Hongkong: 1-2 March 2007 Singapore: 5-6 March 2007
Transcript of Hongkong: 1-2 March 2007 Singapore: 5-6 March 2007
Presentation to Investors
Thai Oil Public Company Limited
Arranged by Citibank, N.A.Hongkong: 1-2 March 2007Singapore: 5-6 March 2007
2
DisclaimerDisclaimer
The information contained in this presentation is intended
solely for your personal reference. Please do not circulate
this material. If you are not an intended recipient, you
must not read, disclose, copy, retain, distribute or take any
action in reliance upon it.
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Corporate Vision, Mission and ValueCorporate Vision, Mission and Value
TOP seeks to be one of the leading fully integratedrefining and petrochemical companies in the region
recognized for our sustainable growth, optimum stakeholder value, and commitment to environmental
and social well-being.
Vision
• To be PTT’s flagship refinery through optimized management of the group’s refining portfolio
• To expand facilities to better meet domestic demandgrowth
• To enhance the competitive advantage of our power generation operations to further solidify the core refining business
• To create a high-performance organization that promotes teamwork, innovation and trust
Mission
P = ProfessionalismO = Ownership & CommitmentS = Social ResponsibilityI = Integrity
T = Teamwork and CollaborationI = Initiative
V = Vision FocusE = Excellent Striving
Value
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ContentsContents
• Company Overview
• Business Outlook
• Progress of Investment Projects
• Consolidated Financial Performance
5
PTT Group 80%
Thai Lube Base
(TLB)
9%55%
SPP program3-on-1 Combined cycleElectricity 118 MWSteam 168 T/hrUtility Supply to Group
IPP program2-on-1 Gas-fired,Combined cycleElectricity 700 MW
Related Business & Earnings Stability
Thai Paraxylene
(TPX)
Capacity: Current: 348 KTA (PX)
72 KTA (MX)
Q4/07: 900 KTA (Total)489 KTA (PX)177 KTA (Bz)144 KTA (To) 90 KTA (MX)
Capacity: Lube Base oil: 270 KTA
A fleet of 5 oil & petrochemical vessels with int’l classifications
Total capacity: approx 30,000 DWT
Multi-product Pipeline Capacity: 26,000 mn. Litres/Y.
PTT 20% TOP 24%
100%
56%
100% 100%
Capacity: Current: 225 Kbd
Refinery Petrochem/Lube Base Oil
Power/Renewable Energy Transportation / Others
PTT 26% J-Power 19%
Q4/07: 275 kbd
20%
Thaioil
(TOP)
Independent Power
(Thailand) (IPT)
Thaioil Power
(TP)
Thaioil Marine
(TM)
Thappline
PTT ICT Solutions
(PTT ICT)
30% Maesod Clean
Energy
Mitr Phol Group 35% Padaeng 35%
Sugar Cane Based Ethanol
Q1/09: 0.1 mn. L/D
Core Refining Operations Value Enhancement Product Marketing / IT Support
PTT 31% Others 60%
Plat 1.8 MTA
TOP’s Group StructureTOPTOP’’ss Group StructureGroup Structure
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TOP – One of Region’s Leading RefineriesTOP TOP –– One of RegionOne of Region’’s Leading Refineriess Leading Refineries
Gulf of Thailand
Total Refining Capacity = 1,042 kbd
ESSO (170 kbd)
IRPC (150+65 kbd)
BCP (120 kbd)
SPRC (150 kbd)RRC (145 kbd)
TOP (225 kbd) (275 kbd) PTT’s Flagship Refinery
Bangkok
RPC (17 kbd)
Nationally: • Largest, most complex & highly integrated. • The flagship refinery of the PTT group.
• Advantageous site location (120 km east of Bangkok) –Close to the market.
• Highly capable and experienced management / staff.
Source: PTIT Focus Special Annual Report 2004, except for capacity figure for RRC (based on RRC Offering Memorandum)
Regionally:• One of the most complex in the region with TCU, HCU,
FCCU, CCR and ISOM.
• High operational flexibility from multiple-unit configuration.
• High complexity ratios (Oil & Gas Journal / Nelson Index – 8.6).
• Top-ranked performance according to Shell’s and Solomon’s benchmarking exercise:
• High efficiency / utilization• Low cash operating cost
Well diversified earnings through significantly increase in subsidiaries’ contributions.
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2006 Key Highlights 2006 Key Highlights
• Successfully increased refining capacity by 5 kbdto 225 kbd from synergy project with TLB.
• Maintained high utilization of Refinery, TPX and maximized lube base production (after 1st major turnaround and by co-processing Hydrocrackerbottom).
• Maintained high integrated Refinery / TPX / TLB margin through joint production planning, cooperation within PTT group, products diversification and margin improvement program:-
• Collaborated with PTT / RRC / IRPC for crude sourcing and delivery, thereby reduced freight costs,
• Maximized jet production / export at the expense of diesel during flooding in Thailand,
• Increased overall margin ~ US$ 0.50/bbl through Hydrocarbon Management Review (HMR) and other activities.
• Repaired & reinstalled transformer 2 months ahead of plan and received satisfactory insurance compensation (BI of Bt. 328 mn. & PD of Bt. 66 mn.).
Operation & Commercial Investment
• All approved major projects progressed as planned.
• Engaged PMC for 500,000 L/D ethanol plant (cassava-based) with an aim to complete project specification and detailed cost estimate by Q2/07.
• Signed JV agreement with PDI and Mitr Phol to study & develop 100,000 L/D ethanol plant (based on sugar cane) at Maesod, Tak to diversify feedstock sources.
Finance• Paid annual dividend of Bt 3.50/share (40% payout
vs. min. stated 25%) & 1st interim dividend of Bt. 1.50/share.
• Diversified sources of funds by issuing inaugural THB bond of Bt. 5,500 mn. (AA- Fitch’s) & Cross Currency Swap to US$.
• Successfully negotiated to reduce cost of existing domestic syndicated loans by ~ 1.375% or Bt. 72 mn./yr.
• Prepaid, repaid & refinanced loans, thus lowering interests by ~ Bt. 134 mn. in 2006.
8
TOP GroupTOP Group’’s Integrated Margin s Integrated Margin
4.65
10.62
2.70 1.51
6.62 4.96
1.82
1.57
2.862.19
2.090.24 0.641.530.81
0.87
0.38
0.54
Q1/06 Q2/06 Q3/06 Q4/06 FY/05 FY/06
TOP Acct GRM TPX TLB
7.00
12.56
4.57
7.69
Integrated Margin (US$/bbl)
6.37
-8%• TOP’s integrated refinery & petrochem
operations lead to increased and more stable margins.
• Group’s integrated margin stood at $7.69/bbl, 8% reduction vs. 25% drop of GRM.
8.39
PX – ULG 95
Plat
+42%
402 398
732575
371527403 399
733
576
Q1/06 Q2 Q3 Q4 FY/05 FY/06
(US$/T)
LB - HSFO 480 525623 687
579331
481 526624
688
Q1/06 Q2 Q3 Q4 FY/05 FY/06
+75% (US$/T)L/R
Crude GRMOil Products
-25%(US$/bbl)
2.701.51
6.624.96
10.62
4.65 Mrk. Mrg.Stock G/(L)
Q1/06 Q2 Q3 Q4 FY/05 FY/06
9
Financial HighlightsFinancial HighlightsEBITDA & Net Profit from Operation by Quarters Net Profit from Operation by Sectors – FY/05 & FY/06
Bt. 16,647 mn.Bt. 15,948 mn.
+4%
Refinery 61%
PX23%
LB10%
Power6%
FY/05
PX33%
Refinery 43%
LB13%
FY/06
Power11%
6,338 5,351 3,691 4,086
3,5316,878
9,737 5,993
6,2543,843
4,803
3,438
2,521 1,840
10,2328,126
EBITDA 05 EBITDA 06 NP fr. Oper. 05 NP fr. Oper. 06
Q4
Q3
Q2
Q1
(Bt. mn.)29,003
15,948
25,014
16,647
*Exclude other activities (Gain & Loss from Fixed Asset sold & Assets Impairment)
+4% YoY
-14%YoY
• Q4/06 - While GRM dropped significantly, subsidiaries (TPX, TLB & IPT) contributed strongly to Group’s bottom line, Net Profit from Operation in Q4/06 was Bt. 1,840 mn.
• FY/06 - Group's Net Profit from Operation increased marginally (by 4% YoY), thanks to strong GRM in Q2/06 and robust PX & LB margins, especially in 2H/06.
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ContentsContents
• Company Overview
• Business Outlook
• Progress of Investment Projects
• Consolidated Financial Performance
11
Regional Oil Demand/Supply OutlookRegional Oil Demand/Supply Outlook
China1) 6,791 416 386 666 550 Japan 4,445 - - 56 - India 2,771 210 64 751 256 Taiwan 1,265 28 - - - Thailand 1,042 - - 115 - Pakistan 282 - 17 - - Vietnam 5 - - - 121 Others 6,966 - 88 - 25 Total 23,567 654 555 1,588 952
2009-10FKbd Jul'06 Exist ing 2006F 2007F 2008F
1)Include Monkolia 20 kbd in 2007 2)The Company
Regional Oil Demand Asia Pacific Refining Capacity Additions
China 6,492 4.3% 6,903 8,634 5.8%Japan 5,102 0.5% 5,073 5,018 (0.3%)India 2,333 1.3% 2,524 2,858 +4.1%South Korea 2,237 0.9% 2,212 2,314 +1.1%Thailand 970 2.3% 1,009 1,112 +2.5%Singapore 816 5.0% 866 1,105 +6.3%Others 5,207 1.1% 5,102 5,866 +3.6%Total Demand 23,157 2.0% 23,689 26,907 +3.2%Total Supply 22,964 0.8% 24,221 27,316 +3.1%
ME Sur/Def 1,305 1,502 1,786
2006F 2010F% Annual Growth
(2006-10F)Kbd 2005A % Growth
2)
26,90725,293
23,157 23,689 24,51226,364 27,316
22,964 24,221 24,826
2005A 2006F 2007F 2008F 2010F
Total Demand Total SupplyKbd
Source: FACTS, Fall 2006
Asia-Pacific Demand/Supply Balance
90%
• Delay of a few refinery projects in China and latest regional oil demand forecast support tight supply up to 2010.
• New refineries and expansions in M/E are needed to fulfill the gap, especially LPG, Naphtha and Fuel Oil.
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Demand PX Total Capacity Operating Rate
0
5
10
15
20
25
30
35
40
00 01 02 03 04 05 06 07 08 09 1065
70
75
80
85
90
95
100% Op. Rate
Domestic PX Demand & Supply
Global Total PX Supply / Demand & Operating Rate
PX Business OutlookPX Business Outlook
0
0.5
1.0
1.5
2.0
2.5
3.0
3.5
4.0
99 00 01 02 03 04 05 06 07 08 09
Mn. T.
10 11World Demand Growth Americas EuropeAfrica/Mideast Asia/Pacific
Source: CMAI & Company
0
400
800
1,200
1,600
2,000
04 05 06 07 08 09 10 11ATC Exxon TPX Demand
KTA
11
• Delay of a few Chinese & M/E PX projects (~2.4 mn. T/Y) from 2009 to 2010 will help extend high operating rate period till end 2009.
Global PX Supply & Demand GrowthMn. T.
• With new Indorama’s and expansion of Siam Mitsui’s PTA plants in 2006, Thailand remains net importer of PX till Q3/08 when new ATC II project will be completed.
13
LB Business OutlookLB Business Outlook
Regional Base Oil Supply & Demand
6,000
8,000
10,000
12,000
14,000
16,000
'02 '03 '04 '05 '06 '07 '08 '09 '10 '11
Supply DemandKTA
• Delay in new capacity coming on-stream is the main reason for limited supply.
• Shortage of base oil is expected to continue in 2007 but could turn into balance after 2008 when new capacity additions commence operations.
Global Base Oil Market
2000 2005 2010 2015 2000 2005 2010 2015
Rest of the worldW. EuropeAsia PacificN. America
Demand by Region Demand by GroupGroup 3Group 2Group 1
• Global base oil demand is expected to grow by 2% CAGR until 2015. However, demand for Group I is forecasted to decline by 1% CAGR.
• Although demand for Group I declined, regional base oil supply of Group I is still tight due to permanent shutdown of some base oil plants in Australia & Philippines.Source: Kline, Shell Lubricants
90%
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ContentsContents
• Company Overview
• Business Outlook
• Progress of Investment Projects
• Consolidated Financial Performance
15
TOP GroupTOP Group’’s Major CAPEX Programss Major CAPEX ProgramsProjects (US$ mn.) COD 2005 2006 2007 2008 2009 2010 2011 Total
CDU-3 Revamp
New Gas Turbine
SBM Expansion
TPX Expansion
Total
Q4/07
Q2/07
Q3/07
Q4/07
34 59 125
9 22 12
78 72
6 66 210
49 225 419 693
On-going218
43
150
282
16
Details & Progress of Investment ProjectsDetails & Progress of Investment ProjectsProjects Details Work Progress as of End-Jan’07
CDU-3 Revamp
Size : + 50 kbd (CDU Capacity)
Cost : US$ 218 mn. (US$ 4,360/bbl)
IRR : ~ 28% based on
US$ 4.5/bbl GRM
EPCM : Foster Wheeler
Exp. C.O.D. : Q4/07
Overall Work Progress: 58%
• Installation of new KMT unit scheduled to be completed in Mar’07.
• Substation, cooling tower and new crude furnace construction work is in progress.
Prior to commissioning of the expansion, CDU-3 will be shutdown for 2 months in Q4/07 for major turnaround & tie-in with the new facilities.
New Crude Furnace F- 2102 Foundation New Scot Unit FoundationUnit 2350 New KMT
17
Details & Progress of Investment ProjectsDetails & Progress of Investment Projects
Projects Details Work Progress as of End-Jan’07
New Gas Turbine
Size : 38 MW
Cost : US$ 43 mn.
EPC : CTCI
PMC : Foster Wheeler
Exp. C.O.D. : Q2/07
Overall Work Progress: 95%
• Gas Turbine, Generator and Heat Recovery Steam Generator installed.
• Construction work is in progress.
Auxiliary / Local Control RoomGas Turbine and Generator Package Transformer
18
Details & Progress of Investment ProjectsDetails & Progress of Investment ProjectsProjects Details Work Progress as of End-Jan’07
SBM Expansion
Size : 52” diameter * 14.5 km
long pipeline (to receivecrude fr. VLCC @ 2 mn. bbl)
Cost : US$ 150 mn.EPC : SAIPEM
PMC : Bechtel
Exp. C.O.D. : Q3/07
Overall Work Progress: 49%
• Major equipment and 52” concrete coated steel pipe are scheduled to deliver to site as planned.
• On-shore construction work started in Jan’07.
• Subsea pipe laying will be started in Apr’07.
19
Details & Progress of Investment ProjectsDetails & Progress of Investment ProjectsProjects Details Work Progress as of End-Jan’07
TPX Expansion
Size : +480 KTA Aromatics (add.)
+PX 141 KTA +MX 18 KTA
+BZ 177 KTA +Tol 144 KTA
Cost : US$ 282 mn.
EPC : Bechtel
PMC : Foster Wheeler
Exp. C.O.D. : Q4/07
Overall Work Progress: 42%
• Foundation work for new units completed.
• Erection of storage tanks started in Dec’06.
• Piping installation outside battery limit is in progress.
Prior to commissioning of the expansion, TPX will be shutdown for 2 months in Q4/07 for major turnaround & tie-in with the new facilities.
H-1601/B- 4007 Demolition Work CompletedBig Mat. Foundation in the New Process Area Foundation work inside TATORAY
20
TOP GroupTOP Group’’s Major CAPEX Programss Major CAPEX ProgramsProjects (US$ mn.) COD 2005 2006 2007 2008 2009 2010 2011 Total
Specialties 2009
Euro IV2) 2011
CDU-3 Revamp
New Gas Turbine
SBM Expansion
TPX Expansion
Ethanol 0.5ML/Day
Ethanol 0.1ML/Day1)
730 MW IPP
Total
Q4/07
Q2/07
Q3/07
Q4/07
Q4/08
Q1/09
2011
34 59 125
9 22 12
78 72
6 66 210
92 58
4 8
10384 163
49 225 515 100111 213 153 1,366
On-going
Under Development
218
43
150
282
150
12
350
5050 100
45 16 61
1)Investment for 30% equity stake 2)Based on 50 ppm sulphur in gasoline & diesel Not yet confirmed on project’s holding stake
210.00 0.25 0.50 0.75 1.00 1.25 1.50
Sugar CaneCassava
TOPTOP’’ss Ethanol Project ProgressEthanol Project Progress
> 15%> 15%Project IRR
Finalize detailed feasibility studyPrepare project specifications & finalize detailed cost estimationCurrent Status
Q1/09Q4/08Expected COD
Sugar Cane (~0.5 mn. T/Y)Tapioca chips (~0.5 mn. T/Y)Feedstock
• Padaeng Industry (35%)• Mitr Phol Sugar Group (35%)Under discussionPartners with TOP
Maesod, Tak, ThailandCentral, ThailandLocationUS$ 150 mn.
0.5 mn. L/D
US$ 40 mn.Est. Investment
0.1 mn. L/DCapacityEthanol Plant
US$/L
Grain (EU)
Corn (China)*
Sugar Cane (TH)
Sugar Cane (Brazil) As of 2006
Source: Worldwatch Institute, except *Food & Economy Research Institute of Jilin Province
Cellulose
Comparison of Production Cost Analysis
Cassava (TH)
Corn (US)
0.3 0.4
0.40.3
• Import parity price from Brazil has been agreed to be used as domestic price which is currently traded at Bt. 19.3 per litre.
• With new Ethanol capacity come on stream in 2007, campaign for the use of Gasohol 91 will be promoted soon.
• Surplus production will have to be exported, if economical.
Latest Development
22
TOPTOP’’ss New IPP BiddingNew IPP BiddingTimetable for New IPP Bidding
Apr’07 Jul Oct Jan’08 Apr Jul Oct Oct’11 Oct’12
• Expected 3,000-4,000 MW capacity during 2011-2013.
• Unit and Plant Size Restriction: 800 and 1,600 MW, respectively.
• Annual capacity will be announced following finalization of the new load forecast and power development plan in early-2007.
RFP issued
Bid submission
Preferred bidders named
PPA signed
COD – Gas plants
COD – Coal plantsSource: IPP Solicitation Conference held by EPPO on 15 Dec’06
Key PoliciesDetails for New Bidding
Opportunity for TOP
TOP is in advantageous position given infrastructure available for additional 2*730 MW power plants:-• Land of 100 Rais (40 acres)• 28” natural gas / raw water pipeline• 230 KV transmission line and available diesel oil storage facilities for back up • EIA approval obtained
• State-owned enterprise (SOE) and any bidder that is directly or indirectly owned by SOE more than 50% is not allowed to bid.
• US$ indexation of Availability Payment is partially allowed if FX moves more than +/- 2 Baht around the reference rate.
• EIA approval & many Community Development Programs are required prior to PPA execution.
23
Details & Potential of Investment ProjectsDetails & Potential of Investment Projects
• To upgrade the existing base oil and by-products to higher value specialty products
• Improved Refining Margin
• Better Plant Utilization
• Potential Projects
• Market survey to be conducted 2 new products
TLB Strategy
Treated Distillate Aromatic Extract (TDAE) White Oil
Raw Material : Aromatic Extract
1st Phase : 16 kT/Y w/o major investment, start commercial production in Q2/07
2nd Phase : 36 kT/Y require investmentCost : US$ 25 mn.
Raw Material : Base Oil 150SN & 500 SN
Size : 50-75 kT/Y
Cost : US$ 36 mn.
24
ContentsContents
• Company Overview
• Business Outlook
• Progress of Investment Projects
• Consolidated Financial Performance
25
Improved OperationsImproved Operations
2005 & 2006
105 9682
7492 91
104 97
71 7792 92
FY/05
FY/06
(%)
TOP TPX TLB IPT TP TMTOPTOP TPXTPX TLBTLB IPTIPT TPTP TMTM
Refinery Utilization PX Production Lube Production Availability Utilization Utilization
2006Net Profit 7,497 5,666 2,322 1,573 318 30∆ YoY -2,099 +1,996 +724 +1,130 -154 +1
%∆ YoY -22% +54% +45% +255% -33% +3%
(Bt. mn.)
26
14,39518,168
14,39518,168
29,099
15,580 7,308
21,492
8,853 4,166
10,015 5,894
4,9765,842 2,600 2,600
1,170
1,170
FY/04 FY/05 FY/06 FY/04 FY/05 FY/06
JPY LoanTHB LoanUS$ LoanUS$ & THB Bonds
0
100
200
300
400
'07 '08 '09 '10 '11 '12 '13 '14 '15
Diversification & Cost ReductionDiversification & Cost ReductionDebt Portfolio
40,284
35,869
25,848
(60%)
(16%)
Bt. mn.
FY/06 Conso. TOP Only
84 / 16
49 / 51
60 / 40
6.3%
US$ / Bt. 90 / 10
Fixed / Float 51 / 49
Bond / Loan* 73 / 27
Cost of Debt 6.2%
TOP82%
IPT16%
TP2%
Consolidated Debt
TOP Group’’s Repayment Schedule
Bt. 30,452 mn.(-US$ 841 mn.)
$ 350 mn. Euro Bond
$ 72 mn. BHT Bond
As of 31 Dec’06
30,452 28,504
24,934
*THB Bond swapped into US Loan with floating interest rate
(24%)
Consolidated Repayment Schedule US$
Remarks: No long-term debts for TLB & TM , Numbers based on FX = Bt. 38/US$
31 30
148118
145
39
97
12
350
$ 72 mn. BHT Bond
• Group’s total debt at YE/06 reduced to Bt. 30,452 mn. due mainly to prepayment / repayment of LT loans, by Bt. 8,191 mn. in 2006.
• TPX has successfully secured new attractive LT loan in Q4/06 to finance expansion.
• TOP’s inaugural Bt. 5,500 THB bond helps smoothen repayment profile.
Consolidated TOP Only
27
Financial StrengthFinancial Strength
Treasury Policy
Net Debt / Equity <= 1.0x
Net Debt / EBITDA <= 2.0x
13.113.5
11.1
1.3 1.00.8
0.30.6
0.42004 2005 FY/06
ICR
Net Debt / EBITDA
Net Debt / Equity
(Times)
Financial RatiosBalance Sheet
40,28435,869
76,292
48,390
72,813
21,417
30,452Current Assets
Non-currentAssets
TotalEquities
Total Assets 115,427124,169
OtherLiabilities
LT Debt
Bt. mn.
FY/04 FY/05 FY/06
124,682
Dividend
• Dividend Policy : Not less than 25% of net profit after reserves, subject to investment plans.
Dividend Payments for FY/06 Result
Interim Dividend Bt. 1.50/sh.
Annual Dividend Bt. 3.50/sh.
Closing of Register Book : 21 Mar’07
Payment : 3 May’07
7.829.19
8.13
3.503.50
1.80
25%
40%45%
FY/04 FY/05 FY/06
EPS
TotalDividend
25% Min. Div. Payout
Bt./Sh.
Interim
Final
1.50
2.00
Payout 25% 40% 45%Yield 3.5% 5.5% 6.7%
28
Changes in Accounting StandardsChanges in Accounting Standards
Previous Standard Equity Method Last-in-First-out (LIFO)
New Standard Cost Method Weighted Average (WA)
RationaleTo comply with the Federation of Accounting Professions on Accounting Standard (FAP) announcement, dated 11 Oct 2006
• To comply with FAP, expected to be announced in 2007
• To better reflect company’s business & financial position
• In line with common industry practice
Implementation 1 Jan’07 with Retro Adjustment 1 Jan’07 with Retro Adjustment
Impact on F/S Company Alone(No impact on conso. F/S)
Company Alone & Consolidated F/S
Others
• No implication on financial ratios as per loan covenants and / or treasury policy levels
• No impact on ability to pay dividends
• Value of inventories better reflect prevailing prices
• Reduce volatility of stock gain/loss
Crude & Feedstock InventoryInvestment in Subsidiaries / Affiliates
29
Conclusions Conclusions
• 2006 was another excellent year for TOP:-• Utilization rate for TOP’s group was at a high level from group business
management and joint production planning.• Overall margin improvement program of TOP group (Refinery/TPX/TLB)
and cooperation within PTT group (PTT/TOP/IRPC/ARC/BCP) contributed to US$ +0.50/bbl GRM.
• All major expansion projects progressed as planned.• Our strong balance sheet provide greater opportunity for TOP group to
steadily grow its business while minimizing financial risk.
• 2007 will be another challenging year for TOP:-• To complete all major projects as planned and within budget.• To prepare and submit Bid for new IPP and be selected as a preferred
Bidder for at least one block of 730 MW (NG fired power plant).• To proceed Ethanol projects and become major Cassava based Ethanol
Producer.• To further optimize TOP group asset and strengthen cooperation within
PTT Petrochemical & Refining group.
30
AppendicesAppendices
31
Awards & Recognitions in 2006Awards & Recognitions in 2006
LT: Baa1 LT: BBB LT: AA-(tha) & ST: F1+(tha)
Highest Credit Ratings Among Pure-Play Refineries in the Region
Best Newly Listed Company & Most Improved Company in Asia
1,330th : World’s 2000 Leading Companies1 of 13 : Thai Listed Companies
33rd : Platts Top Companies in Asia 140th : Platts Top Companies Globally
Best Corporate Governance Report Award 2006
• 2nd: Largest Revenues ~ US$ 6 bn. (5% of SET) - 9M/06
• 4th: Largest Net Profit ~ US$ 0.4 bn. (4% of SET) - 9M/06
• 6th Most Liquidly Daily Traded ~ US$ 12 mn. (3% of SET) - 2006
• 8th: Largest Market Cap. ~ US$ 3 bn. (2% of SET) - 2006
One of the Most Popular Stocks on the SET
32
TOP RefineryTOP Refinery’’s Simplified Process Diagrams Simplified Process Diagram
CDU-1
CDU-2
CDU-3
TCU19,300
HCU-1
FCCU10,300
CCR-1
HDT-1
KMT2,400
HDS-1
LPG
ULG 95
JET
KEROSENE
GAS OIL
ULG 91
HCU-247,600
CCR-250,000
HVU-1
HVU-2
HVU-395,000
HDT-2
HDT-374,900
210,000
FUEL OIL
HDS-2HDS-374,000
MXMX*34,300
Crude
Distillation/SeparationConversion/UpgradingTreating
Long Residue
LVGO
Gas Oil
Kerosene
CDU Overhead
TC Residue
Short Residue
TC Waxy
Heavy Cycle Oil
HeavyNaphtha
Platformate
LPG
Light Plat
Light Cycle Oil
HC
Ker
o
Waxy
CC Gasoline
HC Gas Oil
ADIP
Isomerate
NGL72 RON
Mixed Xylene
50 RON
70 RONISOM21,500
Waxy
IN-LINE
BLEND
BATCH
BLEND
LightNaphtha
TC Kero/GO
95 RON
103 RON
89 RON
91 RON
Imported LR
*Sold to TPX in Apr’05
33
Hydrotreating-to-Refining Ratio2)
72% 48% 44% 33% 32% 32% 29% 22% 18% 16%
TOP Zhenhai Reliance S-Oil Formosa BPCL SingaporePetroleum
Esso Malaysia Indian Oil SK Corp
(%)
Higher conversion ratios result in higher refining margins
90% 80% 71% 63% 44% 42% 42% 28% 15% 10%
TOP* Reliance Formosa S-Oil SingaporePetroleum
Esso Malaysia SK Corp BPCL Zhenhai Indian Oil
Ability to meet more stringent product specifications at lower costs
+50 kbd after debottleneck in ‘07
Source: 2006 Oil and Gas Journal and *the Company1) Hydrocracking, catalytic cracking, thermal cracking, catalytic reforming and isomerization capacities divided by total crude distillation capacity2) Hydrocracking, hydrotreating and hydrodesulfurization capacities divided by total crude distillation capacity
*
Upgrading-to-Refining Ratio1)
70%
56%
+50 kbd after debottleneck in ‘07
(%)
One of the Most Complex Refineries in Asia PacificOne of the Most Complex Refineries in Asia Pacific-- Oil & Gas JournalOil & Gas Journal
34
Consistently Outstanding Performance - SGSI Worldwide Annual Benchmarking
2004Peer group comparisions
1st Tercile2nd Tercile3rd Tercile
• TOP performed very strongly when benchmarked against the global peers.• The company ranked in the first tercile for five out of eight benchmarks, evidenced of its highly efficient operations.• High Maintenance Effort and Personal Indices were offset by low labor costs.
Operating Cost Index
Shell Personnel Index (Based on Headcounts)
2005
CELCorrected Energy Loss
Maintenance Effort(Based on Headcounts)
Avg. Personnel Cost
Utilization
OperationalAvailability
AnnualizedMaintenanceCosts
36
35
Regional Oil Demand, Regional Oil Demand, Refinery Utilization and SpreadsRefinery Utilization and Spreads
90% 90%82% 83% 82% 81%
86%91%
0
5,000
10,000
15,000
20,000
25,000
30,000
35,000
'99 '00 '01 '02 '03 '04 '05 '0640%
50%
60%
70%
80%
90%
100%
China S. Korea Japan India Others Utilization
Oil Demand (Kbd) Refinery Utilization
Source: FACTS, Fall 2006
0
2
4
6
8
'99 '00 '01 '02 '03 '04 '05 '060
20
40
60
80SGP Complex Refinery's GRM TOP's GRM Spot Dubai
GRM US$/bbl
Source: *Singapore Complex GRM & Dubai Spot Prices from Reuters
Gross Refinery Margins & Spot Dubai PricesDubai US$/bbl
Regional Oil Demand & Refinery Utilization
36
Volatile Oil Product / Crude Prices & Volatile Oil Product / Crude Prices & Spreads in FY/06 Spreads in FY/06
US$/bbl US$/bbl
Oil Product & Crude Prices (US$/bbl) Product - Dubai Spreads (US$/bbl)
-25
-15
-5
5
15
25
35US$/bbl US$/bbl
20
30
40
50
60
70
80
90
100
Q1/05 Q2 Q3 Q4 Q1/06 Q2 Q3 Q4
Diesel Gasoline
Dubai
Fuel Oil
Jet
ULG95-DB
FO-DB
Jet-DB
GO-DB
Q3/06 : Slump in ULG & FO prices & weaker GRM than expected
• Built-up crude stock in US & OECD countries,
• No hurricane as widely expected,
• End of US driving season,
• Easing geopolitical concerns in Iran and Nigeria.
Q4/06 : Depressed margin
• Mild winter in the region & US,
• Hefty US crude and heating oil stock,
• Very high Japanese kerosene stock due to warm weather,
• Limited gasoline demand from the US due to high stock.
Q1/06 : Soften GRM carried over from Q4/05
• Increase in crude prices faster than product prices due to geopolitical tension in Iran (nuclear enrichment program) & Nigeria (ethnic unrest),
• Weak heating oil demand due to late winter.
Q2/06 : Record high GRM
• Unprecedented high level of global & regional turnarounds,
• US phasing out of MTBE (summer ULG spec.),
• Very high gasoline imports to the US,
• Late winter in North Asia.
Q1/05 Q2 Q3 Q4 Q1/06 Q2 Q3 Q4
37
709 765 739 689 695 738 722
84% 89% 91% 91% 87% 87% 89%
0
200
400
600
800
1,000
1,200
1,400
4Q/05 1Q/06 2Q/06 Q3/06 Q4/06 FY/05 FY/06 0%
20%
40%
60%
80%
100%
Domestic Demand/Sales Net ExportPetrochem & Others Utilization Rate
Softening Domestic Demand in FY/06 Softening Domestic Demand in FY/06
(Intake)903921 944
Domestic Oil Demand / Refinery Intake (Kbd)
867940 928906
TOP RRC SPRC ESSO BCP
151 57
4889
Intake (Kbd) 234 157 156 169
IRPC
Utilization (%) 104105 108 79
Intake / Utilization by Major Refineries in FY/06 (Kbd)
• Impact of heavy flooding, slowdown in industrial & transportation sectors (Diesel) in Q3/06 and lower power consumption (FO) Q4/06 mainly caused oil demand in FY/06 to decline to 722 kbd (-2% YoY).
• Utilization dropped to 87% in Q4/06, mainly due to maintenance shutdown at TOP (Oct) & IRPC (Nov).
• Apart from being shutdown for almost 1 month, TOP maintained high utilization level at 105%.
• In FY/06, the country’s overall utilization was on avg. at 89%.
Oil Demand by Product Volume in FY/06 (Kbd)
93125
74
338
107124101 78
317
101
05 06 05 06 05 06 05 06 05 06
%∆ +9% 0% +5% -6% -6%
kbd
LPG Gasoline Jet/Kero Diesel FO
Source: DOEB, Ministry of Energy and Company *RRC’s total intake capacity 145 kbd from its Offering Memorandum
Utilization
38
11%14%
4%
15%7%
49%
TOPTOP’’ss Refinery Intake and Sales BreakdownRefinery Intake and Sales Breakdown
80% 81%
16%
10% 11% 14%
41% 38%43%
17% 19%11%
26% 26% 17%
6% 6% 14%14%
3%6%
TOP’s Crude Mix and Oil Product Yield TOP’s Customer Sales Breakdown
Middle
Heavy
LightLPGGasoline
Jet/KeroDiesel
PTT
50%
13%
10%4%
12%
11%
Fuel Oil
TPX
Shell / Caltex
Domestic Independents
BCP
Export = 14%
7% 7%
Export = 18%
FY/05 +3%
• In FY/06 TOP was able to process more local crude up to 16% at the expense of more expensive Far East crude.
• With highly complex & integrated facilities, up to 81% of crude came from M/E (heavy sour crude, i.e. Murban & Oman) , allowing the company to capitalize on sweet-sour crude differentials.
• Approx. 60% of TOP production was middle distillates to meet country’s demand & yield higher margin.
FY/05 FY/06
F/E
Local
M/E
• TOP increased export sales in FY/06 by 4% YoY as it switched to focus on jet export during Q3/06 to capture higher margin and to adjust with lower demand in Thailand.
Tapis(F/E)
Dubai (M/E)
FY/05 57.9
70.0
+12.1
49.3 12.8 18.3 14.7 -9.0
FY/06 61.5 11.7 19.1 15.2
∆
-13.1
+12.2 -1.1 +0.8 +0.5 -4.1
ULG 95 -Dubai
Jet -Dubai
Diesel -Dubai
Fuel Oil -Dubai
Oil Prices / Spreads – MOPS (US$/bbl)
14,351 Mn. L
FY/06
14,843 Mn. LThailand’s Oil Demand
39
TOP’s Gross Refining Margin - LIFO
GRM & GRM & TOPTOP’’ss PerformancePerformance
2,415 2,056 428
13,334
164 783
9,596
20,356
7,497
-425
105 10898 104 105
EBITDA Net Profit % Utilization(Bt. mn.)
TOP’s Performance
Q4/06 FY/06
%YoY %QoQ %YoY
EBITDA -82% -79% -34%
NP -359% -154% -22%
• In Q4/06, TOP’s utilization reduced to 98% due to planned shutdown of CDU-1 for 25 days in October. FY/06’s utilization however remained high at 105%.
• With slow winter demand in Q4/06, market GRM for TOP decreased to US$ 3.62/bbl.
• Inventory loss of US$ 2.11/bbl was realized in Q4/06 due to higher cost of crude purchased in the previous quarters. Accounting GRM therefore reduced to US$ 1.51/bbl for the period.
• FY/06, market GRM remained at US$ 4.92/bbl. With minimal stock gain, accounting GRM reduced YoYby 25% to US$ 4.96/bbl.
• As a result, Q4/06 reported a net loss of Bt. 425 mn. (-359% YoY). However, the company remained to report a net profits for FY/06 of Bt. 7,497 mn. (-22% YoY).
Q4/05 Q3/06 Q4/06 FY/05 FY/06
--22%22%
3.75
8.005.08 4.92
0.90
2.62
1.540.04
3.624.353.85
-0.85 -2.11-1.65
Market GRM Stock Gain/Loss
3.00 2.701.51
6.624.96
(US$/bbl)
Q4/05 Q1/06 Q2/06 Q3/06 Q4/06 FY/05 FY/06
10.62
4.65
40
PX Margin & PX Margin & TPXTPX’’ss PerformancePerformance
-
200
400
600
800
1,000
1,200
1,400
1,600
(US$/Ton)
PX
MX
ULG 95
PX, MX and ULG 95 Spot Prices / Margins
527371
Q1/05 Q2 Q3 Q4 Q1/06 Q2 Q3 Q4
512 332 264 378 402 398 732 575 PX-ULG 95
(Bt. mn.)
TPX’s Performance
1,3542,110
1,419
4,376
6,1255,666
3,670
1,3231,965
1,299
94 9791
97 96
EBITDA Net Profit % Production
Q4/05 Q3/06 Q4/06 FY/05 FY/06
Q4/06 FY/06
%YoY %QoQ %YoY
EBITDA +5% -33% +40%
NP +2% -33% +54%
+54%
+54%
• In Q4/06, TPX’s utilization dropped to 97% due to shutdown for catalyst change for 5 days. FY/06’s utilization, however, remained high at 96%.
• PX – ULG 95 spread narrowed to US$ 575/T in Q4/06 which reflected softening PX price at a higher magnitude than its feedstock.
• FY/06, PX – ULG 95 spread rose YoY by 42% to US$ 527/T, reflecting regional tight supply as well as limited arbitrate from the US aggravated by MTBE phasing out.
• With significant improvement in performance, TPX totally repaid LT loans of Bt. 1,331 mn. in Oct’06, thus reducing interest by Bt. 134 mn.,
• As a result, TPX reported a net profit of Bt. 1,419 mn. in Q4/06 while it registered a record net profit for FY/06 of Bt. 5,666 mn. (+54% YoY).
41
LB Margin & LB Margin & TLBTLB’’ss PerformancePerformance500 SN & HSFO Spot Prices / Margins
(Bt. mn.)
TLB’s Performance
-
200
400
600
800
1,000
1,200
HSFO
500 SN
(US$/Ton)
296 282 318 429 480 525 623 687 500–HSFO
Q1/05 Q2 Q3 Q4 Q1/06 Q2 Q3 Q4
579331
2,768
8194
8471
82
EBITDA NP fr. Oper. % Production
278843 716
247697 572
2,3221,767
1,598
Q4/05 Q3/06 Q4/06 FY/05 FY/06
Q4/06 FY/06
%YoY %QoQ %YoY
EBITDA +158% -15% +57%
NP fr. Oper. +132% -18% +45%
*Exclude TLB’s impairment reversal of Bt. 2,894 mn. & gain from assets sold of Bt. 154 mn. in Q4/05 & FY/05
+45%+45%
• Utilization dropped to 84% in Q4/06 due to shutdown for a partial catalyst change in TOP’s HCU-1. Nonetheless, FY/06’s registered a record utilization at 94% due in to catalyst change during major turnaround in Q1/06 & HCU bottom processing.
• 500 SN – HSFO spread further strengthened to US$ 687/T in Q4 due to softening feedstock cost.
• 500 SN – HSFO spread for FY/06 rose to US$ 579/T (+75%), reflecting regional tight supply due to shutdown of regional lube base plants & widening gap between gasoil – fuel oil.
• TLB also enjoyed the benefit from synergy with TOP, e.g. reduction in fuel cost from using cheaper refinery fuel oil from TOP.
• Despite higher corporate income tax in Q4/06, TLB reported a record operating profit of Bt. 572 mn. Net profit for FY/06 of was Bt. 2,322 mn. (+45% YoY).
42
IPT, TP & TM PerformanceIPT, TP & TM Performance
11 20 15
81
7 230
82
-1
29
93 90 90 92 91
EBITDA NP fr. Oper. % Production
(Bt. mn.)
IPT’s Performance
538 763 710
1,996
274 563 577
1,5731,638
443
8798 91
77 74
EBITDA Net Profit % Production
Q4/05 Q3/06 Q4/06 FY/05 FY/06
+255%+255%
(Bt. mn.)
TP’s Performance
198 203 154
724
119 84 44
318
790
472
95 9789 92 92
EBITDA Net Profit % Production
Q4/05 Q3/06 Q4/06 FY/05 FY/06
--33%33%
(Bt. mn.)
TM’s Performance
+3%+3%
Q4/05 Q3/06 Q4/06 FY/05 FY/06
• IPT’s utilization in Q4/06 remained at 91%, resulting in FY/06 utilization of 74% following resuming full operation since Jun’06.
• With the remaining insurance claim revenue of Bt. 231 mn., IPT reported net profit of Bt 577 mn in Q4/06. Coupled with FX gain of Bt 523 mn, IPT’s net profit for FY/06 increased to Bt. 1,573 mn. (+255% YoY).
• TP’s utilization declined to 89% in Q4/06 due to 10-day shutdown for Hot Gas Path Inspection. FY/06 utilization remained at 92%. TP’s net profit reduced 33% YoY due to higher utility fuel cost & corporate income tax.
• Excluding gains from sales of 2 TM’s vessels amounting of Bt. 55 mn., net profit from operation increased by Bt. 1 mn. YoY.
*Exclude gain from 2 vessels sold of Bt. 55 mn. in FY/05
43
Consolidated Profit & Loss StatementConsolidated Profit & Loss Statement
(Bt. mn.) Q4/05 Q3/06 Q4/06 % YoY % QoQ FY/05 FY/06 % YoY
Sales Revenue 67,081 77,807 61,723 -8% -21% 249,111 279,109 +12%
EBITDA 4,803 5,993 3,438 -28% -43% 29,003 25,014 -14%
EBIT 3,270 4,054 1,636 -50% -60% 22,538 17,922 -20%
Interest Expenses (538) (481) (496) -8% +3% (2,152) (1,917) -11%
Net Profit from Operation 2,521 3,783 1,840 -27% -51% 15,948 16,647 +4%
Bt/US$ - ending 41.17 37.64 36.23 -12% -4% 41.17 36.23 -12%
Gain/(Loss) fr. Other Act.* 2,756 0 1 -100% 0% 2,805 (52) -102%
FX Gain/(Loss) 38 511 850 +2,137% +66% (1,032) 3,489 +438%
Tax Expense (249) (301) (150) -40% -50% (3,406) (2,847) -16%
Net Profit 5,277 3,783 1,841 -65% -51% 18,753 16,595 -12%
Thaioil 164 783 (425) -359% -154% 9,596 7,497 -22%
Subsidiaries 5,113 3,000 2,266 -56% -24% 9,157 9,098 -1%
EPS (Bt/sh.) 2.59 1.85 0.90 -65% -51% 9.19 8.13 -12%
Effective Tax Rate (%) 4% 7% 7% +3% 0% 15% 14% +1%
*Other Activities mean Gain & Loss from Fixed Asset sold & Assets Impairment.
44
Total TOP TPX TLB IPT TP TM
164
-425
2
-1
119274247
1,299
2,521
44577572
1,3231,840
Q4/05 Q4/06 Q4/05 Q4/06 Q4/05 Q4/06 Q4/05 Q4/06 Q4/05 Q4/06 Q4/05 Q4/06 Q4/05 Q4/06
(Bt. mn.)-27%
9,596
1,573318 30294724431,598
3,670
15,948
2,3225,666
7,497
16,647
(Bt. mn.)+4%
FY/05 FY/06 FY/05 FY/06 FY/05 FY/06 FY/05 FY/06 FY/05 FY/06 FY/05 FY/06 FY/05 FY/06
Financial Highlight Financial Highlight –– Net Profit from OperationNet Profit from Operation
PX33%
Refinery 43%
LB13%
FY/06
Power11%
Q4/06 PX63%LB
27%
Power30%
Q4/06 NP from OperationBt. 1,840 mn.
*Refinery -20%
FY/06 NP from OperationBt. 16,647 mn.
*Exclude other activities (Gain & Loss from Fixed Asset sold & Assets Impairment)
45
FY/05 FY/06 YoY
Utilization 92% 92% 0%
EBITDA 790 724 -8%
NP from Op. 472 318 -33%
TLB100%
(Bt. mn.)
100%
TPX
FY/05 FY/06 YoYProduction 97% 96% -1%PX-ULG95 ($/t) 371 527 +42%EBITDA 4,376 6,125 +40%NP from Op. 3,670 5,666 +54%
FY/05* FY/06 YoYProduction 71% 82% +11%500SN-HSFO ($/t) 331 579 +75% EBITDA 1,767 2,768 +57%NP from Op. 1,598 2,322 +45%
FY/05 FY/06 YoY
Utilization 92% 91% -1%
EBITDA 82 81 -1%
NP from Op. 84 30 +3%
100%
TM
FY/05 FY/06 YoY
Avail. 77% 74% -3%
EBITDA 1,638 1,996 +22%
NP from Op. 443 1,573+255%
55%
56%24%
TP
IPT
FY/05 FY/06 YoYUtilization 104% 105% +1%GRM ($/bbl) 6.62 4.96 -25%EBITDA 20,356 13,334 -34%NP from Op. 9,596 7,497 -22%
TOP ConsolidatedThaioil’s Group
FY/05* FY/06 YoY
29,003 25,014 -14%15,948 16,647 +4%
Performance Breakdown by CompanyPerformance Breakdown by Company
*Net Profit form Operation excluded other activities (Gain & Loss from Fixed Asset sold & Assets Impairment)
46
Cash Flow FY/05 & FY/06Cash Flow FY/05 & FY/06
(Bt. mn.) FY05 / FY/06
Operating Cash Flow 20,404 17,911
Net income & non-cash adj. 28,946
(8,542)
26,072
Change in assets & liabilities (8,161)+
Financing (12,113) (14,342)
Repayment of LT loans (30,586)
24,384
(3,799)
(2,112)
(9,670)
Proceed from Loan & Notes 7,978
Dividend payment (10,358)
Interest payment (2,292)
+
+ =
Free Cash Flow
16,697 9,616
CAPEX & Investment (3,707) (8,295)
CAPEX (PP&E) (4,377)
670Other investment
(8,278)
(17)
Beginning Cash
6,667 11,252 (4,726)4,584
Net Increase in Cash
6,52611,251
Ending Cash