Bongkot Field 20 year anniversary

ENERGISING THAILAND

CELEBRATING 20 YEARS

BONGKOT

July 15, 1993 marked the birth of Bongkot and a turning point in the energy scene of Thailand where most people never imaged possessing rich gas reserves.Bongkot, or lotus in Thai, arose against the backdrop of a country that once was entirely dependent on imported petroleum resources for its energy needs.The coming on-stream of Bongkot on the day ushered in a new era for partial energy sufficiency and national economic development by opening up a string of industrial projects which captured added-values originated from the gas.

Twenty years on, the Kingdoms largest gas field, lying about 600 km south of Bangkok in the Gulf of Thailand, has unwaveringly maintained its role as an energy lifeline and an enabler of progress for Thailand.

Bongkot, part of the 4,231-square-kilometre Navamindra Petroleum Area, has contributed significantly to the Eastern Seaboard Development Project on the Thai eastern coast which gave a dramatic impetus in industrialisation.

An outstanding track record achieved by Bongkot over the past two decades provides a good reason to celebrate and commemorate Bongkots 20th anniversary.

Cumulative Bongkot gas production reached 3.66 trillion cubic feet (Tcf) plus 106 million barrels of condensate, translated into 700 million barrels of crude oil equivalent.

The current gas output of over 870 million cubic feet per day (MMcfd), excluding about 30,000 barrels per day (b/d) of condensate produced in association with the gas, meets about 20% of Thailands overall daily natural gas consumption, or accounting for around 30% of the combined indigenous gas output.

Bongkot has been one of the main contributors of gas supplies which together generate 70% of electricity that Thailand consumes.

Recording a 99.5% reliability factor, meaning any disruption to gas delivery is extremely rare. Operating in an environmentally friendly and utmost safe manner. Valuable gaseous components extracted from raw natural gas stream from Bongkot are

turned into to liquefied petroleum gas (LPG) and vital feedstocks for petrochemical, an industry that arose partly out of Bongkot discovery.

Contributing over 240 billion baht to the national coffers in the forms of royalty, taxes and government sharing over the 20-year span.

A major job creation with thousands of people employed directly and indirectly down the value chains stemming largely from Bongkot.

Today, 15 July 2013, also represents a special moment for the country in general and PTTEP in particular as it underlines the 15th year of successful running of Bongkot by a Thai outfit PTTEP.

The celebration will go on for another decade as the Bongkot consortium strives to sustain its key role in providing affordable, reliable and clean energy for Thailand.

HistoryThe success story of Bongkot dated back to May 1973 when the US oil firm Tenneco struck oil and gas at the wildcat 15-B-1X in block B15, lying in the Malay Basin.

Although not originally perceived to be large, later drilling by the UK-based BP Petroleum and Texas Pacific International Inc of the US in the area confirmed the presence of a gas bonanza.

Texas Pacific, which took over the interests of B15 and its adjacent tracts B16 and 17 in 1978, drilled 23 wells to confirm the rich gas deposits at the intensely faulted field which was known as the B structure.

Realising the vast long-term benefits of B Structure gas to national development, the Thai government made a landmark decision to acquire the concession rights from Texas Pacific in 1988.

At the same time, PTTEP, which was incorporated in June 1985, was entrusted by the government to assume the concession rights and leading the development towards tapping benefits thus derived.

In 1990, PTTEP took three major global oil companies, namely Total of France, British Gas and Norways Statoil, on board as partners in the B Structure which was renamed as Bongkot. Statoil withdrew its interest in Bongkot project in 1998 as part of its realigned business strategy.

Total was initially entrusted as the operator of Bongkot for the first five years of production with an agreement to transfer the controls of operation to PTTEP by mid-1998.

That agreement was triggered by the governments foresight to use Bongkot as a platform to develop a local capability to manage, hands-on, a sophisticated capital and technological intensive industry which is all important to the kingdom.

Indeed, PTTEP has become what it is a world-class energy company with more than 40 upstream interests across 12 countries, due to its fruitful engagement in Bongkot.

Bongkot is like a prestigious university which provides real-life practical lessons and rich experience for us at PTTEP, said Nawee Anantraksakul, PTTEP senior vice president for Bongkot Asset.

PTTEPs growth may not be as impressive as it has been without an active involvement in Bongkot, he pointed out, referring especially to human resource capability.

BONGKOTGAS FIELD

Pragmatic approachDevelopment of Bongkot was successful carried out over time with a pragmatic approach in four stages with a view to increase deliverability in a maximum sustainable manner.

Phase I: Initial endeavour zeroed in on bringing the field on stream at the rate of 150 MMcfd in July 1993 and subsequently raising the flow rate to 250 MMcfd. Supporting that plan was an offshore production facility which included the three well-head platforms, one production platform, one living quarter platform and a condensate tanker with 200,000-barrel capacity.

Phase II: A second offshore complex was put into place and 48 additional production wells were sunk to enable Bongkot to boost gas output to 350 MMcfd in April 1996. The extended facilities consisted of five well-head platforms, a riser platform and a flare structure.

Phase III: In July 1998, Bongkot began to ramp up the gas flow rate further to 550 MMcfd along with 22,000 b/d condensate which were made possible by additional offshore facilities. They included 12 well-head platforms, a new sour process platform, additional facilities installed on the central complex, and a 400,000 barrel-capacity floating storage and offloading vessel (FSO), named Pathumabaha by HRH Princess Maha Chakri Sirindhorn, to replace the old FSO.

Phase IV: This development was geared towards incorporating productive areas within the concession including South Bongkot, Ton Koon and Ton Nok Yoong structures into the mainstream Bongkot production with an incremental delivery of 320 MMcfd in 2012.

Being instrumental to this development phase, collectively known as Bongkot South, was a set of offshore facilities including one production platform, one living quarters platform, 13 well-head platforms and an 8-inch 82-km condensate pipeline linking Bongkot South production platform to the Pathumabaha vessel.

ChallengesWhile Bongkots performance has been highly impressive beyond original expectation by yielding 3.66 trillion cubic feet (Tcf) and 106 million barrels of condensate to date, huge challenges remain to keep the field flowing over the next ten years.

It will be more difficult and costly to obtain new gas which will tend to be marginal, deeper and remote away from Bongkot central facilities.

That will require PTTEP and its partners to continue to work strenuously and invest heavily, to the tune of US$5 billion over the next five years, to recover some 300 million barrels of oil equivalent in proved gas and condensate reserves remaining at Bongkot.

The scale of future development and expenditures are as impressive as what already put into Bongkot over the past two decades but in a shorter period.

Some comparisons: Between 2013 and 2017, 400 development and 40 exploration wells were planned.

Over the past two decades, a total of 73 exploration and appraisal wells plus 416 development wells were bored at Bongkot with a combined investment cost soaring to $6.6 billion.

If we did not continue to work hard and integrating all kinds of technology into our endeavour, we would see a steep and fast decline in production from Bongkot, Mr. Nawee pointed out.

The mission to find reserves replacement is the order of the day at PTTEP as the known deposits are drained everyday too.

Despite the prohibitive cost investment for the next stage of development at Bongkot, PTTEP and its partners are preoccupied with searching ways and means to be more cost-effective and recovering as much as hydrocarbons in the most efficient and environmental-friendly manner, he added.

PTTEP sees the possibilities of Bongkot flowing even after the end of concession in 2022-23, albeit at a lower rate, pending government approval for concession extension and further exploration.

Eco-friendlyEco-friendliness is one the cardinal operating words at Bongkot whose environment, both in the air and water, is well protected by a series of technological-driven measures and determination.

The discharge of muddy water produced in the process of drilling into the sea is zero as such liquid is re-injected back into the disposal wells at the depth of between 1,000-2,000 metres where it is safely contained.

A facility has also been put in place to recover part of the gas from the offshore processing process, which would otherwise be totally burned at flare stacks for safety reason, for good use.

The flare recovery unit allows PTTEP to capture more than half of 8-9 MMcfd of gas which was normally directed to the flare stacks at Bongkot and turned into useful condensate. A second unit will be installed offshore in 2014 as Bongkot joint venture strives to optimise the benefits of the fields resource as well as further reducing emission in its atmospheric environment.

Membrane technology has also been effectively applied at Bongkot South to remove carbon dioxide, mercury and hydrogen sulphide from natural gas.

Through that process, natural gas becomes purer and can be cleanly burned, thus contributing to better air quality.

The history of Bongkots environmental responsibility goes back to its day-one and to its operations being ISO 14001 Environmental Management System certified in December 2001. Since then it has been continuously re-certified.

Bongkot is also where PTTEPs core value SSHE (safety, security, health and environment) - has been vigorously practiced.

While operating in hazardous environment with inflammable substance, years of monitoring show that Bongkot field is one of the safest place to work.

How important is the overall Bongkot project to Thailand in terms of petroleum imports substitution and other value chains it helps to spur?

From the perspective of the country, Bongkot has been a vital indigenous source of energy supply, substituting petroleum imports, lessening dependence on imported energy while creating an extensive value chain for the Thai economy.

Bongkot has been Thailands largest gas field. Its current gas output of over 870 million cubic feet per day (MMcfd), excluding about 30,000 barrels per day (b/d) of condensate produced in association with the gas, is equivalent to about 20% of the Kingdoms overall gas consumption which stands at around 4,500 MMcfd.

Bongkot gas also represents around 30% of the Kingdoms combined indigenous natural gas production.

Its present gas production level can fuel six generators the size of Khanom power plant (818 megawatt capacity), one of the main sources of electricity supplies for southern Thailand and which is located in Nakhon Si Thamarat.

Propane and Butane extracted Bongkot gas have also been turned into LPG (liquefied petroleum gas) which are widely used as household, vehicular and industrial fuel, as well as raw material for petrochemical industries.

Over the past two decades, Bongkot has contributed over 200 billion baht in the form of royalty and tax payment to the national coffer.

Bongkot is a major job creation, directly employing about 600, 200 of them are PTTEP staff and 400 are personnel of contractors.

The size of people employed indirectly by contractors who provide supporting services for the offshore gas operation, those who engage in petrochemical industries and other downstream activities are hard to quantify, but it is absolutely in great numbers.

What does the Bongkot development mean to PTTEP?From PTTEPs viewpoint, our remarkable evolution over the past 28 years, from

a tiny offshoot of the then Petroleum Authority of Thailand (PTT) to an outfit with world-class status, stemmed from our fruitful engagement in the Bongkot JV for more than 20 years.

Here at the Bongkot, PTTEP has developed the capability, expertise, confidence and reputation in operating a geologically complex and the substantial hydrocarbon saccumulation offshore.

Bongkot is like an institution to PTTEP, a place where we have learned, hand-on, practical knowledge about running a giant gas field professionally, efficiently, smoothly and safely.

The apprentice began in 1990 when Total was tasked to operate Bongkot on behalf of the joint venture group and in that process helped grooming key PTTEP personnel for seamlessly taking over the fields operatorship eight years later.

Gas production began in 1993, and by 1998, PTTEP was ready for such a big act, amid certain scepticisms that a Thai outfit would really be able to accomplish that

task.But from that time onward, PTTEP has proved

sceptics wrong and successfully been operating Bongkot whose operation has grown by leaps and bounds with daily gas flow leaping five folds between then and now.

Further we have a rewarding and mutually beneficial relationship with our JV partners, Total E&P Thailand and BG Asia Pacific Pte. Ltd., strengthened over 23 years of successful collaboration.

What are the lessons learned prior to and after PTTEPs assuming the operatorship

of Bongkot?Most senior members of PTTEPs

current management team have passed through a good learning curve embedded in the Bongkot operatorship transfer process in one way or another.

I myself engaged in finalizing Bongkot gas contract with PTT, finding joint venture partners, looking at reservoirs and mapping out field development plan in the initial stage.

Our previous operator, Total, has had a truly industrys best practice, being it in safety procedure, operating standards, philosophy and culture which altogether provides an excellent basis from which PTTEP can build its own procedural platform, corporate culture and safety regimes.

With profound knowledge and practical skill derived from running Bongkot, PTTEP has naturally become fully confident in the pursuit of new interests both at home and overseas.

Our experience at Bongkot serves as a superb reference when we seek ventures abroad as the sense of confidence in us permeates across all parties concerned right from our own board of directors, to joint venture partners and countries in which we seek a presence.

Without the capability and expertise gained from active participation in Bongkot, as well as the onshore S1 oil producing concession (Sirikit oil field in Kamphaeng Phet, Pitsanulok and Sukhothai) to some extent, PTTEP will not have the leverage to grow so robustly to become what it is today.

Arthit, the sibling of Bongkot, is a good showcase which the Bongkot experience was effectively applied by several members transferred from Bongkot.

At Arthit, they have engaged in the entire spectrum of activities necessary in actually putting a field on stream - right from exploration to development and production.

Furthermore, the Bongkot experience has found good application at the Zawtika, one of the major gas deposits lying in Myanmars Gulf of Martaban and whose development is entirely being carried out by PTTEP.

We can duly claim that our insightfulness about the Gulf of Thailands subsurface character is second to none, thankfully to our Bongkot experience.

What is the scale of cumulative investment and works put into the Bongkot over the past two decades?

Undoubtedly it is indeed sizable. Including the shares of our joint venture partners, the cumulative combined capital and operating expenditures so far soared to US$6.6 billion with $3.3 billion being PTTEPs portion.

To date, a total of 73 exploration and appraisal wells plus 416 development wells were bored at Bongkot.

The production has been supported by 33 well-head platforms, three processing platforms, two living quarter platforms, two flare structures and a floating condensate storage tanker.

Aggregate cumulative gas production, from North and South Bongkot fields, is 3.66 trillion cubic feet (Tcf) and 106 million barrels of condensate, together being translated into 700 million barrels of crude oil equivalent.

Since Bongkot has been in production for two decades now, does it show that the field is more prolific beyond the original expectation?

Given what Bongkot has already yielded so far, it is absolutely right to say that the field has performed far better than what we saw back in early1990s when PTTEP took over the ownership of what was known as B Structure from Texas Pacific, the former concessionaire from the United States.

At that time, we reckoned there would be 1.5 Tcf in proved gas reserves, or up to 2 Tcf in a bestcase scenario, to work with.

But as time went by with better knowledge, greater expertise, technological advancement, Bongkot gas flow rate has consistently on the way up, from 150 MMcfd to 250 MMcfd in the initial phase, and been 350 MMcfd to 550 MMcfd in intermediate stage, before reaching the current plateau level of approximately 900 MMcfd.

Proving more reserves and raising gas delivery has been a big challenge due to the complexity of geological condition which requires PTTEP to penetrate many more small pockets of gas deposits in a wider spread of the offshore areas.

However, We are fortunate that an average well at Bongkot yields about 10 billion cubic feet, twice as much as an average producing well lying in the upper part of the Gulf of Thailand.

Tevin Vongvanich, PTTEP President and CEO, speaks candidly about the evolution, vision and dedication involving Bongkot as an energy lifeline for Thailand.

Bongkot has been Thailands largest gas field. Its current gas output of over 870 million cubic feet per day (MMcfd), excluding about 30,000 barrels per day (b/d) of

condensate produced in association with the gas, is equivalent to about 20% of the Kingdoms overall gas consumption which stands at around 4,500 MMcfd.

Bongkot gas also represents around 30% of the Kingdoms combinedindigenous natural gas production.

REFLECTIONS OF20-YEAR SUCCESSFUL PRODUCTION

However, it is much more difficult to recover the gas from Bongkot or elsewhere in the Gulf of Thailand when compared to, say, the productive gas fields offshore Myanmar where hydrocarbons deposits are more concentrating and larger in size within a more expansive reservoir.

To be able to produce 600 MMcfd of gas at North Bongkot, we need 300 wells, compared to merely lowerthan 20 wells required to drain a similar flow rate from Yadana field, Gulf of Martaban.

How long will Bongkot be able to sustain the current flow rate?

There are about 300 million barrels of oil equivalent in proved gas and condensate reserves left at Bongkot, meaning that if we continued at the present production level, those reserves would be depleted over the next 4-5 years.

However, there still are probable and possible reserves, as well as resource potential, at Bongkot and the nearby area which could potentially be recovered, pending further investment by the JV exploration and evaluation.

In the possible category, the discovery certainty is at 50% and 20% for the probable.

All in all, we are fairly confident to be able to sustain the current delivery rate of over 900 MMcfd for another ten years or until 2022-23 when the concession granted by the government ends.

It is our intention to keep Bongkot on stream after 2022-23 and we believe that there are some resources lying there awaiting to be tapped for the benefits of our country if the Government allows the extension of the concession.

What are the challenges PTTEP is facing to sustain Bongkot production?With 20 years in production, Bongkot is like a middle-aged person who needs to

care for himself.That is why, in the first place, we have to ensure that our offshore facilities are in

tip-top working condition through proper maintenance.Secondly, we have to drill more wells to replace those whose production has

depleted.Thirdly, we have to move into areas where gas was found but were not

commercially viable to develop because of their small deposits.That is a huge challenge to recover gas from these marginal gas accumulation in

the sense that we have to find most economical methods to do so.Fourthly, we have to expand our reach to locations where no exploration wells

were previously drilled but possessing discovery potential.Furthermore, we will have to drill deeper wells, which are greater than 3 kilometres

for an average Bongkot well.These deep wells present much more challenging not only from greater difficulties

involving depths but there are issues about high pressure and temperature, of more than 200 degree Celsius, in the borehole, as well as prohibitive costs.

What is the scale of works and investment required to enable Bongkot to remain active in production?

Over the next five years (2013-2017), PTTEP and partners together would need to spend about $5 billion in capital and operating expenditures to sustain Bongkot production.

We target to bore 40 exploration and appraisal wells in the period. We also need to drill up to 400 development wells to collect all those small gas pockets.

Those numbers are significant as compared to what we have undertaken in the longer span of time, of over 20 years, at Bongkot.

Part of the planned capital outlay will go towards installing more well platforms to accommodate those new development wells which more difficult and costly to drill.

It is essential for us to continue to work hard and capitalising in on the advanced technology, such as the so-called slim-hole drilling technique, and long-established experience and knowledge, to prolong Bongkots longevity in the most cost effective way possible.

If you could go back in time, what should have been done regarding the Bongkot project?

If we knew the fields reserves could be this large and spreading out like this, we could come up with better overall development planning such as in terms of optimising platforms design and locations as well as preparing larger manpower base.

Moreover, we should have been more active in sharing the Bongkots success story and difficulties involved so that members of the public were better aware of the importance of an energy resource and use it efficiently.

But after all, the truth was that we did not have the luxury of such knowledge then and we did what we saw fit.

Our step-by-step approach in ramping up gas delivery smoothly over the period, from 150 MMcfd to over 900MMcfd, is a good indication that we have been on the right track.

Thai Energy Ministry officials have been saying that Thailand will run out of indigenous oil and gas in the next ten years and the chance of new discoveries is slim. What is PTTEPs view on that?

What they have been saying is the countrys remaining known gas reserves would dry up over that period based on the current flow rates and assumption of no new discoveries are made.

However, I believe there are still chances for finding more reserves if exploration and production companies were allowed by the government and communities to do their jobs well.

New petroleum concession blocks should be made available to support the hunt for possible new reserves in locations where little or no exploration has been undertaken.

Of course, the chance of finding gas deposits the size of Bongkot in the Gulf of Thailand is probably like winning the first lottery prize.

However there are shining opportunities for gas reserves in the offshore Thailand-Cambodias Overlapping Claims Area (OCA).

The 26,000 sq km tracts share subsurface geological structure similar to productive areas on the Thai waters.

Since no exploration has been undertaken, the magnitude of gas deposits is still unknown.

Unfortunately, I think it may take a long while before the governments of Thailand and Cambodia can settle their differences that will allow activities to start.

PTTEP has played a key role in providing hydrocarbons to meet a good part of Thailands energy need. Will that role continue well into the future even if all local reserves were gone? How does PTTEP go about ensuring energy supplies for Thailand?

The mission of meeting Thailands energy demand entrusted to us and parent PTT Plc by the Government remains unabatedly at the forefront.

That means to say our top priority is maximising local petroleum production, searching for more reserves and sustaining optimum output.

As Thailands energy grows and indigenous hydrocarbon production looks set for dwindling, PTTEP has, at the same time, sought resources from overseas.

Today, PTTEP has extended our engagement in the upstream industry in places like Australia, Africa, Middle East, North America, on top of Southeast Asia especially Myanmar.

These overseas provide possible direct access to energy supplies which can either be directed to Thailand or being disposed locally there to generate income for PTTEP.

We are especially keen to engage in gas development projects which have the potential to be turned into liquefied natural gas (LNG) which will fulfil Thailands demand.

But the opening of Myanmar and its energy demand ensures that we cannot significantly increase our natural gas imports more than we received from Yadana and Yetagun gas fields in Mayanmars Gulf of Martabun today. Therefore, we are on the lookout virtually on almost all countries surrounding Thailand, particularly Indonesia, for supplies which are more easily accessible.

Over the long term, we see shale oil and shale gas as likely additions to our portfolio. We are taking a good look at these new energy forms and if there is suitable opportunity emerging we may consider taking it on board.

PTTEP has pursued a path of being a global player in resource development. How does it strike a good balance between meeting Thailands energy needs and playing an international role?

When you compare PTTEP with multi-national major oil concerns like ExxonMobil and Royal Dutch/Shell, theirs are more than 20 times the size of ours.

By that comparison, ours falls into the S (small) category when measured in terms of investment, reserves and production scales.

But it is gratifying to say that our capability, dynamism and growth potential are nothing to shy about in the international standards, and we are capable of competing well with other industry players when it come to the issues of resource development.

We are a national oil company which seeks overseas interests to consolidate our resource base largely to build on security of energy supplies for Thailand while providing growth for the firm itself.

We are committed to be a major player at home and expanding an international role with the purpose of serving the best interest of Thailand.

1993

1998

2001

PTTEP has signed a joint venture contract with TOTAL E&P Thailand and BG Asia Pacific Pte. Limited to jointly develop Bongkot field.

Exploration and development began in earnest with the construction of offshore production facilities started.

On September 15, Her Royal Highness Princess Maha Chakri Sirindhorn presided over Bongkot production start-up.

Gas production has achieved the contractual rate of

150 MMscfd.

Bongkot gas output ramped up to 350 MMscfd. under an upgraded contractual volume.

An advanced drilling technology, known as Slim Hole, debuted in May.

The first well in Thailand drilled horizontally was sunk at Bongkot at well BK-4-M1.

The water injection, a method whereby muddy water produced along with natural gas was pushed back into the reservoir, has been introduced in August as part of an eco-friendly procedure.

PTTEP assumed the operatorship of Bongkot, becoming Thailands first outfit in history to play such a role.

Bongkots gas production has increased further to 550 MMcfd together with 22,000 BPD in condensate output as the third production train on stream.

Pathumabaha, a new condensate floating storage and offloading vessel, or FSO2, with 400,000 bbls holding capacity, was deployed.

His Majesty the King has graciously granted the name Navamindra Petroleum Area to the 4,231 square-kilometer production area covering the Bongkot and Arthit Projects.

Bongkots 100th development well, BK-7-MRW, was successfully completed on

July 22.

Successful drilling of Tonsak- 6 exploration well, bored to the total depth of 2,770 metres, has enhanced Bongkots gas reserves by 600 Bcf.

Bongkot South, a prolific extension of Bongkot, was discovered by PTTEP and its partners.

Thailands longest well, BK-7-GR, was drilled horizontally up to 90* angle at Bongkot to a total depth of 5.2 km. The well was expected to yield 30 Bcf of gas delivery.

A production platform that separated hydrogen sulphide (H2S) from raw gas stream has been installed.

BONGKOT BLOSSOM MILESTONESIn June 1985, PTTEP set out on a significant path of history that changed the face of Thailands petroleum exploration and production industry. The development of Bongkot field has played a crucial role in that transformation.

Begin here to trace the evolutionary milestones of the Kingdoms most prolific and largest gas and condensate deposits throughout the past two decades.

2012 A 3-dimensional seismic

campaign was launched at Bongkot South in March.

The coverage of Bongkots production area has increased to 3,200 sq km.

Fabrication of Bongkot Souths central processing platform began.

Condensate production from Arthit, the other major field operated by PTTEP in the same general area, was successfully integrated with Bongkots facilities with Arthit gas liquid delivered to the FSO2.

PTTEP and partners concluded a long-term accord to sell natural gas from Bongkot South to PTT Plc.

Cumulative gas production from Bongkot has reached a landmark level of 3 Tcf.

Installation of additional living quarters and central processing platforms at Bongkot were completed on July 19 and August 12, respectively.

Princess Sirindhorn inaugurated Bongkot South on September 24.

Bongkots cumulative condensate production has touched 100 million bbls.

First trial gas delivery from Bongkot South to PTT started on February 4 with contractual volumes being met on June 16.

Bongkot Project has won bronze award in 2012 Operational Excellence Best Practice from PTT.

Pathumabaha FSO celebrated its 10th anniversary of service with no accident.

Editor Simon K Project Manager Sangsoam K Text Supplied Editorial Design Arthit K Photographs Supplied Display Advertising and Supplement Sales SVP Voravadhana J Tel +66 (0) 2616 4000 Email Production Allied Printers

The Bangkok Post is edited by Pattnapong Chantranontwong for The Post Publishing Public Company Limited, Printer, Publisher and Owner Office Bangkok Post Building, 136 Na Ranong Road, Klong Toey, Bangkok 10110, Thailand www.bangkokpost.com 0713

1st operated by Thai Company.

Up to 1,000,000,000 scfd of natural gas are produced.

ISO 14001 has been certified by the International Environment Management System and recertified by AJA Registrars Ltd., since 2001.

VALUE CHAINS FROM BONGKOT IN

NUMBERS

Natural Gas field

Or 20% of Thai natural gasdemand is produced each day.

Over 1,000 jobsare indirectly supported.

Over 600 jobs are directly supported.

Over 200,000,000,000 baht has been injected into governments circulation via royalty and tax payment, since the implementation of Bongkot project.6 power plants, as big as 800 MW, are fueled up

daily by natural gas provided by Bongkot project.

5.2 kilometers long of BK-7-GR, which is the longest gas well in Thailand.

100% of produced waterre-inject back into the disposal well to eliminate pollution.