equivalency at the wellhead. 2 - Discovery Labrador The corporate - - PowerPoint PPT Presentation
equivalency at the wellhead. 2 - Discovery Labrador The corporate - - PowerPoint PPT Presentation
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.
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 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 obligation to update or revise these statements. An investment in Canacol is speculative due to the nature of the Corporation's business. The ability of the Corporation to carry out its growth initiatives as described in this confidential presentation is dependent on Canacol obtaining additional capital. There is no assurance that the Corporation will be able to successfully raise the capital required or to complete each of the growth initiatives
- described. Investors must rely upon the ability, expertise, judgment, discretion, integrity, and good faith of the Management of the
Corporation. 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.
The corporate production average has increase 42% over the last 4 quarters: (1)
(1) Value calculated with average net production before royalties from 3Q – F2013 hasta el 3Q- F2014
- Discovery Labrador
and Leono in LLA 23
- Esperanza gas Block
- Libertador & Atacapi
field in Ecuador
The guidance production for calendar 2014 has been revised upwards, from 11,500 – 12,500 boepd to 12,500 – 13,500
Quarterly Average Production
Before royalties
Corporate Netback : $35,40
7,659 boepd
Corporate Netback : $32,14
8,269 boepd
Corporate Netback : $39,33
9,132 boepd
Corporate Netback o: $38,44 Corporate Netback : $43,57
10,095 boepd 10,893 boepd
Quarterly production, included in Financial Statements and MD&A, for each of the periods. tarif tarif
- thers
Increased production is reflected in : Increase in incomes: (1)
- 3Q – F2014 US $55,7 mm
vs 3Q – F2013 US$34,6 mm Scaling up of funds from operations(2)
- 3Q – F2014 US $32,3 mm
vs 3Q – F2013 US$14,8 mm Production with higher netbakcs : (3)
- 3Q – F2014 $43,57/boe
vs 3Q – F2013 $35,41/boe
↑61% ↑118% ↑23%
(1) Adjusted Income from oil and gas for each period – Includes CPI Ecuador. Figures in millions of U.S. dollars (2) Operating average netback for each period.
Figures in millions of U.S. dollars ($) Quarterly values. The date represents the end of each quarter Values obtained from the Financial Statements and MD&A for each of the periods.
a Mar 31 2013 a Jun 30 2013 a Sept 30 2013 a Dic 31 2013 a Mar 31 2014 $ 36,7 $ 41,8 $ 51,6 $ 46,0 $ 61,6 $ 18,4 $ 14,0 $ 17,6 $ 17,8 $ 14,8
Ingresos Totales & Opex + Transporte
Series1 Opex + Transporte
TOTAL INCOMES & OPEX + TRANSPORTATION
Total incomes Opex + transportation
Figures in millions of U.S. dollars($) Quarterly values. The date represents the end of each quarter Values obtained from the Financial Statements and Management Report and Analysis for each of the periods.
$ 14,8 $ 19,1 $ 24,3 $ 15,6 $ 32,3 a Mar 31 2013 a Jun 30 2013 a Sept 30 2013 a Dic 31 2013 a Mar 31 2014
Fondos Provenientes de Operaciones
FUNDS FROM OPERATIONS
Canacol reported net income of $ 19.4 MM for the quarter ended March 31, 2014, compared to a net loss of $ 3.4 million in the comparable period.
Figures in thousands of dollars ($) Values extracted from the audited financial statements at June 30, 2013.
Quarter March 31 2014 2013
Utility (loss) net
19.438 (3.425)
Adjusted: Interests
12.885 478
Taxes
2.416 2.607
Depreciation
9.015 11.446
Stock-based compensation
2.454 1.435
Loss gain on derivatives and financial instruments
(2.657) (320)
Pre-license costs/E&E write - down
3.405 95
Gain (no cash)on business acquisition
- 1.240
Change in the provision
(10.545)
- EBITDA
35.097 14.886
CANACOL WITH THEIR CURRENT SITUATION:
- Solid financial structure
- Reserves increase and "dv"
- Diversified production
- Broad Portfolio of Exploration
- Cash flow:
- $ 35.7 $ 52.1 MM + MM (RC)
- Recent financing for an
additional $ 80 million (Apr 24) WELL POSITIONED FOR:
- Maintain strong production
levels
- Generate cash flow with better
netbacks
- Grow their reserves
(1) Pre-royalty 2P reserves + deemed volumes and pre-tax NPV-10 as of Jun ‘13 and Dec ‘13 (D&M reserve reports). These figures do not reflect production volumes since the date of D&M’s reserve reports (2) Management’s estimate for net risked recoverable resources
Diversified base production
Portfolio 5 basins / 8 fields Enterprise value US $ 752 million 2P reserves + DV 41 MMboe / US $ 846 million(1) Long reserve life ~9 years
Exploration upside
Portfolio 23 contracts / 1.8 million net acres Resource potential ~210 MMboe(2) World-class partners ConocoPhillips, ExxonMobil, Shell
56 gross wells (39 remaining) + 13 workovers
Diversified across 5 basins in Colombia and Ecuador ~$44 million capex in calendar 1Q ‘14(1)
→43 gross development wells (28 remaining)
Calendar ‘14e 12,500-13,500 boepd(2) Y/Y growth 40-50% ~65% oil / ~25% gas Calendar ’14 exit ~17,000 boepd(2)
→13 gross exploration wells (11 remaining)
~85% of exploration capex committed around existing fields ‘14e: Targeting 89 MMboe / 31 MMboe(3)
(1) Excludes business acquisition (2) Pre-royalty average net production (2) Management’s estimate for net unrisked / risked recoverable resources
10.000 20.000 30.000 40.000 50.000 '13a '14e '15e '16e '17e '18e '19e '20e
Nearly triple production from existing 2P reserves over the next 3 years
Calendar year average production positioned on x-axis labels Pre-royalty avg net production (boepd)
$581 $752 $1.546 $265 $708 $190 $81 $- $500,0 $1.000,0 $1.500,0 $2.000,0 $2.500,0
Proven Probable Possible EV Upside
Exploration upside
2P reserves + DV 41 MMboe / US $ 846 million Exploration upside ~210 MMboe / US $2.3 billion
Pre-royalty 2P reserves + deemed volumes and pre-tax NPV-10 as of Jun ’13 and Dec ‘13 (D&M reserve reports). These figures do not reflect production volumes since the date of D&M’s reserve reports Management’s estimate for net risked recoverable resources
Guidance ~13,000 boepd for calendar year ‘14e 8 fields ~$62 / barrel netbacks at LLA 23
Pre-royalty avg net production (boepd) Corp avg netback (/boe) Producing Rancho Hermoso tariff oil Gas
$- $5 $10 $15 $20 $25 $30 $35 $40 $45
- 2.000
4.000 6.000 8.000 10.000 12.000
Operated 80% WI Strong $62/barrel netback Accelerate production and reserves growth Up to 9 wells left in ‘14 Up to 6 development 3 exploration (Tigro-1, Pointer-1, Maltes-1) 1 ‘08→
Rancho Hermoso Field
13 for 13 ~15,000 net bopd at peak 2 ‘12→
Labrador Field
4 for 4 Spud Lab-4 on April 30 3 ‘13→
Leono Field
2 for 2 Set to spud Leono-3 4 ‘14→
Pantro Field 1 for 1
Tigro-1 5 MMbls(1)
LLA 23
50 MMbls pursuit(1) Rancho Hermoso
Fault Oil fields Leads
Pointer-1 2 MMbls(1)
(1) Management’s estimate of net unrisked prospective resources
Labrador Leono Pantro
3D 3D
2 1 3 4
Maltes-1 2 MMbls(1)
Barco Gacheta Ubaque Mirador C7
20 straight successful wells at 4 fields Rancho Hermoso Labrador Leono Pantro
Dec ‘09 Dec ‘12 Dec ‘13 May ‘14 13 4 2 1 6 3 4 5 Field Discovery Wells Reservoirs
Source ANH: Digitally reproduced stratigraphic column for the Eastern Llanos basin (Casanare) Shales Sandstones
Tested 2,930 bopd Tested 1,038 bopd Guadalupe
LLA 23
16
Agueda pad Pointer pad
A-1ST
C7,G,U
Pointer-1 2 MMbls(1) Lab-4 Lab-5
C7,G
Lab-2
G,U
Lab-3
C7,G,U
A-1ST L-5 L-2 L-3 L-4 P-1
(1) Management’s estimate
P P A A
2km LLA 23
4-for-4 at Labrador
Tests ≤1,800 bopd Lab-4 spud
Stacked pay mitigates risk Pointer-1 coming soon $62/bbl netback
80% WI 3 confirmed reservoirs
(2 displayed)
Leono-2 Leono-3 Leono-1 Pantro-2 Tigro-2c Pantro-3 Tigro-3c L-3 P-1 P-2 P-3 T-2c T-3c L-1 L-2
2km
Pantro-1
Tigro pad Lanceros pad
L T Tigro-1 5 MMbls(1) L T
Leono → Pantro → Tigro → 80% WI 5 confirmed reservoirs
(2 displayed)
≤6 month payback/well
OWC @ 10,346 ft OWC @ 9,446 ft
3 solid results
Test rate Leono-1 (B) 1,490 net bopd Leono-2(B) 2,406 Pantro-1(G) 2,344 Pantro-1(M) 830
(1) Management’s estimate
Tigro-1
LLA 23 Pantro Leono
LLA 23
Las Maracas Macarenas Heredia Saimiri Zopilote Cravo E Cravo S Mateguaia Fault Oil fields Leads
19
In Jun ‘14, shoot 400 sq km
- f 3D seismic to firm up ‘15
and ‘16 drilling locations 115k gross acres One of the largest E&P contracts 10x the 3D seismic coverage
Sandstones Shales Limestones
Conventional Unconventional Umir La Luna Simiti Tablazo Paja Rosablanca Colorado Mugrosa Esmeraldas La Paz Lisama
20
VMM 2
VMM 3 Santa Isabel
MA-1
MA-1 40% WI shallow 20% WI deep
VMM 2
VMM 2 Jan ‘13, Mono Araña-1 discovery at VMM 2
Shallow conventional WI 40% Operator Vetra E&P Net oil pay (Lisama) 85 ft Up and Low Lisama tests 703 / 727 gross bopd, 21˚ Comingled test 1,043 Deep unconventional Same source rock as prolific Maracaibo basin (250 b barrels) 3-6x the thickest shale basin in the world (Vaca Muerta) WI 20% Operator Exxon Net oil pay (La Luna) 230 ft LT production test of La Luna
pipeline
1 km Top Lisama depth (3) Represents comingled gross production test results for ~ 1 mo Management’s estimate of gross / net production
100 mmbls OOIP(1) 25 / 10 mmbls(2)
MA-1A next…
2 for 2 at MA
3 6 4 1 2
VMM 2 40% WI ‘14e activities Drill 3 development wells
5
21
MA-1 MA-2
72 ft pay U Lisama 172 ft pay B Lisama 85 ft pay U+ L Lisama 21˚ API Tested 1k bopd(3)
(1) Management’s estimate for Basal Lisama only (2) Management’s estimate of gross / net recoverable resources for Basal Lisama only
Esperanza 100% WI Solid LT gas contracts + strong pricing / netback + minimal development capital Asset ranks in the top 5% in Colombian reserve life 2P reserves 22.6 mmboe(1) Current producction ~3,000 boepd Reserve life 20-yrs Exploration upside Jun ‘14e activities Commence 3 exploration wells 20.3 / 10.4 mmboe(2) Existing contract ‘14→’21e 2,800 boepd @ ~$4/mmbtu 2 new contracts will triple production in Dec ‘15e ’15e→’20e 6,140 boepd @ $5.40/mmbtu >8,900 boepd in Dec ‘15e
Corozo Palmer Cañandonga 1 3 2
Nispero
Prospects Leads Producing fields
Katana
Nelson
Arianna
Cana Flecha Jobo station Pipeline to mine
(1) Reserve report effective Dec ‘13 (2) Management’s estimate for net unrisked/risked recoverable resources
pipeline
Esperanza
A
Palmer-1 (P-1) exploration
B C
P-1
A B C
N-3 N-2 N-4
Max closure at 6600ft ss
20 MMboe pursuit kicks off in late June
Upper Porquero Upper Cienaga de Orgo
(1) Reserve report effective Jun ’13 (2) As of Mar ‘14, the Corporation had spent ~$45 million
Mature fields w/ 15-yr risked service contract Producing > 30 years / >130 wells Partners Tecpetrol, Schlumberger, Sertecpet Terms Incremental oil + exploration Insensitive to oil prices $38.54/bbl above base curve State pays all opex Gross/net capital $334 mm / $93 mm(2) New wells + workovers 31 + >40 Facilities + waterflood pilot Current net production ~1,800 bopd Remaining ‘14e activities Drill 6 development 5 workovers 1 exploration
- 2.000
4.000 6.000 8.000 10.000 12.000 14.000 16.000 18.000
2P deemed volumes of 4 mmbls(1) Net incremental 10.5 mmbls over contract life
Base Incremental
’16e peak ~2,500 net to Canacol
bopd
Oct’12 ’14e ’16e ’18e ’20e ’22e ’24e ’26e Current 18,132 bopd gross
25% JV equity interest
3 2 1 4 6 COR 4 COR 12 VMM 3 VMM 2 COR 11 COR 39 Santa Isabel 5 7
N
N S
The motivation is crystal clear
‘93 → ‘12, Colombia’s oil reserve life has decreased from 19 → 7 years Shale solution to ↑ Colombia’s reserves
Canacol has the 2nd largest shale land position in Colombia Objective: Repeat North farm-out performance in the South
S
COR 62 $263/acre
‘14e: 11 wells 5 fracs $240 mm capex ’16e >25,000 bopd defined shale oil area(1)
Proposed wells (1) ~1.5 mm acres of prospective La Luna shale oil in the Middle Magdalena Basins, EIA Jun ‘13
La Luna Totumal 1-5 Produced 800k bbls La Luna Olivo-1 Tested ≤ 6,400 bopd Catalina-1 Tested 7,820 bopd
Santa Isabel VMM 3 VMM 2
Buturama 1-4 Produced 500k+ bbls
Mono Araña-1 LT test
Rosablanca OP-1 El Cejudo-1 Pico Plata-1
Multiple shale zones Sweet spot
Santa Isabel discoveries (Lisama & Umir) VMM 2 discoveries (Lisama & La Luna)
OP-1 MA-1 Tested 590 bopd 21˚ API
W E
Conventional production test of thick, tectonically-induced fractured shale Expansive volume of unfractured shale best suited for frac-induced technology
Santa Isabel VMM 3
VMM 2 MA-1
OP-1
ROSA ROSA + LUNA LUNA
Development
LLA 23 (Labrador, Leono, Pantro) VMM 2 Ecuador Capella Rancho Hermoso
(1) Management’s estimate of net unrisked/risked prospective resources (2) Represents net average production before royalties
‘14e guidance 43 development wells 13 workovers 12,500 – 13,500 boepd(2)
Exploration upside ‘14e Total HEAVY
Capella: Chipo 1 3.3/0.8
Q 3 ‘14e Q 4 ‘14e Q 2 ‘14e SHALE
VMM 3: Picoplata 1 54.8/13.7 VMM 2
GAS
Esperanza: Palmer, Corozo, Canandonga 3 20.3/10.4 11 89/31 mmboe
LIGHT
LLA 23: Pointer, Tigro, Maltes 3 8.3/4.7 mmbls CLT: Guepardo 1 1.3/0.7 Santa Isabel: Morsa 1 0.3/0.2 Ecuador: Secoya Oeste 1 1.0/0.4
Wells Resources(1)
Advantage
29
TSX (CNE), BVC (CNEC), OTCQX (CNNEF) Team with > 50-yr combined operating history in Colombia Calendar ‘14e 12,500 - 13,500 boepd Targeting 89 mmboe / 31 mmboe(4) Diverse platform 5 basins / 8 fields 2P reserves + DV 41 mmboe(5) Resource potential ~210 mmboe(6) World class partners ConocoPhillips, Exxon, Shell
Investment summary
(1) Excludes anti-dilutive securities based on current market price CDN $7.60/share 101.9 mm fully diluted securities: 90.2 mm common shares + 3.7 mm warrants + 8.0 mm options (2) Converted using CDN → USD exchange rate (0.91) as of 5/13/14 (3) As of March 31, 2014
28% 32% 18% 22% In mm Shares outstanding 90.2 Dilutive securities 3.0 93.2 USD in mm Market capitalization $645.3 Net debt 106.7 Enterprise value $752.0 Diversified ownership
(1) (2) (4) Management’s estimate for net unrisked/risked recoverable resources (5) Reserve reports effective Jun ‘13 and Dec ‘14 (6) Management’s estimate of net risked recoverable resources (3)