PGN Budgeted US $ 500 Million in Investment

PT Perusahaan Gas Negara (PGN) Tbk will invest around US $ 500 million, up 10 percent from last year's realization. The investment budget will be used for the construction of pipes with an additional target of around 700 kilometers (km). PGN President Director Gigih Prakoso said this year's investment plan was focused on developing a pipeline. 

    The company will increase the length of the pipeline, both distribution and transmission. One of the mistakes is by completing the pipeline projects undertaken by PT Pertamina Gas (Pertagas).

"The investment budget is around US $ 500 million. There is a 10% increase from 2018 realization, "he said.

He explained, there are at least three pipelines that Pertagas worked on that will be completed this year. In the fields, Gresik-Semarang Pipe, Duri-Dumai, and Grissik-PT Pupuk Sriwijaya (Pusri). In addition, it will also add distribution pipes to consumers. Thus, the length of PGN's pipeline segment of around 9,500 km will increase.

"Later it will probably increase by around 700 km this year, this is all, transmission, distribution, to pipes to consumers," said Gigih.

Pertagas began building the Grissik-Pusri Gas pipeline in July last year. This pipe was built to provide gas supply for energy and raw material needs of PT Pupuk Sriwidjaja (Pusri) in South Sumatra. The Grissik-Pusri gas pipeline that passes through Banyuasin and Musi Banyusin Regency is designed with a diameter of 20 inches and a length of 176 kilometers (Km).

The pipeline will deliver gas from ConocoPhillips (COPI) Grissik Gas Plant in Grissik, Musi Banyuasin 30 million cubic feet per day (million standard cubic feet per day / mmscfd) in the first year. Furthermore, the gas supply can increase to 70 mmscfd.

For Pipa Duri-Dumai with an investment of US $ 52.2 million, Pertagas works with PGN. The US $ 76 million Duri-Dumai pipeline has a diameter of 24 inches and a length of 64 km. The starting point of the transmission pipe is in the Grissik-Duri Pipe Meter Station and ends at Kilari Unit II Dumai. 

    The gas flowed through this pipeline comes from the Corridor Block which is managed by ConocoPhillips in South Sumatra. In addition, there will be additional gas from the Bentu Block which is operated by PT Energi Mega Persada (EMP). The total gas supply that can flow to the transmission pipeline network can reach 200 mmscfd.

The gas supply will be used by PT Pertamina (Persero) and PGN. Pertamina will use 57 mmscfd of gas and can increase to 120 mmscfd to meet the needs of Dumai Refinery. While PGN will deliver 37 mmscfd of gas to meet the needs of customers both industrial, commercial, small customers and households. Furthermore, the Gresik-Semarang transmission pipe is planned to have a capacity of up to 500 mmscfd and length 267 km.

The investment value of this project reaches US $ 250 million. The pipeline, which is equipped with 19 future connections, has the potential to channel gas to industries in seven districts / cities along the Central Java and East Java pipelines. 

     The gas supply for this pipe comes from the Jambaran-Tiung Biru Project which will be channeled to PT PLN (Persero) 100 mmscfd and 72 mmscfd industries. Construction of the distribution pipeline was also carried out to open new markets.

"There are many new markets, areas that we have developed in Central Java, Duri, Dumai, and North Sumatra," he said.

Integration

After completing the acquisition of 51% of Pertagas shares at the end of last year, Gigih revealed, PGN immediately had control of Pertagas. With this control, it wants the entire Pertagas project to be integrated with the PGN project, both for the distribution pipeline project or transmission. Furthermore, his party will determine the pattern of operation between Pertagas and PGN.

He explained, one of the options, it would divide the management of the transmission pipeline to Pertagas and the distribution pipeline by PGN, or vice versa.

"PGN is on the distribution side, or we submit a new project in the transmission sector to Pertagas," he said.

With transmission pipes held entirely by Pertagas, it is expected that operational costs will be more edition. Gigih added that his party would also regulate the market which would be managed by PT Pertagas Niaga. So far, Pertagas Niaga has been said to tend to sell liquefied natural gas (LNG) in retail. Pertagas in the future can be focused on working on this market.

"PGN also has an idea (PT Gagas Energi Indonesia), we can give Gagak the assignment of the SPBG handle," he said.

Last December, PGN officially took ownership of 51% of the shares of PT Pertamina Gas (Pertagas) and four of its subsidiaries with a transaction value of Rp 20.18 trillion Four Pertagas subsidiaries namely PT Perta Arun Gas, PT Perta-Gas, PT Perta-Samtan Gas , and PT Perta Kalimantan Gas. Initially, PGN would only take over Pertagas and one of its subsidiaries, PT Pertagas Niaga. With this acquisition, PGN officially became a gas subholding.

However, the payment of this acquisition will be carried out in two stages. In the first stage, PGN has paid 50% of the total purchase price or equivalent to IDR 10.09 trillion in cash. As for the second stage, the company will issue a Promissory Note of 50% of the total purchase price within a period of six months.

IN INDONESIAN

PGN Anggarkan Investasi US$ 500 Juta

PT Perusahaan Gas Negara (PGN) Tbk bakal mengeluarkan dana investasi sekitar US$ 500 juta, naik 10% dari realisasi tahun lalu. Anggaran investasi ini akan digunakan untuk pembangunan pipa dengan target tambahan sekitar 700 kilometer (km). Direktur Utama PGN Gigih Prakoso mengatakan, rencana investasi tahun ini difokuskan untuk pengembangan jaringan pipa. Perusahaan akan menambah panjang ruas pipa, baik distribusi maupun transmisi. Salah satimya yakni dengan merampungkan proyek-proyek pipa yang dikerjakan PT Pertamina Gas (Pertagas).

“Anggaran investasinya sekitar US$ 500 juta. Ada kenaikan 10% dari realisasi 2018,” katanya.

Dia merinci, setidaknya ada tiga proyek pipa yang digarap Pertagas yang akan diselesaikan pada tahun ini. Rincinya, Pipa Gresik-Semarang, Duri-Dumai, dan Grissik-PT Pupuk Sriwijaya (Pusri). Selain itu, pihaknya juga akan menambah pipa distribusi ke konsumen. Sehingga, panjang ruas pipa PGN sekitar 9.500 km akan meningkat.

“Nanti mungkin akan bertambah sekitar 700 km tahun ini, ini semuanya, transmisi, distribusi, sampai pipa-pipa ke konsumen,” tutur Gigih.

Pertagas mulai bangun pipa Gas Grissik-Pusri pada Juli tahun lalu. Pipa ini dibangun guna memberikan pasokan gas untuk kebutuhan energi dan bahan baku PT Pupuk Sriwidjaja (Pusri) di Sumatera Selatan. Pipa gas Grissik-Pusri yang melewati Kabupaten Banyuasin dan Musi Banyusin ini didesain berdiameter 20 inchi dan panjang 176 kilometer (Km).

Pipa akan mengalirkan gas dari Grissik Gas Plant ConocoPhillips (COPI) di Grissik, Musi Banyuasin 30 juta kaki kubik per hari (million standard cubic feet per day/mmscfd) pada tahun pertama. Selanjutnya, pasokan gas dapat bertambah menjadi 70 mmscfd.

Untuk Pipa Duri-Dumai dengan nilai investasi US$ 52,2 juta, Pertagas mengerjakannya bersama PGN. Pipa Duri-Dumai senilai US$ 76 juta ini memiliki diameter 24 inch dan panjang 64 km. Titik awal pipa tranmisi di Duri Meter Station Pipa Grissik-Duri dan berakhir di Kilari Unit II Dumai. Gas yang dialirkan melalui pipa ini berasal dari Blok Corridor yang dikelola oleh ConocoPhillips di Sumatera Selatan. Selain itu, akan ada tambahan gas dari Blok Bentu yang dioperasikan oleh PT Energi Mega Persada (EMP). Total pasokan gas yang dapat mengalir ke jaringan pipa transmisi tersebut bisa mencapai 200 mmscfd.

Pasokan gas tersebut akan digunakan PT Pertamina (Persero) dan PGN. Pertamina akan menggunakan gasnya 57 mmscfd dan bisa naik menjadi 120 mmscfd untuk memenuhi kebutuhan Kilang Dumai. Sementara PGN akan menyalurkan gasnya 37 mmscfd untuk memenuhi kebutuhan pelanggan baik industri, komersial, pelanggan kecil, dan rumah tangga. Selanjutnya, Pipa transmisi Gresik-Semarang rencananya memiliki kapasitas hingga 500

mmscfd dan panjang 267 km. 

Nilai investasi proyek ini mencapai US$ 250 juta. Pipa yang dilengkapi dengan 19 future connection ini berpotensi menyalurkan gas bagi industri di tujuh kabupaten/kota sepanjang Jawa Tengah dan Jawa Timur yang terlewati pipa. Pasokan gas untuk pipa ini berasal dari Proyek Jambaran-Tiung Biru

yang akan dialirkan ke PT PLN (Persero) 100 mmscfd dan industri 72 mmscfd. Pembangunan pipa distribusi juga dilakukan untuk membuka pasar baru.

“Pasar baru banyak, daerah-daerah yang kami kembangkan Jawa Tengah, Duri, Dumai, dan Sumatera Utara,” kata dia.

Integrasi

Pasca rampungnya akuisisi 51% saham Pertagas pada akhir tahun lalu, Gigih mengungkapkan, PGN langsung memiliki kendali pada Pertagas. Dengan adanya kendali ini, pihaknya menginginkan agar seluruh proyek Pertagas dapat diintegrasi dengan proyek PGN, baik untuk proyek pipa distribusi

maupun transmisi. Selanjutnya, pihaknya akan menentukan pola operasi antara Pertagas dan PGN.

Dia menjelaskan, salah satu opsinya, pihaknya akan membagi pengelolaan pipa transmisi ke Pertagas dan pipa distribusi oleh PGN, atau sebaliknya.

“PGN di sisi distribusinya, atau ada proyek baru di bidang transmisi kami serahkan ke Pertagas untuk membangun,” tutur dia. 

Dengan pipa transmisi dipegang seluruhnya oleh Pertagas, maka diharapkan biaya operasionalnya lebih edisiensi. Gigih menambahkan, pihaknya juga akan mengatur pasar yang akan dikelola oleh PT Pertagas Niaga. Selama ini, Pertagas Niaga disebutnya cenderung menjual gas alam cair (liquefied natural gas/ LNG) secara retail. Pertagas ke depannya bisa difokuskan untuk menggarap pasar ini.

“PGN juga punya Gagas (PT Gagas Energi Indonesia), Gagak bisa kami kasih penugasan handle SPBG,” ujarnya.

Pada Desember lalu, PGN resmi mengambil alih kepemilikan 51% saham PT Pertamina Gas (Pertagas) dan empat anak usahanya dengan nilai transaksi Rp 20,18 triliun Empat anak usaha Pertagas yakni PT Perta Arun Gas, PT Perta Daya Gas, PT Perta-Samtan Gas, dan PT Perta Kalimantan Gas. Awalnya PGN hanya akan mengambil alih Pertagas dan satu anak usahanya, PT Pertagas Niaga. Dengan akuisisi ini, PGN secara resmi menjadi subholding gas. 

Namun, pembayaran akuisisi ini akan dilakukan dalam dua tahap. Pada tahap pertama, PGN telah membayar sebesar 50% dari total harga pembelian atau ekuivalen Rp 10,09 triliun secara tunai. Adapun untuk tahap kedua, perusahaan akan menerbitkan Promissory Note sebesar 50 % dari total harga pembelian dalam jangka waktu enam bulan.

Investor Daily, Page-9, Saturday, Jan 12, 2019

Chevron IDD Oil and Gas Project Contract Scheme Evaluated

The government through the Ministry of Energy and Mineral Resources (ESDM) is currently evaluating the Ultra Deep Development (IDD) project contract scheme specifically for the Rapak and Ganal Blocks. Until the IDD project contract expires in 2027-2028, the contract uses a cost recovery scheme in the form of a production sharing contract (PSC).

The evaluation of the contract scheme was carried out because Chevron Asia Pacific had just submitted a contract extension at the IDD Project on the Rapak and Ganal Blocks. Deputy Minister of ESDM, Arcandra Tahar said, the contract extension of the two oil and gas blocks to date is still evaluated by the government.

"Their cost recovery is until the year 2027-2028. After that it is being processed," he said.

So far, the government always requires the extension of the new oil and gas block contract to use a profit sharing scheme or gross split. But unlike this one, the government still has to conduct a study and evaluate before deciding on the extension of Chevron's contract in the Rapak Block and Ganal Block.

"Depends on the government. This is being evaluated," he said.

Last year, Chevron officially revised the Plan of Development (POD) I with a value of US $ 6 billion. Chevron's Corporate Communication Manager, Sonitha Poernomo, confirmed that Chevron had submitted a Revised POD and a proposal to extend the Rapak Cooperation Contract and Ganal KKS.

However, Sonitha was not prepared to mention in detail the contract scheme to be used by Chevron to extend the Ganal Block and Rapak Block.

"For commercial reasons, we cannot convey the details of the contents of the proposal to the public," he added.

IDD projects are categorized as National Strategic Projects (PSN). The first phase IDD project at Bangka Field has been in production since August 2016. Currently, the gas field produces eight liquefied natural gas (LNG) cargoes shipped from the Bontang LNG Terminal, East Kalimantan.

Chevron previously targeted that gas could spurt from the second phase of IDD projects with the development of the Gendalo and Gehem fields in the period 2023-2024. Referring to data from the Special Task Force for Upstream Oil and Gas (SKK Migas), the production could reach up to 1,120 mmscfd of gas and 40,000 barrels per day (bpd) of oil. 

Dwi Soetjipto

    Head of SKK Migas, Dwi Soetjipto estimates that the cost of developing IDD projects reaches around US $ 5 billion. That value is still below the previous Chevron submission.

IN INDONESIAN

Skema Kontrak Proyek Migas IDD Chevron Dievaluasi

Pemerintah melalui Kementerian Energi dan Sumber Daya Mineral (ESDM) tengah mengevaluasi skema kontrak proyek ultra laut dalam atau Indonesia Deepwater Development (IDD) khusus untuk Blok Rapak dan Blok Ganal. Sampai kontrak proyek IDD berakhir pada tahun 2027-2028 nanti, kontraknya menggunakan skema bagi hasil atau cost recovery dalam bentuk production sharing contract (PSC).

Evaluasi skema kontrak itu dilakukan lantaran baru saja Chevron Asia Pacific mengajukan perpanjangan kontrak di Proyek IDD pada Blok Rapak dan Blok Ganal. Wakil Menteri ESDM, Arcandra Tahar menyebutkan, perpanjangan kontrak kedua blok migas tersebut sampai dengan saat ini masih dievaluasi oleh pemerintah. 

"Kan cost recovery mereka sampai tahun 2027-2028. Setelah itu sedang diproses," katanya.

Selama ini, pemerintah selalu mewajibkan perpanjangan kontrak baru blok migas harus menggunakan skema bagi hasil atau gross split. Namun berbeda dengan yang satu ini, pemerintah masih harus melakukan kajian dan mengevaluasi sebelum memutuskan perpanjangan kontrak Chevron di Blok Rapak dan Blok Ganal. 

"Tergantung dari pemerintah. Ini sedang dievaluasi," katanya.

Tahun lalu, Chevron secara resmi sudah merevisi biaya pengembangan atau Plan of Development (POD) I dengan nilai US$ 6 miliar. Manager Corporate Communication Chevron, Sonitha Poernomo membenarkan, bahwa Chevron sudah mengajukan POD Revisi I dan proposal perpanjangan Kontrak Kerja Sama (KKS) Rapak dan KKS Ganal.

Namun, Sonitha tidak bersedia menyebutkan secara detail skema kontrak yang akan digunakan oleh Chevron untuk perpanjangan Blok Ganal dan Blok Rapak. 

"Karena alasan komersial, kami tidak dapat menyampaikan detail isi proposal kepada publik," dia menambahkan.

Proyek IDD dikategorikan sebagai Proyek Strategis Nasional (PSN). Adapun proyek IDD tahap pertama di Lapangan Bangka telah berproduksi sejak Agustus 2016. Saat ini, lapangan gas tersebut  menghasilkan delapan kargo gas alam cair (LNG) yang dikapalkan dari Terminal LNG Bontang, Kalimantan Timur.

Chevron sebelumnya menargetkan gas bisa menyembur dari proyek IDD tahap kedua dengan pengembangan lapangan Gendalo dan Gehem pada periode 2023-2024. Mengacu data Satuan Kerja Khusus Hulu Minyak dan Gas Bumi (SKK Migas), produksi itu bisa mencapai hingga 1.120 mmscfd gas dan 40.000 barel per hari (bph) minyak. 

     Kepala SKK Migas, Dwi Soetjipto memperkirakan, biaya pengembangan proyek IDD mencapai sekitar US$ 5 miliar. Nilai itu masih di bawah dengan pengajuan Chevron sebelumnya.

Kontan, Page-14, Saturday, Jan 12, 2019

Six Oil and Gas Working Areas Become Gross Split

The Ministry of Energy and Mineral Resources (ESDM) noted that there will be six Oil and Gas Working Areas (WK) that will change their oil and gas profit sharing scheme. From the previous use of the cost recovery production sharing contract (PSC) scheme, the scheme will be changed to gross split PSC

Arcandra Tahar

Deputy Minister of Energy and Mineral Resources (ESDM), Arcandra Tahar said, the change in the contract scheme from the cost recovery to gross split will be carried out in February 2019.

"In two weeks two blocks will change to gross split, then there will be four more exploration and WK production, and six more until next month," he claimed in ESDM Ministry Office.

Arcandra reasoned, the KKKS chose contract amendments to be gross split because it was far more efficient.

"Efficient, not complicated, simple, there is also certainty," he added.

The WK Migas whose contract scheme will change is first, the Block Supports the contractor Conrad; second, the Muralim and Tanjung Enim Blocks with the Dart Energy contractor; third, North Arafura WK with Madura Oil contractor; fourth, the Bungamas Block with the Bunga Mas International contractor; fifth, Blok Sebatik with Energy Star contractors.

Of the several Work Areas mentioned, Arcandra stated that the Tanjung Enim Block would be the first conventional oil and gas block to be turned into a gross split this year. So far, Tanjung Enim Block is indeed a working area that has the production of cool bed methane (CBM) types. While Arcandra itself is targeting the signing of the Tanjung Enim Block contract to be carried out on the upcoming February 9, 2019.

IN INDONESIAN

Enam Wilayah Kerja Migas Menjadi Gross Split

Kementerian Energi dan Sumber Daya Mineral (ESDM) mencatat, akan ada enam Wilayah Kerja (WK) Migas yang bakal berubah skema bagi hasil migasnya. Dari sebelumnya memakai skema production sharing contract (PSC) cost recovery, skemanya akan diubah menjadi PSC gross split

Wakil Menteri Energi dan Sumber Daya Mineral (ESDM), Arcandra Tahar bilang, perubahan skema kontrak dari cost recovery menjadi gross split itu akan dilakukan pada Februari 2019. 

"Dua pekan lagi dua blok berubah ke gross split, lalu akan ada empat lagi WK eksplorasi dan ada produksi, dan enam lagi sampai bulan depan," klaimnya di Kantor Kementerian ESDM.

Arcandra beralasan, para KKKS memilih amandemen kontrak menjadi gross split lantaran jauh lebih efisien.

"Efisien, tidak berbelit-belit, simpel, juga ada kepastian," imbuhnya.

Adapun WK Migas yang skema kontraknya akan berganti adalah pertama, Blok Dukung dengan kontraktor Conrad; kedua, Blok Muralim dan Blok Tanjung Enim dengan kontraktor Dart Energy; ketiga, WK North Arafura dengan kontraktor Madura Oil; keempat, Blok Bungamas dengan kontraktor Bunga Mas International; kelima, Blok Sebatik dengan kontraktor Star Energy.

Dari beberapa Wilayah Kerja yang disebutkan itu, Arcandra menyatakan, Blok Tanjung Enim akan menjadi blok migas konvensional pertama yang berubah menjadi gross split di tahun ini. Selama ini, Blok Tanjung Enim memang merupakan wilayah kerja yang memiliki produksi jenis cool bed methane (CBM). Sementara Arcandra sendiri menargetkan penandatanganan kontrak Blok Tanjung Enim bisa dilakukan pada 9 Februari 2019 mendatang.

Kontan, Page-14, Saturday, Jan 12, 2019

Maintained Production

Production realization is ready to sell oil in 2018 lower than the target. Production was maintained, even though the field age in Indonesia was getting older.

The Rokan block in Riau

Maintaining domestic oil production is a government priority in the short term. The Rokan block in Riau and the Cepu Block in East Java are relied on to keep production levels from decreasing. Last year, the realization of production was ready to sell (lifting) oil as much as 778,000 barrels per day. 

the Cepu Block in East Java

   This realization is lower than the target of the state budget of 800,000 barrels per day. As for this year, production is ready to sell oil in the state budget targeted at 775,000 barrels per day. While gas production is ready to sell in the APBN 1,250 million barrels of oil equivalent per day.

Production is ready to sell Indonesian oil in the last few years, ranging from 700,000 barrels per day to 800,000 barrels per day. Approximately 75 percent of oil fields in Indonesia are around 25 years to 50 years old. As the field age ages, the field's productivity continues to decline.

"Naturally, if it continues to be drained, yes, it will run out. Our priority is how to maintain production. The Cepu block, for example, is planning to produce 165,000 barrels per day, but until now it has produced 220,000 barrels per day. That is what we will protect, "said Director General of Oil and Gas at the Ministry of Energy and Mineral Resources (ESDM) Djoko Siswanto.

In addition to the Cepu Block, oil production comes from the Rokan Block, which is currently managed by Chevron Pacific Indonesia. The block produces 200,000 barrels of oil per day. Starting in 2021, the Rokan Block is managed by PT Pertamina (Persero) as the Chevron contract period in the block ends.

"Pertamina will begin to engage in drilling in the block this year. Hopefully the production will be maintained with Pertamina's involvement later, "Djoko said.

Exploration

According to the lecturer at the Trisakti University Faculty of Earth and Energy Technology, Pri Agung Rakhmanto, in the long run, exploration to find new oil reserves must be increased. Moreover, oil and gas resources in Indonesia are still relatively large. It takes a lot of effort so that these resources are upgraded to proven reserves.

"Pertamina must be encouraged to intensify domestic exploration. Without the discovery of large-scale new reserves, Indonesia will continue to depend on imports. Remember, the oil and gas production we enjoy today comes from large fields that have been producing for a long time, such as the Rokan, Mahakam, Tangguh and Cepu blocks, "said Pri Agung.

Previously, the President of the Indonesian Petroleum Association (IPA) Tumbur Parlindungan said, to increase oil production in the country, the only way to increase exploration. Exploration can be intensified if the investment climate in Indonesia is attractive to investors. The ease of licensing and the fast execution process is needed by investors.

"Investors will always compare the condition of upstream oil and gas investments from a number of destination countries. Countries that are considered the most attractive for investment will be the main target, "said Tumbur.

Upstream oil and gas investment in 2018 rose to 12.5 billion US dollars, compared to the realization in 2017 of 11 billion US dollars. The oil and gas sector non-tax revenues also rose from Rp 88.6 trillion in 2017 to Rp 163.4 trillion in 2018. The increase in oil and gas investment has not been able to increase the production rate of ready-to-sell oil domestically.

In addition, the government budget for seismic surveys in an effort to find new sources of oil and gas reserves is very limited. In 2018, the government budgeted Rp. 96 billion for surveys in two locations. However, there is no budget allocation for the same activities this year.

The survey results are important to strengthen the data on recommendations for determining the oil and gas working areas to be auctioned. The potential for oil and gas in Indonesia is said to be still large.

IN INDONESIAN

Produksi Dipertahankan

Realisasi produksi siap jual minyak pada 2018 lebih rendah daripada target. Produksi dipertahankan, meskipun usia lapangan untuk di Indonesia semakin menua.

Mempertahankan produksi minyak dalam negeri menjadi prioritas pemerintah dalam jangka pendek. Blok Rokan di Riau dan Blok Cepu di Jawa Timur diandalkan untuk menjaga tingkat produksi agar tidak semakin menurun. Tahun lalu, realisasi produksi siap jual (lifting) minyak sebanyak 778.000 barel per hari. Realisasi ini lebih rendah daripada target APBN yang sebesar 800.000 barel per hari. Adapun tahun ini, produksi siap jual minyak dalam APBN ditargetkan 775.000 barel per hari. Sementara produksi gas siap jual dalam APBN 1,250 juta barel setara minyak per hari.

Produksi siap jual minyak Indonesia dalam beberapa tahun terakhir berkisar 700.000 barel per hari sampai dengan 800.000 barel per hari, Sekitar 75 persen dari lapangan minyak di Indonesia berumur sekitar 25 tahun hingga 50 tahun. Seiring usia lapangan yang menua, produktivitas lapangan tersebut juga terus merosot.

”Secara alamiah, kalau dikuras terus, ya, akan habis. Prioritas kami, bagaimana mempertahankan produksi. Blok Cepu, misalnya, perencanaan awal berproduksi 165.000 barel per hari, tetapi sampai sekarang menghasilkan 220.000 barel per hari. Itu yang akan kami jaga,” kata Direktur Jenderal Minyak dan Gas Bumi Kementerian Energi dan Sumber Daya Mineral (ESDM) Djoko Siswanto.

Selain Blok Cepu, produksi minyak berasal dari Blok Rokan, yang saat ini masih dikelola Chevron Pasific Indonesia. Blok itu menghasilkan minyak 200.000 barel per hari. Mulai 2021, Blok Rokan dikelola PT Pertamina (Persero) seiring masa kontrak Chevron di blok itu berakhir.

”Pertamina akan mulai terlibat pengeboran di blok tersebut pada tahun ini. Semoga produksi terus terjaga dengan keterlibatan Pertamina nanti,” ujar Djoko. 

Eksplorasi

Menurut pengajar pada Fakultas Teknologi Kebumian dan Energi Universitas Trisakti, Jakarta, Pri Agung Rakhmanto, dalam jangka panjang, eksplorasi untuk menemukan cadangan minyak baru harus ditingkatkan. Apalagi, sumber daya migas di Indonesia terbilang masih besar. Perlu usaha keras agar sumber daya tersebut dinaikkan statusnya menjadi cadangan terbukti.

”Pertamina harus didorong untuk menggiatkan eksplorasi di dalam negeri. Tanpa penemuan cadangan baru berskala besar, Indonesia akan terus bergantung pada impor. Ingat, produksi migas yang kita nikmati sekarang ini datang dari lapangan besar yang sudah lama berproduksi, seperti blok Rokan, Mahakam, Tangguh, dan Cepu,” kata Pri Agung.

Sebelumnya, Presiden Asosiasi Perminyakan Indonesia (IPA) Tumbur Parlindungan mengatakan, untuk menaikkan produksi minyak di dalam negeri, satu-satunya cara dengan meningkatkan eksplorasi. Eksplorasi bisa diintensifkan jika iklim investasi di Indonesia menarik di mata investor. Kemudahan perizinan dan proses eksekusi yang cepat sangat dibutuhkan investor.

”Investor akan selalu membandingkan kondisi investasi hulu migas dari sejumlah negara tujuan. Negara yang dianggap paling menarik untuk investasi akan menjadi target utama,” ujar Tumbur.

Investasi hulu minyak dan gas bumi pada 2018 naik menjadi 12,5 miliar dollar AS, dibandingkan dengan realisasi pada 2017 yang sebesar 11 miliar dollar AS. Penerimaan negara bukan pajak sektor migas juga naik dari Rp 88,6 triliun pada 2017 menjadi Rp 163,4 triliun pada 2018. Kenaikan investasi migas belum mampu meningkatkan angka produksi siap jual minyak di dalam negeri.

Selain itu, anggaran pemerintah untuk survei seismik dalam usaha menemukan sumber cadangan migas yang baru sangat terbatas. Pada 2018, pemerintah menganggarkan Rp 96 miliar untuk survei di dua lokasi. Akan tetapi, belum ada alokasi anggaran untuk kegiatan yang sama pada tahun ini.

Hasil survei tersebut penting untuk memperkuat data rekomendasi penetapan wilayah kerja migas yang hendak dilelang. Potensi migas di Indonesia disebut-sebut masih besar.

Kompas, Page-13, Saturday, Jan 12, 2019

5 Oil and Gas Blocks Approved Early This Year

The Ministry of Energy and Mineral Resources (ESDM) will open an oil and gas block auction Phase I / 2019 in five working areas. The five WKs are divided into two ex-production blocks and three exploration blocks. 

     ESDM Ministry Director General of Oil and Gas Djoko Siswanto said, for the first stage five oil and gas blocks were selected to be auctioned. This year, according to him, oil and gas blocks offered to investors reach 10 working areas.

"Gradually, for Phase I / 2019 there are 5 working areas," he said at the Press Conference on the Performance of the Directorate General of Oil and Gas at the Ministry of Energy and Mineral Resources 2018, Friday (11/1).

The ex-production oil and gas blocks are the West Kampar Block and the Long Strait Block. The Kampar Block has actually been auctioned by the Ministry of Energy and Mineral Resources on September 19-October 22 2018. However, investors have not been interested in the block that has an estimated reserve of 8.3 MMSTB (oil + condensate).

Oilex Ltd

Initially this block was managed by PT Sumatera Persada Energi (SPE). Then on December 28, 2008, Oilex Ltd purchased management rights of 45% of PSE. However, at the end of December 2016, PSE was in bankruptcy. The contract for the West Kampar Block was signed in October 2005 with a 30-year contract. 

     Termination of the SPE contract as manager of the Kampar Block is realized through a letter from the Minister of Energy and Mineral Resources with No. 29 74/2018 signed on 15 August 2018.

Similar to West Kampar, the Long Strait Block, which is located in Riau, will be terminated on September 5, 2021, attempting to be re-auctioned. Because, Petroselat Ltd. who is a subsidiary of PT Sugih Energy Tbk. as the operator has been declared bankrupt. On July 5, 2017, the government again auctioned the oil and gas block.

Meanwhile, the exploration work areas to be auctioned are the West Ganal Block, West Kaimana Block and Anambas Block. Actually, the West Ganal Block is included in the Makassar Strait area, but is separated. 

     Djoko said the Makassar Strait WK was a production block because of West Seno. With the issuance of West Ganal from Makassar Strait, purely a exploration WK.

"The production facility was issued, the West Seno Block was issued. So, [West Ganal] is exploration, "he said.

For the Makassar Strait Block, there are investors who are interested in managing this working area. In the conventional oil and gas working area Phase II / 2018, Eni Muara Bakau B.V has submitted a proposal. However, the ESDM Ministry rejected the proposal because the KKKS did not meet the requirements provided by the government.

Previously, on Wednesday (2/1), Djoko ensured that the three blocks to be auctioned again had passed the evaluation process, especially related to the Makassar Strait Block. 

    In addition, the Anambas Block has also been offered at Phase III / 2018 Auction, but no investors have been interested. Regarding the auction phase I / 2019 for oil and gas blocks, Djoko did not want to provide certainty. He said the auction will take place this month.

"Yes this month, I just had a meeting with the CoC. There was also a discussion with Pak Wamen, "he added.

Later the five oil and gas blocks auctioned will use gross split contract schemes. So far, there are 36 oil and gas blocks operating using this gross production sharing scheme.

IN INDONESIAN

5 Blok Migas DiIelang Awal Tahun Ini

Kementerian Energi dan Sumber Daya Mineral (ESDM) akan membuka lelang blok minyak dan gas Tahap I/2019 sebanyak lima wilayah kerja. Lima WK tersebut terbagi atas dua blok eks produksi dan tiga blok eksplorasi. 

     Dirjen Migas Kementerian ESDM Djoko Siswanto mengatakan, untuk tahap pertama dipilih lima blok migas untuk dilelang. Pada tahun ini, menurutnya, blok migas yang ditawarkan ke investor mencapai 10 wilayah kerja.

“Bertahap, untuk Tahap I/2019 ada 5 wilayah kerja,” katanya dalam Konferensi Pers Paparan Kinerja Ditjen Migas Kementerian ESDM 2018, Jumat (11/1).

Blok migas eks produksi adalah Blok West Kampar dan Blok Selat Panjang. Blok Kampar sebenarnya sudah pernah dilelang oleh Kementerian ESDM pada 19 September-22 Oktober 2018. Namun, investor belum tertarik pada blok yang memiliki estimasi cadangan sebesar 8,3 MMSTB (minyak + kondensat).

Awalnya blok ini dikelola oleh PT Sumatera Persada Energi (SPE). Kemudian pada 28 Desember 2008, Oilex Ltd membeli hak kelola sebesar 45% dari PSE. Namun, pada akhir Desember 2016, PSE berada dalam kondisi pailit. 

    Kontrak bagi hasil Blok West Kampar ditandatangani pada Oktober 2005 dengan kontrak selama 30 tahun. Pemutusan kontrak SPE sebagai pengelola Blok Kampar diwujudkan lewat surat Menteri ESDM dengan No 29 74/2018 yang ditandatangani pada 15 Agustus 2018.

Serupa dengan West Kampar, Blok Selat Panjang, yang berlokasi di Riau akan terminasi pada 5 September 2021 berupaya kembali dilelang. Pasalnya, Petroselat Ltd. yang merupakan anak usaha dari PT Sugih Energy Tbk. sebagai operator telah dinyatakan pailit. Pada 5 Juli 2017, pemerintah kembali melelang blok migas tersebut.

Sementara itu, untuk wilayah kerja eksplorasi yang akan dilelang adalah Blok West Ganal, Blok West Kaimana dan Blok Anambas. Sebenarnya, Blok West Ganal masuk dalam wilayah Makassar Strait, tetapi dipisahkan. 

     Djoko mengatakan WK Makassar Strait menjadi blok produksi karena adanya West Seno. Dengan dikeluarkannya West Ganal dari Makassar Strait, murni menjadi WK eksplorasi.

“Fasilitas produksinya dikeluarkan, Blok West Seno yang dikeluarkan. Makanya, [West Ganal] itu eksplorasi,” ujarnya.

Untuk Blok Makassar Strait, ada investor yang tertarik untuk mengelola wilayah kerja ini. Dalam wilayah kerja migas konvensional Tahap II/2018, Eni Muara Bakau B.V telah memasukkan proposal. Namun, Kementerian ESDM menolak proposal karena KKKS tersebut tidak memenuhi persyaratan yang diberikan pemerintah.

Sebelumnya, pada Rabu (2/1), Djoko memastikan tiga blok yang akan dilelang ulang sudah melewati proses evaluasi, khususnya terkait Blok Makassar Strait. Selain itu, untuk Blok Anambas, juga sudah pernah ditawarkan pada Lelang Tahap III/2018, tetapi belum ada investor yang tertarik. 

    Terkait dengan waktu lelang blok migas Tahap I/2019, Djoko belum mau memberikan kepastian. Dia mengatakan lelang akan berlangsung pada bulan ini.

“Ya bulan ini, tadi baru saja rapat TnCnya. Tadi sudah diskusi juga dengan Pak Wamen," tambahnya.

Nantinya kelima blok migas yang dilelang akan menggunakan skema kontrak gross split. Sejauh ini, sudah ada 36 blok migas yang beroperasi dengan menggunakan skema bagi hasil produksi kotor ini.

Bisnis Indonesia, Page-9, Saturday, Jan 12, 2019

National Oil and Gas Lifting Target Increases to 2.02 Million BOEPD

Lifting oil and gas (oil and gas) this year is targeted to increase to 2.02 million barrels of barrel oil equivalent per day (BOEPD), from the 2018 realization of 1.9 million BOEPD. The addition of production is one of the 13 oil and gas projects planned to start operating this year. 

     Head of the Special Task Force for Upstream Oil and Gas Business Activities (SKK Migas) Dwi Soecipto said, oil lifting in 2019 is targeted at 775 thousand barrels per day (BPD), where last year's realization was 778 thousand BPD. While the gas lifting target is set at 1.25 million BOEPD, up from last year's 1.13 million BOEPD.

"So that oil and gas lifting in 2019 is 2.02 million BOEPD, from the 2018 realization of 1.92 million BOEPD," he said at a hearing at the House of Representatives Commission VII (DPR).

2D & 3D Seismic

To achieve this target, his party has compiled a work program that will be carried out in the exploration block and in the exploitation block. According to him, the exploration block is planned to carry out 4,328 kilometers (km) of 2D seismic, 3D seismic area of ​​4,693 square kilometers (km2), and 57 wells of exploration well drilling.

While in the exploitation block, exploration activities will be carried out in the form of 3,814 km of 2D seismic, 3D seismic area of ​​1,747 km2, and drilling of wildcat wells or delineation of 40 wells.

"Then there will be workover of 969 wells, 29,256 well service activities, and drilling wells for the development of 345 wells," he explained.

In addition, SKK Migas also plans to have 13 oil and gas projects that will be operational this year. In the first quarter, there were two projects planned to start on stream, the Betara Complex Project with the production of 12 million cubic feet per day (million standard cubic feet per day / MMSCFD) by Petrochina International Jabung Ltd. and Terang Sirasun Batur Phase 2 of 200 MMSCFD by Kangean Energy Indonesia Ltd.

Furthermore, in the second quarter, the project which began operations was Ario Damar-Sriwijaya Phase 2 with production of 20 MMSCFD by PT Tropik Energi Pandan, Temalat gas flow to South Kembang Mountain 10 MMSCFD by PT Medco E & P Indonesia, and Bukit Tua Phase-3 31.5 mmscfd by Petronas Carigali Ketapang II Ltd.

Petronas Carigali Ketapang II Ltd.

In the third quarter, there were eight projects that would start flowing oil and gas. In particular, Kedung Keris Full Well Stream Project with production of 3,800 BPH by Exxon Mobil Cepu Ltd, Buntal-5 45 mmscfd by Medco E & P Natuna Ltd, Bison-Iguana-Gajah Putri 163 MMSCFD by Premiere Oil Natuna Sea BY and Suban Compression 780 MMSCFD by ConocoPhilips (Grissik) Ltd.

ConocoPhilips (Grissik) Ltd.

Next, the project operating in the last quarter of this year was the installation of 15 MMSCFD Betung Compressors by PT Pertamina EP Bayan Gas Production Facilities which produced 15 MMSCFD gas and 250 BPH oil by Manhattan Kalimantan Investment Pte Ltd, YY with production. oil 4,605 ​​BPH and 25.5 MMSCFD by PT Pertamina Hulu Energi Offshore North West Java (ONWJ), as well as Calling 20 MMSCFD by Santos (Madura Offshore) Pty Ltd.

PT Pertamina Hulu Energi Offshore North West Java (ONWJ)

"So the total production estimate is 240 thousand BOEPD, which is 1,300 MMSCFD gas and 8,600 BPH oil. "The estimated total investment value is US $ 702 million," Dwi said.

To achieve this year's lifting target, SKK Migas recorded five of the biggest oil producers, namely Exxon Mobil Cepu Limited 216 thousand BPH, PT Chevron Pacific Indonesia 190 thousand BPD, PT Pertamina EP 85 thousand BPD, PT Pertamina Hulu Mahakam 50 thousand BPH, and PT Pertamina Hulu Energi OSES 32 thousand BPH.

Furthermore, the five largest gas producers are PT Pertamina Hulu Mahakam 196 thousand BOEPD, BP Berau Ltd 188 thousand BOEPD, ConocoPhilips (Grissik) Ltd 145 thousand BOEPD, PT Pertamina EP 145 thousand BOEPD, and Eni Muara Bakau 115 thousand BOEPD.

Press Cost Recovery

"Meanwhile, Dwi added, this year's upstream oil and gas investment is targeted at the US $ 14.79 billion, up from last year's US $ 11.99 billion. Next, the target of state revenue from the upstream oil and gas sector is set at the US $ 17.51 ​​billion, not unlike the realization of 2018 of US $ 17.5 billion.

For cost recovery, this year it is targeted to reach the US $ 10.22 billion. This figure is lower than last year's realization of US $ 11.7 billion. According to Dwi, his party is indeed trying to control this cost recovery amount. According to Dwi, one of the ways to reduce cost recovery is the synergy between the contractors (KKKS).

Investor Daily, Page-9, Friday, Jan 11, 2019

13 Oil and Gas Projects Operate

This year, the Special Task Force for Upstream Oil and Gas (SKK Migas) projects that 13 oil and gas (oil and gas) projects will operate and produce (onstream).

Dwi Soetjipto

Head of SKK Migas, Dwi Soetjipto predicts that from the 13 projects there will be an additional peak production of 240,000 barrels of oil equivalent per day (boepd).

"The total investment value reaches US $ 702 million," he said when met at the House of Representatives (DPR) Building.

The 13 projects are the Betara Complex project, the Terang Sirasun Batur Phase 2 project, Ario Damar-Sriwijaya Phase 2, the Terminal gas drainage project to Gunung Kembang Selatan. Then the Bukit Tua Phase 3 project, Kedung Keris Full Well Steam, Buntal 5, Gajah Putri Bison-Iguana, Suban Compression. Next is the installation of the Betung Compressor, the Bayan Gas Production Facilities project, the YY project and the Mellwis project.

"While in 2018, there were six onstream projects with an estimated peak production of 34,000 boepd. The total investment value of the six projects reached US $ 345 million. But this is an estimate, we are still waiting for the audit results," Dwi said.

IN INDONESIAN

13 Proyek Migas Beroperasi

Tahun ini, Satuan Kerja Khusus Hulu Minyak dan Gas Bumi (SKK Migas) memproyeksikan sebanyak 13 proyek minyak dan gas bumi (migas) bakal beroperasi dan berproduksi (onstream).

Kepala SKK Migas, Dwi Soetjipto memprediksikan dari 13 proyek itu akan ada tambahan produksi puncak sebesar 240.000 barrel oil equivalen per day (boepd). 

"Total nilai investasinya mencapai US$ 702 juta," ungkap dia saat ditemui di Gedung Dewan Perwakilan Rakyat (DPR).

Adapun ke-13 proyek tersebut adalah proyek Kompleks Betara, proyek Terang Sirasun Batur Phase 2, Ario Damar-Sriwijaya Phase 2, proyek pengaliran gas Terminal ke Gunung Kembang Selatan. Kemudian proyek Bukit Tua Phase 3, Full Well Steam Kedung Keris, Buntal 5, Bison-Iguana-Gajah Putri, Suban Compression. Selanjutnya pemasangan Kompresor Betung, proyek Bayan Gas Production Facilities, proyek YY serta proyek Mellwis.

"Sementara pada tahun 2018, realisasinya ada enam proyek onstream dengan estimasi puncak produksi sebesar 34.000 boepd. Total nilai investasi enam proyek tersebut mencapai US$ 345 juta. Tapi ini estimasi, kami masih menunggu hasil audit," ungkap Dwi.

Kontan, Page-14, Friday, Jan 11, 2019