Jun 2021: The Bid Round, postponed in 2020 due to Covid-19, has been re-opened with improved terms. There are 6 working areas on offer, 4 in a Direct Proposal Tender mechanism and 2 in a Regular Tender mechanism.
Apr 2021: Eni (operator, 65%), Neptune (20%) and Pertamina (15%) started gas production from the Merakes Project in the East Sepinggan block in the Kutei Basin of the Makassar Strait in 1,500m of water. Five subsea wells provide a capacity of 4.65 bcm a year. The field is tied back to the Jangkrik FPU. Processed gas is sent to the Onshore Receiving Facility in Senipah.
Feb 2021: Petronas (100%) made an oil discovery at the Hidayah-1 exploration well in the North Madura II PSC, offshore East Java. The well encountered the oil-bearing Ngimbang carbonate formation and was tested at approximately 2,100 bbls of oil per day.
Jan 2021: Cue Energy (12.5%) reports that production has started from the PB-1 well (PB field) discovered in the Mahato PSC in Central Sumatra in 2019 at around 600 bbls of oil per day. The PB-2 well and 3 new development wells are expected to come onstream soon.
Jan 2021: The Minister of Energy and Mineral Resources approved the plan of development (POD) for Repsol’s Kali Berau gas/condensate field in the Sakakemang block. Gas will be piped to the existing Grissik Central Gas Plant. The Kali Berau field was discovered in early 2019 and holds up to 56 bcm of recoverable gas plus condensate.
Aug 2020: SKK Migas approved development of the Paus Biru gas field discovered in 2018 in the offshore Sampang PSC. Santos is operator with Cue Energy. Production will come from a single horizontal well through an unmanned WHP tied to the Oyong field and then to the Grati onshore production facility. FID is expected by mid 2021 with first gas in late 2022.
Dec 2019: Premier Oil (operator) has achieved first gas from the Bison, Iguana and Gajah Puteri (BIG-P) project in the Natuna Sea Block A. BIG-P’s recoverable reserves are estimated around 2.7 bcm of gas with production tieing into existing Block A infrastructure exporting gas to Singapore.
Jun 2019: Inpex and Shell submitted a revised Plan of Development (POD) for the Abadi field in the Masela Block, Arafura Sea. It is based on an onshore LNG development with a production capacity of 9.5 mmtpa. An amendment has also been submitted requesting an extension of the PSC to 2055.
Mar 2019: Kangean Energy started producing gas from the Sirasun and Batur fields in the Kangean block, 90 kms north of Bali in a water depth of 90m. The fields are part of the TSB complex where the Terang field has been producing since 2012. Gas is processed at an FPSO and piped onshore to East Java.
Feb 2019: Repsol (operator, 45%), Petronas (45%) and MOECO (10%) have made the largest gas find in the country for 18 years with the Kali Berau (KBD)-2X well in South Sumatra in the Sakakemang block.
Dec 2018: The winner of the 3rd bidding round has been announced. Pearl Oil will operate the South Andaman block, offshore of Aceh, Talisman (South Saka Kemang block, onshore South Sumatra) and Pertamina (Maratua block, on and offshore NE Kalimantan). Nine blocks were awarded in 2018 compared to 5 in 2017.
Dec 2018: Cue Energy (15%) along with Santos (operator, 45%) and Singapore Petroleum (40%) announced a gas discovery at the Paus Biru-1 well, Sampang PSC, offshore East Java in the Madura Strait. It is 27 kms east of the producing Oyong Gas Field. A Plan of Development through Oyong facilities will now be prepared.
Apr 2018: The development plan for the Merakes gas field in the offshore Kutei Basin, East Sepinggan PSC, has been approved. It includes the drilling of 6 subsea wells tied back to the Jangkrik FPU. Eni is operator with 85%, along with Pertamina Hulu (15%).
Apr 2018: Black Platinum completed a Preliminary Plan of Development for the Dara East gas field in 110m of water in the East Natuna Sea. The plan includes a Central Floating Processing Unit and satellite Wellhead Platforms with gas exported via a pipeline to the West Natuna Transport System (WNTS). The Field would be the first development in East Natuna with first gas by 2023.
Jan 2018: The Energy and Mineral Resources Ministry plans to offer 40 conventional and 3 unconventional blocks through a tender in early March, including 32 blocks that failed to attract investors in 2015-2017 auctions. In Dec 2017 the ministry announced it had bidders for 5 of 15 blocks offered through that year’s auction.
Aug 2017: Husky-CNOOC (operator, 40% each) and Samudra (20%) started production from the BD gas field in the Madura Strait at a water depth of 55m. Facilities include an unmanned WH platform, an FPSO and 4 production wells. The field is expected to reach peak production in 2018.
May 2017: Indonesia is offering 10 conventional and 5 unconventional (shale gas and CBM) blocks to bidders with more flexible production sharing rules.
May 2017: Eni has started gas production from the deep water Jangkrik field. Production from 10 subsea wells, connected to a new Floating Production Unit (FPU), will gradually reach 4.5 bcm a year and flow via a 79km pipeline to the Onshore Receiving Facility and then the Bontang LNG plant.
Feb 2016: ENI has drilled and tested Merakes-2 in 1,269m of water, the first appraisal well of the Merakes gas discovery in the East Sepinggan PSC, Kutei Basin. The field is close to ENI’s Jangkrik gas field due onstream in 2017 through an FPSO in the Muara Bakau PSC.
Dec 2016: Total expects gas output at its offshore Mahakam Block in East Kalimantan to be 14.8 bcm in 2017 against 16.9 bcm in 2016. Mahakam is in decline but performed better than expected in 2016. Oil output is expected to be 53,000 bbls per day in 2017 against 64,000 bbls per day in 2016.
Nov 2016: Output from the Bontang LNG plant, operated by Badak NGL, will decline by up to 10% in 2017 due to falling supplies from the Mahakam block. Bontang has been operating since 1977. Pertamina is due to take over operation of the Mahakam block in January 2018 from Total.
Aug 2016: Chevron (operator, 62%) announced start-up of gas production from the Bangka Field Development Project, the first stage of the Indonesia Deepwater Development (IDD) Project in East Kalimantan. Partners are Eni (20%) and Tip Top (18%). Development drilling commenced in 2014.
Jul 2016: The Ministry of Energy of Mineral Resources (MEMR) issued an invitation for companies to bid on 14 onshore and offshore blocks under the Conventional Oil and Gas Bidding Year 2016. Seven of these blocks will be awarded through direct negotiations, the remainder through a regular tender.
Jul 2016: BP announced that the FID has been approved for expansion of Tangguh LNG in Papua Barat Province adding a 3rd train and 3.8 mm tpa ofcapacity to the existing facility, bringing total plant capacity to 11.4 mm tpa. The project includes 2 offshore platforms and 13 wells. Around 75% of production has been sold to the state electricity company. Start-up is expected in 2020.
Jun 2016: SKKMigas has rejected a proposal to increase oil output from the Cepu block operated by Exxon Mobil to up to 200,000 barrels per day.
May 2016: Oil output from ExxonMobil's Banyu Urip project in the Cepu block in East Java could reach 200,000 bbls per day (from185,000 at present) if the government approves an increase. Production from Cepu more than tripled through 2015 reaching 130,000 bbbls per day at the end of the year.
Mar 2016: Inpex (operator, 65%) and Shell (35%) will delay the development of the Abadi LNG project by at least 2 years. The project, which may be floating or land-based, will not be operational until at least 2026. The Indonesian government favours a land-based approach.
Dec 2015: Exxon Mobil (operator, 45%) along with Pertamina (45%) and 4 local government entities (10%) have started the processing facility at the onshore Banyu Urip field in central Java. It could produce over 450 mm barrels of oil over its lifetime from 45 wells in 3 well pads, delivering to an FSO in the Java Sea. The field commenced production in late 2008.
Nov 2015: The government has invited bids for 3 shale gas blocks; Blora in Central Java, Batu Ampar in East Kalimantan and Central Bangkanai in Central Kalimantan. Indonesia has identified 7 shale gas basins; Baong, Telisa and Gumai in Sumatra, 2 in Java and 2 in Kalimantan.
Oct 2015: PT Energi Mega Persada Tbk (EMP) has received approval to develop the Seng and Segat gas fields in the Bentu block in Riau, Sumatra increase the block’s output from 0.5 bcm each year to nearly 1 bcm from 2017.
Sep 2015: Indonesia plans to offer 21 conventional and unconventional oil and gas blocks in a tender in 2016 including existing fields, shale gas blocks and CBM blocks in an open tender. Separately the country will offer up to 11 conventional and unconventional blocks in 2015.
Sep 2015: Inpex (65%, operator) and Shell (35%) have submitted a new plan of development for the Abadi gas field in the Masela Block, Arafura Sea including an FLNG plant with a processing capacity of 7.5 mm tonnes per annum and 24,000 bbls of condensate per day. Three appraisal wells were drilled in 2013 and 2014 confirming a greater volume of gas reserves.
Aug 2015: SKK Migas approved development of the Tiung Biru and Jambaran fields in Java. The unitised fields will commence production of gas and condensate in 2019. Tiung Biru is in Pertamina’s Cepu operations area and Jambaran is in the Cepu block, operated by ExxonMobil.
Jul 2015: Husky and CNOOC report that shallow water gas projects in the Madura Strait are on track for first production in 2017. A wellhead platform and FPSO at the liquids-rich BD field are being built whilst tendering is underway for facilities to develop the MDA-MBH fields.
Jul 2015: The Donggi Senoro LNG facility started production after feed gas was delivered from the Senoro gas field. The US$2.8 bn DSLNG plant is owned by Pertamina Hulu Energy, Medco LNG and Sulawesi LNG located in Central Sulawesi 25 km SE of Luwuk.
May 2015: Petronas (operator, 80%) and PGN (20%) commenced production at the Bukit Tua field in the Ketapang Block off East Java. The field will produce 20,000 bbls of oil per day and 0.5 bcm per year of gas into the Ratu Nusantara FPSO at peak. Gas will be piped to the onshore receiving facility (ORF) in Gresik while oil will be offloaded to carriers for export.
May 2015: ExxonMobil is ramping up production at the Banyu Urip field in the Cepu Block in Java targeting peak output in 2015 of 200,000 bbls per day. It was producing 75,000 bbls per day at the end of April. Recoverable resources are estimated at over 450 mm bbls.
Apr 2015: Inpex (operator, 65%) plans to increase its FLNG plant capacity at the offshore Masela block (Abadi field) from 2.5 mm tonnes per year to 7.5 mm. The project was expected to start production in 2018 but may be pushed back to 2020. Shell (35%) is Inpex’s partner.
Jan 2015: Indonesia targets producing 825,000 bbls of oil per day in 2015 (3.9% more than 2014) and plans to offer 8 onshore and offshore exploration blocks in 2015. A total of 17 contracts will expire between 2015 and 2019. Meanwhile the country intends to invest in regasification terminals in the west to meet growing domestic demand for gas.
Jan 2015: The government will offer 8 conventional blocks in 2015; 4 in direct tender (Rupat - Riau Off, North Jabung - Riau On, Southwest Bengara - Kalimantan On, West Berau - West Papua Off); and 4 in regular tender (West Asri, Lampung Off, Oti - East Kalimantan Off, North Adang - West Sulawesi Off and Kasuri II - Papua On).
Oct 2014: Full operation of the US$12bn Indonesia Deepwater Development (IDD) gas project has been delayed to 2020. Chevron is reassessing the Gendalo , Gehem, Gandang and Maha fields although Bangka is still scheduled to start producing in 2016. The full development will have 2 production hubs, each with an FPU. Gas will be piped to the Bontang LNG plant.
Oct 2014: Eni (operator, 100%) has made a gas discovery in the Merakes-1 well in the East Sepinggan Block offshore East Kalimantan at a water depth of 1,372m, 35 kms from the Jangkrik field. The field could supply additional gas volumes to the Bontang LNG plant.
Oct 2014: After 36 years of production, the Arun LNG plant in North Sumatra is to close with a last cargo exported to South Korea. The plant will be converted to a regasification terminal and will receive its first LNG shipments from the Tangguh project in 2015.
Sep 2014: Oil output from Exxon Mobil ‘s Cepu block near Surabaya in East Java will peak in the middle of 2015. The Banyu Urip field is expected to produce an average of 119,000 bbls per day in 2015 reaching a peak of 165,000 bbls per day.
Aug 2014: Kris Energy has submitted a plan of development for the Lengo gas field offshore East Java in the Bulu PSC. The development will include an unmanned wellhead platform, 5 wells and a single well tie-back from the East Lengo discovery, 15 kms away in the East Muriah PSC. First production is scheduled for late 2016 via a 65 km pipeline to shore.
Jul 2014: Energi Mega Persada (EMP) commenced first production at the Kuat gas field in the Malacca Strait PSC in Central Sumatra. The PSC is operated by EMP (60.49%) with CNOOC (39.51%). It produced 5,436 bbls of oil per day in the first quarter of 2014.
Jul 2014: Technip has been awarded a contract by Pertamina for the Matindok Gas Development project in Central Sulawesi covering engineering, construction and installation of gas well pads, flowlines, pipelines and a central processing plant. Gas will be sent to the Donggi-Senoro LNG plant. The project includes the Donggi, Matindok, Maleoraja and Minahaki fields.
Jul 2014: KrisEnergy will acquire from Premier its 41.7% interest in the onshore Block A Aceh PSC in North Sumatra. Medco is the operator (41.7%) along with Japex (16.7%). The block contains several gas condensate discoveries including the Alur Rambong, Alur Siwah and Julu Rayeu fields. First gas from Alur Rambong is due in 2017.
Jun 2014: Premier reports that its offshore Singa Laut-1 well in the Tuna PSC has encountered wet gas. The well penetrated 54m of reservoir sands within the Oligocene and will now be plugged and abandoned before appraisal drilling to assess the combined Singa Laut/Kuda Laut oil and gas resources in 2015.
May 2014: Inpex announced that gas production has started from the South Belut field in a water depth of 100m in the South Natuna Sea Block B. ConocoPhillips is operator with Inpex and Chevron. The block also holds the Belida oil field, the Belanak oil and gas field, and the Tembang, Hiu, Kerisi, North Belut and Bawal gas fields. South Belut has the potential to produce 1.25 bcm each year to Singapore.
May 2014: Development on the Banyu Urip oil and gas project in Bojonegoro, Cepu Block, East Java, is almost complete with a target of 165,000 bbls per day in 2015. The project, operated by ExxonMobil (45%), has produced 38 mm bbls barrels of oil since early production began in August 2009 and is now at 29,000 bbls per day. Pertamina's has 45% and Badan Kerja Sama (10%).
Apr 2014: Premier Oil (operator, 65%) announced an oil and gas discovery at the Kuda Laut-1 well in the Tuna PSC in the Natuna Sea. The well drilled 56m of net oil-bearing reservoir and 100m of net gas-bearing reservoir. The well will be side-tracked to drill the Singa Laut prospect in an adjacent fault block.
Mar 2014: Santos reports that production has commenced from the Peluang gas field off East Java., a tie-back to the Maleo field in the Madura Offshore PSC. It will have peak production of 0.25 bcm each year and will be used by domestic consumers in East Java along with gas from Santos fields; Oyong, Wortel and Maleo. Operator Santos has 67.5% with partners Madura Ltd. and PT Petrogas Pantai Madura.
Mar 2014: Chevron's Indonesia Deepwater Development (IDD) gas project off Kalimantan will be delayed to 2018 pending completion of a tender for the floating production units. Daily production from the project is expected to peak at 11 bcm per year and 31,000 bbls per day of condensate.
Feb 2014: Production from the Seram oilfields in the (Non-Bula) Block Renewal PSC is averaging 2,831 bbls per day, a 20% increase after completion of the Oseil-26 well. The next well will be Oseil-21 followed by the Lofin-2 appraisal well. CITIC Seram Energy (51%) is operator with partners KUFPEC (30%), Gulf Petroleum (16.5%) and Lion (2.5%).
Feb 2014: The US$4.1 bn development of Jangrik and North East Jangrik gas and condensate fields in 500m of water, operated by Eni, is to go ahead with an FPU at 120m water depth and 11 development wells. The 2 fields are expected to commence production in 2017, reaching peak output of 4.6 bcm for 6 years. Initially 70% of its gas will be set aside for export as LNG.
Jan 2014: BP, operator with 37.16%, will award a FEED contract for a third train at the Tangguh LNG plant in Bintuni Bay, West Papua by the end of March. Estimated to cost US$12 bn first shipment will be in 2019 if a decision to go ahead is made in 2015. Capacity will be 3.8 mm tons per year to add to the 2 trains in operation which produce a total of 7.6 mm tons per year.
Dec 2013: Indonesia plans to offer 27 oil and gas blocks in 2014 in both regular tenders and direct offers. The blocks on offer include 20 conventional blocks, 6 shale gas blocks and 1 coal bed methane block.
Oct 2013: Mubadala announced that production has commenced at the Ruby gas field in the Sebuku PSC in the Makassar Strait. Ruby has 4 wells, 2 platforms and a 312 km subsea pipeline that connects to the terminal at the Senipah onshore processing plant operated by Total. Mubadala holds 70% and is the operator of the Sebuku PSC, with Total and Inpex each with 30%.
Sep 2013: Indonesia's Ministry of Energy and Resources has invited companies to bid for 18 onshore and offshore blocks mostly in the east. Sixteen are being offered through direct bids, while two will be through a regular tender.
Aug 2013: Santos has acquired 50% of the Northwest Natuna PSC from AWE, containing the undeveloped Ande Ande Lumut oil field. The field development plan includes a well-head platform and a permanent FPSO. Santos will take as operator.
May 2013: Ramba Energy has announced the Akatara-1 well in the Lemang block tested gas and condensate in several reservoirs. A full Extended Well Test and appraisal well are planned. The Lemang block lies in the northern part of the South Sumatra basin. In December 2012, Ramba announced a discovery at the Selong-1 well, the first to be drilled in the block. Ramba holds 51%.
Apr 2013: Santos received sanction for the Peluang gas project in February 2013. Peluang involves a tieback to the existing platform and facilities at the Maleo gas field and will include one horizontal gas well, a stand-alone wellhead platform and a pipeline to Maleo. First gas is expected in first quarter 2014.
Feb 2013: SKMigas has approved the $1.4 bn development of Eni’s Jangkrik field in East Kalimantan. The field will go on stream in 2015 reaching peak production of 1.5 bcm per year. Gas and condensate will be exported from a floating production unit to the Bontang LNG plant via 86 km subsea pipelines. Eni operates with 55% with partner GDF Suez (45%).
Jan 2013: ExxonMobil’s Cepu Block will reach full production in the 3rd quarter of 2014, behind the initial schedule for May 2014. Cepu is currently producing 24,000 bbls per day with a target production of 165,000 bbls per day.
Nov 2012: Total (operator, 50%) and Inpex (50%) announced start-up of the South Mahakam project to offset decline in the Mahakam PSC. The development comprises 3 gas condensate fields (Stupa, West Stupa and East Mandu), and 2 gas fields (Jempang and Metulang), 35 kms SE of Balikpapan. The first phase includes 3 platforms and 19 wells with production planned to reach 69,000 bbls per day oil equivalent at the end of 2013. Gas and condensate will be exported through a new pipeline to the Senipah terminal and used for both LNG at Bontang and to supply domestic clients.
Nov 2012: A US$12.1 bn deal has been announced involving expansion of the Tangguh LNG project in Papua Barat province, eastern Indonesia. The expansion will add a third 3.8 mmtpa LNG train bringing total capacity to 11.4 mmtpa. FID is expected in 2014 with operations beginning in 2018. Partners have agreed to sell 40% of output from the third train to state electricity company PT PLN (Persero). Tangguh is operated by BP (37.16%) with MI Berau B.V (16.30%), CNOOC (13.90%), Nippon (12.23%), KG Berau/Wiriagar (10.00%), LNG Japan Corporation (7.35%), and Talisman (3.06%).
Sep 2012: Regulator BPMigas is evaluating the plan of development (POD) submitted by Pertamina, operator of the Tiung Biru oil and gas field in the Cepu Block, East Java. The field lies in the same area as the Jambaran field, operated by Mobil Cepu, a subsidiary of ExxonMobil. Pertamina has drilled 3 wells in Tiung Biru and 4 out of 7 wells in Jambaran this year. The Tiung Biru field is reported as having the potential to first produce 2,546 bbls per day of oil and then 0.28 bcm per year of gas. The gas would be delivered to local fertilizer or petrochemical companies.