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

Projected Oil Price Trimmed

Although heating up to US $ 50 per barrel, oil prices are still vulnerable to a correction in line with the projected increase in the production of the Organization of the Petroleum Exporting Countries (OPEC) in July 2017. Even analysts revised down the 2017 oil price projection target.

On Tuesday's trading at 17.05 GMT, the price of West Texas Intermediate (WTI) oil contracted in September 2017 rose 0.16% or 0.08 points to US $ 50.2S per barrel. The October 2017 Brent oil price fell 0.04% or -0.02 points to US $ 52.71 per barrel.

CMC Markets analyst Ric Spooner said crude prices are heating up in the near future due to the projected loss of weekly US inventories. Suevei Bloomberg said stockpiles of oil inventories ended Friday at 3.3 million barrels. Official data from U.S. data The Energy Information Administration (EIA) will be released Wednesday (2/8). Throughout June 2017, US stocks have fallen 26 million barrels. The recent decline in US inventory levels is quite constructive and the market responds, "he said as quoted by Bloomberg on Tuesday (1/8).

Nevertheless, now the price rally has moved into an area at risk of correction. Meanwhile, the volume of shale oil supply will be one key to the sustainability of price growth.

According to him, oil prices are also supported by OPEC's plan to reduce export volume. Saudi Arabia will reduce oil shipments abroad by 1 million barrels to about 6.6 million barrels starting in August 2017. Nigeria also reduced exports when it reached production capacity of 1.8 million barrels per day (bpd). In June 2017, the country pumped 1.75 million bpd of oil.

Spooner added that the market is also concerned with the agenda of the discovery of several OPEC and non-OPEC countries in the United Arab Emirates on 7-8 August 2017. Both sides will discuss the commitment to reduce production. OPEC and non-OPEC earlier agreed to cut production by 1.8 million bpd in January 2017-March 2018. However, the new supply-reduction volume has yet to reach the 100% target.

According to a Reuters survey involving a number of oil companies and consultants, OPEC production volume actually increased to 33 million bpd last month which was the highest level in 2017. This figure exceeded the target organizations that seek new supply to the level of 32.5 million bpd, in accordance with the agreement with Non-OPEC. 

     The largest increase in OPEC production comes from Libya that spur supply to exceed 1 million bpd, compared with the previous month at 840,000 bpd. Other members such as Iraq, the United Arab Emirates, Gabon and Ecuador are also pumping more oil.

REVISED DOWN

In another Reuters survey involving 33 analysts and economists, the average projected WTI oil price in 2017 was revised to US $ 0.08 per barrel and Brent headed for US $ 52.4S per barrel. This figure is down from the projection in June 2017 amounting to US $ 51.92 per barrel and U $ 53.96 per barrel respectively.

Interfu's senior energy analyst Global Gas Analytics analyst Abhishek Kimiar said the slump in analysts' projections was due to concerns about trimming OPEC and non-OPEC oil production cuts. When production peaked in July 2017, market attitudes were increasingly skeptical of the agreement.

Citing data from the International Energy Agency (IEA), OPEC production cuts in June 2017 fell to 78 percent from 95 percent the previous month. Countries that do the most cuts are Saudi Arabia, Angola, and Kuwait.

Negative sentiment also came from Ecuador withdrawing from production cuts. However, the impact on the market is not large enough. Thomson Reuters Oil Research and Forecast analyst Giorgios Beleris said negative sentiment from Ecuador was quickly tackled as Saudi Arabia pledged to cut exports. Other countries such as Nigeria and Kuwait are also ready to reduce the volume of overseas shipments of oil.

IN INDONESIA

Proyeksi Harga Minyak Dipangkas

Meski kembali memanas ke level US$ 50 per barel, harga minyak masih rentan koreksi seiring dengan proyeksi meningkatnya produksi Organization ot the Petroleum Exporting Countries (OPEC) pada Juli 2017. Bahkan kalangan analis merevisi turun target proyeksi harga minyak 2017.

Pada perdagangan Selasa (1/8) pukul 17.05 WIB, harga minyak West Texas Intermediate (WTI) kontrak September 2017 naik 0,16% atau 0,08 poin menuju US$50,2S per barel. Adapun harga minyak Brent kontrak Oktober 2017 turun 0.04% atau -0,02 poin menjadi US$52,71 per barel.

Analis CMC Markets Ric Spooner menyampaikan harga minyak mentah memanas dalam waktu dekat akibat proyeksi berkurangnya persediaan mingguan Amerika Serikat. Suevei Bloomberg mengungkapkan persediaan stok minyak yang berakhir Jumat (28/7) turun 3,3 juta barel. Data resmi dari data U.S. Energy Information Administration (EIA) akan dirilis Rabu (2/8).

     Sepanjang Juni 2017, stok AS sudah turun 26 juta barel. Tingkat penurunan persediaan AS akhir-akhir ini cukup konstruktif dan pasar merespons itu,” paparnya seperti dikutip dan Bloomberg, Selasa (1/8).

Namun demikian, kini reli harga sudah bergerak ke area yang berisiko mengalami koreksi. Adapun, volume pasokan minyak shale akan menjadi salah satu kunci keberlanjutan pertumbuhan harga.

Menurutnya, harga minyak juga ditopang rencana OPEC mengurangi volume ekspor. Arab Saudi akan mengurangi pengapalan minyak ke luar negeri sebesar 1 juta barel menjadi sekitar 6.6 juta barel mulai Agustus 2017. Nigeria turut mengurangi ekspor ketika sudah mencapai kapasitas produksi sebesar 1,8 juta barel per hari (bph). Adapun pada Juni 2017, negara tersebut memompa minyak sejumlah 1,75 juta bph.

Spooner menambahkan, pasar juga memperhatikan agenda penemuan beberapa negara OPEC dan non-OPEC di Uni Emirat Arab pada 7-8 Agustus 2017. Kedua pihak akan membahas komitmen untuk mengurangi produksi. OPEC dan non-OPEC sebelumnya sepakat memangkas produksi sebesar 1,8 juta bph pada Januari 2017-Maret 2018. Namun, volume pengurangan suplai baru belum mencapai target 100%.

Menurut survei Reuters yang melibatkan sejumlah perusahaan minyak dan konsultan, volume produksi OPEC justru meningkat menjadi 33 juta bph pada bulan lalu yang menjadi level tertinggi sepanjang 2017. Angka ini melampaui target organisasi yang mengupayakan suplai baru ke level 32,5 juta bph, sesuai kesepakatan dengan non-OPEC. 

     Kenaikan produksi OPEC paling besar berasal dari Libya yang memacu suplai hingga melampaui 1 juta bph, dibandingkan dengan bulan sebelumnya di kisaran 840.000 bph. Anggota lain seperti Irak, Uni Emirat Arab, Gabon, dan Ekuador juga memompa lebih banyak minyak.

REVISI TURUN

Dalam survei Reuters lainnya yang melibatkan 33 analis dan ekonom, proyeksi rerata harga minyak WTI pada 2017 direvisi menjadi US$ 0,08 per barel dan Brent menuju US$ 52,4S per barel. Angka ini turun dari proyeksi pada Juni 2017 masing-masing senilai US$ 51,92 per barel dan U$ 53,96 per barel.

Senior energy analyst Interfax Energy’s Global Gas Analytics Abhishek Kimiar menyampaikan, merosotnya proyeksi analis disebabkan kekhawatiran menganai kepatuhan pemangkasan produksi minyak OPEC dan non-OPEC. Ketika produksi memuncak pada Juli 2017, sikap pasar semakin skeptis dengan perjanjian tersebut.

Mengutip data International Energy Agency (IEA), kepatuhan pemangkasan produksi OPEC pada Juni 2017 turun menjadi 78% dari bulan sebelumnya sebesar 95%. Negara yang melakukan pemangkasan paling banyak ialah Arab Saudi, Angola, dan Kuwait.

Sentimen negatif juga datang dari Ekuador yang menarik diri dari perjanjian pemangkasan produksi. Namun, dampaknya terhadap pasar tidak cukup besar. Analis Thomson Reuters Oil Research and Forecast Giorgios Beleris mengatakan sentimen negatif dari Ekuador cepat tertanggulangi karena Arab Saudi berjanji memangkas ekspor. Negara lain seperti Nigeria dan Kuwait juga siap mengurangi volume pengapalan minyak ke luar negeri. 

Bisnis Indonesia, Page-16, Wednesday, August 2, 2017

ExxonMobil Must Review Production Increase

ExxonMobil said it still needs review before ensuring it can raise Cepu Block oil production to 300 thousand barrels per day (bpd).

During his trip to the United States, Energy and Mineral Resources Minister Ignatius Jonan was in the company of Senior Vice President of Exxon Mobil Corporation Mark W Albers. In the meeting it was said that Banyu Urip Field production, Cepu Block can be boosted to 300 thousand bpd from the current 200 thousand bpd. ExxonMobil responded positively by conducting a further field development potential.

"In terms of production of 300,000 bpd, we will evaluate the capacity of CPF (central processing facility) and existing wells," said Vice President of Public and Government Affairs of ExxonMobil Cepu Limited Erwin Maryoto. If realized, this is the second time the production of Cepu Block is ramped up.

As is known, initially Cepu Block is only targeted to produce oil of 185 thousand bpd. However, then at the insistence of Commission VII of the House of Representatives after considering the proposal of ExxonMobil, the production of this block was requested to be raised to an average of 200 thousand bpd.

But this increased production requires approval of a revised environmental impact assessment from the Ministry of Environment and Forestry. According to Erwin, his party has obtained the environmental permit and allowed to produce oil up to 220 thousand bpd higher than the target on the work plan and budget (WP & B) of 200 thousand bpd.

"Permission is up to 220 thousand bpd. Currently we are producing in the range of more than 200 thousand bpd, "he said.

Increased production to 200 thousand bpd does not require the addition of a significant tool. Because the production capacity of existing facilities can still be adjusted. Similarly, the floating production, storage, and ofiloading (FPSO) capacity of Rimang Crow, which is designed with the assumed peak of Cepu Block production of 185,000 bpd, is anticipated by oil pickup using larger tankers.

The Banyu Urip field is expected to generate 450 million barrels of oil during the project's operational life. In the last few decades, Banyu Urip Field is the largest oil project in Indonesia. Currently, the composition of shares in Cepu Block is ExxonMobil Cepu Limited as the operator owns 45% shares, PT Pertamina EP Cepu 45%, and four Regional Owned Enterprises 10%. The four BUMDs are PT Blora Patragas Hulu, PT Petrogas Jatim Utama Cendana, PT Asri Darma Sejahtera and PT Sarana Patra Hulu Cepu. Minister Jonan hopes that increased production can have a positive impact on Indonesia.

"With the increase in production, I hope to be able to give a double effect to the surrounding area through the development of national and local companies, opening up jobs to community development," he said.

In addition to discussing Cepu Block, Jonan also expects ExxonMobil to make the downstream sector as a new investment land in Indonesia. Some of the offered investments include opening a Public Filling Station (SPBU) or aromatic development in Indonesia. Currently, PT ExxonMobil Lubricants Indonesia (PT ELMI) representing ExxonMobil company has developed downstream and petrochemical sectors in Indonesia.

Encourage Investment

Not only ExxonMobil, Jonan also met with other oil and gas companies, ChevronConocoPhilips, Schlumberger, and Baker Hughes GE Company. Jonan asked the entire company to boost its investment in Indonesia. While visiting Chevron, Jonan was greeted by President Chevron North America Exploration and Production Jeff Shellebarger and President of Chevron Environmental Management Company Mary Boroughs.

The meeting discussed the development of deep-sea gas in Kutai Basin, East Kalimantan, known as Indonesia Deepwater Development (IDD). IDD's first project, Bangka Field, has been in production since August 2016. Meanwhile, Gendaho-Gehem Field is targeted to start production in 2022. The discussions are held together.

"One of them is to discuss the development of IDD and the cooperation of the use of facilities (Float Production Unit / FPU) Jangrik with Eni for gas from Gendalo-Gehem," he said. Jonan wants the IDD Project to begin immediately.

When meeting ConocoPhilips CEO Ryan Lance, Jonan discusses the continued management of the South Jambi B Block, whose contract expires in 2020. ConocoPhillips is requested to submit a block management proposal with the option of partnering with PT Pertamina or other companies. ConocoPhillips stated immediately submit a proposal after conducting internal discussions including discussing economic issues.

In a meeting with Schlumberger Venture Fund Senior Vice President of Schlumberger Limited Imran Kizilbash, Jonan obtained two bids to increase oil and gas exploration and production activities in Indonesia.

First, through multiclient surveys in areas approved by the Government especially in the eastern offshore and upstream oil and gas management data management. Schlumberger also has an investment program in oil and gas field development as has been done in Latin America amounting to US $ 4.6 billion.

Jonan also met President & CEO Baker Hughes, Lorenzo Simonelli. At the meeting, Baker Hughes offered technology for upstream oil and gas activities, among others, reduction of cost drilling by utilizing digital technology through IntelliStream solution, as well as some enhanced oil recovery (EOR) technology in several oil and gas fields in Indonesia.

In addition, GE also offers barge power plant technology with comprehensive solutions that include gas infrastructure for islands with low electrification ratios and participation in geothermal development in Indonesia.

IN INDONESIA

ExxonMobil Harus Kaji Peningkatan Produksi

ExxonMobil menyatakan masih perlu kajian sebelum memastikan dapat menaikkan produksi minyak Blok Cepu sampai 300 ribu barel per hari (bph).

Dalam lawatannya ke Amerika Serikat, Menteri Energi dan Sumber Daya Mineral (ESDM) Ignasius Jonan menemuni Senior Vice President Exxon Mobil Corporation Mark W Albers. Dalam pertemuan itu disampaikan bahwa produksi Lapangan Banyu Urip, Blok Cepu dapat digenjot menjadi 300 ribu bph dari saat ini 200 ribu bph. Pihak ExxonMobil merespon positif dengan segera melakukan kajian potensi pengembangan lapangan lebih lanjut.

“Terkait produksi 300 ribu bph, kami akan evaluasi kapasitas CPF (central processing facility) dan sumur-sumur yang ada dahulu,” kata Vice President Public and Government Affairs ExxonMobil Cepu Limited Erwin Maryoto. Jika terealisasi, maka ini kali kedua produksi Blok Cepu digenjot produksinya. 

Seperti diketahui, awalnya Blok Cepu hanya ditargetkan memproduksi minyak sebesar 185 ribu bph. Namun, kemudian atas desakan Komisi VII DPR RI setelah mempertimbangkan usulan ExxonMobil, produksi blok ini diminta dinaikkan menjadi rata-rata 200 ribu bph.

Tetapi peningkatan produksi ini membutuhkan persetujuan revisi analisis dampak lingkungan dari Kementerian Lingkungan Hidup dan Kehutanan. Menurut Erwin, pihaknya telah memperoleh izin lingkungan tersebut dan diperbolehkan memproduksi minyak hingga maksimal 220 ribu bph lebih tinggi dari target pada rencana keria dan anggaran (work plan and budget/WP&B) 200 ribu bph.

“Izinnya sampai dengan 220 ribu bph. Sekarang ini kami produksi di kisaran lebih dari 200 ribu bph," tutur dia. 

Peningkatan produksi sampai 200 ribu bph ini tidak membutuhkan penambahan alat yang cukup signifikan. Pasalnya, kapasitas produksi fasilitas yang ada masih dapat disesuaikan. Demikian juga kapasitas fasilitas produksi, penampungan, dan bongkar muat terapung (floating production, storage, and ofiloading/FPSO) Gagak Rimang yang didesain dengan asumsi puncak produksi Blok Cepu 185 ribu bph,sudah diantisipasi dengan pengambilan minyak menggunakan kapal tanker yang lebih besar.

Lapangan Banyu Urip diharapkan dapat menghasilkan 450 juta barel minyak selama masa operasi proyek. Dalam beberapa dekade terakhir, Lapangan Banyu Urip merupakan proyek minyak terbesar di Indonesia. Saat ini, komposisi saham di Blok Cepu adalah ExxonMobil Cepu Limited sebagai operator memiliki saham 45%, PT Pertamina EP Cepu 45%, serta empat Badan Usaha Milik Daerah 10%. Keempat BUMD itu yaitu PT Blora Patragas Hulu, PT Petrogas Jatim Utama Cendana, PT Asri Darma Sejahtera, dan PT Sarana Patra Hulu Cepu. Menteri Jonan berharap peningkatan produksi dapat memberi dampak positif bagi Indonesia. 

“Dengan peningkatan produksi, saya harap mampu memberikan efek ganda bagi daerah sekitar melalui pengembangan perusahaan nasional dan lokal, membuka lapangan pekerjaan hingga pengembangan masyarakat,” ujarnya.

Selain membahas Blok Cepu, Jonan juga mengharapkan ExxonMobil bisa menjadikan sektor hilir sebagai lahan investasi baru di Indonesia. Beberapa investasi yang ditawarkan seperti membuka Stasiun Pengisian Bahan Bakar Umum (SPBU) atau pengembangan aromatik di Indonesia. Saat ini, PT ExxonMobil Lubricants Indonesia (PT ELMI) mewakili perusahaan ExxonMobil telah mengembangkan sektor hilir dan petrokimia di Indonesia. 

Dorong Investasi

Tidak hanya ExxonMobil, Jonan juga menemui petinggi perusahaan migas lain, yakni ChevronConocoPhilips, Schlumberger, dan Baker Hughes GE Company. Jonan meminta seluruh perusahaan ini untuk mendongkrak investasinya di Indonesia. Ketika berkunjung ke Chevron, Jonan disambut President Chevron North America Exploration and Production Jeff Shellebarger dan President Chevron Environmental Management Company Mary Boroughs. 

Pertemuan ini membahas pengembangan gas laut dalam di Kutai Basin, Kalimantan Timur yang dikenal dengan Indonesia Deepwater Development (IDD). Proyek pertama IDD, yakni Lapangan Bangka, telah berproduksi sejak Agustus 2016. Sementara itu, Lapangan Gendaho-Gehem ditargetkan akan mulai produksi pada 2022. Diskusi dilakukan bersama.

“Salah satunya adalah membahas terkait perkembangan IDD dan kerjasama penggunaan fasilitas (Floating Production Unit/FPU) Jangrik dengan Eni untuk gas dari Gendalo-Gehem,” kata dia.  Jonan menginginkan Proyek IDD segera dimulai.

Saat bertemu CEO ConocoPhilips Ryan Lance, Jonan membahas kelanjutan pengelolaan Blok South Jambi B yang kontraknya akan habis pada tahun 2020. ConocoPhillips diminta segera mengajukan proposal pengelolaan blok tersebut dengan opsi berpartner dengan PT Pertamina atau perusahaan lainnya. ConocoPhillips menyatakan segera menyampaikan proposal setelah melakukan pembahasan internal termasuk membahas masalah keekonomian.

Dalam pertemuan dengan Senior Vice President Schlumberger Venture Fund Schlumberger Limited Imran Kizilbash, Jonan memperoleh dua tawaran dalam meningkatkan kegiatan eksplorasi dan produksi migas di Indonesia. 

Pertama, melalui multiclient survey di daerah yang disetujui oleh Pemerintah khususnya di daerah timur offshore dan manajemen pengelolaan data hulu migas. Kemudian, Schlumberger juga mempunyai program investasi dalam pengembangan lapangan migas seperti yang telah dilakukan di Amerika Latin sebesar US$ 4,6 miliar.

Jonan juga menemui President & CEO Baker Hughes, Lorenzo Simonelli. Pada pertemuan tersebut, Baker Hughes menawarkan teknologi untuk kegiatan hulu migas antara lain pengurangan cost drilling dengan memanfatkan teknologi digital melalui solusi IntelliStream, serta beberapa teknologi enhanced oil recovery (EOR) pada beberapa lapangan migas di Indonesia. 

Di samping itu, GE juga menawarkan teknologi barge power plant dengan solusi komprehensif yang meliputi infrastruktur gas untuk pulau-pulau dengan rasio elektrifikasi yang masih rendah dan keikutsertaan dalam pengembangan panas bumi di Indonesia.

Investor Daily, Page-48, Monday, August 1, 2017