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The Path to ~230 MMcf/d Forward Looking Statements This - - PowerPoint PPT Presentation

March 2018 The Path to ~230 MMcf/d Forward Looking Statements This presentation may include certain forward looking statements. All statements other than statements of historical fact, included herein, Caribbean Sea including, without


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SLIDE 1

March 2018

The Path to ~230 MMcf/d

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SLIDE 2

2

Forward Looking Statements

2 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

  • bjectives 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 obligation 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. Production and Reserves Production represents net before royalty. Reserves represent 2P reserves and before tax NPV-10 as of December 31, 2016 USD All dollar amounts are shown in US dollars, unless indicated otherwise

140 280 420 560 Km

Bogota

Natural Gas

19 blocks / 2.1 MM net acres

Caribbean Sea Colombia

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SLIDE 3

3

The Leader In Natural Gas Production Growth

+48% CAGR in gas production

MMcf/d

Guidance 70 85 ~230 '16 '17e '18e '19e 114 - 129

(1) Based on current gas contracts, net of transportation costs (2) Includes in-the-money options based on CDN $4.29 / share price (3) Converted from CDN → USD exchange rate (0.79) as of 2/21/18 (4) As of 9/30/17

  • 2018 guidance
  • Capital

$80 MM

  • Gas

114 – 129 MMcf/d

  • Oil

1,700 boepd

  • % gas

>90%

  • Avg. gas pricing

$4.75/MMbtu(1)

  • 2019
  • New Promigas pipeline

+100 MMcf/d USD in MM, except CDN $/share TSX $/share (2/21/18) CDN $4.29 Fully diluted shares outstanding(2) 178 Market capitalization(3) $ 602 Net debt(4) $ 243 Enterprise value $ 845 Insider ownership 22%

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SLIDE 4

A History Of Discovery

+314 BCF in 2P reserves over the trailing 4-yrs.

In USD Pro forma for the sale of Canacol’s assets in Ecuador as of Dec ‘17 (1) The 2017 acquisition of SSJN-7 exploration asset from Pacific Exploration & Production is not pictured (2) Gaffney, Cline & Associates (“GCA”) resource report, effective Dec ’16 (3) Expected Monetary Value discounted at 10%, GCA Dec ‘16

In MMboe(1)

  • il gas

17 20 65 72 7 8 11 14 14 19 9 8

'09 '10 '11 '12 '13 '14 '15 '16

80

74

4

3 gas acquisitions(1) 2 oil acquisitions

  • Highly disciplined exploration growth
  • Evaluated over 150 transactions
  • Selected 3 gas acquisitions

Long-lived reserve base Acquired gas reserves ('12-'14) 96 BCF Canacol’s 2p reserve adds 314 BCF 410 BCF Gas exploration success 10/12 wells (83%) Producing wells 17 Large resource upside Net acres 1.1 MM Blocks 5 Gross mean unrisked resources(2) > 2 TCF BT EMV-10(3) US $789 MM Prospects / leads 44

+51% CAGR in 2P reserves

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SLIDE 5

Canacol Gas vs. North America Gas

$1 $2 $3 $4 $5 $6

Mar '14 Jun '14 Sep '14 Dec '14 Mar '15 Jun '15 Sep '15 Dec '15 Mar '16 Jun '16 Sep '16 Dec '16 Mar '17 Jun '17 Sep '17 Dec '17

$4.96(1)

Selling premium-price gas in a stable price environment

Quarterly average USD sale price per MMbtu $2.82

(1)For the 3 months ended 9/30/2017

Higher netback / productivity = competitive edge

Canacol gas vs. top 8 most economic conventional gas plays in N.A. 2018e USD operating netback Pre-tax USD $/MMbtu Canacol 2018E pricing USD $4.75/MMbtu US/Canada 2018E pricing USD $2.75/MMbtu $1.95 $3.66 $2.38 $2.08 $1.79 $1.49 $1.49 $1.49 $1.34 $1.19

$- $1.00 $2.00 $3.00 $4.00

NE Penn (US) Kakwa-Nest (CA) Sunrise/Sunset (CA) SW Penn super rich (US) Septimus (CA) SW Penn rich (US) Dawson (CA) Susquehanna (US) Canacol Payout Canacol 8-mo. Top 8 avg. 25-mo.

Source: Scotiabank

5

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SLIDE 6

6

Natural Gas Comparison

Canacol vs. North America

Special gas economics

(1) Canacol’s ‘18e projected realized gas contracts, net of transportation costs (2) Barclays N.A. E&P research NYMEX spot 2018 estimate (3) Barclays N.A. E&P research AECO 30+ day spot as of 1/29/18. Conversion CDN→USD as of 1/29/18. (4) Scotiabank 2018E operating netback (5) Barclays N.A. E&P research representing 25+ pure-play, intermediate size natural gas companies in N.A. (6) Canacol’s average for the trailing 2-yr. period (7) Canacol’s average D&A cost for ‘18e exploration program

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SLIDE 7

2018 Plan

Exploration & Development, $33 Facilities & equipment, $17 Seismic, workover &

  • ther, $30

$80 MM capital budget for 2018

US $ in MM

  • 1. Ensure gas productive capacity exceeds

230 MMcf/d by Dec 2018

  • ‘17e guidance

85 MMcf/d

  • ‘18e guidance

114-129 MMcf/d

  • 2. Execute 7-well program
  • Program

4 exploration & appraisal 3 development

  • Avg. F&D cost

$0.44 / MCF(1)

  • ‘18e avg. sales price

$4.75 / MCF(2)

  • 3. Divest or spin out legacy conventional oil assets
  • Creating a pure-play, clean natural gas-focused

Colombian E&P company

(1) Average over the trailing 2-yr. period (2) Based on current gas contracts, net f transportation costs

Gas overweight: 97% of production and capital

7

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SLIDE 8

Build Capacity To Exceed 230 MMcf/d

  • Accelerated drilling program
  • 2 rigs
  • 4 exploration & appraisal wells
  • 3 development
  • Facilities
  • Gas gathering system debottlenecking
  • Gas plant expansion from 200 → 300 MMcf/d
  • Key objectives
  • Achieve 230 MMcf/d of productive capacity

by mid-year 2018

  • Add new reserves to plan for future pipeline

projects

Execute 7-well program and upgrade facilities

2018 Block 1Q 2Q 3Q 4Q

DRILLING Exploration Gaiteros-1 VIM-5 Breva-1 VIM-21 Borojo-1 Esperanza Appraisal/development Pandereta-3 VIM-5 Chirimia-1 VIM-5 2 more well (TBD) FACILITIES Clarinete sub-station VIM-5 Water treatment system Esperanza Betania sub-station Esperanza

8

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SLIDE 9

9

2015 – 2016 Promigas-funded pipeline

(1) ANH statistics

Canacol’s Success Required Access To New Customers

Cartagena Caribbean Sea Jobo Station

+65 MMcf/d N

(1) ANH statistics 10 km Canacol gas blocks 190 km Promigas pipeline Existing gas pipelines

4 blocks 785k acres 20 MMcf/d S

Cerro Matos0

  • ’14 → ’16: Canacol discovered more gas than all

Colombian explorers combined(1)

  • Acquired 2P gas reserves ('12-'14) 96 BCF
  • Canacol’s 2P reserve adds

+314 BCF

  • ’15 → ’16: Promigas funded and constructed a 190

km pipeline from Canacol’s success to Cartagena

  • Replaced declining supply from Chevron fields
  • ’15 → ’16: This new infrastructure enabled Canacol

to increase production from 20 → 85 MMcf/d

  • +65 MMcf/d north to Cartagena
  • Existing 20 MMcf/d south to Cerro Matosa

Barranquilla Mature Chevron fields ~333 MMcf/d

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SLIDE 10

10

2017 – 2018: new and expand infrastructure

(1) ANH statistics

Canacol’s Growth Requires Infrastructure Expansion

On schedule to deliver +100 MMcf/d in Dec ‘18

3

Sincelejo

1

Filadelphia Cartagena Barranquilla Jobo Station Bremen

Added to Canacol’s winning gas portfolio over time

2012 85k acres 2014 Today 1.1MM acres 1

  • In Apr 2017, acquired SSJN-7 block
  • In Dec 2017, ↑ capacity by 40 MMcf/d
  • Private-funded 6-in. line Jobo → Bremen (“Sabanas”)
  • In Dec 2018, scheduled to ↑ capacity from 2nd

expansion of the Promigas pipeline

  • Promigas-funded 20-in. line Jobo → Sincelejo
  • Promigas north

165 MMcf/d

  • Sabanas north

40 MMcf/d

  • Cerro Matos0 south*

25 MMcf/d 2 2 3

VIM 19 Esperanza VIM 21 SSJN-7 VIM-5

3

10 km Canacol gas blocks Promigas pipeline expansion Existing gas pipelines New compression stations

+100 MMcf/d N

Sabanas

3

Mature Chevron fields ~270 MMcf/d Caribbean Sea Cerro Matos0

230 MMcf/d target

* Includes 5 MMcf/d of other customers

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SLIDE 11

Rich History Building Pipes

Esperanza

Palmer Toronja Oboe

Canacol gas field Flow line 5 km

Pandereta Cañandonga Canahuate

Jobo Station

Trombon Nispero Nelson Field 193 BCF

VIM 5 VIM 21

11 Clarinete Field 143 BCF

Sabanas Nov 2017

  • ‘15→’17

Completed 7 pipeline projects

  • ~130 aggregate kilometers
  • Sourced $30 MM to build Sabanas pipeline
  • Private funding (anti-dilutive)
  • Commenced operations Dec 5, 2017
  • 82 kilometers
  • 6-inch line
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SLIDE 12

83% Exploration Success Rate

VIM 21 Esperanza

’18 Chirimia-1 (appraisal) Clarinete Field 143 BCF Cañandonga Toronja Palmer

VIM 5

Oboe Trombon Nispero

’18 Breva-1 (Porquero exploration) ’18 Borojo-1 (CDO exploration)

Lead Prospect ‘18 prospect ‘18 appraisal / development

Nelson Field 193 BCF

5 km

  • Strong track record from two

productive geological formations

  • Ciénaga de Oro (“CDO”)
  • Porquero
  • 3-well exploration program in 2018
  • Targeting 2 CDO / 1 Porquero
  • Applying AVO to investigate presence of

gas-charged sandstones

  • Gas exploration success

10-for-12 (83%)

  • Avg. net pay/well

77 ft. TVD

  • Avg. test rate/well

32 MMcf/d

12

Jobo Station

Canacol gas field 3D seismic Flow line

Canahuate Pandereta

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SLIDE 13

CENTRAL HORST BLOCK WEST FAULT BLOCK NORTH FAULT BLOCK

PAN-1 PAN-2 PAN-3 500 M

SOUTH FAULT BLOCK

CDO

Pandereta-2 Pandereta-1

VIM-5 CDO

64 ft. net gas pay 20.5% porosity 130 ft. net gas pay 23%% porosity

Pandereta 1, 2, 3 Pursuit Tests A Combined 159 MMcf/d

Pandereta-1 Pandereta-2 Pandereta-3

  • Spud

Oct ’17 Dec ’17 Jan ’18

  • Primary target

CDO CDO CDO

  • Net gas pay (in tvd)

64 ft. 130 ft. 103 ft.

  • Flow test

29 MMcf/d 51 MMcf/d 79 MMcf/d Absolute open flow 140 MMcf/d 168 MMcf/d

13

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SLIDE 14

Knowing That Red Means Gas, Which Map Would You Use To Explore For Gas?

1 KM

Uncalibrated 3D Calibrated 3D for AVO analysis

Breva-1 Arandala-1 Carambolo-1

AVO extraction over Porquero formation

Includes test rates

Discovery Prospect

Nuez-1 Datil-1 Cacahuate-1

14 Toronja-1 46 MMcf/d Nelson-5 13 MMcf/d Nelson-6 23 MMcf/d

Applying AVO to investigate presence of gas-charged sandstones (e.g. Porquero reservoir)

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SLIDE 15

2Q 2018 Exploration

Breva-1

  • Breva-1
  • TD

7,300 ft md

  • Reservoir target

Porquero

  • Drill cost(D&A)

$3.1 MM

  • Multiple follow-up locations up to 3

from the Breva pad

1 KM AVO extraction over Mid Porquero SST marker

NUEZ-1 DATIL-1 CACAHUATE-1

A B

VIM-21

TORONJA-1 NELSON-5 NELSON-6

BREVA-1

ARANDALA-1 CARAMBOLO-1 BREVA-1 TORONJA-1

A B

Top Porquero

Breva-1 offers a short 3km tie back to Toronja gas field Breva-1 tests proven play concept in the Porquero supported by AVO

15

BREVA pad

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SLIDE 16

2Q 2018 Appraisal

Chirimia-1 located ~1km from Clarinete-1 (production tested 45 MMcf/d)

  • Chirimia-1
  • TD

9,440 ft md

  • Reservoir target

CDO formation

  • Drill cost(D&A)

$3.65 MM

  • Drilled from Clarinete-1 (“CLA-1) pad
  • On success, well immediately tied in to the

Clarinete flowline to Jobo

VIM-5

Appraise fault-dependent closure downthrown from the Clarinete field (143 BCF 2P reserves)(1) Red/Yellow AVO anomalies reduce risk

16 OBOE-1 CLA-3 CLA-2 CLA-2ST

1 km

CHIRIMIA-1

Upper CDO depth structure B A A B

1000 1200 1400 1600 1800 2000 2200

Basement

Fluid factor dip section

CLA-1 CHIRIMIA-1

(1) Clarinete gas field 2P reserves as of 12/31/16

CLA-1

Penetration point

  • f Upper CDO
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SLIDE 17
  • Borojo-1 is a AVO supported prospect in the CDO
  • TD

9,920 ft md

  • Reservoir target

Cienaga de Oro

  • Drill cost(D&A)

$3.6 MM

  • Offset well COR-12 produced 10 BCF (not drilled

in optimal structural location)

Fluid factor extraction on top CDO, with top CDO depth contours superimposed

A B

COR-12

500 M

Lowest closing contour

Borojo-1 Feijoa-1 Feijoa-1

500 M Esperanza

3Q 2018 Exploration

Borojo-1

17 B A

Fluid factor section

Robust structural closure with strong anomaly

Borojo-1

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SLIDE 18

Ecuador 140 280 420 560 Km

  • S. Pacific Ocean

Colombia

Caguan Putumayo Basin Heavy oil Llanos Basin Light oil Middle Magdalena Basin Shale oil Upper Magdalena Shale oil

  • Solid base producing assets
  • Production

~2k bopd(1)

  • 2P reserves

7.6 MMbls(2)

  • Exploration upside
  • Diversified portfolio

4 basins

  • Blocks / net acres

14 / 1.0 MM

  • Promising exploitation potential for conventional

naturally fractured shale play

  • Access to “world-class” La Luna shale oil

(1) Pre-royalty net production to Canacol, for the 3 months ended 9/30/17 (2) As of the 12/31/16 reserve report

18

Divest or Spin Off Canacol Oil

2Q 2018 anticipated transaction close

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SLIDE 19

19

$1.50 $2.50 $3.50 $4.50

20 22 38 70 86 84 83 77 76 122 ~230

Gas production growth drives share price

Quarterly gas production in MMcf/d CDN $/share

Y/Y growth rate in gas production just turned positive

20 75 85 122 ~230 +275% +13% +43% +82% 0% 50% 100% 150% 200% 250% 300%

  • 50

100 150 200

MMcf/d

‘17e → ‘18e +43% ‘18e → ‘19e +82%

An Even Brighter Future

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SLIDE 20

Special Assets Deliver Significant EBITDA

20

'16 '19e $135 ~$275

US $ in MM

  • Senior secured term loan
  • Credit Suisse

+ syndicate $305 MM

  • Terms

L+5.50%

  • Mar ’19 → Mar ’22

~$24 MM of principal payments for 13 consecutive quarters Significant ebitda to service debt The lowest cost operator wins(1)

In USD (1) For the 3 months ended 9/30/2017 (2) Excludes Ecuador, which is awaiting sale closing

  • Special assets
  • Delivering natural gas under LT take-or-pay price

contracts (~$4.75/MMbtu avg.)

  • Capital light business
  • Spend $80 MM in 2018
  • Increase production by 82%

$/MCF

Natural gas revenues $ 4.96 Transportation expenses $ (0.26) $ 4.70 Royalties $ (0.51) Production expenses $ (0.36) Operating netback $ 3.83 % margin 77%

(2)

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SLIDE 21

Contact IR

TSX: CNE | BVC: CNE.C

21

Carolina Orozco Director, Investor Relations 44 (0) 755.537.3873 corozco@canacolenergy.com Kevin Flick VP, Investor Relations 214.235.4798 kflick@canacolenergy.com Phil Heinrich Investor Relations Manager 403.561.1648 pheinrich@canacolenergy.com