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Wen entworth R Res esources: Building V Value Corporate P e Presen entation October 2018 2018 DISCLAIMER The information set out in this presentation (the Presentation) has been produced by Wentworth Resources Limited (the


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Wen entworth R Res esources: Building V Value

Corporate P e Presen entation

October 2018 2018

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DISCLAIMER

The information set out in this presentation (the “Presentation”) has been produced by Wentworth Resources Limited (the “Company” or “Wentworth”) as at 3 Oct-18, and is being made available to recipients for information purposes only. It does not constitute, nor is it intended to be an offer to sell, or an invitation to subscribe for, or purchase any securities in the Company. The information set out in this Presentation has not been independently verified and may be subject to updating, completion, revision and amendment. The Presentation does not purport to summarize all the conditions, risks and other attributes of an investment in the Company. The Presentation and its contents are strictly confidential and may not be reproduced or redistributed, in whole or in part, to any other person. By receiving this Presentation you acknowledge that you will be solely responsible for your own assessment of the market and the market position of the Company and that you will conduct your own analysis and be solely responsible for forming your own view of the potential future performance of the Company’s

  • business. The distribution of the Presentation may in certain jurisdictions be restricted by law. Persons into whose possession the Presentation may come are required by the Company to inform themselves about, and to comply with

all applicable laws and regulations in force in any jurisdiction in or from which they invest or receive or possess the Presentation and must obtain any consent, approval or permission required under the laws and regulations in force in such jurisdiction, and the Company shall not have any responsibility or liability for these obligations. No representation or warranty (express or implied) is made as to, and no reliance should be placed on, any information including projections, estimates, targets and opinions, contained herein, and no liability whatsoever is accepted as to any errors, omissions or misstatements contained herein, and, accordingly, none of Wentworth or any of its directors,

  • fficers or employees accept any responsibility for the information, statements, matters, facts or opinions stated herein, or any liability whatsoever arising directly or indirectly from the use of or any act or omission undertaken in

reliance on the Presentation. Certain of the information contained herein may include forward-looking statements relating to the business, financial performance and results of the Company and/or the industry in which it operates. Forward-looking statements concern future circumstances and results and other statements that are not historical facts, sometimes identified by the words “believes”, expects”, “predicts”, “intends”, “projects”, “plans”, “estimates”, “aims”, “foresees”, “anticipates”, “targets”, “may”, “will”, “should” and similar expressions. The forward-looking statements contained in the Presentation, including assumptions, opinions and views of the Company or cited from third party sources are solely opinions and forecasts which are subject to risks, uncertainties and other factors that may cause actual events to differ materially from any anticipated development. The forward-looking statements in this Presentation are based on certain assumptions including but not limited to expectations and assumptions concerning prevailing and future commodity prices and exchange rates, applicable royalty and tax rates, future well production rates, the performance of existing and future wells, the sufficiency of budgeted capital expenditures, the availability and cost of labor, services and equipment, adequate weather and environmental conditions and ability to successfully construct or expand facilities. None of the Company or any of its subsidiaries or any directors, officers or employees thereof provide any assurance that the assumptions underlying such forward-looking statements are free from errors, nor do any of them accept any responsibility for the future accuracy of the opinions expressed in the Presentation or the actual occurrence of the forecasted developments. Given these uncertainties, prospective investors are cautioned not to place any undue reliance on such forward-looking statements. Neither the Company nor its directors or officers assume any obligation to update any forward-looking statements or to conform these forward-looking statements to the Company’s actual results. AN INVESTMENT IN THE COMPANY INVOLVES RISK, AND SEVERAL FACTORS COULD CAUSE THE ACTUAL RESULTS, PERFORMANCE OR ACHIEVEMENTS OF THE COMPANY TO BE MATERIALLY DIFFERENT FROM ANY FUTURE RESULTS, PERFORMANCE OR ACHIEVEMENTS THAT MAY BE EXPRESSED OR IMPLIED BY STATEMENTS AND INFORMATION IN THIS PRESENTATION. SHOULD UNDERLYING ASSUMPTIONS ON WHICH THIS PRESENTATION IS BASED PROVE INCORRECT, ACTUAL RESULTS MAY VARY MATERIALLY FROM THOSE DESCRIBED IN THIS PRESENTATION, AND INVESTORS IN THE COMPANY MUST BE PREPARED TO LOSE ALL OR PART OF THEIR INVESTMENTS. THE COMPANY DOES NOT INTEND, AND DOES NOT ASSUME ANY OBLIGATION, TO UPDATE OR CORRECT THE INFORMATION INCLUDED IN THE PRESENTATION. Certain information on a non-exhaustive list and summary of assumptions and risk factors that could affect the operations or financial results of Wentworth are included in Wentworth’s corporate filings which are available on its website at www.wentworthresources.com. This document is being distributed to, and is directed only at: (i) persons in member states of the European Economic Area (“EEA”) who are “professional clients within the meaning of Part I and II and Annex II of the MIFID directive (directive 2004/39/ec) (“professional clients”); or (ii) persons in the United States who are “qualified institutional buyers” as defined in Rule 144A under the U.S. Securities Act of 1933, as amended (the “Securities Act”). Any person in the EEA who receives this document will be deemed to have represented and agreed that they are a professional client. Any such recipient will also be deemed to have represented and agreed that they have not received this document on behalf of persons in the EEA other than professional clients or persons in the United Kingdom and other member states (where equivalent legislation exists) for whom the investor has authority to make decisions on a wholly discretionary basis. The Company and its affiliates and others will rely upon the truth and accuracy of the foregoing representations and agreements. Any person in the EEA who is not a professional client should not act or rely on this document or any of its contents. With respect to the United Kingdom, the information set out in this Presentation has not been written or approved by an authorized person (as defined in the United Kingdom Financial Services and Markets Act 2000). It is considered by the Company that the communication of the Presentation will be exempt from the financial promotion restriction (as defined in Section 21(1) of the Financial Services and Markets Act 2000, as amended) pursuant to Article 69 of the Financial Services and Markets Act 2000 (Financial Promotions) Order 2005 (the “Order”), as the Company’s shares are listed for trading

  • n the Oslo Stock Exchange and the London Stock Exchange’s Alternative Investment Market. Any investment or investment activity to which this document relates is only available in the United Kingdom to such persons as are

permitted under the Order (“Relevant Persons”) and will be engaged only with such persons within the United Kingdom. Persons who are not (within the United Kingdom) Relevant Persons should not in any circumstances rely on this

  • Presentation. The contents of the Presentation are not to be construed as legal, business, investment or tax advice. Each recipient should consult with their own legal, business, investment and tax adviser as to legal business,

investment and tax advice. By receiving the Presentation you acknowledge that you will be solely responsible for your own assessment of the market and the market position of the Company and that you will conduct your own analysis and be solely responsible for forming your own view of the potential future performance of the Company’s business. The securities mentioned herein have not been, and will not be, registered under the Securities Act or under any U.S. state securities laws, and may not be offered or sold in the United States unless they are registered under the Securities Act or pursuant to an exemption from or in a transaction not subject to the registration requirements of the Securities Act. The securities have not been approved or recommended by the U.S. Securities and Exchange Commission nor any U.S. state securities commission or regulatory authority, nor have any of the foregoing authorities passed on the accuracy of this Presentation. Any representation to the contrary is a criminal offence. The information contained in this Presentation does not constitute or form part of, and should not be construed as, an offer or invitation to subscribe for or purchase the securities discussed herein in any jurisdiction. This Presentation is subject to English law, and any dispute arising in respect of this Presentation is subject to the exclusive jurisdiction of the English courts. If you have received this Presentation from anyone other than the Company, your receipt is unauthorised. Please return this document to the Company immediately.

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EAST A T AFRICAN CAN GA GAS FO FOCUS USED E E&P COM OMPANY NY

MATERIAL PRODUCTION & DEMAND

 82 mmscfd (gross), 4,700 boepd (net) average YTD, up ca.144% YoY  Demand growth up 166% since June 2017  Net 2P reserves of 111 Bcf  Low cost ($0.43/mscf) & long-life asset (2031)  Pre-eminent Tanzanian Domestic gas supplier

REGULAR REVENUE PAYMENTS

 $22.7 MM paid year to date*  Deleveraging balance sheet, debt free Jan-20

UPSIDE POTENTIAL

 Unlocking Mnazi Bay reserves  Compelling value (Production & Revenue vs. Market Cap. & NPV15 disconnect)  Onshore Rovuma Basin

SIMPLER COST-EFFECTIVE STRUCTURE

 UK transition complete  AIM re-admission ca.31 Oct-18

STRONG PLATFORM FOR GROWTH

 M&A mandate –targeting a diversified & balanced portfolio

3 * A As s of 2 O 2 Oct-18 18

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4

Corporate & Financial Overview

Market snapshot, WRL.OL (OSLO) / WRL.L (AIM)

SIGNIFICANT SHAREHOLDERS1

  • AXA Framlington

9.5%

  • Vitol

9.0%

  • Sustainable Capital

8.1%

  • Invesco

5.2%

  • R B McBean*

4.9%

  • Fidelity

4.0%

1As of 27 Sept-18

*Executive Chairman

Mnazi Bay Tembo

Market Cap1 Share price1 Revenue Shares in issue Reserves (31 May-18 RPS CPR)

US$ 58MM NOK 478 MM £0.25 NOK 2.56 H1 2017: US$ 5.1 MM H1 2018: US$ 10.79 MM 186.5m basic 197.1 mm diluted Net 2P (Mnazi Bay) 18.5 MMboe 2P NPV15 US$ 121MM

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  • Milestone Mnazi Bay gas sales revenue of $10.79 MM, 112% higher vs. H1 2017 of $5.10 MM
  • EBITDA up by 229% to $4.18 MM compared to H1 2017
  • Net loss of $6.5 million (H1 2017: $1.66 MM), including non-cash deferred tax expense of $8.68 MM
  • Cash and cash equivalents on hand of $4.04 MM (December 2017: $3.75 MM) as at June 30, 2018
  • Reduced outstanding long-term loans by $2.67 MM during the first half of 2018. Carrying value of long-

term loans $13.11 MM (Dec 2017: $15.90 MM)

  • Development (CAPEX) costs of $0.69 MM on Mnazi Bay field infrastructure (tie-in) improvements
  • G&A $5.15 MM incl. non-recurring $2.92 MM* and recurring G&A of $2.23 MM (H1 2017: $2.01 MM)

*Non-recurring expenses includes, management re-structuring costs of $0.83 MM comprising Calgary employee severance and travel expenses related to corporate re- structuring; redomicile costs of $0.34 million comprising consultancy, legal and professional charges and; Tanzanian tax assessments of $1.75 million for the years of 2013 to 2016.

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H1 2018 Financial results

Production progress - Revenue momentum

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SLIDE 6

6

Path to Value

Delivering a revitalized equity story for accretive growth

Complete Redomicile & Transition Q4 2018

Simpler more efficient transactional platform, transitional Governance period

Maintain consistent revenue & receivables

$10.79 MM net H1 2018

Sustain Production plateau

Low Opex and near term Capex. 86 mmscfd gross (ca. 4,700 boepd net WRL) Q3 2018

Tanzania Energy Short

Significant gas demand drivers with look through catalysts to WRL Core NAV

Reducing Overheads

Leaner 2019 operating model post transition exceptionals

Continue deleveraging Balance sheet

Maximising cash at hand. Debt free Q1 2020

Minimize Tembo Expex

Tembo stranded gas discovery. Focus on Commercial options in Country

Leverage In-country presence and Finance function Relationship and Local

content (fully compliant) driven

Africa-Middle East M&A focused mandate

Offset jurisdictional risk / receivables exposure & add value catalysts to portfolio

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  • Wentworth’s on-shore / near-shore Rovuma Basin assets,

located in a rapidly developing, world class gas region with substantial upside & rising demand for Gas to Power

  • Tanzanian infrastructure in place.

 490km 36” Transnational pipeline with 785 mmscfd capacity (ca.10% utilised), to Dar es Salaam.  Madimba Processing Plant near Mnazi Bay, processing gas capacity of 210 mmscfd (3 x 70mmscfd processing plants)

  • Tanzanian demand surging

 Natural Gas contributes ca.55% of power (884MW) to National grid (100MW = 150Bcf 2P reserves)  Demand forecast by end 2021 predicted at ca.300mmcfd

  • Offshore discoveries over 200 TCF:

 Tanzania: Major offshore LNG project(s) in development

  • phase. Shell block 1 and 4 and Equinor block 2, host up to 35

Tcf for 3-Train onshore Lindi project (Offshore total ca.47 Tcf)  Mozambique Area 4-ENI $7Bn Coral FLNG sanctioned in 2017 with 3.4MTPA from 2022.  Mozambique Area 1 Golfinho-Atum APC/XOM Afungi LNG, Initial two trains to produce 12.9 MPTA from Q4 2023

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Rovuma Basin

Strategically located in both Tanzania and Mozambique Mnazi Bay Tembo

Tertiary >1500m water depth >1000m water depth >500m water depth Gas Field Wentworth Licence Licence Block Transnational Pipeline Dry Well Gas Well Gas Well with Oil Shows Plugged & Abandoned LNG Processing Plant

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SLIDE 8

TANZ NZANI ANIA A

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Q3 2018 Avg. Prodn. 86.3 mmscfd (gross) NPV15 2P $121 MM (after tax)1 2P reserves of 111 Bscf, 18.5mmboe1

  • 756 sq.kmonshore / near-shore block
  • Maurel et Prom Op: 48.06% (Prodn.) & 60.075% (Expln.)

Wentworth: 31.94% (Prodn.) & 39.925% (Expln.) W.I. TPDC:20% W.I.

  • Production Sharing Agreement (PSA) with Tanzanian

Petroleum Development Corporation (TPDC) to 20312

  • Long-term GSA (to 20312) with net back price of US$3 /

mscf plus 2% p.a. inflation. Currently US$ 3.10 for Madimba (TPDC) and US$5.36 for Mtwara (Tanesco)

  • Contracted to supply 80mmscfd & 2.5 mmscfd to Mtwara

(GSA option to increase to 130mmscfd)

  • 3P gross sales gas of ca.817 Bcf1

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Tanzania: Mnazi Bay

Hand’s on pro-active JV partner- focused on unlocking NAV

1 Source: RPS Energy Canada Ltd. – Reserves Assessment as at May 31, 2018 (Life of field basis) 2 Provisions in Tanzanian Petroleum law for 10 year licence extension

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SLIDE 10

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Tanzania: Mnazi Bay Gas Demand

Compelling demand driven landscape with two main suppliers

Kinyerezi II (240MW)

Six turbines commissioned December 2017 to October

  • 2018. First combined cycle

plant in Tanzania. Max Demand from facility ca.36 mmscfd

Kinyerezi I extension (185MW)

Expected to commission power plant by Q3 2019. Expected demand of 35 mmscfd

Dangote Cement CNG – 8 mmscfd starting

Q4 2018 increasing to 15 mmscfd by Q2 2019

Goodwill ceramics

averaging 6 mmscfd

  • Tanzanian power generation ca. 1,500 MW, with ca.780 MW from Natural gas
  • Demand for Mnazi Bay gas in excess of 95 mmscf/d: K1 (29 mmscfd); K2 (36 mmscfd); U1 (20

mmscfd); Goodwill (5 mmscfd); Dangote (8 mmscfd); Mtwara (2 mmscfd)

  • Planned power plants include Mtwara (300MW), Sumanga Fungo, Kinyerezi III & Kinyerezi IV

for a combined demand of 180 mmscfd

  • No uncommitted 2P reserves in country vs. Government ambition for 5,000 MW in 2020
  • Future gas fired electricity generation capacity requires gas reserves commercialisation
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11

Tanzania: Onshore Gas Production

Mnazi bay, the pre-eminent DomGas supplier in country

12 40 48 55 54 64 76 86 96 96 87 84 81 78 70

1 1 1 1 2 2 2 2 16 44 50 83

14 10 4

100 200 300 400 500 600 700 800 900 20 40 60 80 100 120 140 160 180

2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018

MW mmscfd Average Gas Production & Permanent Generation Capacity

Songo Songo mmscfd Mnazi Bay mmscfd Kiliwani mmscfd Permanent Gas Fired Power Installed Capacity MW

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SLIDE 12

12

Tanzania: Mnazi Bay Gas Production

Average quarterly gas production (mmscfd)

Q1 2016 Q2 2016 Q3 2016 Q4 2016 Q1 2017 Q2 2017 Q3 2017 Q4 2017 Q1 2018 Q2 2018 Q3 2018 Series1 47.9 50.9 34.3 39.5 43.3 30.9 60.0 62.2 76.2 82.0 86.3

47.9 50.9 34.3 39.5 43.3 30.9 60.0 62.2 76.2 82.0 86.3

Gas Production in MMscf/day Quarterly Period

RAINY SEASON (HYDRO) 80 mmscfd Daily Committed Quotient (DCQ)

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SLIDE 13

13

Tanzania: Mnazi Bay

Arbitrary 2D line through wells

13 ZIWANI-1 MB-1 MB-2ST2 MB-3 MS-1X

0 1 2 3 4 5 KM

NW SE

0.500 1.000 1.500 2.000 2.500 3.000

Time Miocene U/C Lower Miocene U/C

Hinge zone

Base Miocene Top Eocene Top Cretaceous Intra Oligocene Mid Oligocene

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SLIDE 14

1) Securing full GSA w/TPDC

 Commercial Operations Date declaration

2) Potential increase to Reserves AND Value

 Moving inlet pressure from current 95barg to 60barg extends production plateau by ca.18 months on standalone basis and up to 7 years with slickline/choke upgrades  Increases volumes available pre gas compression capex  Immediately accretive to asset value

3) Volumes and Productivity potential

 Establishing connected volume and productivity of all intervals from the existing well stock prior capital expenditure for compression and/or additional wells

4) Development licence extension (2031+)

 Field management strategy & life of asset CAPEX plans  Ongoing discussions with PURA (Regulator)

H2 2018 Operational activities

 MS Sands and Upper MB F sands well understood  Complete pressure monitoring campaign in MB-3, MB-4 & MS-1X  Opening G-sands in MB-2 to maintain plateau  Surveillance focus on Upper MB G sands and Lower

  • MB. Accessed by MB-1 well only (Offtake

ca.12mmscfd, insufficient Production history to date)  Establishing connected volume and productivity of all intervals in the existing well stock prior to capital expenditure for compression and/or additional wells.  WRL working in-house Dynamic field model

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Tanzania: Mnazi Bay

Value catalysts and H2 2018 Operational activities

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SLIDE 15

MO MOZAMBIQU QUE

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SLIDE 16

Extension granted for one year to 16-Jun-19 Tembo-1 post well evaluation- non commercial discovery

  • 2,250km2 onshore block
  • Wentworth Op: 85% W.I. ENH (Mozambique NOC) 15% carried.
  • Jun-14: Tembo-1 gas discovery
  • Q2-18: RPS Canada CPR on prospective resources based on

legacy G&G model (Play fairway assessment)1

  • Q2-18: Secured one year appraisal licence extension from

Instituto Nacional de Petroleo (INP) to 16 Jun-19

  • Q3-18: Operational activity halted due to above ground security

situation in Cabo Delgado province

  • Q3-18: Completed extensive in-house assessment of full Tembo

appraisal licence

  • Q4-18+: Subsurface evaluation focus on remaining Rovuma

potential

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Mozambique: Tembo & Onshore Rovuma basin

Overview

1 Source: RPS Energy Canada Ltd. – Prospective Resource Assessment as at May 31, 2018 Tembo Pmean risked Volume of 262Bcf gross, with 30% Chance of probability

Tertiary Gas Field Wentworth Licence Transnational Pipeline Normal Fault Thrust Fault LNG Processing Plant

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SLIDE 17

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Mozambique: Q3-18 Tembo post mortem

Stranded sub-commercial gas discovery-see appendices

  • RPS classify Tembo as Prospective Resources (not 2C contingent resources) in May-18

Competent Persons report (CPR)

  • In-house Prospect Pmean GIIP ca.87Bcf (Q-sands)-reviewed independently to RPS CPR.

Volume reduction due:

 Detailed petrophysics: rock properties ca.10-15% porosity & ca.0.1-1mD permeabilities  Focus on Q-sand (remaining sands with only residual HC’s)  Decreased up-dip and lateral continuity / trap extent

  • Key risks around:

 Tembo-1 drilled in “best location” to test prospect  Trap effectiveness (extent of stratigraphic component)  Reservoir extent (lateral heterogeneity)  Reservoir effectiveness (quality vs compaction)  Source effectiveness (under filled / flushed Cretaceous Petroleum system)

  • Tembo-1 “twin” requires $3.5mm well cost & 8 mmscfd to breakeven at NPV15
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SLIDE 18

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Mozambique: Tembo block status & next steps

Minimize unessential operational activities

1. 2017-2018 Tembo-2 appraisal well Farmout exercise closed. Ca.80+ Companies contacted, 11 evaluated, 2 Companies expressed interest. 2. Unable to secure risk-sharing partner to date, WRL will not drill on current W.I. basis 3. Minimising on the ground activities due to above ground issues 4. RPS Competent Persons Report (CPR) completed for AIM re-admission (legacy in- house play fairway driven model superseded by in-house assessment) 5. No exit penalties on appraisal licence 6. Significant Technical knowledge and in-house Rovuma basin database 7. Ongoing Commercial discussions with ENH (National Oil Company)

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PATHS T TO O GROWTH

19

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Key points

  • Focus on core NAV (Mnazi

bay) & Corp. look-through value uplift

  • Strong Institutional register
  • Improving cash, balance

sheet & revenues

  • On the ground teams (Dar

es Salaam & Maputo)

  • Upstream / Midstream,

DomGas credibility & track record in E.Africa

  • Complete Transition for a

simpler transactional platform Strategic focus

  • Emphasis on producing (cash

flow positive) 2P-2C assets

  • Offset existing risks

(receivables & monetization)

  • Ongoing DD on M&A
  • pportunities
  • Bilateral deal focus
  • Onshore producing assets or

with line of sight to monetization & 2C-2P conversion options

20

Strategic Growth Mandate

Leveraging WRL differentiators to offset existing jurisdictional risk exposure Initial M&A focus

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SLIDE 21

WENT NTWORTH AFRICA FOUN OUNDATION

21

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SLIDE 22

22

Wentworth Africa Foundation

Inesting in local communities

  • Refurbishment
  • f

Secondary School Library: In Partnership with READ International. Renovated 1 library in Mtwara, provided text books, computers and teachers training on the use of technology

  • “Keep a Girl in School” program - Supplied Sanitary

Products to 820 girls in Secondary Schools in Mtwara and Costal Regions

  • Secondary

School Sponsorship: 6 students from Msimbati village (WRL operation area) sponsored

  • University Sponsorship Program: 3 students Majoring

in Medicine, Social Sciences and Accountancy. Students are residents from Mtwara Region

  • Vocational Training Sponsorship: Provided sponsorship

to 2 students studying in Vocational Educational and Training Authority (VETA) centre located in Mtwara

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SLIDE 23

EAST A T AFRICAN CAN GA GAS FO FOCUS USED E E&P COM OMPANY NY

MATERIAL PRODUCTION & DEMAND

 82 mmscfd (gross), 4,700 boepd (net) average YTD, up ca.144% YoY  Demand growth up 166% since June 2017  Net 2P reserves of 111 Bcf  Low cost ($0.43/mscf) & long-life asset (2031)  Pre-eminent Tanzanian Domestic gas supplier

REGULAR REVENUE PAYMENTS

 $22.7 MM paid year to date*  Deleveraging balance sheet, debt free Jan-20

UPSIDE POTENTIAL

 Unlocking Mnazi Bay reserves  Compelling value (Production & Revenue vs. Market Cap. & NPV15 disconnect)  Onshore Rovuma Basin

SIMPLER COST-EFFECTIVE STRUCTURE

 UK transition complete  AIM re-admission ca.31 Oct-18

STRONG PLATFORM FOR GROWTH

 M&A mandate –targeting a diversified & balanced portfolio

23 * A As s of 2 O 2 Oct-18 18

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SLIDE 24

APPENDICES

24

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SLIDE 25

Iain McLaren, Non-Executive Director (on re-admission to AIM)

  • Mr. McLaren has significant experience in the oil and gas

sector with deep experience as Audit committee chair. He is currently a Non-Executive Director of Jadestone Energy Inc. and until May 2018 was Senior Independent Director and Chair of the Audit Committee for Cairn Energy plc. He is currently Chairman of F&C UK High Income Trust plc as well as the director of four investment trust Companies. He is a past President of the Institute of Chartered Accountants of Scotland and was a partner of KPMG for 28 years until 2008.

Cameron Barton, Non-Executive Director

Over 35 years of finance and accounting experience within the energy industry. Former Chief Financial Officer of Sanjel Corporation, Canada’s largest independent oil and gas service company. Mr. Barton was the former President, CEO and CFO of Artumas Group Limited (now Wentworth). Previously Vice President & General Manager, and Vice President of Finance for Direct Energy Marketing Limited (owned by Centrica plc in the UK)

Tim Bushell, Deputy Chairman (on re-admission to AIM)

  • Mr. Bushell is a qualified geologist with more than 30 years'

experience in the oil and gas industry. He has worked at British Gas, Ultramar, LASMO, and Paladin Resources. Most recently Tim was Chief Executive Officer at Falkland Oil and Gas Limited and Director/co-founder of Core Energy AS. He is currently serving as a Non-Executive Director on the Board of Rockhopper Exploration PLC, Genel Energy plc and Petro Matad Limited and as a Director of Point Resources AS and Redrock Energy Limited.

John Bentley, Non-Executive Director

Over 40 years of experience in international natural resource corporations at both the executive management and board level. Specific focus in his career on upstream oil & gas in Africa. Currently non-executive chairman of Faroe Petroleum plc and non- executive director of Africa Energy Corp. Degree in Metallurgy from Brunel University.

Robert McBean, Executive Chairman

Over 40 years experience in the upstream, midstream, and downstream oil and gas industries. Former Developer and Managing Director of Qatar Fuel Additives Company (‘‘QAFAC’’), a world-scale methanol and MTBE petrochemicals facility in Qatar. Previously Developer and Managing Director of Dubai Natural Gas Company (‘‘DUGAS’’), an associated gas LPG processing facility in Dubai, and non-executive chairman of Black Marlin Energy. Co-founder of Scarboro Resources with interests and operations in Italy, Libya, Abu Dhabi, Indonesia, France, Pakistan and Canada

Neil Kelly, Non-Executive Director

A 40+ year veteran of the upstream, midstream, and downstream oil and gas industries. Prior to his retirement from ExxonMobil he was Managing Director of Ras Laffan LNG Company (RasGas) in the State

  • f Qatar. Mr. Kelly served as a Director of PT Arun LNG Company

(Indonesia) during a six year assignment, which also saw him direct production from the giant Arun gas field

25

Board of Directors

Transitional Board (post AIM re-admission)

Eskil Jersing, Chief Executive Officer

33 years diverse experience across Exploration and Production and projects in Africa, UK North Sea, Gulf of Mexico, DW Brazil, SE Asia and Australasia. Commenced in 1985 as a Field Seismologist with SSL, before roles with Enterprise Oil, Shell International, Marathon Oil, Apache Corporation and latterly Head of New Ventures and Co-Head of Mergers & Acquisitions at Petrobras Oil & Gas BV. Recently served as CEO of Sterling Energy plc, a UK based independent oil and gas exploration company focused primarily

  • n Africa and the Middle East.
  • Mr. Jersing holds a BSc in Geophysics from Cardiff

University and an MSc in Petroleum Geology from Imperial College, London.

Katherine Roe, Chief Financial Officer (on re-admission to AIM)

Previously Vice President Corporate Development & Investor Relations for the Company since 2014. Extensive oil and gas advisory and transactional experience for a range of international companies. Currently Non-executive Director of Faroe Petroleum plc and Chair of Audit Committee from June 2019. 14 years’ experience in the City of London and former Director of Investment Banking at Panmure Gordon, heading up the Natural Resources franchise. Bachelor’s degree from the University of Bristol, England

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SLIDE 26

Eskil Jersing, Chief Executive Officer

33 years diverse experience across Exploration and Production and projects in Africa, UK North Sea, Gulf of Mexico, DW Brazil, SE Asia and Australasia. Commenced in 1985 as a Field Seismologist with SSL, before roles with Enterprise Oil, Shell International, Marathon Oil, Apache Corporation and latterly Head of New Ventures and Co- Head of Mergers & Acquisitions at Petrobras Oil & Gas BV. Served as CEO of Sterling Energy plc from 2015 to 2018, a UK based independent oil and gas exploration company focused primarily on Africa and the Middle East. BSc in Geophysics from Cardiff University and an MSc in Petroleum Geology from Imperial College, London.

Katherine Roe, Chief Financial Officer

Previously Vice President Corporate Development & Investor Relations for the Company since 2014. Extensive oil and gas advisory and transactional experience for a range of international companies. Currently Non-executive Director of Faroe Petroleum plc and Chair of Audit Committee from June 2019. 14 years’ experience in the City of London and former Director of Investment Banking at Panmure Gordon, heading up the Natural Resources franchise. Bachelor’s degree from the University of Bristol, England

26

Richard Tainton, Tanzania & Mozambique Country Manager

25 years of diverse experience with engineering projects around the world including gas and power development projects. Proven experience in the development and management of integrated gas- to-power projects in Africa and Central Asia, including working with Government Agencies and Regulatory Authorities to obtain the Government consents required for project sanction and

  • implementation. Skilled negotiator and energy asset manager. MSc

Mining Engineering Degree from the University

  • f

the Witwatersrand, Johannesburg

Executive & Senior Management

Reading (UK) and Dar es Salaam (Tanzania)

Cameron Snow, Head of Subsurface & Business Development

Extensive experience across the upstream cycle from New Ventures through Exploration and Development in both conventional and unconventional assets. Prior history includes experience in onshore USA, Gulf of Mexico, Canada, South America, and Africa during roles with Apache, SDX Energy, and First Alpha Energy. BSc in Geology from NC State University, MSc in Geology from Utah State University, PhD in Geology from Stanford University, and MBA from Imperial College London

Andrew Smith, Group Financial Controller

Experience in the oil & gas sector for over 19 years and has held the positions of Group Financial Controller and Chief Financial Officer at AIM listed Tower Resources plc, Group Head of Finance at Sterling Energy plc and Group Financial Controller at Xcite Energy plc and Matra Petroleum plc. Andrew has extensive experience of operating and commercialising assets within Sub- Saharan Africa as well as Russia/FSU and the UK Continental Shelf. Andrew has also assisted a number of companies in their initial public offerings, most notably Energean Oil & gas plc. Andrew holds a BA degree in Accounting from Staffordshire University, is an Associate Chartered Accountant of the Institute of Chartered Accountants in England and Wales.

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SLIDE 27

27

Transition & Redomicile

H2 2018 Activity

Redomicile

  • UK CEO appointed, outsourced Financial

Controller, Company Secretary

  • Ongoing review of Administration and

Overheads, including re-domicile exceptionals (ca.$1m) & Advisors

  • Governance alignment with AIM standards.

Half yearly reporting

  • Relocated to serviced UK Corporate office
  • Complete exit from Calgary office
  • Addressing ongoing “Exceptionals”
  • WRL relaunch
  • Iain McLaren and Tim Bushell UK NEDs to

Board on AIM re-admission

Transition

  • Oslo Børs delisting application & decision
  • Certificate of continuance-discontinuance
  • AIM Schedule 1 re-admission
  • Investor relations & shareholder roadshows,

Retail investor meetings / Q&A sessions etc.

  • Updated CPRs for Mnazi bay and Tembo*

(Reserves & Prospective resources)

  • Financial Position Prospects & Procedures

(FPPP), Risk Matrix, new Articles, Change of Control legal opinions, Working capital model

  • etc. Shareholder Circular

Q3 Q4 Q3 Q4

*31 May-18 Tembo RPS Canada CPR based on legacy (pre Q2 2018) in-house subsurface model

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SLIDE 28

Source: RPS Energy Canada Ltd. – Mnazi Bay Field Reserves Assessment as at May 31, 2018

28

Tanzania Reserves Summary

Mnazi Bay Competent Persons Report 31 May-18

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SLIDE 29

29

Tanzanian Gas Network serving Tanesco

Mnazi Bay -the major gas provider in Tanzania

GRF Kinyerezi Songas 186MW (40mmscf/d) 8" pipeline 36" pipeline from Madimba 18" pipeline 36" pipeline 16" pipeline Songas Pipeline IPTL Tegeta SONGOSONGO Somanga Fungu 43MW (10mmscf/d) 95MW (Closed 2016) 129MW (29mmscf/d) 105MW (20mmscf/d) 240MW (36mmscf/d) 150MW (30mmscf/d) Kinyerezi 2 Kinyerezi 1 Symbion Site A Ubungo 1 Ubungo 2 16" pipeline Kinyerezi 1 Ext. X 8" Pipeline MNAZI BAY 185MW (Commissioning due Q3 2019; 35 mmscf.d) Mtwara 8" pipeline 6" pipeline 18MW (2.5mmscf/d) Symbion Site B 20MW (Closed May 2016) TWIGA Cement & Industrial Customers (20mmscf/d) TEGETA DANGOTE Cement (8mmscf/d) 12" pipeline Goodwill Tile Factory (5mmscf/d)

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30

Mozambique: Tembo post mortem

Petrophysical Interpretation- net HC pay Upper Sand B, C, & D Sands J Sand Q Sand

  • Petrophysical cutoffs adjusted upwards to reflect

porosity to permeability relationship

  • High water saturations in B, C & D Sands and J

Sands are likely a product of residual HCs

  • Clean, porous intervals generally not vertically

continuous

  • Q Sand with best properties, but only 1.5m of net

HC pay

Sw Cut-Off PHIE Cut- Off Vshale Cut- Off Average Sw Average PHIE Average Vshale Net Thickness

% % % % % % meters

Upper Sand 50 10 35 0.0 0.0 0.0 0.00 B, C & D Sands 50 10 35 41.7 14.8 28.0 2.10 J Sands 50 10 35 47.1 10.7 29.7 0.20 Q Sand 50 10 35 22.1 12.7 23.9 1.50 Formation

Sw calculation from table above represents an upside case, with higher implied water salinity than previously used (ca. 36kppm compared to 28kppm NaCl)

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SLIDE 31

31

Mozambique: Tembo-1 post mortem

Volumetrics GIIP (Prospect vs. Play)

  • Pmean volume estimate

reduced1 to ca. 87 BCF GIIP

  • Volume reduction due:

 Petrophysics based focus on Q-sand (remaining sands with residual Hydrocarbons

  • nly)

 decreased up-dip and lateral continuity / trap extent

  • Key risks remain:

 Trap effectiveness (extent of stratigraphic component)  Reservoir extent (lateral heterogeneity)  Reservoir effectiveness (quality vs compaction)  Source effectiveness (under filled / flushed K Petroleum system)

1 RPS CPR Prospective Resource Assessment as at May 31, 2018 Tembo Pmean risked Volume

  • f 262Bcf gross
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SLIDE 32

Fora (2nd Floor) Thames Tower Station Road Reading RG1 1LX United Kingdom Eskil Jersing Chief Executive Officer eskil.jersing@wentworthresources.com Katherine Roe Chief Financial Officer katherine.roe@wentworthresources.com