resilient and transitioning to overcome growth …...2 agenda 1. key highlights 4. 2017-2020:...
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ECOPETROL
Resilient and Transitioning to Overcome Growth Challenges
October 2016
1
Disclaimer This document was prepared by Ecopetrol S.A. (the “Company” or “Ecopetrol”) with the purpose of providing the market and interested parties certain financial and other information of the Company.
This document may include strategy discussions and forward-looking statements regarding the probable development of Ecopetrol’s business. Said projections and statements include references to estimates or expectations of the Company regarding its future and operational results. Potential investors and the market in general should be aware that the information provided herein does not constitute any guarantee of its performance, risks or uncertainties that may occur or materialize. Actual results may fluctuate and differ from those provided herein due to several factors outside of the control of the Company. Such forward-looking statements speak only as at the date in which they are made and neither Ecopetrol nor its advisors, officers, employees, directors or agents, make any representation nor shall assume any responsibility in the event actual performance of the Company differs from what is provided herein. Moreover, Ecopetrol, its advisors, officers, employees, directors or agents shall not have any obligation whatsoever to update, correct, amend or adjust this presentation based on new information or events occurring after its disclosure. Additional factors that may affect the future results of Ecopetrol are set forth in the section entitled “Risk Factors” in the Company’s Report on Form 20-F for the year ended December 31, 2015 and in the Company’s other filings with Securities and Exchange Commission (the “SEC”), which are available at www.sec.gov.
This presentation is for discussion purposes only and is incomplete without reference to, and should be viewed solely in conjunction with, the oral briefing provided by Ecopetrol. Neither this presentation nor any of its contents may be used for any other purpose without the prior written consent of Ecopetrol.
2
Agenda
1. Key Highlights
4. 2017-2020: Business Plan Update
3. 2016: Transitioning to Growth
2. 2015: Navigating the Low Crude Oil Price Environment
3
Key Highlights
World-class operator of mature assets and a national
leader
Financial excellency and solid corporate governance
Vertically-integrated with diversified revenues
Decreasing lifting cost: 2014: USD$11.23/bl, 2015: USD$7.39/bl and LTM(1): USD$6.1/bl
80% developed proved reserve base (total oil and gas reserves: ~1.8 bn barrels as of December 31st, 2015)
CAGR(2) production of 7.9% (2008 – 2015)
Main Oil (58%) & Gas (60%) Colombian producer
2015/2014 Revenues breakdown(3): Upstream: (49.0%/54.4%), Downstream: (42.9%/40.3%) and Midstream: (8.1%/5.2%)
Largest Ownership of Mid/Downstream infrastructure
Reficar: optimizing feedstock and more valuable mix of products
Majority shareholder support: no dividend distribution in 2016
Discipline of capital and new engineering & projects leadership
Investment Grade(4) despite challenging crude oil price scenario
(1)LTM: Last twelve months, July 2015 to June 2016 (2)CAGR: Compound Annual Growth Rate (3)Third parties revenues by business segment under IFRS (4)Moodys: Baa3 Negative outlook, S&P: BBB Negative outlook and Fitch: BBB Negative outlook
4
Ebitda
2015
Crude Basket (USD$/bl)
Savings (USD$ Bn)
1Q 2016 2014
Key Financial Metrics: Resilience to Lower Crude Oil Price Environment
2Q 2016 1Q 2016 1H 2016 1H 2015
4.5 (1) 4.1(1) 8.7
10.3
38.1 25.1 30.7 47.9 (35.9%) (52%)
(9.8%)
Net Income 0.78 (1) 0.36(1) 1.2 (1) 1.7 (1) (29.4%) (117%)
Figures in COP$ Tn except where otherwise noted
(1) Figures under Colombian IFRS (2) Versus the same period a year ago. 1Q 2016: COP$421 Bn expressed in USD$ using the 1Q-16 average exchange rate of COP$3,249 to USD$1. 2Q2016: COP$392 Bn expressed in USD$ using the 2Q2016 average exchange rate of COP$2,994.68 to USD$1 (3) 1H2016: COP$813 Bn expressed in USD$ using the 1H2016 average exchange rate of COP$3,121.86 to USD$1
Ebitda margin 38.5% 39.5% 38.9%
39.2%
(15.5%)
0.13 (2) 0.26 (3) 0.13 (2)
5
2015 Balance
Proven Reserves 2015 (1)
Costs Optimization
Natural Gas Consumption
Infill Drilling
Foreign Exchange Rate effect over Cost
45% Drop in Sales Prices
2,084 1,849 -251
-404 154 -55
275 47 -1
1P 2014 Efecto Precio(3) ProyectosRevaluados(4)
Consumo Internode Gas(4)
1P 2015
Net Addition: 16 MMBOE
1P 2014 Production Price Effect(3) Additions(4) Revisions(4) Optimization(4) Consumption of
nat. gas(4) Subsidiaries 1P 2015
Million of barrels of oil equivalent (MMBOE)
Source: Ecopetrol (1) SEC methodology (2)Reserve replacement ratio in 2015: 6% (3) Sensitivity over Ecopetrol´s 2014 volumes using 2015 prices 4) Figures for Ecopetrol S.A.
Good Production Performance
6
Agenda
1. Key Highlights
4. 2017-2020: Business Plan Update
3. 2016: Transitioning to Growth
2. 2015: Navigating the Low Crude Oil Price Environment
7.4
4.8 5.4 6.1
0
2
4
6
8
2015 1T 2016 2T 2016 U12M 2015 1Q 2016 (1) 2Q 2016(1) LTM (1)
7
(1) Q1 and Q2 lifting cost has low seasonality; LTM: Last twelve months, July 2015 to June 2016 (2) Dilution factor: percentage of diluent to dilute the total volume of heavy crudes and extra- heavy crude standardized to Castilla quality conditions (12 API). ( 3) cST: centistock. The exchange rates used for the calculation of the costs are: 2014 (COP$2,000 to US$1), 2015 (COP$2,743 to US$1), 1Q-2016 (COP$3,249 to US$1) and 2Q 2016 (COP$2,994.7 to US$1). Cost reductions reflects the impacts of COP$/USD$ devaluation, austerity measures and activity reduction.
Sustained Lifting and Dilution Cost Reduction Enhances Heavy Crude Profitability
Key drivers for lifting reduction: Optimized subsurface and above ground
maintenance
Increased self generation with less expensive fuels and lower tariffs
Optimization of fluids treatment process and lower fees
Dilution and transportation cost reduction by means of: Greater use of multipurpose pipelines vs. trucking
Use of light crude oil as diluent (from Floreña, La
Punta and Ocelote fields)
Pipeline transportation of crudes with higher viscosity, from 300 cSt to 405 cSt.(3)
20.0% 18.5% 17.8%
16.8%
14%
16%
18%
20%
22%
2014 2015 1Q 2016 2Q 2016
Lifting cost USD$/barrel
Dilution factor % (2)
(18%)
- 5.7
12.1
1.8
2014 2015 2016
Viscosity: 200 cSt 300 cSt 405 cSt 600 cSt
Years
Dilution Costs in heavy and extra heavy crude as structural reduction example
Optimization Emphasis
Dilution factor decrease (% diluent / Normalized heavy crude volume)
20.0%
18.5%
16.8%
2014 2015 Jun-2016
Decrease of 210 trucks per day and 608,000 Km/year
Take advantage of the increase in capacity of Pozos-Galán
pipeline
Codilution
Increase of cSt
Ah
orr
o D
ilu
ye
nte
KB
D
Dilution Optimization Strategies
Dilution total savings
Real efficiency Dec of 2016 Forecast
394
332
726
177 177
509 903
2015 2016 Acumulado
CO
P B
n
Accumulated D
iluen
t Sa
vin
gs
MB
D
Significant drilling-days reduction Standardized designs and operations
Cutting-edge drilling technology
Operational discipline
Fee renegotiation and improved
procurement process
Upstream Optimization Achievements
Drilling Days in the Company´s Main Fields
34 36
26 26
19 21
14 14
Castilla Chichimene
2014 2015 2016 to date Record* 2015
12
Production: 1H-2016: 126 mbod
2015: 123 mbod 2014: 104 mbod
Production: 1H-2016: 76 mbod
2015: 78 mbod 2014: 56 mbod
(44%) (42%)
9
Record *2016
*Record: Lowest number of drilling days accomplished
4.0 3.4 3.4 3.8
2014 2015 1Q 2016 2Q 2016
7.2 4.4 3.5 4.3
2014 2015 1Q 2016 2Q 2016
Initiatives Aimed to Increase Efficiency and Reduce Cost in Down & Midstream
Refining cash cost(1)
USD$/barrel
Downstream:
Strategies for optimization in maintenance and support services
Renegotiation of contracts and new procurement strategies
Midstream:
Lower operating cost on maintenance materials, security, attention of contingencies.
Transportation cost (1)
USD$/barrel
The exchange rates used for the calculation of the costs are the following: 2014 (COP$2,000 to USD$1), 2015 (COP$2,743 to USD$1) , 1Q-2016 (COP$3,249 to USD$1) and 2Q 2016 (COP$2,994.7 to US$1). Cost reductions reflects the impacts of COP$/USD$ devaluation, austerity measures and activity reduction by Ecopetrol.
(5%)
(40%)
10
11
152
87
110 8 53
213
172
214
1,009
Cost P&L ECP 2015 Capex Dilution & Sales Subsidiaries Total 2015
Supply Labor CostsAssociation Contracts Inventories OptimizationConsulting, Trucks, Energy
2015 Savings*
USD$ Millions
Fixed and Variable Costs
192
Operational Expenses
68
Total Savings 260
Cost Efficiencies: Opportunities Realized since 2015
410
1H 2016 Additional
Savings
USD$ Millions
2015: COP$2,800 million expressed in USD$ using the 2015 average exchange rate of COP$2,743 to USD$1. 1H 2016: COP$813 Bn expressed in USD$ using the 1H2016 average exchange rate of COP$3,121.86 to USD$1
Dilution and
Logistics
2016 Savings
Target:
USD$512
million
Δ 2014 - 2016
%
CAPEX 2011 - 2016
USD$ Billions
12
(25%)
2016 Budget adjusted
3.0
1.0
2012
8.7
4.1
2.1
1.3
1.0
0.2
2011
9.4
3.9
2.1
1.6
1.1
0.2 0.0 0.5 0.0
0.0
0.0
8.7
4.3
1.9
1.0
1.4
0.1
2013
9.2
4.1
1.9
1.7
1.3
0.2
1.0
0.4
0.3
0.0 0.3
2015
6.7
3.3
1.8
0.9
0.6
0.1
2014
(66%)
Corporate
Downstream Exploration
Midstream Others *
Production
Production
Downstream
Exploration
Corporate
(76%)
(80%)
(49%)
(56%)
(77%)
Capital Discipline: Capex Adjustment since 2015 with Significant Cuts
Midstream
* Others : contingent investments
CAPEX 2011-2016
USD$ Bn
Upstream 26
Downstream 11
Midstream 7
Corporate and others
2
TOTAL 46
Agenda
1. Key Highlights
4. 2017-2020: Business Plan Update
3. 2016: Transitioning to Growth
2. 2015: Navigating the Low Crude Oil Price Environment
14
1. Challenging price
scenario
2. Ambitious saving
targets
0.3
0.8
0.7
1.1
0
1
USD (Bn)
+38%
+120%
Aug 2016 2015
Target 2020
USD 1,5 Bn
Real / Estimated
Initial Goal
3. Efficient cost
reductions
9.1
7.1
6.1
0
2
4
6
8
10
2015 2014 FC 2016
-18%
COP (Bn)
20
25
30
35
40
45
50
55
60
65
70
01
20
15
03
20
15
05
20
15
07
20
15
09
20
15
11
20
15
01
20
16
03
20
16
05
20
16
07
20
16
09
20
16
Brent USD/bl
-31% -61%
CAGR
Since 2014, cash flow focus has been the pillar of a solid financial basis
Recent Exploratory Discoveries and 2016 Activity Basin Potential – Main Countries
ECOPETROL AMERICA • 2Q 2016: APPRAISAL
WELL ‘LEON 2’ UNDER EVALUATION
• 3Q 2016: DRILLING “WARRIOR” WELL
(OPERATOR: ANADARKO)
Orca
GoM West
Mid Magdalena
Lower Magdalena
Llanos
GoM East
Campos
Potiguar
OFF-SHORE COLOMBIA 2014: ORCA discovery 2015: KRONOS
discovery 4Q 2016: BEGINNING
DRILLING OF “PURPLE ANGEL-1” WELL
Colombia:OffShore
ON-SHORE COLOMBIA 2014: discoveries: CPO
09, Cacica y Tiribita 2015: discoveries: CPO
(Nueva Esperanza 2 and 3)
2Q 2016: DRILLING
“PAYERO-1” WELL
Beginning of the Cardon seismic program with a target of 228 km 2d seismic
CPO-09
Brazil
North America
Potential Discovery per Basin (MMBOE) (1)
50 to 100
100 to 250
250 to 1000
> 1000
(1) Source: Wood Mackenzie. Ecopetrol Exploration Review 2015
Kronos Colombia
ECOPETROL BRAZIL
2Q: PROCESSING 854 Km2 OF 3D SEISMIC POT-M-567 BLOCK
NISCOTA- PAYERO-1
CARDON
15
REASSESSMENT OF MATURE FIELDS INTEGRATING EXPLORATION AND PRODUCTION TEAMS
Exploration: Pursuing high-value and quality prospects
Start up
Jul/2016
Stabilization
2H 2016
Optimal Operation
2017
Refining: Completion of Reficar's start up
16
The start up of the 34 units of the modernization project was completed in July
Begin of the stabilization stage and performance tests:
• Design capacities test
• Performance and operational limit verification
• Economic benefit maximization
60%
35%
2%
3%
Output
Propylene
LPG
Naphta &Gasoline
Mid-
Distillates
Bottoms
Reficar
Downstream: Improved Refining Capacity; High-Value Products and Clean Fuels
17
Processing ~100 MBD of Heavy Crude, Extra Heavy Crude and Sour
70% local crude and 30% imported crude
International Fuel Quality Standards: Gasoline of less than 50 ppm vs. 2400 ppm and Diesel of 10 ppm vs. 800 ppm of Sulphur
165 KBD
2016: Ongoing Transformation into a more Efficient and Competitive Company
Capital Discipline
Profitable Barrels
• Focus on capital discipline and cash flow protection • 2016 CAPEX reduction
• Value over volume: 715 mboed targeted production • Sustained Reduction in Operational Costs
• Ecopetrol Group´s savings amounted USD$260 million in 1H 2016(1) Efficiency Focus
Procurement Strategy
• Supply Chain Intervention
Divestment Plan • Divestment program 2016-2017: in 2016 USD$242 million raised from
ISA and EEB(2)
• Proceeds of the Program are not considered in the cash flow planning
18
(1) COP$813 Bn expressed in USD$ using the 1H-16 average exchange rate of COP$3,121.86 to USD$1. (2) ISA: Interconexion Electrica S.A. COP$ 377.08 billion and EEB: Empresa de Energia de Bogota COP$347.8 billion at the exchange rate of COP$3,000 to USD$1.
Ecopetrol´s Employees*
19
Optimizations: Reduction in Direct and Indirect Employees
Ecopetrol´s total employees, including outsourcing, decreased from 53,600 in December 2014 to 28,400 in June 2016 (47% reduction)
* Figures correspond to period end. Rounded figures.
9,150 8,700 8,700
44,450
30,300 19,700
2014 2015 2Q 2016
Direct Employees Indirect Employees
53,600
39,000
(47%)
28,400
2016 Cost-efficient Financing Strategy: ~85% of Requirements Fulfilled
Company Total (%)
Ecopetrol 13,489 75%
Reficar 2,915 16%
Bicentario 561 3%
ODL 323 2%
Bioenergy 165 1%
Ocensa 500 3%
Propilco 0 0%
Total 17,953 100%
(1) Figures expressed in USD$ millions using June 30, 2016 exchange rate. (2) Last Twelve Months EBITDA. (3) February 22, 2016, exchange rate, date of credit resolution. Original amount of the transaction was COP$990 billion.
175
295
300
500
2016 Financing
Remaining Financing
Reopening
Bilateral Loan (ExportDevelopment Canada -EDC)
Bilateral Loan(Bancolombia)
Bilateral Loan (Bank ofTokyo-Mitsubishi)
1,500 - 1,900
Outstanding Debt
USD$ million
2016 Financing Needs
USD$ million
Average life (years) 9.38
Average cost in COP$ 8.63%
Average cost in USD$ 4.67%
Financial Debt/Ebitda(1) (2) 3.25x
1,270
20
(3)
Public Offering
2Q 2016
Data Room Access
2Q 2016
Auction
4Q 2016
Assets Transfer
2Q 2017
Council of Ministers
2Q 2016
Release of Decree
3Q 2016
First Stage
4Q 2016
Second Stage
2017
377
ISA EEB
348
21
2016-2017 Divestment Program: Portfolio Rotation to Generate Cash
2Q 2016 Divestments (COP$ Bn)
Divestments proceeds are not included in our Cash Flow planning Plan 2016-2017: USD$400-USD$900 million
Divestment in Minor Fields
Agenda
1. Key Highlights
4. 2017-2020: Business Plan Update
3. 2016: Transitioning to Growth
2. 2015: Navigating the Low Crude Oil Price Environment
22
23
Strict Capital
Discipline
Cash flow focus &
cost efficiency
Transformation
Program
Reserves &
Production
growth
Ecopetrol’s 2020 Corporate Strategy Pillars
24
-80 -60 -40 -20 0
1. Efficiencies normalized to crude prices, diluent prices and exchange rate.
Upstream Midstream
Dowstream
Ecopetrol S.A.
-30 -20 -10 0
-30 -20 -10 0
-9% -20%
-12% -11%
OPEX
CAPEX
-19%
-9% -8%
-9% -3%
-60 -40 -20 0
-21% -20%
-60 -40 -20 0
-38% -13%
-57% -23%
% Reduction 1H 2016 vs 2015
% Reduction 2015 vs 2014
Fluid treatment cost
(COP/bl)
Energy cost (COP/KWH)
Dilution cost (USD/bl)
Transportation cost
(COP/bl)
Transport maintenance
cost (COP/bl)
Refining cash cost
(COP/bl)
Contract
management
(COP/bl)
Drilling Cost
(USD/PP)
USD
480 MM
USD
340 MM
USD
230 MM
USD
25 MM
USD
150 MM
Total cost reduction USD 1.2 Bn
Improving efficiency and operational indicators (2015-2016)
25
CAPEX
Reduction
25% between
2014 and 2015
54% between
2015 and 2016
due to challenging
prices
Financial strength
3.0 to 3.5
Gross Debt/EBITDA
ratio
Projects
100% units of the
New Cartagena
Refinery in
operation
Capital Discipline: Lower investments while achieving goals
26
Surroundings
• New model for
shared
development
•Elimination of
the “division” between
Ecopetrol’s
operation and
communities
Leadership
•18 new Senior
Management
members, out of 20
•Middle Managers
Training
Procurement
• New procurement model
• ˜3400 reduction in
external headcount
• Renegotiation of 4,000
contracts
Transformation Model Changes in leadership, procurement & surroundings relations
27 (1) Includes OPEX efficiencies and initiatives for revenue maximization
Efficiencies through the Transformation plan(1)
(USD Bn)
0,3
0,8 1,1 1,2 1,4
1,5
0,7 1,1
2015 2016 2017 2018 2019 2020
Target Accumulated result
+130%
Competitive Growth Operational excellence and additional efficiencies by 2020
28
Investment level optimization Focus on Upstream vs. Mid & Down
0
10
20
30
@ 70
USD/bl
Ecopetrol Total Capex, 2017-20 (USD Bn)
31%
@ 50 USD/bl Previous plan
(80 USD/bl)
85%
Includes project breakeven reduction from
CAPEX optimization of ~USD 2.0 Bn
(Transformation Plan 2.0)
47
75
12
15 41
10 100
80
60
40
20
0
Capex distribution by segment (%)
2017-2020 2014-2016
Development & Production
Exploration
Mid & Down
Total
Upstream 59% 90%
13
(3,3/year)
17
(4,3/year)
24
(6,0/year)
Profitable production growth Flexible investment plan focused on Upstream
Business plan secures the company’s profitability and sustainability at 50 USD/bl
44
50
70 70 70
44
50 50 50 50
30
40
50
60
70
80
90
2016 2017 2018 2019 2020
Business plan @70 Business plan @50
Brent (USD/bl)
Previous Plan 80
Planning the Strategy at 50 USD/bl
An increase in
prices is not
contemplated
in the financial
plan
30
715 760
830 870
0
250
500
750
1,000
2020 @ 80
USD/bl
2020 @
70 USD/bl
2020 @
50 USD/bl
Expected
2016
+6%
Production (Mboed)
Growth between 6% and 22% Profitable barrels
EBITDA/barrel at 760 Mboed (USD/bl)
Business
plan
May/2015
16% 22%
7
12
25
30
0
10
20
30
71%
Expected
2016
2020 @
50 USD/bl 2020 @
70 USD/bl 2020 @ 80
USD/bl
257%
328%
Profitable production growth 760 Mboed in 2020 at 50 USD/bl, upturn is subject to price performance
31
Profitable production growth Current assets portfolio is the base for 2020 production target
340
49
1839314
340
715
346
69
49
0
200
400
600
800
1.000
26
830
2020 @ 50
USD/bl
760
(mboed)
+6%
Upturn Exploration
45%
2020 @
70
USD/bl
+9%
2016
Plan
Infill Drilling Secondary
Recovery
Basic Tertiary
Recovery
Production breakdown 2020 and comparison at 2016
Source: Ecopetrol
94% on
current
assets
USD 9.0 Bn in development investments between 2017-2020
(USD 2.2 Bn average per year)
32
0
5000
10000
15000
20000
25000
Ta
sa
de
Cru
do
(B
PD
)
Incremental
production
through water
injection
Primary
production
Infill
Drilling
0
10000
20000
30000
40000
50000
60000
70000
Cru
de
Ra
te (
BO
D)
Incremental
Production
through infill and
water injection
Current recovery factor: 22%
Expected recovery factor: 32%
Current recovery factor 21%
Expected recovery factor: 29%
‘La Cira Infantas’ – Mid-Magdalena Valley – Partnership
‘Yariguí Cantagallo’ – Mid-Magdalena Valley – Direct Operation
Infill and water injection recovery program
since 2005. Reserves increased in 259
Mmboe through the increase of the
recovery factor.
Water injection recovery program since
2009. Reserves increased in 41 Mmboe
through the increase of the recovery
factor.
Profitable production growth Proven ability to add production and reserves through Recovery Factor
33
• Infill Wells
• ~USD 790 MM
investment towards
2020
• Infill Wells
• ~USD 1.400 MM
investment towards
2020
Rubiales
• Infill Wells
• ~USD 470 MM
investment towards
2020
Caño Sur
Castilla
• Infill Wells
• ~USD 370 MM
investment towards
2020
Quifa
• Chichimene, Apiay, Sur,
Casabe, Yariguí,
Piedemonte, Lisama,
Palagua, Dina, Hocol
• ~USD 2.850 MM
towards 2020
Other
• Secondary recovery
• ~USD 460 MM
investment towards
2020
La Cira Infantas
Profitable production growth Focus on main development and production assets
34
Profitable production growth Colombia´s offshore is the best long term gas supply opportunity
35
Onshore
Colombia
Offshore
Colombia
Latam
• Mexico
• Ecuador
• Brazil
• Argentina
• Venezuela
Offshore GOM-US
Mature Fields
(Mid-term)
Off-shore
(Mid-longterm)
Estimated reserves growth Financial flexibility will allow further development in the Americas
36
75
300 50
70
55
110
240
180
720
2017 2020
Operational excellence represents USD 0.7 Bn of impact in EBITDA by 2020
1. Calculated with high impact range of commercialization Source: Ecopetrol, Strategy team analysis ECP - BCG
Reficar Efficiencies
B/meja Efficiencies
Midstream efficiencies
Improved Commercialization
Transportation: Investment
rationalization and profit
maintenance
Downstream: Profit and cashflow
maximization
Commercialization: Increase of
barrel revenue of 1 USD/bl
Profitable growth in Midstream and Downstream Cash flow generation and profit maximization
37
Capacity
Thousand barrels per day (mbd)
B/Bermeja
Ayacucho
Santa Marta
Cartagena Coveñas
Vasconia
Apiay
Santiago
Tumaco
Orito
Tenay
Rubiales
Monterrey Araguaney
Cusiana Porvenir
Sebastopol Banadia
Main Pipelines
1,096 1,276 1,301 1,310
1,445
307 307 352 385 385
2012 2013 2014 2015 2016 e
Crude Products
Maintenance CAPEX: USD 155 million per year.
EBITDA 2020: USD 2.6 Bn
2017: Transportation of crudes with higher
viscosity: from 405 to 600 cSt.
cSt: centistokes
Midstream, a cash flow source The expansive cycle has been fulfilled
38
(USD Bn)
21.3
4.8
16.5
4.0
0
5
10
15
20
25
Sources:
Operating Cash flow
And Divestments
Uses:
CAPEX and Interest
payments
Available cash
@ 50 USD/bl
Additional cash
@ 70 USD/bl
Sources and Uses of cash, 2017-2020
Financial Sustainability Group´s viability at 50 USD/bl and upside with higher prices
39
Divestment of non-strategic
assets
Focus on profitable projects
40% Payout
Reduce leverage
Maintain strict
Capital Discipline
Reduce
financial leverage
3.6
2.5
0
1
2
3
4
Target
2020
3,0
2016
Financial strength Reduce Debt/Ebitda and preserve Investment Grade rating
40
Segments
Main Pillars
2017-2020 Business plan : Seven main pillars
Para uso restringido en Ecopetrol S.A. Todos los derechos reservados. Ninguna parte de esta presentación puede ser reproducida o utilizada en ninguna forma o por ningún medio sin permiso explícito de Ecopetrol S.A.