zargon.ca

Corporate PresentationSeptember 1, 2016

Forward Looking-Advisory

Forward-Looking Statements - This presentation offers our assessment of Zargon's future plans and operations as at August 31, 2016, and contains forward-looking statements. Such statements are generally identified by the use of words such as "anticipate", "continue", "estimate", "expect", "forecast", "may", "will", "project", "should", "plan", "intend", "believe" and similar expressions (including the negatives thereof). In particular, this presentation contains forward-looking information as to Zargon’s corporate strategy and business plans, Zargon’s oil exploration project inventory and development plans, Zargon’s dividend policy and the amount of future dividends, future commodity prices, Zargon’s expectation for uses of funds from financing, Zargon’s capital expenditure program and the allocation and the sources of funding thereof, Zargon’s cash flow and dividend model and the assumptions contained therein and the results there from, anticipated payout rates, 2016 and beyond production and other guidance and the assumptions contained therein, estimated tax pools, Zargon’s reserve estimates, Zargon’shedging policies, Zargon’s drilling, development and exploitation plans and projects and the results there from and Zargon’s ASP project plans 2016 and beyond, strategic alternatives review process, the source of funding for our 2016 and beyond capital program including ASP, capital expenditures, costs and the results therefrom. By their nature, forward-looking statements are subject to numerous risks and uncertainties, some of which are beyond our control, including such as those relating to results of operations and financial condition, general economic conditions, industry conditions, changes in regulatory and taxation regimes, volatility of commodity prices, escalation of operating and capital costs, currency fluctuations, the availability of services, imprecision of reserve estimates, geological, technical, drilling and processing problems, environmental risks, weather, the lack of availability of qualified personnel or management, stock market volatility, the ability to access sufficient capital from internal and external sources and competition from other industry participants for, among other things, capital, services, acquisitions of reserves, undeveloped lands and skilled personnel. Risks are described in more detail in our Annual Information Form, which is available on our website. Forward-looking statements are provided to allow investors to have a greater understanding of our business.You are cautioned that the assumptions, including, among other things, future oil and natural gas prices; future capital expenditure levels; future production levels; future exchange rates; the cost of developing and expanding our assets; our ability to obtain equipment in a timely manner to carry out development activities; our ability to market our oil and natural gas successfully to current and new customers; the impact of increasing competition; our ability to obtain financing on acceptable terms; and our ability to add production and reserves through our development and acquisition activities used in the preparation of such information, although considered reasonable at the time of preparation, may prove to be imprecise and, as such, undue reliance should not be placed on forward-looking statements. Our actual results, performance, or achievement could differ materially from those expressed in, or implied by, these forward-looking statements. We can give no assurance that any of the events anticipated will transpire or occur, or if any of them do, what benefits we will derive from them. The forward-looking information contained in this presentation is expressly qualified by this cautionary statement. Our policy for updating forward-looking statements is that Zargondisclaims, except as required by law, any intention or obligation to update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.Barrels of Oil Equivalent - Natural gas is converted to a barrel of oil equivalent (“Boe”) using six thousand cubic feet of gas to one barrel of oil. In certain circumstances, natural gas liquid volumes have been converted to a thousand cubic feet equivalent (“Mcfe”) on the basis of one barrel of natural gas liquids to six thousand cubic feet of gas. Boes and Mcfes may be misleading, particularly if used in isolation. A conversion ratio of one barrel to six thousand cubic feet of natural gas 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 from the energy equivalency of 6:1, utilizing a conversion ratio on a 6:1 basis may be misleading as an indication of value. The estimates of reserves and future net revenue for individual properties may not reflect the same confidence level as estimates of reserves and future net revenue for all properties, due to the effects of aggregation. Estimated reserve values disclosed in this presentation do not represent fair market value. Discovered Petroleum Initially-In-Place (“DPIIP”) is that quantity of petroleum that is estimated, as of a given date, to be contained in known accumulations prior to production. The recoverable portion of discovered petroleum initially in place includes production, reserves, and contingent resources; the remainder is unrecoverable.The aggregate of the exploration and development costs incurred in the most recent financial year and the change during that year in estimated future development costs generally will not reflect total finding and development costs related to reserves additions for that year.

2

Strategic Review Asset Sales

Combined Production: 1,344 barrels of oil equivalent per day (H1 2016)

92 percent oil and liquids

Combined Proven plus probable reserves: 5.81 million barrels of oil equivalent

92 percent oil and liquids

McDaniel & Associates Consultants Ltd. – Dec. 31, 2015

Killam, Alberta

3

Zargon has concluded the sale of all of its Southeast Saskatchewan assets for cash consideration of

$89.5 million cash, subject to $2.7 million of transaction and severance costs.

July 1, 2016 effective date

Closed on September 1, 2016

Zargon has entered into a definitive agreement for the sale of all of its Killam, Alberta assets for cash consideration of

$4.0 million cash, subject to normal closing adjustments.

August 1, 2016 effective date

Closing scheduled for mid-September 2016

Production & ReservesSold

Southeast Saskatch-ewan

Impact of Asset Sales on Zargon

Production: 2,749 barrels of oil equivalent per day (H1 2016)

81 percent oil and liquids

Proven plus probable reserves: 15.09 million barrels of oil equivalent

88 percent oil and liquids

Undeveloped oil exploitation locations – 12 net locations

McDaniel & Associates Consultants Ltd. – Dec. 31, 2015

Remaining Assets

4

Property Description &

Closing

Property Value

(million)

Transaction and Severance Costs

(million)

Net Proceeds

(million)

Pre Sale Bank Debt, Debentures & WC Deficiency

(million)

Available Cash

(million)

Post Sale Net Debt (Debentures & WC

Deficiency)

(million)

SE Sask (Sept. 1) $89.5 $2.7 $86.8 $122.3 $22.0 $35.5

Killam (mid-Sept.) $4.0 $0.0 $4.0 $35.5 $26.0 $31.5

The property sales have the following impact on Zargon’s (June 30, 2016) balance sheet:

Key Investment Highlights

5

Oil Exploitation Focus• Zargon is an oil-weighted company focused on the exploitation of mature oil properties• Following a 2012-14 divestment program of natural gas and high cost assets, Zargon’s

remaining high-graded operated oil reservoirs are characterized by significant oil-in-place, low recovery factors and low oil production declines

Low Decline Oil Production

• Zargon’s current blended corporate oil decline of 11% is enabled by reservoir pressure support from natural aquifers, waterfloods and tertiary floods

• The Little Bow ASP project (polymer only) has provided strong gains in H1 2016• With the return of higher oil prices, ASP production growth will return with the resumption of

(high graded) Phase 1 alkali sufactant injection and the implementation of a modified phase 2 scheme

Oil Exploitation Opportunities

• Zargon’s properties provide waterflood optimization opportunities plus exploitaion drilling opportunities that enable improved reservoir recovery factors in existing pools

• The McDaniel reserve report books 12 P+P exploitation locations with average per well parameters of 60 Mbbl oil reserves, 48 bbl/d initial rate and $0.90 MM all-in costs

Control of Properties &Key Infrastructure

• Very high working interest and operatorship across core operating areas, batteries and facilities.• Majority of batteries and facilities have been upgraded in the last five years• An actively managed abandonment and reclamation program

Little Bow ASP Project• At higher oil prices, the existing ASP infrastructure can be utilized for multiple ASP phases and

Polymer only projects seeking a 10 percent incremental oil recovery on over 80 million barrels of working interest oil-in-place.

Other Corporate Attributes • Zargon holds ~$279 million of high quality tax pools (June 30, 2016), including $144 million of non capital losses

Zargon offers a variety of attractive oil exploitation opportunities ranging from horizontal exploitation infill drills to a long term Southern Alberta tertiary recovery project

Capitalization(1) Asset Profile

Share Price (08/31/16) $0.93 Last Quarter Production (Q2 2016) Gas (MMcf/d) Liquids (bbl/d) % Liquids Total (boe/d) % of ProductionFully Diluted Shares Outstanding 31.5 Market Capitalization $29.3 North Dakota 0.00 415 100% 415 16% Net Debt(2,3) $31.5 Alberta Plains (excl. Killam) 2.68 1,256 74% 1,702 63% Option Proceeds - Little Bow - ASP 0.23 530 93% 569 21% Entity Value $60.8 LQ Daily Production 2.91 2,201 82% 2,686 100%

52-Week High $1.95 52-Week Low $0.35

Net Debt Summary(2,3)

Credit Facility Drawn $nil Convertible Debentures (Due June 2017) $57.5 Working Capital ($26.0) Net Debt $31.5

Credit Facility Summary (3)

Credit Facility Under ReviewDrawn $nil Bank Line Available Under Review

Other Company Details (Post SE Sask. & Killam Sales)

Employees 22 Office 4 Field

Headquarters Calgary, Alberta, Canada Primary Exchange Listing TSE Reserve Evaluators McDaniel

(1) All numbers in $millions except per share values.(2) Net debt calculated as bank debt, convertible debentures plus net working capital(3) Post SE Saskatchewan sale (completed) and Killam sale (est. mid-Sept. 2016)

Corporate Overview (Post SE Saskatchewan & Killam Sales)

6

zargon.ca

Conventional Properties

Alberta Plains (excluding ASP & Killam)

8

Zargon has maintained a low production decline despite restricted capital programs

• Q2 2016 production of 1,702 boe/d

– 74% liquids-weighted (16 - 32º API)

– Average WI ~72%,

– ~98% operated• Oil production decline of ~13% over the last 12

months (moderating)

– No drilling in 2015-16 due to capital allocation considerations

– Drilling programs of prior years had been successful in managing overall production decline

• Multiple exploitation and development opportunities have been identified throughout Zargon’s asset base including:

– 8 booked infill and exploitation drilling opportunities (McDaniel locations)

– Good 3D seismic coverage over key properties support an additional 8+ un-booked locations

Q2 2016Production % Liquids API OOIP

Recoveryto Date Decline

Gross UndevelopedLocations

(boe/d) (%) ( ⁰ ) (MMbbl) (%) (%) McDaniel AdditionalBellshill Lake 502 95% 27 16 32% 16% 5 1+Taber 494 98% 16-24 27 15% 19% 3 5+Little Bow(Conventional) 322 66% 21 82 25% 7% - tbd

Alberta Other 383 21% 18-32 n.a. n.a. 6% - 2+Total 1,702 74% 16-32 125+ 24% 12% 8 8+

0

200

400

600

800

1,000

1,200

1,400

1,600

1,800

2,000

2010 2011 2012 2013 2014 2015 2016

Oil

Prod

uctio

n Ra

te (b

bl/d

ay)

2016 Additions

2015 Additions

2014 Additions

2013 Additions

2012 Additions

Base Production

Zargon Alberta - Excluding Little Bow Phase 1 ASP Wells

Based on non-ASP Alberta oil wells licensed to Zargon which were on production in 2016 (data to May 31, 2016)9

Alberta Plains Properties Overview (Excluding Little Bow ASP and Killam)

Q4 2015 Contribution Decline Rate

Base 73% 11.1%

2012 7% 12.5%

2013 8% 22.1%

2014 13% 27.9%

2015 n/a n/a

Operating Summary – Q2/2016Production 1,256 bbl/d (1,702 boe/d)Royalty Rate 5.6%

Forecast Quarterly OPEX $3.05 million ($12.2 million in 2016)

Reserves: McDaniel has recognized 8 gross (8.0) P+PUD locations and there is the potential of an additional 8+ locations

McDaniel Reserves (2015 Year End)

Liquids Total PV 10%(mbbl) (mBOE) ($MM)

PDP 3,034 3,596 $ 48.7TP 3,300 4,197 $ 53.8P+PDP 4,008 4,791 $ 63.3P+P * 4,789 6,204 $ 75.9

* includes new wells, tie-ins and reactivations

Alberta Plains – Bellshill Lake

Bellshill Lake produces low-decline oil with remaining infill drilling potential • Q2 2016 production of 502 boe/d (95 % oil) − Low production declines; OPEX $12.80/boe − Historical capital programs have kept production flat since 2010 − Yearly programs have continued to make positive impacts on production

given the maturity of the field • Zargon operated, high working interest (99% on production) − 100% Working interest in all Dina production • Areally extensive Dina sand with aquifer pressure support − Rock is of sufficient quality to allow for high-impact vertical well

development − Horizontals drilled primarily as sidetracks to minimize surface disturbance − 27° API oil

Alberta Plains – Taber Mannville

• Sunburst development is seismically defined with 30 horizontal wells drilled since 2007

− 25 on production, 5 on injection • South pool is seeing stabilizing rates due to waterflood (vertical well

historical production was negligible due to higher density oil) − Estimated recovery to date ~10.1% − Ultimate forecasted 2PDP recovery ~18% − estimated OOIP of 15.5 MMbbl • North pool receives pressure maintenance from two vertical flank

injectors − Estimated recovery to date ~ 16%, higher due to lower density oil (and

vertical well recoveries) − Ultimate forecasted 2PDP recovery ~ 21.7% − estimated OOIP of 6.7 MMbbl

Taber is Zargon’s main oil producing asset outside of the ASP project, and offers low-decline production with remaining development potential

North Dakota Properties

• Long life conventional oil properties - Stable production, more than 15 MMbbl oil produced to date - Infrastructure and water disposal in place• Established waterflood and unitized production − Production optimization opportunities − Includes undeveloped land with exploration opportunities • Land Base of 18.78 gross sections (18.43 net) − 12,019 gross acres (11,795 net) , 46% Undeveloped• Total 2P Reserves NPV10 ~$26.6 MM − 4 PUD locations • Large OOIP with bypassed pay opportunities with infill drilling

potential in all of the properties - Opportunities to increase drilling density, no downspacing regulations

− Similar properties in Saskatchewan have up to 20 wells/section

Undercapitalized area with high working interest, undeveloped land and horizontal drilling opportunities

North Dakota Williston Basin geology is directly analogous to the offsetting Southeast Saskatchewan Williston Basin geology, however activity levels are substantially lower and the properties are less developed.

Q2 2016Production % Liquids API OOIP

Recoveryto Date Decline

Gross UndevelopedLocations

(boe/d) (%) ( ⁰ ) (MMbbl) (%) (%) McDaniel AdditionalHaas 208 100% 28 51 23% 3% 1 5+Mackobee Coulee 108 100% 27 17 12% 12% 3 7Truro 99 100% 27 30 4% 11% None 2Total 415 100% 27 98 xx% xx% 4 14+

12

zargon.ca

Little Bow ASP (Tertiary EOR)

Little Bow ASP Project

14

Zargon’s Little Bow ASP project is showing good oil banking and production gains.

• Phase 1 of the Little Bow ASP project was implemented in March 2014 in the heart of the Mannville “I” Pool

• Recent rates of 622 boe/d (94% oil and liquids, 21º API)

• North and Central regions of the scheme are responding very well and are anticipated to recover a full 12% incremental recovery of their 15 million bbl of oil-in-place

• Cumulative Phase 1 ASP injection at 22% of the pore volume which compares to a design target of 30% (8% remaining)

• To reduce costs, alkali and surfactant injections have been suspended. Model studies indicate that a one year suspension will not impact ultimate oil recovery

• With higher oil prices, AS injections will be resumed in the high-graded central region area, which would be followed up with the AS injections in a modified (truncated) phase 2 area.

Little Bow ASP – Plan View

Little Bow ASPEOR in a mature Southern Alberta Waterflood

Alberta Crown July 11 Announcement Extends EOR royalty program to polymer projects

At higher oil prices, the existing ASP infrastructure can be utilized for multiple ASP and Polymer only projects seeking a 10 percent incremental oil recovery on over 80 million barrels of working interest oil-in-place.

15

Zargon W.I.(%)

W.I. OIIP(mmbbl)

Phase 1 (I Pool)North and Central 100 15

South 100 8Future Potential Phases

Remaining I/P Pools 97 16U&W Unit (D8D/H9H Pools) 97 26

G Unit (B8B Pool) 95 10MM Unit (E8E Pool) 100 5

C8C / X8X Pool 100 9Total 89

16

Little Bow ASP (Tertiary EOR) Overview

Q4 2015 Contribution Decline Rate

Base 73% 12.9%

2012 6% 15.1%

2013 7% 22.6%

2014 13% 26.2%

2015 n/a n/a

Operating Summary – Q2/2016

Production 530 bbl/d (569 boe/d)Oil Prod’n Decline Rate n/a (increasing rates)

Royalty Rate 2.9%

Forecast Quarterly OPEX $1.25 million ($5 million in 2016)

Significant OPEX improvements are anticipated:

AS injections (incl. water softening) are now suspended.

Streamlined facility operations and improved pumping designs.

Based on these improvements, Q2 OPEX dropped to $1.15 million.

McDaniel Phase 1 Reserves (2015 Year End)

Liquids Total PV 10%(mbbl) (mBOE) ($MM)

PDP 1.099 1,268 $ 23.9TP 2,187 2,358 $ 32.9P+PDP 1,462 1,688 $ 30.0P+P 3,463 3,734 $ 72.6

ASP Enhanced Oil Recovery Process

Dilute concentrations of chemicals (Alkali, Surfactant and Polymer) in water are injected into an existing oil pool to “scrub” out oil that waterflooding alone will not recover.

Surfactants: Detergent; mobilizes trapped oil.

Alkali: Increases surfactant effectiveness.

Polymer (Thickener): Thickened water helps sweep oil from the reservoir.

17

1) ASP InjectionA blend of Alkali,

Surfactant & Polymer mobilizes trapped oil

2) Polymer “Push”Polymer displaces

mobilized oil to producing wells

3) Terminal WaterfloodReturn to waterflood to

complete oil displacement

OIL BANK ASP POLYMER WATER

Husky Taber Mannville “B” ASP Husky Gull Lake ASP

Analog ASP Performance (The Prize)

The Taber Mannville B and Gull Lake ASP projects are good analogs to our Little Bow ASP project.

Successful ASP projects provide stable production volumes for many years after the first three years of cost intensive AS injections are completed.

Although our Little Bow production response was slower than anticipated, we continue to foresee many years of production growth followed by many years of free cash generating stable production for our Little Bow property.

18

zargon.ca

Cash Flow Projections & Valuations

Zargon – H2 2016 Cash Flow Parameters(Pro forma SE Saskatchewan and Killam Sales)

Oil 2,170 bbl/d (includes 560 bbl/d ASP and 400 bbl/d North Dakota) Gas 2.75 mmcf/d Equiv. 2,630 boe/d; compares to H1 2016 rate of 2,686 boe/d.

Oil Prices WTI oil price to Zargon average field differential; $18.0 Cdn./bbl Gas Prices $2.05/mcf Alberta average field price Royalties 8% Alberta, 24% North Dakota (includes state and severance taxes) G&A Costs $2.4 million (6 mos.) – after reorganization and severance Interest $1.7 million (6 mos.) – full debenture cost, no interest on cash balances

Production

Costs & Capital

Other Parameters

20

Operating $9.6 million (6 mos.) – $8.6 million Alberta, $1.0 million North Dakota Abd. & Reclam. $0.3 million. US Taxes $ nil ASP Capital $1.8 million chemical costs. Conv. Capital $0.6 million maintenance capital (minor exploitation and facility costs).

Zargon – H2 2016 Cash Flows (Annualized)(Pro forma SE Saskatchewan and Killam Asset Sales)

No Drilling Case)

21

WTI Pricing

(US/bbl)FX

(US/Cdn.)Field Pricing (Cdn./bbl)

Annualized Field Cash Flow (million)

AnnualizedCorporate Cash Flow (million)

Annualized Free Cash Flow After All Capital

(million)

$35 $0.72 $30.61 $ 4.7 ($ 4.2) ($ 9.0)

$45 $0.75 $42.00 $12.8 $ 3.9 ($ 0.9)

$50 $0.765 $47.36 $16.6 $ 7.8 $ 3.0

$55 $0.78 $52.51 $20.3 $11.4 $ 6.6

$65 $0.81 $62.25 $27.2 $18.3 $13.5

2016 Alberta Plains Cash Flow

-10

0

10

20

30

30 40 50 60 70

WTI Oil Price ($US/bbl)

Cas

h F

low

($

mil

lio

ns)

Field Cash Flow

Corporate Cash

Zargon’s cash flows are exceptionally sensitive to oil prices.

Zargon’s assets provide positive field cash flow down to less than $35 US/bbl WTI price and corporate cash flow down to approximately $45 US/bbl WTI.

At higher prices, Zargon’s assets provide significant free cash flow that can be used to retire debt, reinstate/expand the Little Bow ASP floods or drill high-graded horizontal oil exploitation wells.

Valuation from H2 2016 Cash Flow (Annualized)(Pro forma SE Saskatchewan and Killam Asset Sales)

No Drilling Case)

22

WTI Pricing

(US/bbl)Field Cash Flow

(million)

4.5 Times Field Cash Flow (million)

Zargon Pro Forma Net Debt

(million)

Attributed to Zargon Shares

(million)

Calculated Zargon Value

(per share)

$35 $ 4.7 $ 21.2 $ 31.5 $ nil $ nil

$45 $12.8 $ 57.6 $ 31.5 $ 26.1 $0.86

$50 $16.6 $ 74.7 $ 31.5 $ 43.2 $1.42

$55 $20.3 $ 91.4 $ 31.5 $ 59.9 $1.96

$65 $27.2 $122.4 $ 31.5 $ 90.9 $2.98

Zargon’s long-life oil reserves provide investor’s exceptional torque (both operational and financial leverage) to future increases in oil prices.

A corporate valuation based on a 4.5 times property cash flow multiple suggests that significantly higher share prices may be realizable if/when WTI oil prices rebound to higher levels.

Zargon Share Value - 4.5 Times Property Cash Flow

0.00

1.00

2.00

3.00

4.00

30 40 50 60 70

WTI Oil Price ($US/bbl)

Shar

e P

rice

($

per

sh

are)

Reserves Summary

23

Reserves Summary(1)

(1) McDaniel & Associates Consultants Limited reserve appraisal as of December 31, 2015

Incorporates sale of South East Saskatchewan& Killam assets

Crude Oil Natural GasNatural Gas

Liquids Total % LiquidsB.Tax

PV @ 10%Mbbl MMcf Mbbl Mbbl % $MM

ProvedDeveloped Producing 6,057 4,636 65 6,895 89% 91.9Developed Non-Producing 186 2,004 5 526 36% 4.1UnDeveloped 1,442 23 1 1,447 100% 12.0

Total Proved 7,686 6,664 71 8,868 87% 107.9

Probable Additional 5,423 4,567 38 6,222 88% 67.8

Total Proved plus Probable 13,109 11,231 109 15,090 88% 175.7

0.00

20.00

40.00

60.00

80.00

100.00

120.00

140.00

2008 2011 2014 2017 2020 2023 2026 2029

WTI

Pric

e ($

US/b

bl)

McDaniel WTI Price Forecast(December 31, 2015)

Zargon Enterprise Value – August 31, 2016 Price(Incorporating the completed SE Sask. Asset Sale Only)

Zargon Valuation with Discounted Debentures (August 31 pricing)Common Shares (30.5 million @$0.93 @ August 31, 2016) $ 28.4 millionDebentures (0.575 million @$77.61 @ August 31, 2016) $ 44.6 millionSubtract Positive Working Capital (Est. @ Sept. 1, 2016) ($22.0 million)

Total Enterprise Value $51.0 million

H1 2016 Production (2,882 boe/d est. – 80% oil/liquids) $17,700 per boe/d2015 YE Reserves PDP (7.11 mmboe – 87% oil/liquids) $ 7.17 per boe2015 YE Reserves TP (9.23 mmboe – 86% oil/liquids) $ 5.53 per boe2015 YE Reserves 2PDP (9.32 mmboe – 87% oil/liquids) $ 5.47 per boe2015 YE Reserves 2P (15.74 mmboe – 86% oil/liquids) $ 3.24 per boe

24

Zargon Valuation with Debentures at Face ValueCommon Shares (30.5 million @$0.93 @ August 31, 2016) $ 28.4 millionDebentures (0.575 million @$100 face value) $ 57.5 millionSubtract Positive Working Capital (Est. @ Sept. 1, 2016) ($22.0 million)

Total Enterprise Value $63.9 million

H1 2016 Production (2,882 boe/d est. – 80% oil/liquids) $22,200 per boe/d2015 YE Reserves PDP (7.11 mmboe – 87% oil/liquids) $ 8.99 per boe2015 YE Reserves TP (9.23 mmboe – 86% oil/liquids) $ 6.92 per boe2015 YE Reserves TP (9.32 mmboe – 87% oil/liquids) $ 6.86 per boe2015 YE Reserves 2P (15.74 mmboe – 86% oil/liquids) $ 4.06 per boe

Incorporating the Southeast Saskatchewan asset sale (but not the Killam property sale announced on September 1), Zargon’s low decline oil assets continue to be valued at low levels when compared to industry peers.

Key Takeaways

Zargon’s Board and management believe that Zargon’s share price has not been reflective of the fundamental value inherent in the Company.

A broad marketing process has resulted in the sale of Zargon’s Williston Basin Saskatchewan and Killam, Alberta assets.

The strategic review continues.

Strategic Process Ongoing

Deep Discount to NAV

25

Investors buy Zargon at a large discount to the proved and probable (or proved developed producing) net asset value when evaluated at prices above current strip.

At current prices, little or no value is attributed to the very significant Little Bow ASP project upsides.

Zargon’s long-life oil reserves provide investor’s exceptional torque (operational, financial and oil exploitation leverage) to future increases in oil prices.

zargon.ca

Corporate PresentationSeptember 1, 2016