Corporate Presentation July 2019 TSXV : SOU Disclaimers BOE - - PowerPoint PPT Presentation

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Corporate Presentation July 2019 TSXV : SOU Disclaimers BOE - - PowerPoint PPT Presentation

Corporate Presentation July 2019 TSXV : SOU Disclaimers BOE Disclosure This presentation contains information that may be considered to be forward-looking information within the meaning of applicable securities laws. Such forward-looking


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TSXV : SOU

Corporate Presentation

July 2019

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TSXV: SOU www.southernenergycorp.com

Disclaimers

1

This presentation contains information that may be considered to be forward-looking information within the meaning of applicable securities laws. Such forward-looking information relates to internal projections, expectations, estimates or beliefs relating to future events or future performance . All statements contained herein, other than statements of historical fact, may be forward-looking information. Forward-looking information is often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "expect", "may", "will", "project", "predict", “propose”, "potential", "targeting", "intend", "could", "might", "should", "believe" and similar expressions. These statements are only predictions and actual events or results may differ materially. Although the recapitalized corporation believes that the expectations reflected in the forward-looking information contained in this investor presentation are reasonable, it cannot guarantee future results, levels of activity, performance or achievement since such expectations are inherently subject to significant business, economic, competitive, political and social uncertainties and contingencies. Therefore, investors should not unduly rely on the forward- looking information contained in this investor presentation as actual results may vary. With respect to forward-looking information contained in this presentation, the recapitalized corporation has made assumptions regarding, among other things: the legislative and regulatory environment in the jurisdiction where it intends to

  • perate, the impact of increasing competition, costs related to exploration, drilling, seismic and the development of oil and gas

properties will remain consistent with historical experiences, anticipated results of exploration and drilling activities and the price of oil and gas. The forward-looking information contained in this investor presentation involves known and unknown risks, uncertainties and other factors that may cause actual results or events to differ materially from those anticipated in such forward-looking information. Actual results could differ materially from those anticipated in the forward-looking information contained in this presentation as a result of the following risk factors: volatility in the market prices for oil and natural gas, unanticipated changes in any applicable royalty regime, uncertainties associated with estimating resources and reserves, geological problems, technical problems, drilling and seismic problems, liabilities and risks including environmental liabilities and risks inherent in oil and natural gas operations, fluctuations in currency and interest rates, incorrect assessments of the value of acquisitions, unanticipated results of exploration and development drilling and related activities, competition for capital, competition for acquisitions of reserves and resources, competition for undeveloped lands, competition for skilled personnel, unpredictable weather conditions, the impact of general economic conditions and political conditions, industry conditions including changes in laws and regulations including adoption of new environmental laws and regulations, the possibility of future financings and divestitures, expectations regarding future production and obtaining required approvals of regulatory authorities. The forward-looking information contained in this investor presentation speaks only as of the date of this investor presentation and is expressly qualified, in its entirety, by this cautionary statement and the recapitalized corporation disclaims any intent or obligation to update publicly any forward-looking information, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws. This information is confidential and is being presented to potential investors solely for information purposes. These materials do not and are not to be construed as an

  • ffering memorandum. An investment in securities involves a high degree of risk and potential investors are advised to seek

their own investment and legal advice.

BOE Disclosure

The term barrels of oil equivalent (“BOE”) may be misleading, particularly if used in isolation. A BOE conversion ratio of six thousand cubic feet per barrel (6Mcf/bbl) of natural gas to barrels of oil equivalence is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead.

US Disclaimer

This presentation is not an offer of the securities for sale in the United States. The securities have not been registered under the U.S. Securities Act of 1933, as amended, and may not be offered or sold in the United States absent registration or an exemption from registration. This presentation shall not constitute an offer to sell or the solicitation of an offer to buy nor shall there be any sale of the securities in any state in which such offer, solicitation or sale would be unlawful.

Non-GAAP Measures

In this presentation, certain key performance indicators and industry benchmarks such as netback are used to analyze financial and operating performance. These key performance indicators and benchmarks are key measures of profitability and provide investors with information that is commonly used by other oil and gas companies. These key performance indicators and benchmarks as presented do not have any standardized meaning prescribed by Canadian generally accepted accounting principles and therefore may not be comparable with the calculation of similar measures for other entities.

Information Regarding Disclosure on Reserves and Resources

The reserve and resource estimates contained herein are estimates only and there is no guarantee that the estimated reserves or resources will be recovered. Where discussed herein "NPV 10“ or similar expressions represents the net present value (net of capex) of net income discounted at 10%, with net income reflecting the indicated oil, liquids and natural gas prices and IP rate, less internal estimates of operating costs and royalties.

All figures in USD unless otherwise specified

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TSXV: SOU www.southernenergycorp.com

About Southern Energy

1) Market capitalization is calculated as of June 17, 2019 using a share price of CAD $0.10/share 2) Includes CAD $8.1 MM of convertible debentures and CAD $20.7 MM of reserves-based lending bank debt (Total available credit of ~ CAD $22.7 MM) 3) Enterprise value is the sum of market capitalization, convertible debentures and bank debt 4) Estimated Working Interest production as of June 2019 5) Based on reserve reports by Netherland, Sewell and Associates, Inc., estimated at December 31, 2018 using the GLJ Petroleum Consultants January 1, 2019 price forecast 2

  • Management and Board has extensive operating experience in the United States with a

track record of creating shareholder value

  • Positioned to premium commodity pricing in North America
  • Exposure to structural demand growth in U.S. Gulf Coast LNG
  • Target of 10,000 boe/d in 18 - 24 months through consolidation and development
  • Multiple recent accretive acquisitions provide stable production and cash flow base
  • Assets characterized by multi-zone, large resource in place with low recovery
  • Significant low-risk drilling inventory with optionality to both oil and gas projects

Company Profile

Capitalization CAD $

Trading Symbol (TSX-V) SOU.V Common Shares Outstanding (Basic / FD) 223.8/ 310.7 Insider Ownership (Basic / FD) 21% / 34% Market Capitalization (1) $22.4 MM Convertible Debenture and Bank Debt (2) $28.8 MM Enterprise Value (3) $51.2 MM

Metrics CAD $

Land > 50,000 acres Production (4) ~ 2,550 boe/d PDP Reserves (5) 7.7 MMboe PDP NPV10 (5) $58.9 MM Proved Reserves (5) 13.5 MMboe Proved NPV10 (5) $95.9 MM

Southern Energy Assets – Global Gas Export Perspective

Magee

Southern US Office Approved LNG Export Terminal

20+ Bcf/d export by 2025

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TSXV: SOU www.southernenergycorp.com

Strong Base Asset Optimization Additional Accretive PDP Acquisitions Low-Risk Development Drilling and Reserves Growth

  • Accretive PDP acquisitions
  • Low risk, stable cash flow
  • Management & basin

experience

  • Technical advantage
  • Operating cost savings
  • Production and lift
  • ptimizations
  • Environmentally conscious

and safety driven approach

  • Disciplined strategy
  • Low decline long life assets
  • PDP valuations
  • Synergistic with base
  • No value paid for extensive

upside

  • Under-developed assets

with low historic recovery from verticals

  • Creation of large-scale

reserve additions and drilling inventory

Timing driven by commodity environment: BUY LOW – DRILL HIGH

Access to Capital

The Business Plan

3

  • Build a high margin asset base of sufficient

scale with significant low risk drilling inventory that continues to generate free cash flow

  • Southern will be attractive to patient, value

shareholders, as well as LNG players seeking easily expandable, long-life gas assets

Focused on Value Creation:

Real Shareholder Returns

Long-Term Sustainability Exit Optionality

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Investment Thesis

4

Why Invest in Southern Energy? Experience

  • Highly experienced management team
  • Extensive operations experience in southeastern U.S. core area
  • Management and Board have significant personal investment

Financial Support

  • Strong institutional investor support
  • Cash flow resilient in low price environment
  • Focused on being a low-cost operator

Premium Commodity Pricing

  • Access to the best commodity pricing in North America
  • Exposure to operational U.S. Gulf Coast LNG
  • Unique amongst Canadian-listed energy companies

Accretive Acquisition Strategy

  • Complementary, accretive acquisitions at attractive metrics
  • Target low decline, under-developed assets
  • Team continues to execute strategy

Future Development Opportunities

  • Organic growth from low-risk, multi-zone, infill drilling inventory
  • Held by production lands offer oil and gas drilling optionality
  • Horizontal Cotton Valley re-development in northern Louisiana

TEAM HAS SPENT5 YEARS OPERATING IN THE U.S. GULF COAST AREA SOUTHERN IS 21% INSIDER OWNED (NON-DILUTIVE BASIS)

2,550 BOE/D OF LOW DECLINE PRODUCTION 95% WORKING INTEREST

HENRY HUB CURRENTLY TRADING AT$3+ / MCF CAD PREMIUM TO AECO LLS CRUDE TRADING AT$20+ / BBL CAD PREMIUM TO EDMONTON PAR RECENTLY CLOSED AN ACQUISITION OF1,000 BOE/D IN CORE AREA ACQUISITION COST OF1X PDP NPV10 USING THIRD PARTY EVALUATION

STACKED PAY WITH12 PRODUCING FORMATIONS IN CORE AREA

HORIZONTAL DRILLING POTENTIAL WITH60+ HZ LOCATIONS AT GWINVILLE

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U.S. Gulf Coast Gas Demand to Increase 20+ Bcf/d in Next 5 years

5

Positioning Southern for the future The U.S. Gas Depletion Story: 2020 and Beyond

  • Unprecedented production of 90 Bcf/d with annual decline rate of > 25%
  • System requires ~ 25 Bcf/d of new annual production to stay flat
  • Producers currently focused on fiscal responsibility and FCF – not growth

Associated Gas Supply Becoming Capital Constrained

  • Constrained to self-funded growth opposed to equity/debt funded growth
  • Low oil prices (~ $55 WTI) not expected to incent incremental oil drilling

Structural Demand From Increasing U.S. Natural Gas Exports

  • LNG exports currently 5 Bcf/d; reaching up to 10 Bcf/d by year-end 2019
  • Second wave LNG projects adding another 10+ Bcf/d of exports by 2025
  • Pipeline exports to Canada and Mexico to exceed 10 Bcf/d by 2025

Industrial Power Demand in Gulf Coast States increasing

  • Industrial power demand increase of ~ 10% in 2018 is expected to continue
  • U.S. industrial natural gas power demand now over 25 Bcf/d
  • Recent major manufacturing plants include Yokohama, Mercedes & Toyota

Southern LNG Exposure

LNG Terminal Primary Sales Point Southern Assets Existing Pipelines

A B C D E F

Increasing Market Share for Gas-Fired Power Generation

  • Continued coal and nuclear retirement (currently 30 & 20% share)
  • 20 years ago coal provided 50% of power generation market share
  • Every 1% of market share gain for gas creates 0.8+ Bcf/d of new demand

Legend Project Company Capacity Timeline Corpus Christi Cheniere 2.1 Bcf/d Active Freeport Freeport LNG 2.5 Bcf/d Active Sabine Pass Cheniere 3.7 Bcf/d Active Cameron

  • Intl. Consortium

3.5 Bcf/d Active Lake Charles Energy Transfer / Shell 1.8 Bcf/d FID 2019 Driftwood Tellurian 3.5 Bcf/d First LNG 2023 A B

C D E F

Source: Cheniere, Platts, EIA, TSI, BMO, Jefferies, Morgan Stanley

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Five Years of Operating History Has Formed Growth Strategy

6

  • Management expects to establish a dominant production base through an

acquire and exploit model

  • Target production of 10,000 boe/d over 18 - 24 months
  • Pursuing multiple follow on acquisitions while focusing on cash flow per

share growth

  • Opportunities range from 500 – 2,500 boe/d

Acquire and Exploit

  • Low decline low risk assets, with a stable production base,

complementary to Southern’s existing assets

  • Operated, high WI assets with control of infrastructure
  • Under-developed assets containing a significant inventory of

drilling locations

  • Opportunity to realize material OPEX savings through field

synergies and facility optimization Evaluation Criteria

  • Southern plans to secure drill-ready position up to 10,000 acres
  • Analog HZ wells with IP30 > 1,500 boe/d offsetting old vertical tests
  • 50,000+ acres identified by digital workflow within historic well control

Expanding Core Area - HZ Cotton Valley Focus Area

Southern Field Office Core Areas

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Environment, Social & Governance

7

Core Values at Southern – Not Buzz Words Environment

  • Actively engaged with Mississippi state regulators to help design best

practices and policies for air emissions and fresh water usage

  • Maintain a thorough asset integrity program designed to mitigate risk
  • f environmental damage

Safety

  • Strong corporate safety culture with highly experienced and trained

field personnel

  • No lost time incidents for employees or contractors since Management

began operations in the southeastern U.S. in 2013

Social

  • Southern supports employees who are active in their communities in

the form of time or financial resources and encourages ongoing community involvement

Governance

  • Southern maintains clear controls and oversight with a diverse and

independent board that is well aligned with shareholders

  • All Board Committees and Chairs are independent
  • Regular engagement with shareholders, employees and stakeholders
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Leadership Team

8

Management Team Board of Directors

Ian Atkinson, M.Sc., P. Eng. – President & CEO

Athabasca Oil, Morpheus, Renaissance and Talisman

Ian Atkinson, P. Eng., ICD.D

Former founder and EVP of Athabasca Oil Former VP Engineering of Morpheus Director of Chronos Resources

Calvin Yau, CA, CPA – VP Finance & CFO

Molopo, Waldron and Daylight

Bruce Beynon, P. Geol.

Former EVP, Exploration and Corporate Development of Baytex Energy Former President of Raging River Exploration

Chris Birchard – VP Geoscience

Athabasca Oil, Bellamont, Espoir and Devon

Michael Kohut

CFO of Hammerhead Resources, Chairman of Big Rock Brewery Director of Chronos Resources

Erin Buschert – VP Land

Crescent Point, TriStar, ARC and Talisman

Tamara MacDonald, ICD.D

Former SVP Corporate and Business Development of Crescent Point

Jim McFadyen – VP Operations

Athabasca Oil, Galleon, Fairborne and Renaissance

Andrew McCreath, CFA

Portfolio Manager at Forge First Asset Management Inc. The Market Commentator on BNN Bloomberg TV

Gary McMurren, P.Eng. – VP Engineering

Athabasca Oil, Galleon, ARC and Talisman

  • C. Neil Smith, P.Eng., MBA

Former Chief Operating Officer of Crescent Point

  • R. Steven Smith, CA, CPA

Former Director and Chief Financial Officer of Broadview Energy Director of Karve Energy

Strong technical expertise combined with a modern approach to data and workflow creates proven early mover advantage Proven track record of success and value creation through acquisitions, joint ventures and organic growth Board of Directors bring substantial technical, financial and capital markets expertise and experience Management has 5+ years operating experience in the southeastern U.S.

Experienced and successful management team with a history of creating shareholder value

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TSXV: SOU www.southernenergycorp.com

$0.01 $0.03 SOU (Pre-Acq) SOU (Pro-Forma) 1,550 2,550 SOU (Pre-Acq) SOU (Pro-Forma) $8.80 $6.00 SOU (Pre-Acq) SOU (Pro-Forma)

Corporate Cash Flow ($/share) (1)

Recent Transformative Acquisition – Executing on Strategy

1) Netback and Cash Flow based on 2019 flat pricing at $62/bbl WTI and $2.90/MMBTU HH as at April 25, 2019 9

Production (boe/d) Operating Cost ($/boe)

  • Significant accretion to both
  • perating and corporate cash flow
  • Pro-forma PDP reserves increase of > 45%
  • Mature wells with decline rate of < 5%
  • Field synergies to drive further 25%
  • perating cost reduction
  • Costless production optimization expected to increase production over 20%
  • Control of owned and operated infrastructure
  • Zero non-producing wellbore or facility liability
  • Held by production acreage increases SOU’s exposure to prolific Cotton Valley oil fairway
  • Installed safety and production monitoring enhancements

Further Acquisition Value

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Recent Transformative Acquisition – Details

1) Netback and Cash Flow based on 2019 flat pricing at $55/bbl WTI and $2.60/MMBTU HH 2) Based on reserve reports by Netherland, Sewell and Associates, Inc., estimated at December 31, 2018 using the GLJ Petroleum Consultants January 1, 2019 price forecast and 0.75 USD/CAD 10

Acquisition Assets

Southern Field Office Field Location Acquisition Field

Mississippi

1,000

boe/d

2.4

MMboe

$16.5

$MM Purchase Price

  • 9 gross producing wells in core area (97% gas)
  • Annualized 2019 Cash Flow (1): ~ $5.1 MM
  • Operated, average 93% working interest
  • Mature fields with minimum 5 years of production history at low

decline < 5% per annum

  • Limited number of wells significantly improves corporate metrics

and complements existing operations

– Zero additional G&A expense – Low standalone operating expenses of < $2/boe

  • Gas sells into Henry Hub market with low transportation offset
  • Costless well optimization initiatives identified with potential to

increase production > 20%

  • Immediate deal synergies, marketing upside and operating cost

reduction opportunities have potential to add significant incremental cashflow in 2019

  • Over 4,500 acres of held by production land
  • Historically prolific shallow structures are prospective for deeper

Cotton Valley development

Overview

  • Total purchase price of $16.5 MM before customary

purchase price adjustments

– Effective transaction date of February 1, 2019

  • Funded with a $6 MM ($8.1 MM CAD) convertible

debenture offering, available credit under expanded RBL facility and cash

Transaction Summary

Metrics (2)

Flowing Barrel ($/boepd) $16,500 PDP F&D ($/boe) $6.88 1P F&D ($/boe) $6.98 PDP Multiple 1.02 x 1P Multiple .98 x 2P Multiple .80 x

Oak Grove Greens Creek Mount Olive East Bassfield

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Mechanicsburg Gwinville Acquisition Assets

  • Liquids rich (> 30 bbl/MMcf oil & NGL)
  • Field covered by 53 mi2 3D
  • 10 - 12 infill Cotton Valley locations
  • Large gas resource; OGIP: > 300 Bcf

Growing the Core Southern Energy Asset Base

1) CMS assets covering 34,000 acres are > 97% held by production 2) June estimated production 3) Based on reserve reports by Netherland, Sewell and Associates, Inc., estimated at December 31, 2018 using the GLJ Petroleum Consultants January 1, 2019 price forecast 11

Mississippi Alabama

Black Warrior Basin Non-Operated Assets Mechanicsburg Gwinville Williamsburg

Black Warrior Basin Magee Williamsburg

Southern Field Office Field Location Acquisition Field

  • Multi-zone development upside
  • Field covered by 48 mi2 3D
  • 60+ horizontal Selma Chalk

locations (OGIP: > 600 Bcf)

  • Per share accretive on all metrics
  • Production optimizations and
  • perating cost reductions throughout
  • Cotton Valley oil potential

600

boe/d

600

boe/d

1,000

boe/d

  • Light, sweet 45° API oil
  • > 600,000 acres of highly

prospective land on mapped trend

  • OOIP: 8 - 12 MMbbl/sec
  • Field production > 10 MMbbl
  • High quality oil - 40° API
  • 4 - 10 vertical Hosston /

Cotton Valley locations

  • Infill drilling opportunities
  • Recent large oil discoveries on trend
  • 65 - 75 vertical Cotton Valley

locations

100

boe/d

50

boe/d

175

boe/d

Magee

> 50,000

Acres (> 50% HBP (1))

2,550

boe/d (2)

$44.0

$MM PDP PV10 (3)

7.7

MMboe WI PDP Reserves (3)

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Mississippi’s Largest Gas Field

Scalable Large Resource Assets - Gwinville Field Example

12

Currently Producing with low Rf Historic producing horizons with potential for improved recovery

Bcf MMbbl

Wilcox

0.7

  • Selma

128 0.2

City Bank

10 < 0.1

Tuscaloosa

1,100 11

Rodessa

110 0.6

Sligo

48 0.2

Hosston

2.0 < 0.1

Cotton Valley

Gas test

Haynesville

Significant Liquids Upside Potential

  • 1+ Tcf OGIP in Selma Chalk, current recovery ~ 15%
  • Multi-zone production of 1.5 Tcf, 12 MMbbl, current

decline < 8%, with additional upside potential

  • At least 3 stacked horizons to be accessed with

horizontal drilling and modern completion designs, following on the early success of previous operator

  • Significant potential below the Tuscaloosa from zones

which have produced more than 750 Bcf and 80 MMbbl from immediately offsetting fields

  • Owned and operated infrastructure with expandable

capacity

Significant Underdeveloped Gas Resource H2 2019 Planned HZ Location

  • Field is covered by proprietary 3D seismic
  • Delineated from vintage vertical wells
  • EOG and Penn Virginia drilled 25 Gen-1

HZ’s between 2005 – 2010

  • Targeted Upper Selma, Lower Selma and

the City Bank across the entire field

  • SOU’s first location will be a direct offset

to an under-stimulated Gen-1 HZ

H2 2019 HZ

3 - 4+ TCF OGIP Low recovery, large location inventory Multi-Stacked HZ Potential Well IRR’s > 50% at $3/MMBTU Henry Hub

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Low Risk, Multi-Zone Gas Resource Development

13

Gwinville 128 Bcf CTD Baxterville 135 Bcf CTD

  • The Baxterville field has undergone a successful HZ conversion and is a direct analog to the Gwinville Field

‒ Recent horizontal wells in the middle of the pool producing > 7 MMcf/d IP30 ‒ Southern plans to increase the number of stages and proppant loading to optimize completion design

  • Both fields have nearly identical cumulative production, aerial size, pay thickness and reservoir quality
  • Gwinville Field has two porosity units in the Selma Chalk that will be developed

Similar Pool Characteristics Baxterville Selma Chalk Production

1,000 10,000 100,000 2014 2015 2016 2016 2018 2019

Gross CD Gas Rate (Mcf/d)

3 HZ wells more than doubled field production

14 stage, 1200 lb/ft HZ IP30 30 7.3 3 MM MMcf/d /d Vertical well tested 570 Mcf/d 13X HZ Mu Multipl plier er Lower Selma vertical well IP: 770 Mcf/d Upper Selma vertical well IP: 1.0 MMcf/d

Baxterville Gwinville

City Bank vertical well IP: 800 Mcf/d Future Multi-well Pads

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Defined plan to build Cotton Valley oil assets in a regional fairway using Southern’s ‘early mover’ advantage

Significant Oil Potential in Regional Cotton Valley Fairway

  • Trend is less developed with drilling as the

play moves east from Texas

  • Similar ‘macro’ trapping elements exist

throughout the trend

  • Several recent and significant light oil

discoveries along this trend

  • Proven vertical production in Mississippi

with low-cost completions

  • Shallower depths in Louisiana and

Arkansas allow for horizontal development

  • Over-pressured plays in Louisiana enhance

horizontal drilling results Low Risk, Prolific Light Oil Trend

14

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Proven Oil Potential within Core Asset Base

15

CNVL Penetrations CNVL Production Shallow Production

Central Mississippi Cotton Valley (CNVL) Focus Area

Historic exploration:

  • Majority of wells drilled before 1985
  • Pre-2000 drill times up to 12 months

Recently:

  • Successful oil development below historic

shallow production

  • Drilling time down to < 30 days

SOU Acquisition:

  • Access to HBP land to test two of the largest

productive structures west of Williamsburg

  • Existing infrastructure for oil and gas

processing and takeaway

Cotton Valley Oil Success

5 10 15 20 500 1,000 1,500 2,000 2,500 3,000 3,500 4,000 2012 2013 2014 2015 2016 2017 2018 2019 Gross CD Rate (bbl/d) Oil - CD Well Count

Recent Development (1)

1) Collins NE and Glade Crossing fields only

Reduced drilling costs allow for deeper CNVL drilling opportunities Williamsburg

  • 2 CNVL penetrations
  • 1 producer – EUR 2.3 Bcf, 43 Mbbl
  • Under-stimulated; Flowing up 4.5”

Gwinville

  • 2 CNVL penetrations
  • 1980 perf, 8 ft flare

Collins / Seminary

  • Most recent CNVL drilling
  • > 10 MMbbl, 13 Bcf;
  • 1,400 bbl/d, 2.5 MMcf/d
  • Producing from the same interval

as Williamsburg

Glade Crossing

  • 8 recent CNVL producers
  • > 1 MMbbl, 2.7 Bcf since 2015
  • 1,300 bbl/d
  • Implementing waterflood scheme
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TSXV: SOU www.southernenergycorp.com Analog Well SOU Key Well

Multiple HZ tested IP’s > 1,500 boepd

200 bopd 5 bopd

Low Risk Cotton Valley Horizontal Oil Play

16

Fully Delineated Prospect

High Quality Vertical Conversion Play:

  • Immediate focus area contains more than 200

historic vertical wells

  • All historic wells penetrate and define the

target zone

  • Interpretation supported by 2D seismic
  • SOU plans low risk HZ infill drilling to re-

develop play to full potential

  • Estimate > 40 MMbbl OOIP and > 160 Bcf OGIP
  • Early mover on initial ~ 10,000 acres
  • 50,000+ prospective acres on trend
  • Southern has identified a low risk horizontal infill oil play in a member of the Cotton Valley Formation
  • Competitor has recently drilled several horizontal wells in the same zone, similar structure with excellent results

Cotton Valley Focus Area

More prolific historic vertical well production than analog play:

  • Seven wells with test rates from

25 – 200 bopd

  • Cumulative oil production of ~

400 Mbbl oil, 3.3 Bcf gas

  • High quality oil: 53 – 64⁰ API
  • Moderately over-pressured at

> 0.5 psi/ft

  • Recovery factor < 1%

~ 9,000 ft TVD

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The Southern Energy Difference

17

Key Attributes

U.S. Unconventional E&P

Asset Character Corporate Decline Rates

Low (~10%) High (>40%)

Large Inventory of Undeveloped Resources

Yes Yes

Capital Intensity

Low High

Operating Efficiency Harvest Mature Production Efficiently

Yes No

Unit Operating Costs

Low Low

Only during flush production

G&A Overhead Costs

Low High

Shale development model requires more human capital

Barriers to Entry Driven By

Scale & Capital Complexity & Capital

Financial Management Delevering

Yes No

Significant reinvestment required to offset high declines

Sustaining Capital

Low High

Acquisition Metrics

Low (~1x PDP) High

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Summary – Predictable Growth Strategy

18

  • Target of 10,000 boe/d in 18 - 24 months
  • Grow from low risk drilling inventory in under-developed, low-decline assets

Consolidating and developing high quality low risk conventional assets in under-exploited basins in U.S. Gulf Coast states

  • Track record of substantial organic growth in previous companies
  • More than 5 years of operating experience in these basins

Capitalizing on management’s technical experience in the area to enhance asset values

  • Oil development has access to Louisiana Light Sweet Crude pricing > WTI
  • Consolidate large natural gas assets connected to Henry Hub pricing

Focusing on accretive PDP acquisition of conventional assets with exposure to premium commodity pricing Positioning Southern to return significant value to shareholders in a responsible, respectful and environmentally efficient manner U.S. Gulf Coast focused energy company with a goal to create shareholder value by:

Southern Energy

Focus on efficient, sustainable, per share growth

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Appendix

19

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U.S. Gulf Coast LNG Market

Source: Cheniere, Platts, EIA 20

Asia (JKM) $7.00 – 10.00 / MMbtu Europe (NBP & TTF) $6.00 – 8.00 / MMbtu U.S. Gulf Coast LNG cost $2.50 – 4.00 / MMbtu Americas $10.00 / MMbtu China & India expected to double LNG imports by 2025

LNG Imports 2015 (Bcf/d) 2018 (Bcf/d) Japan 11.1 11.0 China 2.4 6.9 South Korea 4.2 5.5 Europe 4.5 5.3 India 1.9 2.5 Taiwan 1.7 2.0

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Access to Premium Commodity Pricing

21

$0.00 $1.00 $2.00 $3.00 $4.00 $5.00 $6.00 $7.00 Jan-17 Jul-17 Jan-18 Jul-18 Jan-19

Differential (CAD $/Mcf) AECO (CAD $/Mcf) HH (CAD $/Mcf)

$20.00 $45.00 $70.00 $95.00 $120.00 Jan-17 Jul-17 Jan-18 Jul-18 Jan-19

Differential (CAD $/bbl) Ed Par (CAD $/bbl) LLS (CAD $/bbl)

Gulf States provide superior commodity pricing through access to Louisiana Light Sweet oil and Henry Hub gas markets Increasing natural gas demand in the region as more LNG projects become

  • perational

Proximity to growing industrial power demand from continued manufacturing infrastructure development

Location Matters

Continued U.S. structural demand growth in natural gas consumption will put upward pressure on pricing if supply cannot keep pace Lack of macro pipeline egress in Canada will ensure that LLS and HH remain premiums to all other North American markets Henry Hub is anticipated by many to become a world seaborn gas price point similar to Brent Crude

Long Term

$2+ / Mcf

CAD | Henry Hub vs AEC | 2019 YTD

17+ / bbl

CAD | WTI vs Edmonton Par | 2019 YTD

Historical: AECO vs Henry Hub Historical: Edmonton Par vs Louisiana Sweet

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TSXV: SOU www.southernenergycorp.com

Selma Chalk HZ Development

22

100 1,000 10,000 12 24 36 48 60

Gas Rate (Mcf/d) Months

Typical advancements in horizontal well completion design leading to significantly improved results

Gen-1: 3 - 4 stages, 400 - 800 lb/ft Gen-2: 12 - 14 stages, 800 - 1,200 lb/ft Gen-3: 20+ stages, 2,000+ lb/ft

Type Curve Development

Economics

WTI ($/bbl) $60.00 $60.00 Henry Hub ($/MMBTU) $2.90 $3.50 IRR (%) 44% 73% NPV10 ($MM) $2.4 $3.8 Payout (years) 1.9 1.3 P/I Ratio (x) 0.68x 1.07x Recycle Ratio (x) 2.5x 3.1x

Southern HZ Gen-3 Type Curve

Assumptions

EUR – Gas (Bcf) 4.3 EUR – Oil (Mbbl) 9.0 Net Revenue Interest (%) 79% Drilling Cost ($MM) $1.7 Completion Cost ($MM) $1.7 Tie-in / Equip Cost ($MM) $0.1 Total Capex ($MM) $3.5

  • Current Selma Chalk drilling inventory of 60+ horizontals
  • > $150 MM of PUD NPV10 value to SOU at > $3/MMBTU Henry Hub
  • Similar scale of upside potential in the City Bank Formation
  • Pad drilling of stacked zones will put downward pressure on future

development costs 1P Reserve Impact

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TSXV: SOU www.southernenergycorp.com

Project Economics

1) Using flat price forecast of $60/bbl WTI, $2.90/MMBTU HH 23

Southern Project Economics Horizontal Selma Chalk Vertical Cotton Valley Horizontal Cotton Valley Play Significant gas upside above $2.90/MMBTU HH Multi-year drilling inventory in identified oil bearing structures IP 30 Oil (bbl/d) 11 160 510 Gas (Mcf/d) 5,700 280 1,800 EUR Oil (Mbbl) 9 225 572 Gas (Bcf) 4.3 0.4 2.0 Liquids EUR 1% 78% 65% DCET Type Curve Cost ($MM) $3.5 $3.5 $6.8 Operating Netback (1) ($/boe) $12.00 $29.00 $27.60 IRR (1) 44% 38% 90% Payout (1) 1.9 years 2.2 years 1.2 years F&D ($/boe) $4.75 $11.90 $6.80 Recycle Ratio 2.5 2.4 4.1 Capital Efficiency (1st year) ($/boe/d) $6,350 $20,550 $12,200 Comments

  • > 2 Tcf OGIP (~ 15% recovery

factor) and 200+ HZ well drilling inventory in identified Selma Chalk pools

  • Unquantified potential in City Bank

expected to yield similar results

  • Structural closure of the Cotton

Valley estimated at 14,000 acres

  • Resource potential is significant
  • Recent offsetting oil pool

development

  • 30,000+ acres high-graded with

vertical production history

  • Analog HZ wells with IP30 > 1,500

boe/d