Key Assets in Place for Immediate Growth:
Significant Behind Pipe Production, Low Cost
Drilling and Large EOR Upside.
May 2017
TSX-V: PUL
Planned Work Program
Pulse Activity
Moderate
Pace(1)
Accelerated
Pace( 1)
Mannville SA:
Purchase price
$ 1,350,000
$ 1,350,000
Drilling of up to three Mannville HZ wells
Drilling of up to six Mannville HZ wells
Bigoray:
$ 4,500,000
$
-
$
$ 9,000,000
Exercise option to buy 100% of Bigoray
$
-
$ 4,250,000
Purchase price capex for recompletions and re-start production
$ 2,750,000
$ 2,750,000
Preparation for enhanced oil recovery project
Whiskey Creek:
Reactivations, production optimization and workovers
$
-
$
250,000
$
500,000
$
500,000
Up-hole completions to bring on behind pipe production
$
700,000
$
700,000
General corporate purposes
$
310,000
$ 1,375,744
Total Use of Proceeds
$ 10,110,000
$ 20,175,744
(1) Assuming Pulse ability to fund operations.
2
Foundation for Early Success
Proven Team:
• 15-Years together; Successful combination of
financial acumen and technical experience
Market Focus:
• Prior TSX Company Market Cap: $2mm to $662
million
• Prior TSX Company Share Price: $0.06 to $11.00
Pre-Acquired
Assets:
• Quality light oil producing assets with large EOR
upside
• Signed agreements for further acquisitions /
drilling inventory
Pre-Financing
Capital Structure:
Skin in the Game:
• 31.94 mm shares o/s; 32.38 mm fully diluted
• Garth and Drew own 30% of Pulse having invested
approximately $1 million combined in cash
3
Leadership Experience: Board
• Drew Cadenhead is a professional geologist (APEGA) who developed his technical expertise, team leadership and
marketing skills through a 37-year career in the oil and gas industry. Drew got his start in Calgary, Alberta working with
Canadian Hunter, Ulster and Summit Resources. He progressed into management with PetroCorp, a state-owned oil
company before taking on a remarkable 12-year Executive role with TAG Oil Ltd. Drew’s experience allows him to stress
the vital role of risk assessment in an industry built on risk / reward. Technical acumen is the foundation of Cadenhead’s
success; that combined with charismatic communication skills make him unique in this multi-faceted industry. With
nearly 4 decades in the “oil-patch”, Drew has accumulated a wealth of technical, operational and market experience.
• Garth Johnson is a chartered professional accountant experienced at building growth and creating value for shareholders
and stakeholders. After joining TAG Oil as Chief Financial Officer in 2001 he accepted the position of Chief Executive
Officer in 2007, boosting the company’s market value of approximately $2 million to a high of over $650 million. Mr.
Johnson’s disciplined approach to business is key to anticipating and managing the risks involved in operating in the
energy industry. A strong leader and a hard worker, Garth has skillfully executed complex multimillion dollar transactions
in capital markets and in partnerships. Strategic experience, corporate governance, HS&E, media communication, legal,
commercial contracts, negotiating acquisitions, marketing, joint venture and operations in the oil and gas industry are all
part of Garth’s experience. A passion for sound leadership, accountability, teamwork, discipline, and long-term prudent
planning are pivotal to his success in driving businesses growth.
• Dr. Douglas Ellenor has 45 years of experience in the petroleum exploration and production industry, having spent 25 of
those on international assignments with the Royal/Dutch Shell Group in Australasia, Europe and North and South
America. He is a registered Professional Geoscientist in British Columbia and member of the American Association of
Petroleum Geologists and Canadian Society of Petroleum Geologists. Since 2004, Dr. Ellenor has continued working in the
oil and gas industry as an independent consultant and he currently sits on the board of Amerisur Resources plc,
a company with exploration and production activities in South America.
• Jack Doyle is a petroleum engineer with 30+ years of experience in the Canadian and international energy industry and is
a current member of APEGA. Jack has a proven ability to bring technical, cost sensitive and project management expertise
to construction, drilling, completions and workover projects. He has managed drilling and completion operations for a
number of companies including Amoco Canada, Dominion Exploration, Northstar Energy, Hawker Resources and TAG Oil
Ltd. Jack is the founder and CEO of Base Engineering Ltd., a private engineering firm specializing in drilling, completions
and workover engineering and project management for industry clients in Canada and abroad.
4
Leadership Experience: Team
• Drew Cadenhead, President and COO
• Garth Johnson, CEO and Corporate Secretary
• Aaron Doyle, CFO, is a chartered professional accountant and a petroleum engineer with over 10 years of experience as
an executive in the oil and gas industry. Aaron has focussed significantly on financial governance, budgeting, reporting,
business growth while actively ensuring safety comes first in all projects.
•
Solana Jear, Consulting Exploration Manager, is a professional geologist with more then 27 years of experience in the
Western Canadian Basin in senior roles as an employee and as a consultant with a proven track record of drilling wells,
prospecting and overseeing development of oil and gas fields with companies such as PennWest, Twin Butte, Amoco
Canada, Dome and Chinook Energy.
• Darren Lehne, Operations and HSE Manager, has worked in the upstream oil and gas industry for over 25 years and has
an extensive background in production operations both domestically and internationally. Darren has worked in the field
as a Senior Production Operator and a Production Foreman with Home Oil and Anderson Exploration. He has also
performed the role of Operations Manager for a number of junior oil & gas companies, including TAG Oil Ltd.
• Dan Brown, Controller, has over thirteen years of experience, primarily with TAG Oil, managing operations of public and
private companies and providing financial oversight expertise as well as facilitating joint venture relations, regulatory
compliance and corporate governance.
5
Opportunity Highlights
Proven Team / Quality Assets / Low-Risk
Upside
• 15-Year Team repeating successful business
plan: Acquire quality assets, provide immediate
value
growth
with
low-risk
drilling,
recompletions; leverage technical / financial
expertise and invest capital early to maximize
value
• 1st Acquisition closed, 2nd and 3rd Acquisitions
conditional on financing, anticipated closing Q2
– 2017
Combined 3 Assets:
• Production start:
220 BOE/D
• Production phase 1:
1,450 BOE/D
• Production phase 2:
6,700 BOE/D
• 81,600 net acres
6
Pulse: Immediate Growth*
Financial Details
(CDN$)
May 2017 *
Phase 1 **
(3-12 months)
Phase 2 ***
(13-24 months)
Reserves/Resource
1,260,000 BOE
1,735,000 BOE
14,433,000 BOE
P+P Reserves/Resource
2,055,000 BOE
2,693,000 BOE
15,679,000 BOE
Production
220 BOE/D
1,450 BOE/D
6,700 BOE/D
Opex costs
(opex and royalty)
$18/BOE
$17.80 / BOE
$16/ BOE
$10.8million at US$50/bbl
$61.4 million @ US$50/bbl
$14.9 million at US$60/bbl
$78.9 million @ US$60/bbl
$8.45 million
$18.8 million
~$21 at US$50/bbl
~$25 at US$50/bbl
~$28 at US$60/bbl
~$32 at US$60/bbl
Future Net Cash Flow from
Operations - 1 yr
$1.85 million
Capex estimate
$2.1 million
Netbacks
$23 at US$50/bbl
*May 2017 Starting Point is reserves independently estimated for Bigoray, Whiskey Creek and Mannville SA ** Phase 1: Internal best estimate of contingent resources using analogous
information, McDaniel October 2016 technical parameters and AER OOIP + 3 new Manville wells included at 250 BOE/D per well and uphole completions. There is uncertainty that
7 any
portion of these resources will be commercially viable to produce. *** Phase 2 also includes best estimate of contingent resource including 6 new Manville wells, acquire Bigoray 50%, Nisku
D and E 100% and implement EOR and completions. Refer to disclaimers below and notes . There is uncertainty that any portion of these resources will be commercially viable to produce.
Forward Strategy
• Out of the Gate: Low risk completions / behind pipe production/
3 Mannville Hz = 220 BOE/D to 1,450 BOE/D
• 13-24 months: 3 Mannville Hz + activations
= 2,500 BOE/D
Full-scale EOR implementation = 6,700 BOE/D
• 25-36 months: Exploration Growth; Bluesky drilling on existing assets
Future accretive acquisitions: Ongoing
Existing Acquisitions Forecast (BOE/D)
8000
7000
6000
5000
4000
3000
2000
1000
0
May-17
Aug-17
Nov-17
Feb-18
May-18
Aug-18
Nov-18
Feb-19
May-19
8
The Assets
More specific steps to production growth are defined on the
following pages as follows:
1. Bigoray: Low-hanging fruit and significant EOR opportunity
2. Mannville SA: Low-cost Mannville HZ development and exploration
drilling with a large land position
3. Whiskey Creek: Up-hole completions adding reserves, reactivations
set to increase production
For detailed NI 51-101 Disclosure related to reserve categories , fair market value, effective dates of reserve estimates
and the pricing and cost assumption of reserves estimates for Bigoray, Mannville SA and Whiskey Creek please see
Pulse’s news release dated May 3, 2017 at http://www.pulseoilcorp.com/press-releases/ .
9
1st Acquisition: Bigoray Assets





Price = $750,000 cash paid to vendor to acquire initial 50% working interest
Immediate $3 million investment: Re-start behind pipe production, low-risk re-completions
$3 million = 7 X immediate production growth (35 boe/d to 250 boe/d)
Option to acquire remaining 50% working interest for $4.25 million
Institute EOR: Potential for order of magnitude increases in boe/d, reserves, cash flow
Starting Point
Phase 1
(3-12 months)
Phase 2***
(13 to 24 months)
Reserves/ Contingent Resource (BOE)
464,000 *
695,000**
12,000,000
$ / Proven BOE (includes Capex)
$4.75
$5.35
$2.50
Production (BOE/D)
35
250
4,700
$ Per BOE/d (includes Capex)
$45,000
$15,000
$4,380
Future Net Revenue
$4,058,800*
$6,161,800**
$185,000,000
Acquisition Metrics (CDN$)
*Actual Proved Reserves independently assessed by McDaniel & Associates Consultants Ltd. (“McDaniel”) December 31, 2016.
** Proved and Probable Reserves independently assessed by McDaniel & Associates Consultants Ltd. December 31, 2016.
*** Contingent gross resource best estimate related to EOR values internally of additional working interests in Nisku pools where Pulse currently has
an interest, estimated by Pulse’s qualified reserve evaluator and estimated using McDaniel October 2016 parameters, AER OOIP, off-setting analog
recovery factors. See disclaimer for definition of Future Net Revenue. There is uncertainty that any portion of these resources will be commercially
viable to produce.
10
Bigoray Assets: Phase 1
Re-start shut-in production: $3 million
to get 250 BOE/d net
• Cardium “B” Pool
- 80 BOE/d net awaiting start-up of existing
vertical wells
• 310 API Light Oil
• Waterflood EOR
- 1-2MMBOE’s Hz line sweep
• Mannville Gas Pools
- Presently producing 400 mcf/d + NGL’s (35
BOE/d net to Pulse)
- 1,000 mcf/d 5-well re-start (80 BOE/d net)
• Nisku Oil Pools
- 55 BOE/d net awaiting start-up of existing
vertical wells
• 380 API Light Oil
11
Bigoray Assets: Phase 1
Re-start shut-in production: $3 million investment
• Operations team has >200 years field experience
• Near term production increases = $2 million net cash flow ($50/bbl WTI), to Pulse
• Total net production: ~35 BOE/D to 250 BOE/D within months net to Pulse
• Light oil development: 310 - 380 API
Annual Cash Flow
$3,500,000
Profitable at $30 Oil
$3,000,000
Daily Prod'n
$2,500,000
$2,000,000
35 BOE/d
250 BOE/D
$1,500,000
$1,000,000
$500,000
$-
$30
$40
$50
$60
$70
12
Bigoray Assets Phase 2: E.O.R.
• Nisku Pinnacle Reefs
- Isolated reservoirs, 1-2km across, 100m thick, 380 API
• Recovery Factors
- 50 offsetting analogous Nisku Pinnacle Reefs with miscible EOR averaging 80% of OOIP
• Pulse Bigoray: Interest in Nisku D and Nisku E Pinnacle Reefs
- 2 Nisku Pinnacles – no miscible EOR implemented yet
- Petroleum Initially in Place of 27 million BBLS - recovered avg. 35% to date
• 12 million BBLS gross (80% RF) more oil can potentially be recovered from
EOR
13
Bigoray Assets Phase 2: E.O.R.
Pulse Timing: 13-24 months
• Forecasted Bigoray gross EOR production:
4,200 BOE/D
• Forecasted total gross production from Bigoray:
4,700 BOE/D
• Gross Contingent resource from EOR*:
12 million BOE’s
• Total gross future net revenue NPV10*:
$185 million
* Contingent resource estimates include internal best estimates using OOIP from AER and McDaniel & Associates Consultants Ltd. reserve report
dated October 2016 by Pulse’s qualified reserve evaluator and assessed technical parameters, $50 oil price, AER estimated OOIP, offsetting pool
recovery factors; option to buy-out option of Bigoray partners in Nisku D & E. See Disclaimer pages for definitions of contingent resources and future 14
net revenue. There is uncertainty that any portion of these resources will be commercially viable to produce.
2nd Acquisition: P&SA Signed
*Mannville SA Reserves:
• 2P NPV10*: $5.524 million
48 Sections Queenstown Area:
Mannville Hz Development
• Proved and probable reserves*:
1,031,000 BOE
• Purchase Price: $1.35 million +
3 million shares of PUL at $0.12
• 100% working interest / operatorship in
7 producing wells + 3 GORR wells
• Current Prod’n: 100 boe/d (280 API)
• Immediate infill production growth
$1.5mm / Hz well = 200 – 600 boe/d
* Sproule Associates Limited as of February 28, 2017
15
2nd Acquisition: Upside
20+ Hz Mannville Development
Drilling Inventory
Mannville Hz
Development Wells
• Discovery well: IP 600 BOE/D
• Drill, Complete, Tie-in: $1.5 million / well
• 20+ Hz Development infill wells /
established Mannville pools
• IP Mannville Hz: 200 - 600 BOE/d
8-5 Discovery Well
IP 600 BOE/d
• Cum Oil / well: 75k boe’s / IRR : 79%
• 3-D Seismic: Exploration inventory:
Mannville Hz Cum Oil
Type Curve
Mannville, Ellerslie, Pekisko / Shunda,
Nisku
16
3rd Acquisition: LOI Signed
Whiskey Creek Package: Reserves
• 2P NPV10*: $4.184 million
• 2p reserves*: 329,000 BOE
• Purchase Price: $1.2 million payable with 10
million shares of PUL at $0.12
Red Earth Area: Light Oil
• Low decline, light oil (35-380 API)
• Presently 25 BOE/D
• Multiple re-activations, repairs, workovers add
150-200 BOE/d
• High Working Interest (>60%), operated
• Opportunity to consolidate operations to
significantly increase net backs
• Long-life, cash flow “machine”
* McDaniel & Associates Consultants Ltd. as of July 1, 2016
17
18
3rd Acquisition: Upside
Whiskey Creek Area: Sweet Gas
• Present Production: 60 BOE/D
• Uphole completion potential: Rock
Creek Zone, 1-3 BCF of sweet gas/well,
1-2 mmcf/d per well (150-200 BOE/d)
• 100% W.I. in 24 km pipeline from wells
to Quirk Creek Gas Plant – 90mmcf/d
capacity, severely underutilized – no
further infrastructure necessary
• CEE credits available
18
19
Why Pulse? Why Now?
• Ground floor opportunity to participate in a newly listed TSX-V
company
• 81,578 net-acres of land containing 20+ drill ready locations –
Mannville (<1500m)
• Immediate low-risk drilling and recompletions growth out of the
gate, order of magnitude EOR upside, accretive acquisition window
open for next few years
• The time is right. Commodity cycles forecast to continue the present
upswing through 2018
• Pulse comes with under-developed assets already acquired by
management as a PrivateCo during the commodity cycle low
• The team is proven, been together for years, and have plenty of “skin
in the game”
• Time to leverage public markets to repeat share price and market cap
history of the team
19
Proven Track Record
Year
Executive’s Look Back to Last PUBCO
Market Capitalization
2007 - 2008
Private placement funding completed at $0.75. Acquired
minority interest in proven reserves during financial crisis.
Lists on TSX-V.
$4 million
2009 – 2010
Drilling and new discoveries. Cash flow and profitability
grows, buys 100% interest in proven reserves and
infrastructure and expands acreage.
$80 million
2011
Raised $20 million at $2.60 per share and six months later
raised $54 million at $5.20 per share. Acquires more assets,
builds new infrastructure and increases reserve values.
$335 million
2012
Raised $44 million at $10.45 per share, moves to TSE and
increase production and profitability.
$662 million
20
Disclaimers
This document is for information purposes only and is not an offer to sell, nor a solicitation of an offer to purchase, any securities. It does not purport to contain all of the information
that a prospective investor may require and is not intended to provide any legal, tax, or investment advice.
BOE’s: Pulse Oil Corp. (“Pulse” or the “Company”) has adopted the standard of six thousand cubic feet of gas to equal one barrel of oil when converting natural gas to “BOEs.” BOEs may
be misleading, particularly if used in isolation. A BOE conversion ratio of 6Mcf: 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.
All oil and natural gas reserves and resources information, including estimated production rates and estimated future net revenue, contained in this presentation have, unless otherwise
stated, been prepared and presented in accordance with National Instrument 51-101 -Standards of Disclosure for Oil and Gas Activities ("NI 51-101") and the Canadian Oil and Gas
Evaluation ("COGE") Handbook.
Reserves Estimates
Reserves are estimated remaining quantities of oil and natural gas and related substances anticipated to be recoverable from known accumulations, as of a given date, based on analysis
of drilling, geological, geophysical and engineering data, the use of established technology, and specified economic conditions, which are generally accepted as being reasonable, and
shall be disclosed.
Reserves are classified according to the degree of certainty associated with the estimates. Proved reserves are those reserves that can be estimated with a high degree of certainty to be
recoverable. It is likely that the actual remaining quantities recovered will exceed the estimated proved reserves. Probable reserves are those additional reserves that are less certain to
be recovered than proved reserves. It is equally likely that the actual remaining quantities recovered will be greater or less than the sum of the estimated proved plus probable reserves.
Possible reserves are those additional reserves that are less certain to be recovered than probable reserves. It is unlikely that the actual remaining quantities recovered will exceed the
sum of the estimated proved plus probable plus possible reserves.
The qualitative certainty levels referred to in the definitions above are applicable to "individual reserves entities", which refers to the lowest level at which reserves calculations are
performed, and to "reported reserves", which refers to the highest level sum of individual entity estimates for which reserves estimates are presented. Reported reserves should target
the following levels of certainty under a specific set of economic conditions:
• at least a 90 percent probability that the quantities actually recovered will equal or exceed the estimated proved reserves;
• at least a 50 percent probability that the quantities actually recovered will equal or exceed the sum of the estimated proved plus probable reserves; and
• at least a 10 percent probability that the quantities actually recovered will equal or exceed the sum of the estimated proved plus probable plus possible reserves.
The reserve estimates contained herein are estimates only and there is no guarantee that the estimated reserves or resources will be recovered. The estimates of reserves for individual
properties may not reflect the same confidence level as estimates of reserves for all properties, due to the effects of aggregation.
Where discussed herein "NPV10%“ or “NPV10” represents the pre-tax net present value (net of capital expenditures) of net income discounted at 10%, with net income reflecting the
indicated oil, liquids and natural gas prices and initial production rate, less internal estimates of operating costs and royalties. It should not be assumed that the future net revenues
estimated by Pulse’s independent reserve evaluators represent the fair market value of the reserves, nor should it be assumed that Pulse’s internally estimated value of its undeveloped
land holdings or any estimates referred to herein from third parties represent the fair market value of the lands.
Resource Estimates: The oil and natural gas resource estimates in this document were prepared for Pulse and unless otherwise noted, the resource estimates in this presentation are a
“Best Case Estimate” or “Best Estimate” prepared by Pulse’s geologist, a non-independent qualified reserves evaluator in accordance with NI 51-101 and the COGE Handbook, with an
effective date of April 18, 2017.
Contingent resources are those quantities of petroleum estimated, as of a given date, to be potentially recoverable from known accumulations using established technology or technology
under development, but which are not currently considered to be commercially recoverable due to one or more contingencies. There is no certainty that it will be commercially viable to
produce any portion of the resources. The economic status of the Bigoray enhanced oil recovery (EOR) project is undetermined, as the project maturity status of the development is
pending a successful miscible flood operation. The company is working with the permit operator at Bigoray to prepare to implement the EOR project. The Company has numerous offset
analogues for the EOR project that confirm the increased recoverability of hydrocarbons in the structure. The commerciality of the EOR project depends on the company securing funding
for the project, pricing of solvent and the successful implementation of the miscible flood project resulting in increased reserves and production rates. The estimated cost is approximately
$9 million with production growth expected in 2017/2018. In addition projects at REWC and Queenstown include future drilling plans to increase current reserves in these areas and there
is no certainty that it will be commercially viable to produce any portion of the resources.
21
Disclaimers
Exploration for hydrocarbons is a speculative venture necessarily involving substantial risk. The Company's future success in exploiting and increasing its current reserve base will depend on
its ability to develop its current properties and on its ability to discover and acquire properties or prospects that are capable of commercial production. However, there is no assurance that
the Company's future exploration and development efforts will result in the discovery or development of additional commercial accumulations of oil and natural gas. In addition, even if
further hydrocarbons are discovered, the costs of extracting and delivering the hydrocarbons to market and variations in the market price may render uneconomic any discovered deposit.
Geological conditions are variable and unpredictable. Even if production is commenced from a well, the quantity of hydrocarbons produced inevitably will decline over time, and production
may be adversely affected or may have to be terminated altogether if the company encounters unforeseen geological conditions. Adverse climatic conditions at such properties may also
hinder the Company's ability to carry on exploration or production activities continuously throughout any given year.
"Best case estimate“ or “Best Estimate” is considered to be the best estimate of the quantity of the prospective resource that will actually be recovered. It is equally likely that the actual
remaining quantities recovered will be greater or less than the best estimate. If probabilistic methods are used, there should be at least a 50 percent probability (P50) that the quantities
actually recovered will equal or exceed the best estimate.
The significant positive factors that are relevant to the resource estimates are:
• Proven production in close proximity; • Proven commercial quality reservoirs in close proximity; • Current production from waterflood; • Nearby analogous on similar formations within 1
kilometer; • Current production on properties owned or to be acquired; •3D seismic coverage across permits
The significant negative factors that are relevant to the resource estimate are:
• Costs may be more to conduct EOR project at Bigoray than estimated; • Estimated EOR recoveries may not be correct; and •production rates estimated may be incorrect, materially
impacting estimated annual production and future net revenue.
“Future Net Revenue(s)” are pre-tax estimated values disclosed by Pulse, whether calculated without discount or using a discount rate, that do not represent fair market value.
Analogous Information
Certain information in this document may constitute “analogous information” as defined in NI 51-101, including, but not limited to, information relating to areas with similar geological
characteristics to the lands held by the Company. Such information is derived from a variety of publicly available information from government sources, regulatory agencies, public
databases or other industry participants (as at the date stated therein) that the Company believes are predominantly independent in nature. The Company believes this information is
relevant as it helps to define the reservoir characteristics in which the company may hold an interest. The company is unable to confirm that the analogous information was prepared by a
qualified reserves evaluator or auditor and in accordance with the COGE Handbook. Such information is not an estimate of the reserves or resources attributable to lands held or to be held
by the company and there is no certainty that the reservoir data and economics information for the lands held by the Company will be similar to the information presented therein. The
reader is cautioned that the data relied upon by the company may be in error and/or may not be analogous to the Company’s land holdings.
Forward-Looking Statements
Statements contained in this document that are not historical facts are forward-looking statements that involve various risks and uncertainty affecting the business of Pulse. Such
statements can be generally, but not always, identified by words such as “expects”, “plans”, “anticipates”, “intends”, “estimates”, “forecasts”, “schedules”, “prepares”, “potential” and
similar expressions, or that events or conditions “will”, “would”, “may”, “could” or “should” occur. All estimates and statements with respect to Pulse’s operations are forward-looking
statements under applicable securities laws and necessarily involve risks and uncertainties including, without limitation: risks associated with oil and gas exploration, development,
exploitation and production, geological risks, marketing and transportation, availability of adequate funding, volatility of commodity prices, imprecision of reserve and resource estimates,
environmental risks, competition from other producers, LLR estimates, dates of commencement of production and changes in the regulatory and taxation environment. Actual results may
vary materially from the information provided in this document, and there is no representation by Pulse Oil that the actual results realized in the future will be the same in whole or in part
as those presented herein. Other factors that could cause actual results to differ from those contained in the forward-looking statements are also set forth in filings that Pulse and its
independent evaluator have made, Pulse undertakes no obligation, except as otherwise required by law, to update these forward-looking statements in the event that management's
beliefs, estimates or opinions, or other factors change.
22
Contact
Garth Johnson, CEO
[email protected]
604.306.4421
Drew Cadenhead, President
[email protected]
403.714.2336
23