EX-99.1
Corporate presentation October 2017
Exhibit 99.1
Disclaimer
$60 million $25 million $207 million
Merger Acquisition February April August December January February June September Charif Souki and Martin Houston establish Tellurian Management, friends and family invest $60 million Meg Gentle joins to lead the company as President & CEO GE
invests $25 million in Tellurian TOTAL invests $207 million in Tellurian Merged with Magellan Petroleum, gaining access to public markets Bechtel, Chart Industries and GE complete the front-end engineering and design (FEED) study for Driftwood LNG
Announced acquisition of natural gas production and undeveloped acreage in the Haynesville Building a low-cost global natural gas business Introduction 2016 2017
New liquefaction capacity required
Sources: ICE via Marketview, Kpler, Wood Mackenzie, Platts and Tullet Prebon, Fearnleys, Tellurian Research. Notes: (1) Effective capacity is defined as total capacity less unplanned outages and gas constraints. Implied utilization rates assume
demand growth of 12% per annum. Accelerated demand growth driven by low LNG prices LNG demand growth 2017 effective capacity(1) utilization >98% LNG capacity utilization Price convergence Emerging indices provide forward transparency Netback
prices to the Gulf Coast Global LNG
Sources:Kpler, Maran Gas, IHS, Wood
Mackenzie. Notes: LNG storage assumes half of fleet is in ballast, 2.9 Bcf capacity per vessel. Average cargo size ~2.9 Bcf, assuming 150,000 m3 ship. In 2017, approximately a third of all LNG cargoes are estimated to be spot volumes. Assumes 12%
per annum demand growth. Daily supply readily available across the globe Global LNG Bcf of LNG storage # of LNG vessels # of cargoes loaded per day Legend LNG carrier – laden LNG carrier – unladen LNG Storage - 2017 Japan + Korea
terminals: 633 Bcf LNG vessels: 686 Bcf
Building a low-cost global gas business
Business model Pipeline Liquefaction Marketing Upstream Purchase low-cost gas at liquidity points or as reserves Diversify gas supply Develop pipeline solutions for constrained production basins Maximize access to supply liquidity Develop low-cost
liquefaction Less than $600 per tonne Develop suite of flexible LNG products Build out risk management and operational infrastructure LNG trade entry in 2017 Acquiring 9,200 net acres with up to 138 drilling locations in Haynesville Delivered gas
cost $2.25/mmBtu FERC permit pending ~27.6 mtpa Driftwood LNG terminal FEED complete Fixed fee construction contract under negotiation FERC permit pending Experienced global marketing team Offices in Houston, Washington D.C., London, and Singapore
Maran Gas Mystras LNG vessel under 6 month time charter
Business model Tellurian Marketing
Driftwood Holdings Driftwood LNG terminal Driftwood pipeline Tellurian Production Company Customers Business model Tellurian will offer equity interest in Driftwood Holdings Driftwood Holdings will consist of Tellurian Production Company, Driftwood
pipeline and Driftwood LNG terminal (~27.6 mtpa) Equity will cost ~$1,500 per tonne Investors will receive equity LNG at tailgate of Driftwood LNG terminal at cost Variable and operating costs expected to be ~$3.00/mmBtu FOB (including maintenance)
Tellurian will retain 7 to 11 mtpa Tellurian will manage and operate the project Equity ownership 25% - 40% ~7-11 mtpa ~17-21 mtpa ~7-11 mtpa Investors/ customers 60% - 75% Customers 100%
Business model Sources: Wood Mackenzie,
Platts, Tullet Prebon, Tellurian Research. Notes: (1) Drilling and completion based on well cost of $10.2 million, 15.5 Bcf EUR, and 75.00% net revenue interest (“NRI”) (8/8ths). (2) Gathering, processing and transportation includes
transportation cost to Driftwood pipeline to market. (3) Platts Gulf Coast Marker. Upstream cost $/mmBtu Liquefaction cost Potential margin capture from Driftwood Total cost of ~$3/mmBtu locks in low cost of supply $3/mmBtu supply cost Nov GCM(3) 6
Oct 2017: $7.58/mmBtu $1.50 – $15.00/mmBtu of margin potential Netback prices to the Gulf Coast $/mmBtu
Illustrative financials Business model
Notes: (1) Phase 1 reflects 1 berth / 2 tanks and full development reflects 3 berths / 3 tanks.(3) Per share amounts based on 211 million shares outstanding as of August 9, 2017 as reported in latest 10-Q. (2) Resource need for 30 year period.
Scenario Phase 1(1) Full development(1) Capacity, mtpa 11.0 27.6 Plant cost, $ per tonne 685 546 Upstream resource need(2), Tcf ~15 ~40 Investment, $ billions 12.0 23.8 Transaction price, $ per tonne 1,500 1,500 Capacity split mtpa % mtpa % -
Customer/investor 8.0 72% 15.9 57% - Tellurian 3.0 28% 11.7 43% LNG sale price, $/mmBtu 6.00 10.00 15.00 6.00 10.00 15.00 Tellurian margin, $/mmBtu 3.00 7.00 12.00 3.00 7.00 12.00 Tellurian annual cash flows, $ millions 470 1,090 1,870 1,820 4,260
7,300 Tellurian annual cash flows per share(3), $ 2.20 5.15 8.85 8.65 20.15 34.60
Driftwood vs. competitors –
cost per tonne Business model Sources: Wood Mackenzie, The World Bank, Tellurian Research. Notes: (1) The World Bank bases the Logistics Performance Index (LPI) on surveys of operators to measure logistics “friendliness “ in respective
countries which is supplemented by quantitative data on the performance of components of the logistics chain. Capacity, mtpa 9.5 27.6 10.0 16.5 13.0 9.0 15.6 9.0 8.9 LPI global ranking(1): 3.6 4.0 2.7 2.6 3.9 3.8 3.8 3.8 3.8
Integrated model prevalent
internationally Business model Source: IHS. Projects include: Australasia APLNG, Darwin, GLNG, Gorgon, Ichthys, NWS, Pluto, Northwest Shelf, QCLNG, Wheatstone, PNG LNG, Tangguh, Brunei LNG, Donggi-Senoro, MLNG, Yamal LNG Mideast/Africa Angola LNG,
EG LNG, Damietta, ELNG, Yemen LNG, Mozambique LNG, Coral LNG, Oman LNG, Qalhat LNG, Qatargas I-IV, RasGas I-III, ADGAS Americas Atlantic LNG, Peru LNG, LNG Canada Europe Snohvit, Yamal LNG Europe Australasia NOC IOC
Tellurian Production Company
objectives Tellurian Production Company Experienced upstream team joined in May 2017 Acquire and develop long life, low-cost natural gas resources Low geological risk Scalable position Production of 1.5 Bcf/d starting in 2022 Total resources of ~15
Tcf Operatorship Low operating costs Flexible development terms Focused on Haynesville and Eagle Ford basins Sources: Company disclosure.
Haynesville acquisition Tellurian
signed a PSA with a private seller to purchase 9,200 net acres in the Haynesville shale for $85.1 million Haynesville acreage provides low development risk, favorable economics and close proximity to significant demand growth Target is to deliver
gas for $2.25/mmBtu Located in De Soto and Red River parishes 100% HBP 92% operated 100% gas Current production – 4 mmcf/d Operated producing wells – 19 Identified development locations – ~138 Total net resource – ~1.3 Tcf
Tellurian Production Company
Driftwood LNG terminal and pipeline
Driftwood LNG terminal Land ~1,000 acres near Lake Charles, LA Capacity ~27.6 mtpa(1) Trains Up to 20 trains of ~1.38 mtpa each Chart heat exchangers GE LM6000 PF+ compressors Storage 3 storage tanks 235,000 m3 each Marine 3 marine berths Capex
~$500 – 600 per tonne ~$13 – 16 billion(2) Driftwood pipeline Size ~96 miles Capacity ~4 Bcf/d avg. throughput Access ~35 Bcf/d flowing gas Capex ~$1.6 – 2.0 billion(2) Notes:(1) Estimate, subject to further engineering evaluation.
(2) Excludes owners’ costs, financing costs and contingencies. Artist rendition Driftwood LNG
First LNG vessel chartered Charter:
Six-month time charter Vessel owner: Maran Gas Maritime Inc. Vessel: Maran Gas Mystras Vessel size: 160,000 m3 Propulsion: Tri-fuel diesel electric (TFDE) Expect to deliver LNG cargoes to global customers by year end 2017 LNG marketing LNG marketing
LNG demand is growing at 12% per
annum(1) Netback LNG prices to the U.S. Gulf Coast of > $5.50/mmBtu have signaled that additional liquefaction capacity is needed The U.S. is best positioned to meet these supply needs with access to abundant low-cost gas and a track record of
building low-cost liquefaction Tellurian’s integrated model to deliver low cost LNG globally Conclusions Conclusions Source:(1) Kpler.
Amit Marwaha Director, Investor
Relations & Finance +1 832 485 2004 amit.marwaha@tellurianinc.com Contact us Joi Lecznar SVP, Public Affairs & Communication +1 832 962 4044 joi.lecznar@tellurianinc.com @TellurianLNG Contacts
2017 Additional detail
Haynesville type curve comparison
Comparative type curve statistics Peer B Peer D Peer A Peer C Tellurian Source:Company investor presentations. Notes:(1) Assumes 75.00% net revenue interest (“NRI”) (8/8ths). (2) Assumes gas prices of $3.00/mcf based on NRI and returns
published specific to each operator. Cumulative production normalized to 7,500’(3) Tellurian Peer A Peer B Peer C Peer D Type curve detail Area De Soto / Red River North Louisiana De Soto NLA De Soto core NLA core / blended development program
Completion (lbs. / ft.) - 4,000 3,800 2,700 3,000 Single well stats Lateral length (ft.) 6,950' 7,500' 7,500' 4,500' 9,800' Gross EUR (Bcf) 15.5 18.8 18.6 9.9 19.9 EUR per 1,000' ft. (Bcf) 2.20 2.50 2.48 2.20 2.03
Gross D&C ($ millions) $10.20 $10.20 $8.50 $7.70 $10.30 F&D ($/mcf)(1) $0.88 $0.73 $0.61 $1.04 $0.69 Type curve economics Before-tax IRR (%)(2) 43% 60% 90%+ 54% - Tellurian Production Company (3)
7,500’ estimated ultimate recovery (“EUR”) = original lateral length EUR + ((7,500’-original lateral length) * 0.75 * (original lateral length EUR / original lateral length)).
Illustrative financials –
additional detail Business model Notes: (1) Phase 1 reflects 1 berth / 2 tanks and full development reflects 3 berths / 3 tanks. (2) Resource need for 30 year period. Scenario Phase 1(1) Full development(1) Capacity, mtpa 11.0 27.6 Plant cost, $ per
tonne 685 546 Upstream resource need(2), Tcf ~15 ~40 Investment, $ billions - Terminal 7.6 15.1 - Pipeline 1.1 2.2 - Owners’ costs and other 1.1 2.1 - Upstream - acquisition 1.0 2.0 - Upstream - drilling capex (net
of sales)(3) 1.2 2.5 Total 12.0 23.8 Transaction price, $ per tonne 1,500 1,500 Capacity split mtpa % mtpa % - Customer/investor 8.0 72% 15.9 57% - Tellurian 3.0 28% 11.7 43% (3) $3.4 billion drilling capex net of $2.2 billion of gas sales.
