FAR LIMITED — Investor Presentation 2017

Mar 29, 2017

A world class oil story

Investor Update 30 March 2017

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*FAR ASX releases dated 23 Aug 2016, best estimate, gross resources, oil only. Market capitalisation at 30 March 2017

FAR in Senegal

• FAR has been in Senegal since 2006

• Senegal is a peaceful democracy with a stable outlook (S&P sovereign credit rating B+/B) and projected growth rate of 6% this year

• Strong in country relationships

• Farmed down to Cairn Energy and ConocoPhillips for US$196M carry + cash in 2013

• Basin opening FAN-1 and SNE-1 oil discoveries 2014

• SNE ranked as worlds largest oil discovery in 2014

• 8 successful wells drilled to date

• President is a petroleum geologist!

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OFFSHORE SENEGAL PSC

FAR 16.7% paying interest, 15% beneficial interest Operator: Cairn Energy PLC

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FAN-1 and SNE-1 opened up Senegal

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• 100% drilling success to date

• Cairn Energy (operator) NPV of US$12.5/bbl at project FID (2018/19) and US$70/bbl oil price*

• Major gas discoveries made in 2015/16 offshore Northern Senegal / Southern Mauritania

• BP farm-in to Kosmos acreage introduces a large IOC to the basin

• CNOOC farm-in to Impact acreage in AGC March 2017

• Global hot spot for exploration

*Source: Cairn Energy estimates (refer Cairn Energy Half Yearly Result 16/08/2016

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SNE Field geological setting and discovery well
SNE-1 oil discovery (Nov 2014)
➢ Oil gravity 32 degrees API
➢ Gross oil column 96m
•➢ FAR gross contingent resource []
Gross oil-bearing interval of > 500m
•
No water-bearing sands intersectedP90 (1C): 348 mmbbls,
P50 (2C): 641 mmbbls,
P10 (3C): 1,128 mmbbls
➢ Excellent reservoir rocks in 2 main
families: lower and upper reservoir sands
Shelf Edge play
Fan play
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*Reference FAR ASX releases dated 13 Apr 2015 and 23 August 2016, best estimate, gross resources, 100% basis, oil only

SNE appraisal program

Six appraisal wells drilled to date Currently completing VR-1 and then drill SNE-6 pulsing well Objectives of the appraisal program:

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• Size of oil pool

• Measure deliverability from logging, coring and flow testing

• Measure field connectivity

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SNE-4 SNE-3 SNE-1 SNE-2 BEL-1
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Drilling
Gas
Oil
Reservoir sands
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Size of the SNE oil pool

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Pre-Drill Post discovery RISC audited Latest RISC audited (Oct 2014) (Nov 2014) (April 2016) (August 2016) P90 : 50mmbbls 1C: 150 mmbbls 1C: 277 mmbbls 1C: 348 mmbbls P50 : 154 mmbbls 2C: 330 mmbbls 2C: 561 mmbbls 2C: 641 mmbbls P10 : 350 mmbbls 3C: 670 mmbbls 3C: 1071 mmbbls 3C: 1128 mmbbls

*Reference FAR ASX releases dated 23 August 2016, 13 April 2016, 20 Nov 2014: unrisked contingent resources, 100% basis, oil only RISC is an independent technical expert that reviewed and modified a probabilistic resource evaluation carried out by FAR in accordance with industry standard SPE-PRMS definitions

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Deliverability of oil from SNE

Main reservoirs flowed at commercially viable rates

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SNE-2 flow test
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SNE-2 lower and upper reservoirs units

• Gross 12m lower sands: 8,000 bopd through 3/4“ choke (stabilised constrained flow)

• Gross 15m upper sands: 1,000 bopd through 3/8“ choke (unstabilised)

SNE-3 tested upper reservoir units

• Gross 15m: 5,400 bopd max flow / 4,000 bopd through a 7/8“ choke (stabilised)

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• Gross 20.5m (2 zones): 4,500 bopd co-mingled through a 7/8“ choke (stabilised)

SNE-5 tested upper reservoir units

• Gross 18m (S480): Maximum rate 4,500 bopd, stabilized rate 2,500 bopd on 40/64” choke, and 3,000 bopd on 56/64” choke – 24hr each test

• Additional 8m perforated (S460): Maximum rate 4,200 bopd, average stabilised rate 3,900 bopd on 64/64” choke

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VR-1 well

• Drilling commenced after completion of SNE-5

• VR-1 to be logged but no DST

• VR-1 well objectives:

• Appraise the upper and lower sands in the west of the field

  • Confirmed 97m gross oil column

  • Greater than expected thickness of lower reservoirs

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• Best reservoir properties encountered so far

• Secondary objective to deepen into Aptian play

• Operations continuing to deepen the well

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SNE-6 well

• Plan to drill following VR-1 well

• SNE-6 used as a pulse well for the interference test (SNE-3 and SNE-5 listening wells)

• Final location for SNE-6 to be decided after results of SNE-5 are understood

• Objectives of the wells:

• Confirm connectivity of the upper reservoirs

• Confirm deliverability of the upper reservoirs

• Confirm dynamic geological model for the field

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• Collect data required to optimise the field development plan

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Efficient drilling, costs coming down

• Currently using the Stena DrillMAX – a 6[th] generation, dual mast, dual BOP drill ship

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• SNE-5 well drilled 21 days ahead of plan

• VR-1 well currently 4 days ahead of plan

• Expect similar performance on VR-1 and SNE-6 wells

• Incremental cost to FAR of adding VR-1 well to the program is A$2-3M

• Daily rig rates reduced by 70% since first drilling campaign in 2014

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Large potential upside in the RSSD acreage

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• 500m of oil intersected in the FAN-1 well – prolific, oil source rock

• New 2015 3D seismic shot along shelf edge trend from SNE

• Extensive portfolio of

• exploration prospects with >1bn bbls potential* updated Feb 2017

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*Reference FAR ASX release dated 7 February 2017,: gross, unrisked, recoverable, best estimate of prospective resources, oil only

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SNE Field at S460
reservoir level
showing Sirius and
Spica Prospects
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Upper sands important for undrilled prospects

• SNE-5 well tested 2 upper sands units (S480 and S460 reservoirs)

• S460 was previously untested upper sand unit and showed good reservoir properties and deliverability in SNE-5

• Map at this level shows confidence in Sirius and Spica prospects has increased due to successful test in S460

Schematic cross section through SNE Field

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SNE development and tie back concept

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• Standalone FPSO: planned expansion capability for tie-backs

• CAPEX: US$12- US$15/bbl*

• OPEX: < US$10/bbl*

• Breakeven oil price: US$35/bbl*

• NPV/bbl : US$12.50/bbl* (at FID, US$70/bbl oil price, 2C 473mmbbls)

• FAR Plateau production: rate expected to be ~140,000 bopd

• FAR Phase 1 development: 349 mmbbls

• FAR phase 1 development has:

• 22 producing wells

• 18 water injection wells

FAR Phase 1 development concept

Refer to FAR ASX releases dated 24 September 2015 and 4 January 2016

• 1 gas injection well plus re-entry into SNE-2

• Drilling cost reductions yet to reduce CAPEX estimate

Flow lines and manifolds

Oil Gas

Water

*Cairn Energy Half Yearly Result 16/08/2016

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The Gambia licence acquisitions

• Farm-in to 80% working interest with operator rights

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• Erin Energy 20% partner

• FAR payment of US$5.18M to Erin, due on Government approval

• Well at end 2018

• Large equity position gives FAR options to farm down

• Support letter from Ministry of Petroleum

About The Gambia

• Capital: Bajul

• Population: 1.8M

• Languages: English (official), Mandinka, Wolof

• Major religions: Islam, Christianity

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Blocks A2 and A5 prospectivity

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• 1 billion barrels of oil prospectivity mapped to date*

• Sama prospect defined on 3D seismic approximately 500mmbbls recoverable*

• 1,504km[2] 3D seismic data acquired in 2015

• Seismic reprocessing planned before drilling in 2018

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*Gross, unrisked, recoverable, best estimate of prospective resources, oil only

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Extension of the SNE shelf edge trend

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• On trend with SNE – same play type

• Access to same source kitchen

• Highly prospective

• High chance of success

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Extension of the SNE shelf edge trend

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Spica
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• On trend with SNE – same play type

• Access to same source kitchen

• Highly prospective

• High chance of success

• Sama prospect reservoirs penetrated by

• 7 wells in SNE program

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Regional schematic cross-section

• Same upper/400 series reservoirs as SNE

• Thickening of 400 series sands to the south

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Next 12 months in Senegal

• Deepen VR-1 appraisal into exploration target

• Conduct interference test by pulsing from SNE-6

• SNE-6 expected to be completed by mid year

• JV to agree possible exploration well to drill in current campaign

• Upgrade in contingent resource estimate for SNE

• Finalise Phase 1 development concept

• Certification of reserves for SNE

• Submission of development plan for approval

• Active new ventures program – focus on the NW African margin

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Contact us

Level 17, 530 Collins Street Melbourne VIC 3000 Australia T: +61 3 9618 2550 info@far.com.au far.com.au

Connect with FAR Limited:

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Disclaimer

• This presentation has been prepared by FAR Limited (‘FAR’). It should not be considered as an offer or invitation to subscribe for or purchase any shares in FAR or as an inducement to make an offer or invitation with respect to those securities. No agreement to subscribe for shares in FAR will be entered into on the basis of this presentation.

• This presentation contains forward-looking statements that are not based on historical fact, including those identified by the use of forward-looking terminology containing such words as ‘believes’, ‘may’, ‘will’, ‘estimates’, ‘continue’, ‘anticipates’, ‘intends’, ‘expects’, ‘should’, ‘schedule’, ‘program’, ‘potential’ or the negatives thereof and words of similar import.

• FAR cautions that these forward-looking statements are subject to risks and uncertainties that could cause actual events or results to differ materially from those expressed or implied by the statements. The forward looking statements are expressly subject to this caution. FAR makes no representation, warranty (express or implied), or assurance as to the completeness or accuracy of these forward-looking statements and, accordingly, expresses no opinion or any other form of assurance regarding them. FAR will not necessarily publish updates or revisions of these forwardlooking statements to reflect FAR’s circumstances after the date hereof.

• By its very nature exploration and development of oil and gas is high risk and is not suitable for certain investors. FAR shares are a speculative investment. There are a number of risks, both specific to FAR and of a general nature which may affect the future operating and financial performance of FAR and the value of an investment in FAR including and not limited to economic conditions, stock market fluctuations, oil and gas demand and price movements, regional infrastructure constraints, securing drilling rigs, timing of approvals from relevant authorities, regulatory risks, operational risks, reliance on key personnel, foreign currency fluctuations, and regional geopolitical risks.

• This presentation does not purport to be all inclusive or to contain all information which you may require in order to make an informed assessment of the Company’s prospects. You should conduct your own investigation, perform your own analysis, and seek your own advice from your professional adviser before making any investment decision.

• Cautionary Statement for Prospective Resource Estimates – With respect to the Prospective Resource estimates contained within this report, it should be noted that the estimated quantities of Petroleum that may potentially be recovered by the future application of a development project may relate to undiscovered accumulations. These estimates have an associated risk of discovery and risk of development. Further exploration and appraisal is required to determine the existence of a significant quantity of potentially moveable hydrocarbons.

• Information in this report relating to hydrocarbon resource estimates has been compiled by Peter Nicholls, the FAR exploration manager. Mr Nicholls has over 30 years of experience in petroleum geophysics and geology and is a member of the American Association of Petroleum Geology, the Society of Exploration Geophysicists and the Petroleum Exploration Society of Australia. Mr Nicholls consents to the inclusion of the information in this report relating to hydrocarbon Prospective Resources in the form and context in which it appears. The Prospective Resource estimates contained in this report are in accordance with the standard definitions set out by the Society of Petroleum Engineers, Petroleum Resource Management System.

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