › Risk mitigation › conclusions !43 marketing integration › third-party financing › pricing bands › renegotiation Project Finance well established in LNG IHS estimates that LNG projects raised over $97 billion in third-party financing since 2000 Financing from project sponsors, export credit agencies, multilateral banks and commercial banks Commercial loans can also secure sovereign guarantees as insurance The Japan Bank of International Cooperation (JBIC) is the largest single provider of funds Examples AP LNG Ichthys Papua New Guinea Peru Sakhalin-2 Tangguh $5.8 billion $20 billion $14 billion $2.25 billion $6.4 billion $3.5 billion US EXIM, China EXIM, banks JBIC, Korea and Australia EXIM, banks, sponsors ($4 bn) Six ECAs and 17 banks, ExxonMobil IADB, US EXIM, Korea EXIM, IFC, others JBIC, NEXI, banks JBIC, ADB, banks Sources: IHS in Ledesma, et. Al, “The Commercial and Financing Challenges of an Increasingly Complex LNG Chain,” LNG 17 (April 2013); Industry press enalytica Data. Analytics. Solutions. in Energy
Basics › structures › development risks › operations › Risk mitigation › conclusions !44 marketing integration › third-party financing › pricing bands › renegotiation Pricing formula can reduce price volatility “S-curves” are clauses that change the relationship between oil and gas above or below thresholds Instead of a linear link, gas prices do not rise/fall as much if oil prices rise/fall above certain thresholds They reduce downside risk by forgoing some upside—they can even provide a floor/ceiling on prices ! ! No S-Curve S-Curve Floor / ceiling ! ! LNG Sales Price ! Oil or other reference Price enalytica Data. Analytics. Solutions. in Energy
Basics › structures › development risks › operations › Risk mitigation › conclusions !45 marketing integration › third-party financing › pricing bands › renegotiation Worst case, there is always renegotiation Most LNG contracts include price review clauses—especially for fundamental / unforeseen changes Most renegotiations focus on pricing—but European disputes have included volumes (take-or-pay) Disputes between states and companies usually center on upside that is not flowing back to the state ! Examples BG and its Chilean buyers renegotiated to raise LNG prices Brunei and Japanese buyers adjusted their price formula—as a result prices tripled from 2007 to 2008 Gas Natural and Atlantic LNG went to arbitration and add a US-based reference price to their contract RasGas gave a price discount to Edison (Italy) after arbitration settlement ($580 mm in 2012) Yemen LNG increased its LNG sales prices towards GDF SUEZ, TOTAL, KOGAS Sources: Company press releases and Industry Press enalytica Data. Analytics. Solutions. in Energy
Basics › structures › development risks › operations › Risk mitigation › conclusions !46 LNG Projects are Big, Complex and Multi-layered LNG projects take years (even decades) from first discovery to commercial production They require a large capital commitment upfront—but deliver long-term revenue thereafter No such thing as a “standard” project structure that Alaska can “adopt” Complexity means that value creation and distribution is often a product of negotiation States’ participation varies from not at all to fully involved throughout the value chain LNG projects are often used to unlock stranded gas that is also supplied to local markets LNG projects face many risks—but have established mechanisms for risk-management and mitigation Third-party finance, marketing integration and pricing bands can reduce exposure/volatility Price review clauses allow counter-parties to provide reprieve to grave imbalances LNG projects tend to be partnerships between many private and state-owned enterprises enalytica Data. Analytics. Solutions. in Energy
‣ ‣ ‣ ‣ Natural gas market outlook fundamentals of LNG Business Implications for Alaska Appendices enalytica Data. Analytics. Solutions. in Energy
Implications for Alaska !48 key questions › decision matrix path forward requires answers to Key Questions How should Alaska take its gas share? Should the state take equity in the project and if so, in what parts of the value chain? If the state decides to take its gas entitlement in kind, how will it market that gas? What is the state’s appetite for risk, and what type of risk? What type of risk mitigators will make the state more comfortable about participating in an LNG project? Is the state prepared to forgo some upside in order to be better protected on the downside? What project structure can expedite development while allowing the project to evolve with time? What are the state’s long-run revenue needs and how might the LNG project help meet those needs? enalytica Data. Analytics. Solutions. in Energy
Implications for Alaska !49 key questions › decision matrix Alaska HAs Many Ways to Participate in LNG Project State’s Gas gas in value: Key question is how to negotiate a “fair” transfer price gas in Kind Agency marketing (Companies Sell gas on Alaska’s Behalf) State markets Gas in-state Sales FOB (Buyers Do Shipping) CIF (Alaska Does Shipping) equity across chain Agency marketing or state markets gas Agency marketing or state markets gas Gas in value state taxes and regulates enalytica Active engagement with project operations Data. Analytics. Solutions. in Energy
‣ ‣ ‣ ‣ Natural gas market outlook fundamentals of LNG Business implications for Alaska Appendices enalytica Data. Analytics. Solutions. in Energy
Our Team !51 Janak Mayer › Nikos Tsafos Before co-founding enalytica, Janak led the Upstream Analytics team at PFC Janak Mayer Partner enalytica! ! janak.mayer@enalytica.info Energy, focusing on fiscal terms analysis and project economic and financial evaluation, data management and data visualization. Janak has modeled upstream fiscal terms in all of the world’s major hydrocarbon regions, and has built economic and financial models to value prospective acquisition targets and develop strategic portfolio options for a wide range of international and national oil company clients. He has advised Alaska State Legislature for multiple years on reform of oil and gas taxation, providing many hours of expert testimony to Alaska’s Senate and House Finance and Resources Committees. Prior to his work as an energy consultant, Janak advised major minerals industry clients on a range of controversial environmental and social risk issues, from uranium mining through to human rights and climate change. He has advised bankers at Citigroup and policy-makers at the US Treasury Department on the management and mitigation of environmental and social impacts in major projects around the world, and has undertaken macroeconomic research with senior development economists at the World Bank and the Peterson Institute for International Economics. Janak holds an MA with distinction in international relations and economics from from the Johns Hopkins School of Advanced International Studies (SAIS), and a BA with first-class honors from the University of Adelaide, Australia. enalytica Data. Analytics. Solutions. in Energy
Our Team !52 Janak Mayer › Nikos Tsafos Nikos Tsafos Partner enalytica! ! nikos.tsafos@enalytica.info Nikos Tsafos has a diverse background in the private, public and non-profit sectors. He is currently a founding partner at enalytica. In his 7 ½ years with PFC Energy, Nikos advised the world’s largest oil and gas companies on some of their most complex and challenging projects; he also played a pivotal role in turning the firm into one of the top natural gas consultancies in the world, with responsibilities that included product design, business development, consulting oversight and research direction. Prior to PFC Energy, Nikos was at the Center for Strategic and International Studies (CSIS) in Washington, DC where he covered political, economic, and military issues in the Gulf, focused on oil wealth, regime stability and foreign affairs. Before CSIS, he was in the Greek Air Force, and prior to his military service, Nikos worked on channeling investment from Greek ship-owners to Chinese shipyards. Nikos has also written extensively on the domestic and international dimensions of the Greek debt crisis. His blog (Greek Default Watch) was listed as one of “Europe’s Top Economic Blogs” by the Social Europe Journal, and his book “Beyond Debt: The Greek Crisis in Context” was published in March 2013. Nikos holds a BA with distinction in international relations and economics from Boston University and an MA with distinction in international relations from the Johns Hopkins School of Advanced International Studies (SAIS). enalytica Data. Analytics. Solutions. in Energy
http://enalytica.info enalytica Data. Analytics. Solutions. in Energy

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Gas Market Outlook & LNG Business Fundamentals

  • 1.
    Natural Gas MarketOutlook & Fundamentals of LNG Business Prepared for the Alaska State Legislature Juneau, Alaska › January 28, 2014 ! Janak Mayer, Partner › janak.mayer@enalytica.info Nikos Tsafos, Partner › nikos.tsafos@enalytica.info http://enalytica.info enalytica Data. Analytics. Solutions. in Energy
  • 2.
    Executive Summary !2 gas marketoutlook › LNG business fundamentals › implications for Alaska Gas and LNG Market Fundamentals are strong Gas makes up a rising share of the world’s energy mix Demand for energy expected to rise by 1.2% a year through 2035, but gas grows faster at 1.6% Gas supplies 23.7% of total energy in 2035 (vs. 21.3% in 2011) Gas makes up 31% of growth in energy demand through 2035 LNG is the fastest growing part of the gas market LNG demand has grown 4x faster than overall gas demand in last decade LNG trade expected to grow by as much as 3.8% annually to 2030 Asia is the prize in terms of demand growth (75+% of total) and pricing Multiple supply options create downward pressure on pricing — suppliers must compete In gas pricing, micro (rather than macro) is still what matters enalytica Data. Analytics. Solutions. in Energy
  • 3.
    Executive Summary !3 gas marketoutlook › LNG business fundamentals › implications for Alaska LNG Projects are Big, Complex and Multi-layered LNG projects take years (even decades) from first discovery to commercial production They require a large capital commitment upfront—but deliver long-term revenue thereafter No such thing as a “standard” project structure that Alaska can “adopt” Complexity means that value creation and distribution is often a product of negotiation States’ participation varies from not at all to fully involved throughout the value chain LNG projects are often used to unlock stranded gas that is also supplied to local markets LNG projects face many risks—but have established mechanisms for risk-management and mitigation Third-party finance, marketing integration and pricing bands can reduce exposure/volatility Price review clauses allow counter-parties to provide reprieve to grave imbalances LNG projects tend to be partnerships between many private and state-owned enterprises enalytica Data. Analytics. Solutions. in Energy
  • 4.
    Executive Summary !4 gas marketoutlook › LNG business fundamentals › implications for Alaska Alaska HAs Many Ways to Participate in LNG Project State’s Gas gas in value: Key question is how to negotiate a “fair” transfer price gas in Kind Agency marketing (Companies Sell gas on Alaska’s Behalf) State markets Gas in-state Sales FOB (Buyers Do Shipping) CIF (Alaska Does Shipping) equity across chain Agency marketing or state markets gas Agency marketing or state markets gas Gas in value state taxes and regulates enalytica Active engagement with project operations Data. Analytics. Solutions. in Energy
  • 5.
    ‣ ‣ ‣ ‣ Natural gas marketoutlook fundamentals of LNG business Implications for Alaska Appendices enalytica Data. Analytics. Solutions. in Energy
  • 6.
    Energy › Gas› LNG › Gas Pricing › conclusions !6 energy supply-demand matrix in 2011 › energy demand drivers › energy demand forecast Energy demand has more than tripled since 1960 Oil provides 31% of total energy and is chiefly a transportation fuel Coal provides 29%, chiefly for power; gas makes up 21.3% of total energy (of which 40% for power) Nuclear and hydro provide a total of 7.5% all in power; biomass (10%) still large in residential use Coal Primary Supply Power/Heat Other Trnsfr Industry Transport Res/Comm/Agr Non-Energy % Total 3,776.1 (2,365.6) 506.8 728.9 3.4 132.1 39.2 28.8% Oil & Products 4,136.0 (283.5) 219.2 323.2 2,265.2 436.1 608.8 31.5% Energy Matrix in MMTOE (2011) Natural Biofuels & Nuclear Hydro Gas Waste 2,787.0 674.0 300.2 1,312.2 (1,118.2) (674.0) (300.2) (134.6) 288.3 65.8 506.4 198.2 92.5 58.6 610.2 855.0 171.4 21.3% 5.1% 2.3% 10.0% Other Total 128.1 2,143.5 383.1 800.1 25.2 1,063.1 1.0% 13,113.4 (2,732.7) 1,463.2 2,556.8 2,444.9 3,096.4 819.4 100% Source: International energy agency, Key world Energy Statistics 2013 enalytica Data. Analytics. Solutions. in Energy
  • 7.
    Energy › Gas› LNG › Gas Pricing › conclusions !7 energy supply-demand matrix in 2011 › energy demand drivers › energy demand forecast strong fundamentals support higher energy usE +0.9% p.a. +1.8 billion 51% › 61% +1.75 billion +3.6% p.a. +240% Total +2.6% p.a. +90% Total -2.2% P.A. +1.25% p.a. non-oecd driven 43% Less Energy 2.5x 2.5x 2x 2x 1.5x 1.5x 1x 1x 0.5x 0.5x Population Urbanization Real GDP 2010 2015 GDP/capita 2020 2025 2030 Energy Use Energy Intensity 2035 Source: UN Population Prospects (2012); UN, World Urbanization Prospects (2011) ; IEA, world Energy Outlook; OECD, Long-term GDP Projections (June 2013) enalytica Data. Analytics. Solutions. in Energy
  • 8.
    Energy › Gas› LNG › Gas Pricing › conclusions !8 energy supply-demand matrix in 2011 › energy demand drivers › energy demand forecast IEA Forecasts Energy to Grow at 1.2% By 2035 Gas accounts for 31% of energy growth (1.6% annual growth); share of total energy from 21.3% to 23.7% Coal plateaus in the 2020s and its share of total energy shrinks to 25.5% (vs. 28.8% in 2010) Percent of fossil fuels declines from 81.6% in 2010 to 76% in 2035 Energy Supply by Fuel 20,000 mmtoe Coal 18,000 Oil Gas Nuclear Hydro Biomass Other 16,000 14,000 12,000 10,000 8,000 6,000 4,000 2,000 0 2011 2020 2025 2030 2035 Source: International energy agency, World Energy Outlook 2013 (November 2013) enalytica Data. Analytics. Solutions. in Energy
  • 9.
    Energy › Gas› LNG › Gas Pricing › conclusions !9 units › regional balances › trade corridors › gas demand forecast gas units and conversions bbl barrel (oil) 1 bbl = 6 thousand cubic feet (6 mcf) $/bbl dollars per barrel (oil) $6/bbl = $1/mcf ≃ $1/mmbtu mmbtu million British thermal units $1/mmbtu ≃ $1/mcf mmcf/d million cubic feet per day 1,000 mmcf/d = 7.8 mmtpa = 10.3 bcm/yr bcf/d billion cubic feet per day 1 bcf/d = 7.8 mmtpa = 10.3 bcm/yr bcm billion cubic meters 1 bcm/y = 0.73 mmtpa = 96.7 mmcf/d mmtpa million tons per annum (LNG) 1 mmtpa = 1.37 bcm = 48.37 bcf/y = 132 mmcf/d mmtoe million tons of oil equivalent 1 mmtoe = 1.11 bcm = 39.2 bcf = 107.4 mmcf/d enalytica Data. Analytics. Solutions. in Energy
  • 10.
    Energy › Gas› LNG › Gas Pricing › conclusions !10 units › regional balances › trade corridors › gas demand forecast Only 30% of global gas Is traded (vs. 64% of Oil) Europe and Asia are deficit regions (71% of imports); FSU is the largest surplus region (26% of exports) North America is the biggest producer (27% of global) and consumer (27% of global); it is in small deficit 68% of gas trade by pipeline; 32% as liquefied natural gas (LNG) N. America S. America Europe FSU Middle East Africa Asia Pacific Total Production bcf/d % 86.5 27% 17.1 5% 25.5 8% 74.4 23% 52.9 16% 20.9 6% 47.3 15% 324.6 100% Regional Balances (2012) in BCF/D Exports Imports bcf/d % bcf/d % 12.5 13% 13.6 14% 4.0 4% 3.1 3% 19.9 20% 43.2 43% 26.1 26% 8.9 9% 15.4 15% 3.3 3% 9.7 10% 0.6 1% 12.4 12% 27.3 27% 99.9 100% 99.9 100% Net bcf/d -1.0 0.9 -23.3 17.2 12.1 9.1 -15.0 0.0 Demand bcf/d 87.5 15.9 48.0 56.5 39.7 11.8 60.3 319.8 % 27% 5% 15% 18% 12% 4% 19% 100% Source: BP Statistical Review of World Energy (June 2013) enalytica Data. Analytics. Solutions. in Energy
  • 11.
    Energy › Gas› LNG › Gas Pricing › conclusions !11 units › regional balances › trade corridors › gas demand forecast More than Half (58%) of gas trade within regions Intra-regional trade patterns Intra-European trade accounts for 19.5% of the volumes traded internationally Intra-North America and Intra-Asia Pacific make up another 12.5% each Intra-FSU trade makes up 9% of total trade, mostly originating from Russia Inter-regional trade patterns Trade from FSU to Europe is the largest inter-regional trade route (13% of global) Middle East and Africa into Europe almost as big (10.3% of global trade) Middle East to Asia (9%) and FSU to Asia (3.5%) other major routes Source: BP Statistical Review of World Energy (June 2013) enalytica Data. Analytics. Solutions. in Energy
  • 12.
    Energy › Gas› LNG › Gas Pricing › conclusions !12 units › regional balances › trade corridors › gas demand forecast IEA puts Gas Demand Growth at 1.6% through 2035 OECD accounts for 18% of demand growth; non-OECD 82% Asia accounts for 44% of incremental demand; Middle East follows by 19.5% OECD North America grows faster than OECD Europe / OECD Asia due to cheaper gas prices Gas Demand by Region 600 BCF/d N. America Latin America Europe FSU Asia Mid East 500 400 Africa 481 bcf/d 326 bcf/d 300 200 100 0 2011 2020 2025 2030 2035 Source: International energy agency, World Energy Outlook 2013 (November 2013) enalytica Data. Analytics. Solutions. in Energy
  • 13.
    Energy › Gas› LNG › Gas Pricing › conclusions !13 regional overview › suppliers › consumers › demand outlook › supply outlook LNG Market was 31.7 bcf/d in 2012 Middle East is largest surplus region (+12.3 bcf/d); Asia is largest deficit region (-11.5 bcf/d) Around 70% of LNG went to Asia and 21% to Europe South America and Middle East are recent importers (since 2008); they took in 6% of demand in 2012 Middle East (40%) and Asia Pacific (33.2%) were the largest suppliers of LNG Africa is the next largest supplier (Algeria, Nigeria, Eq. Guinea, Egypt) with 16.5% of exports Middle East Africa S. & C. America N. America Europe Asia Pacific Total LNG Imports and Exports in 2012 Imports Exports bcf/d % Total bcf/d 0.4 1.4% 12.7 0.0 0.0% 5.2 1.5 4.6% 2.4 1.1 3.5% 0.1 6.7 21.1% 0.8 22.0 69.3% 10.5 31.7 100% 31.7 % Total 40.1% 16.5% 7.6% 0.2% 2.4% 33.2% 100% Net bcf/d 12.3 5.2 0.9 -1.0 -5.9 -11.5 0.0 Source: BP Statistical Review of World Energy (June 2013) enalytica Data. Analytics. Solutions. in Energy
  • 14.
    Energy › Gas› LNG › Gas Pricing › conclusions !14 regional overview › suppliers › consumers › demand outlook › supply outlook Qatar is by far Largest LNG Exporter (32.6% Total) Five countries (Qatar, Malaysia, Australia, Nigeria, Indonesia, Trinidad) make up 73% of supply Russia, Peru, and Yemen have all started to export after 2008. Angola started exports in 2013 90 80 LNG Exports (2012) mmtons % Total 32.6% 35% 30% 70 25% 60 50 20% 40 15% 8.7% 8.4% 20 7.6% 6.1% 10% 4.6% 4.6% 10 3.4% 2.9% 2.3% 2.2% 2.1% 1.6% 1.6% 1.4% Norway Eq. Guinea Peru Egypt Yemen UAE Brunei Oman Russia Algeria Trinidad Indonesia Nigeria Australia Malaysia Qatar 0 0.1% 5% 0% USA 9.7% 30 Source: international gas union, World LNG Report 2013 (June 2013) enalytica Data. Analytics. Solutions. in Energy
  • 15.
    Energy › Gas› LNG › Gas Pricing › conclusions !15 regional overview › suppliers › consumers › demand outlook › supply outlook LNG Demand concentrated among few buyers Two markets (Japan and Korea) account for 50% of demand Six countries (Japan, Korea, China, Spain, India, Taiwan) make up 75% of demand 15 countries import less than 2% of global demand each — but more and more countries importing LNG % Total 36.7% 40% 35% 30% 25% 20% 15.5% 15% 6.2% 6.0% 5.9% 5.4% 4.4% 3.1% 2.4% 2.2% 1.6% 1.5% 1.4% 1.3% 1.1% 0.9% 0.8% 0.7% 0.5% 0.5% 0.5% 0.4% 0.4% 0.4% 10% 5% Dom. Rep. Puerto Rico Thailand Greece UAE Canada Portugal Belgium Kuwait Brazil Chile USA Mexico Argentina Italy Turkey France UK Taiwan India Spain China Korea 0% Japan 100 90 80 70 60 50 40 30 20 10 0 LNG Imports (2012) mmtons Source: international gas union, World LNG Report 2013 (June 2013) enalytica Data. Analytics. Solutions. in Energy
  • 16.
    Energy › Gas› LNG › Gas Pricing › conclusions !16 regional overview › suppliers › consumers › demand outlook › supply outlook LNG demand to grow 3.8% a year to 2030 Asia has been and remains the dominant market for LNG and accounts for 75+% of demand growth Demand for LNG in Americas flat; shale shrinks N. America’s needs but S. America grows Europe flat through 2020 but growth thereafter driven by resource maturity Middle East and Africa fastest growing markets but volumetrically make bigger impact post 2020 LNG Imports in MMTPA 2010 2015 2020 2030 Δ: 10-30 Δ: 10-30 Americas 21 20 16 19 -2 -0.3% Europe 64 28 60 98 34 6.5% Mid East/Africa 3 6 10 38 35 9.7% Asia 129 200 256 377 248 3.2% Total 217 254 342 532 315 3.8% Source: Wood Mackenzie LNG Forecast (Data from Cheniere IR Presentation in January 2014) enalytica Data. Analytics. Solutions. in Energy
  • 17.
    Energy › Gas› LNG › Gas Pricing › conclusions !17 regional overview › suppliers › consumers › demand outlook › supply outlook Many possible Suppliers, Many Risks to manage Over 34 tcf in north slope but Uncertain Fiscal terms/ project economics Large Scale Resources But technical risks Sizable stranded gas but high costs Ample possible Shale Gas but need for infrastructure and commercial viability Cheap Gas, but Slow permitting process and possible Price volatility Over 30 tcf but significant political risks Much Associated gaS but local markets take priority Qatar / Iran huge resource; local markets priority, Economics, politics Sizable undeveloped gas But Local market take priority Much Associated gas But local markets take priority Over 100 tcf But high cost of entry, low government capacity, High infrastructure needs enalytica Sizable remaining resources but exorbitant costs Data. Analytics. Solutions. in Energy
  • 18.
    Energy › Gas› LNG › Gas Pricing › conclusions !18 pricing structures › regional spreads › intra-region spreads › intra-country spreads › outlook GAs Pricing structures highly variable Gas pricing can be either cost-plus or market netback Gas is usually priced in any of four alternative ways; some deals could include a mixture of all four Market-Based (Hubs) Pricing references a marker; e.g. Henry Hub in the United States or National Balancing Point (NBP) in the United Kingdom Alternative Fuels (e.g. Pricing references a competing fuel to retain competitiveness of gas; e.g. LNG into Japan priced against Japan Customs Cleared (JCC) price; pipe gas Oil, Oil Products, Coal) in Europe vs. HFO/diesel end-products (e.g. Pricing references a final product price; e.g. EOG in Trinidad sells gas to electricity, chemicals) local consumers at a price linked to exported methanol/ammonia FLAT RATE enalytica The price negotiated does not reference any external marker, except perhaps inflation; e.g. The Alba gas field in Equatorial Guinea sells to the LNG and a methanol plant at a flat rate Data. Analytics. Solutions. in Energy
  • 19.
    Energy › Gas› LNG › Gas Pricing › conclusions !19 pricing structures › regional spreads › intra-region spreads › intra-country spreads › outlook No Such Thing as a “Global Gas” Price There has always been a major disparity between regional prices In 2012, Henry Hub in the United States averaged $2.76/MMBtu; the price in Japan was $16.75/MMBtu European pricing was somewhere in the middle: $9.46/MMBtu in the UK to $11.03/MMBtu in Germany ! 18 Gas Prices in Select Markets $/MMBtu Japan 16 14 12 Germany 10 UK 8 6 4 United States 2 0 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 Source: BP Statistical Review of World Energy (June 2013) enalytica Data. Analytics. Solutions. in Energy
  • 20.
    Energy › Gas› LNG › Gas Pricing › conclusions !20 pricing structures › regional spreads › intra-region spreads › intra-country spreads › outlook No Such Thing even as an “Asian” Gas Price LNG prices in Asia ranged from $17.81/mcf on average in Japan to $11.52/mcf on average in China China and India have cheaper average prices due to some lower priced contracts signed in early 2000s From 2003 to 2008, Japan had lower prices than Korea and Taiwan; since 2010, it has had higher prices Gas Prices in Select Markets 20 $/mcf Japan Taiwan Korea 18 16 14 India China 12 10 8 6 4 2 0 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 Source: National Statistical Agencies, UN Comtrade, BP Statistical Review of World Energy (June 2013) enalytica Data. Analytics. Solutions. in Energy
  • 21.
    Energy › Gas› LNG › Gas Pricing › conclusions !21 pricing structures › regional spreads › intra-region spreads › intra-country spreads › outlook pricing can vary even within countries For example, Korea paid $15.88/mcf for LNG in 2013 But bilateral prices ranged from $19.25/mcf (Norway) to $6.40/mcf (Russia) Individual contract terms can matter more than the destination country in general Korea LNG Supply Curve (2013) $/mcf 20 Oman 18 Qatar Brunei 16 14 Indonesia 12 Malaysia 10 Yemen 8 Russia 6 4 2 0 0 1 2 3 4 5 billion cubic feet / Day 6 Source: Korea International Trade Association (KITA), http://Kita.org (Accessed January 2014) enalytica Data. Analytics. Solutions. in Energy
  • 22.
    Energy › Gas› LNG › Gas Pricing › conclusions !22 pricing structures › regional spreads › intra-region spreads › intra-country spreads › outlook Gas Pricing is Undergoing Fundamental Changes Gas pricing tends to go through cycles Surplus: prices tend to fall to the marginal cost of supply (cost-plus): $8-12/MMBtu Shortage: prices move to cost of alternative fuels or demand destruction (netback): $16-18/MMBtu Timing is everything — but pricing formulae can change Current market conditions pushing pricing towards cost-plus (e.g. US Gulf Coast) LNG pricing post 2020 will be driven by: How quickly will proposed projects move forward (turning possible supply into real supply)? The strategies of importers: will they create new supply and not renew old contracts? How will existing suppliers (e.g. Qatar) respond? Will they try to undercut new suppliers? How quickly will gas hubs develop (e.g. Singapore, Tokyo)? enalytica Data. Analytics. Solutions. in Energy
  • 23.
    Energy › Gas› LNG › Gas Pricing › conclusions !23 Gas and LNG Market Fundamentals are strong Gas makes up a rising share of the world’s energy mix Demand for energy expected to rise by 1.2% a year through 2035, but gas grows faster at 1.6% Gas supplies 23.7% of total energy in 2035 (vs. 21.3% in 2011) Gas makes up 31% of growth in energy demand through 2035 LNG is the fastest growing part of the gas market LNG demand has grown 4x faster than overall gas demand in last decade LNG trade expected to grow by as much as 3.8% annually to 2030 Asia is the prize in terms of demand growth (75+% of total) and pricing Multiple supply options create downward pressure on pricing — suppliers must compete In gas pricing, micro (rather than macro) is still what matters enalytica Data. Analytics. Solutions. in Energy
  • 24.
    ‣ ‣ ‣ ‣ Natural gas marketoutlook Fundamentals of LNG Business Implications for Alaska Appendices enalytica Data. Analytics. Solutions. in Energy
  • 25.
    Basics › structures› development risks › operations › Risk mitigation › conclusions !25 economic rationale › milestones › LNG sales and purchase agreements (SPAs) › domestic gas allocation Big, Upfront investment, Long-term revenue LNG projects take 4-5 years to build but run for 20-50 years with low maintenance / upkeep costs Majority of LNG projects have been expanded and/or taken gas from new fields Subpar rate of return tends to be bigger risk than outright “losing money” LNG Plant Cash Flow: Typical Plant 8 6 US$ billion 4 2 0 -2 -4 CAPEX Revenue -6 -4 enalytica -2 0 2 4 Liquefaction OPEX Government Take 6 8 10 12 Upstream OPEX Cash Flow 14 16 years 18 20 22 24 Data. Analytics. Solutions. in Energy
  • 26.
    Basics › structures› development risks › operations › Risk mitigation › conclusions !26 economic rationale › milestones › LNG sales and purchase agreements (SPAs) › domestic gas allocation LNG projects move on many parallel fronts Upstream Delineate resource base, certify reserves, define production plan Midstream Define pipeline path, secure right-of-way, environmental permits Liquefaction Define project size, processing / gas quality, project structure Shipping Decide whether to own, lease or outsource shipping to buyers Marketing Define commercialization plan, secure buyers, sign contracts Financing Define financing plan, secure in-house and third-party lending Permitting Secure permits to construct facility, export gas Partners conduct front-end engineering and design studies (pre-FEED and FEED) They then sign engineering, procurement and construction (EPC) contracts Construction starts with final investment decision (FID); usually less than 10% of CAPEX spent before FID enalytica Data. Analytics. Solutions. in Energy
  • 27.
    Basics › structures› development risks › operations › Risk mitigation › conclusions !27 economic rationale › milestones › LNG sales and purchase agreements (SPAs) › domestic gas allocation Pricing Pricing will refer to some alternative fuel (usually crude oil or oil products) and/or a gas marker (e.g. Henry Hub, NBP in the United Kingdom, etc.) Duration & Start For new projects, contracts are usually 15-20 years. Contracts will also specific start date (month / year) Destination clauses Destination clauses, which restrict which markets the LNG can be sold at, are increasingly out of favor—and are illegal in Europe. However, producers dislike when their gas is resold to third parties without any upside to them. LNG in Atlantic Basin is generally destination-free, Qatari equity marketed gas is flexible, and Pacific LNG has territorial restrictions. Volume quantity Contracts are typically take-or-pay: buyers can typically buy 10-20% more or less of their annual take-or-pay volumes— & Flexibility but they have to pay for LNG whether they lift it or not. Schedule & Logistics Estimated schedule for delivering cargoes (e.g. seasonality patterns) and logistics for delivery (e.g. tanker size) Gas Quality Specifications for gas, including any treatment of liquids Profit Sharing Some contracts allow the original seller to share the profit in case a cargo is diverted from its original source, but such provisions are illegal in Europe (they are considered to inhibit competition) Non-Compliance Penalties can involve non-delivery, delays, off-spec gas (different gas quality) Renegotiation Most contracts will allow price reviews every 3-4 years but usually within a band. Most contracts will also allow a onetime review clauses for extraordinary circumstances. Arbitration is usually required when parties cannot agree Title Transfer Specification of when the LNG transfers ownership from buyer to seller (e.g. FOB, CIF, DES) enalytica Data. Analytics. Solutions. in Energy
  • 28.
    Basics › structures› development risks › operations › Risk mitigation › conclusions !28 economic rationale › milestones › LNG sales and purchase agreements (SPAs) › domestic gas allocation LNG exports Often linked to Domestic Gas sales LNG projects could either seek to scale up existing producing assets or may unlock stranded gas In cases where there is no existing production, LNG exports often serve as foundation for a local market The prospect of exports often incentivizes further exploration that benefits local and export markets Some jurisdictions (Indonesia, Western Australia) have explicit domestic gas reservation policies ! Examples Angola LNG will deliver 125 mmcf/d to the local market Bintulu LNG (Malaysia) makes possible gas consumption in the remote areas of Sarawak (east Malaysia) Donggi Senoro LNG (Indonesia) will couple exports with sales to local ammonia and power plants North West Shelf (Australia) started to supply local market 5 years before exports started (1984 / 1989) Yemen LNG sources gas from gas Marib Area—1 tcf of 9.15 has been allocated to local market Sources: Company press releases and Industry Press enalytica Data. Analytics. Solutions. in Energy
  • 29.
    Basics › structures› development risks › operations › Risk mitigation › conclusions !29 integrated › merchant › tolling › trade-offs › state participation Integrated Projects distribute Value Internally Same companies own upstream and midstream—value driven by sales price (FOB/CIF) Distribution of value between upstream and midstream is an internal transfer question Transfer price may or may not be public Russia Qatar Algeria Upstream Liquefaction Sales Gas produced across Algeria Piped to shore Sonatrach 100% owned facilities FOB: $11.50/mcf Various LNG SPAs & direct marketing Gas produced from the North Field Varying ownerships Qatargas & RasGas Varying ownerships FOB: $11.36/mcf LNG pricing ranging from China: $20 North America >$3 Gas produced and piped across Sakhalin Island (500 miles of pipe) Sakhalin-2 LNG project Both trains same ownership FOB: $6.18/mcf Various SPAs Japan (76%): $15.40 Korea (20%): $8.10 Source: Company financial reports and country import statistics enalytica Internal Transaction | Third-Party Transaction Data. Analytics. Solutions. in Energy
  • 30.
    Basics › structures› development risks › operations › Risk mitigation › conclusions !30 integrated › merchant › tolling › trade-offs › state participation Infrastructure owner drives pricing Infrastructure owner buys gas and sells LNG—value in differential between upstream and downstream FOB price does not need to be linked to upstream price (e.g. Equatorial Guinea) Upstream Liquefaction Sales Eq. Guinea Noble Energy: Alba Field 235 mmcf/d (2012) % sold to LNG $0.25/MMBtu Marathon-Operated: EG LNG T1 90% * Henry Hub linked FOB price: $2.57 FOB cost: under $1 BG Group LNG Sales to Japan (76%): $18.65 Korea (10%): $15.04 Taiwan: (5%): $20.38 Malaysia Murphy Oil: SK 309 and SK 311 174 mmcf/d (2012) 50% * LNG export price $7.50/mcf PETRONAS: Malaysia LNG Oil-linked pricing Various contracts (mostly cif) FOB: $15.64 LNG Sales to Japan (62%): $19.07 Korea (18%): $11.69 Taiwan: (12%): $19.11 Sabine Pass Upstream price can be netback (e.g. Malaysia LNG) or cost-plus (e.g. Sabine Pass) No single supplier Gas sourced from the market Henry Hub prompt month in 2013 $3.73/MMBtu Source: Company financial reports and country import statistics enalytica Cheniere Energy: Sabine Pass LNG SPAs 16-18 mmtpa BG Group, Gas Natural Fenosa 115% * Henry Hub + $2.25 to $3 GAIL, KOGAS FOB: $6.54 to $7.29 Companies can resell LNG for any price Internal Transaction | Third-Party Transaction Data. Analytics. Solutions. in Energy
  • 31.
    Basics › structures› development risks › operations › Risk mitigation › conclusions !31 integrated › merchant › tolling › trade-offs › state participation LNG Akin to Pipeline: Pay a Fee to use Facility In a tolling structure, the supplier or buys pays the liquefaction owner a usage fee The infrastructure owner takes no ownership of the gas Liquefaction Sales Egyptian LNG BG Group (50%) and PETRONAS (50%) West Delta Deep Marine Conduct SPAs with off-takers Pay liquefaction plant a fee T1: BG 35.5%, PETRONAS 35.5% EGPC 12% EGAS 12%, GDF SUEZ 5% T2: BG 38%, PETRONAS 38% EGPC 12% EGAS 12% Train 1 sales 100% to GDF SUEZ Train 2 sales 100% to BG Group Various suppliers e.g. BG and partners 28.9% of gas supply Pay liquefaction plant a fee (est. $1/mcf) Upstream pricing is netback from FOB T4 : BP 38%, BG 29%, Shell 22%, NGC 11% FOB price (est. $5.16/mcf) Off-take proportional to gas supply Some suppliers may sell gas FOB Henry Hub pricing and profit sharing e.g. Japan ($13.63/mcf) Cameron Upstream Trinidad The relevant pricing is between supplier and buyer; infrastructure owner is “irrelevant” No single supplier Gas sourced from the market Source: Company financial reports and country import statistics enalytica ! Sempra 50.2% Mitsubishi, Mitsui and GDF SUEZ Mitsubishi 16.6% Pay LNG facility a tolling fee Mitsui 16.6% They also procure their own gas GDF SUEZ 16.6% Internal Transaction | Third-Party Transaction Data. Analytics. Solutions. in Energy
  • 32.
    Basics › structures› development risks › operations › Risk mitigation › conclusions !32 integrated › merchant › tolling › trade-offs › state participation There is No “Right” Project Structure Type of resource base is often a major driver (size of initial resource, expansion potential, new fields) The partners risk appetite and desire to commit capital is another main driver Expansion prospects and competitive landscape is a third driver (# of companies that could supply gas) Advantages Integrated plants are simple—the only relevant point is Integrated the sales price to the off-take Disadvantages Integrated projects work when there is high partner alignment, a steady (not variable) source of gas and where all partners are equally interested in any expansions Project can accommodate new supply sources. Especially Multiple transaction points can cause tensions and/or Merchant useful to allow companies varying participation along the delays in the project. chain and to enable projects to tap new resources Tolling enalytica Very adaptable and able to accomodate changes in upstream supply. Easily scalable. Setting tolling fee can be a challenge, particularly in cases where the upstream players have a bias towards using their own supplies Data. Analytics. Solutions. in Energy
  • 33.
    Basics › structures› development risks › operations › Risk mitigation › conclusions !33 integrated › merchant › tolling › trade-offs › state participation State Participation in LNG Projects varies Greatly Several states take no equity stake in LNG projects—they merely regulate and tax Most countries have some equity—but their involvement varies from passive to very active Equity stakes are held through national oil companies—Brunei and Norway (Petoro) are exceptions equity across chain Algeria, Malaysia, Qatar Angola Brunei Nigeria Australia, Canada, Indonesia (Tangguh), Peru, Russia (Yamal), USA state taxes and regulates Russia (Sakhalin-2), Indonesia (Bontang) Norway Eq. Guinea Egypt Yemen Abu Dhabi Oman Trinidad Active engagement with project operations Source: Ownership from GIIGNL, The LNG Industry in 2012, http://www.giignl.org/sites/default/files/publication/giignl_the_lng_industry_2012.pdf enalytica Data. Analytics. Solutions. in Energy
  • 34.
    Basics › structures› development risks › operations › Risk mitigation › conclusions !34 delays to sanction project › partner drag › delays and cost overruns LNG Takes Time, often decades from First Discovery LNG projects are big, complex, multi-stakeholder agreements and they often take years to put together Challenges include offtake, capital, permits, partner commitment, or overcoming technical problems Several existing projects were stuck for a long-period of time in the planning phase ! Examples The Camisea complex (Peru) discovered in early 1980s, online in 2004 and exported LNG in 2010 The Gorgon gas field (Australia) discovered in 1981 with LNG exports starting in 2015 North Field (Qatar) was discovered in 1971, but LNG exports started in 1996 Shtokman (Russia) discovered in 1988, but still lacks a development path Snøhvit (Norway) was discovered in 1984 and LNG started in 2007 Atlantic LNG (Trinidad) project first mulled in 1970s, then again early 1980s; first LNG started in 1999 Sources: Company press releases and Industry Press; ViktoR, et. Al, “Natural Gas and Geopolitics” enalytica Data. Analytics. Solutions. in Energy
  • 35.
    Basics › structures› development risks › operations › Risk mitigation › conclusions !35 delays to sanction project › partner drag › delays and cost overruns Partner alignment crucial for LNG Development Many LNG projects were developed by a different set of companies that first proposed the LNG project Partners with low portfolio fit and/or risk appetite can slow down project development Getting new partners is often a precondition for an LNG project to move forward ! Examples ExxonMobil pulled out of Angola LNG; Eni acquired stake soon thereafter Atlantic LNG (Trinidad) T2-3 needed new shareholding deal as Cabot and NGC did not want to participate Kitimat LNG (Canada) started off as Apache/EOG, then EnCana joined; now Chevron / Apache (50:50) PTT (Thailand) acquired Cove Energy to access gas that could supply an LNG project in Mozambique North Field (Qatar) discovered by Shell; Shell and later BP left; LNG developed by Mobil (now ExxonMobil) Marathon and McDermott sold out of Sakhalin Energy (Sakhalin-2 LNG in Russia) Sources: Company press releases and Industry Press; ViktoR, et. Al, “Natural Gas and Geopolitics” enalytica Data. Analytics. Solutions. in Energy
  • 36.
    Basics › structures› development risks › operations › Risk mitigation › conclusions !36 delays to sanction project › partner drag › delays and cost overruns Project Sanctioned Target Date Actual Date DElay Budget BN Cost BN % Overrun Snøhvit (Norway) Egyptian LNG T1 Mar-02 Sep-02 2006 Aug-05 Sep-07 May-05 1.5 years 3 months early NOK39.50 $1.1 NOK48.00 on budget 21.5% 0% Sakhalin-2 (Russia) May-03 2007 Mar-09 2 years $10.0 $22.0 120.0% Atlantic LNG T4 (Trinidad) Jun-03 2005 Dec-05 on time $1.2 on budget 0% Egyptian LNG T2 Jul-03 Jun-06 Sep-05 9 months early $0.6 on budget 0% Equatorial Guinea Jun-04 Late 2007 May-07 6 months early $1.5 on budget 0% North West Shelf (Australia) Jun-05 2008 Sep-08 on time AUS$2 AUS$2.6 30.0% Yemen Aug-05 Dec-08 Nov-09 1 year $3.7 $4.5 21.6% Peru Jan-07 mid 2010 Jun-10 on time $3.8 $3.9 2.6% Pluto Jun-07 Early 2011 May-12 1.5 years AUS$11.2 AUS$14.9 33.0% Skikda LNG (Algeria) Jun-07 2011 Mar-13 2 years $2.8 ? ? Angola Dec-07 Early 2012 Jun-13 1.5-2 years ? $10.0 ? Gorgon (Australia) Sep-09 2014 n/a n/a $37.0 $54.0 45.9% Papua New Guinea Dec-09 2014 n/a n/a $15.0 $19.0 26.7% Queensland Curtis (Australia) Nov-10 2014 n/a n/a $15.0 $20.5 36.7% Gladstone LNG (Autralia) Jan-12 2015 n/a n/a $16.0 $18.5 15.6% Source: Company press releases and Industry Press enalytica Data. Analytics. Solutions. in Energy
  • 37.
    Basics › structures› development risks › operations › Risk mitigation › conclusions !37 outages › domestic gas diversion › natural decline › demand shock: volume › demand shock: price Technical challenges can lead to frequent outages Historically, the LNG industry has operated plants at high utilization rates (85-90%) However, as projects become more technically complex, outages are a real risk For example, Snøhvit (Norway) has experienced frequent outages (2-3 months) since start-up in 2007 Outages 600 Outages Outages 700 Snøhvit LNG Plant (Norway): GAs Production MMCf/d 500 400 300 200 100 0 Sep-07 Mar-08 Sep-08 Mar-09 Sep-09 Mar-10 Sep-10 Mar-11 Sep-11 Mar-12 Sep-12 Mar-13 Sep-13 Source: Norwegian petroleum Directorate, Factpages, Production Monthly by Field (Accessed January 2014) enalytica Data. Analytics. Solutions. in Energy
  • 38.
    Basics › structures› development risks › operations › Risk mitigation › conclusions !38 outages › domestic gas diversion › natural decline › demand shock: volume › demand shock: price supplying local markets can divert gas from LNG Indonesia has seen exports from its oldest facilities (Arun and Bontang) decline over time At issue is a combination of resource depletion and a need to divert gas to local markets Arun has been shut down and is being converted to an import terminal Arun and Bontang LNG Plants (Indonesia): GAs Exports 3.5 3.0 bCf/d 3.15 3.26 3.04 3.01 3.05 3.03 2.81 2.96 2.81 2.80 Bontang Arun 2.67 2.54 2.5 2.0 2.24 1.75 1.62 1.5 1.03 1.0 0.95 0.97 0.87 0.65 0.46 0.5 0.53 0.44 0.40 0.34 0.30 0.18 0.14 0.0 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 Sources: Pengkajian Energi Universitas Indonesia, Indonesia Energy Outlook & Statistics 2006, Ministry of Energy and Natural Resources, “Statistik Gas Bumi 2012” enalytica Data. Analytics. Solutions. in Energy
  • 39.
    Basics › structures› development risks › operations › Risk mitigation › conclusions !39 outages › domestic gas diversion › natural decline › demand shock: volume › demand shock: price Feedstock Maturity Can Lead to Rapid Decline Kenai was the second LNG project in the world and it supplied Japan continuously since 1969 As production matured, however, exports faced a precipitous decline: from 2007 to 2012 fell 25% a year Matching the production profile to LNG sales contracts is essential to mitigate any penalties LNG Exports from Alaska to Japan 200 MMCf/d 180 178 160 140 120 100 80 60 40 20 26 0 1975 1977 1979 1981 1983 1985 1987 1989 1991 1993 1995 1997 1999 2001 2003 2005 2007 2009 2011 Source: US Energy Information Administration,Alaska Liquefied Natural Gas Exports to Japan (Accessed January 2014) enalytica Data. Analytics. Solutions. in Energy
  • 40.
    Basics › structures› development risks › operations › Risk mitigation › conclusions !40 outages › domestic gas diversion › natural decline › demand shock: volume › demand shock: price Demand Shock led to output losses— But long ago Algeria experienced two waves of LNG output contraction in the 1980s and early 1990s Both were driven by declines in demand for Algerian LNG from the United States (and, less so, France) But the depth of the current LNG market has meant that producers face price but not output risk LNG Exports from Algeria ! 2,500 mmcf/d For example, Snøhvit (Norway) has experienced frequent outages since coming online in 2007 2,002 2,000 1,872 1,903 1,948 1,800 1,709 1,548 1,500 1,198 1,250 1,768 1,485 1,222 1,003 1,000 644 500 1,382 USA Total 235 743 359 101 151 1981 1982 99 65 - 1984 1985 1986 0 1980 1983 - 48 116 1987 1988 1989 231 1990 224 174 118 1991 1992 1993 139 1994 49 1995 Sources: US Energy Information Administration,U.S. LNG Imports From Algeria (Accessed January 2014), Ministère de l’Energie et des Mines, Energy Balance 1980-2004 enalytica Data. Analytics. Solutions. in Energy
  • 41.
    Basics › structures› development risks › operations › Risk mitigation › conclusions !41 outages › domestic gas diversion › natural decline › demand shock: volume › demand shock: price Price Risk More Important than Volume Risk Market fundamentals affect price rather than volume (2012 utilization was over 100%) Qatar earns vastly different prices across markets: $20/mcf in China to sub-$3/mcf in North America Lower prices reflect contracts linked to low benchmarks (e.g. Belgium) or LNG “pushed into” markets 25 Qatar: LNG Price Curve (2012) (markets Accounting for 89% of total sales) $/mcf China 20 Korea Japan Italy 15 10 India United Kingdom 5 billion cubic feet / Day 0 0 1 2 3 4 5 6 7 8 9 10 Sources: international gas union, World LNG Report 2013 (June 2013), UN Comtrade Database (Accessed January 2014) enalytica Data. Analytics. Solutions. in Energy
  • 42.
    Basics › structures› development risks › operations › Risk mitigation › conclusions !42 marketing integration › third-party financing › pricing bands › renegotiation Buyers Often Take Equity | Partners off-take LNG In half of the world’s LNG capacity, a share of the LNG is sold to equity partners Such deals can mitigate risk by aligning supplier-buyer interests (e.g. output shortfall) Buyers get sense of supply security, and these deals often open up the project to third-party financing PErcent Of LNG Capacity Sold to Equity Partners Projects Online in 2012 % LNG Sold to Partners 100% 90% Partners take all the LNG 80% 70% Share of LNG Sold to Partners 60% 50% 40% 30% 20% buyers have no Equity 10% 0% 0% 10% 20% 30% 40% 50% 60% 70% % LNG Capacity 80% 90% 100% Source: Based on GIIGNL, The LNG Industry in 2012, http://www.giignl.org/sites/default/files/publication/giignl_the_lng_industry_2012.pdf enalytica Data. Analytics. Solutions. in Energy
  • 43.
    Basics › structures› development risks › operations › Risk mitigation › conclusions !43 marketing integration › third-party financing › pricing bands › renegotiation Project Finance well established in LNG IHS estimates that LNG projects raised over $97 billion in third-party financing since 2000 Financing from project sponsors, export credit agencies, multilateral banks and commercial banks Commercial loans can also secure sovereign guarantees as insurance The Japan Bank of International Cooperation (JBIC) is the largest single provider of funds Examples AP LNG Ichthys Papua New Guinea Peru Sakhalin-2 Tangguh $5.8 billion $20 billion $14 billion $2.25 billion $6.4 billion $3.5 billion US EXIM, China EXIM, banks JBIC, Korea and Australia EXIM, banks, sponsors ($4 bn) Six ECAs and 17 banks, ExxonMobil IADB, US EXIM, Korea EXIM, IFC, others JBIC, NEXI, banks JBIC, ADB, banks Sources: IHS in Ledesma, et. Al, “The Commercial and Financing Challenges of an Increasingly Complex LNG Chain,” LNG 17 (April 2013); Industry press enalytica Data. Analytics. Solutions. in Energy
  • 44.
    Basics › structures› development risks › operations › Risk mitigation › conclusions !44 marketing integration › third-party financing › pricing bands › renegotiation Pricing formula can reduce price volatility “S-curves” are clauses that change the relationship between oil and gas above or below thresholds Instead of a linear link, gas prices do not rise/fall as much if oil prices rise/fall above certain thresholds They reduce downside risk by forgoing some upside—they can even provide a floor/ceiling on prices ! ! No S-Curve S-Curve Floor / ceiling ! ! LNG Sales Price ! Oil or other reference Price enalytica Data. Analytics. Solutions. in Energy
  • 45.
    Basics › structures› development risks › operations › Risk mitigation › conclusions !45 marketing integration › third-party financing › pricing bands › renegotiation Worst case, there is always renegotiation Most LNG contracts include price review clauses—especially for fundamental / unforeseen changes Most renegotiations focus on pricing—but European disputes have included volumes (take-or-pay) Disputes between states and companies usually center on upside that is not flowing back to the state ! Examples BG and its Chilean buyers renegotiated to raise LNG prices Brunei and Japanese buyers adjusted their price formula—as a result prices tripled from 2007 to 2008 Gas Natural and Atlantic LNG went to arbitration and add a US-based reference price to their contract RasGas gave a price discount to Edison (Italy) after arbitration settlement ($580 mm in 2012) Yemen LNG increased its LNG sales prices towards GDF SUEZ, TOTAL, KOGAS Sources: Company press releases and Industry Press enalytica Data. Analytics. Solutions. in Energy
  • 46.
    Basics › structures› development risks › operations › Risk mitigation › conclusions !46 LNG Projects are Big, Complex and Multi-layered LNG projects take years (even decades) from first discovery to commercial production They require a large capital commitment upfront—but deliver long-term revenue thereafter No such thing as a “standard” project structure that Alaska can “adopt” Complexity means that value creation and distribution is often a product of negotiation States’ participation varies from not at all to fully involved throughout the value chain LNG projects are often used to unlock stranded gas that is also supplied to local markets LNG projects face many risks—but have established mechanisms for risk-management and mitigation Third-party finance, marketing integration and pricing bands can reduce exposure/volatility Price review clauses allow counter-parties to provide reprieve to grave imbalances LNG projects tend to be partnerships between many private and state-owned enterprises enalytica Data. Analytics. Solutions. in Energy
  • 47.
    ‣ ‣ ‣ ‣ Natural gas marketoutlook fundamentals of LNG Business Implications for Alaska Appendices enalytica Data. Analytics. Solutions. in Energy
  • 48.
    Implications for Alaska !48 keyquestions › decision matrix path forward requires answers to Key Questions How should Alaska take its gas share? Should the state take equity in the project and if so, in what parts of the value chain? If the state decides to take its gas entitlement in kind, how will it market that gas? What is the state’s appetite for risk, and what type of risk? What type of risk mitigators will make the state more comfortable about participating in an LNG project? Is the state prepared to forgo some upside in order to be better protected on the downside? What project structure can expedite development while allowing the project to evolve with time? What are the state’s long-run revenue needs and how might the LNG project help meet those needs? enalytica Data. Analytics. Solutions. in Energy
  • 49.
    Implications for Alaska !49 keyquestions › decision matrix Alaska HAs Many Ways to Participate in LNG Project State’s Gas gas in value: Key question is how to negotiate a “fair” transfer price gas in Kind Agency marketing (Companies Sell gas on Alaska’s Behalf) State markets Gas in-state Sales FOB (Buyers Do Shipping) CIF (Alaska Does Shipping) equity across chain Agency marketing or state markets gas Agency marketing or state markets gas Gas in value state taxes and regulates enalytica Active engagement with project operations Data. Analytics. Solutions. in Energy
  • 50.
    ‣ ‣ ‣ ‣ Natural gas marketoutlook fundamentals of LNG Business implications for Alaska Appendices enalytica Data. Analytics. Solutions. in Energy
  • 51.
    Our Team !51 Janak Mayer› Nikos Tsafos Before co-founding enalytica, Janak led the Upstream Analytics team at PFC Janak Mayer Partner enalytica! ! janak.mayer@enalytica.info Energy, focusing on fiscal terms analysis and project economic and financial evaluation, data management and data visualization. Janak has modeled upstream fiscal terms in all of the world’s major hydrocarbon regions, and has built economic and financial models to value prospective acquisition targets and develop strategic portfolio options for a wide range of international and national oil company clients. He has advised Alaska State Legislature for multiple years on reform of oil and gas taxation, providing many hours of expert testimony to Alaska’s Senate and House Finance and Resources Committees. Prior to his work as an energy consultant, Janak advised major minerals industry clients on a range of controversial environmental and social risk issues, from uranium mining through to human rights and climate change. He has advised bankers at Citigroup and policy-makers at the US Treasury Department on the management and mitigation of environmental and social impacts in major projects around the world, and has undertaken macroeconomic research with senior development economists at the World Bank and the Peterson Institute for International Economics. Janak holds an MA with distinction in international relations and economics from from the Johns Hopkins School of Advanced International Studies (SAIS), and a BA with first-class honors from the University of Adelaide, Australia. enalytica Data. Analytics. Solutions. in Energy
  • 52.
    Our Team !52 Janak Mayer› Nikos Tsafos Nikos Tsafos Partner enalytica! ! nikos.tsafos@enalytica.info Nikos Tsafos has a diverse background in the private, public and non-profit sectors. He is currently a founding partner at enalytica. In his 7 ½ years with PFC Energy, Nikos advised the world’s largest oil and gas companies on some of their most complex and challenging projects; he also played a pivotal role in turning the firm into one of the top natural gas consultancies in the world, with responsibilities that included product design, business development, consulting oversight and research direction. Prior to PFC Energy, Nikos was at the Center for Strategic and International Studies (CSIS) in Washington, DC where he covered political, economic, and military issues in the Gulf, focused on oil wealth, regime stability and foreign affairs. Before CSIS, he was in the Greek Air Force, and prior to his military service, Nikos worked on channeling investment from Greek ship-owners to Chinese shipyards. Nikos has also written extensively on the domestic and international dimensions of the Greek debt crisis. His blog (Greek Default Watch) was listed as one of “Europe’s Top Economic Blogs” by the Social Europe Journal, and his book “Beyond Debt: The Greek Crisis in Context” was published in March 2013. Nikos holds a BA with distinction in international relations and economics from Boston University and an MA with distinction in international relations from the Johns Hopkins School of Advanced International Studies (SAIS). enalytica Data. Analytics. Solutions. in Energy
  • 53.