TSXV : SOU
Corporate Presentation July 2019 TSXV : SOU Disclaimers BOE - - PowerPoint PPT Presentation
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
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
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
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
TSXV: SOU www.southernenergycorp.com
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
TSXV: SOU www.southernenergycorp.com
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
TSXV: SOU www.southernenergycorp.com
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
TSXV: SOU www.southernenergycorp.com
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
TSXV: SOU www.southernenergycorp.com
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
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
TSXV: SOU www.southernenergycorp.com
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
TSXV: SOU www.southernenergycorp.com
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)
TSXV: SOU www.southernenergycorp.com
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
TSXV: SOU www.southernenergycorp.com
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
TSXV: SOU www.southernenergycorp.com
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
TSXV: SOU www.southernenergycorp.com
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
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
TSXV: SOU www.southernenergycorp.com
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
TSXV: SOU www.southernenergycorp.com
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
TSXV: SOU www.southernenergycorp.com
Appendix
19
TSXV: SOU www.southernenergycorp.com
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
TSXV: SOU www.southernenergycorp.com
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
$2+ / Mcf
CAD | Henry Hub vs AEC | 2019 YTD
17+ / bbl
CAD | WTI vs Edmonton Par | 2019 YTD
Historical: AECO vs Henry Hub Historical: Edmonton Par vs Louisiana Sweet
TSXV: SOU www.southernenergycorp.com
Selma Chalk HZ Development
22
100 1,000 10,000 12 24 36 48 60
Gas Rate (Mcf/d) Months
Typical advancements in horizontal well completion design leading to significantly improved results
Gen-1: 3 - 4 stages, 400 - 800 lb/ft Gen-2: 12 - 14 stages, 800 - 1,200 lb/ft Gen-3: 20+ stages, 2,000+ lb/ft
Type Curve Development
Economics
WTI ($/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
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