• The current landscape of offshore exploration trends Asia Pacific reveals a strategic shift toward the appraisal of frontier basins and deepwater regions that were previously considered too technically challenging or economically risky. Through more attractive offshore licensing terms and improved fiscal incentives, governments across the region are successfully attracting international investment, leading to a new wave of offshore discoveries that have the potential to significantly alter the regional energy balance and reduce the dependence on long-distance imports.
• Modern upstream exploration trends in Asia Pacific are increasingly defined by the integration of sophisticated seismic imaging and data analytics, which allow for a more precise understanding of complex geological structures. This technological evolution, combined with a focus on gas-prone prospects, is aligning regional energy security goals with the broader global transition toward lower-carbon fuels, ensuring that new discoveries contribute to a more sustainable and resilient energy infrastructure for the growing economies of the Asia Pacific.

The Asia Pacific region stands as one of the most dynamic and complex energy markets in the world, characterized by soaring demand, diverse geological potential, and a critical need for energy security. In recent years, the maritime landscapes of nations ranging from Australia and Indonesia to Malaysia and Vietnam have witnessed a significant shift in offshore exploration trends Asia Pacific. As traditional, shallow-water fields enter their twilight years, the industry’s focus is pivoting toward deeper waters and untapped frontier basins. This revitalization is not just about finding more hydrocarbons; it is about securing the energy independence of some of the world’s fastest-growing economies while navigating the multifaceted challenges of the global energy transition.

The current wave of exploration is driven by a renewed sense of urgency. The disruptions in global energy supply chains and the volatility of international prices have highlighted the strategic importance of domestic production. Consequently, regional governments are becoming more proactive, refining their offshore licensing frameworks to attract the capital and technical expertise of global energy majors. This competitive environment is fostering a new era of Asia Pacific offshore exploration, where advanced technology and favorable fiscal terms are combining to unlock potential that was previously deemed inaccessible. The result is a vibrant upstream sector that is critical to the region’s long-term economic stability.

Unlocking Potential in Frontier Basins and Deepwater Regions

One of the most prominent offshore exploration trends Asia Pacific is the bold move into frontier basins. These are areas with little or no previous production history, often located in ultra-deep water or challenging geological settings. Regions such as the Andaman Sea, the deepwater areas of the South China Sea, and the Great Australian Bight are now at the center of exploration strategies. The attraction of these basins lies in their potential for “elephant” discoveries massive reservoirs that can transform a nation’s energy outlook for decades. However, exploring these frontiers requires immense capital investment and the latest in drilling and subsea technology, making the involvement of experienced international partners essential.

The push into deeper water is also a technical necessity, as the “easy” oil and gas in shallow shelves have largely been found. Deepwater exploration in Asia Pacific is benefiting from the lessons learned in other major basins like the Gulf of Mexico and offshore Brazil. Operators are deploying advanced 3D and 4D seismic imaging to “see” through complex rock layers and identify subtle traps that were invisible to previous generations of explorers. This technological edge is significantly improving the success rate of wildcat wells, reducing the financial risk associated with high-stakes exploration in frontier basins. The success of recent deepwater campaigns is providing the confidence needed for sustained investment in the region’s most challenging maritime environments.

The Evolution of Asia Pacific Offshore Exploration Licensing

Governments across the region are recognizing that attracting investment requires more than just geological potential; it requires a stable and attractive regulatory environment. This has led to a significant evolution in offshore licensing strategies. Countries like Indonesia and Malaysia have introduced more flexible fiscal terms, such as the “Gross Split” or improved Production Sharing Contract (PSC) models, which allow for a more equitable sharing of risks and rewards between the state and the operator. These changes are designed to remain competitive in a global market where capital is increasingly being directed toward low-cost or low-carbon projects.

Furthermore, the transparency and frequency of licensing rounds are increasing. Digital data rooms and streamlined bidding processes are making it easier for companies to evaluate prospects and submit bids. This proactive approach to offshore licensing is essential for maintaining the momentum of exploration, ensuring a continuous pipeline of new projects. By fostering a collaborative relationship with the energy industry, Asia Pacific nations are positioning themselves as attractive destinations for long-term investment, even in a world that is gradually moving away from fossil fuels. The focus is on finding and developing the most efficient and sustainable resources as part of a balanced energy portfolio.

Impact of Recent Offshore Discoveries on Regional Strategy

Recent offshore discoveries are having a profound impact on the regional energy strategy, particularly in the gas sector. Major finds in the waters of Malaysia, Indonesia, and Vietnam are reinforcing the role of natural gas as a critical transition fuel for the region. These discoveries are providing the feedstock for new LNG projects and domestic gas-to-power initiatives, which are essential for displacing coal-fired generation and meeting national carbon reduction targets. The focus on gas-prone exploration is one of the most significant upstream exploration trends in the region, aligning energy security with environmental stewardship.

Moreover, these discoveries are acting as catalysts for infrastructure development. A single large find can justify the construction of new subsea pipelines and processing hubs, which can then be used to tie in smaller, nearby prospects. This “hub-and-spoke” development model is improving the economics of marginal fields and extending the life of existing maritime energy infrastructure. The success of recent exploration campaigns is also boosting regional confidence, encouraging national oil companies (NOCs) to take a more active role in exploration, often in partnership with international players. This blend of local knowledge and global expertise is a powerful driver of the Asia Pacific offshore exploration sector.

The Role of Digital Technology in Shaping Exploration Trends

The digital revolution is fundamentally changing how exploration is conducted in the Asia Pacific. The use of artificial intelligence and machine learning to analyze vast quantities of seismic and geological data is allowing explorers to identify prospects with unprecedented accuracy. These tools can identify patterns and anomalies that might be missed by human interpreters, leading to more informed decision-making and a higher return on exploration spend. This data-driven approach is a key component of modern upstream exploration trends, enabling companies to do more with less in a budget-conscious environment.

Digitalization also extends to the operational side of exploration. The use of remote-operated vehicles (ROVs) and autonomous underwater vehicles (AUVs) for site surveys and environmental monitoring is reducing costs and improving safety. Real-time data transmission from drilling rigs allows for instant adjustments to the drilling program, minimizing the risk of wellbore incidents and optimizing the collection of subsurface data. As the region continues to embrace these technologies, the efficiency and sustainability of Asia Pacific offshore exploration will continue to improve, ensuring that new discoveries are found and developed with the smallest possible environmental footprint.

Navigating the Energy Transition and Geopolitical Complexities

Offshore exploration trends Asia Pacific are also being shaped by the broader global energy transition and the region’s complex geopolitical landscape. Many companies are now prioritizing “advantaged” resources those that are low-cost, low-carbon, or close to existing markets. This is leading to a more disciplined approach to exploration, with a focus on prospects that can be developed quickly and responsibly. The integration of carbon capture and storage (CCS) into new offshore projects is also becoming an important consideration, as companies seek to mitigate the environmental impact of their upstream activities.

Geopolitical factors also play a significant role, particularly in disputed areas such as the South China Sea. Managing the risks associated with these tensions requires a sophisticated approach to diplomacy and risk management. However, the shared need for energy security is also a powerful force for cooperation, with some nations exploring joint development agreements as a way to unlock resources in overlapping maritime claims. The ability to navigate these complexities while maintaining a focus on exploration excellence will be a defining characteristic of the successful energy companies and nations in the Asia Pacific for decades to come.

Conclusion: The Future of Offshore Exploration in the Region

The future of offshore exploration in the Asia Pacific is marked by both immense opportunity and significant challenge. By embracing new technology, refining regulatory frameworks, and targeting frontier basins, the region is positioning itself for a new era of offshore discoveries. These efforts are essential for meeting the growing energy needs of the region while supporting the transition to a more sustainable energy future. The focus on gas, the rise of deepwater exploration, and the evolution of offshore licensing are all evidence of a vibrant and resilient sector that is adapting to a rapidly changing world.

As the industry continues to evolve, the focus must remain on the relentless pursuit of efficiency, transparency, and environmental responsibility. The offshore exploration trends Asia Pacific that we see today are the foundation for the energy security and economic prosperity of tomorrow. By working together to overcome technical and geopolitical hurdles, the nations of the Asia Pacific can ensure that their vast maritime resources are developed for the benefit of all, providing a secure and sustainable energy supply for generations to come. The journey is far from over, but the progress made in recent years demonstrates that the region remains a cornerstone of the global energy industry.

The Kikeh development consists of a Floating Production Storage and Offloading (FPSO) vessel receiving production from wells drilled from a Spar dry tree unit. The Spar has 24 slots.

Kikeh has a recoverable reserve base in excess of 400 to 700 million barrels of oil. A production plateau of 120,000bpd is planned within two years of first oil and is expected to continue at that level for six years. Project capital expenditures are projected at approximately $1.4bn.

“The Kikeh development consists of a Floating Production Storage and Offloading (FPSO) vessel.”

In early 2006, Petronas awarded Murphy a deepwater license for block P and an extension to the exploration term of a portion of block K. Blocks K and P comprise about 4,111km² and 4,246km² respectively, and lie in water 3,000ft-9,000ft deep. Block P lies on trend 110km to the northeast of block K.

Murphy carried out a large drilling programme to appraise the limits of the oil trend and the adjacent fault blocks.

KIKEH FIELD DEVELOPMENT

The truss spar or Dry Tree Unit (DTU) is 142m long and 32m in diameter. Murphy awarded the contract for the engineering, procurement, construction, installation and commissioning of the unit to Technip Marine (Malaysia). Construction and completion work was carried out by Malaysia Shipyard & Engineering’s facility in Pasir Gudang, Johor, Malaysia. The Spar will incorporate a tender assisted drilling rig to drill and complete the Kikeh wells.

FMC supplied ten surface / dry trees with a pressure of 5,000psi as well as ten OD production risers systems and joints.

It also supplied a surface BOP drilling riser system.

FLOATING PRODUCTION STORAGE AND OFFLOADING (FPSO)

The FPSO Kikeh will be located in 1,350m of water. It will be owned by MDFT Labaun and operated by MDPX Sdn Bhd, two joint ventures between SBM and Misc Berhad. The converted tanker was built in 1974 It has an overall length of 337m a breadth of 54.6m and a deadweight of 273,000t. It has a storage capacity of two million barrels.

The FPSO is designed to accommodate an oil production at a rate of 120,000bpd and water injection at 260,000bpd water. It can compress gas at 135 million cubic feet a day.

At the bow, is the external turret which can accommodate up to 17 flexible risers ranging from 8in to 10in in diameters. There will be nine risers to start with, four in the future, three umbilicals and one spare.

“The Kikeh development has a recoverable reserve base in excess of 400 to 700 million barrels of oil.”

The swivel will house a 12in subsea production line (future), a 14in high-pressure production line, a 10in oil import line(future), a 10in low-pressure production line, a 16in water injection line, an 8in test / pigging line, a multi-path double-drum, a high-voltage power electric line, a low-voltage / signal line and an 8in gas export line.

The metering system is based on three turbo meter runs with a prover loop. The FPSO has four 4,500m³/hr carbo pumps.

Power is provided by two 12MW steam generators and two 1,800kW diesels. There are two 87t/hr boilers. The export system is by tandem mooring

CONTRACTS

Technip was awarded the contract for the engineering, design, supply and installation of the Kikeh Area Development subsea pipeline and riser system.

The project includes design, supply and installation of flexible flowlines and risers, holdback anchors, the installation of control umbilicals and manifolds, tie-in of the subsea wellheads, hook-up of the risers to the Kikeh floating production and offloading system and the pre-commissioning of the system.

Offshore installation will use Technip’s vessel Venturer and Subsea 7’s vessel Rockwater 2.

The facility was given the go-ahead by the Malaysian Government in March 2007 and broke ground in July 2007. The hub is being constructed on a 40ha man-made island in Mukim Serkat Daerah Pontian, near the port of Tanjung Pelepas, Johor.

Asia Petroleum Hub financing problems

The project was initially expected to cost $528.9m (MYR1.7bn) to build and was scheduled for completion in 2009; however, in April 2010 APH announced that the project was delayed due to land stabilisation works being carried out on the reclaimed island.

In June 2011, CIMB placed APH under receivership. APH has already spent $265m on the project and requires $630m in additional financing. The additional funds are required to carry out work on the island. In August 2011, reports emerged that a new investor would provide the additional funds. However, as of July 2012, APH’s receivers, PricewaterhouseCoopers, are seeking to carve out its assets for a restructuing scheme with questions over who has the legal rights to develop the hub

The project stalled at 64% complete in June 2011.

Asia Petroleum Hub development

“The Asia Petroleum Hub is one of the newest petroleum storage projects started in Asia.”

The hub development was started by Asia Petroleum Hub (APH), which is 90% owned by KIC Oil and Gas, a Malaysian private oil company, and 10% owned by Trek Perentis.

The land for the project was leased to Seaport Terminal by the Malaysian Government, which in turn leased it to APH.

The facility was set to be managed by Kadriah Intergrated Facilities, a company that manages oil terminals in Tanjung Pelepas and Westport for KIC Oil and Gas.

Financing for the project was being provided by CIMB Group (also financial advisor for the project). APH expected that Malaysia Petroliam Nasional would use the hub for storage.

Asia Petroleum Hub concept

The concept behind the Asia Petroleum Hub is to reduce the cost of landed petroleum products in Malaysia by cutting out the double handling charges that are usually levied on deliveries.

Shipments can be made directly from the source to the hub, thus helping reduce government fuel subsidies (Malaysia will have more control over its own petroleum reserves). The hub is expected to attain world recognition and become a recognised market for global petroleum-trading activities.

The hub will also act as a new supply chain for the area, and may help attract foreign investment to the island.

Facilities at the Asia Petroleum Hub

The Asia Petroleum Hub was designed with facilities to receive, store, blend and distribute petroleum products. The facility will also include breakbulk facilities for fully laden vessels of up to 350,000dwt.

“The Asia Petroleum Hub will reduce the cost of landed petroleum products in Malaysia.”

The island will be accessible from the mainland via a bridge, and will have an estimated product storage capacity of 950,000m3. The facility will also be equipped with seven fixed berths for vessels of up to 150,000dwt, and will have a single point mooring system for ultra large crude carriers.

The hub will have loading facilities for tanker trucks for road deliveries inland, bunker barges for offshore bunkering of ships, and oil product carriers for trading in the petrol and petroleum products markets.

There will also be facilities to blend fuel oil and petrol, so that the hub can produce different grades of these products for sale.

Products will include industrial and marine fuel oils, petrol (unleaded), diesel (low sulphur), jet fuel and biodiesel products. The facility will eventually handle 60 million tonnes of petroleum products a year, and play host to over 2,000 vessels annually.

Contractors

Operator APH appointed Mott MacDonald to provide design services for the project and engineering, procurement and construction management services.

“Mott Macdonald was asked to provide design services for the Asia Petroleum Hub.”

Other contractors appointed by APH for construction work include Muhibbah Engineering and Nam Fatt Corporation. In addition, ZAQ Construction and QI-pmc will provide construction management services.

In April 2007, Kencana HK, a subsidiary of Kencana Petroleum, was awarded a subcontract for procurement, construction and commissioning.

Petronas Bintulu LNG Complex, located approximately 20km from Bintulu Town, covers 276ha and currently accounts for 40.5% of Sarawak’s gross export, 6% of Malaysia’s total export and 4.2% of the country’s GDP. It includes three LNG plants with eight LNG trains in total. The three plants are respectively owned and operated by Malaysia LNG, MLNG Dua and MLNG Tiga, in joint venture with Petronas.

The complex is supplied with gas from gas fields in the Central Luconia area, which are located 125km to 275km offshore Bintulu, Sarawak. LNG from the complex is exported by vessels primarily to customers in Japan and China, and few more countries in the Asia Pacific. The shipping activities are overseen by MISC, a subsidiary of Petronas.

“The complex is supplied with gas from gas fields in the Central Luconia area, which are located 125km to 275km offshore Bintulu, Sarawak.”

Subsidiary Petronas LNG Train 9 was created in January 2012 to add the ninth LNG train to the complex and revamp the existing Trains 4, 5 and 6. The 3.6 million tonnes per annum (mtpa) LNG Train 9 will increase the complex’s production capacity from 25.7mtpa to 29.3mtpa. It is scheduled for completion in late 2015.

Petronas Bintulu LNG complex details

The first train at the complex came online in August 1982 and the first cargo from the complex was exported to Japan in January 1983. Two more trains were commissioned in the first plant by 1984. Each train has a production capacity of 2mtpa.

The second plant, featuring LNG Trains 4 and 6 with a production capacity of 2.65mtpa each, came online in 1996, while the third plant featuring Trains 7 and 8, with a capacity of 3.8mtpa each, came online in 2004.

Petronas LNG Train 9 project details

The project will involve the construction and installation of gas receiving facilities, an acid gas removal unit, a dehydration and mercury removal unit, a fractionation and liquefaction unit, an LNG rundown unit, and associated utilities and facilities.

The new LNG train will also implement Air Product’s proprietary Split MRTM liquefaction process technology similar to the remaining trains.

The project will require an additional supply of approximately 850 million standard cubic feet per day (mmscfd) of feed gas from fields offshore Sarawak. It will benefit by using the existing storage and loading facilities within the complex.

EPCC contractor for Petronas LNG Train 9

The front end engineering design (FEED) studies and early works for the new LNG unit were completed in December 2012, under a dual FEED scheme, by JGC Corporation and the joint venture (JV) of Chiyoda Corporation and Saipem. JGC was awarded the $2bn engineering, procurement, construction and commissioning (EPCC) contract in March 2013 based on the results of the FEED studies.

Petronas RAPID Project, Southern Johor, Malaysia

Malaysian oil and gas company (Petronas) is developing a refinery and petrochemical integrated development project (RAPID) in Pengerang, Southern Johor.

JGC was awarded another EPPC contract worth JPY60bn (approximately $504m) in January 2015 to install piping and ancillary facilities to connect the existing six LNG storage tanks and the seventh new LNG storage tank with the shipping facilities at the complex. The company was also involved in constructing all the existing eight trains and is involved in revamping the existing Trains 4, 5 and 6.

Other contractors involved with the LNG Train 9

Gas turbo-compression equipment and variable speed drive systems for the liquefaction facility are being supplied by GE Oil & Gas, while air-cooled heat exchangers are being supplied by Hamon D’Hondt.

Ebara International was contracted in April 2013 to supply 12 cryogenic pumps and expanders for the project.

Contractual, commercial and quantity surveying services are being provided by Cannonway Energy. An absorber facility weighing 1,480t was transported from the Malaysian Bintulu port to the project site by Scheuerle.

The structural steel works and civil defence shelter doors for the project are being supplied by TTJ Holdings, while the steel structure erection works are being performed by Muhibbah Engineering.

Boil-off gas (BOG) re-liquefaction facility

The latest major activity at the complex prior to the implementation of the Petronas LNG Train 9 Project involved the installation of the 1,840t/d capacity new boil-off gas (BOG) re-liquefaction facility to reliquefy the excessive BOG evaporating out of the LNG storage tanks.

The facility incorporates Linde’s proprietary LNG process and core cryogenic heat exchanger. Siemens supplied a cryogenic-temperature BOG turbo compressor and a single-casing LNG-refrigerant turbo compressor. The compressors are both driven by Siemens’ SGT-700 mechanical drive gas turbines.

Launched in May 2012, PIC is part of the larger Pengerang Integrated Petroleum Complex (PIPC) proposed by the Johor State Government. Total investment for the PIPC project is approximately RM97bn ($27bn), of which the RAPID project costs RM57bn ($16bn) and the associated facilities require RM40bn ($11bn).

A feasibility study along with site topographical survey and soil investigation work for the project were completed in October 2011. A front-end engineering design (FEED) study and an environmental impact assessment study have also been completed.

In April 2014, Petronas Board of Directors has approved the final investment decision (FID) for the RAPID project. The refinery project is anticipated to be completed by early 2019. It is expected to employ 70,000 workers during construction and generate 4,000 new jobs upon completion.

RAPID project site details and facilities

“The complex will cover an area of 2,000 hectares and will produce nine million tons of petroleum products and 4.5 million tons of petrochemicals a year.”

Southern Johor was chosen as the location for the project due to its proximity to deepwater port facilities and regional demand centres. The location enables easy transport of finished products to the market.The complex will cover an area of 2,000ha and includes a 300,000 barrels per day (bpd) crude oil refinery and a petrochemical complex. These two projects together will produce 7.7mtpa of differentiated and specialty chemicals such as synthetic rubbers and high-grade polymers.

The RAPID project refinery will produce gasoline and diesel which will meet Euro 4 and Euro 5 fuel specifications. It will also supply feedstock for the petrochemical complex which will produce highly-specialised chemicals. The refinery will use modern technologies to produce these products and follow stringent environmental regulations.

Associated facilities of Petronas PIC project

Related project:

Malaysian Super Refinery and Pipeline Project, Malaysia

In April 2007 it was reported that Malaysia had developed a plan to build two refineries and a 320km pipeline in the north of the country in order to have a more integrated petroleum refining policy.

The PIC project includes construction of associated facilities including a naphtha cracker complex with a capacity of 3Mtpa of propylene, C4 and C5 olefins, and a petrochemical and polymer complex to produce C4 and C5 derivates.

An agreement was signed with Itochu and PTT Global Chemical in May 2012. The two companies will partner to develop a few downstream units of the complex.

In June 2012, Petronas and BASF signed an agreement to develop two projects including the RAPID project. Under the agreement, the two companies will build facilities for the production of polyisobutylene, isononanol, non-ionic surfactants and methanesulfonic acid. Some of these facilities will be part of the RAPID project.

BASF signed this agreement as part of its plans to generate 70% of its sales from the Asia Pacific region. It already operates the Gebeng complex along with Petronas through BASF Petronas Chemicals.

In January 2013, Petronas signed a partnership agreement with Evonik Industries to collaborate to develop chemical facilities that produce hydrogen peroxide, C4 co-monomer and oxo-products. The chemical plants will produce up to 250,000t/y of hydrogen peroxide, 220,000mt of isononanol (INA) and 110,000mt of 1-butene. These plants are expected to be operational by 2016.

In November 2014, Petronas broke ground for a Pengerang Co-Generation Plant (PCP) in the PIC complex. The PCP will have four co-generation units and generates 1.22GW of electricity and supplies power to the entire PIC complex. It will also provide a continuous supply of steam up to 1,480t per hour for plants within the complex. The first co-generation unit is expected to become commercially operational by mid-2017.

The PCP is being constructed by a consortium of three firms including Siemens AG, Siemens Malaysia and MMC Engineering. Petronas, in November 2014, awarded a contract to construct Polypropylene (PP) plant in the RAPID complex to an US-based LyondellBasell’s Spherizone and Spheripol polypropylene process technologies. The PP plant will produce a wide range of PP products and will have a production capacity of producing 900,000t/y.

Petronas is also exploring the viability of constructing a liquefied natural gas (LNG) terminal to support the RAPID project. The LNG terminal will include natural gas receiving facilities for LNG carriers and a tie-in to the Peninsular Gas Utilisation system.

Other ancillary projects include air separation unit, raw water supply project (PAMER), crude and product tanks, and centralised and shared utility facilities.

Expansion of the petrochemical industry in Malaysia

The project will help Petronas to produce premium petroleum products and specialty chemicals. Demand for such high-value products is increasing, especially in the Asia Pacific region. The RAPID project will enable Petronas to meet this demand for the next 20 years.

Development of the project is also in line with Malaysia’s aim to establish new areas of growth, aimed towards improving people’s quality of life. The petrochemical industry has been identified as the main sector for achieving this growth.

The RAPID project is expected to help transform Southern Johor into a new petrochemical hub. Several employment opportunities are also expected to be created in the region by suppliers and related industries.

Petronas already operates petrochemical complexes in Melaka, Kertih and Gebeng. The RAPID project is much larger than the existing complexes, and is expected to spur economic growth in the region as well as attract domestic and foreign direct investments into the country.

Shell (the operator) and ConocoPhillips hold 35% interest each in the development, while Petronas Carigali owns the remaining 30% interest. Production from the project is scheduled to start in early 2017.

Front-end engineering and design (FEED) activities for the project started in 2009 and the final investment decision was made in February 2013.

Malikai oilfield discovery

The production sharing contract for the Block G was awarded in 1995 and the oilfield was discovered in 2004 by drilling the Malikai-1 exploration well. The field was appraised in 2005 and 2006.

Development details

The deepwater offshore oilfield development involves the drilling of 17 wells, employing a 26,000t tension leg platform (TLP) production facility, the first of its kind in the Malaysian waters. The riserless tophole drilling of eight wells will be carried out using a Norshore Atlantic multipurpose drilling vessel.

Production from the field’s offshore facilities will be tied back by subsea pipelines to Kebabangan (KBB) shallow-water hub gas processing facility, from where it will further be conveyed to Sabah Oil & Gas Terminal (SOGT) for export.

Subsea export facilities will comprise an eight-inch-diameter, 50km-long gas pipeline and ten-inch-diameter, 55km-long liquid pipeline, including steel catenary risers (SCRs).

Details of Malikai TLP

Malikai TLP’s topside will weigh 14,000t and its hull will weigh 12,000t. The facility will be classed by ABS.

The manned topside will be equipped with power generation, metering, separation, liquid pumping, gas compression, chemical storage, living quarters and water injection facilities. The hull, to be fastened and attached to the seafloor, will feature components, including marine systems, tender assisted drilling (TAD) units, foundation driven piles and suction anchor piles.

The topside of the TLP will be capable of accommodating 24 well slots. The TLP will have a processing capacity of 60,000bpd and 1.4 million cubic metres or 50 million standard cubic feet per day of gas.

Contractors involved

The FEED of the offshore oil project was performed by AMEC. The engineering, procurement and construction (EPC) contract for the TLP was awarded to a 50:50 joint-venture (JV) of Technip and Malaysia Marine and Heavy Engineering Holdings Berhad (MHB). Technip will also supply and install the subsea pipelines, engaging its Global 1201 S-Lay vessel.

Drilling and production equipment, including subsea wellheads, tensioner systems, risers, production trees, injection trees and tieback connectors, will be supplied by Dril-Quip Asia Pacific, a subsidiary of Dril-Quip in collaboration with UMW Petrodril.

Frames has been subcontracted by the Technip-MHBE JV to supply three shell and tube heat exchangers, as well as a gas dew pointing unit, based on low-temperature separation (LTS) technology.

Transportation and installation of the TLP will be jointly performed by IEV Malaysia and Heerema Marine Contractors (HMC), under a contract worth $100m. They will also perform the pre-installation works for the TLP tendon foundation piles, tendons, suction anchor piles and pre-laid mooring lines.

Flowserve has been contracted to supply its water injection and liquid transfer pumps for the TLP. The company will also supply pumps for seawater lift, firewater, drain caisson, flare knockout drum, circulation and sump services.

IKM’s second-generation MMR riserless mud recovery technology will be employed for tophole drilling by the Norshore Atlantic drilling vessel. Virgo Valves will supply 1,900 shutdown, blowdown, motor-operated and manual ball valves for the TLP.