PLUS MINUS REVISION GROSS SPLIT

Revision of Ministerial Regulation No. 8 of 2017 on contracts for gross split share gets the spotlight from stakeholders in oil and gas sector [oil and gas]. There are some points that are considered positive, but there is also a note to be fixed.

Executive Director of Indonesian Petroleum Associatioan (IPA) Marjolijn Wajong said basically the oil and gas industry requires a business climate that has high legal certainty and competitive fiscal provisions. Especially in the current difficult situation that makes investors reduce their capital expenditure and selective in investing.

For that there are at least some points to be conveyed oil and gas industry actors who are incorporated in the IPA. First, each block and oil and gas field have different characteristics, risks and challenges in either the development or production phase.

On that basis, it is necessary to have fiscal provisions or the appropriate form of cooperation contract on each of these characteristics.

"It may require different forms of contracts, fiscal provisions and incentives to ensure economical and competitive development," he said.

Second, IPA sees positive changes to improve the competitiveness of oil and gas industry in the country. Revision of the gross split rule is also better than the previous regulation.

Positive changes include, among others, the increase in the number of split variables that will help the field economy. Then the addition of gas price components and the amount of profit-sharing calculations that can help the field economy, especially in the early days of production.

Another positive point is that it no longer limits the incentive to increase the profit sharing that can be given by the Minister if necessary on the development of certain fields. In addition, the provision of incentives in the development of further fields.

The third note of IPA for the gross split rule is in the new rule, the choice of contract form on the renewal block is retained. Thus, the block whose term of contract expires and is extended, the Government may determine the form of a conventional or gross split contract of employment.

"This is important considering the possibility of special issues in the extension that need to be discussed further between the Government and the Contractor," Marjolijn said.

Fourth, IPA has also provided inputs to the government on tax regulations and facilities for the Gross Split system. Although not detailed, clear to the IPA input that can improve the competitiveness of Indonesia's oil and gas industry at the level international.

Fifth, in the end, according to Marjolijn, investment decisions are in each investor. They will make strategic considerations according to their portfolio and investment opportunities.

IN INDONESIA

PLUS MINUS REVISI GROSS SPLIT

Revisi Peraturan Menteri Nomor 8 tahun 2017 tentang kontrak bagi hasil gross split mendapat sorotan dari pemilik kepentingan di sektor minyak dan gas bumi [migas]. Ada beberapa poin yang dianggap positif, tapi ada juga yang menjadi catatan untuk diperbaiki.

Direktur Eksekutif Indonesian Petroleum Associatioan (IPA) Marjolijn Wajong mengatakan pada dasarnya industri migas memerlukan iklim usaha yang memiliki kepastian hukum tinggi dan ketentuan fiskal yang kompetitif. Apalagi di situasi sulit seperti saat ini yang membuat investor mengurangi belanja modalnya dan selektif dalam berinvestasi.

Untuk itu setidaknya ada beberapa poin yang ingin disampaikan pelaku industri migas yang tergabung dalam IPA. Pertama, setiap blok dan lapangan migas memiliki karakteristik, risiko dan tantangan yang berbeda baik dalam fase pengembangan atau produksi.

Atas dasar itu, perlu ketentuan fiskal ataupun bentuk kontrak kerja sama yang sesuai atas masing-masing karakteristik tersebut. 

“Bisa jadi memerlukan bentuk kontrak, ketentuan fiskal dan insentif yang berbeda pula untuk memastikan pengembangan yang ekonomis dan kompetitif,” ujarnya.

Kedua, IPA melihat ada perubahan yang positif untuk meningkatkan daya saing industri migas di Tanah Air. Revisi aturan gross split ini juga lebih baik dibandingkan regulasi sebelumnya.

Perubahan positif itu antara lain, kenaikan besaran beberapa variable split yang akan membantu keekonomian lapangan. Kemudian penambahan komponen harga gas serta besaran perhitungan bagi hasil yang bisa membantu keekonomian lapangan terutama pada masa awal produksi.

Poin positif lainnya yakni tidak dibatasinya lagi insentif penambahan bagi hasil yang dapat diberikan oleh Menteri apabila diperlukan pada pengembangan lapangan-lapangan tertentu. Selain itu pemberian insentif pada pengembangan lapangan-lapangan lanjutan.

Catatan ketiga IPA untuk aturan gross split adalah dalam aturan baru, pilihan bentuk kontrak pada blok perpanjangan masih dipertahankan. Jadi, blok yang jangka waktu kontraknya berakhir dan diperpanjang, Pemerintah dapat menetapkan bentuk kontrak kerja Sama konvensional atau gross split.

“HaI ini penting mengingat kemungkinan terdapat hal-hal khusus dalam perpanjangan yang perlu dibicarakan lebih lanjut antara Pemerintah dan Kontraktor,” ujar Marjolijn.

Keempat, IPA juga telah memberi masukan kepada pemerintah tentang peraturan dan fasilitas perpajakan bagi sistem Gross Split. Meski tidak merinci, yang jelas bagi IPA masukan itu dapat meningkatkan daya saing industri migas Indonesia di tataran internasional.

Kelima, pada akhirnya, menurut Marjolijn, keputusan investasi ada pada masing-masing investor. Mereka akan membuat pertimbangan strategis sesuai portofolio dan kesempatan investasi yang dimiliki.

Global Energi, Page-59, Wednesday, Sept 20, 2017

Waiting for Certainty of Tuban Block

Although the management of Tuban Block Working Area (WK) by Joint Gperating Body of Pertamina Petrochina East Java (JOB PPEJE ended on February 28, 2018, until now there is no official standby explanation that will manage the block) Tuban Block Work Area (WK) to be submitted JOB PPEJ to the government, then on March 1, 2018 by the management government, will be handed over to Pertamina Hulu Energi (PHE).

"As far as I know, WK Block Tuban will be managed by Pertamina Hulu Energi (PHE). Whether Petrochina will join, I am not in the capacity to explain, "said Superintendent JOB PPEJ Akbar Pradima in a press release on Monday (21/08/2017).

On the other hand, General Manager of Pertamina EP Asset 4 Didik Susilo confirmed that Sukowati Field will be managed by Pertamina EP Asset 4. The reason is Sukowati field as part of Pertamina EP work area.

"There is a letter from Upstream Director of Pertamina that starting March 1, 2018 Sukowati field will be managed by Pertiamina EP Asset 4," said Didik.

WK Tuban Block which is divided into East Tuban Block covers Sidoarjo Regency, Mojokerto Regency, Gresik Regency and Lamongan Regency. The West Tuban Block covers the Regencies of Tuban and Bojonegoro Regencies. At the beginning of the contract signing on 29 February 1988, WK Block Tuban covering an area of ​​7,391 km2. After three regional allowances, the current working area is about 1,478 km2.

After obtaining a mandate to manage WK Block Tuban, the discovery of the first proved reserves in April 1994. The discovery of this first Reserve was named Field Mudi. The next discovery occurred in 2001 known as Sukowati field.

Prior to the global oil price crisis, the total contribution of JOB PPEJ was 25,083 BOPD of crude oil and 25.73 MMCPD of gas (July 2014). The highest production JOB-PPEJ occurs in 2012 which could reach 48,000 barrels per day.

Now, due to the absence of new well drilling, to counter natural decline, JOB-PPEJproduction in Mudi and Sukowati Fields is controlled through well-care and innovation activities. The total number of active wells managed by JOB PPEJ at this time is 35 wells, with details of Sukowati Field 26 wells and Mudi Field 9 wells.

Because of the natural process commonly referred to as the Normal Production Decline, water production is now much larger than the oil. At Mudi well, only 18,000 to 19,000 barrels of water per day (BWPD) are produced, while oil production is around 1,100 - 1,200 BOPD.

"So is Sukowati whose water production is 19.000 - 20.000 BWPD and oil 8,700 - 8,900 BOPD," explained Senior Field Operations Superintendent Joint Operation Body of Pertamina Petrochina East java (OB PPEJ), Fauzy Mayanullah.

Petrochina Still Interested

Fauzy also said that Petrochina through its subsidiary, Petrochina International East Java Limited, is interested to re-participate in oil drilling at the border of Bojonegoro and Tuban. Currently negotiations are being held in connection with Petrochina's re-involvement in oil drilling in the Tuban block. Negotiated matters related to new cooperation opportunities and oil revenue sharing.

"We are negotiating with Pertamina for a new partnership," Fauzy said during Media Gathering JOB PPEJ in Banyuwangi, Thursday (7/9/2017).

Although, Fauzy acknowledged, in accordance with the Regulation of the Minister of Energy and Mineral Resources in 2015, the management of the Tuban Block will be returned to Pertamina. However, Petrochina hopes to return to work with Pertamina or its subsidiaries.

"The possibility will be operated by a subsidiary of Pertamina. Due to direct entry to the upstream directorate there is Pertamina EP and Pertamina Hulu Energi, "he added.

Oil and gas production of Tuban Block is currently 4,000 barrels of oil equivalent per day (boepd). Potential reserves of 4 million barrels of oil equivalent (mmboe). Previously, the Government of East Java Province also admitted interested in managing the Tuban Block. In addition to efforts to approach the Ministry of Energy and Mineral Resources (ESDM), to manage the Upstream Oil and Gas business in Tuban Block managed by BUMD, East Java Provincial Government will also conduct economic studies.

Four district leaders, including Lamongan, Gresik, Tuban and Bojonegoro have also signed a Memorandum of Understanding (MOU) to manage the upstream oil and gas business in Tuban Block.

Furthermore, the Provincial Government of East Java together with four districts will soon develop an economic assessment of Tuban Block, which will be done by an independent consultant.

"The results of the economic assessment, will be the basis for the distribution of rights and obligations of each region or district, in the management of the Tuban Block later. For his study, it could involve SKK Migas and geologists from ITB, "said the Governor East Java Soekarwo, on Saturday (5/11/2016) ago.

Meanwhile, Head of East Java ESDM Service, Dewi Juniar Patriatni explained that East Java is the third largest oil and gas producer in Indonesia, after Riau and East Kalimantan.

"For the Tuban Block, it covers an area of ​​1,478 square kilometers, located in four districts. Namely, Lamongan, Tuban, Bojonegoro, and Gresik, "explained Dewi.

He also explained that in East Java there are 39 Cooperation Contract Contractors (KKKS) that conduct exploration, development, and production activities. Both onshore (on shore) and in the sea (off shore).

"Based on the Tuban Cooperation Oil and Gas Cooperation Contract, started on 29 February 1988 with Joint Operating Body Pertamina-Petrochina East Java (JOB-PPEJ) operator, and KKKS Contractor will expire on February 28, 2018," he explained.

Whereas, in the Regulation of the Minister of Energy and Mineral Resources Number 15 Year 2015 on the Management of the Oil and Gas Block Working Areas that will expire, the cooperation contract states that the management application to the minister is the fastest 10 years, and no later than two years before the contract expires!

IN INDONESIA

Menunggu Kepastian Blok Tuban

Meski pengelolaan Wilayah Kerja (WK) Blok Tuban oleh EJoint Gperating Body Pertamina Petrochina East Java (JOB PPEJ) berakhir pada 28 Februari 2018, hingga kini belum ada penjelasan resmi siaga yang akan mengelola blok itu. Wilayah Kerja (WK) Blok Tuban yang akan diserahkan JOB PPEJ pada pemerintah, selanjutnya pada 1 Maret 2018 oleh pemerintah pengelolaannya, akan dis-erahkan kepada Pertamina Hulu Energi (PHE).

“Setahu saya, WK Blok Tuban akan dikelola oleh Pertamina Hulu Energi (PHE). Apakah Petrochina akan gabung, saya tidak dalam kapasitas menjelaskan,” kata Admin Superintendent JOB PPEJ Akbar Pradima dalam siaran pers pada Senin (21/8/2017).

Di pihak lain, General Manager Pertamina EP Asset 4 Didik Susilo menegaskan, Lapangan Sukowati akan dikelola oleh Pertamina EP Asset 4. Alasannya, lapangan Sukowati sebagai bagian dari wilayah kerja Pertamina EP.

“Sudah ada surat dari Direktur Hulu Pertamina bahwa mulai 1 Maret 2018 lapangan Sukowati akan dikelola Pertamina EP Asset 4,” kata Didik.

WK Blok Tuban yang terbagi menjadi Blok Tuban Timur meliputi wilayah Kabupaten Sidoarjo, Kabupaten Mojokerto, Kabupaten Gresik dan Kabupaten Lamongan. Sementara Blok Tuban Barat meliputi Wilayah Kabupaten Tuban dan Kabupaten Bojonegoro. Pada awal penandatangan kontrak 29 Februari 1988, WK Blok Tuban seluas 7.391 km2. Setelah tiga kali penyisihan wilayah, saat ini luas wilayah kerja tinggal sekitar 1.478 km2.

Setelah mendapatkan mandat mengelola WK Blok Tuban, penemuan cadangan terbukti pertama pada April 1994. Penemuan Cadangan pertama ini diberi nama Lapangan Mudi. Penemuan selanjutnya terjadi pada 2001 yang dikenal dengan nama lapangan Sukowati.

Sebelum krisis harga minyak dunia, total kontribusi JOB PPEJ sekitar 25.083 BOPD minyak mentah (crude oil) dan 25,73 MMCPD gas (Juli 2014). Produksi tertinggi JOB PPEJ terjadi pada 2012 yang bisa mencapai 48.000 barel per hari.

Kini, akibat tiadanya pengeboran sumur baru, untuk melawan penurunan alamiah, produksi JOB di Lapangan Mudi dan Sukowati berupaya dikendalikan lewat kegiatan perawatan sumur dan inovasi. Total jumlah sumur yang aktif dikelola JOB PPEJ pada saat ini sebanyak 35 sumur, dengan rincian Lapangan Sukowati 26 sumur dan Lapangan Mudi 9 sumur.

Karena proses alamiah yang biasa disebut dengan istilah Normal Production Decline, kini produksi air jauh lebih besar daripada minyaknya. Di Sumur Mudi saja, air yang ikut diproduksi sebanyak 18.000 - 19.000 barel water per day (BWPD), sementara produksi minyak tinggal sekitar 1.100 - 1.200 BOPD.

“Begitu juga dengan Sukowati yang produksi airnya 19.000 - 20.000 BWPD dan minyak 8.700 - 8.900 BOPD,” jelas Senior Field Operations Superintendent joint Operation Body Pertamina Petrochina East java (]OB PPEJ), Fauzy Mayanullah.

Petrochina Tetap Berminat 

Fauzy juga mengatakan, Petrochina melalui anak perusahaannya, Petrochina Internasional East Java Limited, berminat untuk kembali ikut berpartisipasi dalam pengeboran minyak di perbatasan Bojonegoro dan Tuban ini. Saat ini sedang dilakukan perundingan terkait dengan keterlibatan kembali Petrochina dalam pengeboran minyak di blok Tuban. Hal-hal yang dirundingkan terkait peluang kerja sama baru dan pembagian hasil minyak.

“Kita sedang melakukan perundingan dengan Pertamina untuk kerjasama baru,” ujar Fauzy saat Media Gathering JOB PPEJ di Banyuwangi, Kamis (7/9/2017).

Meskipun, diakui Fauzy, sesuai dengan Peraturan Menteri ESDM tahun 2015, pengelolaan Blok Tuban akan dikembalikan ke Pertamina. Namun besar harapan Petrochina untuk kembali bekerja sama dengan Pertamina ataupun anak perusahaannya.

“Kemungkinan akan dioperasionalkan oleh anak perusahaan Pertamina. Karena langsung masuk ke direktorat hulu disana ada Pertamina EP dan Pertamina Hulu Energi,” tambahnya.

Produksi migas Blok Tuban saat ini 4.000 barel setara minyak per hari (boepd). Potensi cadangannya 4 juta barel setara minyak (mmboe). Sebelumnya, Pemerintah Provinsi Jawa Timur juga mengaku berminat mengelolal Blok Tuban. Selain upaya pendekatan kepada Kementerian Energi dan Sumber Daya Mineral (ESDM), agar pengelolaan Usaha Hulu Minyak dan Gas Bumi yang ada di Blok Tuban dikelola oleh BUMD, Pemerintah Provinsi Jawa Timur juga akan melakukan kajian ekonomi.

Empat pimpinan kabupaten yang meliputi Lamongan, Gresik, Tuban dan Bojonegoro juga sudah menandatangani Nota Kesepahaman (MoU) dalam rangka pengelolaan usaha hulu minyak dan gas bumi yang ada di Blok Tuban.

Selanjutnya, Pemerintah Provinsi Jatim bersama empat kabupaten bakal segera menyusun kajian ekonomi Blok Tuban, yang bakal dilakukan oleh konsultan independen.

“Hasil dari kajian keekonomian tersebut, akan menjadi dasar pembagian hak dan kewajiban masing-masing daerah atau kabupaten, dalam pengelolaan Blok Tuban nantinya. Untuk kajian-nya, bisa melibatkan SKK Migas dan ahli geologi dari ITB,” kata Gubernur Jawa Timur Soekarwo, Sabtu (5/11/2016) lalu.

Sementara Kepala Dinas ESDM Jawa Timur saat masih dijabat Dewi Juniar Patriatni menjelaskan, bahwa Jawa Timur merupakan penghasil minyak dan gas bumi terbesar ketiga di Indonesia, setelah Riau dan Kalimantan Timur.

“Untuk Blok Tuban, meliputi kawasan seluas 1.478 kilometer persegi, yang berada di empat kabupaten. Yakni, Lamongan, Tuban, Bojonegoro, dan Gresik,” jelas Dewi.

la juga menjelaskan, di Jawa Timur terdapat 39 Kontraktor Kontrak Kerja Sama (KKKS) yang melakukan kegiatan eksplorasi, pengembangan, maupun produksi. Baik yang berada di darat (on shore) maupun di laut (off shore).

“Berdasarkan Kontrak Kerja Sama (KKS) Migas Blok Tuban, dimulai pada 29 Februari 1988 dengan operator Joint Operating Body Pertamina-Petrochina East Java (JOB-PPEJ), dan Kontraktor Kontrak Kerjasa Sama (KKKS) ini akan berakhir pada 28 Februari 2018,” paparnya.

Sedangkan, pada Peraturan Menteri ESDM Nomor 15 Tahun 2015 tentang Pengelolaan Wilayah Kerja Blok Minyak dan Gas Bumi yang akan berakhir, kontrak kerjasamanya disebutkan bahwa permohonan pengelolaan kepada menteri paling cepat 10 tahun, dan paling lambat dua tahun sebelum kontrak berakhir!

Global Energi, Page-30-31, Wednesday, Sept 20, 2017

The Auction of Oil and Gas Blocks is Postponed Again

The revised Regulation of the Minister of Energy and Mineral Resources (ESDM) on gross split, apparently did not cause oil and gas investors to rush to auction 10 blocks of conventional oil and gas and 5 non-conventional oil and gas blocks that have been offered since last May 2017. The proof, the Ministry of ESDM again extended the return of documents auction.

It should be since the auction opened in May 2017, the participants have returned the auction documents on July 17, 2017 for conventional oil and gas blocks and July 12, 2017 for non-conventional oil and gas blocks. However due to the lack of participants, the return is postponed to August 9, 2017 for conventional and non-conventional blocks on August 7, 2017.

Well, this time the Ministry of ESDM re-set schedule deadline for bid document November 20-November 27, 2017. Quoting the website of Directorate General of Oil and Gas, Tuesday (19/9), after the issuance of Regulation of the Minister of Energy and Mineral Resources. 52/2017 on Amendment to Regulation of the Minister of Energy and Mineral Resources No. 08/2017 About Production Sharing Contract Gross Split August 29, 2017, the participants need time to learn some changes draft Contractor Cooperation Contract (KKKS) according to the minister's regulation.

"Candidate participants can submit participation documents before the deadline by submitting directly to the Directorate of Upstream Oil and Gas Business Development, Directorate General of Oil and Gas," wrote the official website of the Directorate General of Oil and Gas, Tuesday (18/9)

The adjustment of tax regulations related to gross split which is still an issue is also the reason for the Ministry of Energy and Mineral Resources to extend the period of bidding process of 10 conventional oil and gas blocks and 5 blocks of non-conventional oil and gas.

IN INDONESIA

Jadwal Lelang Blok Migas Diundur Lagi

Revisi Peraturan Menteri Energi dan Sumber Daya Mineral (ESDM) soal gross split, rupanya tidak menyebabkan para investor minyak dan gas buru-buru mengikuti lelang 10 blok migas konvensional dan 5 blok migas non-konvensional yang sudah ditawarkan sejak Mei 2017 lalu. Buktinya, Kementerian ESDM kembali memperpanjang waktu pengembalian dokumen lelang. 

Seharusnya sejak dibuka lelang pada Mei 2017 lalu, para peserta sudah mengembalikan dokumen lelang pada 17 Juli 2017 untuk blok migas konvensional dan 12 Juli 2017 untuk blok migas non-konvensional. Namun karena minimnya peserta, pengembalian diundur menjadi 9 Agustus 2017 untuk blok konvensional dan non-konvensional di 7 Agustus 2017.

Nah, kali ini Kementerian ESDM kembali memundurkan jadwal batas waktu akses bid document 20 November-27 November 2017. Mengutip situs Ditjen Migas, Selasa (19/9), setelah terbitnya Peraturan Menteri ESDM No. 52/2017 tentang Perubahan Peraturan Menteri ESDM No. 08/2017 Tentang Production Sharing Contract Gross Split 29 Agustus 2017, para peserta membutuhkan waktu mempelajari beberapa perubahan draf Kontraktor Kontrak Kerjasama (KKKS) sesuai peraturan menteri tersebut. 

"Calon peserta dapat memasukkan dokumen partisipasi sebelum batas akhir pemasukan dengan mengirimkan langsung ke Direktorat Pembinaan Usaha Hulu Migas, Ditjen Migas," tulis situs resmi Ditjen Migas, Selasa (18/9)

Penyesuaian peraturan perpajakan terkait gross split yang saat ini masih menjadi isu juga menjadi alasan Kementerian ESDM memperpanjang kembali jangka waktu proses penawaran 10 blok migas konvensional dan 5 blok migas non konvensional.

Kontan, Page-18, Wednesday, Sept 20, 2017

Space Cost Recovery Next Year Stronger

Space refunds operating costs of upstream oil and gas activities or cost recovery are narrower in the Draft Budget of 2018. In a meeting with the House Budget Board on Monday (18/9), it was agreed that the cost recovery ceiling of US $ 10 billion or less than the estimated realization this year US $ 10.7 billion.

Director General of Oil and Gas Ego Syahrial said the House Budget Agency wants the upstream business activities to be more efficient. In addition, the assumption of policy changes from cost recovery to gross split so that the government no longer expenses to the contractor contractors (KKKS) is also expected to reduce cost recovery.

According to him, in the House Budget Board meeting has explained that the impact of reduction of ceiling of cost recovery from the application of gross split can not be felt next year. The reason, only one working area that uses a new contract type of gross split Offshore Block Nort West Java (ONWJ).

"They also hope that with the change of cost recovery policy to gross split we have already said that only ONWJ is using gross split," he said after attending a meeting at the Parliamentary Budget Board (DPR), Monday (18/9) night.

With the shrinking cost recovery space in the RAPBN 2018, efficiency must be done in order to remain able to achieve the target production of ready-to-sell or lifting oil and gas.

"It was recorded in the House Budget Agency, SKK Migas to perform efficiency measures because it has been reduced to US $ 10 billion," he said.

He assesses that the target decisions made during the meeting can still change if macro assumptions such as lifting and oil prices change. According to him, the assumption of cost recovery of US $ 10 billion refers to the target of oil and gas lifting in 2017. This year, Indonesian Crude Price (ICP) assumption is US $ 48 per barrel, oil lifting target is 815,000 bpd and gas 1.15 million boepd gas the government set a ceiling of cost recovery of US $ 10.4 billion

In 2018, with an oil lifting target of 800,000 bpd, gas lifting 1.2 million boepd of Indonesian crude oil or ICP price of US $ 48 per barrel and cost recovery of US $ 10 billion.

"The development of oil prices will determine how we step," he said.

Meanwhile, Deputy Chief of SKK Migas Sukandar said there are currently 86 production work areas with one of them using gross split contracts so that the impact on cost recovery reduction has not been seen next year.

Based on data from the Special Unit for Upstream Oil and Gas Business Activities (SKK Migas) in August 2017, the cost recovery is realized US $ 7.22 billion from the target of US $ 10.4 billion with the government part of US $ 8.14 billion and contractor portion of US $ 2.87 billion.

BEYOND THE TARGET

He estimates that the realization of Coast recovery will exceed the target of US $ 10.7 billion. Previously, it was mentioned that the potential for additional cost recovery occurs at the end of the year as capital expenditure usually increases towards the end of the year.

This year, the largest increase of cost recovery by the end of the year comes from the Mahakam Block (Total E & P lndonesie) in East Kalimantan which ends its contract in 2017 of approximately US $ 900 million and Muara Bakau Block (Eni Muara Bakau BV) in East Kalimantan waters because the field is already producing .

"In 2017 we have a budget of US $ 10.5 billion will be US $ 10.7 billion [projection realization]," he said.

Initially, the costs returned by the government for upstream oil and gas business activities in 2018 amounted to US $ 11.39 billion. This figure is an assumption of efficiency from the initial figure of US $ 13.29 billion. The reason is, the burden of depreciation cost is increased with the onstream of Jangkrik field, Muara Bakau Block and Block A in Aceh.

The reduction of cost recovery is difficult to realize because no amount of ceiling is set for realization is always missed because of the many old wells that cost more to produce oil and gas. Currently, drilling activities in the field are easier to produce water than to produce oil and thus cost more to achieve production targets.

IN INDONESIA

Ruang Cost Recovery Tahun Depan Kian Sempit

Ruang pengembalian biaya operasi kegiatan usaha Hulu minyak dan gas Bumi atau cost recovery semakin sempit dalam RAPBN 2018. Dalam rapat dengan Badan Anggaran DPR, Senin (18/9), disepakati bahwa pagu cost recovery sebesar US$ 10 miliar atau lebih kecil dari perkiraan realisasi tahun ini US$ 10,7 miliar.

Direktur Jenderal Minyak dan Gas Bumi Ego Syahrial mengatakan Badan Anggaran DPR menginginkan agar kegiatan usaha hulu semakin efisien. Selain itu, asumsi perubahan kebijakan dari cost recovery ke gross split sehingga pemerintah tidak lagi mengeluarkan biaya pengembalian kepada kontraktor kontrak kerja sama (KKKS) juga diharapkan mengurangi cost recovery.

Menurutnya, dalam rapat Badan Anggaran DPR telah dijelaskan bahwa dampak pengurangan pagu cost recovery dari penerapan gross split belum bisa dirasakan tahun depan. Alasannya, hanya satu wilayah kerja yang menggunakan kontrak baru jenis gross split yakni Blok Offshore Nort West Java (ONWJ).

“Mereka juga berharap bahwa dengan perubahan kebijakan cost recovery ke gross split padahal kita sudah sampaikan bahwa hanya ONWJ yang menggunakan gross split,” ujarnya seusai menghadiri rapat di Badan Anggaran Dewan Perwakialn Rakyat (DPR) , Senin (18/9) malam.

Dengan mengecilnya ruang cost recovery dalam RAPBN 2018, efisiensi harus dilakukan agar tetap bisa mencapai target produksi siap jual atau lifting minyak dan gas bumi.

“Tadi catatannya di Badan Anggaran DPR, SKK Migas agar melakukan langkah-langkah efisiensi karena sudah ditekan jadi US$10 miliar," katanya.

Dia menilai ketetapan target yang dibuat selama rapat itu masih bisa berubah bila asumsi makro seperti lifting dan harga minyak berubah. Menurutnya, asumsi cost recovery sebesar US$ 10 miliar mengacu kepada target lifting migas pada 2017. Pada tahun ini, asumsi Indonesian Crude Price (ICP) US$ 48 per barel, target lifting minyak 815.000 bph, dan gas 1,15 juta boepd gas sehingga pemerintah menetapkan pagu cost recovery sebesar US$ 10,4 miliar

Pada 2018, dengan target lifting minyak 800.000 bph, lifting gas 1,2 juta boepd harga minyak mentah Indonesia atau ICP sebesar US$ 48 per barel dan cost recovery US$ 10 miliar.

“Perkembangan harga minyak akan menentukan langkah kita bagaimana," tegasnya.

Sementara itu, Wakil Kepala SKK Migas Sukandar mengatakan saat ini terdapat 86 wilayah kerja produksi dengan satu di antaranya yang menggunakan kontrak gross split sehingga dampaknya terhadap pengurangan cost recovery belum terlihat pada tahun depan. 

Berdasarkan data Satuan Kerja Khusus Pelaksana Kegiatan Usaha Hulu Minyak dan Gas Bumi (SKK Migas) pada Agustus 2017, cost recovery yang terealisasi US$ 7,22 miliar dari target US$ 10,4 miliar dengan bagian pemerintah sebesar US$ 8,14 miliar dan bagian kontraktor sebesar US$2,87 miliar.

MELAMPAUl TARGET

Dia memperkirakan realisasi Cost recovery akan melampaui target yakni menjadi US$ 10,7 miliar. Sebelumnya, disebutkan potensi penambahan cost recovery terjadi pada akhir tahun karena biasanya belanja modal bertambah menjelang pengujung tahun.

Pada tahun ini, penambahan terbesar cost recovery pada akhir tahun berasal dari Blok Mahakam (Total E&P lndonesie) di Kalimantan Timur yang berakhir kontraknya 2017 sekitar US$ 900 juta dan Blok Muara Bakau (Eni Muara Bakau BV) di perairan Kalimantan Timur karena lapangannya sudah berproduksi.

“Pada 2017 kita punya anggaran US$ 10,5 miliar akan menjadi US$ 10,7 miliar [proyeksi realisasinya],” katanya.

Awalnya, biaya yang dikembalikan pemerintah untuk kegiatan usaha hulu minyak dan gas bumi pada 2018 sebesar US$ 11,39 miliar. Angka ini merupakan asumsi efisiensi dari angka awalnya sebesar US$ 13,29 miliar. Alasannya, beban biaya depresiasi yang bertambah dengan onstream-nya lapangan Jangkrik, Blok Muara Bakau dan Blok A di Aceh.

Pengurangan cost recovery sulit direalisasikan karena berapa pun pagu yang ditetapkan realisasinya selalu meleset karena banyaknya sumur tua yang membutuhkan biaya lebih banyak agar bisa menghasilkan migas. Saat ini, kegiatan pengeboran di lapangan lebih mudah menghasilkan air daripada menghasilkan minyak sehingga membutuhkan biaya lebih agar target produksi bisa tercapai.

Bisnis Indonesia, Page-28, Wednesday, Sept 20, 2017

Government Confident, Gas Production Can Beyond Target

The Ministry of Energy and Mineral Resources (ESDM) noted that up to September 14, the national average annual gas production was 7,606 million standard cubic feet per day (mmscfd). This figure reached 96.61% of target work plan and budget in 2017.

"We are optimistic that we will be able to exceed the target of work plan and budget in 2017," said the Director General of Oil and Gas at the Ministry ESDM, Ego Syahrial last weekend.

His argument, a number of gas fields in Indonesia showed increased production. Proven gas production in Indonesia could increase in July 2017 ago. Data from the Directorate General of Oil and Gas show that the average gas production in July 2017 was 7,781 mmscfd. ESDM parties synchronize with the Special Unit for Upstream Oil and Gas Business Activities (SKK Migas)

"According to the data we have synchronized, there is an increase of 212 mmscfd compared to the previous month which amounted to 7,569 mmscfd," said Ego.

The increase from the average production of Pertamina EP which rose by 30.46 mmscfd compared to the previous 1024.26 mmscfd to 1.05452 mmscfd.

"There is an increase in production performance from the Matindok and Subang blocks," explains Ego.

The average gas production of ENI Muara Bakau also jumped from 192.39 mmscfd to 450.9 mmscfd or up 258.51 mmscfd. The gas increase was from ConocoPhillips Grissik Ltd at 153.49 mmscfd. This is due to optimal consumer absorption.

IN INDONESIA

Pemerintah Yakin, Produksi Gas Bisa Melampaui Target

Kementerian Energi dan Sumber Daya Mineral (ESDM) mencatat, hingga 14 September kemarin, rata-rata produksi tahunan gas nasional sebesar 7.606 juta standar kaki kubik per hari (mmscfd). Angka ini mencapai 96,61% target work plan and budget tahun 2017. 

"Kami optimistis akan bisa melampaui target work plan and budget tahun 2017," ujar Dirjen Minyak dan Gas (Migas) Kementerian

ESDM, Ego Syahrial akhir pekan lalu.

Argumen dia, sejumlah lapangan gas di Indonesia menunjukkan kenaikan produksi. Terbukti produksi gas bumi Indonesia bisa mengalami peningkatan pada bulan Juli 2017 lalu. Data Ditjen Migas menunjukkan produksi rata-rata gas bumi bulan Juli 2017 sebesar 7.781 mmscfd. Pihak ESDM mensinkronisasikan dengan Satuan Kerja Khusus Pelaksana Kegiatan Usaha Hulu Minyak dan Gas Bumi (SKK Migas) 

"Sesuai data yang telah kami sinkronisasikan, terdapat kenaikan 212 mmscfd dibandingkan bulan sebelumnya yang sebesar 7.569 mmscfd," ungkap Ego. 

Kenaikan tersebut dari produksi rata-rata Pertamina EP yang naik sebesar 30,46 mmscfd dibandingkan sebelumnya 1.024,26 mmscfd menjadi 1.05452 mmscfd. 

"Ada peningkatan performa produksi dari blok Matindok dan Subang," jelas Ego. 

Produksi rata-rata gas ENI Muara Bakau juga melonjak dari 192,39 mmscfd menjadi 450,9 mmscfd atau naik 258,51 mmscfd. Kenaikan gas Iain berasal dari ConocoPhillips Grissik Ltd sebesar 153,49 mmscfd. Ini disebabkan penyerapan konsumen yang optimal.

Kontan, Page-18, Tuesday, Sept 19, 2017

Optimum Consumer Absorption, Gas Lifting Continues to Increase

Indonesia's natural gas production increased at the beginning of second semester of this year. Average gas production in July reached 7,781 million standard cubic feet per day (mmscfd). This number increased slightly compared to June last year, which was 7,569 mmscfd.

The main factor of increasing gas production is the increase of Pertamina EP's average production of 30,46 mmscfd from 1,024,26 mmscfd to 1,054,82 mmscfd. The increase in production comes from the Matindok and Subang Blocks. 

    Another factor is the increase production from ENI Muara Bakau field. That is, from 192.39 mmscfd to 450.90 mmscfd. In addition to Pertamina and ENI, ConocoPhillips Grissik Ltd recorded a production increase of 153.49 mmscfd due to optimum absorption by consumers.

Director General of Oil and Gas at the Ministry of Energy and Mineral Resources (ESDM) Ego Syahrial Ego said that ten contractors of cooperation contracts (KKKS) accounted for 80.38 percent of national gas production last July. Namely, Total E & P Indonesie, BP Bureau, Pertamina EP ConocoPhillips Grissik, ENI Muara Bakau, JOB Pertamina-Medco Tomori Sulawesi, PetroChina International (Jabung), Premier Oil Natuna Sea, Medco E & P Natuna, and Kangean Energy Ind.

As of September 14, the national average annual gas production was recorded at 7,606 mmscfd. The figure is 96.61 percent of this year's KKKS work plan and budget (WP & B) target. Therefore, Ego believes that the gas production target set in WP & B can be exceeded.

Previously, the House Budget Board determined the production of oil ready for sale (lifting) and gas 2 million barrels of oil equivalent per day (boepd). Breakdown, oil 800 thousand barrels per day and natural gas 1.2 million barrels of oil equivalent per day. However, SKK estimates that oil and gas production in 272 oil and gas working areas continues to decline due to termination.

Currently, oil and gas lifting relies on 86 working areas of exploitation. Among the 86 working areas, there are 71 production areas and 15 development areas. Meanwhile, by the end of August, oil lifting reached 792 thousand barrels per day and natural gas lifting 1.134 million barrels of oil equivalent per day.

IN INDONESIA

Serapan Konsumen Optimal, Lifting Gas Terus Meningkat

Produksi gas bumi Indonesia tercatat meningkat pada awal semester II tahun ini. Produksi rata-rata gas pada Juli mencapai 7.781 juta standar kaki kubik per hari (mmscfd). Jumlah tersebut meningkat sedikit jika dibandingkan dengan Juni lalu, yaitu 7.569 mmscfd.

Faktor utama kenaikan produksi gas adalah peningkatan produksi rata-rata Pertamina EP 30,46 mmscfd dari 1.024,26 mmscfd menjadi 1.054,82 mmscfd. Peningkatan produksi itu berasal dari Blok Matindok dan Subang.

     Faktor lainnya adalah kenaikan produksi dari lapangan ENI Muara Bakau. Yakni, dari 192,39 mmscfd menjadi 450,90 mmscfd. Selain Pertamina dan ENI, ConocoPhillips Grissik Ltd mencatatkan kenaikan produksi 153,49 mmscfd karena penyerapan optimum oleh konsumen. 

Direktur Jenderal Minyak dan Gas Bumi Kementerian Energi dan Sumber Daya Mineral (ESDM) Ego Syahrial Ego menuturkan, sepuluh kontraktor kontrak kerja sama (KKKS) menyumbang 80,38 persen dari produksi gas nasional Juli lalu. Yakni, Total E&P Indonesie, BP Bureau, Pertamina EP ConocoPhillips Grissik, ENI Muara Bakau, JOB Pertamina-Medco Tomori Sulawesi, PetroChina International (Jabung), Premier Oil Natuna Sea, Medco E&P Natuna, dan Kangean Energy Ind.

Hingga 14 September lalu, rata-rata produksi tahunan gas nasional tercatat 7 .606 mmscfd. Angka tersebut berkisar 96,61 persen dari target rencana kerja dan anggaran (WP&B) KKKS tahun ini. Karena itu, Ego meyakini bahwa target produksi gas yang ditetapkan dalam WP&B bisa terlampaui.

Sebelumnya, Badan Anggaran DPR menetapkan produksi minyak siap jual (lifting) dan gas 2 juta barel setara minyak per hari (boepd). Perinciannya, minyak bumi 800 ribu barel per hari dan gas bumi 1,2 juta barel setara minyak per hari. Meski demikian, SKK migas memprediksi bahwa produksi di 272 wilayah kerja migas terus menurun karena terminasi.

Saat ini, lifting migas mengandalkan 86 Wilayah kerja eksploitasi. Di antara 86 wilayah kerja tersebut, terdapat 71 wilayah produksi dan 15 Wilayah pengembangan. Sementara itu, hingga akhir Agustus, lifting minyak bumi mencapai 792 ribu barel per hari dan lifting gas bumi 1,134 juta barel setara minyak per hari.

Jawa Pos, Page-5, Tuesday, Sept 19, 2017

Pertamina Discusses Tuban Refinery with Rosneft

In the last week, surprisingly China's oil and gas company, CEFC China Energy Co. bought 14.16% of Russia's largest oil company, Rosfnet. The value of the share purchase reached US $ 9 billion. Purchase of shares is allegedly increasingly cementing the hubugan China and Russia. 

     But what is the fate of the Tuban refinery project which is a joint venture between PT Pertamina and Rosneft? Adiatma Sardjito, Corporate Communications VP of Pertamina does not want much comment on the continuation of the Tuban Refinery project plan after the acquisition of Rosneft shares by China Energy.

He did not explain the impact of Rosneft's share ownership on the construction of the Tuban refinery. Adiatma just made sure that the discussion on the construction of the Tuban refinery continues.

"Still in the discussion, later if there is updatenya akan dikabari," said Adiatma

So far, Pertamina has failed to complete the completion of the feasibility study phase. To enter the next stage of engineering packet, Rosneft and Pertamina must form a Joint Venture Company first. Pertamina is in the process of forming JV Co with Pertamina's share of 55% and Rosneft at 45%.

It is targeted this year that JV Co can be established so that the construction of Tuban refinery can enter the engineering packet stage up to PID and EPC. In parallel, Pertamina is also discussing the land issue with the Ministry of Environment and Forestry (KLHK) for land acquisition in Tuban. Pertamina itself has signed a Memorandum of understanding (Mou) of 60 hectares of land owned by KLHK in Tuban in January.

On the other hand, Pertamina has also agreed with Rosneft teekait issue offtaker Tuban refinery. Rosneft is finally willing to be off taker of Tuban refineries. If everything goes smoothly, Pertamina also believes the construction of Tuban refinery can

finished in 2024.

IN INDONESIA

Pertamina Bahas Kilang Tuban dengan Rosneft

Pada pekan lalu, secara mengejutkan perusahaan migas asal China, CEFC China Energy Co. membeli 14,16% saham perusahaan minyak terbesar Rusia, Rosfnet. Nilai dari pembelian saham tersebut mencapai US$ 9 miliar. Pembelian saham tersebut disinyalir semakin mengokohkan hubugan China dan Rusia. Namun bagaimana nasib proyek Kilang Tuban yang merupakan kerjasama antara PT Pertamina dan Rosneft? Adiatma Sardjito, VP Corporate Communication Pertamina belum mau banyak komentar mengenai kelanjutan rencana proyek Kilang Tuban pasca akusisi saham Rosneft oleh China Energy. 

Dia tidak menjelaskan dampak perubahan kepemilikan saham Rosneft terhadap pembangunan Kilang Tuban. Adiatma hanya memastikan hahwa pembahasan mengenai pembangunan kilang Tuban terus berlanjut. 

"Masih dalam pembahasan, nanti kalau sudah ada updatenya akan dikabari," ujar Adiatma 

Sejauh ini Pertamina mencacat pembangunan Kilang Tuban sudah mencapai penyelesaian tahap feasibility study. Untuk masuk ke tahap selanjutnya yaitu engineering packet, Rosneft dan Pertamina harus membentuk Joint Venture Company terlebih dahulu. Pertamina pun sedang dalam proses pembentukan JV Co dengan share Pertamina sebesar 55% dan Rosneft sebesar 45%. 

Ditargetkan tahun ini JV Co sudah bisa terbentuk sehingga pembangunan Kilang Tuban bisa masuk tahapan engineering packet hingga PID dan EPC. Secara pararel, Pertamina juga sedang membahas masalah lahan dengan Kementerian Lingkungan Hidup dan Kehutanan (KLHK) untuk pembehasan lahan di Tuban. Pertamina sendiri telah melakukan penandatanganan Memorandum of understanding (Mou) penggunaan lahan milik KLHK sebesar 60 hektar di wilayah Tuban pada Januari lalu.

Di sisi lain, Pertamina juga telah bersepakat dengan Rosneft teekait masalah offtaker kilang Tuban. Rosneft akhirnya bersedia menjadi off taker kilang Tuban. Jika semuanya berjalan mulus, Pertamina pun yakin pembangunan Kilang Tuban bisa

selesai pada 2024.

Harian Bangsa, Page-9, Monday, Sept 18, 2017

Exxonmobil Confident, Production Target in Cepu Achieved

ExxonMobil Cepu Limited is optimistic that Banyu Urip Blok Cepu field oil production target in Bojonegoro, East Java will continue to grow until the end of 2017. Currently Banyu Urip Blok Cepu oil production in Gayam District, averages 200,000 barrels per day. Initially the production of this block is only an average of 185,000 barrels per day.

"We are optimistic that the government's production target will rise to an average of 201,600 barrels per day in 2017," said Vice President of Public and Government EXXonMobil Indonesia, Erwin Maryoto, Friday (15/9).

The optimism is that since June 2017, the Cepu Block field production has always been above 200,000 barrels per day. The effort to increase the oil production of Cepu Block field, without having to add equipment.

"The amount of flare gas flares remain the same as before," Erwin said.

Efforts to boost production from Banyu Urip Field is possible because the oil reserves there reach 729 million barrels. Erwin says even though the world oil price is still low, it does not cause EXXonMobil Cepu Limited to withhold or reduce production.

"Its production accounts for 20% of national oil production," he said on Friday (15/9)

US Ambassador Joseph R. Donovan Jr., reviewed the Banyuurip Blok Cepu field in Gayam District. Donovan also visited a learning center built on the initiative of ExxonMobil Cepu Limited.

IN INDONESIA

Exxonmobil Yakin, Target Produksi di Cepu Tercapai

ExxonMobil Cepu Limited optimistis, target produksi minyak lapangan Banyu Urip Blok Cepu di Kabupaten Bojonegoro, Jawa Timur, akan terus bertambah hingga akhir 2017 nanti. Saat ini produksi minyak Banyu Urip Blok Cepu di Keeamatan Gayam, rata-rata 200.000 barel per hari. Awalnya produksi blok ini hanya rata-rata 185.000 barel per hari. 

"Kami optimistis, target produksi yang ditetapkan pemerintah naik menjadi rata-rata 201.600 barel per hari bisa tercapai pada tahun 2017 ," kata Vice President Public and Government EXXonMobil Indonesia Erwin Maryoto, Jumat (15/9).

Optimisme itu karena sejak Juni 2017, produksi lapangan Blok Cepu selalu di atas 200.000 barel per hari. Usaha meningkatkan produksi minyak lapangan Blok Cepu itu, tanpa harus menambah peralatan. 

"Besarnya pembakaran gas flare tetap sama dengan sebelumnya," ucap Erwin.

Upaya menggenjot produksi dari Lapangan Banyu Urip dimungkinkan karena cadangan minyak di sana mencapai 729 juta barel. Erwin bilang meskipun harga minyak dunia masih rendah, tidak menyebabkan EXXonMobil Cepu Limited menahan atau mengurangi produksi. 

“Produksinya menyumbang 20% produksi minyak nasional," ujarnya pada Jumat (15/9) 

Duta Besar Amerika Serikat Joseph R. Donovan Jr, meninjau lapangan Banyuurip Blok Cepu di Kecamatan Gayam. Donovan juga mengunjungi pusat kegiatan belajar yang dibangun atas prakarsa ExxonMobil Cepu Limited.

Kontan, Page-18, Monday, Sept 18, 2017

Gas Infrastructure Needs Improvement

The government can hold SOEs to build infrastructure.

Oil and gas observer Reforminer, Pri Agung Rakhmanto, assesses the domestic gas infrastructure is still very minimal. It also became the reason the Government of Indonesia to open cooperation with Singapore in gas governance. 

     He states, three major gas infrastructure, ranging from regasification, storage, to pipelines, only exist in the eastern region of Indonesia. This is considered to be an evaluation point so that in the future the government should be able to increase the capacity of gas infrastructure.

He said the government could make additional gas infrastructure in the country by holding BUMN and domestic energy companies. He sees this as more important than having to cooperate with Singapore who is just a dealer.

"If there is no guarantee that Singapore can give cheaper price, why should Singapore work together? If it is reason to suppress the price, then the government should also fix the gas infrastructure that has made gas price received by gas consumers cheaper," Pri Agung

Pri Agung said Singapore does not have gas production. They only have adequate facilities so they can supply gas needs in western Indonesia. In fact, liquefied natural gas or LNG used by Singapore may also come from Indonesia.

"The price of landed price is still 6 to 7 US dollars per mmbtu, not the regasification cost, so why should not we build the infrastructure, this will give greater economic effect," said Pri Agung.

Previously, Coordinating Minister for Maritime Affairs Luhut Binsar Pandjaitan had proposed to open cooperation with Singapore for the development of gas infrastructure and gas distribution is cheaper. This policy is taken Luhut because gas prices in Sumatra and Kalimantan are still expensive compared to the Eastern Region of Indonesia.

Luhut explained, the LNG distribution options of two Singapore companies, namely Keppel Offshore and Marine and Pavilion Energy Ltd, due to its location closer to the regasification terminal. As a result, distributed LNG prices are predicted to be cheaper.

So far, LNG owned by Indonesia mostly comes from the eastern region. If it is distributed to the regasification site, the price may soar.

"If we want to openly also most of our gas comes from East Indonesia, so it is expensive to be withdrawn to Nias island," Luhut said last week.

In fact, at the same time, Indonesia would instead export liquefied natural gas (LNG) to Bangladesh to address the country's gas supply deficit. The Government of the Republic of Indonesia and the People's Republic of Bangladesh have signed a memorandum of understanding to strengthen energy sector cooperation.

One such form of cooperation is the possibility of exporting LNG from Indonesia to Bangladesh. Head of Bureau of Communications, Public Information Service and Cooperation of the Ministry of Energy and Mineral Resources, Dadan Kusdiana, said there is still a lot of LNG cargo that has not been purchased and in the future the tendency is increasing.

IN INDONESIA

lnfrastruktur Gas Butuh Peningkatan

Pemerintah bisa menggandeng BUMN untuk membangun infrastruktur. 

Pengamat migas Reforminer, Pri Agung Rakhmanto, menilai infrastruktur gas dalam negeri masih sangat minim. Hal itu pun turut menjadi alasan Pemerintah RI membuka kerja sama dengan Singapura dalam tata kelola gas.

 Ia menyatakan, tiga infrastruktur gas utama, mulai dari regasifikasi, tempat penyimpanan, hingga pipa penyaluran, hanya ada di wilayah timur Indonesia. Hal ini dinilai menjadi titik evaluasi sehingga ke depan pemerintah harus bisa meningkatkan kapasitas infrastruktur gas.

Ia menyatakan, pemerintah bisa melakukan penambahan infrastruktur gas di dalam negeri dengan menggandeng BUMN dan perusahaan energi domestik. Ia melihat hal ini lebih penting daripada harus bekerja sama dengan Singapura yang hanya menjadi penyalur.

"Kalau tidak ada jaminan bahwa Singapura bisa memberi harga lebih murah, kenapa harus bersama Singapura kerja samanya. Kalau memang alasan untuk menekan harga, maka seharusnya pemerintah juga perlu membenahi infrastruktur gas yang selama ini membuat harga gas yang diterima konsumen gas lebih murah," ujar Pri Agung 

Pri Agung mengatakan, Singapura tidak mempunyai produksi gas. Mereka hanya memiliki fasilitas yang memadai sehingga bisa menyuplai kebutuhan gas di wilayah barat Indonesia. Bahkan, gas alam cair atau LNG yang digunakan oleh Singapura juga kemungkinan berasal dari Indonesia.

"Harga landed price masih 6 sampai 7 dolar AS per mmbtu, belum biaya regasifikasi. Maka, kenapa kita tidak lebih baik yang membangun in frastruktur itu. Hal ini tentu akan memberikan efek perekonomian yang lebih besar," ujar Pri Agung.

Sebelumnya, Menteri Koordinator Bidang Maritim Luhut Binsar Pandjaitan sempat mengusulkan membuka kerja sama dengan Singapura untuk pembangunan infrastruktur gas dan distribusi gas yang lebih murah. Kebijakan ini diambil Luhut karena harga gas di Sumatera dan Kalimantan masih mahal dibandingkan di Wilayah Timur Indonesia.

Luhut menjelaskan, pilihan distribusi LNG dari dua perusahaan Singapura, yaitu Keppel Offshore and Marine dan Pavilion Energy Ltd, karena lokasinya yang lebih dekat dengan terminal regasifikasi. Alhasil, harga LNG yang didistribusi diprediksi dapat menjadi lebih murah.

Selama ini LNG yang dimiliki Indonesia sebagian besar berasal dari wilayah bagian timur. Jika didistribusikan ke lokasi regasifikasi, harganya dapat melonjak.

"Kalau kita mau terang-terangan juga sebagian besar gas kita datang dari Indonesia Timur. Sehingga, mahal kalau mau ditarik sampai ke pulau Nias," ujar Luhut pekan lalu.

Padahal, di saat yang Sama, Indonesia justru akan mengekspor gas alam cair (liqufied natural gas/ LNG) ke Bangladesh untuk mengatasi defisit pasokan gas di negara tersebut. Pemerintah RI dan Republik Rakyat Bangladesh telah menandatangani nota kesepahaman untuk memperkuat kerja Sama bidang energi.

Salah satu bentuk kerja sama tersebut adalah kemungkinan mengekspor LNG dari Indonesia ke Bangladesh. Kepala Biro Komunikasi, Layanan Informasi Publik dan Kerja Sama Kementerian ESDM, Dadan Kusdiana, mengatakan, masih cukup banyak kargo LNG yang belum terbeli dan ke depan kecenderungannya terus meningkat.

Republika, Page-13, Monday, Sept 18, 2017