Opportunity Day: Year-end 2013

Stock Exchange of Thailand

March 5, 2014

PTT Exploration and Production Public Company Limited

Passion to Explore for a Sustainable Future

2

Agenda

Company Overview and Industry Update

2013 Key Achievements and Financial Performance

Growth Strategy and Investment Plan

2 / 21

3

Leading Regional Exploration and Production CompanyLargest publicly-listed E&P company in Southeast Asia

PTT

65.3%

Others

34.7%

Others

73%

PTTEP

27%

PTTEP Thailand

Moody’s Baa1 Baa1

S&P’s BBB+ BBB+

JCR A- A-

TRIS AAA N/A

Source: Bloomberg as of 28 February 2014

Shareholding structure

PTTEP is the 3rd largest company on

the Stock Exchange of Thailand ("SET")…

…is a subsidiary of PTT Public Company

Limited

…is on par with sovereign ratings

…and contributes more than 1/4 of Thailand's

total petroleum production

Source: Department of Mineral Fuels, PTT, PTTEP

(November 2013)

Note: As of 17 February 2013

Note: Foreign currency credit rating except TRIS for local currency rating

3 / 21

8.24

10.10

10.40

10.84

12.55

15.81

15.87

18.80

19.29

25.73

AOT

BBL

PTTGC

CPALL

KBANK

SCB

SCC

PTTEP

ADVANC

PTT

(US$bn)

4

Notes:

* 3 Projects are pending withdrawal official approval

** After KKD asset swap, subject to approval from

the Canadian government

*** Other segments and unallocated assets are

considered Corporate / Head Office asset, hence

classified under "Thailand"

Thailand 46.3%

Australasia14.1%

North America

13.3%

Africa and Middle East

11.8%

SE Asia14.5%

PTTEP’s Asset Base by Book Value (as of December 31, 2013)***

North America (1)

1 Exploration

Canada**

Africa and Middle East (7)

1 Production

1 Development

5 Exploration Algeria

Mozambique

Kenya

Oman

Thailand (18)

14 Production

1 Development

3 Exploration

South East Asia (15)

5 Production

1 Development

9 Exploration

Myanmar

Vietnam

Indonesia

Australasia (1)

1 Production

Australia

Internationally Diversified and Balanced PortfolioWorldwide operations: 42* projects in 10 countries

4 / 21

5

Oil PricesSlightly softer oil price environment in 2014 driven by increasing N.American Supply

40

60

80

100

120

Jan-13 Apr-13 Jul-13 Oct-13 Jan-14 Apr-14 Jul-14 Oct-14

US$ / BBLWTI WCS

90

100

110

120

Jan-13 Apr-13 Jul-13 Oct-13 Jan-14 Apr-14 Jul-14 Oct-14

US$ / BBL Dubai Brent

WTI Consensus

Range $115

$90

Brent Average $104.38

2013 AverageWTI 97.99 US$/BBLDiff. 24.31 US$/BBL

Q1 13 Q2 13 Q3 13 Q4 13

2013 Average Dubai 105.04 US$/BBLBrent 108.54 US$/BBL

Q1 14 Q2 14 Q3 14 Q4 14

Brent Consensus

WTI Average$91.73

2014Consensus

2014Consensus

Range $111

$83

Q1 13 Q2 13 Q3 13 Q4 13 Q1 14 Q2 14 Q3 14 Q4 14

WCS Forward Curve

WCS Average$70.44

5 / 21

6

Agenda

Company Overview and Industry Update

2013 Key Achievements and Financial Performance

Growth Strategy and Investment Plan

6 / 21

7

2013 Key Achievements

Strong operations, healthy financial position and excellent safety records

Recurring profit growth of 6% YoY, in-line with

sales volume growth

Maintain strong EBITDA margin at ~ 70% with

increased operating cash flow

Upward revision of credit rating outlook to stable

1.24

0.81

0.590.39

0.19 0.18

0.0

0.5

1.0

1.5

2008 2009 2010 2011 2012 2013

Lost Time Injury Frequency (LTIF)

Industry Benchmark PTTEP

Exploration and Production Operations Portfolio Management

Safety Records

Highest total production level at 329 KBOED

S1 project highest production at 37,890 BPD

Successful first production for Montara

Discoveries in Myanmar M3 and Algeria HBR

Top quartile safety performance in E&P industry

Financial Performance

Acquisition of producing asset in Natuna Sea A

Farm-out of Myanmar M3 and Myanmar M11

Refocus strategy and investment plan through

KKD asset swap

No. o

f inci

dents

per m

illio

n m

an h

ours

7 / 21

8

PTTEP Sales Volume and Operating Expenses

Strong average product price offsets higher operating costs

186,982 183,314 191,798

78,065 92,609 100,831

0

100,000

200,000

300,000

Liquid GasBOED

275,923292,629

265,047

Gas ($/MMBTU)

Liquid ($/BBL)

Weighted Avg. ($/BOE)

Avg. Dubai ($/BBL)

Avg. HSFO ($/BBL)(High Sulfur Fuel Oil)

Revenue Mix

(Gas : Liquid)

20122011 2013

6.00

102.23

55.49

105.52

99.81

46 : 54

7.59

103.27

64.86

109.03

103.26

46 : 54

*7.92

100.15

**65.58

105.54

97.52

47 : 53

Sales Volume and Price

* Gas price, if excludes Vietnam 16-1 retroactive sale recording, is 8.01 $ for 2013

** Average selling price, if excludes Vietnam 16-1 retroactive sale recording is 66.09 $ for 2013

0

10

20

30

40

$/BOE

20122011

14.95

33.94

DD&A

Royalties

G&A

Exploration Exp.

Operating Exp.***

Lifting Cost

F&D Cost

- Organic F&D

Cash Cost Unit Cost

14.47

2013

15.33

7.65

3.17

1.61

6.18

4.88

33.49

26.58

13.61

7.80

3.09

2.11

5.61

4.28

28.97

21.71

32.22

11.55

6.67

2.67

2.24

5.73

4.35

19.70

15.82

13.13

28.86

Unit Cost

*** Exclude diluent cost for blending bitumen in KKD Oil Sands project

8 / 21

9

2013 Financial Performance

~ 70% EBITDA margin from strong core operations with higher operating cash flows

2,908

3,4553,740

80

120

160

200

240

280

0

1,000

2,000

3,000

4,000

5,000

2011 2012 2013

Operating Cash Flows

69% 70% 71%

MMUSD KBOE/D

Cash Flow Performance

1,846482 401

84 50 67179 204 73

0

500

1,000

1,500

2,000

2,500

A Sa

le

Cost*

Inco

me ta

x e

xp

.

Oth

er R

ecu

rring**

Lo

ss o

n F

X

Defe

rred T

ax fro

m F

unc.

Curre

ncy

Impairm

en

t loss fro

mM

onta

ra

Oth

er N

on

-Recu

rring***

B

MMUSDRecurring Factors

1,846

2012 2013

Non-Recurring Factors Sales Volume

EBITDAMargin

Net Profit Factor Analysis

Note:

* Included DD&A , Exploration expense ,and Opex

** Included revenue from pipeline , Interest Revenue , Royalties & SRB ,G&A expenses, Finance costs ,and etc.

*** Included Insurance claims received ,Abandonment expenses in PTTEP AA ,Current Tax from FX Revaluation , and Gain/loss from Financial instrument

9 / 21

10

Weighted Average

Cost of Debt* (%)

[Fixed : Floating]

3.12

[84 : 16]

3.99

[79 : 21]

3.99

[75 : 25]

Average Loan Life*(Years) 3.96 7.50 6.81

2013 Financial Position

Healthy capital structure with low gearing and cost of debt

6,31210,711 11,728

3,873

3,7734,023

3,946

5,1535,821

0.61

0.35 0.34

0.00

0.20

0.40

0.60

0.80

1.00

0

5,000

10,000

15,000

20,000

25,000

2011 2012 2013

Equity (LHS) Interest Bearing Debt (LHS) Other Liabilities (LHS) Gearing Ratio D/E (RHS)

MMUSD D/E Ratio

* Exclude Hybrid bonds

US$97%

THB3%

US$89%

CAD11%

US$87%

CAD13%

Capital Structure

Asset

Debt Profile*

Assets

14,131

19,63721,572

10 / 21

11

1.48

2.55 2.61 2.80 3.001.20

2.482.79

3.00 3.00

40% 40% 40%38%

40%

0%

25%

50%

0

5

10

2009 2010 2011 2012 2013

Dividend Payment History(No Less Than 30% of Net Income)

1H 2H Payout Ratio

2.68

5.03

5.40

THB per share

Payout Ratio

5.80 6.00

Consistent top quartile Return on Equity (ROE) performer with solid dividend payout

Sources: based on company latest filings, note not all companies have full year 2013 reporting

- Comparable Peers include CNOOC, Sinopec, Petrochina, Inpex, ONGC, Santos, BG, ENI, Statoil, OMV, Apache, Anadarko, Hess, Murphy, Marathon Oil, Petrobras and Ecopetrol

- Calendar Year Return On Equity as defined by CapIQ source: Net Income from Continuing Operations / ((Beginning of the Year Total Equity + End of the Year Total Equity)/2)

Top

Quartile

ROE

PTTEP’s ROE

ROE – PTTEP vs. Industry

Median

16.0%

27.2%25.1%

21.7%

16.4%

(20)%

(10)%

0%

10%

20%

30%

40%

2009 2010 2011 2012 2013

Competitive Returns to Shareholders

11 / 21

12

Agenda

Company Overview and Industry Update

2013 Key Achievements and Financial Performance

Growth Strategy and Investment Plan

12 / 21

13

PTTEP Three-Pronged Strategy

Balanced approach to become a BIG, LONG and STRONG E&P company

“BIG”

“STRONG”“LONG”

Production target of

600 KBOED by 2020

Proved Reserves life

at 10 years

Competitive ROE

Maintain

Credit Rating

VISION

Become a leading Asian E&P company through technology and green practices

13 / 21

1414 / 21

Reserves and Resources Classification

15

969 901 846

898 885 860

1,350

2,200 2,700

0

1,000

2,000

3,000

4,000

5,000

2011 2012 2013

MMBOE

Proved (P1) Probable (P2)

3,217

3,986

4,406

Reserves /

Resource Life*

Contingent (2C)

7 Years

14 Years

37 Years

2013 by Geography

Reserves

(P1 + P2 + 2C)P1 P1 + P2

Reserves

P1 P1 + P2

2013 by Product Type

Domestic International

Gas Liquid

Resources Base

(P1 + P2 + 2C)

Resources Base

47%53%

47%

56%42%

44%

846

1,706

4,406

846

1,706

4,406

* Based on total production of natural gas, crude oil (including bitumen) and condenstate of 329 KBOED for the year ended December 31, 2013

Reserves and resources data as of year-end 2013, prior to the KKD asset swap transaction announced on January 30, 2014

5-Year Average Proved Reserves Replacement Ratio (RRR)

2011 2012 2013

1.10x 0.91x 0.82x

Reserves and Resources Base

Large resources base to support sustainable growth LONG

58%

53%

26%

74%

30%

70%

15 / 21

16

Target Production at 600 KBOED by 2020

Clear visibility on growth strategy through international growth andopportunistic M&A

Production Volume (KBOED)

~250

~400

600

Maintain Production Plateau in Domestic Projects

Growth from International Projects Start-ups and Ramp-ups

Evaluate New Exploration and M&A Potentials

Thailand :

- S1

- Bongkot

- Pailin

- Arthit

- MTJDA

Long-term Contributors :

- Myanmar M3

- Mozambique Offshore

Area 1

- Canada Oil Sands

M&A targets :

- Southeast Asia producing assets

- North America shale assets

with high liquid content

- Other prospects

Discovered Prospects :

- Cash / Maple

- Algeria HBR

New Frontiers:

- Mozambique and Kenya

2013 2020

Near-term Growth :

- Montara

- Vietnam 16-1

- Zawtika

- Algeria 433a & 416b

329

BIG

16 / 21

17

Effective Investment Allocation

Asset rationalization to sustain strong and competitive performance

* Calculated based on exclusion of acquisition

** Excludes expenditure for M&A opportunities and after KKD asset swap, which is

subject to approval from the Canadian government

STRONG

2,9613,388 3,562

3,0743,514

2,866

1,535

2,010 1,679

1,671

1,742

1,775

328

0

2,000

4,000

6,000

2013 2014 2015 2016 2017 2018

MMUS$

Key Projects ExpenditureArthit, Bongkot, Pailin, S1, Zawtika, THSL

Mozambique Offshore Area 1, Myanmar M3, Natuna Sea A

Total Expenditures (2014-2018)** =

CAPEX =

OPEX =

Acquisitions

Exploration 11 * 5 1 4 8 9

Development 56 * 47 7 59 54 46

Operation 5 0 4 5 9

Corporate & Others 10 3 2 3 3 6

$27 bn $25 bn

$17 bn $16 bn

$10 bn $ 9 bn

Before KKD

Asset Swap

4,824 5,398 5,241 4,745 5,256 4,641Total

Expenditures

17 / 21

18

Strong Positioning in South East Asia

A key growth platform with attractive returns next to home

…with Myanmar as primary growth driver

Almost 1/4 of 2014 – 2018 CAPEX allocated… …to strengthen contribution from region…

~16 bn

USD

Source : Company own data, Premier Oil

27%22%

Thailand

Other

International

30%

70%

of total production volume at

~400 KBOED by 2020

of 2013 proved reserves

EBITDA margin contributors

Vietnam 16-1

Natuna Sea A

Zawtika Processing and

Living Quarter (ZPQ)

Natuna Sea A

Processing Platform

Myanmar

Zawtika

Myanmar M3

PSC-G & EP2

Myanmar M11

MD7 & MD8

18 / 21

19

Long-term Prospects in International Hotspots

Large resources base mainly in Canada Oil Sands and Mozambique LNG

..in worldwide growth hubs

Source : Company own data, Anadarko

450+

80%

2019

MMBOE of 2C turn to 2P

reserves to support production

of ~2.7 bn BOE 2C resources

onwards expected production

from Mozambique and Canada

Canada

Oil Sands

Mozambique

LNG

Cash/Maple

Mozambique LNG Park THSL Oil Sands Leases

Algeria HBR

Over 1/4 of 2014 – 2018 CAPEX planned… …to monetize major international assets…

~16 bn

USD

26%

Thailand

Other

South East

Asia

North

America

Middle East

& AfricaAustralasia

19 / 21

20

Target Sales Volume*

Strong home base with solid growth from Southeast Asia

0

100

200

300

400

’000 BOED

2016 20182013 2014

Key Commercial

Volume Additions

2017

Algeria433a &416b

Thailand **

South East Asia

Other International

Montara /

Zawtika /

Natuna Sea A

11%7%

293

325347

336322

305

2015

Product Mix

Gas (%)

Liquid (%)

65

35

64

36

65

35

70

30

71

2966

34

** Including overlapping area

* Estimated sales volume figures after KKD asset swap, which is subject to approval from the Canadian government

20 / 21

21

Key Takeaway

Solid Revenue Drivers

- Sales volume growth ~6% in 2013 ; expected ~10% growth in 2014

- Expected gas price of 8 USD / MMBTU and oil price range of 97 – 102 USD / BBL

Continued Exploration Progress

- Focus remains in Southeast Asia, especially Myanmar

Maintain Good Financial Discipline

- Maintain flexible capital structure through low gearing at no higher than 0.5x

- Consistent dividend ; 6.00 THB / share for FY2013

Optimize Company Portfolio

- Focus M&A on producing assets and continue assets rationalization

21 / 21

22

Q & A

For more information, please visit our website at

http://www.pttep.com

OR

Contact us via email address at

IR@pttep.com

OR

Call us at +66 2 537 4000

Exploring new horizons, we take every step as learning

23

DISCLAIMER

Forward-looking Information

The information, statements, forecasts and projections contained herein reflect the Company’s current views with respect to future events and financial performance.

These views are based on assumptions subject to various risks. No assurance is given that these future events will occur, or that the Company’s assumptions are

correct. Actual results may differ materially from those projected.

Petroleum Reserves and Resources Information

In this presentation, the Company discloses petroleum reserves and resources that are not included in the Securities Exchange and Commission of Thailand (SEC)

Annual Registration Statement Form 56-1 under “Supplemental Information on Petroleum Exploration and Production Activities”. The reserves and resources data

contained in this presentation reflects the Company’s best estimates of its reserves and resources. While the Company periodically obtains an independent audit of a

portion of its proved reserves, no independent qualified reserves evaluator or auditor was involved in the preparation of reserves and resources data disclosed in this

presentation. Unless stated otherwise, reserves and resources are stated at the Company’s gross basis.

This presentation may contain the terms “proved reserves”, “probable reserves”, and/or “contingent resources”. Unless stated otherwise, the Company adopts

similar description as defined by the Society of Petroleum Engineers.

Proved Reserves - Proved reserves are defined as those quantities of petroleum which, by analysis of geological and engineering data, can be estimated with

reasonable certainty to be commercially recoverable, from a given date forward, from known reservoirs and under current economic conditions, operating methods,

and government regulations.

Probable Reserves - Probable reserves are defined as those unproved reserves which analysis of geological and engineering data suggests are more likely than not

to be recoverable.

Contingent Resources - Contingent resources are defined as those quantities of petroleum which are estimated, on a given date, to be potentially recoverable from

known accumulations, but which are not currently considered to be commercially recoverable. The reasons for non commerciality could be economic including market

availability, political, environmental, or technological.

24

1. Industry Recap and Outlook

2. 2013 Awards and Recognitions

3. 2014 Key Exploration Activities

4. PTTEP Project Information

5. Corporate Social Responsibility

6. Organization Structure

7. Ratio Formula

Supplementary Index

25

Macroeconomics and Industry OutlookGlobal economic growth and uncertainty extends into 2014

Financial

Performance

E&P

Operations

Oil Prices

Cost of Funds

• EU painful reforms, and

lackluster growth

• Improving global growth trend

• Chinese credit controls;

slower sustainable

growth

• US Recovery and QE Tapering

• Violent demonstrations;

Libyan and South-Sudanese

barrels at risk

• Potential return of Iran

to international oil & gas markets

• East Africa poised for more exploration activities

• Significant production growth

from shale oil/gas assets

• Political Conflicts

• Weak private sector confidence

• Loss of international FDI

opportunities

• Asset rationalization

of N.American shale

and non-core assets

• South China Sea

Spratly Islands Territorial dispute

Supplementary 1.1 / 7

26

Upstream M&A Activities2013 activities mainly focused on sales of conventional assets

63%20%

17%

2013 Top M&A Deals over $2 Billion

Mozambique: $9.3bn

United States: $10.5bn

United States: $3.8bn

Russia: $11.6bn

LEGEND

Conventional

Unconventional

Deep water

2013 Total Deal Value of $53.6bn

Egypt: $3.1bn

Norway: $2.7bn

Kazakhstan: $10.4bn

Source: IHS Herold

Thailand: $2.3bn

2012 2013

$157.1bn

$53.6bn

Deal Value by Year

2012 2013

Deal Count by Year

21

15

-66% -29%

Supplementary 1.2 / 7

27

Thailand – Gas Production and ConsumptionResilient Gas Demand amidst economic uncertainty

• Gas consumption positively correlated

with GDP

• Gas production is resilient

• LNG imports is the ‘swing’ volume

-

2,000

4,000

6,000

8,000

10,000

0

2,000

4,000

6,000

2008 2009 2010 2011 2012 2013E 2014E

LNG Imports Gas Imports (Mynamar)

Domestic Production Gas Consumption

Real GDP* (THB Bn)

Notes: * GDP at 1988 Prices

Gas Production/Consumption

MMSCFD

Real GDP (THB Bn)

Gas Production/Consumption vs Real GDP

Supplementary 1.3 / 7

28

Project NameNon-FTA1 Capacity

BCF/D

1) Sabine Pass 2.20

2) Freeport 1&2 1.80

3) Cove Point 0.77

4) Lake Charles 2.00

6.77 BCF/D or 51.5 MTPA

4

Henry Hub Gas PricesUS LNG Export Facilities

21

3

Remarks: 1) Non-Free Trade Agreement with the United States of America

2)US Department of Energy, 3) US Federal Energy Regulatory Commission

2.5

3

3.5

4

4.5

5

5.5Historical HH Price NYMEX HH Gas Futures

$/MMBTU

• Unusually cold and long winter caused a spike in HH

Natural Gas Prices.

• HH NYMEX futures implies weather effects are

temporary; and support production growth to restore

inventories.

• ~$4.50-5.50/mmbtu provides sufficient economic

incentives.

• US LNG export capacity to non-FTA countries submitted

for approval ~ 342.5 MTPA

Awarded non-FTA export license

Awarded non-FTA export license and FERC approval

• DOE2 approved capacity for export to non-FTA countries

~ 51.5 MTPA

• FERC3 approved capacity for construction of export terminal

~16.7 MTPA

Progress of US LNG export facilities will impact international gas price parity,

Henry Hub futures indicate rebased gas prices from ~$3/mmbtu to ~4/mmbtu

LNG Pricing and Henry Hub

Source : International Energy Agency (IEA), NYMEX

Supplementary 1.4 / 7

29

-

500

1,000

1,500

2,000

2,500

3,000

3,500

4,000

4,500

5,000

North American Liquid Pipeline ProgressBottleneck to be resolved with additional pipeline capacities

Northern Gateway(Enbridge)

+525 KBPD, in 2017

Energy East(TransCanada)

+850 KBPD, in 2017 - 2018

Keystone XL(TransCanada)

+830 KBPD, in 2016-2017

TransMountain(Kinder Morgan)

+590 KBPD, in 2017

Alberta Clipper Expansion(Enbridge Line 67)

+350 KBPD, in 2015 - 2016

Western Canadian Refineries

Existing Pipelines

Rail Capacity

Alberta Clipper Expansions

Keystone XL

Northern Gateway

Trans Mountain Expansion

Trans Canada Energy East

Heavy Crude Supply and Takeaway Capacity

from West CanadaExpected North American Pipeline Expansions

‘000 BPD

• Majority of pipeline expansions expected to be

operational by 2017-2018, subject to regulatory

approvals.

• Additional pipeline capacity will support future

oil sands production start-ups

Sources: US DOE, Canadian Association of Petroleum Producers, Company Research Sources: US DOE, Canadian Association of Petroleum Producers, Company Research

West Canadian

Heavy Crude Supply

Supplementary 1.5 / 7

30

2013 Awards and Recognitions

Accolades of excellence in operations and management from accredited institutions

Financial ExcellenceManagement Excellence

NACC Integrity AwardThe National Anti-Corruption

Commission (NACC)

Board of the Year AwardsThai Institute of Directors Association

Top Corporate Governance Awards(The Stock Exchange of Thailand)

Best Managed Company in Thailand

and in Asia Oil & Gas(Euromoney Magazine)

Asia’s Best CSR Award(The Corporate Governance Asia)

2013 Best Public Company in

Resources Industry(Money and Banking Magazine)

Honorary Outstanding Achievement in

CSR Excellence(Thailand Management Association)

Best Secondary Offering Award

Prestigious Platinum Corporate Award(The Asset Magazine)

Best Secondary Deal of the Year(The Alpha Southeast Asia)

Thailand Capital Markets Deal Award(IFR Asia)

Best Investor Relations – Energy Sector(IR Magazine)

Best Investor Relations Company(The Corporate Governance Asia)

Supplementary 2 / 7

31

2014 Key Exploration Activities

South East Asia exploration and appraisal drilling is the key theme

2013(Actual)

2014

International Domestic

~ 7065

Planned Drilling (# wells)

Continue exploring marginal areas to

maintain domestic production

Expand resources base through

rigorous international exploration

Explore frontier areas to better

understand their potentials

Thailand

Over 30 wells planned to find

more potential and extend

development areas in :

S1, Bongkot, Arthit, MTJDA

Myanmar

Over 15 wells planned in one of the

most important growth areas

- Zawtika appraisal

- Myanmar M3 appraisal

- Seismic and G&G of other areas

Australia

2 wells planned to firm up resources

potential from previous discoveries

- Cash / Maple

- Other exploration areas

Mozambique

and Kenya

Over 10 wells planned in

- Mozambique Rovuma Offshore Area 1

- Mozambique Onshore

- Kenya exploration projects

Algeria

Approximately 3 wells planned in the

exploration program through 2014-15

in Hassi Bir Rakaiz

Planned Exploration Budget

765MMUSD

Approximately 40% of

prior year net profit is

allocated to exploration

and appraisal

Remark : Exploration and appraisal wells does not include Canada Oil Sands project

Supplementary 3 / 7

Content ceiling cut-off

Conte

nt w

idth

cut-o

ffConte

nt w

idth

cut-

off

PTTEP Project Information (1 / 5)

* Sales volume stated at 100% basis

Project PTTEP’s

Share

Partners 2013 Average Sales Volume * 2014 Key Activities

Gas Oil and Other

Production Phase

Thailand

1 Arthit 80% Chevron

MOECO

16%

4%

223 MMSCFD

Condensate: 9.3 k BPD

- Ensure gas deliverability level above 220 MMSCFD

Drill Exploration/Appraisal wells

2 B6/27 60% JX NOEX 40% N/A N/A Drill Exploration/ Appraisal wells

3 B8/32 & 9A 25% Chevron

MOECO

KrisEnergy

PSTL

51.66%

16.71%

4.63%

2%

103 MMSCFD Crude: 25k BPD Drill Development wells

4 Bongkot 44.4445% TOTAL

British Gas

33.3333%

22.2222%

889 MMSCFD

Condensate: 32 k BPD

- Drill Exploration / Appraisal / Development wells

5 Contract 3

(Unocal III)

5% Chevron

MOECO

71.25%

23.75%

641 MMSCFD

Condensate: 19 k BPD

Crude: 26k BPD Drill 1 Exploration well / Development wells

6 Contract 4

(Pailin)

45% Chevron

Hess

MOECO

35%

15%

5%

376 MMSCFD

Condensate: 16k BPD

- Drill Exploration / Appraisal / Development wells

7 E5 20% ExxonMobil 80% 13 MMSCFD -

8 G4/43 21.375% Chevron

MOECO

PSTL

51%

21.25%

6.375%

2 MMSCFD Crude: 4.7k BPD Drill Exploration / Development wells

9 G4/48 5% Chevron

MOECO

71.25%

23.75%

8 MMSCFD Crude: 1.8 k BPD

10 L53/43 &

L54/43

100% - Crude: 179 BPD Drill Exploration/ Appraisal wells

11 PTTEP 1 100% - Crude: 329 BPD

12 S1 100% 26 MMSCFD Crude: 33k BPD Maintain production level above 30,000 BPD

Continue Exploration activities

13 Sinphuhorm 20% Hess

Apico

ExxonMobil

35%

35%

10%

88 MMSCFDCondensate: 382 BPD

- Drill 1 Development well

14 MTJDA 50% Petronas-

Carigali

50% 321 MMSCFD

Condensate: 8.2 k BPD

- Maintain gas deliver performance to meet DCQ at 335

MMSCFD

Continue Development activities

Supplementary 4.1 / 7

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PTTEP Project Information (2 / 5)

• Sales volume stated at 100% basis

Project PTTEP’s

Share

Partners 2013 Average Sales Volume * 2014 Key Activities

Gas Oil and Other

Production Phase

Overseas

15 Oman 44 100% 38 MMSCFD

Condensate:

3.1k BPD

- Drill Exploration / Appraisal wells

Maintain production rate

16 Vietnam 9-2 25% PetroVietnam

SOCO

50%

25%

14 MMSCFD Crude: 5.5k BPD Drill 1 Development well

17 Yadana 25.5% TOTAL

Chevron

MOGE

31.24%

28.26%

15%

765 MMSCFD - Drill 1 Exploration well

3D Seismic acquisition of 3,335 sq.km.

18 Yetagun 19.3178% Petronas-

Carigali

MOGE

Nippon Oil

PC Myanmar

(Hong Kong)

30.00140%

20.4541%

19.3178%

10.90878%

399 MMSCFD

Condensate:

9.7 k BPD

- Drill 2 development wells

19 Vietnam 16-1 28.5% PetroVietnam

SOCO

OPECO

41%

28.5%

2%

35 MMSCFD Crude: 42.5 k

BPD

Drill 1 Development wells

H5 development Sanction expected in Q2 2014

20 PTTEP Australasia

(PTTEP AA)

20%-100%

(varied by

permits)

- Crude: 2.7 k BPD Drill 2 Exploration wells: Dillion South-1 and Maple

East-1

21 Natuna Sea A 11.5% Premier Oil

KUFPEC

Petronas

Pertamina

28.67%

33.33%

15%

11.5%

N/A N/A

Supplementary 4.2 / 7

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Project PTTEP’s

Share

Partners 2014 Key Activities

Development Phase :

Thailand

22 L22/43 100% Drill 3 Exploration wells

Fabrication and installation of Wellhead production facility

Overseas

23 Algeria 433a & 416b

(Bir Seba)

35% PetroVietnam

Sonatrach

40%

25%

Drill 4 Development wells

Continue Engineering, Procurement & Construction (EPC) work

First oil expected in the end of 2014

24 Myanmar Zawtika

(M9 & a part of M11)

80% Myanma Oil and Gas

Enterprise (MOGE)

20% Continue development activities

First gas expected in Q1 2014

Daily contractual quantity at 300 MMSCFD (80% to Thailand and 20% to

Myanmar)

Project PTTEP’s

Share

Partners 2014 Key Activities

Exploration Phase

Thailand

25 A4, 5 /48 100% G&G Studies

26 G9/43 100%

27 L28/48 70% Resourceful Petroleum

(Thailand)

30% To P&A Ratana-1 and Ratana-2 well

Oversea

28 Myanmar M3 80% MOECO 20% Drill 8 Appraisal wells (Q3 2014 – Q2 2015)

29 Mozambique Rovuma

Offshore Area 1

8.5% Anadarko, Mitsui,

ENH, Bharat Petroleum,

ONGC & Oil India

ONGC

26.5%,20%

15%,10%,

10%

10%

Drill 6 Exploration and 2 Appraisal wells

Complete FEED / FID for Mozambique LNG Project

PTTEP Project Information (3 / 5)

Supplementary 4.3 / 7

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PTTEP Project Information (4 / 5)

Project PTTEP’s

Share

Partners 2014 Key Activities

Exploration Phase

Overseas (con’t)

30 Algeria Hassi Bir

Rekaiz

24.5% CNOOC

Sonatrach

24.5%

51%

Drill 2 Exploration and 4 Appraisal wells

Studies and FDR Preparation

3D seismic acquisition of 1,200 sq.km

31 Indonesia Semai II 28.33% Murphy

INPEX

PT Pertamina Hulu Energi

Semai II

28.33%

28.33%

15%

Drill 2 Exploration wells

G&G Studies

32 Indonesia South

Mandar

34% Talisman

TOTAL

33%

33%

Negotiation with Total (Operatorship transfer & Carry cost)

33 Indonesia Malunda 100% Conduct new 3D seismic over the new oil plays

Continue divestment effort

34 Myanmar M11 45% TOTAL

JX NOEX

40%

15%

G&G Studies

35 Vietnam B & 48/95 8.5% Chevron

MOECO

PVEP

42.38%

25.62%

23.5%

Negotiate a GSA with the Vietnamese government

36 Vietnam 52/97 7% Chevron

PVEP

MOECO

43.4%

30%

19.6%

Negotiate a GSA with the Vietnamese government

37 Myanmar

PSC-G and EP-2

90% WinPreciousResources 10% Drill 4 Exploration wells

38 Mozambique

Rovuma Onshore

10% Anadarko, Maurel&Prom,

ENH, Wentworth Resources

35.7%,27.7%

15%,11.6%

Drill 3 Exploration wells

Acquire 2D seismic acquisition over Tembo prospect area

39 Kenya L10A

Kenya L10B

31.25%

15%

BG, Pan Cont.

BG, Premier, Pan Cont.

50%,18.75%

45%,25%,15%

Conduct G&G studies

Drill 1 Exploration well in Block L10A and 1 Exploration well in Block L10B

3D seismic acquisition of 2,000 sq.km.

40 Kenya L5, L7, L11,

L11B, L12

10% Anadarko, Total 50%,40% Drill 1 Exploration well in Block L11B

Conduct G&G Studies

41 Myanmar MD 7 and

MD 8

100% 2D seismic acquisition and processing

42 Canada

Oil Sands (THSL)*

100% Pre-FEED for the first production phase of the Thornbury field

Preparation for seismic acquisition and drilling campaigns scheduled for

2014-2015.

* Subject to the customary conditions precedent to closing as prescribed in the Partnership Unit Redemption Agreement (PURA)

Supplementary 4.4 / 7

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PTTEP Project Information (5 / 5)

Project PTTEP’s

Share

Partners Key Activities

Australia WA-423-P 30% Murphy

Diamond Resources

40%

30%

Completed the relinquishment of permit in 1Q 2013

Cambodia B 33.33% Resourceful Petroleum

SPC

33.33%

33.33%

Completed the relinquishment of permit in 4Q 2013

PTTEP projects relinquished during 2013

PTTEP projects waiting for official withdrawal approval

Project PTTEP’s

Share

Partners Key Activities

Indonesia Sadang 30% Talisman

TOTAL

40%

30%

Indonesia South

Sageri

20% Talisman

TOTAL

35%

45%

New Zealand

Great South

18% Shell

OMV

Mitsui E&P

50%

18%

14%

Supplementary 4.5 / 7

37

Corporate Social ResponsibilityCommitted to Sustainable Development through Environmental Conservation and Community

Development everywhere we operate

LEGEND

Cultural Heritage Preservation5 Sites; e.g. Khao Yai, Kampaeng Phet

Marine Habitat RestorationArtificial Reefs, Fisheries

Environmental & Reforestation Projects

In Thailand : 200,000 rais between 2013-2020

Promotion of EducationScholarships, Mobile Libraries, Tutor Camps

Promotion of Health, Hygiene, & Social NeedsHealth Stations, Hospital Renovations, Utilities Improvement

Myanmar

Canada

Australia

Oman

Thailand

Supplementary 5 / 7

38

Corporate StructureBoard of Directors and several committees to ensure transparency and integrity

Nominating Committee

Remuneration Committee

Risk Management Committee

President and CEO

Strategy and

Business

Development

Group

Geosciences

and

Exploration

Group

Engineering

and

Development

Group

Operations

Support Group

Technology

and

Sustainability

Development

Group

Human

Resources and

Business

Services Group

Finance and

Accounting

Group

Domestic

Asset Group

International

Asset

Group

Office of President

and CEOLegal Division

Corporate

Secretary OfficeInternal Audit

Department

Board of Directors

Corporate Governance Committee

Audit Committee

Supplementary 6 / 7

39

Ratio Formula

Ratio Formula

Lifting Cost ($/BOE)(Operating Exp. – Transportation Cost – Stock Variation – Other expense not related to lifting) / Production

Volume

Cash Cost ($/BOE) (Operating Exp. + SG&A + Royalty & SRB) / Sales Volume

Unit Cost ($/BOE) (Operating Exp. + Exploration Expense + SG&A + Royalty + DD&A) / Sales Volume

F&D Cost ($/BOE) (5 –Yr Avg. of Acquisition + 5-Yr Avg. of (Expl.+ Dev. Cost )) / 5 – Yr Avg. of additional reserves

Organic F&D Cost ($/BOE) 5-Yr Avg. of (Expl.+ Dev. Cost )) / 5 – Yr Avg. of additional reserves excluded 5 –Yr Avg. of Acquisition

Reserves Replacement Ratio 5-Yr Additional Proved Reserves / 5-Yr Production Volume

Reserves Life Index (Year) Proved Reserves / Production Volume

Success Ratio Number of wells with petroleum discovery / Total number of exploration and appraisal wells

EBITDA(Sales + Revenue from pipeline transportation) - (Operating expenses + Exploration expenses +

Administrative expenses + Petroleum royalties and remuneration + Management's remuneration)

EBITDA Margin EBITDA / Sales Revenue

Return on EquityTrailing-12-month net income / Average shareholders' equity between the beginning and the end of the 12-

month period

Total Interesting Bearing DebtShort-term loans from financial institution + Current portion of long-term debts + Bonds + Long-term loans

from financial institution

Total Debt to Equity Ratio Total interest bearing debt/ Shareholders' equity

Total Debt to EBITDA Ratio Total interest bearing debt / Trailing-12-month EBITDA

Dividend Payout Ratio Dividend Payment / Net Profit

Supplementary 7 / 7