Technology Can Drive Efficiency

Accenture's research shows that most oil and gas companies, including those operating in Southeast Asia, are interested in developing digital technology at their refinery facilities. The application of digital technology will make the company more efficient. Research involving about 200 executives, leaders, and engineers of oil and gas companies shows, 57 percent of respondents will increase digital investment.

"Oil and gas companies realize that they have to invest in digital technology because it will help the maintenance to be more efficient," said Managing Director of Resources Operating Group PT Accenture Mark H. Teoh in a media meeting, Wednesday (2/8), in Jakarta.

Accenture's research noted that digital technology will increase the effectiveness of refinery management (63 percent), reduce operational risk (59 percent), and mitigation in care of refinery facilities (54 percent). Operational cost reduction is the reason to encourage the application of digital technology in oil and gas companies. However, the obstacles faced are still low investment.

According to Mark, awareness of the importance of digital technology emerged due to various factors. The ease and efficiency resulting from the application of digital technology that is felt in other industries besides oil and gas become one of learning. While technically many companies learn from experience if the refinery is suddenly broken. In addition, falling world oil prices are pressing the oil and gas company's finances.

"The cost to run another suddenly damaged refinery is huge. The effect can be on the delay of shipping products so that oil and gas companies can not fulfill the contract, "said Mark.

Data analysis

With an integrated engine, the risk of engine damage will be monitored early. Information technology can also be used to monitor employee stress levels at refineries. Through earlier handling based on data analysis of machines or workers, the costs incurred by the company will eventually be lower.

However, research shows that the development of digital technology raises concerns related to data security of oil and gas companies. Accenture noted, Indonesia's Indonesia Incident Security Response Team on Internet Infrastructure (ID-SIRTII) Indonesia is vulnerable to cyber attacks.

In 2016 there is an increase in cyber attacks by 50 percent over the previous year, therefore 36 percent of respondents call data security as a major obstacle to the adoption of digital technology into oil and gas companies. That number increased to 50 percent when the surveyed were workers in the field of information technology.

Country Managing Director of Accenture Indonesia Neneng Goenadi said the change from manual system to digital technology requires adjustment from the people who work in it. Because, digital technology will integrate people with tools or machines.

IN INDONESIA

Teknologi Bisa Mendorong Efisiensi

Riset Accenture memperlihatkan, sebagian besar perusahaan minyak dan gas, termasuk yang beroperasi di Asia Tenggara, berminat untuk mengembangkan teknologi digital di fasilitas kilangnya. Penerapan teknologi digital akan membuat perusahaan makin efisien. Riset yang melibatkan sekitar 200 eksekutif, pemimpin, dan insinyur perusahaan migas itu menunjukkan, 57 persen responden akan meningkatkan investasi digital. 

”Perusahaan migas menyadari bahwa mereka harus investasi untuk teknologi digital karena akan membantu perawatan sehingga semakin efisien,” kata Managing Director Resources Operating Group PT Accenture Mark H Teoh dalam temu media, Rabu (2/8), di Jakarta.

Riset Accenture mencatat, teknologi digital akan meningkatkan efektivitas pengelolaan kilang (63 persen), mengurangi risiko operasional (59 persen), dan mitigasi dalam merawat fasilitas kilang (54 persen). Pengurangan biaya operasional menjadi alasan untuk mendorong penerapan teknologi digital di perusahaan migas. Namun, hambatan yang dihadapi adalah investasi yang masih rendah.

Menurut Mark, kesadaran pentingnya teknologi digital muncul karena berbagai faktor. Kemudahan serta efisiensi yang ditimbulkan dari penerapan teknologi digital yang dirasakan di industri lain selain migas menjadi salah satu pembelajaran. Sementara secara teknis banyak perusahaan belajar dari pengalaman jika kilang tiba-tiba rusak. Selain itu, harga minyak dunia yang turun menekan keuangan perusahaan migas.

”Biaya untuk menjalankan lagi kilang yang rusak mendadak itu besar. Pengaruhnya bisa sampai pada keterlambatan pengapalan produk sehingga perusahaan migas tidak bisa memenuhi kontrak,” ujar Mark.

Analisis data

Dengan mesin yang terintegrasi, risiko kerusakan mesin akan terpantau secara dini. Teknologi informasi juga dapat digunakan untuk memantau tingkat stres karyawan di kilang. Melalui penanganan yang lebih awal berdasarkan analisis data terhadap mesin atau pekerja, biaya yang dikeluarkan perusahaan pun akhirnya akan semakin rendah.

Meski demikian, riset menunjukkan bahwa perkembangan teknologi digital menimbulkan kekhawatiran terkait dengan keamanan data perusahaan migas. Accenture mencatat, Tim Respons Insiden Keamanan Indonesia mengenai Infrastruktur Internet (ID-SIRTII)Indonesia termasuk rentan terhadap serangan siber. 

Pada 2016 terjadi peningkatan serangan siber sebesar 50 persen dibandingkan tahun sebelumnya, oleh karena itulah 36 persen responden menyebut keamanan data sebagai hambatan utama diadopsinya teknologi digital ke dalam perusahaan migas. Angka itu meningkat menjadi 50 persen ketika yang disurvei adalah para pekerja di bidang teknologi informasi.

Country Managing Director Accenture Indonesia Neneng Goenadi mengatakan, perubahan dari sistem manual menjadi teknologi digital memerlukan penyesuaian dari orang-orang yang bekerja di dalamnya. Sebab, teknologi digital akan mengintegrasikan orang dengan alat atau mesin.

Kompas, Page-18, Thursday, August 3, 2017

Jonan Lift Ego Syahrial As Director General of Oil and Gas

The Ministry of Energy and Mineral Resources (ESDM) rotates the Director General of Oil and Gas at IGN Wiratmaja Puja and replaces it with Geo Ministry of ESDM Ego Syahrial. While Wiratmaja will become Head of Development Agency of Human Resources (BPSDM) Ministry of Energy and Mineral Resources.

Related to this rotation, ESDM Minister Ignasius Jonan said, Ego Syahrial who replaced Wiratmaja with geological background. However, Ego Syahrial still get the mandate as Director General of Oil and Gas to increase oil and gas exploration efforts.

"Improving oil and gas exploration, as well as enhancing oil recovery (EOR) efforts are correct and better," he said at the Ministry of Energy and Mineral Resources, after the inauguration, Wednesday (2/8).

With the new position, Jonan still set targets. But he has not been able to mention the target of the new official, including whether the auction of oil and gas working areas is also included from the target.

"If our auction can not force, the price of oil only reaches US $ 50 per barrel or Indonesian Crude Price (ICP) is still US $ 45 per barrel," he said.

In addition to inaugurate and rotate the two people, Jonan inaugurated 41 officials in the Ministry of Energy and Mineral Resources. Echelon I have 3 people, Echelon II there are 6 people, Echelon III as many as 5 people, Echelon IV there are 15 people and 12 Functional Officials.

IN INDONESIA

Jonan Angkat Ego Syahrial Sebagai Dirjen Migas

Kementerian Energi dan Sumber Daya Mineral (ESDM) merotasi Direktur Jenderal Migas IGN Wiratmaja Puja dan menggantinya dengan Kepala Badan Geologi Kementerian ESDM Ego Syahrial. Sedangkan Wiratmaja akan menjadi Kepala Badan Pengembangan Sumber Daya Manusia (BPSDM) Kementerian ESDM.

Terkait rotasi ini, Menteri ESDM Ignasius Jonan mengatakan, Ego Syahrial yang menggantikan Wiratmaja berlatar belakang geologi. Namun, Ego Syahrial tetap mendapatkan amanah sebagai Dirjen Migas untuk meningkatkan upaya eksplorasi minyak dan gas bumi. 

"Meningkatkan eksplorasi migas, juga upaya melakukan enhanced oil recovery (EOR) yang benar dan Iebih baik," katanya, di Kantor Kementerian ESDM, usai melakukan pelantikan tersebut, Rabu (2/8).

Dengan jabatan baru tersebut, Jonan tetap menetapkan target. Namun ia belum bisa menyebutkan target sang pejabat baru, termasuk, apakah lelang wilayah kerja migas juga termasuk dari target tersebut. 

"Kalau lelang kita tidak bisa memaksa. Harga minyak saja mencapai US$ 50 per barel atau Indonesian Crude Price (ICP) masih US$ 45 per barel. Orang mau berinvestasi banyak pertimbangan" katanya.

Selain melantik dan merotasi kedua orang tersebut, Jonan melantik 41 pejabat di Iingkungan Kementerian ESDM. Eselon I ada 3 orang, Eselon II ada 6 orang, Eselon III sebanyak 5 orang, Eselon IV ada 15 orang dan Pejabat Fungsional 12 orang.

Kontan, Page-14, Thursday, August 3, 2017

Note Pick up Ball

During his working visit to the United States for most of last week, Energy and Mineral Resources Minister Ignatius Jonan met the top giant oil and gas companies Chevron, ConocoPhilips and Exxon. The essence of the visit is to attract investment in the oil and gas sector to Indonesia.

In Indonesia, Chevron, ConocoPhilips, and Exxon crude oil production, combined with 55 percent of Indonesia's total oil lifting production. In 2016, the three contributed 461,757 barrels per day and total lifting reached 832,000 barrels per day.

In an official statement of the Ministry of Energy and Mineral Resources, the government is also introducing the new oil and gas business scheme in Indonesia. The crucial policies issued by the government related to upstream oil and gas investment are among others Government Regulation (PP) No. 27 of 2017, as revised Government Regulation No. 79/2010 on Refundable Operating Costs and Treatment of Income Tax in Upstream Oil and Gas Business Sector, Regulation of Minister of Energy and Mineral Resources No. 8/2017 on Gross Split Distribution Contract.

Government Regulation No. 27/2017 regulates incentives granted by the government to upstream oil and gas investors in the form of abolition of import duty, reduction of land and building tax, and exemption of Value Added Tax or Sales Tax on Luxury Goods. The Regulation of the Minister of Energy and Mineral Resources No. 8/2017 regulates a new oil and gas revenue sharing scheme, from the previous profit sharing with the concept of recoverable operating cost (cost recovery) to profit sharing based on gross production (gross split).

According to one professional of the oil and gas sector, the concept of gross split introduced by the government is no more attractive than the concept of cost recovery. Therefore, investors should bear the full risk of investment during the contract period. The concept of gross split needs further verification because it has just been tested on PT Offshore North West Java which is fully managed by PT Pertamina since the beginning of this year.

From the point of view of the government, the Regulation of Minister of Energy and Mineral Resources No. 8/2017 and Government Regulation No. 27/2017 is one way out in the upstream oil and gas investment crisis in Indonesia Toward 2014 Cap is the beginning of the upstream oil and gas crisis that sweeps the whole world, not to mention Indonesia. Oil prices that were above 100 US dollars per barrel fell to less than 50 US dollars per barrel. In fact, in early 2016 had dropped dramatically to below 30 US dollars per barrel.

Based on the record of the Indonesian Petroleum Association (IPA), Indonesia's upstream oil and gas investment climate is difficult to say, including when oil prices are low today. The so-called classic problem of making investments worse is licensing. Mentioned, there are 373 types of licenses to be administered upstream oil and gas investors in 19 ministries and agencies, including licensing in the region. Indonesia's fiscal incentives are also called less competitive than other countries.

The Special Working Unit for Upstream Oil and Gas Business (SKK Migas) acknowledges that Indonesia's upstream oil and gas business processes are heavily influenced by non-technical factors. Since the upstream oil and gas contract is signed, the exploration and exploitation process takes up to 9 years.

In fact, if there are technical obstacles, such as land acquisition can be up to 16 years, the central government may mention that it has simplified the permit. However, oil and gas affairs are not merely through the center. Local governments also have interests that are not less big, especially since the era of regional autonomy applied.

The government formula to provide incentives or ease of licensing must be thorough to the location of oil and gas resource location. The ease of doing business or incentives should really exist. From central to oil field is located. Oil and gas investment ball is not enough to be picked up, but must be treated and accompanied to completion.

IN INDONESIA

Catatan Jemput Bola

Dalam kunjungan kerjanya ke Amerika Serikat hampir sepanjang pekan lalu, Menteri Energi dan Sumber Daya Mineral Ignasius Jonan bertemu pucuk pimpinan perusahaan minyak dan gas bumi raksasa, yaitu Chevron, ConocoPhilips, dan Exxon. Intisari kunjungan itu adalah untuk menarik investasi di sektor minyak dan gas bumi ke Indonesia.

Di Indonesia, produksi minyak mentah Chevron, ConocoPhilips, dan Exxon, jika digabungkan setara dengan 55 persen dari total produksi siap jual (lifting) minyak Indonesia. Pada 2016, ketiganya menyumbang 461.757 barrel per hari dan total realisasi lifting yang mencapai 832.000 barrel per hari.

Dalam keterangan resmi Kementerian ESDM, pemerintah juga sedang mengenalkan skema bisnis migas di Indonesia yang baru. Kebijakan krusial yang dikeluarkan pemerintah terkait dengan investasi hulu migas antara lain Peraturan Pemerintah (PP) Nomor 27 Tahun 2017, sebagai revisi Peraturan Pemerintah No 79/2010 tentang Biaya Operasi yang Dapat Dikembalikan dan Perlakuan Pajak Penghasilan di Bidang Usaha Hulu Minyak dan Gas Bumi, serta Peraturan Menteri ESDM No 8/2017 tentang Kontrak bagi Hasil Gross Split.

Peraturan Pemerintah No 27/2017 mengatur insentif yang diberikan pemerintah kepada investor hulu migas berupa penghapusan bea masuk, pengurangan Pajak Bumi dan Bangunan, serta pembebasan Pajak Pertambahan Nilai atau Pajak Penjualan terhadap Barang Mewah. Adapun Peraturan Menteri ESDM No 8/2017 mengatur skema baru bagi hasil migas, dari yang sebelumnya bagi hasil dengan konsep biaya operasi yang dapat dipulihkan (cost recovery) menjadi bagi hasil berdasar produksi bruto (gross split).

Menurut salah satu profesional sektor migas, konsep gross split yang dikenalkan pemerintah tidak lebih menarik daripada konsep cost recovery. Sebab, investor harus menanggung penuh risiko investasi selama masa kontrak. Konsep gross split memang perlu pembuktian lebih jauh karena baru diujicobakan pada blok Offshore North West Java yang dikelola penuh PT Pertamina sejak awal tahun ini.

Dari kacamata pemerintah, Peraturan Menteri ESDM No 8/2017 dan Peraturan Pemerintah No 27/2017 adalah salah satu jalan keluar di saat krisis investasi hulu migas di Indonesia Menjelang Tutup tahun 2014 adalah awal dari krisis hulu migas yang melanda seluruh dunia, tidak terkecuali Indonesia. Harga minyak yang saat itu di atas 100 dollar AS per barrel turun sampai menjadi kurang dari 50 dollar AS per barrel. Bahkan, pada awal 2016 sempat turun drastis sampai di bawah 30 dollar AS per barrel.  

Berdasarkan catatan Asosiasi Perminyakan Indonesia (IPA), iklim investasi hulu migas Indonesia sulit dikatakan menarik, termasuk pada saat harga minyak rendah saat ini. Masalah klasik yang disebut membuat investasi terpuruk adalah perizinan. Disebutkan, ada 373 jenis izin yang harus diurus investor hulu migas di 19 kementerian dan lembaga, termasuk perizinan di daerah. Insentif fiskal Indonesia juga disebut kurang kompetitif dibandingkan dengan negara lain.

Pihak Satuan Kerja Khusus Pelaksana Kegiatan Usaha Hulu Minyak dan Gas Bumi (SKK Migas) mengakui, proses bisnis hulu migas Indonesia sangat dipengaruhi faktor non-teknis. Sejak kontrak hulu migas ditandatangani, proses eksplorasi dan eksploitasi memerlukan waktu sampai 9 tahun. 

Bahkan, jika ada kendala teknis, seperti pembebasan lahan bisa sampai hingga 16 tahun, Pemerintah pusat boleh saja menyebut sudah menyederhanakan izin. Akan tetapi, urusan migas tidak melulu melalui pusat. Pemerintah daerah juga punya kepentingan yang tidak kalah besar, apalagi sejak era otonomi daerah diberlakukan.

Formula pemerintah memberikan insentif ataupun kemudahan perizinan harus menyeluruh hingga di daerah lokasi sumber migas berada. Kemudahan berbisnis ataupun insentif harus benar-benar ada. Dari pusat sampai ke lapangan migas berada. Bola investasi migas tidak cukup dijemput, tetapi harus dirawat dan didampingi sampai tuntas.

Kompas, Page-17, Thursday, August 3, 2017

Ego Syahrial Slide Wiratmaja Puja Position

Minister of Energy and Mineral Resources Ignatius Jonan inaugurated Ego Syahrial who previously served as Head of Geological Agency became Director General of Oil and Gas replacing IGN Wiratmaja Puja

Jonan said, Ego Syahrial is suitable to occupy the position of Director General of Oil and Gas to increase oil and gas exploration activities. In addition, he mentioned that the Ego who last year was assigned as Head of Geological Agency was expected to be able to encourage the application of enhanced oil recovery (EOR).

Continuing oil drilling activities to anticipate production decline. Because the trend of oil production continues to decline. Based on the APBNP 2017, production is ready to sell or lifting 815,000 barrels per day (bpd) of oil and gas to 1,150 thousand barrels of oil equivalent per day (Mboepd).

In relation to EOR activities, in the General Plan of National Energy (RUEN), the rate of decline in oil production is estimated at an average of 6% per year. Meanwhile, additional oil production can be obtained from new reserve planning or exploration activities as well as EOR from certain fields.

Further oil drainage activities will contribute to national oil production by 2020 with a reserve amount of up to 2050 restored at 2.5 billion barrels.

"We need to be in the field of geology to improve our exploration efforts. Efforts to do the right EOR, "he said, Wednesday (2/8).

Jonan rate, IGN Wiratmaja Puja with new position as Head of Mineral Resources Development Agency [BPSDM] Iebih suitable to optimize human resources with experience in the academic field.

In addition, Jonan also inaugurated 39 other officials, namely echelon I of 1 person, Echelon II six people, echelon III five people, echelon IV 15 people and functional officials 12 people. Jonan advised officials who had just been sworn in to improve his performance.

"If that can be a promotion, that way of thinking is improved so the better."

IN INDONESIA

Ego Syahrial Geser Posisi Wiratmaja Puja

Menteri Energi dan Sumber Daya Mineral Ignasius Jonan melantik Ego Syahrial yang sebelumnya menjabat sebagai Kepala Badan Geologi menjadi Direktur Jenderal Minyak dan Gas Bumi menggantikan IGN Wiratmaja Puja

Jonan mengatakan, Ego Syahrial cocok menduduki jabatan Dirjen Migas untuk meningkatkan kegiatan eksplorasi minyak dan gas bumi. Selain itu, dia menyebut bahwa Ego yang tahun lalu ditugaskan sebagai Kepala Badan Geologi itu diharapkan agar mampu mendorong penerapan kegiatan pengurasan Minyak lanjutan (enhanced oil recovery/EOR).

Kegiatan pengurasan minyak Ianjutan untuk mengantisipasi penurunan produksi. Pasalnya, tren produksi minyak terus menurun. Berdasarkan APBNP 2017, produksi siap jual atau lifting 815.000 barel per hari (bph) minyak dan gas 1.150 ribu barel setara minyak per hari (Mboepd).

Terkait dengan kegiatan EOR, dalam Rencana Umum Energi Nasional (RUEN), Iaju penurunan produksi minyak diperkirakan rata-rata sebesar 6 % per tahun. Sementara itu, tambahan produksi minyak bisa diperoleh dari kegiatan perencanaan cadangan baru atau eksplorasi juga EOR dari lapangan-lapangan tertentu.

Kegiatan pengurasan minyak Ianjutan akan berkontribusi terhadap produksi minyak nasional pada 2020 dengan jumlah cadangan yang dipulihkan sampai 2050 sebesar 2,5 miliar barel.

“Kita perlu di bidang geologi untuk meningkatkan upaya eksplorasi. Upaya melakukan EOR yang benar,” ujarnya, Rabu (2/8).

Jonan menilai, IGN Wiratmaja Puja dengan jabatan baru sebagai Kepala Badan Pengembangan Sumber Daya Mineral [BPSDM] Iebih cocok untuk mengoptimalkan sumber daya manusia dengan pengalamannya di bidang akademik.

Selain itu, Jonan pun melantik 39 pejabat Iainnya, yaitu eselon I sebanyak 1 orang, Eselon II enam orang, eselon III lima orang, eselon IV 15 orang dan pejabat fungsional 12 orang. Jonan berpesan kepada pejabat yang baru saja dilantik untuk meningkatkan kinerjanya. 

“Kalau yang dapat promosi, itu cara berpikirnya diperbaiki jadi semakin baik."

Bisnis Indonesia, Page-32, Thursday, August 3, 2017

Entrepreneurs are Asked to Follow the Review of the Margin Pipeline Rules

The government asked entrepreneurs to study the draft regulation on the limitation of gas pipeline project margins. The regulation which is a revision of Ministerial Regulation No 19 of 2009 on the business of natural gas through this pipeline has entered the final stage.

Deputy Minister of Energy and Mineral Resources (ESDIVI) Arcandra Tahar said the revision process of Ministerial Regulation 19/2009 has entered the final stage. It has invited related parties to be consulted, including PT PGN PT Pertamina Gas (Pertagas), Indonesia Natural Gas Trader Association (INGTA) and gas user association.

"We ask for the opinions of stakeholders, yesterday we had a meeting. We give them time to see if this [draft Ministerial Regulation] benefits or not, "he said in Jakarta, Tuesday (1/8).

He denied the new regulation will hinder the construction of new gas pipeline in Indonesia. The issuance of this revision of the Ministerial Regulation is also intended to encourage more built-up gas infrastructure. The reason, this new rule will guarantee the rate of return of capital (internal rate of return / IRR) and set the margin obtained by business entities.

"Well if it is out the Minister Regulation, to what margin and return how, just wait," he said.

In the draft Ministerial Regulation obtained, this new rule will limit the toll fee charged to gas consumers. Toll fee will be settled by calculating the sum of asset depreciation, operation and maintenance cost, tax, contribution, and IRR then divided by volume.

In this formula, the IRR will also be limited to 11% for existing and non-pioneering pipelines. As for infrastructure development on the market that has not developed (pioneering) is given limit of IRR 12%. In addition, the economic life of the pipes is also set at 15 years. Furthermore, the volume of gas used in accordance with the allocation or 60% of the initial design capacity of the larger distribution pipeline.

As for the commercial cost formula set at less than or equal to 7% of the price of upstream gas. This commercial cost includes commodity management costs, marketing and customer management costs, risk and profit margins. When the gas distribution through two commercial business entities is facilitated to reach the final consumer, the commercial cost of 7% is divided into the two business entities.

Not just regulating, the draft of this Ministerial Regulation also impose sanctions for business entities that violate regulations. Violation of obligations shall be liable to administrative sanctions in the form of a written warning at most twice with a maximum period of one month. If it is still violated, the next business entity will be subject to suspension for a maximum of three months. Final, business entities may be revoked business license and or cancellation of allocation determination and utilization of natural gas.

Earlier, Menteni ESDM Ignasius jonan confirmed that the toll fee set for gas consumers must be competitive. Because the cost of this transport will affect the price of gas that affects the competitiveness of national industries.

He explained that during this company the owner of the pipeline to share this investment burden with the volume of gas flowed through the pipes. If the gas volume is flowing a bit, then the toll fee drawn can be quite high. It wanted the same amount of toll fee regardless of the volume of gas that flowed.

He added, to reduce the national gas price, it has encouraged oil and gas producers to make efficiency. But if on the midtsream side does not do the same and set a high toll fee, then the national gas price can not be as low as expected

IN INDONESIA

Pengusaha Diminta Ikuti Mengkaji Aturan Marjin Pipa Gas

Pemerintah meminta pengusaha untuk mempelajari rancangan regulasi soal pembatasan marjin proyek pipa gas. aturan yang merupakan revisi dari Peraturan Menteri No 19 Tahun 2009 tentang kegiatan usaha gas bumi melalui pipa ini telah memasuki tahap akhir.

Wakil Menteri Energi dan Sumber Daya Mineral (ESDIVI) Arcandra Tahar mengatakan, proses revisi Peraturan Menteri 19/2009 tersebut telah memasuki tahap final. Pihaknya telah mengundang pihak terkait untuk dimintai pendapat, dintaranya PT PGN PT Pertamina Gas (Pertagas), Indonesia Natural Gas Trader Association (INGTA) dan asosiasi pengguna gas.

“Kami minta pendapati stake Holder, kemarin kami sudah lakukan meeting. Kami memberi mereka waktu untuk melihat apakah ini [rancangan Peraturan Menteri] memberi manfaat atau tidak,” kata dia di Jakarta, Selasa (1/ 8).

Dirinya menampik aturan baru ini akan menghambat pembangunan pipa gas baru di Indonesia. Penerbitan revisi Peraturan Menteri ini juga dimaksudkan mendorong agar infrastruktur gas terbangun semakin banyak. Pasalnya, aturan baru ini akan menjamin tingkat pengembalian modal (internal rate of return/IRR) dan mengatur marjin yang diperoleh badan usaha. 

“Nah kalau sudah keluar Peraturan Menterinya, untuk marjin berapa dan return berapa, tunggu saja,” ujarnya. 

Dalam draf Peraturan Menteri yang diperoleh, aturan baru ini akan membatasi toll fee (ongkos angkut) yang dibebankan kepada konsumen gas. Toll fee akan ditetap dengan menghitung hasil penjumlahan depresiasi aset, biaya operasi dan pemeliharaan, pajak, iuran, serta IRR kemudian dibagi volume.

Dalam formula ini, IRR nantinya juga akan dibatasi 11% untuk pipa eksisting dan non-pioneering. Sementara untuk pengembangan infrastruktur pada pasar yang belum berkembang (pioneering) diberikan batas IRR 12%. Selain itu, umur keekonomian pipa juga ditetapkan 15 tahun. Selanjutnya, volume gas yang digunakan sesuai dengan alokasi atau 60% dari kapasitas desain awal pipa distribusi yang lebih besar.

Sementara untuk formula biaya niaga ditetapkan kurang dari atau sama dengan 7% dari harga gas hulu. Biaya niaga ini telah mencakup biaya pengelolaan komoditas, biaya pemasaran dan pengelolaan pelanggan, biaya risiko dan marjin niaga. Bila penyaluran gas melalui dua badan usaha niaga berfasilitas untuk mencapai konsumen akhir, biaya niaga sebesar 7% dibagi ke dua badan usaha tersebut.

Tidak sekadar mengatur, draf Peraturan Menteri ini juga memberikan sanksi bagi badan usaha yang melanggar peraturan. Pelanggaran kewajiban dikenai sanksi administratif berupa peringatan tertulis paling banyak dua kali dengan jangka waktu maksimal satu bulan. Jika masih melanggar, berikutnya badan usaha akan terkena penghentian sementara maksimal tiga bulan. Finalnya, badan usaha bisa dicabut izin usaha dan atau pembatalan penetapan alokasi dan pemanfaatan gas bumi.

Sebelumnya, Menteni ESDM Ignasius jonan menegaskan ongkos angkut (toll fee) yang ditetapkan bagi konsumen gas harus kompetitif. Pasalnya, ongkos angkut ini akan berpengaruh pada harga gas yang berdampak pada daya saing industri nasional. 

Dijelaskannya selama ini perusahaan pemilik pipa membagi beban investasi ini dengan volume gas yang dialirkan melalui pipanya. Jika volume gas yang mengalir sedikit, maka toll fee yang ditarik bisa cukup tinggi. Pihaknya menginginkan besaran toll fee yang sama berapapun volume gas yang dialirkan.

Dia menambahkan, untuk menekan harga gas nasional, pihaknya sudah mendorong produsen migas untuk melakukan efisiensi. Namun jika di sisi midtsream tidak melakukan hal yang sama dan menetapkan toll fee tinggi, maka harga gas nasional tidak bisa serendah yang diharapkan

Investor Daily, Page-11, Wednesday, August 2, 2017

Gas prices Jambaran Project Blue-flung US $ 76 / MMBTU

The government said it had no gas price agreement for Project Jambaran-flung Blue, which was US $ 7.6 million british thermal unit / mmbtu without esklasi. Minister of Energy and Mineral Resources (EMR) Ignatius Jonan said that there is no longer a problem with the continuation of Project Blue Jambaran-flung. PT Pertamina and PT PLN have agreed on the price of gas from the project.

"PLN will buy from there, at the plant gate (receiving station in the power plant) gas price of US $ 7.6 per mmbtu flat (without escalation)," he said

The price scale is different from that assumed in the plan of development / POD US $ 8 per mmbtu at the well head. Assuming gas prices and the contract period until 2035, the POD predicted revenue from this project to reach US $ 12.97 billion. Acceptance of these, as many as 45.8% belongs to the government, 24.5% of the PSC, and a 29.7% return for the operating costs (cost recovery).

Jambaran is part of the Cepu Block which is operated by ExxonMobil. However, for projects Jambaran-flung Blue, EPC as part of the operator lamparannya connected with the Blue flung owned PT Pertamina EP Currently, the ownership rights to participation in Cepu own 45% of the EPC, Ampolex 24.5%, ExxonMobil 20.5 %, and ROE of 10%.

For their own development, the plan was drilling six development wells and construction of processing facilities and its supporters. Total investment is projected to reach US $ 2.056 billion, or around Rp 28 trillion details of US $ 279.5 million for the cost of the well and US $ 1,777 billion for production facilities.

With lower gas prices, the project is a matter of economics Jambaran-flung Blue also changed. Earlier, President Director of Pertamina EP Cepu Adriansyah said, based on the prediction that the price of gas suitable for the project is estimated at US $ 7 per million British thermal unit (mmbtu) with the escalation of 2% per year at the wellhead. With this benchmark, the price of gas in electricity generation could be around US $ 8.5 per mmbtu.

It is, according to Pertamina's upstream director Syamsu Alam, which makes ExxonMobil does not want to get involved in the project Jambaran-flung Blue. For it, Pertamina must take stock participation in Jambaran. However, it took few incentives to be able to buy with the price offered by ExxonMobil.

"Some of the incentives that we asked, one issue split. We want to split change, "said Alam.

He explains, this change split remember ExxonMobil is no longer involved in the project. Previously, the project Jambaran-flung Blue, the results for the government and Pertamina namely 60:40. while with ExxonMobil 65:35. The composition of the split is expected to be changed because there is no longer at the ExxonMobil Jambaran.

"If we take stock participation of ExxonMobil, who has split Exxon in Jambaran same with us," he said.

Project Jambaran-flung Blue have started this year in order to be able to operate in 2020. Jambaran-flung Blue can produce gas to 320 million cubic feet per day / MMSCFD. But the carbon dioxide content of 30%, net gas that can be used just about 180-185 MMSCFD.

As is known, through its subsidiary, PT Pertamina EP Cepu (PEPC), intends to acquire a participating interest in ExxonMobil projects Jambaran flung Blue to ensure the project can begin producing oil and gas (on stream) in 2020. It is a follow-up letter from the Minister of Energy and Mineral Resources No 9/13 / MEM.M / 2017 dated 3 January 2017 ordered Pertamina to develop a full and complete field JTB discussions with ExxonMobil through schemes business (business to business / b to b)

IN INDONESIA

Harga Gas Proyek Jambaran-Tiung Biru US$ 76/MMBTU

Pemerintah menyatakan telah ada kesepakatan harga gas untuk Proyek jambaran-Tiung Biru yakni sebesar US$ 7,6 juta british thermal unit/mmbtu tanpa esklasi. Menteri Energi dan Sumber Daya Mineral (ESDM) Ignasius Jonan menuturkan tidak ada lagi masalah dengan kelanjutan Proyek Jambaran-Tiung Biru. PT Pertamina dan PT PLN telah menyepakati harga gas dari proyek ini. 

“PLN akan membeli dari situ, di plant gate (stasiun penerima di pembangkit listrik) harga gasnya US$ 7,6 per mmbtu flat (tanpa eskalasi)" kata dia 

Besaran harga ini berbeda dengan yang diasumsikan dalam plan of development/POD US$ 8 per mmbtu di kepala sumur. Dengan asumsi harga gas ini dan masa kontrak hingga 2035, dalam POD diprediksi penerimaan dari proyek ini mencapai US$ 12,97 miliar. Dari penerimaan tersebut, sebanyak 45,8% menjadi milik pemerintah, 24,5% bagian kontraktor KKS, dan 29,7% untuk pengembalian biaya operasi (cost recovery).

Jambaran merupakan bagian dari Blok Cepu yang dioperasikan oleh ExxonMobil. Namun, untuk Proyek Jambaran-Tiung Biru, PEPC menjadi operator karena sebagian lamparannya terhubung dengan Lapangan Tiung Biru milik PT Pertamina EP Saat ini, untuk kepemilikan hak partisipasi di Blok Cepu sendiri yakni PEPC 45%, Ampolex 24,5%, ExxonMobil 20,5%, dan BUMD 10%.

Untuk pengembangannya sendiri, rencananya dilakukan pengeboran enam sumur pengembangan dan pembangunan fasilitas pengolahan dan pendukungnya. Total investasi diproyeksikan sebesar US$ 2,056 miliar atau sekitar Rp 28 triliun dengan rincian US$ 279,5 juta untuk biaya sumur dan US$ 1,777 miliar untuk fasilitas produksi.

Dengan harga gas lebih rendah, maka hitungan keekonomian Proyek Jambaran-Tiung Biru juga berubah. Sebelumnya, Presiden Direktur Pertamina EP Cepu Adriansyah menuturkan, berdasarkan hitungannya harga gas yang cocok agar proyek ini ekonomis yakni US$ 7 per juta british thermal unit (mmbtu) dengan eskalasi 2% per tahun di kepala sumur. Dengan patokan ini, harga gas di pembangkit listrik PLN bisa menjadi sekitar US$ 8,5 per mmbtu.

Hal inilah, menurut Direktur Hulu Pertamina Syamsu Alam, yang membuat ExxonMobil tidak ingin lagi terlibat dalam Proyek Jambaran-Tiung Biru. Untuk itu, Pertamina perlu mengambil alih saham partisipasi di Jambaran. Namun, pihaknya butuh beberapa insentif untuk dapat membeli dengan harga yang ditawarkan ExxonMobil. 

“Beberapa insentif yang kami minta, salah satunya masalah split. Kami ingin splitnya berubah,” tutur Alam.

Dia menjelaskan, perubahan split ini mengingat ExxonMobil tidak lagi terlibat dalam proyek. Sebelumnya, pada Proyek Jambaran-Tiung Biru ini, bagi hasil antara pemerintah dan Pertamina yakni 60:40. sementara dengan ExxonMobil 65:35. Komposisi split ini diharapkan dapat berubah lantaran tidak ada lagi ExxonMobil di Lapangan Jambaran.

“Kalau kami ambil saham partisipasi ExxonMobil, splitnya yang punya Exxon di Jambaran sama dengan kami,” ujar dia.

Proyek Jambaran-Tiung Biru harus dimulai tahun ini agar dapat operasi pada 2020. Lapangan Jambaran-Tiung Biru bisa menghasilkan gas hingga 320 juta kaki kubik per hari/mmscfd. Namun dengan kandungan karbondioksida sebesar 30%, gas bersih yang bisa digunakan hanya sekitar 180-185 mmscfd.

Seperti diketahui, Pertamina melalui anak usahanya, PT Pertamina EP Cepu (PEPC) , berniat mengambilalih hak partisipasi ExxonMobil di Proyek Jambaran Tiung Biru untuk  memastikan proyek tersebut dapat mulai menghasilkan migas (on stream) pada 2020. Hal ini adalah sebagai tindak lanjut Surat Menteri ESDM No 9/13/MEM.M/2017 tertanggal 3 Januari 2017 yang memerintahkan Pertamina untuk mengembangkan secara penuh lapangan JTB dan menyelesaikan pembahasan dengan ExxonMobil melalui skema bisnis (business to business/b to b)

Investor Daily, Page-11, Wednesday, August 2, 2017

Jonan Want to Bost Production of Cepu Block

The government expects domestic oil production to increase. But the government also does not want to spend more money to invest in oil production activities in Indonesia. One of them to boost production from Cepu block. In a meeting with Exxon Mobil Corporation's Senior Vice President Mark W. Albers, in the United States last week, Energy Minister Ignatius Jonan hoped that Cepu Block production would increase to 300,000 barrels per day (bpd).

In fact, currently, the production of Cepu Block with Exxon Mobil as operator has reached the maximum capacity of 200,000 bpd. In order to increase production to 300,000 bpd, investment in Cepu block must be increased.

"If it can be increased a lot without significant investment please If it can be 300,000, yes, 300,000 bpd But if you have to increase investment up to 50% from now, I do not want," said Jonan, in his office, Tuesday (8/1).

That way, Cepu's production target is only targeted to reach 200,000 bph this year. Cepu production is one of the mainstay in meeting Indonesian oil lifting. Until June 2017, Indonesia's oil lifting has just reached 802,000 bpd. The target of this year's oil lifting is 815,000 bpd.

Vice President of Public and Government Affairs ExxonMobil Indonesia Erwin Maryoto said the Ministry of Environment and Forestry (LHK) has issued a production permit Banyu Urip with a capacity of 220,000 bpd. But it is evaluating production to 300,000 bpd.

IN INDONESIA

Jonan Ingin Genjot Produksi Blok Cepu

Pemerintah berharap produksi minyak dalam negeri terus meningkat. Namun pemerintah juga tidak ingin mengeluarkan dana lebih besar lagi untuk berinvestasi dalam kegiatan produksi minyak di Indonesia. Salah satunya untuk menggenjot produksi dari blok Cepu. Dalam pertemuan dengan Senior Vice President (SVP) Exxon Mobil Corporation Mark W. Albers, di Amerika Serikat pekan lalu, Menteri Energi ESDM Ignasius Jonan berharap, produksi Blok Cepu meningkat hingga 300.000 barel per hari (bph).

Padahal saat ini, produksi Blok Cepu dengan Exxon Mobil sebagai operator sudah mencapai kapasitas maksimal sebesar 200.000 bph. Agar meningkatkan produksi hingga mencapai 300.000 bph, maka investasi di blok Cepu harus ditingkatkan. 

"Kalau bisa ditingkatkan banyak tanpa investasi signifikan silahkan. Kalau bisa 300.000, ya, 300.000 bph. Tapi kalau harus ditingkatkan lagi investasi hingga 50% dari sekarang, saya tidak mau," kata Jonan, di kantornya, Selasa (8/1).

Dengan begitu, target produksi Cepu hanya ditargetkan mencapai 200.000 bph tahun ini. Produksi Cepu ini menjadi salah satu andalan dalam memenuhi lifting minyak Indonesia. Hingga Juni 2017, lifting minyak Indonesia baru saja mencapai 802.000 bph. Sementara target Lifting minyak tahun ini sebesar 815.000 bph.

Vice President Public and Goverment Affairs ExxonMobil Indonesia Erwin Maryoto bilang, Kementerian Lingkungan Hidup dan Kehutanan (LHK) sudah mengeluarkan izin produksi Banyu Urip dengan kapasitas 220.000 bph. Tetapi pihaknya mengevaluasi produksi sampai 300.000 bph.

Kontan, Page-14, Wednesday, August 2, 2017

Upon Gas Margin Immediately Determined

The government is still asking for input from business actors related to the plan to limit the gas trading margin and the level of investment development before it is decided in the form of regulation.

Currently, the discussion on the revision of Minister of Energy and Mineral Resources Regulation no. 1 9/2009 on Gas Gas Business Activities Through Pipeline has entered the final stage. It will regulate downstream gas business, such as margin and internal rate of return (IRR).

Deputy Minister of Energy and Mineral Resources (ESDM) Arcandra Tahar said the rules of margin restrictions and payback for gas transmission and distribution pipeline have entered the final stage. According to him, his side has socialized and asked for advice to business actors such as PT Perusahaan Gas Negara. PT Pertamina Gas, Indonesia Natural Gas Trader Association (INGTA), and other gas user associations.

In the revised draft of Regulation of Minister of Energy and Mineral Resources no. 19/2009, stated that the government will guarantee the gas traders get the appropriate IRR, which is about 11%. The amount of IRR is expected to attract the interest of gas trading business to participate in gas pipeline infrastructure.

In addition to IRR, the government will also set a 7% commercial gas margin. The new formula of gas delivery tariff through pipes will also be regulated in the rules. Other components that are included in the regulation are the economic life of existing distribution pipelines and new pipes for 15 years.

In addition, the volume of gas used in accordance with the allocation or 60% of the initial design capacity of the larger distribution pipeline. Meanwhile, on the calculation of commercial margin will be set at approximately 7% of the price of gas in the upstream.

The 7% assumption also includes commodity management costs, marketing costs, and customer management, risk costs, and trade margins. When gas distribution through two business entities has a gas pipeline to reach the final consumer, the commercial margin of 7% is shared for the two business entities.

This formula has actually existed since the meeting of the Ministry of Energy and Mineral Resources held in March 2017. Additional in the draft of the draft Regulation of the Minister of Energy and Mineral Resources, the government prepares sanctions in the form of two written warnings, written termination as well as revocation of business license and cancellation of allocation and utilization of gas.

Sanctions are granted if the business actor violates all the provisions stipulated in the Regulation of the Minister of Energy and Mineral Resources on the price of the Downstream Gas. The impact of sanctions becomes a burden that also borne by business entities.

"It's all over. We asked for feedback [feedback] to all [business actors] he said, (31/7).

He considered that the enactment of the regulation will make the activities in the downstream sector of gas more efficient. However, he hopes that the regulation can support the development of gas pipelines.

"We actually support the infrastructure built with the Ministerial Regulation. That's our hope. In addition to guaranteed rate of return it Construction of the pipe, there is also a regulated margin, "he said.

DIFFICULTALLY SURPRISED

Meanwhile, the Indonesian Natural Gas Association (INGTA) previously conveyed the association's official stance that Determination of the determination of the margin makes the business in the downstream line of gas more difficult to survive. The reason is that the government reduced the contract period of gas sale and sale starting 2008.

Duration of the contract that was originally guaranteed for 10 years, gradually dropped to 5 years, 3 years and is now a provision of renewal every 1 year. In addition, 92.8% of the gas price is a component of upstream costs and gas transportation costs to be paid to gas producers and holders of gas transportation licenses.

Thus, about 7.2% is used for thin operating costs, investments, and margins, although not detailed in terms of division. Therefore, the proposed commercial margin is 10%.

Secretary of Directorate General of Oil and Gas Susyanto said that the draft regulation has not been signed by ESDM Minister Ignasius Jonan. However, the final draft is almost complete after absorbing the aspirations of related parties.

"It's almost done, being socialized with stakeholders," he said.

IN INDONESIA

Atas Margin Gas Segera Ditetapkan

Pemerintah masih meminta masukan dari pelaku usaha terkait dengan rencana pembatasan margin niaga gas dan tingkat pengembangan investasi sebelum diputuskan dalam bentuk regulasi.

Saat ini, pembahasan revisi Peraturan Menteri ESDM No. 1 9/2009 tentang Kegiatan Usaha Gas Bumi Melalui Pipa sudah masuk tahap final. aturan itu akan mengatur bisnis hilir gas, seperti margin dan tingkat pengembalian investasi (internal rate of return/IRR).

Wakil Menteri Energi dan Sumber Daya Mineral (ESDM) Arcandra Tahar mengatakan, aturan pembatasan margin dan pengembalian modal untuk pipa transmisi dan distribusi gas telah memasuki tahap akhir. Menurutnya, pihaknya telah melakukan sosialiasasi dan meminta saran kepada pelaku usaha seperti PT Perusahaan Gas Negara. PT Pertamina Gas, Indonesia Natural Gas Trader Association (INGTA), dan asosiasi pengguna gas Iainnya.

Dalam draf revisi Peraturan Menteri ESDM No. 19/2009, disebutkan bahwa pemerintah akan menjamin pedagang gas mendapat IRR yang sesuai, yakni sekitar 11%. Besaran IRR itu diharapkan mampu menarik minat pelaku usaha niaga gas untuk turut serta dalam infrastruktur pipa gas.

Selain IRR, pemerintah pun akan menetapkan margin niaga gas sekitar 7%. Formula baru tarif penghantaran gas melalui pipa juga akan diatur dalam aturan itu. Komponen lain yang turut diatur dalam aturan tersebut yakni umur keekonomian pipa distribusi yang sudah ada dan pipa baru selama 15 tahun.

Selain itu, volume gas yang digunakan sesuai dengan alokasi atau 60% dari kapasitas desain awal pipa distribusi yang lebih besar. Sementara itu, pada perhitungan margin niaga akan ditetapkan kurang lebih 7% dari harga gas di hulu.

Asumsi 7% itu pun telah mencakup biaya pengelolaan komoditas, biaya pemasaran, dan pengelolaan pelanggan, biaya risiko, dan margin niaga. Bila penyaluran gas melalui dua badan usaha berfasilitas (memiliki pipa gas) untuk mencapai konsumen akhir, margin niaga sebesar 7% dibagi untuk dua badan usaha tersebut.

Formula ini sebenarnya sudah ada sejak rapat Kementerian ESDM yang digelar pada Maret 2017. Tambahan dalam materi draf Peraturan Menteri ESDM tersebut yakni pemerintah menyiapkan sanksi berupa dua kali peringatan tertulis, penghentian tertulis juga pencabutan izin usaha serta pembatalan penetapan alokasi dan pemanfaatan gas.

Sanksi diberikan bila pelaku usaha melanggar semua ketentuan yang diatur dalam Peraturan Menteri ESDM tentang Harga Gas Hilir itu. Dampak pemberian sanksi pun menjadi beban yang turut ditanggung badan usaha.

“Sudah sampai akhir. Tadi kila minta feedback [umpan balik] kepada semua [pelaku usaha] ujarnya, (31/7). 

Dia menilai dengan pemberlakuan regulasi tersebut akan membuat kegiatan di sektor hilir gas lebih efisien. Namun, dia berharap agar regulasi itu mampu mendukung pembangunan pipa gas. 

“Kita justru mendukung infrastruktur terbangun dengan Peraturan Menteri itu. Itu harapan kita. Selain dijamin Rate of return-nya pembangunan pipanya, juga ada margin yang diatur,” katanya.

SULIT BERTAHAN

Sementara itu, Indonesian Natural Gas Association (INGTA) sebelumnya menyampaikan sikap resmi asosiasi itu bahwa penetapan penetapan margin tersebut membuat pelaku usaha di lini hilir gas semakin sulit bertahan. Pasalnya, Pemerintah mereduksi masa kontrak jual beli gas mulai 2008.

Durasi kontrak yang semula dijamin selama 10 tahun, berangsur turun menjadi 5 tahun, 3 tahun dan kini menjadi ketentuan pembaruan setiap 1 tahun sekali. Selain itu, 92,8% dari harga gas merupakan komponen biaya di hulu dan biaya transportasi gas yang harus dibayar ke produsen gas serta pemegang izin transportasi gas.

Dengan demikian, sekitar 7,2% digunakan untuk biaya operasi, investasi, dan margin yang tipis kendati tidak dijelaskan secara rinci pembagiannya. Oleh karena itu, margin niaga yang diusulkan sebesar 10%.

Sekretaris Direktorat Jenderal Minyak dan Gas Bumi Susyanto mengatakan, saat ini draf aturan tersebut belum diteken Menteri ESDM Ignasius Jonan. Namun, draf final hampir selesai setelah menyerap aspirasi pihak terkait.

“Sudah hampir selesai, sedang disosialisasikan dengan stakeholders," katanya.

Bisnis Indonesia, Page-32, Wednesday, August 2, 2017