• Introduction

• 2019-2022 bidding round

• Onshore: TL-OT-17-08 and TL-OT-17-09 (2017, Timor Resources/TimorGAP)

• Pualaca onshore: TL-OT-21-17 (2021, TimorGAP)

• Rarahana onshore: TL-OT-22-18 (2022, TimorGAP)

• Onshore: TL-OT-22-22 (2024, HTS)

• Offshore: SO-15-01 (2015, TimorGAP)

• Offshore: SO-22-23 (2023, Eni)

• Chuditch offshore: SO-19-16 (2019, Sunda Energy/TimorGAP)

• Kuda Tasi/Jahal offshore SO-19-11 formerly JPDA 11-106 (2013, ENI/InpexFinder/TimorGAP)

• TLEA 06-01A, 06-02B, 06-03C, 06-04E, 06-05H, 06-06K (2006, all relinquished)

• JPDA 06-102 (2006, Petronas, relinquished)

• JPDA 06-103 (2006, Oilex, relinquished)

• Kitan JPDA 06-105 (2006, WoodsideEni et al) replaced by PSC TL-SO-T-19-10

• Bayu-Undan JPDA 03-12, 03-13 (2003, Santos et al) replaced by PSC TL-SO-T-19-12 and TL-SO-T-19-13

• Carbon Capture and Storage at Bayu-Undan

• Sunrise JPDA 03-19, 03-20 (2003, TimorGAP, Woodside et al)

• Buffalo offshore SO-19-14 (2019, BHP then Carnarvon & Advance, relinquished)

• Laminaria-Corallina (1994, Woodside then NOGA, then closed)

• The future

• Introdusaun

• 2019-2022 konkursu tenderizasaun

• Onshore: TL-OT-17-08 no TL-OT-17-09 (2017, Timor Resources/TimorGAP)

• Pualaca onshore: TL-OT-21-17 (2021, TimorGAP)

• Rarahana onshore: TL-OT-22-18 (2022, TimorGAP)

• Onshore: TL-OT-22-22 (2024, HTS)

• Offshore: SO-15-01 (2015, TimorGAP)

• Offshore: SO-22-23 (2023, Eni)

• Chuditch offshore: SO-19-16 (2019, Sunda Energy/TimorGAP)

• Kuda Tasi/Jahal offshore SO-19-11 uluk JPDA 11-106 (2013, ENI/InpexFinder/TimorGAP)

• TLEA 06-01A, 06-02B, 06-03C, 06-04E, 06-05H, 06-06K (2006, hotu hapara ona)

• JPDA 06-102 (2006, Petronas, hapara ona)

• JPDA 06-103 (2006, Oilex, hapara ona)

• Kitan JPDA 06-105 (2006, WoodsideEni et al) substitui ba PSC TL-SO-T-19-10

• Bayu-Undan JPDA 03-12, 03-13 (2003, Santos et al) substitui ba PSC TL-SO-T-19-12 no TL-SO-T-19-13

• Kaptura no rai hela karbonu iha Bayu-Undan

• Sunrise JPDA 03-19, 03-20 (2003, TimorGAP, Woodside et al)

• Buffalo Offshore SO-19-14 (2019, BHP, depois Carnarvon no Advance, hapara ona)

• Laminaria-Corallina (1994, Woodside, depois NOGA, depois taka)

• Futuru

Petroleum activities both in the Joint Development Area (JPDA) and Exclusive Area (TLEA) are conducted according to Production Sharing Contracts (PSCs) signed between the oil companies and the National Petroleum and Minerals Authority (ANPM), or its predecessor the Timor Sea Designated Authority (TSDA). Under Article 30.1(a)(i) of Timor-Leste's 2005 Petroleum Act and Article 20.1(a) the Interim Petroleum Mining Code for the JPDA, all PSCs signed after that date are public documents. The 2005 legislation also included model PSCs for the TLEA and JPDA, which serve as templates for the PSCs for each specific area.

In 2016, Timor-Leste enacted Decree-Law 32/2016 (also Portuguese) to regulate offshore Petroleum Operations in the TLEA. Decree-Law 18/2020 (Port.) was enacted in 2020 to cover petroleum operations onshore.

With the entry into force of the Australia-Timor-Leste Maritime Boundary Treaty in August 2019, the Joint Petroleum Development Area ceased to exist, although Greater Sunrise will continue to be under a bi-national special regime. New contracts had to be signed for each project. (See map below.)

Annual reports from the TSDA are no longer on an official website, but you can get them here for 2003, 2004, 2005, 2006 and 2007.

In addition to the summaries below, the ANPM website includes some information, as well as the following ANPM annual and quarterly reports:

• 2008 Annual Report (English 4.6 MB)

• 2009 Annual Report (English 2.7 MB)

• 2010 Annual Report (English 4.5 MB or Tetum 6.4 MB)

• 2011 quarterly reports:  Jan-Mar,  Apr-Jun,  Jul-Sep,  Oct-Dec  (all Tetum)

• 2011 Annual Report (English 2 MB)

• 2012 Annual Report (English 3 MB or Tetum 2 MB)

• 2013 Annual Report (English 4 MB or Tetum 2 MB)

• 2014 Annual Report (English 7 MB or Tetum 6 MB)

• 2015 Annual Report (English 5 MB or Tetum 3 MB)

• 2016 Annual Report (English 4 MB or Tetum 4 MB)

• 2017 Annual Report (English 7 MB or Tetum 4 MB)

• 2018 Annual Report (English or Tetum 22 MB)

• 2019 Annual Report (English 8 MB or Tetum 14 MB)

• Relatóriu Anual 2020 (Tetum 8 MB)

• Relatóriu Anual 2021 (Tetum 10 MB)

• Relatóriu Anual 2022 (English 11 MB)

In each of the contracts described below, the first-listed company (in bold) is the operator. If the contract number is a hyperlink, it links to the text of the contract itself.

Atividade petróleu iha Area Konjunta ba Dezenvolvimentu Petróleu (JPDA) no Area Eskluzivu (TLEA) la’o ona tuir Kontratu Fahe Produsaun (PSC) ne’ebé asina entre kompañia mina-rai sira no Autoridade Nasionál Petróleu Minerais (ANPM), ka órgaun ida ne’ebé troka Autoridade Designada ba Tasi Timor (TSDA). Tuir Artigu 30.1(a)(i) Lei Petróleu Timor-Leste iha 2005 (Ingles ka Portuges) no Artigu 20.1(a) Interim Petroleum Mining Code/Kódigu provizóriu ba Mineira Petróleu ba JPDA (Ingles), PSC tomak ne’ebé asina ona hafoin loron asina sai tiha dokumentu públiku. Lejizlasaun 2005 mós inklui modelu PSC (Ingles) ba Area Eskluzivu no JPDA, ne’e serbí nudár modelu ba PSC ba kada area espesífiku.

Agora, ita labele hetan Relatóriu Anuál sira husi TSDA husi website ofisiál ida, maibé  bele download iha ne'e iha Ingles ba tinan 2003, 2004, 2005, 2006 no 2007.

Aleinde ba sumáriu iha okos, website ANPM nian inklui informasaun balu, no mós Relatóriu anuál no relatóriu trimestral ANPM nian:

• Relatóriu Anuál 2008 (Ingles 4.6 MB)

• Relatóriu Anuál 2009 (Ingles 2.7 MB)

• Relatóriu Anual 2010 (Tetun 6.4 MB ka Ingles 4.5 MB)

• Relatóriu trimestral 2011: Jan-Mar, Abr-Jun, Jul-Set, Out-Dez (hotu iha Tetun)

• Relatóriu Anuál 2011 (Ingles, 2 MB)

• Relatóriu Anual 2012 (Tetun 2 MB ka Ingles 3 MB)

• Relatóriu Anual 2013 (Tetun 2 MB ka Ingles 4 MB)

• Relatóriu Anual 2014 (Tetun 6 MB ka Ingles 7 MB)

• Relatóriu Anual 2015 (Tetun 3 MB ka Ingles 5 MB)

• Relatóriu Anual 2016 (Tetun 4 MB ka Ingles 4 MB)

• Relatóriu Anual 2017 (Tetun 7 MB ka Ingles 4 MB)

• Relatóriu Anual 2018 (Tetun ka Ingles 22 MB)

• Relatóriu Anual 2019 (Tetun 14 MB ka Ingles 8 MB)

• Relatóriu Anual 2020 (Tetun 8 MB)

• Relatóriu Anual 2021 (Tetun 10 MB)

• Relatóriu Anual 2022 (Tetun 12 MB)

Iha kada kontratu ne’ebé hakerek iha okos, kompañia sira ne’ebé iha lista primeiru (ho letra mahar) mak operador. Karik númeru kontratu nian iha hyperlink, ne’e bele liga ba nia testu kontratu rasik.

Bidding round in 2019-2022

At the Timor-Leste Oil and Gas Summit in October 2019, the country opened its first public bidding round for new contract areas in 13 years. As shown on the map at right, virtually the entire country, both onshore and in the Timor Sea, is available, except for the north coast and a few areas with existing contracts.

The Covid-19 pandemic has caused many countries to extend or postpone bidding rounds for new petroleum exploration, and in July 2020 Timor-Leste extended theirs by one year, with bids due by October 2021. A few weeks before the deadline it was extended for four months more.

On 3 June 2020, the government published Resolution 3/2020 reserving up to 20% of each new contract for TimorGAP.

On 17 June 2020, the Norwegian seismic company TGS announced that it had begun a project with ANPM to combine all available data on offshore Timor-Leste into a single database to "impart confidence in [companies'] license round decision-making processes."

The organizers of the 2019 Summit held another (virtually) in July 2020, including a presentation by ANPM's Mateus da Costa on the bidding round. In December, they published an interview with him. A third (virtual) Summit was held in March 2021.

When the bidder pre-qualification period ended on 14 January 2022, nine companies had been qualified and four were still being reviewed. Bids were opened (FB video) on 5 March, with seven companies bidding for six of the 18 blocks, as follows:

On 12 April 2022, ANPM informed bidders and the public that the announcement would be delayed a week due to Easter and the election. Winners were announced on 22 April (see table and map at right):

EnergyVoice called the results "disappointing."

The winning bidders had until 29 June to sign the contracts, but on 8 November ANPM announced that the process was taking longer than expected, and would be finished by February 2023, although no announcement had been made by June.

Contract TL-OT-22-18 with TimorGAP for Block A ("Rarahana"), was signed on 22 December 2022; details below. A year later, Contract TL-SO-22-23 was signed with Eni for Block P; details below. In March 2024, Contract TL-OT-22-22 was signed with HTS for Block F; details below

Konkursu Tenderizasaun iha 2019-2022

Iha Outubru 2019 realiza ona Simeira Mina no Gas iha Timor-Leste, nasaun ne’e loke konkursu tenderizasaun públiku ba kontratu iha área foun sira iha tinan 13. Hanesan hatudu iha mapa sorin loos leten, virtualmente nasaun tomak, tantu iha rai-maran (onshore) no iha Tasi Timor, agora disponivel. Exceptu ba parte norte kostál nian no área balu ne’ebé iha ona kontratu.

Pandemia Covid-19 kauza ona nasaun barak mak prolonga ka adia sira konkursu tenderizasaun ba esplorasaun petrolíferu, no iha Jullu 2020 Timor-Leste prolonga sira nian ba tinan ida tan, ho prazu ba konkursu iha Outubru 2021. Semana hira hafoin loron taka konkursu, prolonga tan ba fulan haat.

Iha 3 Juñu 2020, Governu publika Rezolusaun 3/2020 rezerva kuaze 20% ba TimorGAP ba kada kontratu foun.

Iha 17 Juñu 2020, Kompañia Sízmiku Norwegia TGS anunsia katak sira hahú ona projetu ida ho ANPM atu kombina dadus ne’ebé disponivel on aba iha área tasi laran (offshore) Timor-Leste ba iha baze dadus ida de’it atu “Hatuur fiar ba kompañia sira iha prosesu foti desizaun ba iha konkursu tenderizasaun.”

Organizadora sira iha Simeira 2019 realiza mós enkontru virtual seluk iha Jullu 2020, inklui aprezentasaun husi Mateus da Costa husi ANPM nian kona ba konkursu tenderizasaun. Iha Dezembru, sira públika entrevista ida ho nia. Terseiru Simeira Virtual realiza iha Marsu 2021.

Bainhira periodu pre-kualifikasaun remata iha 14 Janeiru 2022, kompañia 9 mak konsege kualifikadu no 4 seluk sei nafatin iha revizaun nia laran. Proposta sira loke (video iha pajina Facebook) iha 5 Marsu, ho kompañia 7 konkore ba bloku 6 husi bloku 18, hanesan tabela iha sorin karuk.

Iha 12 Abril 2022, ANPM fó sai kona ba konkorrente sira no públika kona ba avizu ne’ebé prolonga tan ba semana ida tanba feriadu Páskua no eleisaun. Manan na’in sira anunsia iha 22 Abril (bele haree iha tabela tuir mai no mapa sorin loos).

Revista Energy Voice fó sai rezultadu katak "disappointing”.

Konkorente manán na’in asina iha 29 Juñu atu asina kontratu, maibé iha 8 Novembru ANPM fó sai katak prosesu hirak ne’e sei lori tempu naruk tan ba saida mak sira antisipa ona, no bele remata iha Fevereiru 2023.

Kontratu ho TimorGAP ba Bloku A asina iha Lautem iha 22 Dezembru 2022. Kontratu ho Eni ba Bloku P asina iha 14 Dezembru 2023.

Onshore PSCs TL-OT-17-08 and 09 awarded without tender in 2017

On 7 April 2017, the ANPM awarded two contracts for onshore oil and gas exploration to a joint venture equally owned by Timor Resources and TimorGAP.  Timor Resources, which is part of the Australian Nepean Group of companies, will be the operator for PSC TL-OT-17-08 (Covalima and Bobonaro municipalities, area A on map at right) and PSC TL-OT-17-09 (Manufahi and Ainaro municipalities, Area C), totalling 2,000 square kilometers.
   The contracts were celebrated by Timor-Leste's government (also 7 MB video), ANPM, TimorGAP and Timor Resources (also Technical press release). Although Timor-Leste's project proponents hoped for "maximum benefits for Timor," Australian news coverage in NT News and the Financial Review expected Darwin to benefit economically by providing logistical supply, as well as a possible refinery.
   In 2017, Timor-Leste held public consultations on draft regulations for onshore petroleum operations, and La'o Hamutuk made a submission.
    In August 2018, Timor Resources announced the award of a seismic exploration contract to BGP Indonesia. Seismic exploration began in October 2018.
    In September 2019 environmental assessment for drilling started, and drilling was expected to begin in March 2020.  Links to draft EIA and draft EMP from February 2020, which also include appendices on Waste mgmt (A), Rehabilitation (B), Redress (C), Oil spill response (D), Traffic mgmt (E), Noise mgmt (G), Incident reporting (H), Community consultation (I) and Air quality (J). Newer environmental documents for this project have been updated in La'o Hamutuk's environmental registry.
   On 16 January 2020, amendments were issued to the two PSCs, extending their areas by several km into the sea, modifying the decommissioning contract and adding specificity to the Local Content projects. Download addenda to PSC17-08 and PSC17-09 (also English).
   In April 2020, due to Covid-19 and the drop in worldwide oil prices, Timor Resources decided to suspend the project for 4-7 months until the situation changes. Initial drilling will not happen before October, if then. In July, Lusa reported that they hope to start drilling in late 2020 or early 2021.
   After years of deliberation and delays, Decree-Law 18/2020 regulating onshore petroleum operations was officially published in May 2020.
   A revised Environmental Management Plan for area -08/A was approved in December 2020, with appendices covering Waste management, Rehabilitation, Redress, Oil spill response, Traffic management, Inspection schedule, Noise management, Incident reporting, Community consultation and Air quality.
   In January 2021, Timor Resources announced that they plan to drill the first of five wells in Covalima (area -08/A, see map) in July, but they were later delayed. The ANPM granted an environmental license in July, and drilling the first well is scheduled for 21 September.
  ANPM held public hearings on the environmental license for the Rusa-1 test well near Betano (area -09/C, see map) in August and September in Manufahi and Ainaro, and relevant documents are in La'o Hamutuk's environmental registry. On 13 September, La'o Hamutuk wrote a 7-page submission to this process, with the following main points, as well as a blog: Onshore oil drilling imminent despite serious concerns:

• The consultant and proponents of this project have no experience with oil drilling, so special caution must be taken.

• This assessment should include the entire project cycle, including production if significant oil is found.

• Climate change should be taken more seriously.

• The analysis of impacts is insufficient and biased, and local communities have not been informed.

• Decommissioning and restoration plans are incomplete.

• Economic benefits are exaggerated.

• This process has several conflicts of interest that make it hard to protect the public interest.

• Public consultation should include listening to the people, and be well-informed and without intimidation.

• Timor Resources' corporate culture obstructs public participation.

On 1 February 2022, ANPM issued an environmental license for the Rusa-1 test well in Ainaro.
  Timor Resources drilled the first test well in Covalima (called Feto Kmaus or Karau-1), in October-November 2021, but the results were discouraging. A gas kick caused oil-contaminated mud to spill over into nearby areas, prompting an emergency response.
  They drilled a second Covalima well (Kumbili-1) in January-February 2022. On 15 March, Timor Resources announced that they found "hydrocarbon shows of significance" at Feto Kmaus and, as data evaluation proceeds, intend "to raise additional capital". Energy Voice reported that "there are no firm figures yet, but plenty of hope."   In April 2022, Timor Resources began withdrawing from the area including the Feto Kmaus test well, as they did not plan any further exploration there. They informed the landowner that they are terminating the lease early. In December, La'o Hamutuk's Bulletin included an article Konsultasaun iha perfurasaun mina no gás iha Covalima, sharing observations on the pre-drilling consultation.
   In March 2023, joint venture partners Timor Resources and TimorGAP engaged in a public squabble about whether TimorGAP should pay part of the exploration costs. TimorGAP denied any obligation, but Timor Resources reasserted in May that TimorGAP should reimburse some of the $68 million it has invested in the project to date. In mid-2023 the new government pledged to settle the dispute; the Council of Ministers approved a resolution in March 2024 and the two companies signed revised commercial agreements in May.
   Exploratory drilling at the Lafaek well in Labarai, Covalima was completed in April 2023, and TR was waiting for analysis by an Indonesian laboratory. In October 2023, Timor Resources claimed to have found 32 million barrels of contingent resources, as reported in the trade press and by ANP. In February 2024, ANP told Tatoli that Timor Resources would drill another test well to see if the discovery was worth developing.

   In July 2023, La'o Hamutuk researcher Jonathan Gonsalves presented Entre Esperansa ho Realidade ba Perfurasaun Mina Rai iha Covalima (mós PDF) to the Timor-Leste Studies Association conference, as well as in an article in the December 2023 LH Bulletin.
  In March 2024, Timor Resources announced the publication of a Competent Persons Report on the oil prospects of seven contracted areas which it hopes could be up to "20,000 barrels/day for twenty years". In anticipation of more drilling, Timor Resources met with community leaders around Feto Kmaus in April.

Suellen Osborne and Mike Bucknill of Timor Resources toast Prime Minister Rui Maria Araujo. 

Locations of proposed wells in Area A, Covalima

Location of proposed Rusa-1 test well in Area C, Ainaro

Map of planned and past seismic exploration in the contract areas.

On 7 December 2021, ANPM awarded PSC TL-OT-21-17 (summary in Portuguese) to TimorGAP without open bidding. The seven-year contract covers a 1,575 km² area in three municipalities: Viqueque, Manufahi and Manatuto.

La'o Hamutuk attended a socialization event for this project on 24 June 2022, and wrote a blog TimorGAP begins exploring Pualaca Block by itself.

Iha loron 7 Dezembru 2021, ANPM fó PSC TL-OT-21-17 (Port.)  (rezumu, Port.) ba TimorGAP laho konkursu públiku. Kontratu ida ne'e sei la'o tinan hitu, no inklui area 1,575 km² iha munisipiu tolu: Viqueque, Manufahi and Manatuto.

La'o Hamutuk asiste iha eventu sosializasaun ba projetu ida ne'e iha loron 24 Juñu 2022, no hakerek blog TimorGAP Hahú Esplorasaun Mesak iha Bloku Pualaca. 

The first contract, PSC TL-OT-22-18 (also Portuguese), from the 2019-2022 bid round was with TimorGAP for Block A ("Rarahana"), including 4,863 km² including all of Lautem and small parts of Baucau and Viqueque municipalities. It was signed on 22 December 2022 and community socialization began in April 2023.

Kontratu primeiru CPP TL-OT-22-18 (Portuges) husi konkorsu 2019-2022 refere ba Bloko A ("Rarahana"), ne'ebé inklui 4,863 km^{2 --} munisipiu Lautem tomak no parte ki'ik rua husi Baucau no Viqueque. ANPM no TimorGAP, E.P. asina iha loron 22 Dezembru 2022 no hahu sosializasaun iha komunidade iha Avril 2023.

The third contract, PSC TL-OT-22-22 (also Portuguese), from the 2019-2022 bid round was for Block F, 844 km² in the southern part of Viqueque municipality. ANP signed the contract with the company HTS from Kazakhstan on 8 March 2024, as reported by Tatoli and the Government. ANP posted the PSC to its website six weeks later.

Contract SO-15-01 awarded to TimorGAP without tender

SO-15-01: On 22 December 2015, Resolution 44/2015 (Portuguese original) came into force, awarding one block in the Timor-Leste Exclusive offshore area and one onshore block to TimorGAP to conduct 3D seismic studies and sign Production Sharing Contracts by direct award, without a public tender. ANPM announced the offshore award in January 2016 and later published a summary and eventually the text of PSC SO-15-01 on its website.
  The Chinese company BGP started offshore seismic research the next day and handed the results over to TimorGAP and ANP on 10 March 2016. TimorGAP will pay BGP $11.4 million over the next three years for the study.
   In November 2016, the Jornal da Republica published a Portuguese summary and maps for both the onshore and offshore PSC.  The onshore area was later divided into PSCs TL-OT-17-08 and OT-17-09, described above.
   On 5 July 2017, TimorGAP announced that it had identified "world-class prospectivity" in the offshore block, based on initial analysis of old seismic data.

Kontratu ba TimorGAP lahó prosesu tenderizasaun iha 2015

SO-15-01: Iha loron 22 Dezembru 2015, Rezolusaun 44/2015 mai en vigor, fo bloko ida iha TLEA no bloko ida iha rai laran ba TimorGAP ne’ebé bele halo estudu sizmiku no asina Kontratu Fahe Produsaun ho ajudikasaun direta, lahó prosesu tenderizasaun ida ne’ebé nakloke, no ANPM halo anunsiu publiku iha fulan Janeiru, no Jornal da Republika publika sumariu iha Novembru 2016.

Contract SO-22-23 (Area P) from bid round awarded to Eni in 2023

The second contract PSC TL-SO-22-23 (also Portuguese) from the 2019-2022 bid round was for Block P, a 3,998 km² offshore area just south of Greater Sunrise. ANP signed it with the Italian company Eni on 14 December 2023.

Kontratu SO-22-23 (Area P) fó ba Eni

Chuditch contract TL-SO-19-16 awarded to Sunda Energy (Baron Oil) and TimorGAP

In the first new contract signed after the Boundary Treaty came into effect, on 8 November 2019 ANPM awarded a no-tender contract to Singapore-based SundaGas (75%, operator) and TimorGAP (25%) for a 3,571 km² area in the former Joint Development Area. It is part of former Minza contract area JPDA 06-101A, which includes the Chuditch gas prospect. PSC TL-SO-19-16 (Portuguese)
  One-third of SundaGas is owned by the British company Baron Oil Plc., which described the project on its website based on Shell's 1998 test well. In April 2020, Baron Oil reinforced its ownership.
  On 9 July 2020, SundaGas VP Colin Murray presented to an online conference about the project, and he made a similar presentation on 25 March 2021.
  In January 2021, citing Covid-19 and problems with data access, SundaGas asked ANPM to extend the time by one year, until December 2022, for them to analyze seismic data and decide whether to drill a test well. Baron Oil updated investors on the project in April, and acquired the remainder of SundaGas's share of Chuditch in June.
  A January 2022 presentation by Baron Oil described why "This year is going to be important for Chuditch & Baron", which was echoed in the trade press two months later. In September, SundaGas presented an update to an industry conference in Perth.  The following month, ANPM granted the company's request to delay the decision on drilling until June 2023.
  In February 2023, Baron Oil released a Competent Person's Report estimating the potential Chuditch reserve. In early June, Baron Oil announced that ANPM had granted a six-month extension to "contract year two" to 18 December 2023, giving the operator until then to decide whether to drill a test well. In October, Baron Oil presented information about their possible appraisal well, which they considered their "priority this year" in their previous six-month results statement. According to a media report, Baron is considering a floating LNG plant for the field.
  Chuditch optimism increased in November 2023, reinforced by an Operational Planning Update from the company. Baron subsidiary SundaGas asked for Expressions of Interest for their offshore drilling operations, expected to begin in the last quarter of 2024. In early December, the ANP granted another six-month extension of "year two" until 18 June 2024.
  In mid-December 2023, SundaGas signed an MOU with TimorGAP, which will increase TG's share of the project from 25% to 40%. TimorGAP will now be responsible for 20% of all costs, and TG's obligation during 2024 is estimated at $7.5 million, in addition to $1 million for "back costs."  The farm-up agreement was signed on 24 January 2024 and approved by the ANP the following week. Baron Oil is proceeding with a site survey.
  In February 2024, Baron Oil issued new shares to raise money for the Chuditch test well. The following month, CEO Andy Yeo and another director resigned from Baron's board. Yeo was replaced by Andy Butler, who had been director for Asia-Pacific.
  In March, Baron Oil subsidiary SundaGas completed their geophysical site survey, and decided to move the planned Chuditch-2 appraisal well 286 meters. They are discussing drilling plans with potential subcontractors.
  Baron Oil continues to promote the project with potential investors, including presentations to the Association of International Energy Negotiators, the Proactive One2One Investor Forum, and Baron's Annual General Meeting. Baron Oil's 2023 Annual Report also highlights their plans for Chuditch.
  In May, following their withdrawal from the North Sea and Peru, Baron Oil changed their name to Sunda Energy to reflect its focus on Southeast Asia. Chuditch is now their only project, for which they continue to seek investors.
  In June, Sunda Energy and the ANP circulated a Terms of Reference for the process of getting a Timor-Leste environmental license for their appraisal (exploratory) well, which they hope to drill early in 2025.

Kontratu ba Chuditch TL-SO-19-16 fó ba Sunda Energy (Baron Oil) no TimorGAP

Contract signed in 2013 in the Joint Petroleum Development Area

• JPDA 11-106 with Eni (40.53%), Inpex (35.47%) and TimorGAP (24%) was signed on 13 April 2013 without an open bidding process. It covers 662 square km of relinquished acreage from JPDA 06-105, near the Kitan field, and was expected to tie into Kitan if a commercial discovery is made while Kitan is in production. Operator Eni committed to drill two exploration wells in the area, which includes the Kuda-Tasi and Jahal oil reservoirs, within two years.
     The signing was announced by ANP. This was the first exploration contract for Timor-Leste's state-owned oil company TimorGAP, and it was celebrated by TimorGAP, INPEX and Timor-Leste's government. ANP published the PSC (12 MB) text to their website seven months later (scanned text), after the Jornal da Republica published a summary.
      In August 2014 Eni announced plans to drill two wells in this contract area in 2015, and details about these plans became available in October 2014. However, due to low world market prices for oil, the drilling was repeatedly delayed, and in 2016 the ANPM agreed to extend the term of the PSC until 2018.
      Kitan ended production in the second half of 2015, and its processing ship departed the area before this block was ready.
      In October 2018, Eni signed a contract with Maersk Drilling to drill one well in March 2019. The well, known as Kanase-1, did not find commercial quantities of oil.
     After the Maritime Boundary Treaty came into force, this contract was replaced by PSC TL-SO-T-19-11.
     In August 2024, the Australian company Finder Energy Holdings Ltd announced (also presentation) that it is purchasing 76% of this PSC from Eni and Inpex for $2 million (plus more money if Finder develops the field). TimorGAP still owns the remaining 24%. Having obtained ANP approval, the two companies signed the revised PSC on 6 September (ASX announcement, corporate presentation). Finder is seeking investors, and then will design the Field Development Plan, with the intention of making a Final Investment Decision for Kuda Tasi/Jahal in 2026.

Kontratu ne’ebé asina iha 2013 iha Area Konjunta ba Dezenvolvimentu Petróleu

• JPDA 11-106 ho Kompañia Eni (40.53%), Inpex (35.47%) no TimorGAP (24%) asina ona iha 13 Abril 2013, maske nune’e PSC ida ne’e la liu husi prosesu tenderizasaun ka la loke ba públiku. Area refere ho nia luan kobre 662 km kuadradu hosi área ne'ebé maka renunsia husi JPDA 06-105, area ne’ebé besik liu kampu Kitan, no hein katak sei liga ba Kitan se deskoberta komersiál ida no iha tempu hanesan Kampu Kitan iha hela produsaun. Operadór Eni kompromete atu fura posu esplorasaun rua iha área refere, ne’ebé inklui rezervatóriu mina-rai Kuda-Tasi no Jahal, iha tinan rua nia laran.
    Asinatura kontratu PSC 11-106 anunsia hosi ANP (Ingles). Kontratu esplorasaun ida ne’e, hanesan foin primeira vez fó ba kompañia nasional Timor-Leste TimorGAP, E.P., no ida ne’e selebra ona husi TimorGAP, INPEX no Governu Timor-Leste. ANP publika kontratu PSC ida ne’e (12 MB) iha sira nia website depois fulan hitu liutiha (testu scan), hafoin Jornál da República publika sumáriu ida.
    Iha Agostu 2014 Eni fó sai planu ba posu rua iha área kontratu ida-ne’e iha 2015, no detalla sira no kona-ba planu ne’e sai disponivel iha Outubru 2014. Maibé, tanba folin ba mina-rai iha merkadu mundiál ne’ebé ki’ik, perfurasaun ne’e atrazu beibeik, no iha tinan 2016 ANPM aseita atu prolonga tan prazu PSC nian to’o 2018.
    Kampu mina matan Kitan hakotu produsaun iha segunda metade 2015, no nia ró prosesamentu sai husi área ne'e molok bloku ida-ne'e prontu.
    Iha Outubru 2018, Eni asina kontratu ida ho Maersk Drilling atu fura posu ida iha Marsu 2019. Posu ne’ebé naran Kanase-1, maske nune’e rezultadu hatudu katak kuantidade mina-rai ne’ebé iha la nato’on at prodús tanba la komersiál.
    Hafoin Tratadu Fronteira Marítima vigora, kontratu ne’e troka ho PSC TL-SO-T-19-11.
    Iha Agostu 2024, empreza husi Australia, Finder Energy Holdings Ltd anunsia (nia aprezentasaun) katak nia sosa 76% husi kontratu PSC ida-ne'e husi kompañia rua Eni no Inpex ho folin tokon $2 (osan tan bainhira nia dezenvolve kampu). TimorGAP nafatin ho nia partisipasaun 24%. Kompania rua asina PSC foun iha loron 6 Setembru. Finder buka investidór sira no sei hili no dezeña Planu Dezenvolvimentu Kampu nian. Iha tinan 2026, nia sei halo Desizaun Investimentu Finál ba Kuda Tasi/Jahal.

Contracts signed in 2006 in Timor-Leste's Exclusive Area

Click here for more information about the 2006 bidding round in the TLEA.

• 06-01 A with Eni (80%), GALP (10%), Kogas (10%). Relinquished in 2011.

• 06-02 B with Eni (80%), GALP (10%), Kogas (10%). Relinquished in 2011.

• 06-03 C with Eni (80%), GALP (10%), Kogas (10%). This area contains the Cova-1 and other test wells. The JV relinquished 25% of this block in 2009. In January 2010, the Cova-1 test well came up dry. Relinquished.

• 06-04 E with Eni (80%), GALP (10%), Kogas (10%). The JV relinquished 25% of this block in 2009 and more in 2012.

• 06-05 H with Eni (80%), GALP (10%), Kogas (10%). The JV relinquished 25% of this block in 2009 and the rest in subsequent years.

• 06-06 K with Reliance. In 2008, Indian Oil Corporation Ltd and Oil India Ltd each bought 12.5% of this PSC. Reliance drilled a test well here in December 2010, but did not find commercial quantities of gas or oil and relinquished the area. They have withdrawn completely from Timor-Leste.

Kontratu sira ne’ebé asina iha 2006 iha Area Eskluzivu Timor-Leste

• 06-01 A ho Eni (80%), GALP (10%), Kogas (10%). Remata

• 06-02 B ho Eni (80%), GALP (10%), Kogas (10%).

• 06-03 C ho Eni (80%), GALP (10%), Kogas (10%). Area ne’e inklui Cova-1 no posu ba teste perfurasaun sira seluk. Konsorsiu/Joint Venture husik 25% hosi bloku ne’e iha 2009. Iha Janeiru 2010, Cova-1 nia teste perfurasaun la hetan buat ida.

• 06-04 E ho Eni (80%), GALP (10%), Kogas (10%). Konsorsiu husik 25% hosi bloku ne’e iha 2009.

• 06-05 H ho Eni (80%), GALP (10%), Kogas (10%). Konsorsiu husik 25% hosi bloku ne’e iha 2009.

• 06-06 K ho Reliance. Iha 2008, Indian Oil Corporation Ltd no Oil India Ltd ida-idak sosa 12.5% hosi PSC ida ne’e. Reliance halo teste perfurasaun iha posu ne’e iha Dezembru 2010, maibé la hetan kuantidade komersiál ba gas ka petróleu. Kompañia ne’e sai ona hosi Timor-Leste.

The above map is from 2010.  By 2014, all PSCs in the TLEA had been relinquished as unproductive, except for the southern part of S06-04, as shown below:

Contracts signed in 2006 in the Joint Petroleum Development Area

Contracts were signed in 2006 for the green areas on the map; older areas are in yellow. The operator of each area is listed in bold. Click here for more information about the 2006 bidding round in the JPDA.

JPDA 06-101A with Minza Oil and Gas. (summary). Minza drilled an exploration well in 2011 and conducted seismic exploration in 2012. Most of this area has been relinquished. At the end of 2014, Minza announced that the company was in liquidation. ANPM announced the termination of the contract in January 2016.
   A new contract for part of this area was awarded to SundaGas and TimorGAP in October 2019 -- see above.

Kontratu sira ne’ebé asina iha 2006 iha Area Konjunta ba Dezenvolvimentu Petróleu

Kontratu sira ne’ebé asina iha 2006 ba area sira ho kór azúl iha mapa; area sira tuan ho kór kinur. Operador ba kada area lista ho letra mahar:

JPDA 06-101A ho Minza Oil and Gas. (sumáriu). Minza sei fura posu esplorasaun ida iha 2011. Iha 2014, Minza bankrut, no ANPM fo aviso kona-ba PSC ida ne'e kansela iha Janeiru 2016.

Contracted and relinquished areas over time

The map above is from 2010. By the start of 2015, many of these contract areas had  been completely or partially relinquished as unproductive, except for the areas shown below:

By 2017, the Oilex and Minza contracts were terminated, and TimorGAP had received a new TLEA area and, with Timor Resources, two new onshore areas. Green lines show where offshore seismic exploration has been conducted:

The Maritime Boundary Treaty came into effect in August 2019. Existing PSCs were adapted, and TimorGAP was awarded one new contract, as shown in the following maps:

In 2022 and 2023, the first contracts were signed from the recently-completed bidding round:

JPDA 06-102 with Petronas (50%), Korea Gas (30%), Samsung (10%) and LG (10%). (summary)
After four dry wells, this area has been relinquished.

JPDA 06-102 ho Petronas (50%), Korea Gas (30%), Samsung (10%) no LG (10%). (sumáriu)
Hafoin posu haat ne’e mamuk, area ne’e husik tiha ona.

JPDA 06-104 was awarded to Zetex, which withdrew its bid before signing a contract.

JPDA 06-104 ajudika ba Zetex, ne’ebé rezigna an molok asina kontratu.

JPDA 06-105 (replaced part of JPDA 03-01) with Woodside (40%), INPEX (35%), Talisman Resources (25%).
In September 2007 Woodside sold its share to Eni, although it avoided taxes on the deal. This area contains the Kitan field which began production in October 2012 and is estimated to contain 34.6 million barrels of oil.
  In April 2013, Eni (with TimorGap and INPEX) signed PSC 11-106 (above) to explore further in the relinquished parts of this contract area.
  In April 2014, Talisman said that it wanted to sell its share of this project, and in June, Malaysian company Hibiscus Petroleum announced it would purchase Talisman's share of Kitan for $18 million, but Hibiscus cancelled the sale on 1 June 2015. The entire Talisman company, including this 25% share, was acquired by the Spanish company Repsol in May 2015.  Kitan revenues dropped sharply in 2014 to less than one-sixth of their 2013 levels, largely because the field is nearly depleted. At the beginning of September 2015, Eni announced it will terminate its contract with the processing platform ten months early. Kitan stopped production in December 2015, and in 2018 Timor-Leste repaid $63 million in profit oil tax revenues that had been overestimated in the past.
   After the Maritime Boundary Treaty came into force in 2019, this contract was replaced by PSC TL-SO-T-19-10.

JPDA 06-105 (troka parte JPDA 03-01) ho Woodside (40%), INPEX (35%), Talisman Resources (25%).
Iha Setembru 2007 Woodside fan nia asoens ba Eni, maske ida ne’e evita atu selu taxa bainhira halo negósiu. Area ne’e inklui kampu Kitan ne’ebé hahú produsaun iha Outubru 2012 no estimasaun iha barríl mina-rai tokon 34.6.
  Iha Abríl 2013, Eni (ho TimorGAP no INPEX) asina PSC 11-106 atu halo tan esplorasaun iha parte sira ne’ebé husik ona iha area kontratu ida ne’e.
  Iha fulan Abril 2014, Talisman fo sai katak nia hakarak faan ninia parte projetu Kitan, no iha fulan Junu, Hibiscus Petroleum fo sai katak sira sei sosa no selu tokon $18. Ikus liu, Repsol husi Espanha hola Talisman tomak.
  Reseitas husi Kitan tun makaas iha 2014, tanba kampu ida ne'e besik hotu. Kitan hapara produsaun iha fulan Dezembru 2015.
   Hafoin Tratadu Fronteira Maritima tama in vigor iha tinan 2019, kontratu ida ne'e hetan substituisaun ho PSC TL-SO-T-19-10.

Contracts signed before 2006 in the JPDA

Contracts signed before the 2005 laws went into effect are not legally obligated to be published. La'o Hamutuk and others have repeatedly asked the oil companies and relevant authorities to give permission for them to be made available. These contracts will be replaced by new ones after the 2018  comes into force.

Kontratu sira ne’ebé asina molok 2006 iha JPDA

Kontratu sira ne’ebé asina molok lei 2005 nian vigora, legalmente laiha obrigasaun atu publika sai. La’o Hamutuk no instituisaun balu dala barak husu ba kompañia mina-rai sira no autoridade sira ne’ebé relevante atu fó lisensa hodi nune’e kontratu sira ne’e ema bele asesu.

Bayu-Undan

   The partners in the Bayu-Undan joint venture have agreed to publish parts of the contracts, although many paragraphs have been censored. Bayu-Undan is the only currently producing field providing revenue to Timor-Leste. These contracts also include the Elang-Kakatua field which ceased production in 2007. From 2009-2020, partners in Bayu-Undan were ConocoPhillips (57%), Santos (11%), Inpex (11%), Eni (11%), Tokyo Electric(later JERA)/Tokyo Gas (9%).

• JPDA 03-12 (Public Information Notice) with ConocoPhillips, Santos, Inpex, Petroz and Emet (signed on 2 April 2003 to replace an occupation-era contract) was amended in May 2003.

• JPDA 03-13 (Public Information Notice) with ConocoPhillips (signed on 2 April 2003 to replace an occupation-era contract) was amended in May 2003.

   As Bayu-Undan neared depletion, three more wells were drilled in 2018 to extract as much oil as possible. However, production is still expected to end by 2022.
   On 30 August 2019, the Maritime Boundary Treaty between Timor-Leste and Australia entered into force. Two days earlier, the PSCs for Bayu-Undan were replaced by ones which recognize that the JPDA no longer exists, and the entire field is now in Timor-Leste's territory. Under the Treaty, 'conditions equivalent' prevail for ConocoPhillips, Santos, Inpex and the other partners. Timor-Leste has published summaries of the new PSCs TL-SO-T 19-12 and TL-SO-T 19-13.
   On 14 October 2019, ConocoPhillips announced that it is selling its entire 57% share in Bayu-Undan and Darwin LNG, as well as its shares in Barossa and other fields, to Santos for $1.4 billion. In March 2020, Santos announced that it will on-sell 25% of B-U and DLNG to SK E&S for $390 million. After approval from partners and regulators in both countries, the CP-Santos deal became operational on 28 May 2020, as announced by Santos and ConocoPhillips. After the transactions are complete, partners in Bayu-Undan and Darwin LNG joint ventures will be Santos (Australia, 43.4%), SK E&S (Korea, 25%, as of 30 April 2021), Inpex (Japan, 11.4%), Eni (Italy, 11.0%) and JERA/Tokyo Gas (Japan, 9.2%).
   At the end of May 2020, about 19 million barrels equivalent of proved oil and gas reserves remained  in the Bayu-Undan field; about 3% of the amount that has already been extracted and sold.
   On 9 July 2020, Bayu-Undan Development Team Leader Michel Buoniauto presented to an online conference. As later reported by Upstream, he said that Santos is considering drilling three more wells to suck up the last drops from the field.
   Like all companies, Santos (which currently owns more than 2/3 of Bayu-Undan and Darwin LNG) is struggling in the Covid economy, and wrote down the value of some of its assets. The company's second quarter 2020 report showed significant drops in Bayu-Undan production (see table at right) and pointed out that the field has higher production costs than other Santos assets.
   Production picked up in the third quarter, as Santos explained: "spot cargo sales which partially offset customers exercising contractual flexibility on LNG cargoes. The two spot cargoes loaded in August and September 2020 were the first to be marketed by Santos on behalf of Darwin LNG since Santos assumed operatorship and were the two largest cargoes ever loaded at DLNG. Evaluation of a further phase of infill drilling in Bayu-Undan continues to be progressed in order to optimise field recovery and extend field life and Darwin LNG production. The planned program consists of an additional three development wells..."
   On 5 January 2021, Santos announced the Final Decision to Invest $235 million to drill three more production wells at Bayu-Undan in mid-2021, which are expected to recover an additional 20 million barrels and extend the life of the field. The additional costs will  be recoverable from revenues which would have gone to Timor-Leste. Following support from Timor-Leste authorities, Santos started drilling the new wells (also Tetum) on 25 May, with better-than-expected results. Year-end 2021 production reports show a slight increase in gas production compared with the previous two years, although liquids production has dropped relative to 2019.
   World LNG prices surged in late 2021 and early 2022, and gas production from Bayu-Undan (running at half-capacity) was lucrative for Timor-Leste -- although it will probably end in 2023. Timor-Leste is preparing to clean up the Bayu-Undan floating platform at the new port at Tibar as part of decommissioning, and has begun an environmental licensing process. Santos shipped the last liquefied gas extracted from Bayu-Undan in November 2023, and decommissioning has begun. Although the Darwin LNG plant is no longer operating, Santos continues to provide small amounts of gas and oil from Bayu-Undan to Darwin to sell to the domestic NT market.
   As the Bayu-Undan PSC neared expiration in August 2024, Timor-Leste pressured Santos to give part of the nearly-empty project to TimorGAP, and Santos and its JV partners agreed to transfer 16% ownership in return for extending the contract through June 2026. Under the extended PSC, which was signed on 16 September, the shares are now held by Santos (Australia, 36.5%), SK E&S (Korea, 21%), TimorGAP (TL, 16%), Inpex (Japan, 9.6%), Eni (Italy, 9.2%) and JERA/Tokyo Gas (Japan, 7.6%). TimorGAP has no obligation for decommissioning costs, and will not receive part of the surplus if some of the $1.3 billion in reserve for decommissioning is not needed.

Bayu-Undan

Parseiru sira iha Konsorsiu Bayu-Undan konkorda atu publika parte hosi kontratu, maske iha parágrafu barak mak hetan sensura. Bayu-Undan mak daudauk ne’e kampu ida de’it ne’ebé fornese reseita ba Timor-Leste. Kontratu sira ne’e mós inklui kampu Elang-Kakatua ne’ebé produsaun remata ona iha 2007. Até tinan 2020, parseiru daudauk iha Bayu-Undan mak ConocoPhillips (57%), Santos (11%), Inpex (11%), Eni (11.0%), Tokyo Electric/Tokyo Gas (9%).

• JPDA 03-12 ho ConocoPhillips, Santos, Inpex, Petroz no Emet (asina iha 2 Abríl 2003 atu troka kontratu ne’ebé hala’o durante okupasaun) hetan alterasaun iha Maiu 2003.

• JPDA 03-13 ho ConocoPhillips (asina iha 2 Abríl 2003 atu troka kontratu ne’ebé hala’o durante okupasaun) hetan alterasaun iha Maiu 2003.

Carbon Capture and Storage (CCS) in Bayu-Undan

On 3 May 2021, Santos and Eni agreed to look into using the Bayu-Undan field, which may be empty in a year or two, to store carbon dioxide underground in an effort to reduce their contribution to climate change. As described in La'o Hamutuk's blog Carbon Capture and Storage under the Timor Sea: Climate Change Prevention or Carbon Colonialism?, this controversial project could allow the companies to develop carbon-intensive gas fields in Australian territory, including Barossa and Evans Shoal, without increasing the companies' overall carbon footprint. The proposal, which will require approval from Timor-Leste, would allow Santos to delay decommissioning the Bayu-Undan field, will make Timor-Leste responsible for Australia's waste, and is likely, overall, to accelerate the negative impacts of climate change.
   Although Santos has great expectations for CCS technology, some shareholders are doubtful. On 13 September 2021, Santos and the ANPM signed an MOU (also Tetum) to discuss moving ahead with this project. At the end of October, notwithstanding serious expert concerns, Santos' CEO Kevin Gallagher lauded it to an industry conference in Darwin. The following week, Gallagher met with ANPM officials on the margins of the climate change conference in Glasgow.
   In November, La'o Hamutuk presented on the CCS project to an Australian environmental webinar (video).

  In February 2022, the Northern Territory Environment Protection Authority held a consultation on Santos' proposed Darwin Pipeline Duplication Project which would enable CO2 to be separated from Barossa gas in Darwin and piped to Bayu-Undan. La'o Hamutuk made a submission, which was reported by Energy Voice and described in a press release. Expert analysis indicates that the project may not reduce the amount of CO2 released into the atmosphere.

  In June 2022, three Japanese companies indicated their interest in joining the project, and a Final Investment Decision is planned for 2023. In July 2022, Santos contracted Worley to prepare a Front End Engineering Design for the CCS project.

  In December, LH gave a presentation Carbon Capture and Storage (CCS) at Bayu-Undan (also PDF).

  Although the Barossa project has been delayed by Australian regulators, Santos and ANPM continue to promote CCS at Bayu-Undan.

   In June 2023, LH made a second submission to the Northern Territory Environment Protection Authority.
   The Australian Parliament is considering Sea Dumping legislation to allow carbon dioxide waste produced in Australia to be pumped into international waters, which independent MPs consider a "colossal attempt at greenwashing" and "a key enabler of gas expansion, granting social licence for new and highly polluting greenwashed fossil fuel projects."
   On 7 August 2023, Santos announced that the Bayu-Undan joint venture partners had signed an MOU with TimorGAP to share information and explore partnership opportunities for a CCS project at Bayu-Undan. The Korean company SK E&S is also interested in storing CO₂ in Bayu-Undan, In November, Australia enacted its Sea Dumping" law, a concept questioned by the Center for International Environmental Law,  Energy Tracker, the IEA and the IEEFA (page 9).
  On 23 January 2024, relevant Ministers from Timor-Leste and Australia discussed the project. Although the Timor-Leste government has yet to enact legislation to enable this project, IFC is supporting it. Despite many legal challenges, Santos is proceeding with the Barossa/CCS project, and the company is going after civil society groups who question it. They hope to start Barossa operation in 2025.

Kaptura no rai hela karbonu (CCS) iha Bayu-Undan

Iha loron 3 Maiu 2021, Santos no Eni konkorda atu konsidera atu uza kampu Bayu-Undan, ne'ebé bele mamuk iha tinan ida ka rua, atu rai hela karbonu dióksidu iha rai okos hanesan esforsu atu hamenus sira nia kontribuisaun ba mudansa klimátika. Hanesan esplika iha La'o Hamutuk nia blog  Kaptura no rai hela karbonu iha Timor-Leste nia Tasi Okos: Solusaun ba Mudansa Klimátika ka Kolonializmu Karbonu?, projetu ida ne'e bele fó espasu ba kompañia sira atu dezenvolve kampu gas sira iha Australia ne'ebé todan ho karbonu, inklui Barossa no Evans Shoal. Proposta ida ne'e presiza konkordansia husi Timor-Leste, sei fó lisensa ba Santos atu adia desmantlementu projetu Bayu-Undan, fó responsabilidade ba Timor-Leste atu tau matan ba fo'er husi Australia, no bele aselera impaktu negativu sira husi mudansa klimátika.
   Maske Santos antisipa buat di'ak husi teknolojia CCS, na'in sira balun ha duvida. Iha loron 13 Setembru 2021, Santos no ANPM asina MOU ida hodi halo progresu ho projetu CCS.
  Iha fulan Outubru, La'o Hamutuk fó aprezentasaun ida (mós PDF) kona-ba CCS ba webinar ida kona-ba mudansa klimátika.

   Iha loron 27 Outubru, Santos nia prezidente promove projetu ida ne'e, maske peritu balu iha duvida. Semana ida tuir mai, Santos no ANPM hasoru malu iha konferensia mudansa klimátika iha Glasgow.

   Iha Marsu 2022, La'o Hamutuk fó sai komunikadu imprensa ida ne'ebé sumariza ami nia submisaun ba NTEPA iha Australia.

   La'o Hamutuk prodús programa radio ida ne’ebé diskute projetu CCS nian, no mos fó aprezentasaun ida (mós PDF) kona-ba CCS ba FONGTIL.

Greater Sunrise

The original partners in the Greater Sunrise joint venture (Woodside (33.4%), Shell (26.6%), ConocoPhillips (30%) and Osaka Gas (10%)) refused to make any parts of their PSCs public, and we have not been able to obtain them. This includes two PSCs inside the JPDA (JPDA 03-19 Public Information Notice and JPDA 03-20 Public Information Notice) and two other contracts in the area occupied by Australia.
   In 2018, ConocoPhillips agreed to sell their 30% share to the Government of Timor-Leste for $350 million, and Shell sold their 26.26% share for $300 million. The deal was finalized in April 2019, as extensively described on another page on this site.
   The Sunrise PSCs will be replaced by new ones, reflecting the dissolution of the JPDA by the Maritime Boundary Treaty which came into force on 30 August 2019, although the negotiation process is still ongoing after four years.
   In July 2020, Woodside devalued its portion of the Sunrise field by $170 million, which one writer saw as foreshadowing the end of the project, which another writer attributed to political changes in Dili.  TimorGAP devalued its share to zero at the end of 2020, although this was secret until October 2021, when the 2022 state budget was proposed.
   In 2022, as contract negotiations dragged on, a leaked report indicated that developing Sunrise with a pipeline to Timor-Leste may not be as unprofitable as previously thought (although La'o Hamutuk has been unable to check the report's reliability). Newly-elected President Jose Ramos-Horta mentioned that Timor-Leste might look to China if Australia continued to be uncooperative,  stepped up diplomatic pressure on Australia to accept a pipeline to Beaçu, and Prime Minister Taur Matan Ruak met virtually with Woodside's CEO. In October, Australia appointed Steve Bracks, a long-time associate of Xanana, as its Special Representative on the project.
   In December 2022, Woodside executives said they were open to considering a pipeline from Sunrise to Timor-Leste, although TimorGAP called Woodside a bully and President Ramos-Horta urged them to continue to consider the TLNG option. As electoral timetable neared, the Minister of Petroleum tried to reduce partisan tensions by involving Xanana Gusmão. Journalist Hamish McDonald put the Sunrise issue in context.
   In mid-January 2023, partisan politics re-emerged with accusations that the government had dropped the ball on Sunrise negotiations. However, on 6 February, a press release from the Sunrise Joint Venture, which received wide media coverage, announced that the JV would "undertake a concept selection process" for Sunrise, including "valuation of which option provides the most meaningful benefit for the people of Timor-Leste." Ramos-Horta recommended against making commitments, given that a new government would be elected soon, and Taur Matan Ruak embarked on his first trip to Australia since becoming Prime Minister five years ago.
  The IX government, headed by former Prime Minister Xanana Gusmão has replaced the petroleum sector leadership, and former TimorGAP President Francisco Monteiro is now Minister for Petroleum and Mineral Resources. They have accelerated talks with Australia and Woodside, hoping to bring the Sunrise gas pipeline to Natarbora (having shifted the site of the proposed LNG plant from Beaçu).
  The Joint Venture has agreed to conduct further studies, as described in a series of articles and the search for a contractor. Discussions between the two governments are continuing. In April 2024, the companies announced that Wood Australia will conduct a Greater Sunrise Contract Study to be completed by the end of the year.
  In May 2024, the Prime Minister appointed Minister of the Presidency of the Council of Ministers Agio Pereira to represent the Government in Sunrise discussions, which are ongoing (including with Australia and Inpex). Australian media continue to worry about China's possible role.
  Wood began working on their study in July, holding consultation with various stakeholders. After a meeting at FONGTIL, La'o Hamutuk wrote to the Study Delivery Director with some of our concerns.
   In mid-July, Minister Francisco Monteiro and Australian representative Steve Bracks visited Natarbora (site of the future LNG plant for Greater Sunrise) and future "petroleum city" Betano. Ongoing negotiations in July are described in press releases and news reports.

Greater Sunrise

Parseiru sira iha konsorsiu Greater Sunrise (Woodside (33.4%), Shell (26.6%), ConocoPhillips (30%) no Osaka Gas (10%)) rekuza atu halo sira nia parte iha sira nia PSC hodi sai públiku, no ami labele hetan PSC sira ne’e. Ne’e inklui PSC rua ne’ebé iha JPDA nia laran (JPDA 03-19 no JPDA 03-20) no kontratu rua seluk ne’ebé okupa hela hosi Australia.
   Iha fulan Setembru 2018, iha konkordansia katak Governu Timor-Leste sei sosa ConocoPhillips nia partisipasaun 30% iha Konsórsiu atu dezenvolve Greater Sunrise ho osan hamutuk tokon $350, no mos Shell nian 26.3% ba tokon $300.

Map of Greater Sunrise from the 2019 Maritime Boundary Treaty

Other contracts signed in 2003 are no longer in effect.

• JPDA 03-01 was replaced by JPDA 06-105.

• JPDA 03-16 with ConocoPhillips (100%). Terminated in 2006 when ConocoPhillips declined to sign a new contract with the TSDA under the new Petroleum Mining Code.

• JPDA 03-21 with ConocoPhillips (75%) and Eni (25%). Terminated in 2006 when the joint venture declined to sign a new contract with the TSDA under the new Petroleum Mining Code.

Kontratu seluk ne’ebé asina iha 2003 la vigora ona.

• JPDA 03-01 troka ona ho JPDA 06-105.

• JPDA 03-16 ho ConocoPhillips (100%). Termina iha 2006 bainhira ConocoPhillips lakohi atu asina kontratu foin ho TSDA tuir Petroleum Mining Code/Kódigu ba Mineira Petróleu ne’ebé foun.

• JPDA 03-21 ho ConocoPhillips (75%) no Eni (25%). Termina iha 2006 bainhira konsorsiu lakohi atu asina kontratu foun ho TSDA tuir Petroleum Mining Code/Kódigu ba Mineira Petróleu ne’ebé foun.

Buffalo

The Buffalo oil field sits just west of the JPDA, in territory that became Timor-Leste's when the Maritime Boundary Treaty with Australia entered into force in 2019. Discovered in 1996, it had previously been occupied by Australia. Buffalo produced 20 million barrels of oil for BHP from 1999 until it was decommissioned in 2005, and Australia is keeping those revenues. In May 2016, Australia signed a new Buffalo contract with the Carnarvon company, which believes that it can extract about 31 million more barrels with new technology, by drilling smarter and deeper than the earlier wells.

   After the Treaty was signed in 2018, Carnarvon reported "that Carnarvon and Timor-Leste are in agreement on achieving first oil as soon as possible. Special legislation is to be enacted to ensure the Buffalo redevelopment will continue under equivalent fiscal terms previously in place with Australia." In May 2018, Carnarvon described the project, after which Carnarvon announced that it had raised investor capital for its first well. In August, Carnarvon updated its information, planning to drill 1-3 wells beginning in Q2 2020. Although it was clear that the field would be in Timor-Leste's sovereign territory before any test wells were drilled, in September 2018 Carnarvon asked Australian regulator NOPSEMA for environmental approval, and NOPSEMA requested changes and then accepted their plan in May 2019. Timor-Leste told Carnarvon that they would not have to comply with Timor-Leste environmental licensing laws, and Carnarvon told their investors that "the approval of the Environmental Plan to drill three wells into the Buffalo field by NOPSEMA will be accepted by the regulator in Timor-Leste."

   When the Treaty came into force on 30 August 2019, Carnarvon explained the new regime under PSC TL-SO-19-14 (Port., also English).  They hired Angelo Lay, former Commercial Director for ANPM, as their country manager. In Timor-Leste, Decree-Law 26/2019 detailed the transition of Buffalo from Australia to Timor-Leste. In its reports to shareholders in June and September 2020, Carnarvon indicated that the wells would be delayed, due to Covid-19 and the reluctance of any other companies to invest in the field. However, on 14 December 2020, Carnarvon announced that Advance Energy will fund drilling in return for a 25-50% share of the PSC. Advance Energy commissioned a Competent Person Report to validate their investment.

   Carnarvon issued a project update on 15 February 2021, and began looking for a drilling company. However, some oil industry experts are skeptical about the project, while others believe it could provide up to $600 million in revenues for Timor-Leste. In May, Carnarvon announced that Petrofac will drill the well, financed with $20 million from Advance Energy. In September, they contracted a drilling rig from Valaris and hoped to drill in November.

   After further delays, the rig was mobilized on 22 December, and drilling began on 31 December 2021. The first week went as planned, and the companies issued another update on 14 January. However, the update on 19 January was less promising, leading to reports that the project would be terminated. Five days later, Carnarvon and Advance Energy announced that the project is "uncommercial" which was reported in the trade press. The CEO of Advance Energy resigned a few days later. In October 2022, Carnarvon's 2022 Annual Report recognized that the company had lost $30 million on the now-abandoned Buffalo project. In July 2023, Carnarvon confirmed that it was giving up on the project.

Timor-Leste's oil stolen by Australia: Laminaria-Corallina

The Laminaria and Corallina oil fields, just outside the JPDA, are closer to Timor-Leste than to any other country and should belong to Timor-Leste under international legal principles. Since operator Woodside began production in 1999, Laminaria-Corallina has paid more than $2 billion in taxes to the Australian government and not one penny to Dili.

The project spreads over two contract areas:
 * Laminaria was owned 59.9% by Woodside and 40.1% by Talisman
 * Corallina was owned 66.7% by Woodside and 33.3% by Talisman.

   In April 2014, Talisman said it wanted to sell its share of the Laminaria-Corallina project. In May 2015, the entire Talisman company was acquired by Repsol.
   Another deal to sell the field was announced (also Tetum) in May 2016, with both Woodside and Talisman selling their holdings to Northern Oil & Gas Australia, a new company created by former WestSide founder Angus Karoll, and the transfer was finalized in February 2017. Because NOGA is not publicly traded, it is much less transparent than companies listed on stock exchanges.
   Australian authorities repeatedly cited NOGA for environmental violations, and ordered NOGA to cease Laminaria operations in July 2019, after which the company went into 'voluntary administration'.  NOGA went into liquidation in February 2020, and Australia may have to pay $200 million or more in clean-up costs. Australia hired Woodside, the former owner who reaped billions from the field, to provide advice on decommissioning, as analyzed by Callum Foote. In December 2020, the Australian Government announced that it "will now start the process of decommissioning and remediating the fields." By May 2021, it became clearer that Australia will assess oil companies to cover the decommissioning costs. In July, Australia sought a company to decommission the Northern Endeavour FPSO. In November 2021, an Australian Senate committee conducted an inquiry on cost recovery legislation and issued a report. Ongoing developments in Australia are not discussed on this web page.
   The 2018 Boundary Treaty entered into force on 30 August 2019. It says that after Laminaria-Corallina has no recoverable oil left, it may become part of Timor-Leste's territory. We hope it is in a clean, safe and stable condition by then.
   During its 15 years of production, Laminaria-Corallina generated about $6.8 billion in sales for Woodside and its partners, of which about $2.2 billion was paid to the Australian government. Timor-Leste got nothing. Under the Maritime Boundary Treaty, Timor-Leste's government relinquished its claim to this money, but La'o Hamutuk and others continue to remind Australia that it has a moral obligation to repay it.
  In August 2014, NOGA's CEO told President Ramos-Horta that he was interest to invest in Timor-Leste's petroleum sector.

Australia nauk mina-rai Timor-Leste: Laminaria-Corallina

Kampu mina-rai Laminaria-Corallina, sai hosi JPDA, besik liu ba Timor-Leste duke ba nasaun seluk ida no Timor-Leste mak tenke sia na’in tuir prinsipiu legal internasionál. Dezde operador Woodside hahú produsaun iha 1999, Laminaria-Corallina selu liu biliaun $2 iha taxa ba Governu Australia no laiha buat ida ba Timor-Leste.

The future

Although results to date have not been very promising, the Government remains optimistic, as shown by their bidding round, conducted in 2019 after a decade of promises and postponement.

In June 2014, the National Petroleum Authority held public consultations on new regulations and model PSCs for the TLEA and onshore areas, and La'o Hamutuk made a submission.

In April 2015, La'o Hamutuk analyzed how much of Timor-Leste's oil and gas wealth is remaining to be exploited, and published Timor-Leste's oil and gas are going fast (also blog and Tetum). In June, we responded (also Tetum) to allegations that our information was unfounded.

This debate continues. On 10 March 2016, La'o Hamutuk explained Santos' report that Bayu-Undan is 93% depleted in Indicators have Consequences.

In June 2017, La'o Hamutuk presented As Bayu-Undan dries up: challenges and opportunities (also PowerPoint and paper). Our 2019 paper After the oil runs dry: Timor-Leste economics and government finances includes additional information about the implications of petroleum dependency.

The Boundary Treaty that took effect in August 2019 opened the way further development of Buffalo, Chuditch, Sunrise and other areas. During first half of 2020, the Covid-19 pandemic and simultaneous fall in global oil and gas prices, made many companies and investors more cautious about continuing financially marginal projects, such as those in Timor-Leste. The future is uncertain.

In June 2021, Charles Scheiner of La'o Hamutuk wrote Timor-Leste: 2021 economic survey: The end of petroleum income (updated version), and the following month the IMF published an Article IV report on Timor-Leste. Both conclude that it would be unwise to expect significant oil and gas revenues to continue for very long, which was confirmed by the Ministry of Finance in Book 1 of the 2022 State Budget (pages 58-61). More recently, the Ministry and others have warned that Timor-Leste may fall over a "fiscal cliff" before 2035 if the economy is not diversified.

Futuru

Maske rezultadu ohin loron la dun fó promesa ida ne’ebé di’ak, Governu nafatin optimistiku.

Iha Junu 2014, ANP halo konsultasaun publiku kona-ba regulasaun foun ba TLEA no modelu Kontratu Fahe Produsaun rua ba TLEA no rai maran, no La'o Hamutuk hakerek submisaun ida.

Iha Abril 2015, La'o Hamutuk analiza montante rikusoin mina no gas Timor-Leste nian nafatin iha tasi okos atu esplora iha futuru, no publiku ona Mina-rai no gas Timor-Leste nian besik hotu ho lalais.

Debate ida ne'e kontinua nafatin. Iha fulan Marsu 2016, La'o Hamutuk esplika relatoriu husi Santos neébe hatete katak Bayu-Undan 93% mamuk tiha ona iha Sinál perigu sei iha konsekuénsia.

Iha Junu 2017, La'o Hamutuk aprezenta Bainhira Bayu-Undan sei maran: dezafiu no oportunidade sira (mos PowerPoint no artigu).