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August 2016 Growth From A Focused Portfolio Forward Looking Statements This presentation may include certain forward looking statements. All statements other than statements of historical fact, included herein, including, without limitation,


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SLIDE 1

August 2016

Growth From A Focused Portfolio

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SLIDE 2

2 2

Forward Looking Statements

This presentation may include certain forward looking statements. All statements other than statements of historical fact, included herein, including, without limitation, statements regarding future plans and objectives of Canacol Energy Ltd. (“Canacol” or the “Corporation”), are forward‐looking statements that involve various risks, assumptions, estimates, and uncertainties. These statements reflect the current internal projections, expectations or beliefs of Canacol and are based on information currently available to the

  • Corporation. There can be no assurance that such statements will prove to be accurate, and

actual results and future events could differ materially from those anticipated in such

  • statements. All of the forward looking statements contained in this presentation are qualified

by these cautionary statements and the risk factors described above. Furthermore, all such statements are made as of the date this presentation is given and Canacol assumes no

  • bligation to update or revise these statements.

Barrels of Oil Equivalent Barrels of oil equivalent (boe) is calculated using the conversion factor of 5.7 Mcf (thousand cubic feet) of natural gas being equivalent to one barrel of oil. Boes may be misleading, particularly if used in isolation. A boe conversion ratio of 5.7 Mcf:1 bbl (barrel) is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Acres Acres represents gross acres Production and Reserves Production represents net before royalty Reserves represent 2P reserves and before tax NPV‐10 as of December 31, 2015 Exploration Resource Potential Exploration resource potential represent management’s estimate of net unrisked recoverable resource potential, unless indicated otherwise USD All dollar amounts are shown in US dollars, unless indicated otherwise

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SLIDE 3

3 Ecuador

70 140 280 420 560 Km

Colombia

  • S. Pacific Ocean

Canacol

Supply‐scarce Caribbean natural gas market

  • Dual‐listed

TSX and BVC

  • Enterprise value

US $717 MM

  • Exploration success (‘08→)

65%

  • Insider ownership

~25%

  • ’16e guidance

16 – 17,000 boepd $135 MM EBITDAX

  • YE 2015 2P reserves

79 MMboe

  • Pre‐tax NPV‐10

US $1.3 B

  • 2P pre‐tax value/share

CDN $6.51

  • Y/Y reserves replacement

1,103%

  • 2P F&D cost

$2.85/boe

  • Long reserves life

~10 yrs.

  • + Mid‐year 2016 2P reserves

5 MMboe

  • Substantial exploration

1,045 MMboe resource potential(1)

  • Blocks / gross acres

23 / 3.4 MM

Focused Portfolio

(1) Management’s estimate of net unrisked recoverable resource potential Shale Oil Light Oil Light Oil Natural Gas

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SLIDE 4

4

3 Key Portfolio Components

Large gas reserves underpin production and cash flow for a decade

(1) Excludes mid‐year 2016 reserves update for Oboe 1 (2) Management’s estimate of net unrisked recoverable resource potential (3) DeGolyer & MacNaugton unrisked mean prospective oil resources, effective June ‘14

17 65 14 '09 '11 '13 '15

82% gas

+52% CAGR in 2P reserves

  • Dry natural gas – [stable cash flow]
  • ‘12 and ‘14

2 acquisitions

  • ‘13 → present

3 large discoveries

  • YE ‘15 2P reserves

372 BCF (65 MMboe)

  • + Mid‐year ‘16 reserves

28 BCF (5 MMboe)

  • Exploration resource

>3 TCF potential(2)

  • Light oil optionality – [flexible approach]
  • 2P reserves

14 MMbls

  • LLA 23 exploration

33 MMbls resource potential(1)

  • Large shale oil opportunity – [call option]
  • Exploration resource

458 MMbls potential(3)

79(1)

7 8 11 18 35 43

18 20 23

2P reserves in MMboe

  • il gas

Over the last 5‐yrs, Canacol has discovered more natural gas than every other Colombian explorer, combined

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SLIDE 5

5

Strong Sales Growth

+27% projected CAGR in corporate sales

  • Produced >20 MMboe since inception
  • Operator of all production and facilities in Colombia
  • Natural gas

100% avg. WI

  • Light oil

91% avg. WI

Expressed in boepd 10,933 16,500 19,521 40,000+

1Q '16 '16e avg. Current Mid '18 ‐ after pipeline

Natural gas 80% Tariff oil 8% Light oil 12%

‘16 guidance and sales mix

  • Recent, large natural gas discoveries driving

shift from oil to natural gas

  • Budgeted $40/ Bbl WTI, $135 MM EBITDAX
  • +$10/ BBL in WTI results in +$4MM EBITDAX

88% insensitive to oil volatility

May‐Jun ’16 cash sales(1)

+27%

(1) Includes deferred revenue cash receipts

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SLIDE 6

Canacol Doesn’t Lose Sleep Over Oil Prices

Pursuit of dry natural gas that features stable pricing

Best gas pricing

Quarterly average MMbtu

$0 $3 $6 $9 $12 Mar '14 Jun '14 Sep '14 Dec '14 Mar '15 Jun '15 Sep '15 Dec '15 Mar '16 2016e

Canacol US Canada

LT gas contracts with price escalation

1 2 3 4 5

$30 $15

WTI oil price sensitivity

$60 $45

$0/Bbl Oil prices at zero? Canacol generates ~$100MM EBITDAX

EBITDAX in US$ MM

$107 MM

$118 $130 $142 $153 MM

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SLIDE 7

Canacol‐Gas Ranks #1

7 $32 $36 $36 $38 $39 $41 $42 $43 $44 $47 $50 $52 $54 $55 $56 $58 $59 $63 $65 Karnes Trough Eagle Ford condensate SE SK Viewfield Bakken oil Tower Motney oil Gordondale Motney oil

  • E. Pembina Cardium oil

Sanish and Parshall Bakken oil Ferguson Bakken/Exshaw oil Permian Midland Basin Wolfcamp (deep) oil Permian Delaware Basin Wolfcamp (tier 1) oil

  • Ft. Berthold Bakken / Three Forks oil

STACK Maramec / Woodford Oil Eagle Ford Black oil SCOOP Woodford oil McKenzie County Bakken oil Tuscaloosa Marine Shale oil Permian Midland Basin Wolfcamp (shallow) oil Permian Delaware Basin Bone Spring oil Williams County Bakken oil Mckenzie/Williams Three Forks oil

Mid‐cycle break even costs ‐ $50/bbl WTI, $2.75/Mcf

$/bbl

Source: Scotia Capital Playbook, October 2015 Barclays North American E&P research

  • Captured ~ 40% of all E&P capital

invested from ‘09 to present

  • N.A. shale oil and gas now

largely uneconomic

  • Enter Canacol
  • Breakeven < $5.00/boe

Canacol‐gas < $5.00/boe

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SLIDE 8

A Leader In E&P Capital Efficiency

Participate in our capex‐light growth

  • Peers spent 8x more money to generate the

same production increase

  • Peers drilled 9x more wells
  • Canacol is a leader in capital efficiency
  • One well / yr. to maintain current gas production
  • $4.6 MM D&A cost per well
  • ‘16e: spend $58 MM to generate $135 MM EBITDAX

(1) Range based on Brent oil price sensitivity: $35/Bbl to $55/Bbl

$97 $807 Canacol‐gas Peer Avg.

‘13 → ’15 cumulative capex

$MM Canacol‐gas Peer avg. Capex, x‐acquisitions ($ MM) $97 $807 Production increase (boe/d) 10M 10M Wells drilled 8 73 1Q ‘16 netback ($/boe) $27 $12 ‘16 outlook ($/boe) Stable $26 Volatile $9 ‐ $28(1)

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SLIDE 9

Natural Gas Demand Greater Than Supply

Canacol Gas pipeline La Creciente

Cartagena

Ballena Chuchupa

Caribbean Sea

Cerro Matoso mine

1 2

Barranquilla

3

15 30 60 90 120 Km

Clarinete Oboe

Jobo facility

  • Supply decreasing 20% / yr. from coastal fields
  • Three mature fields in blow‐down

[‐100 MMcf/d per year decline](1)

  • Demand increasing 3% / yr. for the past 10‐yrs.

and projected to grow at 3‐4% through 2026

  • +65 MMcf/d from new 2016 pipeline
  • Flows north / south

65 / 25 MMcf/d south

  • Total production

90 MMcf/d

  • Gas EBITDAX/yr.

$135 MM

  • +100 MMcf/d from planned 2018 pipeline
  • Total production

190 MMcf/d

  • Gas EBITDAX/yr.

$310 MM

  • By 2020e, Canacol will supply ~42% of the coast

1 2 3 Chuchupa Ballena La Creciente

2016 pipeline

65 MMcf/d

(1) Average annual decline for each of the trailing 2 years 2018 pipeline

25 MMcf/d 9

4 fields 100% WI ~785k acres

Palmer Nelson

+100 MMcf/d

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SLIDE 10

Epic Gas Deficit On Colombia’s Coast

Plan to boost gas production to solve supply shortfall

  • The Caribbean Coast had a balanced gas

supply‐demand profile for decades

  • 3 mature fields in blow‐down
  • 100 MMcf/d per year decline(1)
  • Canacol began planning in 2012
  • ‘12 and ‘14

2 acquisitions

  • ‘14 → present

3 large discoveries

  • ‘15 2P reserves

372 BCF

  • ‘16 mid‐year reserves

+28 BCF

  • Plan to 8x Canacol‐gas
  • Solve 77% of the Caribbean’s lost supply
  • Goal to backfill 165 MMcf/d of the 212 MMcf/d lost
  • 127 MMcf/d of additional opportunity

‐ 200 400 600

'15 '16e '17e '18e '19e '20e

Solving Colombia’s gas supply deficit

Gas supply‐demand forecast in MMcf/d

582 265 477

Supply from three mature fields

‐212 MMcf/d

Supply from Canacol

+165 MMcf/d

25 190 455

Source: Industry and Government Studies

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Supply shortfall

127 MMcf/d

(1) Average annual decline for each of the trailing 2 years

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SLIDE 11

Canacol’s Cluster Of Gas Discoveries

Robust reserves + the quest for exploration upside

Prospects / leads Fields & discoveries Canacol’s fields & discoveries

> 3 TCF of exploration upside(1)

  • 100% WI
  • ~785k acres
  • 4 gas fields
  • 3 of 4 fields booked

Upper zone GWC ‐6,410 ft subsea

Date Test

(MMcf/d)

Pay

(Ft.)

Porosity (%) Clarinete‐1 Dec ‘14 44 149 26% Clarinete‐2ST Sep ‘15 30 127 23% Oboe‐1 Mar ‘16 66 158 23% Average 47 145 24%

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(1)Management’s estimate of net unrisked recoverable resource potential

Esperanza 100% VIM 21 100% VIM 5 100% 3D seismic

Nelson Oboe Nelson‐6 Nispero‐1

Cienaga de Oro time structure map

Palmer

Jobo

Clarinete

10km

  • ‘15 2P reserves 372 BCF
  • ‘16 Oboe add

28 BCF

  • ~50 prospects / leads

3km

Oboe‐1

Subcrop edge

Clarinete‐1 Clarinete‐2ST

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SLIDE 12
  • Using 3D seismic data,

Canacol is mitigating exploration risk by applying AVO seismic attribute analysis

  • Nispero‐1 drilling underway
  • Targeting CDO sandstone

reservoirs sealed by Porquero shale

  • 40 Bcf EUR unrisked

resource potential $4.6MM cost (D&A)

Large Resource Potential At Esperanza

Reduce exploration risk with the application of AVO technology

12 12 3D seismic image

Sucre‐2 Nispero‐1

N S

Top CDO depth structure map

AVO extraction: Top CDO (magenta marker) to Top CDO +25ms

500 M ESPERANZA VIM‐5

AVO seismic attribute anomaly

N S

PLIOCENE UNC BASEMENT

AVO Events

NISPERO‐1

A B

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SLIDE 13
  • Potential for new gas pool at Nelson
  • Up to 62 ft. reservoir net pay encountered

in existing Nelson wells

  • Nelson‐6 to spud after Nispero‐1
  • Targeting shallow CDO reservoir sandstones
  • 31 Bcf EUR unrisked resource potential
  • $4.6MM D&A cost per well

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Nelson‐5 Middle Porquero petrophysical interpretation

GWC‐5500’TVDSS

Nelson‐3 Nelson‐2 Nelson‐6 Nelson‐4 Nelson‐5

Gross Thickness 153 ft Net Pay 62 ft Porosity 31%

B A NELSON‐6 AVO Events

Porquero net pay map (ft)

A B

Gas Opportunities Continue To Multiply

Potential new pool at Nelson field – Porquero formation

Nelson Field (Porquero Fm.)

Area 640 acres

  • Avg. Porosity

29% GIIP 44 Bcf

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SLIDE 14
  • Five light oil discoveries made along Rancho

Hermoso fault trend

  • Exceptional on‐block track record for

exploration success (83%, 5/6 wells)

  • Three additional trends remain undrilled
  • Multiple prospects are drill‐ready
  • At $50/Bbl+ WTI
  • Target four drill ready prospects situated

along flow line for short and immediate tie‐in e.g. Pumara prospect

  • Significant upside in success case

Successful Exploration on Block LLA‐23

With a lot more running room

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Prospect/Leads Wells Gross Unrisked EUR (MMbbl)

3D prospects 13 20 Leads 5 16 Total 18 36

Las Maracas ~12 MMbls Macarenas ~6 MMbls Cravo E ~8 MMbls Cravo S ~9 MMbls

Labrad

  • r

3 2 1

91% WI >110k acres

LLA 23

Rancho Hermoso Maltes Tigro Pantro Leono Labrador

Labrad

  • r

’17 Pumara Prospect Canacol’s fields & discoveries

Prospects Leads 3 Opportunities trends to repeat 3D seismic Competitor oil fields Leono‐Pointer fluids flow line Pointer CPF

1

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SLIDE 15

‘17 Pumara Prospect

On Pumara‐1 well success case, targeting 5k bopd from 3 wells

15

SE NW

C1 C7 BARCO UBAQUE PALEOZOIC

500 m

NW SE

Pumara‐1 (Exploration location) Pumara‐A (Appraisal well) Pumara‐B (Appraisal well)

  • Fault dependent anticlinal closure
  • Mapped on 3D seismic
  • Primary targets: Ubaque & Gacheta
  • Secondary targets: Mirador, Barco and C7
  • 4 MMbls unrisked EUR resource potential
  • $3.8MM D&A well cost

Ubaque TVDSS map Inline 197 over Pumara

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SLIDE 16
  • World class shale oil
  • Source rock to 2.3 trillion barrels discovered in

Ecuador, Colombia and Venezuela(1)

  • Comparable or superior characteristics to the

Bakken and Eagle Ford (thickness, porosity, TOC pressure gradients)

  • Second largest shale oil land position behind

Ecopetrol in Colombia

  • 7 blocks

749k net acres

  • Potential

458 MMbls of audited unrisked prospective resource potential

  • NPV‐10

$1.3 B(2)

  • Early indications are positive
  • Farmed out acreage to Super Majors (‘11 – ‘12)
  • Two wells drilled de‐risked play (‘12 – ’15)
  • First frac planned this year by Conoco
  • Ideal location in producing hydrocarbon basin

Shale Oil Opportunity In Colombia

16

650 km

Oil Fields sourced from La Luna Middle Magdalena Valley Basin (MMV) La Luna shale deposition limit

Orinoco heavy oil belt

Venezuela Colombia Ecuador (1) James 2000, Journal of Petroleum Geology (2) Only three of Canacol’s seven blocks

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SLIDE 17

Oil Exploration Upside

Light oil production upside forecast (unrisked)

(bbl/d) 5,000 10,000 15,000 20,000 25,000 30,000 1 2 3 4

  • Large light oil prospects and leads

inventory

  • Dial up or down with oil price environment
  • Light oil forecast
  • 3x production from drill ready prospects
  • >2x production from remaining prospects

and leads

Remaining Prospects (LLA‐23/VMM‐2) Drill Ready Prospects (LLA‐23/VMM‐2) Base Production (LLA‐23/Ecuador) Years

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SLIDE 18

Projecting 60%+ Drop In Debt Multiple

$MM

Loan Drawn Terms Final Payment BNP $200 $180 L+4.75% Sep ‘19 Apollo $100 $75 L+8.50% Dec ‘19

'16 Dec '17 '18 Sep '19 Dec '19

BNP Apollo Start: Eight equal installments

  • Debt profile

3.8x 3.4x 2.8x 2.6x 2.1x 1.4x Dec '15 Mar '16 Jun '16e Sep '16e Dec '16e '17e

Lower debt multiple to unlock Canacol’s equity?

Debt multiple to trailing 12‐month EBITDAX

  • ’16e guidance

16 – 17,000 boepd $58 MM capex $135 MM ebitdax

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SLIDE 19

A Rare Dislocation in Equity Value

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in MM, except /share amounts

TSX share price (7/25/16) CDN $3.99 FD shares outstanding(1) 163 Market capitalization(2) US $491 Net debt(3) $226 Enterprise value US $717 Cash(3) $30

Buying Canacol at a discount to the value of our existing gas contracts

BT NPV‐10, US $MM CDN $/share

(1) Includes in‐the‐money options based on CDN 3.99/share price (2) Converted from CDN → USD exchange rate (0.76) as of 7/25/16 (3) As of 3/31/16

Stable production under LT contracts

$717 $1,165 $193 $2,124

EV 2P gas 2p oil Exploration

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SLIDE 20

Investment Opportunity

Measuring 2015 – 2016e

TSX: CNE | BVC: CNE.C

Canacol Peer avg. North America Production growth +63% +17% +11% Capex $ growth ‐29% +15% +6% Natural gas pricing ($/MMbtu) $5.64 fixed ~$5.00 volatile $1.58 volatile Sensitivity to oil volatility 12% >90% 88% Gas netback ($/boe) $26 $12 $9 EBITDAX growth 100% < 15% < 10% G&A reduction 40% Debt multiple Decrease Increase Increase F&D cost $2.85 ~$20

  • Oil price trading at zero?
  • Canacol generates over $100 MM in EBITDAX
  • 2018 pipeline to boost EBITDAX: $135 → $310 MM / yr.

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Source: corporate filings and Barclays North American E&P research