The Phase II IDD Project is Underway

PT Chevron Pacific Indonesia plans to work on an underwater oil and gas project or Indonesia Deepwater Development (IDD) phase II. However, the project has not yet been implemented because Chevron has not yet got a business partner.

Corporate Communication Manager of PT Chevron Pacific Indonesia Sonitha Poernomo said that his party through Chevron Rapak Ltd had already worked on the first phase of IDD in the form of developing the Bangka Field. The oil and gas field has been producing since August 2016. 

Indonesia Deepwater Development (IDD) phase II Chevron

    For the Phase II IDD project located in Gehem and Gendalo Field, the work was hampered because Chevron was still looking for strategic partners. Because there is a potential risk if the project is not economical. This means that the existence of these business partners to share risks.

The Phase II IDD project cannot compete for capital in the Chevron portfolio globally, "Sonitha said.

Unfortunately, Sonitha could not name the prospective partners who would collaborate with Chevron to work on the Phase II IDD project. But certainly, Chevron Rapak Ltd has obtained permission from the Special Task Force for Upstream Oil and Gas Business Activities (SKK Migas) to open data in order to facilitate discussions regarding the identification of potential partners who are able to manage IDD projects.

"At the moment there is no final decision regarding the discussion," said Sonitha.

ENI Italy

SKK Migas Deputy for Operations Julius Wiratno said. Chevron has actually partnered with Eni, Tip Top, Pertamina Hulu Energi (PHE) and Mitra Muara Bakau in the Phase II IDD project. Since the Phase II IDD project schedule is always backward, there is a possibility that the economic value of this project will decrease.

So it's only natural that Chevron considers it. Not to mention the project is limited by termination in 2026/2027, "Maybe Chevron wants to share down to partners taking into account the economics of the project," said Julius.

Initially, SKK Migas projected that the Phase II IDD project could start production in 2024, before finally withdrawing to 2025. Chevron is still looking for strategic partners to share risks.

IN INDONESIA

Proyek IDD Tahap II Terancam Molor

PT Chevron Pacific Indonesia berencana menggarap proyek minyak dan gas bawah laut atau Indonesia Deepwater Development (IDD) tahap ll. Namun proyek tersebut belum juga terlaksana karena Chevron belum mendapatkan mitra bisnis. 

Manager Corporate Communication PT Chevron Pacific Indonesia Sonitha Poernomo mengatakan, pihaknya melalui Chevron Rapak Ltd sudah mengerjakan tahap pertama IDD berupa pengembangan Lapangan Bangka. Lapangan migas tersebut telah berproduksi sejak Agustus 2016 siIam. Untuk proyek IDD tahap II yang berada di Lapangan Gehem dan Gendalo, pengerjaannya terhambat karena Chevron masih mencari mitra kerja strategis. Pasalnya, ada potensi risiko jika proyek tersebut tidak ekonomis. Artinya keberadaan mitra bisnis ini untuk berbagi risiko.

Proyek IDD tahap II tidak dapat bersaing untuk mendapatkan modal dalam portofolio Chevron secara global,” kata Sonitha.

Sayangnya Sonitha belum bisa menyebutkan nama calon mitra yang akan bekerjasama dengan Chevron untuk mengerjakan proyek IDD tahap II. Namun yang pasti, Chevron Rapak Ltd sudah memperoleh izin dari Satuan Kerja Khusus Kegiatan Usaha Hulu Minyak dan Gas (SKK Migas) untuk membuka data dalam rangka memfasilitasi diskusi terkait identifikasi mitra potensial yang mampu mengelola proyek IDD.

”Pada saat ini tidak ada keputusan akhir mengenai diskusi tersebut,” kata Sonitha.

Deputi Operasional SKK Migas Julius Wiratno bilang. sebenarnya Chevron sudah bermitra dengan Eni, Tip Top, Pertamina Hulu Energi (PHE) dan Mitra Muara Bakau dalam proyek IDD tahap II. Berhubung jadwal proyek IDD tahap II selalu mundur, ada kemungkinan nilai keekonomian proyek ini semakin berkurang.

Jadi wajar apabila Chevron mempertimbangkannya. Belum lagi proyek tersebut dibatasi oleh terminasi pada tahun 2026/2027, ”Mungkin Chevron ingin share down ke mitra dengan memperhitungkan keekonomian proyek." ujar Julius. 

Awalnya, SKK Migas memproyeksikan proyek IDD tahap II bisa berproduksi pada 2024, sebelum akhirnya mundur menjadi tahun 2025. Chevron masih mencari mitra kerja strategis untuk berbagi risiko.

Kontan, Page-14, Thursday, Jan 23, 2020

PHE Targets Increasing Oil and Gas Lifting

PT Pertamina Hulu Energi (PHE), a subsidiary of PT Pertamina (Persero), targets production-ready to sell or lift oil and gas 2020 by 181,510 barrels of oil equivalent per day (boepd) or up 3.32% compared to the target in the Work Plan and Corporate Budget (RKAP) 2019 of 175,674 boepd.

Meanwhile, PHE 2020 oil and gas lifting targets include oil lifting of 83,100 barrels of oil per day (bopd) and gas sales of 570.11 million cubic feet per day (MMscfd). Meanwhile, in the 2019 RKAP, 76,971 bopd of oil lifting and 572 MMscfd of gas. Until the end of October 2019, PHE recorded 178,208 boepd of oil and gas lifting. Oil and gas lifting consists of lifting oil 77,179 bopd and gas sales of 585 MMscfd.

"Projections until the end of the year, oil and gas lifting reaches 178,052 boepd or 101% of the target in the 2019 RKAP. Lifting oil is 100% of the target and gas is 102% of the target," said PHE Managing Director Meidawati.

In the 2020 oil and gas lifting target, Meidawati said it still relies on the Offshore North West Java (ONWJ) PHE as the largest contributor to the lifting of oil PHE, which until October 2019 was recorded at 25,788 boepd. Besides ONWJ, there is also PHE Offshore Southeast Sumatra (OSES) which also contributed greatly to reach 25,331 bopd.

The ready-to-sell production from ONWJ and OSES is part of the PHE which has a 90% participation or participating interest (PI). He added, other contributors came from PHE CPP (BOB) 4,763 bopd, Sulawesi PHE Tomori of 3,729 bopd, PHE Jambi Merang of 3,599 bopd, and PHE West Madura Offshore (PHE WMO) with the acquisition of 3,116 bopd.

Blogger Agus Purnomo in PT. PHE West Madura Offshore (WMO)

In addition, the largest contributor to natural gas lifting was PHE Tomori Sulawesi, amounting to 146.8 MMscfd. Regarding the PI scale, PHE is recorded to control 50% of PHE in the Tomori Block. In addition to the Sulawesi Tomori PHE, WMO PHE recorded 94.5 MMscfd of gas lifting, PHE ONWJ 73 MMscfd, and Jambi Merang PHE 68.3 MMscfd. To succeed in the performance of 2019, PHE has also drilled two exploration wells, 35 development wells, and 39 workover wells per October. For 2D seismic, it reaches 4,291 km, and 3D seismic reaches 95 km2.

The total investment cost that has been spent reaches the US $ 216 million until October 2019. Until the end of 2019, the investment costs used are estimated at US $ 328 million.

"Until the end of 2019, we will try to do total drilling. 5 exploration wells and 43 development wells ", he added.

Although oil and gas lifting is estimated to be higher than the target, net profit is projected to decline. In the 2019 RKAP, PHE's net profit is targeted to reach the US $ 592 million. However, the prognosis until the end of the year is the only US $ 421 million with the realization up to October worth the US $ 370 million. Meidawati explained, oil prices were the main factor in not achieving the net profit target this year. According to him, the target is based on oil price assumptions in the range of US $ 70 per barrel. However, the average oil price this year is in the range of US $ 63 per barrel.

"The target might be achieved if suddenly the oil price becomes the US $ 100 per barrel until the end of the year. When viewed from the maximum production, but this price is indeed very influential and something we cannot control, "he said.

Meanwhile, for next year it targets a net profit of US $ 487.03 million.

TECHNICAL CONSTRAINTS

Meanwhile, Pertamina Upstream Director Dharmawan Samsu said that next year's production target was very heavy and challenging. This year, technical obstacles haunt the achievement of Pertamina's oil and gas production.

"We have to make sure the drilling is no longer late because yesterday we were late for the procurement of offshore rigs," he said.

Dharmawan explained the 2020 oil and gas production target of 923,000 boepd, would be obtained from the contribution of oil and gas production from Pertamina's upstream operations in the country of 765,000 boepd. Oil production is estimated to reach 323,000 BPD of oil production and 2,559 MMscfd of gas production. Meanwhile, contributions from Pertamina's upstream operations abroad (PIEP) of oil and gas production amounted to 158 Mboepd, consisting of oil production of 107 Mbopd and gas 298 MMscfd.

"The overall prognosis of Pertamina's oil and gas production in 2019 reaches 906,000 boepd consisting of 414,000 bopd of oil production and 2,850 MMscfd of gas," he added.

IN INDONESIA

PHE Menargetkan Kenaikan Lifting Migas

PT Pertamina Hulu Energi (PHE), anak usaha PT Pertamina (Persero), menargetkan produksi siap jual atau lifting minyak dan gas bumi 2020 sebanyak 181.510 barel setara minyak per hari (boepd) atau naik 3,32% dibandingkan dengan target dalam Rencana Kerja dan Anggaran Perusahaan (RKAP) 2019 sebanyak 175.674 boepd.

Adapun, target lifting migas PHE 2020 meliputi lifting minyak sebanyak 83.100 barel minyak per hari (bopd) dan penjualan gas sebanyak 570,11 juta kaki kubik per hari (MMscfd). Sementara itu, pada RKAP 2019, lifting minyak sebanyak 76.971 bopd dan gas 572 MMscfd. Hingga akhir Oktober 2019, PHE mencatat lifting migas sebanyak 178.208 boepd. Lifting migas terdiri atas lifting minyak 77.179 bopd dan penjualan gas sebanyak 585 MMscfd. 

“Proyeksi hingga akhir tahun, lifting migas mencapai 178.052 boepd atau 101% dari target pada RKAP 2019. Lifting minyak 100% dari target dan gas 102% dari target,” ujar Direktur Utama PHE Meidawati.

Pada target lifting migas tahun 2020, Meidawati menyatakan pihaknya masih mengandalkan PHE Offshore North West Java (ONWJ) sebagai kontributor terbesar lifting minyak PHE, yang hingga Oktober 2019 tercatat sebanyak 25.788 boepd. Selain ONWJ, ada pula PHE Offshore Southeast Sumatra (OSES) yang juga berkontribusi besar yakni mencapai 25.331 bopd.

Produksi siap jual dari ONWJ dan OSES tersebut merupakan bagian PHE yang memiliki hak partisipasi atau particpating interest (PI) sebesar 90%. Dia menambahkan, kontributor lainnya datang dari PHE CPP (BOB) 4.763 bopd, PHE Tomoli Sulawesi sebesar 3 .729 bopd, PHE Jambi Merang sebesar 3.599 bopd, dan PHE West Madura Offshore (PHE WMO) dengan perolehan lifting 3.116 bopd.

Selain itu, lifting gas bumi kontributor terbesar adalah PHE Tomori Sulawesi sebanyak 146,8 MMscfd. Terkait dengan besaran PI, PHE tercatat menguasai 50% PHE di Blok Tomori. Selain PHE Tomori Sulawesi, PHE WMO mencatat lifting gas sebesar 94,5 MMscfd, PHE ONWJ 73 MMscfd, dan PHE Jambi Merang 68,3 MMscfd. 

    Untuk menyukseskan kinerja 2019, PHE juga telah melakukan pengeboran dua sumur eksplorasi, 35 sumur pengembangan, dan 39 sumur work over per Oktober. Untuk seismik 2D mencapai 4.291 km dan seismik 3D mencapai 95 km2.

Total biaya investasi yang telah dikeluarkan mencapai US$216 juta hingga Oktober 2019. Hingga akhir 2019, biaya investasi yang digunakan diestimasi mencapai US$328 juta.

“Hingga akhir tahun 2019, kami berupaya melakukan pengeboran total. 5 sumur eksplorasi dan 43 sumur pengembangan”, tambahnya. 

Kendati lifting migas diperkirakan lebih tinggi dari target, laba bersih justru diproyeksi mengalami penurunan. Dalam RKAP 2019, laba bersih PHE ditargetkan mencapai US$ 592 juta. Namun, prognosis hingga akhir tahun hanya senilai US$421 juta dengan realisasi hingga Oktober senilai US$ 370 juta. 

     Meidawati menjelaskan, harga minyak menjadi faktor utama tidak tercapainya target laba bersih pada tahun ini. Menurutnya, target tersebut berdasarkan asumsi harga minyak pada kisaran US$70 per barel. Namun, rata-rata harga minyak sepanjang tahun ini berada pada kisaran US$ 63 per barel.

“Target mungkin tercapai kalau tiba-tiba harga minyak jadi US$100 per barel sampai akhir tahun. Kalau dilihatkan dari produksi sudah maksimal, tapi harga ini memang sangat berpengaruh dan sesuatu yang tidak bisa kami kendalikan,” tuturnya.

Adapun, untuk tahun depan pihaknya menargetkan laba bersih senilai US$487,03 juta.

KENDALA TEKNIS

Sementara itu, Direktur Hulu Pertamina Dharmawan Samsu mengatakan bahwa target produksi tahun depan sangat berat dan menantang. Tahun ini, kendala teknis menghantui pencapaian produksi migas Pertamina.

“Kami harus pastikan pengeboran tidak telat lagi, karena kemarin kami telat untuk pengadaan rig offshore,” katanya.

Dharmawan menjelaskan target produksi migas 2020 sebanyak 923.000 boepd, akan didapatkan dari kontribusi produksi migas dari operasi hulu Pertamina di dalam negeri sebanyak 765.000 boepd. Untuk produksi minyak diperkirakan mencapai 323.000 bph produksi minyak dan produksi gas 2.559 MMscfd.

      Sementara itu, kontribusi dari operasi hulu Pertamina di luar negeri (PIEP) produksi migas sebesar 158 Mboepd, terdiri atas produksi minyak sebesar 107 Mbopd dan gas 298 MMscfd.

“Prognosis produksi migas Pertamina 2019 secara keseluruhan mencapai 906.000 boepd terdiri dari produksi Minyak 414.000 bopd dan gas 2.850 MMscfd,” tambahnya.

Bisnis Indonesia, Page-9, Saturday, Dec 14, 2019

When running helter-skelter Pursue 1 Million Bph

The government's dream to restore the glory of upstream oil and gas by targeting oil production of 1 million barrels per day by 2030 needs to be supported by concrete steps through policy or fiscal stimulus.

The hope of increasing oil production is certainly not an easy job. Moreover, the national upstream oil and gas sector is faced with a decline in natural oil production. In the BP Statistical Review 2019, national oil production decreased by 3.5% in 2018 or above the average decline over the past 10 years by 1.5%.

This year's production realization is even expected to decrease by more than 20,000 BPD compared to 2018. Oil production as of October 2019 was recorded at 750,500 BPD, while at the end of 2018 it was recorded at 778,000 BPD. From these data, the hope of oil production returning to reach 1 million BPD needs concrete steps.

For example, there is an equivalent finding of the Banyu Urip Field. Heading there, the Special Task Force for Upstream Oil and Gas Business Activities (SKK Migas) campaigned for four pillars of the long-term strategy to achieve the production target of 1 million BPD.

The four pillars are maintaining current production, transforming resources into production, implementing advanced oil recovery (EOR), to massive exploration activities.

Feeling that they did not want to lose before the war, SKK Migas was optimistic that the target would be achieved. Moreover, the opportunity for the national oil and gas industry is still large. This can be seen from a total of 128 sedimentary basins in Indonesia, only 54 of which have been explored and whose production is still 19 basins.

Thus there are still 74 basins waiting to be explored and 35 basins that have been explored are expected to find oil and gas reserves through continuous exploration and investment in the basin.

SKK Migas Planning Deputy Jafee Suadin revealed that by looking at the current conditions, the four efforts need to be carried out in parallel. According to him, it is difficult to rely solely on advanced drainage technology (EOR) or wait for the discovery of a new giant oil block.

"Our anchor effort is 1 million BPD. The target is a combination of EOR technology, the discovery of new reserves, and transformation of reserves into

production, "he said.

Regarding the implementation of the EOR, the government considers this to be a solution so that oil production is again attractive. Because, based on the results of a coordination meeting chaired by the Coordinating Minister for Maritime and Investment Luhut Binsar Pandjaitan, EOR is expected to provide an additional 1.6 billion barrels of oil production.

Luhut Binsar Pandjaitan

Maritime and Investment Coordinating Minister Luhut Binsar Pandjaitan said, his party had discussed efforts to increase oil production through EOR activities with oil and gas companies operating in Indonesia. He requested that the oil and gas company identify the potential EOR in oil and gas blocks in Indonesia.

"We have data that there are 1.6 billion barrels that can be produced from EOR activities," he said.

ECONOMY

However, is the production of 1.6 billion barrels using EOR already very economical? This is what seems to influence businesses to count and think again to run the EOR. Executive Director of the Reforminer Institute Komaidi Notonegoro said if the government only prioritizes production without thinking about business factors, then it is difficult for business actors to carry out further stages of drainage. According to him, the implementation of EOR is useless but it is carried out with lifting costs more expensive compared to oil imports.

"If the barrel production is more expensive than imports, will it also be a business decision? If it is seen as a driver of energy independence okay, "he said.

At present, the potential of EOR in Indonesia is spread over 129 oil fields consisting of 15 work areas. Until the middle of the year, the EOR's definite work commitment was the only US $ 446 million. 

     Acting Director-General of Oil and Gas at the Ministry of Energy and Mineral Resources (ESDM) Djoko Siswanto added that the acceleration of EOR can be done by applying this technology to several wells, not one field at a time. According to him, this step is in accordance with the proposal from the Bandung Institute of Technology (ITB).

the Bandung Institute of Technology (ITB).

"So it is injected first, closed for a while, and then the oil will come out, per well. The Minister wants which wells are, what fields the program is, and what obstacles, it will be reported on January 25, 2020, "he said.

Some studies have indeed been carried out by oil and gas contractors that have carried out EOR activities. Unfortunately, this EOR activity has not yet been massive. The government hopes that these activities will produce results, such as those carried out in the Rokan Block, the Offshore North West Java Block (ONWJ), the Rimau Block, and several fields managed by PT Pertamina EP.

Some studies have indeed been carried out by oil and gas contractors that have carried out EOR activities. Unfortunately, this EOR activity has not yet been massive. The government hopes that these activities will produce results, such as those carried out in the Rokan Block, the North West Java (ONWJ) Block, the Rimau Block, and several fields managed by PT Pertamina EP.

"The great potential of EOR is in Rokan Block with Pertamina EP, then in Zulu [ONWJ Block] PHE [Pertamina Hulu Energi], the same in Medco, namely Rimau Block, Kaji-Harapan Field," he added.

IN INDONESIA

Kala berlari pontang-panting Kejar 1 Juta Bph

Mimpi pemerintah untuk mengembalikan kejayaan hulu minyak dan gas bumi dengan menargetkan produksi minyak sebesar 1 juta barel per hari pada 2030 perlu didukung dengan langkah konkret lewat kebijakan ataupun stimulus fiskal. 

Harapan penaikan produksi minyak tentu bukan pekerjaan mudah. Apalagi sektor hulu migas nasional dihadapkan dengan penurunan produksi minyak alamiah. Dalam BP Statistical Review 2019, produksi minyak nasional menurun sebanyak 3,5% pada 2018 atau di atas rata-rata penurunan selama 10 tahun terakhir sebesar 1,5%.

Realisasi produksi tahun ini bahkan diperkirakan mengecil lebih dari 20.000 bph dibandingkan dengan 2018. Produksi minyak per Oktober 2019 tercatat sebesar 750.500 bph, sedangkan pada akhir 2018 tercatat sebesar 778.000 bph. Dari data tersebut, harapan produksi minyak kembali mencapai 1 juta bph perlu langkah konkret. 

Misalnya saja, ada penemuan setara Lapangan Banyu Urip. Menuju ke sana, Satuan Kerja Khusus Pelaksana Kegiatan Usaha Hulu Minyak dan Gas Bumi (SKK Migas) mengampanyekan empat pilar strategi jangka panjang untuk mencapai target produksi 1 juta bph tersebut.

Empat pilar tersebut yakni menjaga produksi yang ada sekarang, transformasi resource menjadi produksi, implementasi pengurasan minyak tahap lanjut (enhanced oil recovery/EOR), hingga aktivitas eksplorasi yang masif. 

Merasa tidak ingin kalah sebelum berperang, SKK Migas optimistis target tersebut tercapai. Terlebih, peluang industri migas nasional masih besar. Hal itu terlihat dari total sebanyak 128 cekungan sedimen yang ada di Indonesia, hanya 54 cekungan yang telah dieksplorasi dan yang berproduksi masih 19 cekungan.

Dengan demikian masih ada 74 cekungan yang menunggu untuk dieksplorasi serta 35 cekungan yang telah dieksplorasi diharapkan dapat ditemukan cadangan migas melalui eksplorasi dan investasi yang terus menerus di cekungan tersebut. 

Deputi Perencanaan SKK Migas Jafee Suadin mengungkapkan dengan melihat kondisi terkini, empat upaya tersebut perlu dijalankan secara pararel. Menurutnya, sulit hanya mengandalkan teknologi pengurasan tahap lanjut (EOR), atau menanti adanya temuan blok minyak raksasa baru.

“Anchor effort kami 1 juta bph. Target tersebut merupakan perpaduan antara teknologi EOR, penemuan cadangan baru, dan transformasi cadangan menjadi

produksi,” katanya.

Terkait dengan penerapan EOR, pemerintah menganggap hal ini menjadi solusi agar produksi minyak kembali menarik. Pasalnya, berdasarkan hasil rapat koordinasi yang dipimpin oleh Menteri Koordinator Maritim dan Investasi Luhut Binsar Pandjaitan, EOR diharapkan bisa memberikan tambahan produksi minyak 1,6 miliar barel. 

Menteri Koordinator Kemaritiman dan Investasi Luhut Binsar Pandjaitan menuturkan, pihaknya sudah membahas upaya menaikkan produksi minyak melalui kegiatan EOR ini bersama perusahaan-perusahaan migas yang beroperasi di Indonesia. Pihaknya meminta agar perusahaan migas mengidentifikasi potensi-potensi EOR yang ada di blok-blok migas di Indonesia.

“Kami punya data ada 1,6 miliar barel yang bisa diproduksikan dari kegiatan EOR,” katanya.

KEEKONOMIAN

Hanya saja, apakah produksi 1,6 miliar barel menggunakan EOR sudah sangat ekonomis? Hal inilah yang rasanya memengaruhi pelaku usaha berhitung dan dan berfikir ulang untuk menjalankan EOR. Direktur Eksekutif Reforminer Institute Komaidi Notonegoro mengatakan jika pemerintah hanya mengutamakan produksi tanpa memikirkan faktor bisnis, maka pelaku usaha sulit melakukan pengurasan tahap lanjut. Menurutnya, percuma saja implementasi EOR tetapi dijalankan dengan biaya lifting lebih mahal dibandingkan dengan impor minyak.

“Kalau produksi per barelnya lebih mahal dari impor, apakah juga akan menjadi keputusan bisnis? Kalau dilihat sebagai pendorong kemandirian energi oke-lah,” katanya. 

Saat ini, potensi EOR di Indonesia tersebar di 129 lapangan minyak yang terdiri dari 15 Wilayah kerja. Hingga pertengahan tahun  komitmen kerja pasti EOR hanya sebesar US$446 juta. Pelaksana Tugas Direktur Jenderal Minyak dan Gas Bumi Kementerian Energi dan Sumber Daya Mineral (ESDM) Djoko Siswanto menambahkan percepatan EOR ini bisa dilakukan dengan menerapkan teknologi ini untuk beberapa sumur, tidak satu lapangan sekaligus. Menurutnya, langkah ini sesuai usulan dari Institut Teknologi Bandung (ITB).

“Jadi diinjeksi dulu, ditutup sebentar, terus nanti keluar minyaknya, per sumur pelaksanaannya. Pak Menteri inginnya sumur mana saja, lapangan mana saja program-nya apa, dan kendalanya apa, itu nanti dilaporkan pada 25 Januari 2020,” ujarnya.

Beberapa studi memang sudah dilakukan kontraktor migas yang telah melaksanakan kegiatan EOR. Sayangnya, kegiatan EOR ini belum masif. Pemerintah berharap aktivitas ini membuahkan hasil, seperti yang dilakukan di Blok Rokan, Blok Offshore North West Java (ONWJ), Blok Rimau, dan beberapa lapangan yang dikelola oleh PT Pertamina EP.

“Yang besar potensi EOR kan ada di Blok Rokan dengan Pertamina EP, kemudian di Zulu [Blok ONWJ] PHE [Pertamina Hulu Energi], sama di Medco yaitu Blok Rimau, Lapangan Kaji-Semoga,” tambahnya.

Bisnis Indonesia, Page-24, Monday, 9 Dec 2019

The Government Guarantees Fertilizer and Petrochemical Industrial Gas Supply

The government is committed to meeting gas needs for the fertilizer and petrochemical industry, in accordance with the applicable regulations and production sharing contracts (PSCs). In fact, seven large gas projects operating in the next few years have the potential to be a source of gas for the industry.

Acting Director-General of Oil and Gas at the Ministry of Energy and Mineral Resources (ESDM) Djoko Siswanto said that in the Oil and Gas Law, the government has prioritized gas supply for the country, particularly the fertilizer and petrochemical industries. In fact, in some PSCs with oil and gas companies, there is an obligation to set aside a portion of their gas production for the domestic market (DMO).

"This DMO problem is only a matter of price. There are DMOs whose prices are set, there are market prices. Then, the DMO contract is five years old, [there is] the same as the contract. It depends on the economy when preparing the POD (the plan of development), "he said after a meeting with the House of Representatives Commission VII.

PUPUK ISKANDAR MUDA (PIM)

He admitted some fertilizer factories are still difficult to get gas, one of them is PT Pupuk Iskandar Muda (PIM). The reason is that the gas sources in this region are starting to run out. In return, the government covered the gas needs of this fertilizer plant using liquefied natural gas / LNG with the risk of very high gas prices.

Pupuk Kalimantan Timur (PKT)

However, fertilizer factories in some regions can obtain gas at competitive prices such as PT Pupuk Kalimantan Timur (PKT), PT Pupuk Kujang Cikampek (PKC), PT Pupuk Sriwidjaja (Pusri), and PT Petrokimia Gresik. In fact, the CCP can obtain gas at prices below the US $ 5 per million British thermal units (MMBTU). Going forward, the fertilizer plant can get gas from supplies currently exported through pipes to Singapore and Malaysia.

"In 2022, fertilizer factories are needed, while the export of gas through pipes from the working area in Natuna and Grissik Field will be completed. So, Kujang and Sriwidjaja Fertilizers can use this, "said Djoko.

The Head of the Special Task Force for Upstream Oil and Gas Business Activities (SKK Migas) Dwi Soetjipto added that the gas supply for PIM had to wait for the development of several oil and gas blocks in the region. The supply of gas directly from the pipeline is expected to cut gas prices to PIM.

"In the future, we will discuss so that the price can be reduced by using other sources. Potential is in the Andaman Blocks I, II, and III. From the available data, the potential is good, "he said.

PT Pupuk Indonesia (Persero)

The Managing Director of PT Pupuk Indonesia (Persero) Aas Asikin Idat revealed that his gas supply shortage problem had already been faced. In addition, some gas supply contracts owned by fertilizer companies are short-term for around 2-3 years. He hopes to be able to obtain long-term supply certainty.

"Moreover, the majority of gas contracts expire in 2021-2022 and many have no certainty about the gas, including the allocation we have not received," he explained.

The absence of long-term supply, he claimed, would have an impact on the continued operation of the plant. Aas gave an example, the PIM-owned factory would stop operating altogether if there was no certainty of gas in 2020. Then, some of the Pupuk Kujang and Pusri factories would also immediately stop operating in 2023 and 2024 respectively due to supply shortages.

PUPUK SRIWIJAYA (PUSRI)

While the urea Petrochemical Gresik plant has the potential to operate in 2021. But he admitted, the absence of long-term gas supply is related to gas prices. At present, the gas price paid by his party exceeds the factory economy, which is an average of US $ 5.8 per MMBtu. 

    This figure is even higher than the price of gas for fertilizer plants in several other countries, where an average of US $ 3.95 per MMBtu. On the other hand, the price of this gas reaches 70% of the total production cost.

"Iskandar Muda has a contract, but this is not yet effective because the price is set at the US $ 7.8 per MMBtu. Some Sriwidjaja ended in 2023-2027 at a price of US $ 5.2-6 plus a toll fee. The Kujang Fertilizer Factory ends in 2022 at a price of US $ 5.73-6 per MMBtu. Petrokimia Gresik has a relatively large price of around US $ 6.36-7.85 per MMBtu, "said Aas.

Seven Projects

Meanwhile, Djoko continued there have been a number of gas projects that could secure gas supplies for fertilizer and petrochemical plants in the future. He hoped that a fertilizer and petrochemical plant would be built near this gas project.

"For example, building [a factory] in Bintuni, or [near] Sakakemang," he said.

Dwi added, there were seven gas projects that could be a source of gas for the fertilizer and petrochemical industries. The total potential supply of this gas reaches 1,167 million cubic feet per day / MMSCFD. The seven gas projects will start producing gas in the period 2023-2027.

"In South Sumatra there is a Sakakemang Project by Repsol SA starting production in 2021 of 300 mmscfd, this can be accelerated in part," he said.

The buyer of this gas is Pupuk Indonesia. Furthermore, the Nunukan PT Pertamina Hulu Energi (PHE) Project 90 mmscfd began in 2024 with the buyer of PT Karya Mineral Jaya. Gas projects in the Bontang Area and Indonesia Deepwater Development (IDD) 100 MMSCFD starting in 2023 with buyers of PT Kaltim Methanol Industri (KMI) and Kaltim Pharma Industri (KPI). 

PT Pertamina EP Cepu (PEPC)

     The Sandalwood and Alas Tua Project by PT Pertamina EP Cepu (PEPC) 150 mmscfd starting in 2023. Then, the Tangguh Train III Refinery Project for the petrochemical industry each amounted to 90 mmscfd for phase I in 2022 and phase II in 2026.

Genting Oil

The Kasuri Project by Genting Oil with petrochemical industry buyers amounted to 197 mmscfd starting in 2023. Finally, the Abadi LNG Project amounted to 150 mmscfd in 2027 and will be accelerated.

Dwi admitted it is not impossible that all national gas production is used domestically. However, this depends on the readiness and ability of the domestic industry to buy the gas supply. Not only that, but the readiness of the gas distribution infrastructure is also important. 

     Referring to SKK Migas data, the distribution of gas into the country until last September was recorded at 4,013.67 mmscfd from the total lifting gas of 6,103.26 mmscfd. While the total gas supply for the fertilizer industry is 749.44 mmscfd.

IN INDONESIA

Pemerintah Jamin Pasokan Gas Industri Pupuk dan Petrokimia

Pemerintah berkomitmen memenuhi kebutuhan gas untuk industri pupuk dan petrokimia, sesuai dalam regulasi dan kontrak kerja sama (production sharing contract/PSC) yang berlaku. Bahkan, tujuh proyek gas besar yang beroperasi dalam beberapa tahun ke depan berpotensi menjadi sumber gas bagi industri tersebut. 

Pelaksana Tugas Direktur Jenderal Minyak dan Gas Bumi Kementerian Energi dan Sumber Daya Mineral (ESDM) Djoko Siswanto mengatakan, dalam Undang-Undang Migas, pemerintah telah memprioritaskan pasokan gas untuk dalam negeri, khususnya industri pupuk dan petrokimia. Bahkan di beberapa PSC dengan perusahaan migas, terdapat kewajiban menyisihkan sebagian produksi gasnya untuk pasar domestik (domestic market obligation/DMO).

“Soal DMO ini kan soal harga saja. Ada DMO yang hargasnya ditentukan, ada yang harga pasar. Kemudian, kontrak DMO ini ada yang lima tahun, [ada yang] sama dengan kontraknya. Itu tergantung keekonomian saat menyusun POD (plan of development),” kata dia usai rapat dengan Komisi VII DPR.

Diakuinya, beberapa pabrik pupuk memang masih sulit mendapatkan gas, salah satunya PT Pupuk Iskandar Muda (PIM). Pasalnya, sumber gas yang ada di wilayah ini memang mulai habis. Sebagai gantinya, pemerintah menutup kebutuhan gas pabrik pupuk ini menggunakan gas alam cair/LNG dengan risiko harga gas yang sangat tinggi. 

Namun pabrik pupuk di beberapa wilayah bisa memperoleh gas dengan harga kompetitif seperti PT Pupuk Kalimantan Timur (PKT), PT Pupuk Kujang Cikampek (PKC), PT Pupuk Sriwidjaja (Pusri), dan PT Petrokimia Gresik. Bahkan, PKT bisa memperoleh gas dengan harga di bawah US$ 5 per juta british thermal unit (mmbtu). Ke depannya, pabrik pupuk bisa memperoleh gas dari pasokan yang saat ini diekspor melalui pipa ke Singapura dan Malaysia. 

“Di 2022, pabrik pupuk sudah butuh, sementara ekspor gas melalui pipa dari wilayah kerja di Natuna dan Lapangan Grissik akan selesai. Jadi, Pupuk Kujang dan Sriwidjaja bisa pakai ini,” tutur Djoko. 

Kepala Satuan Kerja Khusus Pelaksana Kegiatan Usaha Hulu Minyak dan Gas Bumi (SKK Migas) Dwi Soetjipto menambahkan, pasokan gas untuk PIM memang harus menunggu pengembangan beberapa blok migas di wilayah tersebut. Adanya pasokan gas langsung dari pipa diharapkan bisa memangkas harga gas ke PIM.

“Ke depan, kami diskusi agar harganya bisa ditekan dengan memanfaatkan sumber lain. Potensi ada di Blok Andaman I, II, dan III. Dari data yang ada, potensinya bagus,” ujarnya.

Direktur Utama PT Pupuk Indonesia (Persero) Aas Asikin Idat mengungkapkan, masalah kekurangan pasokan gas sudah dihadapi pihaknya. Ditambah lagi, sebagian kontrak pasokan gas yang dimiliki perusahaan pupuk bersifat jangka pendek sekitar 2-3 tahun saja. Pihaknya berharap bisa memperoleh kepastian pasokan untuk jangka panjang.

“Apalagi, mayoritas kontrak gas berakhir di 2021-2022 dan banyak yang belum ada kepastian gasnya, termasuk alokasinya belum kami terima,” jelasnya.

Tidak adanya pasokan jangka panjang, diklaimnya akan berdampak pada kelanjutan operasi pabrik. Aas mencontohkan, pabrik milik PIM akan berhenti operasi seluruhnya jika tidak ada kepastian gas di 2020. Kemudian, sebagian pabrik Pupuk Kujang dan Pusri juga akan menyusul berhenti beroperasi masing-masing di 2023 dan 2024 karena ada kekurangan pasokan. 

Sementara pabrik urea Petrokimia Gresik berpotensi beroperasi pada 2021. Namun diakuinya, tidak adanya pasokan gas jangka panjang ini berkaitan dengan harga gas. Saat ini, harga gas yang dibayarkan pihaknya melebihi keekonomian pabrik, yakni rata-rata US$ 5,8 per mmbtu. 

     Angka ini bahkan lebih tinggi dari harga gas bagi pabrik pupuk di beberapa negara lain, di mana rata-rata US$ 3,95 per mmbtu. Di sisi lain, harga gas ini mencapai 70% dari total biaya produksi.

“Iskandar Muda ada kontrak, tetapi ini belum juga efektif karena harga yang ditetapkan US$ 7,8 per mmbtu. Sriwidjaja ada yang berakhir di 2023-2027 dengan harga US$ 5,2-6 ditambah toll fee. Pabrik Pupuk Kujang berakhir di 2022 dengan harga US$ 5,73-6 per mmbtu. Petrokimia Gresik harga relative besar sekitar US$ 6,36-7,85 per mmbtu,” kata Aas.

Tujuh Proyek

Sementara itu, Djoko melanjutkan telah ada sejumlah proyek gas yang bisa mengamankan pasokan gas untuk pabrik pupuk dan petrokimia di masa mendatang. Dia berharap, pabrik pupuk dan petrokimia dibangun di dekat proyek gas ini. 

“Misalnya bangun [pabrik] di Bintuni, atau [dekat] Sakakemang,” ujarnya.

Dwi menambahkan, terdapat tujuh proyek gas yang bisa menjadi sumber gas bagi industri pupuk dan petrokimia. Total potensi pasokan gas ini mencapai 1.167 juta kaki kubik per hari/MMSCFD. Ketujuh proyek gas ini akan mulai memproduksi gas pada periode 2023-2027.

“Di Sumatera Selatan ada Proyek Sakakemang oleh Repsol SA mulai berproduksi di 2021 sebesar 300 mmscfd, ini bisa dipercepat sebagian,” ujarnya. 

Pembeli gas ini adalah Pupuk Indonesia. Selanjutnya, Proyek PT Pertamina Hulu Energi (PHE) Nunukan 90 mmscfd mulai 2024 dengan pembeli PT Karya Mineral Jaya. Proyek gas di Area Bontang dan Indonesia Deepwater Development (IDD) 100 mmscfd mulai 2023 dengan pembeli PT Kaltim Methanol Industri (KMI) dan Kaltim Pharma Industri (KPI). 

     Proyek Cendana dan Alas Tua oleh PT Pertamina EP Cepu (PEPC) 150 mmscfd mulai 2023. Kemudian, Proyek Kilang Tangguh Train III untuk industri petrokimia masing-masing sebesar 90 mmscfd untuk tahap I di 2022 dan tahap II di 2026. 

Proyek Kasuri oleh Genting Oil dengan pembeli industri petrokimia sebesar 197 mmscfd mulai 2023. Terakhir, Proyek LNG Abadi sebesar 150 mmscfd di 2027 dan akan dipercepat. 

Dwi mengakui, bukan tidak mungkin seluruh produksi gas nasional digunakan di dalam negeri. Namun, hal ini tergantung kesiapan dan kemampuan industri domestik membeli pasokan gas tersebut. Tidak hanya itu, kesiapan infrastruktur distribusi gas juga penting. 

      Mengacu data SKK Migas, penyaluran gas ke dalam negeri hingga September lalu tercatat mencapai 4.013,67 mmscfd dari total lifting gas 6.103,26 mmscfd. Sementara total pasokan gas untuk industri pupuk yakni sebesar 749,44 mmscfd.

Investor Daily, Page-9, Friday, 6 Dec 2019

Next year, Pertamina Oil and Gas Production 923 BOEPD

PT Pertamina (Persero) targets oil and gas production from the oil and gas block it manages to reach 923 thousand barrels of oil equivalent per day (boepd) next year, or up slightly from this year's target of 922 thousand boepd.

Pertamina Upstream Director Dharmawan H Samsu said that the oil and gas production target next year of 923 thousand boepd consisted of oil production of 430 thousand barrels per day (BPD) and gas of 2,857 million cubic feet per har / mmscfd. 

      According to Pertamina's data, the company's oil production is recorded to rise 3.85% from this year's target of 414 thousand BPD, while gas production is down 2.92% from this year's target of 2,943 mmscfd.

"The target is planned to be obtained from the contribution of oil and gas production from Pertamina's upstream operations in the country amounting to 765 thousand boepd and 158 thousand boepd abroad," he said.

Meanwhile, until the end of this year, the company's oil and gas production is projected at 906 thousand boepd or 98.26% of the target. Specifically, the prognosis of oil production is in accordance with the target of 414 thousand BPD and 2,850 mmscfd or 96.84% of the target.

Dharmawan admitted that this year's oil and gas production was less than optimal due to rig procurement constraints. He said he must ensure that the same problem does not recur in order to pursue the 2020 oil and gas production target.

"It is heavy [with a production target of 923 thousand boepd] because we have to make sure drilling cannot be late. Yesterday we were late because there were no rigs, especially offshore rigs, "he said.

However, he is optimistic that the company's oil and gas production next year will be better. Because, only abroad, Pertamina's oil and gas production will improve. This is because Pertamina's team in Algeria has created a system so that compressor disruption that have an impact on oil and gas production performance this year do not re-occur. 

     So that the company's oil and gas production from foreign assets next year is targeted to increase 3.26% from the prognosis by the end of this year 153 thousand boepd to 158 thousand boepd. In particular, oil production is targeted to increase slightly from 105 thousand bpd to 107 thousand BPD, and gas production will increase from 276 mmscfd to 298 mmscfd.

"Next year's domestic production consists of 323 thousand bpd of oil and 2,559 mmscfd of gas," he said.

For information, the company's oil and gas block assets in the country are managed through its subsidiaries, PT Pertamina Hulu Energi (PHE), PT Pertamina Hulu Indonesia (PHI), PT Pertamina EP (PEP), and PT Pertamina EP Cepu (PEPC).

Director of Pertamina Hulu Energi Meidawati added that oil production from its assets in the next year is targeted at 84 thousand BPD and 822 mmscfd of gas. To achieve this target, his party will carry out drilling for the development of 51 wells and exploration of 6 wells, as well as the workover of 50 wells.

"The challenge going forward is fluctuations in oil prices because supply is greater than demand. Then, changes to the gas or LNG market have the potential the decline in gas prices globally, "She said.

Furthermore, Pertamina EP President Director Nanang Abdul Manaf targets the production of assets under management to be stable in 2020. To be precise, Pertamina EP oil production is still targeted at 85 thousand BPD and 965 mmscfd of gas as this year. This is due to a decrease in production in some oil and gas fields, which is offset by an increase in production in other fields.

To achieve the production target, the company plans to drill 108 development wells. In addition to the development well, he also plans to drill 10 exploration wells in 2020. Not only that, but he will also start producing (on stream) a number of oil and gas projects, including the Great Bamboo Field and Akasia Bagus which gives an additional production of around 4,300 BPD.

Investment increases next year, Pertamina budgeted upstream investment of US $ 3.7 billion of the company's total investment target of US $ 7.8 billion. This investment budget is up 53.5% from this year's prognosis of US $ 2.41 billion.

the Merakes Field - Sepinggan 

According to Dharmawan, one of the increases in upstream investment is due to the development of the Merakes Field, the East Sepinggan Block will begin in 2020. In this block, for information, Pertamina through PHE has a participating interest (PI) of 15%. While the operator of this block is ENI from Italy.

IN INDONESIA

Tahun Depan, Produksi Migas Pertamina 923 BOEPD

PT Pertamina (Persero) menargetkan produksi migas dari blok migas yang dikelolanya mencapai 923 ribu barel setara minyak per hari (barrel oil equivalent per day/ boepd) pada tahun depan, atau naik sedikit dari target tahun ini sebesar 922 ribu boepd. 

Direktur Hulu Pertamina Dharmawan H Samsu menuturkan, target produksi migas tahun depan sebesar 923 ribu boepd tersebut terdiri dari produksi minyak 430 ribu barel per hari (bph) dan gas 2.857 juta kaki kubik per har/mmscfd. Sesuai data Pertamina, produksi minyak perseroan tercatat naik 3,85% dari target tahun ini 414 ribu bph, sementara produksi gas turun 2,92% dari target tahun ini 2.943 mmscfd.

“Target tersebut rencananya akan didapatkan dari kontribusi produksi migas dari operasi hulu Pertamina di dalam negeri sebesar 765 ribu boepd dan luar negeri 158 ribu boepd,” kata dia.

Sementara itu, hingga akhir tahun ini, produksi migas perseroan diproyeksikan sebesar 906 ribu boepd atau 98,26% dari target. Rincinya, prognosa produksi minyak sesuai target 414 ribu bph dan gas 2.850 mmscfd atau 96,84% dari target. 

Diakui Dharmawan, produksi migas tahun ini kurang optimal lantaran kendala pengadaan rig. Pihaknya harus memastikan masalah yang sama tidak terulang agar bisa mengejar target produksi migas 2020. 

“Berat [target produksi 923 ribu boepd], karena kami harus pastikan drilling tidak boleh telat. Kemarin kami telat karena rig toidak ada, terutama rig offshore,” ujar dia. 

Meski demikian, pihaknya optimistis produksi migas perseroan tahun depan akan lebih baik. Pasalnya, di luar negeri saja, produksi migas Pertamina akan membaik. Hal ini mengingat tim Pertamina di Aljazair telah membuat sistem agar gangguan kompresor yang berdampak pada kinerja produksi migas tahun ini tidak kembali terjadi. 

      Sehingga produksi migas perseroan dari aset luar negeri pada tahun depan ditargetkan naik 3,26% dari prognosa akhir tahun ini 153 ribu boepd menjadi 158 ribu boepd. Rincinya, produksi minyak ditargetkan naik sedikit dari 105 ribu bph menjadi 107 ribu bph, serta produksi gas meningkat dari 276 mmscfd menjadi 298 mmscfd.

“Untuk produksi dalam negeri pada tahun depan terdiri dari minyak 323 ribu bph dan gas 2.559 mmscfd,” kata dia. 

Sebagai  informasi, aset blok migas perseroan di dalam negeri dikelola melalui anak usahanya, PT Pertamina Hulu Energi (PHE), PT Pertamina Hulu Indonesia (PHI), PT Pertamina EP (PEP), dan PT Pertamina EP Cepu (PEPC).

Direktur Utama Pertamina Hulu Energi Meidawati menambahkan, produksi minyak dari asetnya di tahun depan ditargetkan sebesar 84 ribu bph dan gas 822 mmscfd. Untuk mencapai target tersebut, pihaknya akan melaksanakan pengeboran pengembangan 51 sumur dan eksplorasi 6 sumur, serta kerja ulang (workover) 50 sumur.

“Tantangan kedepan adalah fluktuasi harga minyak karena supply lebih besar dari demandnya. Kemudian, perubahan pasar gas atau LNG berpotensi penurunan harga gas secara global,” kata Meidawati.

Selanjutnya, Presiden Direktur Pertamina EP Nanang Abdul Manaf menargetkan produksi aset yang dikelolanya bakal stabil di 2020. Tepatnya, produksi minyak Pertamina EP tetap ditargetkan sebesar 85 ribu bph dan gas 965 mmscfd seperti pada tahun ini. Hal ini karena adanya penurunan produksi di beberapa lapangan migas, yang diimbangi kenaikan produksi di lapangan lainnya. 

Untuk mencapai target produksi tersebut, pihaknya berencana mengebor 108 sumur pengembangan. Selain sumur pengembangan, pihaknya juga berencana mengebor 10 sumur eksplorasi di 2020. Tidak hanya itu, pihaknya juga akan mulai memproduksikan (on stream) beberapa proyek migas, diantaranya Lapangan Bambu Besar dan Akasia Bagus yang memberi tambahan produksi sekitar 4.300 bph. 

Investasi meningkat pada tahun depan, Pertamina menganggarkan investasi hulu sebesar US$ 3,7 miliar dari total target investasi perseroan US$ 7,8 miliar. Anggaran investasi ini naik 53,5% dari prognosa tahun ini US$ 2,41 miliar.

Menurut Dharmawan, kenaikan investasi hulu salah satunya lantaran pengembangan Lapangan Merakes, Blok East Sepinggan akan dimulai di 2020. Di blok ini, sebagasi informasi, Pertamina melalui PHE memiliki hak partisipasi (participating interest/PI) sebesar 15%. Sementara operator blok ini adalah ENI dari Italia.

Investor Daily, Page-9, Tuesday, Dec 3,  2019