catalysts for growth · 4 point loma growth catalysts plx:tsxv inception 135 boe/d september 2016...
TRANSCRIPT
September 2017
Catalysts for GrowthAccretive Steps
PLX:TSXV1
2
Point LomaSnapshot
• Funded growth steps in second half of 2017
o September drilling 2 Hz wells
o Activation of acquired development well
o Re-activation of Paddle River volumes
• Further re-activations in Q4 and Q1 continue low risk growth
• Increased liquids weighting with deep cut facilities
• Key capital partners can reduce cost of capital
• Creating shareholder value
PLX:TSXV
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Point LomaStrategy
PLX:TSXV
• Point Loma has captured a significant
position on the highly prospective
multi-zone Mannville and
Mississippian fairway of West Central
Alberta.
• Modest drill depth and technological
advancements leads to strong
economics with low costs per well
• Over 160,000 net acres with
significant shallow to medium depth
horizontal drilling inventory (> 250 net
drilling opportunities)
• Joint Venture and new equity
unlocks immediate growth
• Build value for successful exit strategy
and shareholder return
4
Point LomaGrowth Catalysts
PLX:TSXV
Inception
135 boe/d
September 2016
400 boe/d
Re-activate Paddle River
Ostracod
March 2017
830 boe/d
Acquire Judy Creek Assets
Q3 2017
Drill 2 wells
Purchase key wells
Optimize Facilities
Q3/Q4 2017
Re-activate Leaman area wells
Drill follow up wells
Q1 2018
Re-activate Thornbury wells
Drill follow up wells
$8 M
Evenergy
Salt Bush
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Basic Shares Outstanding(2) 42,078,907
Fully Diluted Shares Outstanding 46,028,907
Insider Ownership (Basic / Fully Diluted) 44% / 47%
Management Ownership (Basic / Fully Diluted) 7.0% / 11.0%
Market Capitalization (Basic)(1) $13,465,000
Convertible Debenture – Matures on June 28, 2021(2) $2,500,000
Working Capital $5,400,000
Management Average Cost – per share $0.55-0.59
Notes:
(1) Based on Aug 28 – Sept 1, 2017 weighted average closing price of approximately $0.32 per share
(2) The convertible debenture 3.0% interest with conversion price of $0.50 per share
TSXV – PLX
Share Price (Aug. 28-Sept. 1, 2017) $0.32
Capital StructureCurrent Balance sheet
2017 Current production
Oil/Gas weighting
600 boe/d
25%/75%
6
Lower Mannville DevelopmentQ3 drill one horizontal well, place acquired well on production
1-3
2
8-3
1
LOWER MANNVILLE SS NET PAY MAP
Cutoff: 6% SSØ
• Purchased 2 wells in
Sec. 4-56-7W5
• 12-4-56-7W5
scheduled to start
production in
September
• 2-4 is potential re-
entry candidate
• Acquisition adds 2
potential drilling
opportunities
• Future cost
reductions with
central facilities
PUD location
Drilling opportunity
Q3 Drilling
location
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Lower Mannville FacilitiesOptimization plan
PLX:TSXV
Facility plan
• Construct central tankage, treating for Paddle
River lower Mannville oil development
• Add flowline capacity
• Utilize existing well as water injector
• Save on emulsion/water trucking
• Support reservoir pressure
$1.2M Capital
Savings $7.20/bbl
• Total
• $1.2M Annual Savings
Results
• With additional development of the
area significant savings result
• 2 new wells in Q3 see benefits
• Future drilling realizes significant
savings
Paddle RiverRe-activation plans and increased liquids recovery
• September 2017 -Re-activation of
approximately 1.2-1.5
mmcfd (1.0-1.2 net)
additional area gas
• September 2017 -Flow paddle river solution
gas, new drill and newly
acquired 12-4 well to
Tidewater plant
• Ultimate re-activations
would add a further 1.0 –
1.5 mmcfd
• Increased liquids
recovery from deep cut
facility
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Point Loma Land
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ThorsbyTie-in Glauconite and drill Sparky
PLX:TSXV
Successful
Sparky wells -
Blackspur
9-18 HZ Location and
tie-in
• Tie-in 103/11-18
Glauconite well
• Drill Hz Sparky well
• Opportunity to develop
in two zones with
multi-well potential
• Emerging play has
good growth potential
Oil Gas
6 Regional Horizontal Wells – Oil and Gas Production
WhitecourtBuilding drilling and recompletion inventory
• Current production of
1,600 mcfd net, 45%
WI in gas processing
facility at Judy Creek
• Ownership reduces
incremental costs
• Successful industry
HZ offset sets up
potential future drilling.
IP 4 mmcfd, Cum 2.5
BCF
• Multiple re-completion
candidates and
potential drilling
opportunities
10
Point Loma Land
ThornburyQ1 2018 re-activation opportunities allow for cost growth
• Current production of
500 mcfd net, 80% WI
in gas compression
facility
• Q1 2018 plans to re-
activate approximately
2.0 mmcfd (1.6 net)
• Will require 3 minor
pipeline connections
planned for winter
2017/18 to re-activate
additional volumes,
$360k net
• Approximately 40,000
net acres
Jumper #1
Prod. Add :
0.75 -1.0
MMCFD
Jumper #2
Prod Add:
1.25 – 1.5
MMCFD
Algar 12-28
Compressor
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Why Invest in Point Loma?Catalysts for Growth
• Capital in place to unlock value
• September drilling 2 wells to develop production
• Addition of new well via acquisition adds production
• Re-activations in Paddle River increase volumes and
liquids
• Further re-activations (Paddle, Thornbury) continue
built in growth steps
• Experienced team aligned with shareholders
PLX:TSXV
13
Disclaimers
Forward Looking StatementsCertain information regarding Point Loma Resources Ltd. (the “Corporation” or “PLX”) inthis
presentation including without limitation management's assessment of future plans and operations,the
benefits to be derived from the proposed transactions, future acquisitions, timing of drilling and tie-in of
wells, cash flow projections, pricing assumptions, productive capacity of the new wells and productive
capacity from different wells, expected production rates, drilling success rates, expected operating
rates, expected LLR ratings, dates of commencement of production, may constitute forward looking
statements under applicable securities laws and necessarily involve risks including, without limitation,
risks associated with oil and gas exploration, development, exploitation, production, marketing and
transportation, loss of markets, volatility of commodity prices, currency fluctuations, imprecision of
reserve estimates, environmental risks, competition from other producers, inability to retain drilling rigs
and other services, unexpected decline rates in wells, wells not performing as expected, delays
resulting from or inability to obtain required regulatory approvals and ability to access sufficient capital
from internal and external sources. As a consequence, actual results may differ materially from those
anticipated in the forward-looking statements. Readers are cautioned that the foregoing list of factors
is not exhaustive. Additional information on these and other factors that could effect the Corporation's
operations and financial results will be included in financial reports. Furthermore, the forward looking
statements contained in this presentation are made as at the date of this presentation and the
Corporation does not undertake any obligation to update publicly or to revise any of the included
forward looking statements, whether as a result of new information, future events or otherwise, except
as may be required by applicable securities laws.
PLX:TSXV
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Disclaimers
Oil and Gas DisclosuresBarrel of oil equivalents or BOEs may be misleading, particularly if used in isolation. A BOE conversion
ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the
burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio
based on the current price of crude oil as compared to natural gas is significantly different than the
energy equivalency of the 6:1 conversion ratio, utilizing the 6:1 conversion ratio may be misleading as
an indication of value.
References in this document to production test rates, initial test production rates, and other short-term
production rates are useful in confirming the presence of hydrocarbons, however such rates are not
determinative of the rates at which such wells will commence production and decline thereafter and
are not indicative of long term performance or of ultimate recovery. Additionally, such rates may also
include recovered "load oil" fluids used in well completion stimulation. While encouraging, readers are
cautioned not to place reliance on such rates in calculating the aggregate production for Point Loma. A
pressure transient analysis or well-test interpretation has not been carried out in respect of all wells.
Accordingly, the Corporation cautions that the test results should be considered to be preliminary.
This presentation discloses drilling locations in two categories: (i) proved locations; and (ii)potential
drilling opportunities. Proved locations, which are sometimes collectively referred to as “booked
locations”, are derived from the Corporation’s most recent independent reserves evaluation as of
December 31, 2016 and account for drilling locations that have associated proven reserves, as
applicable.
PLX:TSXV
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Disclaimers
Potential drilling opportunities are internal estimates based on the Corporation’s prospective acreage
and an assumption as to the number of wells that can be drilled per section based on industry practice
and internal review. Potential drilling opportunities do not have attributed reserves or resources. The
Corporation has, based on the December 31, 2016 reserve report and management's current internal
estimate, 3.4 net proved locations and 70 identified potential drilling opportunities. Potential drilling
opportunities have specifically been identified by Management as an estimation of our multi-year
experience in drilling activities based on evaluation of applicable geologic, seismic, engineering,
production and reserves data on prospective acreage and geologic formations. The drilling locations
on which we actually drill wells will ultimately depend upon the availability of capital, regulatory
approvals, seasonal restrictions, oil and natural gas prices, costs, actual drilling results and other
factors. While certain of the potential drilling opportunities have been de-risked by drilling of wells by
the Corporation or other operators in close proximity to such potential drilling opportunities, the
majority of other potential drilling opportunities are farther away from existing wells where
management has less information about the characteristics of the reservoir and therefore there ismore
uncertainty whether wells will be drilled in such locations and, if drilled, there is more uncertainty that
such wells will result in additional oil and gas reserves, resources orproduction.
Type wells indicated herein are internal estimates based on common industry practices of reviewing
analogous wells in reasonable proximity to the drilling opportunities and defining a ‘type well’ by
averaging production of the analogous wells for the first 24 months, or longer, as available from public
sources. These type wells have been prepared by a qualified reserves evaluator or auditor and do not
represent ‘reserves’ as defined by NI 51-101. Well economics associated with these estimates are
based on certain assumptions made by management based on current pricing, costs, royalties and are
not intended to provide an estimate of future performance of wells or an estimate of reserves.
PLX:TSXV
Contact Information
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Head Office2000, 350 – 7 Avenue SW
Calgary, Alberta T2P 3N9
403-705-5051
Contacts Terry Meek,
President, CEO
403-705-5051, e444
Kevin Angus,
Executive Vice President Business Development
403-705-5051, e440
Randall Boyd,
Vice President Finance, Chief Financial Officer
403-705-5051, e443
Corporate Services Legal Counsel
McCarthy Tétrault
Reserve Engineers
McDaniel &Associates
Consultants Ltd.
Auditors
KPMG LLP
Transfer Agent
Computershare Investor
Services
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An Experienced & Energized TeamWith a Track Record of Unlocking Value in West-Central Alberta
Terry Meek, P.Eng., President, CEO
• Mr. Meek has 30+ years of experience in the conventional and unconventional oil & gas industry. Former founder, Executive VP and COO of the
coal bed methane focused company Ember Resources Inc. (2005-2011). Former founder, VP Engineering and COO of Thunder Energy (1995-
2005), growing market capital to over $600 million from inception.
Kevin Angus, P.Geoph., ICD.D, Executive Vice President Business Development
• Mr. Angus has 30+ years of geotechnical experience and is also a director of Painted Pony Petroleum. Former co-founder of three public oil and
gas companies, Mustang Resources Inc., Pegasus Oil and Gas Inc. and Surge Energy Inc. Mr. Angus has also held positions with Husky Energy
Inc., Ulster Petroleum Ltd. and Archean Energy Ltd.
Randall Boyd, CPA, CGA, Vice President Finance and CFO
• Mr. Boyd is an experienced public CFO with 30+ years in the oil and gas industry. His experience includes positions as CFO at Deventa Energy
Inc., Masters Energy Inc. and other listed companies. Prior experience includes Flagstone Energy Inc., Norwich Resources and Archean Energy.
Dan Boyko, P. Eng., Vice President, Engineering
• Mr. Boyko has 30+ years of experience in the petroleum industry. Former VP Business Development for Open Range Energy Corp. and has
acted as a Petroleum Engineering consultant for multiple companies including NAL Resources.
Brad Johnston , B.Comm – Vice President Land
• Mr. Johnston has 18 years of experience in the oil and gas industry, both internationally and in Western Canada, Mr. Johnston previously held
positions at Galleon Energy Inc., Nexen Energy Inc. and was VP Land for Carnaby Energy Ltd.
Gordon Cameron – Corporate Secretary
• Mr. Cameron is a partner at McCarthy Tétrault LLP. He has been a practicing corporate lawyer for over 9 years and specializes in the areas of
corporate finance, capital markets, corporate governance and mergers and acquisitions.
Travis Brookson P. Geo., Exploration Manager
• Mr. Brookson has 21 years of geological experience in the Western Canadian Sedimentary Basin, mostly focused on conventional stacked plays
in central Alberta and the Peace River Arch. Mr. Brookson’s prior companies include Taqa North, Ravenwood Energy, Spartan Energy.
Jamie Chisholm, P. Eng., Operations Manager
• Mr. Chisholm has 19 years of experience in the Oil and Gas sector. Mr. Chisholm has worked various positions starting at the field level and
progressing into more senior positions with companies such as Canadian Natural Resources, Birchcliff Energy and Westfire Energy.
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Strong GovernanceExperienced Board of Directors, Four Independent
Steve Dabner, P. Geol., - Chairman
• Mr. Dabner previously Vice President Exploration and New Ventures at Madalena. Mr. Dabner has 33 years of industry experience, including
founding roles as President and Chief Executive Officer of Online Energy Inc., Trimox Energy Inc. and Moxie Exploration Ltd.
Doug Dafoe, CA
• Mr. Dafoe is currently the Chief Executive Officer and President of Ember Resources Inc. and Chairman of the Board of Xtreme Drilling and Coil
Services Corp. Mr. Dafoe has 35 years industry experience with public and private oil and gas companies in Western Canada, including acting
as Chief Executive Officer and President to Sword Energy Inc.
Jay Reid, B.Comm, LLB
• Mr. Reid is currently a partner at Burnet Duckworth and Palmer LLP and has a practice focused on securities laws in the area of capital markets,
mergers and acquisitions and corporate governance. Mr. Reid has over 26 years of industry experience. During the course of his career Mr. Reid
has acted as a Director or Officer of 19 public companies.
Don Brown
• Mr. Brown is an independent businessman with over 30 years of industry experience and formerly the President and Chief Executive Officer of
Elkwater Resources Ltd. until July 2014.
Kevin Baker, Q.C.
• Mr. Baker has served as a Director of Calfrac Well Services Ltd. since 2010. Mr. Baker has also served as the President and Managing Director
of Baycor Capital Inc., a private merchant banker, since January 1990 and the CEO of ConleyMax Inc., an oilfield services company since
September2011.
Terry Meek – President, CEO
• Bio in Management Section
Jianjun Cui, PhD Geoph.
• Mr. Cui has more than 20 years of senior management experience including Senior Vice President of a Hong Kong listed company, Vice President
of Mergers and Acquisitions for Sinochem Petroleum, Country Manager to Colombia and General Manager of Asset Management for Sinochem
Petroleum.
PLX:TSXV
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Multiple Zone Oil and Liquids Rich Gas FairwayUpper Mannville Inventory
Blackspur
Bonavista
Tourmaline
Cenovus
Cardinal
Vermillion
Petrus
Manitok
Industry
Success
Significant Horizontal Opportunity Base
Zone Bypass drilling
Opportunities (1)
Follow-up
Opportunities(1)
Glauconite 17 104
Other Upper
Mannville
15 90
Assumptions
Drill - $900k
Complete - $600k
Tie-in - $400k
15 stage frac
(1)See Disclaimers for additional definitions of locations and opportunities. Follow up
opportunities are wells on industry standard spacing that would result from a successful
drilling opportunity.
Month Month
18 Regional Horizontal Wells – Oil and Gas Production By Well
• Over 5,500 well penetrations in
the area have identified our
bypass opportunities
20
Multiple Zone Oil and Liquids Rich Gas FairwayLower Mannville Inventory
Industry
Success
Significant Horizontal Opportunity Base
• Over 5,500 well penetrations in
the area have identified our
bypass opportunities
(1)See Disclaimers for additional definitions of locations and opportunities. Follow up
opportunities are wells on industry standard spacing that would result from a successful
drilling opportunity.
Assumptions
Drill - $900k
Complete - $600k
Tie-in - $400k
15 stage frac
Blackspur
Bonavista
Tourmaline
Cenovus
Cardinal
Vermillion
Petrus
Manitok
Zone Bypass drilling
Opportunities (1)
Follow up
Opportunities(1)
Ostracod 19 121
Ellerslie 5 30
Month Month
6 Regional Horizontal Wells – Oil and Gas Production
21
Multiple Zone Oil and Liquids Rich Gas FairwayJurassic Inventory
Industry
Success
Significant Horizontal Opportunity Base
Zone Bypass drilling
Opportunities (1)
Follow-up
Opportunities(1)
Rock Creek 3 18
Nordegg 8 58
(1)See Disclaimers for additional definitions of locations and opportunities. Follow up
opportunities are wells on industry standard spacing that would result from a successful
drilling opportunity.
Sinopec
Surge
New Star
LongRun
Assumptions
Drill - $900k
Complete - $400k
Tie-in - $400k
37 Regional Horizontal Wells – Oil and Gas Production
• Over 5,500 well penetrations in
the area have identified our
bypass opportunities
Month Month