“Our goal is to become the largest and most profitable onshore producer in Trinidad”

March 26, 2018

LSE / TSX: TXP

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Touchstone Exploration Inc. 2

Forward-looking Information

Certain information regarding Touchstone set forth in this presentation, including assessments by the Company’s Management of the Company’s plans and futureoperations, contains forward-looking statements that involve substantial known and unknown risks and uncertainties. All statements other than statements ofhistorical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as “seek”,“anticipate”, “plan”, “continue”, “estimate”, “expect”, “may”, “will”, “project”, “predict”, “potential”, “targeting”, “intend”, “could”, “might”, “should”, “believe”and other similar expressions. Statements relating to “reserves” and “resources” are deemed to be forward-looking statements, as they involve the impliedassessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated, and can beprofitably produced in the future. Such statements represent the Company’s internal projections, estimates or beliefs concerning future growth, results ofoperations based on information currently available to the Company based on assumptions that are subject to change and are beyond the Company’s control, suchas: production rates and production decline rates, the magnitude of and ability to recover oil and gas reserves, plans for and results of drilling activity, wellabandonment costs, the ability to secure necessary personnel, equipment, production licenses and services, environmental matters, future commodity prices,changes to prevailing regulatory, royalty, tax and environmental laws and regulations, the impact of competition, future capital and other expenditures (includingthe amount, nature and sources of funding thereof), future financing sources and business prospects and opportunities, among other things. Many factors couldcause the Company’s actual results to differ materially from those expressed or implied in any forward-looking statements made by, or on behalf of, the Company.

Forward-looking statements and information involve significant risks, assumptions, uncertainties and other factors that may cause actual future results oranticipated events to differ materially from those expressed or implied in any forward-looking statements or information and, accordingly, should not be read asguarantees of future performance or results.

In particular, forward-looking statements contained in this presentation may include, but are not limited to, statements with respect to: the Company's operationalstrategy, including targeted jurisdictions and technologies used to execute its strategy; the Company’s future dividend policy; crude oil production levels; thequantity of the Company’s reserves; drilling and recompletion plans and the anticipated timing thereof; future capital expenditures, the timing thereof and themethod of funding; activities to be undertaken in various areas and timing thereof; treatment under governmental regulatory regimes and tax laws; the Company'sfuture sources of liquidity; the Company’s future compliance with its term loan covenants; and estimated amounts for the Company's decommissioning obligations.

Actual results, performance or achievement could differ materially from that expressed in, or implied by any forward-looking statements or information in thispresentation, and accordingly, investors should not place undue reliance on any such forward-looking statements or information. Further, any forward-lookingstatement or information speaks only as of the date on which such statement is made, and Touchstone undertakes no obligation to update any forward-lookingstatements or information to reflect information, events, results, circumstances or otherwise after the date on which such statement is made or to reflect theoccurrence of unanticipated events, except as required by law, including securities laws. All forward-looking statements and information contained in thispresentation are qualified by such cautionary statements. New factors emerge from time to time, and it is not possible for Management to predict all of suchfactors and to assess in advance the impact of each such factor on Touchstone's business or the extent to which any factor, or combination of factors, may causeactual results to differ materially from those contained in any forward-looking statements.

Corporate Snapshot – December 31 2016 and 2017 3

Capital Structure 2016 2017

Common shares outstanding 83,137,143 129,021,428

Market capitalization ($000’s)(1) 12,055 29,030

Cash ($000’s) 8,433 13,920

Working capital ($000’s)(2)(3) 846 6,808

Credit facility principal balance ($000’s) 15,000 15,000

Reserves (2) 2016 2017

2P Reserves (Mbbl) 15,698 18,535

2P NPV (10% Discount, After Tax) ($000’s) 130,740 156,698

2P Reserve Life Index (years) 24.0 20.2

2P F&D costs per bbl– Including FDC(4) 6.00 6.33

Operations 2016 2017

Production (bbls/d) 1,301 1,375

Wells drilled - 4

Recompletions 11 20

Capital expenditures ($000’s) 3,881 9,378

Why Invest In Touchstone? 4

Operating cash flow positive in 2017: $3.1 million ($0.03 per basic share)

Operating netback of $22.14 per barrel(1)(2)

Year over year reserve growth; 2P reserves increased by 18% in 2017(3)

Focused solely onshore Trinidad

Largest independent onshore land owner

11 producing blocks

208 drilling locations(4)

Commenced 2018 operations program forecasting 10 new wells and 24

recompletions(5)

Significant exploration opportunity on Ortoire licence

Strive to be the leader in minimizing environmental impacts

Proud supporter of charities within the communities we operate

Organic Production Growth via Drilling and Recompletions 5

One of the largest onshore independent oil producers in Trinidad with 11 producing properties

2017 average production of 1,375 bbls/d

Current field estimated production ~1,654 bbls/d (March 25, 2018 month to date)

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Touchstone Corporate ProductionJanuary 1, 2016 through March 25, 2018

Swab Oil Base Production Recompletions New Drills (2017) New Drills (2018)

Our Approach 6

Touchstone Exploration is focused on maximizing crude oil

recovery and returns through drilling, well optimization, and

enhanced oil recovery

Technology and new ways of thinking are the significant

value creators

“Our business is not dependant on finding oil…

we know the oil is there.”

Corbis, Fyzabad, ca. 1950’s

Touchstone, WD-4, 2017

2017 Highlights 7

Production averaged 1,375 bbls/d, a 6% increase from 2016 annual average production of 1,301 bbls/d.

Achieved operating netback prior to derivatives of $22.56 per barrel, an increase of 50% from the $15.08 per barrel generated in 2016.

Generated funds flow from operations of $3,110,000 ($0.03 per basic share) compared to $6,117,000 ($0.07 per basic share) realized in 2016.

Recorded a net loss of $947,000 ($0.01 per basic share) versus a net loss of $12,853,000 ($0.15 per basic share) in 2016.

Executed a $9,378,000 exploration and development program to drill four successful wells and perform 20 recompletions.

Reduced the Company’s former cash collateralized US$6,000,000 letter of credit related to its East Brighton exploration property to US$2,150,000.

Raised net proceeds of $5,329,000 from two private placements completed during the year.

Exited 2017 with cash of $13,920,000 and reduced net debt by 42% from 2016 to $8,192,000.

Q1 2017(1) Q2 2017(1) Q3 2017(1) Q4 2017(1) 2017(1)

Sales (bbls/day) 1,280 1,334 1,437 1,448 1,375

Petroleum sales ($/bbl) 64.16 61.26 59.64 69.88 63.79Royalties ($/bbl) (21.04) (16.01) (14.59) (20.16) (17.89)

Operating costs ($/bbl) (19.46) (25.36) (20.59) (27.58) (23.34)

Operating netback ($/bbl)(1)(2) 23.66 19.89 24.46 22.14 22.56

Reserves Growth(1) 8

Seven Consecutive Years of Positive Reserves Growth

0

5,000

10,000

15,000

20,000

25,000

30,000

2010 2011 2012 2013 2014 2015 2016 2017Proved Probable Possible

October 1, 2010(2) December 31, 2016(3) December 31, 2017(4)

Reserves Volumes (bbls)

Total Proved (1P) 960,700 8,977,000 10,733,000

Total Proved + Probable (2P) 1,930,600 15,698,000 18,535,000

Total Proved + Probable + Possible (3P) 3P not evaluated 20,376,000 24,456,000

Reserves Values ($)(Net Present Value, 10% Discount, After Tax)

Total Proved (1P) 8,317,000 72,668,000 83,484,000

Total Proved + Probable (2P) 17,593,000 130,740,000 156,698,000

Total Proved + Probable + Possible (3P) 3P not evaluated 169,073,000 207,027,000

Mb

bls

2017 Reserves Report 9

Record Organic Reserves Growth and ValueReserve Volumes December 31,

2016(1)

December 31, 2017(2)

Year over Year Difference

Year over YearDifference (%)

Reserves Volumes (bbls)

Total Proved (1P) 8,977,000 10,733,000 1,756,000 20

Total Proved + Probable (2P) 15,698,000 18,535,000 2,837,000 18

Total Proved + Probable + Possible (3P) 20,376,000 24,456,000 4,080,000 20

2017 Capital Efficiency(2) FutureDevelopment

Capital ($)

Drilling Locations

Finding &Development Costs(3)

Recycle Ratio(4)(5)(based on $22.56

operating netback)

Reserves Case

Total Proved (1P) 57,842,000 62 $ 7.66 2.9 X

Total Proved + Probable (2P) 85,287,000 90 $ 6.33 3.6 X

$0

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$250,000

Proved Producing Total Proved (1P) Total Proved +Probable (2P)

Total Proved +Probable + Possible

(3P)

December 31, 2017 Net Present Value (10% Discount) After Taxes Gross Reserves by Reserves Category

Proved Producing

Proved DevelopedNon-Producing

Proved Undeveloped

Total Possible

Total Probable

Principal Properties 10

Touchstone Assets - Trinidad

11 Developed and producing blocks 9 Undeveloped or exploration blocks

8,736 Net (working interest) acres 55,042 Net (working interest) acres

Trinidad Operations 11

2018 DRILLING CAMPAIGN(1)

DEVELOPMENT BLOCK PLANNED WELLS

WD-8 3

WD-4 1

COORA 1 2

COORA 2 2

FYZABAD 2

Touchstone Producing Assets

Operations Update – 2017 Drilling Results 12

Four wells drilled

Targeted new horizons within and below known pools

Program anticipated initial production of 212 bbls/d

Peak production of 584 bbls/d

Current production of 380 bbls/d (after 8+ months production)

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14-Jun-17 14-Jul-17 14-Aug-17 14-Sep-17 14-Oct-17 14-Nov-17 14-Dec-17 14-Jan-18 14-Feb-18 14-Mar-18

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New Drills (2017)

1CO 0368 1CO 0369 PS 598 PS 599 Model Est. Daily Production Cumulative Oil Model Est. Cumulative Production

Improvements in Drilling Efficiencies – 2014 vs. 2018 13

Moved to a “Turn Key” drilling program in 2017

21% decrease in days per well vs. 2014 program

39% reduction in drilling cost per foot vs. 2014 program

Have Turn Key bids in hand all ten approved 2018 wells

Further 24% reduction in days per well anticipated

Additional 10% reduction in drilling cost per foot quoted

Further efficiencies can be realized through a continuous drilling program

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Petrotrin Farm OutOperators

ISPCOperators

LOAOperators

Touchstone

Feet

per

day

Operator Category

Drilling Efficiency (2017 Onshore Trinidad)(1)Feet Drilled per Day - Spud to Rig Release

US$

per

fo

ot

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$100

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$300

$400

2014 Actual (11 Wells) 2017 Actual (4 Wells) 2018 Quoted (10 Wells)

Touchstone ExplorationAverage Drilling Cost per Foot Drilled (US$)

Drill Complete Equip

Operation Update – Recompletion Results 14

20 wells recompleted in 2017

5 wells recompleted in 2018 YTD

Recompletion program helps maintain base production

Cumulative production of 71,194 bbls

Current production of 189 bbls/d (March 25, 2018, month to date)

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Recompletion Group PerformanceNovember 2016 through March 25, 2018

Total Oil Production RCP Well Count Cumulative Oil

Exploration Upside: Ortoire Block

ORTOIRE BLOCK

35,785 net acres

80% working interest

77 wells drilled to date

4 known pools

Technical work supports low risk exploration and highlightspotential for reactivation, recompletion, and infilldevelopment of vintage fields on the block.

Four established pools on the block

• Balata West (1953)• Herrera FM• conventional oil

• Mayaro (1937/1968) • Gros Morne FM• conventional gas

• Maloney (1946) • Lower Cruse FM• conventional oil

• Lizard Springs (1928)• Lengua/Karamat FM • fractured shale oil

Surface Expression

Balata West

Maloney

Carapal Ridge 2002 – Gas/CondensateLargest onshore discovery in 50 yearsHerrera Formation500 bcf / 25 MMboe condensate

Lizard Springs

Mayaro

Navette, 1952 – OilGros Morne Formation60 MMbbls

Balata East, 1952 – OilHerrera Formation10 MMbbls

Catshill, 1952 – OilForest & Cruse Formations30 MMbbls

15

Exploration Upside: Ortoire Block

ORTOIRE BLOCK

16

A’B

B’

LOW ANGLE THRUST FAULTING

SEISMIC LINE 92_325: AMPLITUDE

B B’

Structurally complex

Seismically well defined

Structural traps

Stratigraphic traps

Turbidite deposits

Shallow and deep potential

Analogies to known pools

Untested anomalies

Moruga Time Structure

EAST BRIGHTON (OFFSHORE) BLOCK

Onshore surface location to offshore target identified

14,412 net acres

70% working interest

4 wells drilled to date

Two abandoned wells

Two wells standing capped

Two 3D Seismic Surveys

1996 – 42 square kilometers

2009 – 113 square kilometers

Exploration Upside: East Brighton Block

PBM 1CAPPED

Drilled 08/1999

Total Depth 8,740 feet

Testing:

DST #4: Nariva 30

3,988 – 4,052 feet

43 feet Net Oil Pay

328 bopd peak

+38 skin

DST#5: Nariva 20

3,480 – 3,564 feet

52 feet Net Oil Pay

259 bopd peak

-3 to +8 skin

Nearshore Prospect – Onshore Location #1

Miocene Age Duplex Feature

Offshore Anomaly – Line 170 – Fault / Fold / Bend

Basin fill

East Brighton

17

5

4

s

surface

ONSHORE LOC 1

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Lease Operators Petrotrin TouchstoneExploration

Fram Exploration Columbus Rocky Point Range Resources Trinity Exploration

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Onshore Drilling - Total Feet Drilled by Operator(1)January 1, 2017 through December 31, 2017

2017 Onshore Drilling Activity in Trinidad 18

2018 Initia

l P

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)

2017 A

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12 wells

12 wells

4 wells

10 wells

1 well2 wells

1 well 2 wells

0 wells

Peer Evaluation(1) 19

Company DateProduction

(bbls/d)Market Cap

(C$)Enterprise Value

(C$)EV per flowing barrel

(C$/bbl)

TRIN 30/06/2017 2,397 59,586,400 61,144,360 25,509

Columbus 30/06/2017 561 31,232,023 31,417,703 56,003

RRL 31/12/2017 605 32,158,849 137,321,877 226,978

TXP 31/12/2017 1,375 29,029,821 37,221,821 27,070

Environmental Impact 20

We strive to minimize the environmental impacts of ouroperations, maximize safety and ensure ethical businesspractices.

We are the first oil company in Trinidad to have a waterdisposal well. Reinjection began on March 22, 2018allowing us to reinject all of the water that we producefrom the Fyzabad and surrounding Blocks back into theground rather than releasing at surface.

In 2017 at the Health, Safety and Environment Forum hostedby Petrotrin, the Company was awarded two awards.

Touchstone placed first in Leadership Engagement in HSEManagement for Large Companies and placed second forthe Gathering Stations HSE Compliance award.

Current water disposal regulations in Trinidad

Improving our Community 21

We are proud to run a community investment program that supports initiatives and local organizations in Trinidad that make a positive impact on the lives of others.

In 2017 Touchstone worked with the following charities:Food hampers to local Trinidadians

Trini Fever - Carnival Mas Band Cerebral Palsy Foundation

Friends of Della-Marie WalcottHelena Charles Home for the aged

Therapeutic & Life Skills CentreCheshire Home for Disabled

Mothers Union Children's Home Fyzabad Community Centre

Cyril Ross Nursery Just Because Foundation

Christmas food hampers to schoolsUnited Way T & T

Victims of 2017 Hurricanes and floods

Drilling and Recompletions

Reduced drilling costs by 43% per footsince 2014

Commenced 2018 10 well drillingprogram(2)

Anticipate recompleting 24 wells(2)

Touchstone Exploration Inc. 22

Ability to deploy capital rapidly to drive production and income to support a future dividend policy

Low risk production play with upside

Currently producing ~1,654 bbls/d

On-shore acreage in place to rapidly expandproduction at low cost

Exploration upside at Ortoire block

Significant Reserves(1)

Total Proved (1P) – 10,733 Mbbl

Total Proved & Probable (2P) – 18,535 Mbbl

2P Finding and Development Costs of $6.33 per bbl

Financially Sound

Operationally cash flow positive $3.1 million 2017

Cash balance: $13.9 million

Term loan in place to support growth

Appendix - Corporate Information

Abbreviations

bbl(s) barrel(s)

Mbbl(s) thousand barrel(s)

MMbbls(s) million barrel(s)

bbls/d barrels per day

bopd barrels of oil per day

boe barrels of oil equivalent

Mboe thousand barrels of oil equivalent

MMboe million barrels of oil equivalent

boepd barrels of oil equivalent per day

Mtpa million tonnes per annum

bcf billion cubic feet

$ or C$ Canadian dollar

US$ United States dollar

TT$ Trinidad & Tobago dollar

$M thousand dollars

$MM million dollars

Brent The reference price paid for crude oil FOB North Sea

1P Proved reserves

2P Proved plus probable reserves

Ha Hectare

LOA Lease Operator Agreement

FOA Farmout Agreement

IP30 Average initial production in the first 30 days of well production

Year End: Dec 31

Engineers: GLJ Petroleum Consultants Ltd.

Auditors: Ernst & Young LLP

Legal: Norton Rose Fulbright Canada LLPNunez & Co.

Transfer Agent: Computershare Trust Company of Canada

Corporate Information

Head Office

Suite 4100, 350 7th Ave SWCalgary, AB T2P 3N9

Office: (403) 750-4400Website: www.touchstoneexploration.com Fax: (403) 266-5794info@touchstoneexploration.com

Trinidad Office

Touchstone Exploration (Trinidad) Ltd.#30 Forest Reserve Road

Fyzabad, Trinidad

Office: (868) 677-7411

Contacts

Paul R. BaayPresident and Chief Executive Officerpbaay@touchstoneexploration.com(403) 750-4488

Scott BudauChief Financial Officersbudau@touchstoneexploration.com(403) 750-4445

James ShipkaChief Operating Officerjshipka@touchstoneexploration.com(403) 750-4455

TSX: TX

P23

Endnotes and Advisories 24

ENDNOTES & ADVISORIES

Endnotes 25

Slide 3 – Corporate Snapshot(1) Market Capitalization was calculated using the TSX closing price on December 31, 2016 ($0.145/share) and December 31, 2017

($0.225/share) multiplied by our common shares outstanding.(2) 2016 2017

Current assets 17,735,000 23,107,000Less: current liabilities 16,889,000 16,299,000Working capital 846,000 6,808,000

(3) Non-GAAP measure. Refer to “Advisories: Non-GAAP Measures”.(4)

Slide 4 – Why Invest In Touchstone?(1) See endnotes from “slide 7 – Year End Highlights”.(2) Non-GAAP Measure. Refer to “Advisories: Non-GAAP Measures”.(3) Based on December 31, 2016 and December 31, 2017 GLJ Petroleum Consultants Ltd. Independent reserves evaluation. See “Slide 9 – 2017

Reserve Report”(4) Drilling locations are based on December 31, 2017 GLJ Petroleum Consultants Ltd. Independent reserves evaluation and internal estimates.(5) The Company’s Board of Directors has approved ten new wells and 24 well recompletions in 2018, subject to stable commodity prices and

adequate liquidity. See “Advisories: Forward-looking Information”.

2016 Total Proved plus

Probable Reserves

2017 Total Proved plus

Probable Reserves

Exploration capital expenditures ($000’s) 1,823 1,183

Development capital expenditures ($000’s) 842 6,960

Change in future development costs ($000’s) 1,592 12,986

Estimated finding and development costs 4,257 21,129

Net reserve additions (Mbbl) 709 3,339

Estimated finding and development costs per barrel ($/bbl) 6.00 6.33

Endnotes 26

Slide 7 – Year End Highlights (1)

(2) Non-GAAP Measure. Refer to “Advisories: Non-GAAP Measures”.

Slide 8 - Reserves Growth (1) ,

(2) Based on October 1, 2010 AJM Petroleum Consultants independent reserves evaluation. Economic values referenced from this report have been converted to Canadian Dollars from the original US$ reference at the October 1, 2010 Bank of Canada exchange rate of C$1.0215 to US$1.00.

(3) Based on December 31, 2016 GLJ Petroleum Consultants Ltd. independent reserves evaluation. Possible Reserves are based on the December 31, 2016 GLJ Petroleum Consultants Ltd. Competent Persons Report. See advisories.

(4) Based on December 31, 2017 GLJ Petroleum Consultants Ltd. independent reserves evaluation. (5) Compound Annual Growth Rate = (2017 2P Reserves / 2010 2P Reserves)(1/# of Years) - 1

CAGR = (18,535,000/1,930,600)1/7-1 = 38%

YearReserve Evaluators

Effective Date Proved Developed

Reserves (Mbbl)

Proved Undeveloped

Reserves (Mbbl)

Total Probable Reserves (Mbbl)

Total Possible Reserves (Mbbl)

2010 AJM 01-Oct-10 961 970 Not Evaluated

2011 GLJ 30-Sept-11 4,005 1,845 5,029 Not Evaluated

2012 GLJ 30-Sept-12 4,501 2,089 4,954 Not Evaluated

2013 GLJ 30-Sept-13 5,519 2,809 5,576 Not Evaluated

2014 GLJ 31-Dec-14 5,521 3,441 5,824 Not Evaluated

2015 GLJ 31-Dec-15 5,393 3,422 6,650 Not Evaluated 2016 GLJ 31-Dec-16 5,554 3,423 6,722 4,678

2017 GLJ 31-Dec-17 5,582 5,152 7,802 5,921

($000’s unless otherwise indicated)

Three months ended

March 31, 2017

Three months ended

June 30, 2017

Three months ended

Sept 30, 2017

Three months ended Dec 31,

2017

Year ended Dec 31, 2017

Petroleum revenue 7,391 7,436 7,885 9,308 32,020Royalties (2,424) (1,944) (1,929) (2,685) (8,982)Operating expenses (2,242) (3,079) (2,722) (3,673) (11,716)Operating netback 2,725 2,413 3,234 2,950 11,322

Production (bbls) 115,201 121,394 132,199 133,191 501,985Operating netback ($/bbl) 23.66 19.89 24.46 22.14 22.56

Endnotes 27

Slide 9 – 2017 Reserve Report (1) Based on December 31, 2016 GLJ Petroleum Consultants Ltd. independent reserves evaluation. Possible Reserves are based on the December

31, 2016 GLJ Petroleum Consultants Ltd. Competent Persons Report. See advisories.(2) Based on December 31, 2017 GLJ Petroleum Consultants Ltd. independent reserves evaluation. (3)

(4)

(5) Non-GAAP Measure. Refer to “Advisories: Non-GAAP Measures”.

Slide 11 – Trinidad Operations(1) The Company’s Board of Directors has approved ten new wells in 2018, subject to stable commodity pricing and adequate liquidity. See

“Advisories: Forward-looking Information”.

Slide 13 – Improvement in Drilling Efficiencies – 2014 vs. 2018(1) Source: Government of the Republic of Trinidad and Tobago, Ministry of Energy and Energy Industries; MEEI Bulletins Vol 54 No 11,

Consolidated Monthly Bulletins, January – November 2017: http://www.energy.gov.tt

Slide 18 – 2017 Onshore Drilling Activities in Trinidad(1) Source: Government of the Republic of Trinidad and Tobago, Ministry of Energy and Energy Industries; MEEI Bulletins Vol 54 No 11,

Consolidated Monthly Bulletins, January – November 2017: http://www.energy.gov.tt(2) The Company’s Board of Directors has approved ten new wells in 2018, subject to stable commodity pricing and adequate liquidity. See

“Advisories: Forward-looking Information”.

Total Proved (1P) Total Proved + Probable (2P)Operating Netbacks $22.56 $22.56FD&C ÷$7.66 ÷$6.33Recycle Ratio 2.9X 3.6X

Total

Proved Reserves

Total Proved plus Probable

Reserves

Exploration capital expenditures ($000’s) 1,183 1,183

Development capital expenditures ($000’s) 6,960 6,960

Change in future development costs ($000’s) 9,142 12,986

Estimated finding and development costs 17,285 21,129

Net reserve additions (Mbbl) 2,258 3,339

Estimated finding and development costs per barrel ($/bbl) 7.66 6.33

Endnotes 28

Slide 19 – Peer Evaluation (1) Based on the Company’s public financial information. Pounds Sterling and United States dollar figures were translated to Canadian dollars based

on the applicable closing date foreign exchange rate. Market capitalization was calculated using the entity’s closing share price multiplied by its common shares outstanding. Enterprise value was calculated as market capitalization plus net debt. Net debt was calculated as working capital (current assets minus current liabilities) less long-term debt.

Slide 22 – Touchstone Exploration Inc. (1) Based on December 31, 2017 GLJ Petroleum Consultants Ltd. independent reserves evaluation. (2) The Company’s Board of Directors has approved ten new wells and 24 well recompletions in 2018. See “Advisories: Forward-looking

Information”.

Advisories 29

Advisories

This presentation is for information purposes only and is not, and under no circumstances is to be construed as a prospectus or an advertisement for a publicoffering of such securities. No securities commission or similar authority in Canada or elsewhere or the Toronto Stock Exchange has in any way passed upon thispresentation, or the merits of any securities of Touchstone Exploration Inc. (“Touchstone” or the “Company”) and any representation to the contrary is an offence.An investment in Touchstone Exploration Inc.’s securities should be considered highly speculative due to the nature of the proposed involvement in the explorationfor and production of oil and natural gas.

This presentation and the information contained herein does not constitute an offer to sell or a solicitation of an offer to buy any securities in the United States. Thesecurities of Touchstone Exploration Inc. have not been registered under the United States Securities Act of 1933, as amended (the “U.S. Securities Act”) or anystate securities laws and may not be offered or sold within the United States or to U.S. Persons unless registered under the U.S. Securities Act and applicable statesecurities laws or an exemption from such registration is available.

Business Risks

The Company is exposed to numerous operational, technical, financial and regulatory risks and uncertainties, many of which are beyond its control and maysignificantly affect anticipated future results. The Company is exposed to risks associated with negotiating with foreign governments as well as country riskassociated with conducting international activities. Operations may be unsuccessful or delayed as a result of competition for services, supplies and equipment,mechanical and technical difficulties, ability to attract and retain qualified employees on a cost-effective basis, commodity and marketing risk. The Company issubject to significant drilling risks and uncertainties including the ability to find oil reserves on an economic basis and the potential for technical problems that couldlead to well blow-outs and environmental damage. The Company is exposed to risks relating to the inability to obtain timely regulatory approvals, surface access,access to third party gathering and processing facilities, transportation and other third party related operation risks. The Company is subject to industry conditionsincluding changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced.There are uncertainties in estimating the Company’s reserve base due to the complexities in estimated future production, costs and timing of expenses and futurecapital. The Company is subject to the risk that it will not be able to fulfill the contractual obligations required to retain its rights to explore, develop and exploit anyof its properties. The financial risks the Company is exposed to include, but are not limited to, the impact of general economic conditions in Canada and Trinidad,continued volatility in market prices for oil, the impact of significant declines in market prices for oil, the ability to access sufficient capital from internal and externalsources, changes in income tax laws or changes in tax laws, royalties and incentive programs relating to the oil and gas industry, fluctuations in interest rates, theCanadian dollar to United States dollar exchange rate and the Canadian dollar to Trinidad and Tobago dollar exchange rate. The Company is subject to localregulatory legislation, the compliance with which may require significant expenditures and non-compliance with which may result in fines, penalties or productionrestrictions or the termination of license, lease operating or farm-in rights related to the Company’s oil and gas interests in Trinidad. Certain of these risks are set outin more detail in the Company’s Annual Information Form dated March 26, 2018 which has been filed on SEDAR and can be accessed at www.sedar.com.

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Oil and Gas Reserves

The reserves information summarized in this presentation are from the Company’s December 31, 2017 independent reserve report prepared by Touchstone’sindependent reserves evaluator, GLJ Petroleum Consultants Ltd. (“GLJ”), dated March 7, 2018, as well as the Company’s prior period reports, as individually noted inthis presentation. Each of these reports were prepared in accordance with definitions, standards and procedures contained in the Canadian Oil and Gas EvaluationHandbook and National Instrument 51-101 - Standards of Disclosure for Oil and Gas Activities (“NI 51-101”). All December 31, 2017 reserves presented are based onGLJ’s forecast pricing dated January 1, 2018 and estimated costs effective December 31, 2017. Additional reserves information as required under NI 51-101 areincluded in the Company’s Annual Information Form dated March 26, 2018.

The estimated future net revenue figures contained in this presentation do not necessarily represent the fair market value of the Company's reserves. There is noassurance that the forecast price and costs assumptions contained in the Company’s reserves evaluation will be attained and variances could be material. Therecovery and reserves estimates of crude oil provided herein are estimates only, and there is no guarantee that the estimated reserves will be recovered. Actualcrude oil reserves may be greater than or less than the estimates provided herein. The reserves evaluator forecasts reserve volumes and future cash flows basedupon current and historical well performance through to the economic production limit of individual wells. Notwithstanding established precedence and contractualoptions for the continuation and renewal of the Company’s existing operating agreements, in many cases the forecast economic limit of individual wells are beyondthe current term of the relevant operating agreements. There is no certainty as to any renewal of the Company’s existing operating arrangements.

Oil and Gas Metrics

This presentation may contain certain oil and gas metrics that are commonly used in the oil and gas industry such as finding and development costs, reservesadditions, reserve replacement ratio, reserve life index and recycle ratio. These metrics do not have standardized meanings or standardized methods of calculationand therefore such measures may not be comparable to similar measures presented by other companies. Such metrics have been included herein to provide readerswith additional metrics to evaluate the Company’s performance; however, such measures are not reliable indicators of the future performance of the Company, andfuture performance may not compare to the performance in prior periods and therefore such metrics should not be unduly relied upon. The Company uses these oiland gas metrics for its own performance measurements and to provide shareholders with measures to compare the Company’s operations over time. Readers arecautioned that the information provided by these metrics, or that can be derived from the metrics presented in this presentation, should not be relied upon forinvestment purposes.

Finding and development costs are the sum of capital expenditures excluding capitalized general and administrative costs and corporate capital expendituresincurred in the period and the change in future development costs required to develop those reserves. Finding and development costs per barrel is determined bydividing current period net reserve additions to the corresponding period’s finding and development cost. The aggregate of the exploration and development costsincurred in the most recent financial year and the change during that year in estimated future development costs generally will not reflect total finding anddevelopment costs related to reserves additions for that year.

Net reserve additions are calculated as the change in reserves from the beginning to the end of the applicable period excluding period production.

Reserves replacement ratio is calculated as period net reserve additions divided by period production.

Reserve life index is calculated as total Company gross reserves divided by annual production.

Recycle ratios are calculated by dividing the current period finding and development costs per barrel to operating netbacks before hedging in the correspondingperiod (see “Non-GAAP Measures”). The recycle ratio compares netbacks from existing reserves to the cost of finding new reserves and may not accurately indicatethe investment success unless the replacement of reserves are of equivalent quality as the produced reserves.

Advisories 31

Drilling Locations

This presentation discloses drilling locations in three categories: (i) proved locations; (ii) probable locations; and (iii) unbooked locations. Proved locations andprobable locations are derived from the Company's reserves evaluation of GLJ Petroleum Consultants Ltd. effective December 31, 2017 and account for locationsthat have associated proved and/or probable reserves, as applicable. Unbooked locations are internal estimates based on the prospective acreage associated withthe Company’s assets and an assumption as to the number of wells that can be drilled based on industry practice and internal review. Unbooked locations do nothave attributed reserves. Of the approximately 208 (net) drilling locations identified herein, 62 are proved locations, 28 are probable locations and the remaining areunbooked locations. Unbooked locations have been identified by Management as an estimation of potential multi-year drilling activities based on evaluation ofapplicable geologic, seismic, engineering, production and reserves information. There is no certainty that the Company will drill all unbooked drilling locations and ifdrilled there is no certainty that such locations will result in additional oil and gas reserves or production. The locations on which the Company will drill wells willultimately depend upon the availability of capital, regulatory approvals, crude oil prices, costs, actual drilling results, additional reservoir information that can beobtained and other factors. While certain of the unbooked drilling locations have been de-risked by drilling existing wells in relative close proximity to such unbookeddrilling locations, other unbooked drilling locations are farther away from existing wells where Management has less information about the characteristics of thereservoir and therefore there is more uncertainty whether wells will be drilled in such locations and if drilled there is more uncertainty that such wells will result inadditional oil and gas reserves or production.

Non-GAAP Measures

This presentation may contain terms commonly used in the oil and natural gas industry, such as funds flow from operations per share, operating netback and netdebt. These terms do not have a standardized meaning under International Financial Reporting Standards (“IFRS”) and may not be comparable to similar measurespresented by other companies.

The Company calculates funds flow from operations per share by dividing funds flow from operations by the weighted average number of common sharesoutstanding during the applicable period.

The Company uses operating netback as a key performance indicator of field results. Operating netback is presented on a per barrel basis and is calculated bydeducting royalties and operating expenses from petroleum revenue. Operating netback is presented herein prior to realized gains or losses on commodityderivative contracts. The Company considers operating netback to be a key measure as it demonstrates Touchstone’s profitability relative to current commodityprices. This measurement assists Management and investors in evaluating operating results on a per barrel basis to analyze performance on a historical basis.

Net debt (surplus) is calculated by summing the Company’s working capital and undiscounted non-current interest bearing liabilities. Working capital is defined as

current assets less current liabilities. The Company uses this information to assess its true debt and liquidity position and to manage capital and liquidity risk.