Corporate_Presentation_April_2013

Corporate Presentation 

April 2013 

© Coastal Energy Company 2012 | All Rights Reserved

Forward Looking Statements 

This presentation contains ‘forward-looking statements’ as defined by the applicable securities legislation. 

Statements relating to current and future drilling results, existence and recoverability of potential hydrocarbon 

reserves, production amounts or revenues, forward capital expenditures, operation costs, oil and gas price 

forecasts and similar matters are based on current data and information and should be viewed as forward-looking 

statements. Such statements are NOT guarantees of future results and are subject to risks and uncertainties 

beyond Coastal Energy’s control. Actual results may differ substantially from the forward-looking statements. This 

presentation does not contain all of the information contained in the preliminary prospectus of Coastal Energy 

Company, which should reviewed for complete information. 

Corporate Presentation April 2013 

2

Company Overview 

Operational Overview Asset Overview 

Production 

Current Production (boepd) 25,500 

Offshore Production (oil) 23,000 

12/31/2012 RPS Reserves 1 

2P (Mmboe) 144.3 

% Oil 84% 

Increase vs. YE 2011 2P 40% 

After-Tax 2P PV-10 ($MM) $2,713.1 

Prospective Resources (Recoverable - Mmboe) 2 

(1) Per RPS Energy, Ltd. Reserve evaluation as of 12/31/2012 (2) Internal estimate - 

offshore only 

Financial Overview 

($US in millions, except shares / share price) 

Share Price (at 4/8/2013) C$18.60 

Shares Outstanding 113.6 

Shares Outstanding, Fully Diluted 118.3 

Equity Value / Market Cap. $2,200.3 

Debt (at 3/31/2013) $100.0 

Cash (at 3/31/2013) $55.0 

Enterprise Value $2,245.3 


486.6 

3

Investment Highlights 

Highly Prospective Inventory / 

Significant Asset Base 

Material Exploration Success 

During Past 2 Years 

Substantial 2013 Drilling Program 

Note: 2012 reserve figures per RPS Energy Ltd. report as of March 31, 2012; prospective resource volumes are undiscovered and represent internal estimates 


Opportunity to de-risk 660 Mmbbls unrisked oil-in-place by year-end 2013 

>30 identified prospects comprising 487 Mmbbls offshore prospective resources 

0.7 million acres in Gulf of Thailand; Malaysian RSC covering 3 fields 

Highly successful drilling program targeting shallow Miocene at Bua Ban North 

Added 56 Mmbbls 1P, 68 Mmbbls 2P in 2011 at Bua Ban North; +102% total 2P y/y 

Added 40 Mmbbls 2P & 85 Mmbbls 3P in 2012 

Two rigs running for entire year; approximately 60% development/40% 

exploration 

First oil expected in Malaysia in 2H2013 

Industry Leading F&D Costs 5-year F&D cost of $4.66/boe ($6.81/boe including facilities CapEx) 

Growing Oil Production Profile 

Strong Management and 

Shareholder Support 

Current production ~25,500 boepd, >80% offshore oil (+102% vs. 4Q11) 

33,000 boepd 2013 guidance (+50% y/y) 

Highly incentivized management team and employees 

30% of outstanding shares owned by management and founding shareholders 

4

Field Overview 


Offshore Thailand 

Bua Ban North 

Booked 68 Mmbbl 2P in 2011; added 40 Mmbbl 2P at 3/31/2012 

To test 70 Mmbbl of prospective resources in 2013 

Bua Ban South 

Songkhla 

Onshore 

Pilot fracking program was successful and two frac wells are 

onstream 

56 mmbbl of prospective resources at Bua Ban South 

34 mmbbl Miocene and 22 mmbbl tight sands 

Appraisal & exploration of 89 Mmbbls of prospective resources in 

Songkhla area 

Sinphuhorm gas field current production ~2,500 boepd 

15-year Gas Sales Agreement with Nam Phong power plant 

Dong Mun discovery being evaluated for development 

10 Mmboe contingent resources 

5

(Mmboe) 

Substantial Organic Reserve Growth 

800 

700 

600 

500 

400 

300 

200 

100 

0 

51.0 


144 Mmboe 2P reserves at 12/31/2012 (84% oil/offshore, 53% 1P)* 

Near-term drilling program could result in significant additional uplift 

Opportunity to de-risk ~660 Mmbbls of unrisked oil-in-place through 

year-end 2013 

*Per RPS Energy, Ltd. Reserve evaluation as of December 31, 2012 

Note: Offshore prospective resources reflect internal estimates 

102.8 

2P YE 2010 2P YE 2011 2P Bua Ban 

North Addition 

27.3 6.7 7.4 

2P Bua Ban 

South Addition 

144.2 

Other 2P 

YE2012 

51.9 

3P 

YE2012 

10.0 

484.8 

Contingent Prospective 

6

Track Record of Consistent Growth 

(Boepd) 

Production Growth EBITDA Growth 

35,000 

30,000 

25,000 

20,000 

15,000 

10,000 

5,000 

0 

2013 production expected to average 33,000 

27,000 boepd offshore Thailand, 2,300 onshore Thailand, 3,700 boepd Malaysia (3Q commencement) 


2008 2009 2010 2011 2012 2013 

Est. 

Onshore Offshore Malaysia 

($US MM) 

1,000 

900 

800 

700 

600 

500 

400 

300 

200 

100 

0 

2008 2009 2010 2011 2012 2013 

Est. 

Note: See EBITDA sensitivity slide for 2013 potential outcomes 

$120/bbl 

$80/bbl 

7

Shares at Discount to 1P & 2P NAV 

$25.00 

$20.00 

$15.00 

$10.00 

$5.00 

$0.00 


$2.03 

$21.13 

$0.00 

$19.00 

Net Asset Value Share Price 

Offshore 2P Onshore 2P 

8

2013 EBITDAX Sensitivity 


Note: Assumes 2013 guidance of 33,000 boepd, $19/boe OpEx and $315 MM capital program 

9

Drilling Sequence 


Rig Mar-13 Apr-13 May-13 Jun-13 Jul-13 Aug-13 Sep-13 Oct-13 Nov-13 Dec-13 Jan-14 Feb-14 

Vicksburg 

Manta 

Songkhla 

Development 

G5/43 EXPL 

Songkhla M 

Bua Ban North 

Development & 

Appraisal 

G5/50 EXPL Well 

Bua Ban Main 

Sidetrack Wells 

(Fracs) 

MOPU required 

Malaysia Appraisal Drilling 

Bua Ban South Appraisal 

8 Wells 

MOPU required 

Songkhla H 

Development 4 

Wells 

Exploration Development 

Workover / Completion Appraisal 

G5/43 EXPL Bua 

Ban North Terrace 

G5/43 EXPL Bua 

Ban Terrace 

Bua Ban North Development 8 

Wells 

G5/43 EXPL 

Benjarong South 

Water Disposal 

/Injection 

Note: HWU = hydraulic workover unit 

10

Industry Leading F&D Costs 

F&D Cost ($/boe) 

F&D Cost ($/boe) (Including Facilities CapEx) F&D Cost ($/boe) (Excluding Facilities CapEx) 

$7.00 

$6.80 

$6.60 

$6.40 

$6.20 

$6.00 

$5.80 

Robust 2013 Drilling Program 

($US MM) 

Drilling & Completions 

2013 % 

Offshore Thailand 153 18% 

Onshore Thailand 21 nm 

Malaysia 42 nm 

Facilities 81 (50%) 

Seismic 7 (82%) 

Other 10 (46%) 

Total 315 (13%) 


2013 FCF of $200 MM post CapEx and taxes 

at $100 realized oil price 

2013 CapEx budget of $315 MM ~13% below 

2012 due to substantially lower facilities 

expenditures while including a 2 rig program 

Two MOPUs 

1 for Thailand and 1 for Malaysia 

Onshore CapEx focused on development 

activities at Dong Mun field 

12

Thailand Exploration

Exploration Overview 

Prospective resource inventory of 486.6 mmbbl 

Substantial prospective resources to be tested in Q213 


Songkhla M – 12.7 mmbbl (recoverable) 

Bua Ban Terrace A – 32.7 mmbbl (recoverable) 

G5/50 – 23.7 mmbbl (recoverable) 

Bua Ban Terrace – 105.5 mmbbl (recoverable) 

Additional exploration upside at producing fields 

Bua Ban North - 67.5 mmbbl of prospective resources (recoverable) 

Bua Ban South – 55.9 mmbbl of prospective resources (recoverable) 

Songkhla Basin has significant upside 

Recent 3D seismic survey being processed 

Survey covers entire Songkhla basin as well as the G5/50 exploration block 

Initial data quality is excellent 

Data have already produced new leads and structures and initial mapping is in progress 

Onshore Exploration 

Dong Mun gas discovery (10 mmboe net to Coastal) 

Commerciality study has been approved 

Expected to begin production in 2015 

Q2 13 

H2 13 

14

Highly Prospective Songkhla Basin 

Bua Ban Terrace 


Bua Ban North 

Bua Ban South 

Songkhla J 

(Buried Hill II) 

Benjarong South 

(Songkhla N) 

Songkhla H 

Songkhla L 

Songkhla M 

Songkhla A 

Extensions 

Prospects 

Eocene 

Lower 

Oligocene 

Lower 

Miocene/ 

Up Oligocene 

Pre-Tertiary 

Buried Hill 

Fields 

Eocene 

Lower 

Oligocene 

Lower 

Miocene 

Note: Prospective resource volumes are undiscovered resources and represent internal estimates 

15

Songkhla M Lead 

Time Structure : Upper Oligocene 

Jerry’s Modifications

Terrace Prospects 

A 


B’ 

B 

A’ 

Top Eocene Map 

EAST TERRACE A 

PROSPECT 

Miocene (600 acres) 

and 

Eocene (2700 acres) 

Primary Objectives 

B 

EAST TERRACE A 

A A’ 

Eocene 

EAST TERRACE A B’ 

M50 

Eocene 

M50 

17

Bua Ban South Field 


Stratigraphic limit of M100 

net sand 

No Miocene oil water contact encountered yet 

Could be materially lower than current depths 

A-06 well will test eastern boundary 

47 Mmbbls prospective resources (recoverable) 

21 Mmbbls associated with fracking success 

Fracking of BBS 1 & 3 was successful 

Booked 6.7 Mmbbls 2P, 13.7 Mmbbls 3P reserves at 

12/31/2012 

All associated with Miocene 

A-04 and A-05 wells encountered Miocene pay in same 

reservoir as Bua Ban Main A-11 

18

Bua Ban South Pilot Fracturing Program 


Bua Ban South A-01 and A-03 were successfully fracked in Q113 

A-01 A-03 

Interval Lower Oligocene Eocene 

Stabilized IP Rate (bopd) 450 bopd 1,450 bopd 

EUR (mmbbl) 0.19 0.39 

IRR (@ $100 / bbl realized) 65% 163% 

PV10 ($mm) $5.4 $15.9 

PV10 / bbl $28.61 $44.14 

With further optimization, results can improve while bringing 

fracturing costs down 

Substantial resources to be exploited in tight sands in Songkhla 

basin 

Recoverable Oil Assuming 10% Recovery Factor 

Songkhla 3.3 MMBO 

Bua Ban North 3.5 MMBO 

Bua Ban Main & South 23.2 MMBO 

Total: 30.0 MMBO 

19

A 

Songkhla Basin Miocene Trend 


A’ 

20

Songkhla N (Benjarong) Prospects 

Lower Miocene M200 Time Structure 

20 ms contour interval 


M200 A 

M200 B 

M200 C 

Multiple stacked structural targets in: 

Lower Miocene 

Upper Oligocene 

Lower Oligocene 

Eocene 

21

Songkhla N (Benjarong) Prospects – Dip Line 

Time (sec) 

west 

colored inversion 


M200 A 

1000 m 

Bua Ban North Field 

east 

M050 

M075 

M200 

U Olig marker 

22

Preliminary Results of New 3D Seismic 

Fractured 

Basement 


4-way Fault 

Closures 

Fractured Basement 

Stratigraphic 

Pinch-outs 

23

New Plays Along Basin Margins 

Terrace Play 

Asri Sub-Basin, Indonesia 

300 MMBO in basin 

margin ramp/strat play 


Bua Ban North 

Original 3D Limit 

Songkhla A 

Miocene Ramp Play 

Oligocene 

Strat Play 

24

Malaysian Risk Service Contract

Background 


Coastal entered into a Risk Service Contract with 

PETRONAS for the development of the Kapal, 

Banang and Meranti fields (KBM) offshore 

Peninsular Malaysia 

Coastal is a 70% partner and a local Malaysian 

contractor is a 30% partner 

The contract requires the drilling of 17 wells: 10 

wells at Kapal, 4 wells at Banang and 3 wells at 

Meranti 

Once the wells are drilled, Coastal will operate the 

production facilities and coordinate oil liftings, 

operating cost disbursements, etc. 

There are existing discoveries at each field. 

Coastal estimates recoverable oil could be 

anywhere from 15 to 35 Mmbbl 

Additional upside from exploration prospects 

26

Overview of Terms 

The contract duration is 8 years ; the KBM SFRSC model strikes a balance in sharing of risks 

with fair returns for development and production of already discovered fields 

PETRONAS remains the project owner while Contractors (Coastal and partners) are the service 

provider 

Contractor will incur upfront costs for Petroleum Development and Operations and will be 

reimbursed upon first commercial production; the contractor will also be entitled to a 

Remuneration Fee per barrel from a pre-determined percentage of the field revenue 

The reimbursement and remuneration are tied to cost and production performances; priority of 

payment shall be cost reimbursement of CAPEC and OPEX, followed by Remuneration Fee 

Contractors are subjected to the Corporate Income Tax Act (CITA) and not the Petroleum 

Income Tax Act (PITA). Corporate tax payable by the Contractor Group under CITA is at the 

prevailing rate of 25% 


27

Overview of Costs/Timeline 

First oil from Kapal field is expected 3Q13 

The Capital Expenditure (CAPEX) of KBM Cluster is estimated to be USD320 million over 3 years 

Coastal expects to fast track development of the fields using MOPUs and FSOs similar to how it 

has fast tracked development of its Gulf of Thailand assets 


28

Appendix

Further Exploration Potential 


Richest source facies in the Songkhla basin are found within the lower 

Oligocene balanced-fill lake phase, an extensive carbonate‐rich 

interval with analogies to the Qingshankou and Nenjiang source strata 

in the Songliao Basin of China 

Reservoirs associated with this lake type include lake marginal 

carbonate strata, lake marginal beach deposits, and deltaic facies that 

would tend to be restricted to the lake margin 

Source rock is currently sitting in oil window; start of oil window is 

estimated to be between 6,250 - 10,000 feet 

Thickness of source rock ranges from 77 feet to 300 feet in the center 

of the basin 

Total Petroleum System Evaluation 

Contour (ft) Acres Barrels of Oil (possible) 

Barrels Recoverable 

(assuming 10% recovery factor) 

10,000.00 17,078.73 19,877,199,359.56 1,987,719,935.96 

8,000.00 96,577.08 14,499,833,844.09 1,449,983,384.41 

6,250.00 88,006.43 13,213,058,545.69 1,321,305,854.57 

10,000 & 8,000 Total 3,437,703,320.37 

Total 4,759,009,174.94 

30

Bua Ban North 


Additional 63.0 mmbbl of prospective 

resources at Bua Ban North 

Discovered Oil 

Oil Well 

Prospect or development location M100 penetration 

point 

Interval wet 

Interval tight or absent 

31

Songkhla H Field 

Main Field 

Downthrown Closure 


• Songkhla H Development 

• 3 Oil Producers 

• 1 Water Injector 

• Exploration 

• Well Downthrown Closure 

• Reserve Exposure 14mmbbls STOOIP 

32

Dong Mun Field – Onshore Gas 


Likely Commercial Development 

Potential CNG for Natural Gas Vehicles 

53 km pipeline to Nam Phong 

24 Mmscfd gross from 4 wells (20 yrs) 

60 Bcf contingent (recoverable) net to 

Coastal’s 40% interest 

107.4 Bcf net incremental prospective 

resources (recoverable) 

Dong Mun-3st (1Q12) 

Confirmed G/W contact 

Improved reservoir 

Milestones 

Commerciality approval (DMF) by 1Q13 

Gas Sales Agreement by 2Q13 

EIA/ONEP Approval by 3Q13 

First Gas 4Q14 

33

Comparison Between Malaysia PSC and SFRSC 

* Petroleum Income Tax Act 

**Corporate Income Tax Act 


* 

** 

34

2013 Projected Tax 

Assumes production, expenses and capital program outlined in 2013 guidance 

Tax calculation includes Petroleum Income Tax and Special Remuneratory Benefit 


Realized Offshore Cash Tax Rate Effective Tax 

Crude Price EBITDAX ($MM) (Due in 2013) Rate 

$85.00 543.5 26.7% 45.5% 

$90.00 587.1 25.5% 48.1% 

$95.00 630.6 24.2% 50.6% 

$100.00 675.8 23.0% 53.0% 

$105.00 723.7 22.0% 54.6% 

$110.00 771.7 20.9% 56.5% 

$115.00 819.7 20.2% 57.6% 

$120.00 867.7 19.6% 58.6% 

Note: Tax rate expressed as a percentage of EBITDAX 

Cash tax rate reflects actual amounts due in 2013 and is inversely related to commodity 

prices given large proportion of fixed amounts related to 2012 taxes 

Effective tax rate reflects taxes incurred in 2013 and includes amounts payable in 2014 

35

Overview of Thailand Fiscal Terms

“Thai I” Regime (Onshore) 

12.5% royalty rate 

Petroleum Income Tax (PIT) assessed at 50% of taxable income (revenues – allowable 

deductions) 

Allowable deductions for PIT are as follows: 

Operating Expenditures 

Hedging Losses 

G&A expenses related to the petroleum operations 

Capital expenditures under the following depreciation rules 


o Pre-production intangibles are depreciated straight line over 10 years 

o Post-production intangibles are fully expensed in the year incurred 

o Tangibles are depreciated straight line over 5 years 

Royalties are not deductible; however, the operator receives a PIT credit for royalties paid, 

lowering the effective tax rate 

37

“Thai III” Regime (Offshore) 

Royalty payable on a sliding scale determined by monthly production volume (5 – 15%) 

Daily production of 25,000 bopd results in an approximate 11% royalty rate 

Petroleum Income Tax (PIT) assessed at 50% of taxable income (revenues – allowable 

deductions) 

Allowable deductions for PIT are as follows: 

Royalties 

Operating Expenditures 

Hedging Losses 

G&A expenses related to the petroleum operations 

Special Remuneratory Benefit (“SRB”) payments 

Capital expenditures under the following depreciation rules 


o Pre-production intangibles are depreciated straight line over 10 years 

o Post-production intangibles are fully expensed in the year incurred 

o Tangibles are depreciated straight line over 5 years 

38

Special Remuneratory Benefit (“SRB”) 

Designed as a “Windfall Profits Tax” for high oil price environments 

Assessed on a sliding scale basis determined by “Revenue per Meter Drilled” 

Petroleum Revenue is adjusted for inflation and exchange rate fluctuations since 

inception of the concession and then divided by total meters drilled on the concession 

Coastal’s offshore concessions provide a 600,000 meter “allowance” to be added to 

actual drilling footage 

Resulting metric determines the SRB rate (0 – 75%) 

Tax assessed on “Petroleum Profit” 

Allowable deductions are: Royalty, Hedging Losses, Capital Expenditures, Operating 

Expenses, G&A 

All Capex is expensed as incurred, with a special 35% “uplift” on facilities capex 

Allows for full capital recovery plus uplift 

Coastal had an approximate $165MM loss carryforward for SRB purposes at year end 2011 

SRB is deductible for PIT purposes 


39

Legal Disclaimer 

The information contained in this presentation (“Presentation”) has been prepared by Coastal Energy Company (“Company”) and is being delivered for informational purposes only to a limited 

number of persons to assist them in deciding whether or not they have an interest in investing in the Company. The Presentation has not been independently verified and the information contained in 

it is subject to updating, completion, revision, verification and further amendment. The Presentation does not purport to contain all information that a prospective investor may require. While the 

information contained in it has been prepared in good faith, neither the Company nor its shareholders, directors, officers, agents, employees, or advisors give, has given or has authority to give, any 

representations or warranties (express or implied) as to, or in relation to, the accuracy, reliability or completeness of the information in this Presentation, or any revision thereof, or of any other written 

or oral information made or to be made available to any interested party or its advisers (all such information being referred to as “information”) and liability therefore is expressly disclaimed. 

Accordingly, neither the Company nor any of its shareholders, directors, officers, agents, employees or advisers take any responsibility for, or will accept any liability whether direct, express or implied, 

contractual, torturous, statutory or otherwise, in respect of the accuracy or completeness of the information or for any of the opinions contained in, or for any errors, omissions or misstatements or for 

any loss, howsoever arising from the use of this Presentation. In furnishing this Presentation, the Company does not undertake or agree to any obligation to provide the recipient with access to any 

additional information or to update this Presentation or to correct any inaccuracies in, or omissions from, this Presentation which may become apparent. 

Information contained in this Presentation is confidential information and the property of the Company. It is made available strictly for the purposes referred to above. 

The Presentation and any further confidential information made available to any recipient must be held in complete confidence and documents containing such information may not be reproduced, 

used or disclosed without the prior written consent of the Company. This Presentation must not be copied, published, reproduced or distributed in whole or in part at any time without the prior written 

consent of the Company and by accepting the delivery or making to it of this Presentation, the recipient agrees not to do so and to return any written copy of this Presentation to the Company at the 

request of the Company. 

This Presentation should not be considered as the giving of investment advice by the Company or any of its shareholders, directors, officers, agents, employees or advisors. Each party to whom this 

Presentation is delivered or made must make its own independent assessment of the Company after making such investigations and taking such advice as may be deemed necessary. In particular, 

any estimates or projections or opinions contained in this Presentation necessarily involve significant elements of subjective judgement, analysis and assumption and each recipient should satisfy 

itself in relation to such matters. Neither the delivery or making of this Presentation nor any part of its contents is to be taken as any form of commitment on the part of the Company to proceed with 

any transaction and the right is reserved to terminate any discussions or negotiations with any prospective investors. In no circumstances will the Company be responsible for any costs, losses or 

expenses incurred in connection with any appraisal or investigation of the Company. 

This Presentation does not constitute, or form part of, any offer or invitation to sell or issue, or any solicitation of any offer to subscribe for or purchase any securities in the Company, nor shall it, or 

the fact of its delivery, making or distribution, form the basis of, or be relied upon in connection with, or act as any inducement to enter into, an contract or commitment whatsoever with respect to 

such securities. Any such solicitation or offer will be made by means of a prospectus to be issued by the Company in due course and any decision to subscribe for securities in the Company should 

be made solely on the basis of the information contained in such prospectus. 

The delivery, making or distribution of this Presentation in or to persons in certain jurisdictions may be restricted by law and persons who receive this Presentation should inform themselves about, 

and observe, any such restrictions. Any failure to comply with these restrictions may constitute a violation of the laws of the relevant jurisdiction. In particular, this Presentation has not been 

approved by an authorised person pursuant to Section 21 of the Financial Services and Markets Act 2000 (“FSMA”) and accordingly, it is being communicated in the United Kingdom only to persons 

to whom this Presentation may be communicated without contravening the financial promotion prohibition in Section 21 of the FSMA. Those persons are described in the Financial Services and 

Markets Act 2000 (Financial Promotion) Order 2005 (“Order”) and include persons who fall within the category of person set out in Articles 19 and 49 of the Order. Any investment activity to which 

this Presentation relates in the United Kingdom is available to, and will only be engaged with such persons and this Presentation should not be acted or relied upon in the United Kingdom by persons 

of any other description. This Presentation has not been approved as a prospectus by the UK Financial Services Authority (“FSA”) under Section 87A of the FSMA and has not been filed with the 

FSA pursuant to the United Kingdom Prospectus Rules. No offer of securities in the Company is being or will be made in the United Kingdom in circumstances which would require such a prospectus 

to be prepared. 

The securities proposed to be issued by the Company (the "Common Shares") have not and will not be registered under the U.S. Securities Act of 1933, as amended (the "Securities Act") and may 

not be offered or sold in the United States except pursuant to an exemption from, or transactions not subject to, the registration requirements of the Securities Act. In addition, other than to a limited 

number of persons reasonably believed to be qualified institutional buyers (as defined in Rule 144A under the Securities Act), neither this Presentation nor any copy of it may be taken or transmitted 

into the United States or America or distributed directly or indirectly, in the United States of America or to any resident thereof except in compliance with the applicable U.S. securities laws. Any 

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By accepting this Presentation, the recipient represents and warrants that it is a person to whom this Presentation may be delivered or distributed without a violation of the laws of any relevant 

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40

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