For personal use only J. Michael Yeager Chairman and Chief - - PowerPoint PPT Presentation

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For personal use only J. Michael Yeager Chairman and Chief - - PowerPoint PPT Presentation

Investor Presentation May 2017 AGM For personal use only J. Michael Yeager Chairman and Chief Executive Officer 25 26 May 2017 1 Important Notice and Disclaimer For personal use only This presentation has been prepared by Freedom Oil


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1

Investor Presentation – May 2017 AGM

  • J. Michael Yeager

Chairman and Chief Executive Officer 25 – 26 May 2017

For personal use only

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2 This presentation has been prepared by Freedom Oil and Gas Ltd (“Freedom”). The information in this presentation is of a general nature and does not purport to be complete, nor does it contain all of the information which would be required in a prospectus prepared in accordance with the requirements of the Corporations Act. It contains information in a summary form only and should be read in conjunction with Freedom’s other periodic disclosure announcements to the ASX available at: www.asx.com.au. An investment in Freedom shares is subject to known and unknown risks, many of which are beyond the control of Freedom. In considering an investment in Freedom shares, investors should have regard to (amongst other things) the risks outlined in this presentation. This presentation contains statements, opinions, projections, forecasts and other material (“forward looking statements”), based on various assumptions. Those assumptions may or may not prove to be correct. None of Freedom, its respective officers, employees, agents, advisers or any other person named in this presentation makes any representation as to the accuracy or likelihood of fulfilment of the forward looking statements or any of the assumptions upon which they are based. Maps and diagrams contained in this presentation are provided to assist with the identification and description of Freedom’s lease holdings and Freedom’s intended targets and potential exploration areas within those leases. The maps and diagrams may not be drawn to scale and Freedom’s intended targets and exploration areas may change in the future. The information contained in this presentation does not take into account the investment objectives, financial situation or particular needs of any recipient and is not financial product advice. Before making an investment decision, recipients of this presentation should consider their own needs and situation and, if necessary, seek independent professional advice. To the extent permitted by law, Freedom and its respective officers, employees, agents and advisers give no warranty, representation or guarantee as to the accuracy, completeness or reliability of the information contained in this presentation. Further, none of Freedom and its respective officers, employees, agents and advisers accept, to the extent permitted by law, responsibility for any loss, claim, damages, costs or expenses arising out of, or in connection with, the information contained in this presentation. Any recipient of this presentation should independently satisfy themselves as to the accuracy of all information contained herein. COMPETENT PERSON STATEMENT The evaluation of reserves referred to in this presentation were undertaken by Netherland, Sewell & Associates, Inc. (“NSAI”), a worldwide leader of petroleum property analysis for industry and financial organizations and government agencies. NSAI was founded in 1961 and performs consulting petroleum engineering services under Texas Board of Professional Engineers Registration No. F-2699. NSAI’s technical principals meet or exceed the education, training, and experience requirements set forth in the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Engineers; both are proficient in judiciously applying industry standard practices to engineering and geoscience evaluations as well as applying United States Security and Exchange and other industry reserves definitions and guidelines. NSAI’s technical principals are qualified persons as defined in ASX Listing Rule 5.22. The reserves estimates are consistent with the definitions of Proved and Probable hydrocarbon reserves defined in the Australian Stock Exchange (ASX) Listing Rules. Compensation for the required investigations and preparation of third party reserve reports are not contingent upon the results

  • btained and reported, and the third party reserve engineers have not performed other work for us that would affect their objectivity. NSAI has consented to the

use of the reserves figures in this report in the form and context in which they appear.

Important Notice and Disclaimer

For personal use only

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  • Based in Houston, TX
  • Trades on ASX under “FDM” and

OTCQX under “FDMQF”

  • Focused on developing a 10,000

acreage position in the liquids-rich Eagle Ford shale formation in Dimmit County, TX

  • Identified over 300 well locations at

60 acre spacing

  • Pursuing high-return projects that
  • ffer lower well costs combined with

higher revenue streams for best investment value

  • Proven and highly experienced

management team with operating history in the Eagle Ford shale

Company Profile

Freedom Oil & Gas Eagle Ford Acreage

Eagle Ford Shale Producing Counties in Texas

3

Dimmit

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SLIDE 4

Investment Highlights

Compelling investment opportunity in early-stage E&P company with significant upside

  • Acreage positioned in volatile oil/condensate window
  • Shale thickness of ~400 ft. with three productive intervals (stack-pay)
  • Production is 70-80 percent liquids of 47-degree API volatile oil and

natural gas liquids

  • Over 350 offset wells have been drilled to de-risk the geology

Positioned in premium area

  • f Eagle Ford

Shale

  • First well of initial drilling program commenced on 21 May 2017
  • Up to six initial evaluation wells to be drilled in 2017, then full

development

  • Potential proved reserves and production growth through

development for up to 10 years

Acreage position can support a decade of growth

  • Acreage position leased at attractive prices during very low oil prices
  • Moderate reservoir depths and easy drilling allow for low drilling

costs at $4-$5 million per well

  • Recent offset operator results show returns of 40 percent plus
  • Technology enhancements in last two years are driving

improvements of 30-40 percent in production rate and reserves

Solid economic returns at current oil prices

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Why the Eagle Ford in Dimmit County, TX?

Screening Criteria / Opportunity Characteristics Dimmit County Eagle Ford Shale Large Oily Basin with Proven Super Source Rocks Proven Area Light to Medium Gravity Oil & High-Rate Gas Large Oil-in-Place Volumes Moderate Depth – Lower Cost Drilling Acreage Adjacent to Active Development High Oil Recovery per Well Predictable Geology, Repeatable Low Risk Drilling Significant Development Upside and Growth Stacked Pays to Increase Number of Investment Opportunities Operated Assets – High Working Interest Open Well Spacing / Down Spacing Potential Long Life Assets Where Technology Improvements Add Value Economically Developable at Today’s Prices

             

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  • Contiguous Acreage Position
  • 9,300 acres adjacent to proven productivity, which is sufficient to initiate drilling program
  • Additional acres under negotiation for 10,000-acre target
  • Contiguous acreage allows for long laterals and simple development
  • 100% working interest and 75% Net Revenue Interest in all acreage. All acreage is operated by FDM.
  • Quality Resource Play
  • Offset operator wells on production allowed for booking of proved reserves prior to drilling first well
  • Major acquisitions by Sanchez, Protégé and Venado and active follow up drilling on offset acreage is occurring

immediately adjacent to FDM acreage

  • Acreage position and three stacked levels is very material at a ~200 MMBoe opportunity fully developable
  • All Data Independently Verified
  • Von Gonten & Company independently verified all type curves and estimated reserve recoveries (EUR)
  • FDM reserve analysis by Netherland, Sewell & Associates, Inc. on 31 December 2016 resulted in proved

reserves being recorded

  • Oil and gas pipeline transportation costs are based on actual contract rates currently being finalized
  • Solid Fundamentals and Improving Returns
  • New completion designs are enhancing well performance and positively impacting value
  • Close proximity to Gulf Coast refining and high gravity oil leads to advantaged oil pricing
  • Service costs are up 15% in last 6 months, but significantly down from 2014

FDM’s Eagle Ford Acreage Advantages

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  • Expect to drill the first two wells in Q2 2017 targeting the Eagle Ford Shale
  • Four more wells expected to be drilled in 2017 to finalize design and execution plans for the
  • ptimum field development
  • Single rig continuous drilling program planned for 2018
  • Reserves Based Lending facility and operating cash flow should fund development after 6

initial wells are drilled, completed and producing

  • Development currently planned as per timeline below

FDM’s Eagle Ford Drilling Plan

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… 2017

Secure drilling rig from Patterson UTI

Plan for Drilling Program Q2 2017 … 2018 …

Spud two wells targeting LEF shale Drill and complete four additional delineation wells Secure Reserves Based Lending facility Commence single rig continuous drilling program Secure interim four well funding

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Plan to Develop Three Distinct Intervals

8

Buda Upper Eagle Ford Marl

“B” “A”

Austin Chalk Lower Ford Shale

60 Acre/ 500ft 200 ft 60 Acre/ 500ft 60 Acre/ 500ft

Lower Eagle Ford A ~ 60 feet thick Projected EUR of 690 MBOE Upper Eagle Ford: ~200 feet thick EUR projection of 695 MBOE Lower Eagle Ford B ~ 110 feet thick EUR projection of 552 MBOE, lowered for potential interference

Initial Development Plan & EUR Assumptions

Drilling Program: Six Wells 2017 One Rig (24 wells/yr) 2Q18 Two Rigs (48 wells/yr) 2Q19

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 Drilling Services Contracted

  • Contracted with Patterson-UTI Drilling Company to drill the

first two EF wells

  • Completion program in final stages of preparation
  • All other services are finalized

 Seismic and Well Data Obtained to Optimize the Well Design and Results

  • 3D seismic coverage over initial area has been acquired
  • Well logs and landing results of over 350 offset operator

wells have been obtained and analyzed

  • Cores in five surrounding wells obtained for foot by foot

reservoir analysis

 Infrastructure

  • Available pipeline capacity within one mile of the acreage for
  • il and gas transportation
  • Multiple pipeline options being negotiated for August startup

FDM’s Eagle Ford Program Status

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Recent Drilling & Completion Advances

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Advancing Drilling and Completion Technology Increases Production

2014 - 2017

5,000’ – 6,000’ 6,000’ – 8,000’

600 – 900 LB/FT 2,000 – 3,000 LB/FT ~ 15 Stages ( > 400ft Spacing) >30 Stages ( < 200ft Spacing) > 70ft Spacing 25 – 50ft Spacing Variety of Fluid System Hybrid and Slickwater with Diversion Ceramic Proppant White Sand Various 100 Mesh - 40/70

2007 - 2013

Lateral Length Proppant Volume # of Stages Cluster Spacing Fluid Type Proppant Type Proppant Size

  • Longer laterals
  • More intense fracturing
  • More sand per foot
  • But lower cost than 2014

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11

  • FDM commenced

drilling of 2 horizontals

  • Protégé acquired

Newfield EF Assets

  • Protégé drilling pilot - 6

wells planned

  • Sanchez (SN) acquired

Anadarko EF Asset

  • SN actively leasing

directly east and north

  • f Freedom acreage
  • SN plans 35 wells east

and north of FDM

  • Venado acquired EXCO

Recent Activity Reinforces Asset Value

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8K LL EUR Breakeven WTI* LEF A 690 $4.0 67% $4,481 <$37 UEF 695 $4.0 >100% $5,835 <$34 LEF B** 552 $4.0 59% $3,400 <$39

MBOE ($MM) ROR NAV PV10, $M PV10%

* NYMEX Gas Price assumed $2.50/Mcf flat ** EUR reduced by 20% to account for potential interference

Single Well Economics

12

NYMEX Forward Strip – May 23, 2017 2017 2018 2019 2020 2021 2022+ Oil ($/bbl) WTI $51.69 $51.96 $51.23 $51.32 $52.05 $53.17 Gas ($/MMbtu) NYMEX HH $3.29 $3.10 $2.85 $2.87 $2.90 $2.95

May 23, 2017 Strip D&C Cost

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* Net three stream EUR assuming 75% NRI, 19% shrink and 129 bbl/mmcf of NGL’s ** EUR reduced by 20% to account for potential interference

Proved Reserves and Resource Potential

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Development Potential Gross Well Net Reserves / Resource Net Asset Value Locations Potential (Mmboe) PV-10 $MM (5/23/2017) YE2016 2P Reserves* 23 11 $65 Lower Eagle Ford A 88 59 $257 Upper Eagle Ford 107 66 $418 Lower Eagle Ford B** 100 49 $166 Total 60 Acre Reserves & Resources 318 185 $906 30 Acre Downspacing 318 158 $376 Total Potential Undeveloped Resource 636 343 $1,282 NYMEX Forward Strip – May 23, 2017 2017 2018 2019 2020 2021 2022+ Oil ($/bbl) WTI $51.69 $51.96 $51.23 $51.32 $52.05 $53.17 Gas ($/MMbtu) NYMEX HH $3.29 $3.10 $2.85 $2.87 $2.90 $2.95

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 2 well drilling plan has commenced for next 30 – 40 days  Wells will be hydraulically fractured and put on production 30 – 40 days later  6 total wells needed for Wells Fargo lending facility to commence  Banking service has been hired to pursue interim debt, obtain a partner and/or raise equity for wells 3 to 6  Initial wells are expected to de-risk the economics due to furthering our geologic understanding, establishing drilling and completion cost/execution plans and determining production rates  Well results are projected to continually improve as more wells are drilled and more knowledge is gained

Business Summary

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APPENDIX

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Impact of Recent Technology Changes

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  • Major changes in well design by all
  • perators in last two years
  • Results in 40 percent improvement in

Estimated Ultimate Recovery (EUR)

  • Drilling and Completion costs today for a

8,000 foot lateral with modern hydraulic fracturing of $4.0 to $5.0 million per well

  • Improved EUR and lower cost create

strong economics at Strip Prices

  • 10 percent RoR breakeven oil price of

$38.00/barrel

  • Single Well economics of 50 – 60

percent RoR at today’s forward strip Eagle Ford wells 2007 to 2013 metrics 2014 to 2017 metrics Laterals 5,000 foot 6,000 to 10,000 foot Stages of hydraulic fracturing 10 to 15 stages with 400 foot spacing 30 to 40 stages with 200- 250 foot spacing Perf clusters 70 foot spacing 25-50 foot spacing Sand volume 600 to 900 pounds per foot 1,200 to 3,000 pounds per foot

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Improving EF Well Performance

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  • The EIA has

recently reported that the Eagle Ford well results are improving dramatically YOY

  • Oil and gas

production per well up 40% over last three years

  • Technology changes

in completions indicate production growth in EF shale since early 2007 will continue

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Single Well Economic Parameters

8000’ Lateral EUR(1) EUR UEF (74% Liquids) 695 MBOE EUR LEF B (72% Liquids) 554 MBOE EUR LEF A (72% Liquids) 690 MBOE Liquids Yield(2) NGL Yield 129 bbl/mmcf Gas Shrinkage 19% Drilling Costs Well D&C Costs (Dimmit) $4 - $5 Million Operating Expense(2) Total LOS $6-7.00/boe Development Plan Two Wells (One with Pilot) May ‘17 Four Wells 4Q17 One Rig Program (2 wells/month) 2Q18 Two Rig Program (4 wells/month) 2Q19

(1)Type Curve Verified by WDVG (2)Based data of offset operator data

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  • Alt. Single Well Economic Parameters

8000’ Lateral EUR(1) EUR UEF (74% Liquids) 695 MBOE EUR LEF B (72% Liquids) 554 MBOE EUR LEF A (72% Liquids) 690 MBOE Liquids Yield(2) NGL Yield 129 bbl/mmcf Gas Shrinkage 19% Drilling Costs Well D&C Costs (Dimmit) $4 - $5 Million Operating Expense(2) Total LOS $6-7.00/boe Development Plan Two Wells (One with Pilot) May ‘17 Four Wells 4Q17 One Rig Program (2 wells/month) 2Q18 Two Rig Program (4 wells/month) 2Q19

(1)Type Curve Verified by WDVG (2)Based data of offset operator data

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5,000 10,000 15,000 20,000 25,000 30,000 35,000 40,000 45,000 50,000 2017 2020 2023 2026 2029 2032

Development Plan Production Curve

30 Acre Infill 60 Acre Development 20

Development Plan Production Curve

Two Rig Program 30 Acre Development 6 Well Program One Rig Program

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Dimmit | La Salle | McMullen | Karnes | DeWitt SW NE

Eagle Ford Shale

GR Res

Upper Eagle Ford Marl Austin Chalk “B” “A” Buda

370 ’

“B” “A” Upper Eagle Ford Marl

  • Similar characteristics

throughout the trend

  • Dimmit County Area EF is

~ 370’ thick

  • Three proven productive

intervals of EF development

  • Doubling of development

wells, EUR and longer term production rates possible

  • Downspacing
  • pportunities being

tested

  • Prospective for the Austin

Chalk and Buda

Regional EF Well Correlation Cross Section

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  • EF is oil mature over Target Area
  • FDM area has Oil Gravity in the 45 to 48

Degree API Range

  • Optimal Oil Gravity for Efficient Recovery

Oil Gravity EF

EF API Gravity Map - Dimmit Focus Area

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170 ’ 150 ’

Res GR

Up Upper per Eagle For

  • rd

d Marl “B” “A” 200’ Lower Lower Eagle For

  • rd

d Sha hale Buda Buda De Del Rio

  • (Ba

Base of

  • f Bud

Buda)

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  • FDM area has GOR between 2,000 - 3,000
  • Higher GOR Improves Recovery
  • 70 – 80% Liquids

Eagle Ford GOR Map – Dimmit Focus Area

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Third-Party Type Curve Verification

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  • Engaged W. D. Von Gonten & Co.

(WDVG) to verify type curve work

  • Type curves were created using past

four years of production data

  • No filtering was done for poor

completions

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FDM Area – 8,000 ft Normalized Oil Production Plots (Lower EGFD)

Lower EF Wells EUR Verified by WDVG

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Lower Eagle Ford Shale Isopach

FDM Acreage 8K LL EUR Estimate Oil EUR = 379 MBO Gas EUR = 1,865 MMCF Total EUR = 690 MBOE

  • WDVG 4 Year Verified EUR in

October 2015

  • WDVG 2 Year Verified in April

2016

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FDM Area – 8,000 ft Normalized Oil Production Plots (Upper/Marl EGFD)

  • WDVG 4 Year Verified EUR in

October 2015

  • WDVG 2 Year Verified in April

2016

Upper EF Wells EUR Verified by WDVG

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Lower Eagle Ford Shale Isopach

FDM Acreage 8K LL EUR Estimate Oil EUR = 417 MBO Gas EUR = 1,665 MMCF Total EUR = 695 MBOE

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