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

2

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 $ 4,500,000 $ -

Drilling of up to six Mannville HZ wells $ - $ 9,000,000

Bigoray:

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 $ - $ 250,000

Whiskey Creek:

Reactivations, production optimization and workovers $ 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.

3

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:

• 31.94 mm shares o/s; 32.38 mm fully diluted

Skin in the Game: • Garth and Drew own 30% of Pulse having invested approximately $1 million combined in cash

Leadership Experience: Board

4

• 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.

Leadership Experience: Team

5

• 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.

Opportunity Highlights

6

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

Pulse: Immediate Growth*

7

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

Future Net Cash Flow from Operations - 1 yr

$1.85 million

$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

Capex estimate $2.1 million $8.45 million $18.8 million

Netbacks $23 at US$50/bbl

~$21 at US$50/bbl ~$25 at US$50/bbl

~$28 at US$60/bbl ~$32 at US$60/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 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

8

0

1000

2000

3000

4000

5000

6000

7000

8000

May-17 Aug-17 Nov-17 Feb-18 May-18 Aug-18 Nov-18 Feb-19 May-19

Existing Acquisitions Forecast (BOE/D)

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

9

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/ .

1st Acquisition: Bigoray Assets

10

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

Acquisition Metrics (CDN$)

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

*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.

Bigoray Assets: Phase 1

11

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

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

12

Profitable at $30 Oil

$-

$500,000

$1,000,000

$1,500,000

$2,000,000

$2,500,000

$3,000,000

$3,500,000

35 BOE/d

250 BOE/D

Annual Cash Flow

$30 $40 $70

$60 $50

Daily Prod'n

Bigoray Assets Phase 2: E.O.R.

13

• 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

Bigoray Assets Phase 2: E.O.R.

14

* 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 net revenue. There is uncertainty that any portion of these resources will be commercially viable to produce.

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

2nd Acquisition: P&SA Signed

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• 2P NPV10*: $5.524 million

• 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

48 Sections Queenstown Area: Mannville Hz Development

*Mannville SA Reserves:

2nd Acquisition: Upside

16

20+ Hz Mannville Development Drilling Inventory

• 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

• Cum Oil / well: 75k boe’s / IRR : 79%

• 3-D Seismic: Exploration inventory:

Mannville, Ellerslie, Pekisko / Shunda,

Nisku

Mannville Hz Cum Oil Type Curve

Mannville Hz Development Wells

8-5 Discovery Well IP 600 BOE/d

3rd Acquisition: LOI Signed

17

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

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3rd Acquisition: Upside

18

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

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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

20

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

Disclaimers

21

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.

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

23

Garth Johnson, CEO

garth@pulseoilcorp.com

604.306.4421

Drew Cadenhead, President

drew@pulseoilcorp.com

403.714.2336