Cost Recovery Pressed

The government targets the cost recovery of upstream oil and gas business activities in 2018 to be reduced to US $ 1.39 billion with various efficiency and optimization efforts. The assumption of cost recovery in 2018 without any efficiency efforts is targeted at US $ 13.28 billion.

Secretary of Special Unit for Upstream Oil and Gas Upstream Activities (SKK Migas) Arief Handoko said that the target cost recovery in 2018 is an assumption of efficiency from the initial calculation of US $ 13.29 billion.

According to him, the adjustment of cost recovery figures in accordance with the proposal of the Minister of Energy and Mineral Resources (ESDM) Ignasius Jonan to Finance Minister Sri Mulyani Indrawati.

In the proposal, an assumption was made based on 2017 performance and upstream oil and gas projects that will operate for the next 5 years. Initial assumption, cost recovery in 2019 reached US $ 1 2.49 billion, in 2020 of US $ 12.09 billion, in 2021 of US $ 12.44 billion and became US $ 12.18 billion in 2022. However, the government targeted the realization cost recovery is lower than that assumption through efficiency and optimization efforts.

The government targets cost recovery in 2019 (US $ 10.82 billion), 2020 (US $ 10.28 billion), 2021 (US $ 9.76 billion), and in 2022 (US $ 9.28 billion).

Based on data from SKK Migas, cost recovery until August 2017 was realized US $ 7.22 billion. Meanwhile, the government's share of US $ 8.14 billion and contractor's share of US $ 2.87 billion. The government targets oil and gas revenues in 2018 of US $ 10.95 billion when cost recovery is assumed to be US $ 11.39 billion and contractor portion of US $ 3.9 billion resulting in gross revenue of US $ 26.25 billion with Indonesian crude oil price price / ICP] US $ 48 per barrel.

This figure is in accordance with Letter of Minister of Energy and Mineral Resources to the Minister of Finance in February 2017, namely the number of cost recovery optimization, "he said.

TWO ASSUMPTIONS

In the proposal on 14 February 2017, the Ministry of Energy and Mineral Resources made the assumption of oil and gas lifting made two versions, namely moderate and optimistic. Moderate assumptions in 2018, oil lifting of 771,000 barrels per day (bpd) and gas 1.19 million barrels of oil equivalent per day (barrel oil equivalent per day / boepd). Oil assumption in 2019 fell to 722,000 bpd and gas rose to 1.21 million boepd.

By 2020, the moderate oil lifting assumption touches 695,000 bpd and gas 1.19 million boepd. Oil lifting assumptions continue to fall in 2021 and 2022 with 651,000 bpd and 589,000 bpd respectively.

Unlike oil, in 2021 and 2022 the assumption of lifting gas actually rose to 1.23 million boepd and 1.25 million boepd. Meanwhile, the optimistic assumption in 2018, target lifting 815,000 bph. Then, the figure rose to 850,000 bpd in 2019 and again fell in 2020, 2021, and 2022 respectively 840,000 bp, 802,000 bpd, and 800,000 bpd.

In addition to performance factors in 2017, next year's cost recovery target calculates the additional cost of depreciation expense from the new project. Two projects that contribute to cost recovery next year include the Jangkrik Iapangan, which operates in mid-2017 and Block A, Aceh, operating in early 2018.

"The magnitude of cost recovery in 2018 takes into account the performance of 2017, coupled with the burden of depreciation costs incremented with onstreamnya [operations] of Jangkrik Field and Block A in Aceh," he said.

Earlier, Head of SKK Migas Amien Sunaryadi said the addition of cost recovery realization this year will happen at the end of the year so that it must keep its achievement not exceed the target of US $ 10.49 billion. With the largest composition, ie 48% comes from operating costs. It also seeks to make operating costs more efficient.

Nevertheless, he mentioned that there is a potential for additional cost recovery by the end of the year as capital expenditures usually grow by the end of the year.

By the end of this year, the biggest increase comes from the Mahakam Block (Total E & P Indonesie) in East Kalimantan which ends this year's contract of around US $ 900 million and Muara Bakau Block (Eni Muara Bakau BV) in East Kalimantan waters because the field is already in production.

"At the end of the year it will be approximately from Mahakam block because all Mahakam expenditure [expenditure] issued by Total will be charged at the end of the year according to PSC contract termination. The number is also large from Cricket Field because it has started onstream, then the field Cricket began to be entitled to charge depreciation this year, "said Amien.

IN INDONESIA

Cost Recovery Ditekan

Pemerintah menargetkan pengembalian biaya operasi (cost recovery) kegiatan usaha hulu minyak dan gas bumi pada 2018 dapat ditekan menjadi US$1 1,39 miliar dengan berbagai upaya efisiensi dan optimalisasi. Asumsi cost recovery pada 2018 tanpa ada upaya efisiensi ditargetkan sebesar US$13,28 miliar.

Sekretaris Satuan Kerja Khusus Pelaksana Kegiatan Usaha Hulu Minyak dan Gas Bumi (SKK Migas) Arief Handoko mengatakan bahwa target cost recovery pada 2018 tersebut merupakan asumsi efisiensi dari perhitungan awal sebesar US$13,29 miliar.

Menurutnya, penyesuaian angka cost recovery sesuai dengan usulan Menteri Energi dan Sumber Daya Mineral (ESDM) Ignasius Jonan kepada Menteri Keuangan Sri Mulyani Indrawati.

Dalam usulan itu telah ditetapkan asumsi yang dibuat berdasarkan kinerja 2017 dan proyek hulu migas yang akan beroperasi hingga 5 tahun ke depan. Asumsi awal, cost recovery pada 2019 mencapai US$1 2,49 miliar, pada 2020 sebesar US$ 12,09 miliar, pada 2021 sebesar US$ 12,44 miliar dan menjadi US$ 12,18 miliar pada 2022. Namun, pemerintah menargetkan realisasi cost recovery lebih rendah dari asumsi tersebut melalui berbagai upaya efisiensi dan optimalisasi.

Pemerintah menargetkan cost recovery pada 2019 (US$ 10,82 miliar), 2020 (US$ 10,28 miliar), 2021 (US$ 9,76 miliar), dan pada 2022 (US$ 9,28 miliar).

Berdasarkan data SKK Migas, cost recovery hingga Agustus 2017 terealisasi US$ 7,22 miliar. Sementara itu, bagi hasil pemerintah sebesar US$ 8,14 miliar dan bagi hasil kontraktor sebesar US$ 2,87 miliar. Pemerintah menargetkan pendapatan migas pada 2018 sebesar US$ 10,95 miliar ketika cost recovery diasumsikan US$ 11 ,39 miliar dan bagian kontraktor US$ 3,9 miliar sehingga pendapatan kotor sebesar US$ 26,25 miliar dengan harga minyak mentah Indonesia [Indonesian crude price/ICP] US$48 per barel.

Angka ini sesuai dengan Surat Menteri ESDM ke Menteri Keuangan pada Februari 2017, yakni angka optimalisasi cost recovery,” ujarnya. 

DUA ASUMSI 

Dalam usulan pada 14 Februari 2017 itu, Kementerian ESDM membuat asumsi lifting migas dibuat dua versi, yakni moderat dan optimistis. Asumsi moderat pada 2018, lifting minyak sebesar 771.000 barel per hari (bph) dan gas 1,19 juta barel setara minyak per hari (barrel oil equivalent per day/boepd). Asumsi minyak pada 2019 turun menjadi 722.000 bph dan gas justru naik menjadi 1,21 juta boepd.

Pada 2020, asumsi moderat lifting minyak menyentuh 695.000 bph dan gas 1,19 juta boepd. Asumsi lifting minyak terus turun pada 2021 dan 2022 dengan angka 651.000 bph dan 589.000 bph secara berturut-turut.

Berbeda dengan minyak, pada 2021 dan 2022 asumsi lifting gas justru naik menjadi 1,23 juta boepd dan 1,25 juta boepd. Sementara itu, asumsi optimistis pada 2018, target lifting 815.000 bph. Kemudian, angkanya naik menjadi 850.000 bph pada 2019 dan kembali turun pada 2020, 2021, dan 2022 berturut-turut 840.000 bph, 802.000 bph, dan 800.000 bph.

Selain faktor kinerja pada 2017, target cost recovery tahun depan menghitung penambahan beban biaya depresiasi dari proyek baru. Dua proyek yang berkontribusi menambah cost recovery pada tahun depan, yakni Iapangan Jangkrik yang beroperasi pada medio 2017 dan Blok A, Aceh yang beroperasi awal 2018.

“Besaran cost recovery pada 2018 memperhitungkan performance 2017, ditambah adanya beban biaya depresiasi yang bertambah dengan onstreamnya [beroperasinya] Lapangan Jangkrik dan Blok A di Aceh,” katanya.

Sebelumnya, Kepala SKK Migas Amien Sunaryadi mengatakan penambahan realisasi cost recovery pada tahun ini akan terjadi pada akhir tahun sehingga pihaknya harus menjaga agar pencapaiannya tidak melampaui target US$ 10,49 miliar. Dengan komposisi terbesar, yakni 48% berasal dari biaya operasi. Pihaknya pun berupaya agar biaya operasi bisa lebih efisien.

Kendati demikian, dia menyebut terdapat potensi penambahan cost recovery pada akhir tahun karena biasanya belanja modal benambah menjelang penghujung tahun.

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

Mahakam Block-East Kalimantan

“Pada akhir tahun nanti kira-kira dari Blok Mahakam karena memang semua expenditure [belanja] Mahakam yang dikeluarkan Total akan dibebankan pada akhir tahun sesuai berakhirnya kontrak PSC. Yang jumlahnya cukup besar juga dari Lapangan Jangkrik karena sudah mulai onstream, maka lapangan Jangkrik mulai berhak untuk membebankan depresiasi tahun ini,” kata Amien. 

Bisnis Indonesia, Page-28, Thursday, Sept 14, 2017

Domestic Gas Consumption Continues to Rise

Utilization of natural gas to meet domestic demand continues to increase since 2013. Rising demand for domestic gas and the decline in the commitment of export gas distribution to cause the increase in gas utilization in Indonesia. Since 2013-2015, domestic gas utilization growth is 9%.

From the data of SKK Migas as of June 2017, the trend of gas exports is now lower compared to 2010 and 2011. In 2010, the export proportion is still 4.336 billion British. thermal unit per day (BBtud) and domestic 3,379 BBtud. In 2011, although the total volume of distribution is smaller, the export share is still dominant, which is 4,078 BBtud and domestic 3,276 BBtud. In 2012, the export and domestic exports are narrowed by 81 Bbtud with export details of 3,631 BBtud and domestic 3,550 BBtud.

The share of gas utilization for domestic needs is greater than that of export starting in 2013, namely domestic 3,703 BBtud and export 3,402 BBtud.

Head of Program and Communications Division SKK Migas Wisnu Prabawa Taher said that the increasing trend of domestic gas utilization is influenced by the development of gas infrastructure and new gas field.

"Some things that increase domestic usage include the building of new gas infrastructure facilities such as regasification terminal Nusantara Regas, onstream of several new gas fields," he said.

From the consumer side, pipe gas users are dominated by industrial sector and electricity.

"The largest domestic gas pipeline users are industrial consumers, followed by electricity, especially PLN and its subsidiaries."

Meanwhile, Head of SKK Migas Amien Sunaryadi considered that information technology has changed the pattern of working relationships and changes in business paradigm significant. Slowly start more and more companies that stood and established with based on information technology as a platform in business development.

He explained that the challenges in the application of technology are not only relevant for profit-oriented organizations. However, it also applies to SKK Migas and or upstream oil and gas industry in general.

"The technology is also used to improve the efficiency of time and cost, which in turn will affect how much revenue for the country," he said when opening the Indonesia HR Summit 2017 in Yogyakarta earlier this week.

He added, efficiency and effectiveness in the digital era is a process that continues to be studied and conducted studies.

"By maximizing the role of information technology is expected to optimize performance both in SKK Migas and in terms of supervision and control activities to contractors cooperation contracts."

The independent statistics agency in the United States, Statista, reveals the most publicly valuable shift of the company in the period 2006 and 2016. In 2006 of six world-class companies there were three major oil and gas companies, ExxonMobil at number 1, and BP and Royal Dutch Shell at ranks 5 and 6. Meanwhile, General Electric, Microsoft, and Citigroup are ranked 2 to 4.

IN INDONESIA

Konsumsi Gas Domestik Terus Naik

Pemanfaatan gas bumi untuk memenuhi kebutuhan dalam negeri terus naik sejak 2013. Naiknya permintaan gas dalam negeri dan menurunnya komitmen penyaluran gas ekspor menjadi penyebab naiknya pemanfaatan gas di Indonesia. Sejak 2013-2015, pertumbuhan pemanfaatan gas domestik sebesar 9%.

Dari data SKK Migas per Juni 2017, tren ekspor gas kini lebih rendah dibandingkan dengan 2010 dan 2011. Pada 2010, proporsi ekspor masih 4.336 billion British. thermal unit per day (BBtud) dan domestik sebesar 3.379 BBtud. Pada 2011, kendati volume total penyalurannya lebih kecil, bagian ekspor masih dominan , yaitu 4.078 BBtud dan domestik 3.276 BBtud. Pada 2012, selisih porsi ekspor dan domestik semakin tipis, yakni hanya sebesar 81 Bbtud dengan rincian ekspor sebesar 3.631 BBtud dan domestik 3.550 BBtud.

Porsi pemanfaatan gas untuk kebutuhan domestik lebih besar dibandingkan ekspor mulai terjadi pada 2013, yaitu domestik 3.703 BBtud dan ekspor 3.402 BBtud.

Kepala Divisi Program dan Komunikasi SKK Migas Wisnu Prabawa Taher mengatakan bahwa tren peningkatan pemanfaatan gas domestik dipengaruhi oleh terbangunnya infrastruktur gas dan lapangan gas baru. 

“Beberapa hal yang meningkatkan pemakaian domestik antara lain terbangunnya fasilitas infrastruktur gas baru seperti terminal regasifikasi Nusantara Regas, onstream-nya beberapa lapangan gas baru,” ujarnya.

Dari sisi konsumen, pemakai gas pipa didominasi sektor industri dan ketenagalistrikan.

“Pemakai gas pipa domestik terbesar adalah konsumen industri yang kemudian diikuti oleh kelistrikan terutama PLN dan anak perusahaannya.”

Sementara itu, Kepala SKK Migas Amien Sunaryadi menilai bahwa teknologi informasi telah mengubah pola hubungan kerja dan perubahan paradigma bisnis yang signifikan. Secara perlahan mulai hanyak perusahaan yang berdiri dan didirikan dengan berbasiskan teknologi informasi sebagai platform dalam pengembangan bisnis.

Dia menjelaskan bahwa tantangan dalam penerapan teknologi tidak hanya relevan bagi organisasi yang berorientasi profit. Namun, juga berlaku bagi SKK Migas dan atau industri hulu migas pada umumnya.

“Teknologi juga digunakan untuk meningkatkan efisiensi waktu dan biaya, yang pada akhirnya akan memengaruhi seberapa besar penerimaan bagi negara,” katanya saat membuka Indonesia HR Summit 2017 di Yogyakarta awal pekan ini.

Dia menambahkan, efisiensi dan efektivitas di era digital merupakan suatu proses yang terus dipelajari dan dilakukan kajian. 

“Dengan memaksimalkan peran teknologi informasi diharapkan dapat mengoptimalkan kinerja baik di SKK Migas maupun dalam hal kegiatan pengawasan dan pengendalian kepada kontraktor kontrak kerja sama.”

Lembaga survei independen di Amerika Serikat, Statista, mengungkap adanya pergeseran perusahaan yang paling bernilai secara publik dalam periode 2006 dan 2016. Pada 2006 dari enam perusahaan kelas dunia terdapat tiga perusahaan migas besar, yakni ExxonMobil pada peringkat 1, serta BP dan Royal Dutch Shell di peringkat 5 dan 6. Sementara itu, General Electric, Microsoft, dan Citigroup berada di peringkat 2 hingga 4.

Bisnis Indonesia, Page-28, Thursday, Sept 14, 2017

Oil and Gas BPH Charges Industrial Engineering Commitment

Oil and Gas Downstream Regulatory Agency. (BPH Migas) noted that there are still two pipagas projects that have not been built yet. Both projects are the Cirebon -Semarang pipeline project assigned to PT Rekayasa Industri and the Kalija II gas pipeline project assigned to PT Bakrie Brothers Tbk.

Specifically for the Cirebon - Semarang gas pipeline project, Head of BPH Migas Fanshurullah Asa said it would meet with Industrial Engineering to discuss the completion of the project

"Industrial Engineering sent a letter to BPH Migas on September 18, 2017 and requested time for presentation of the progress of the Cirebon-Semarang pipeline builder," he said.

Previously, BPH Migas had summoned the Engineering Industry on July 6, 2017 to present the development of the 255 kilometer-long Cirebon-Semarang transmission pipeline with an investment of US $ 400 million.

As a result, Industrial Engineering has not yet realized the construction of Cirebon - Semarang transmission pipeline, due to gas supply constraints and buyers. The project stopped for almost 11 years.

Head of Marketing and Product Development Division of PT Perusahaan Gas Negara Tbk Adi Munandir revealed that Indonesia has not yet masterplan gas infrastructure development. Though the master plan is needed to implement the planning, ranging from gas production, gas development, to the industry to be built.

IN INDONESIA

BPH migas Menagih Komitmen Rekayasa Industri

Badan Pengatur Hilir Minyak dan Gas. (BPH Migas) mencatat, masih ada dua proyek pipagas yang hingga saat ini belum juga dibangun. Kedua proyek tersebut adalah proyek pipa Cirebon -Semarang yang ditugaskan kepada PT Rekayasa Industri dan proyek pipa gas Kalija II yang ditugaskan kepada PT Bakrie Brothers Tbk. 

Khusus proyek pipa gas ruas Cirebon - Semarang, Kepala BPH Migas Fanshurullah Asa mengatakan, pihaknya akan bertemu dengan Rekayasa Industri untuk membahas penyelesaian proyek   

"Rekayasa Industri mengirim Surat ke BPH Migas tanggal 18 September 2017 dan meminta waktu untuk presentasi progres pembangun pipa Cirebon-Semarang," katanya.

Sebelumnya, BPH Migas telah memanggil Rekayasa Industri pada 6 Juli 2017 lalu untuk mempresentasikan perkembangan pembangunan ruas pipa transmisi Cirebon-Semarang sepanjang 255 kilometer dengan nilai investasi US$ 400 juta.

Hasilnya, Rekayasa Industri sampai saat ini belum juga merealisasikan pembangunan pipa mas transmisi Cirebon - Semarang, karena kendala pasokan gas dan pembeli. Proyek ini berhenti selama hampir 11 tahun.

Head of Marketing and Product Development Division PT Perusahaan Gas Negara Tbk Adi Munandir mengungkapkan, Indonesia hingga saat ini belum juga memiliki masterplan pembangunan infrastruktur gas. Padahal masterplan diperlukan untuk mengimplementasikan perencanaan, mulai dari produksi gas, pengembangan gas, hingga industri yang akan dibangun.

Kontan, Page-18, Thursday, Sept 14, 2017

Shares of Mahakam Block Removable Maximally 39%

The government will send a letter to PT Pertamina which revised the maximum limit of Mahakam Block share participation share up to 39%. Previously, the maximum limit of shares that could be released only 30%.

Deputy Minister of Energy and Mineral Resources (ESDM) Arcandra Tahar said that despite rejecting all incentives request, it opens the opportunity for Total E & P Indonesie to have a maximum participation of 39% in Mahakam Block. To that end, his side immediately sent a letter revising the limit of shares that can be released Pertamina from 30% to 39%.

"As per the direction of the Minister of Energy and Mineral Resources Ignasius Jonan, may share down to 39%. Up is a letter we are preparing, "he said in Jakarta.

However, the existence of this letter does not mean that Pertamina should release 39%. The decision concerning the amount of participation rights that turned to Total, will remain based on Pertamina's business negotiations with the French oil and gas company.

"Everything is B to B (business to business). Total ask may not be up to 39%, later B to B with Pertamina, how much and how many shares, "explained Arcandra.

Previously, he said Total E & P Indonesie sent a letter expressing interest in buying 39% stake in the Mahakam Block. This 39% share is a joint for Total (France) and Inpex Corporation (Japan) which each have a 19.5% share, if the proposal is approved. Although Pertamina does not mind as an operator, Total does not want Mahakam Block shares if it is below 39%.

Together with the letter, Total also put forward a number of incentives. These three incentives are investment credit of 17%, acceleration of depreciation to two years only and the production part to be set aside before the cost (First Tranche Petroleum / FTP) 0%. All these incentives have been rejected by the government.

Upstream Director of Pertamina Syamsu Alam said, related to the change in the maximum share down of the Mahakam Block's participation rights have been discussed with his side. It will follow the government's direction on this matter.

"Regarding the amount of PI (participating interest) that can be shared down, of course we will refer to the regulator or the government," he said.

About stock negotiations with Total E & P Indonesia, Syamsu once revealed, there is no time limit. However, it hopes a deal on the acquisition of these shares can be achieved before Pertamina's contract in the Mahakam Block is effective on January 1, 2018.

"Let the January 1, 2018 is clear," said Alam.

Pertamina has drilled three wells in the Mahakam Block. This drilling is done by Total E & P Indonesie, but with funds from Pertamina. The plan, Pertamina will drill 14-15 wells in the Mahakam block this year. Further oil and gas production from these new wells will begin to flow next year.

"He opened the well on January 1, 2018," said Syamsu Alam.

Previously, it was known that Pertamina had signed a new Mahakam Bloc contract starting from 1 January 2018 at the end of 2015. Under the contract, the company promised a signature bonus of US $ 41 million. In addition, state revenues from production bonuses include US $ 5 million from a cumulative production of 500 million barrels of oil equivalent, of US $ 4 million from a cumulative production of 750 million barrels of oil equivalent, and US $ 4 million from a cumulative production of 1,000 million barrels of oil equivalent.

As for the first three-year investment plan, Pertamina pledged US $ 75.3 million. The details are respectively US $ 1.3 million, then US $ 33.5 million, and US $ 40.5 million. Currently, Pertamina begins to manage the Mahakam block in preparation for operator switching. This is to keep the oil and gas production in the block is not free fall.

Mahakam Block-East Kalimantan

IN INDONESIA

Saham Blok Mahakam Dapat Dilepas Maksimal 39%

Pemerintah bakal mengirim surat ke PT Pertamina yang merevisi batas maksimal share down saham partisipasi Blok Mahakam maksimal 39%. Sebelumnya, batas maksimal saham yang bisa dilepas hanya 30%.

Wakil Menteri Energi dan Sumber Daya Mineral (ESDM) Arcandra Tahar mengatakan, meski menolak seluruh permintaan insentif, pihaknya membuka kesempatan bagi Total E&P Indonesie untuk memiliki hak partisipasi di Blok Mahakam maksimal 39%. Untuk itu, pihaknya segera mengirim surat yang merevisi batas saham yang dapat dilepas Pertamina dari 30% menjadi 39%.

“Sesuai arahan Menteri ESDM Ignasius Jonan, boleh share down up to 39%. Up-nya itu suratnya sedang kami siapkan,” kata dia di Jakarta.

Meski demikian, adanya surat ini bukan berarti Pertamina harus melepas 39%. Keputusan soal besaran hak partisipasi yang beralih ke Total, nantinya tetap berdasarkan negosiasi bisnis Pertamina dengan perusahaan migas asal Prancis itu.

“Semuanya B to B (business to business). Total minta boleh tidak sampai 39%, nanti B to B dengan Pertamina, harganya berapa dan besar sahamnya berapa,” jelas Arcandra.

Sebelumnya, dikatakannya Total E&P Indonesie mengirimkan surat yang menyatakan minatnya membeli 39% saham partisipasi Blok Mahakam. Saham 39% ini merupakan gabungan untuk Total (Perancis) dan Inpex Corporation (Jepang) yang masing-masing memiliki jatah 19,5%, jika usulan itu disetujui. Meski tidak keberatan Pertamina sebagai operator, Total tidak menginginkan saham Blok Mahakam jika di bawah 39%.

Bersama dengan surat itu, Total juga mengajukan sejumlah insentif. Ketiga insentif ini yakni, investment credit sebesar 17%, percepatan depresiasi menjadi dua tahun saja dan bagian produksi yang harus disisihkan sebelum dikurangi biaya (First Tranche Petroleum/FTP) 0%. Seluruh insentif ini telah ditolak oleh pemerintah.

Direktur Hulu Pertamina Syamsu Alam menuturkan, terkait perubahan batas maksimal share down hak partisipasi Blok Mahakam itu sudah dibahas dengan pihaknya. Pihaknya akan mengikuti arahan pemerintah soal hal ini. 

“Mengenai besarnya PI (participating interest/hak partisipasi) yang dapat di-share down, tentu kami akan mengacu kepada regulator atau pemerintah,” tuturnya.

Soal negosiasi saham dengan Total E&P Indonesia, Syamsu pernah mengungkapkan, tidak ada batasan waktu. Namun, pihaknya berharap kesepakatan soal akuisisi saham ini dapat dicapai sebelum kontrak Pertamina di Blok Mahakam mulai efektif pada 1 Januari 2018. 

“Biar 1 Januari 2018 sudah jelas,” ujar Alam.

Pertamina telah mengebor tiga sumur di Blok Mahakam. Pengeboran ini dikerjakan oleh Total E&P Indonesie, namun dengan dana dari Pertamina. Rencananya, Pertamina akan mengebor 14-15 sumur di Blok Mahakam pada tahun ini. Selanjutnya produksi migas dari sumur-sumur ini baru akan mulai dialirkan pada tahun depan. 

“Dibukanya sumur pada 1 Januari 2018,” ujar Syamsu Alam.

Sebelumnya, seperti diketahui Pertamina telah meneken kontrak baru Blok Mahakam yang berlaku mulai 1 Januari 2018 pada akhir 2015 lalu. Dalam kontrak itu, perseroan menjanjikan bonus tanda tangan US$ 41 juta. Selain itu juga penerimaan negara dari bonus produksi meliputi US$ 5 juta dari kumulatif produksi 500 juta barel setara minyak, sebesar US$ 4 juta dari kumulatif produksi 750 juta barel setara minyak, dan US$ 4 juta dari kumulatif produksi 1.000 juta barel setara minyak.

Sementara untuk rencana investasi tiga tahun pertama, Pertamina menjanjikan dana sebesar US$ 75,3 juta. Rinciannya secara berurutan US$ 1,3 juta, kemudian US$ 33,5 juta, dan US$ 40,5 juta. Saat ini, Pertamina mulai ikut mengelola Blok Mahakam untuk persiapan peralihan operator. Hal ini untuk menjaga agar produksi migas di blok tersebut tidak terjun bebas.

Investor Daily, Page-9, Wednesday, Sept 13, 2017

April 2018 Study Results of PLN-Keppel Completed

PT PLN states that April 2018 becomes the deadline Study with Pavilion-Keppel related Logistics studies and preparation of small-scale LNG infrastructure. The results of the study with Keppel will be used for gas infrastructure development planning in Tanjung Pinang and Natuna Islands.

PLN Director Amir Rosidin said PLN and Keppel have signed a Head of Agreement (HoA) related to the cooperation at the Singapore Palace last week. The signing took place at a bilateral meeting of state leaders in commemoration of 50 years of Indonesia-Singapore cooperation.

"The cooperation of HOA is based on the principle of equality and mutual benefit of both parties and carried out for 6 not since signed. If the results of the Study are not beneficial to both parties then this HOA does not proceed to the stage of the agreement, "said Amir in Jakarta, Monday (9/11).

Amir said HoA contains activities and intensive discussions related to the peyusunan more in-depth feasibility study related to the distribution of LNG for the region of Tanjung Pinang and Natuna. Then the concept of cooperation framework to distribute LNG owned by PLN from PLN's existing contract with domestic source to small scale plant in Tanjung Pinang and Natuna.

The HoA also includes the development of a small-scale LNG infrastructure for the Tanjung Pinang and Natuna areas adjacent to Singapore.

"So HoA is not a contract sale and purchase transactions LNG. Rather for the preparation of mini LNG infastructure studies with the aim of obtaining the most reliable and efficient logistics solutions. If later the study results obtained higher costs then the study will end without follow-up implementation, "he said.

He said through this HoA with an offer in order to take advantage of the location of Singapore's LNG terminal as the location of the LNG hub. Given the location of Singapore adjacent to several gas-fired generator sites in Sumatra region. He called this cooperation as a form of decrease of Cost of Production (BPP).

"PLN is interested to see whether the utilization of Singapore's LNG terminal to be proposed by the Pavilion-Keppel can lower BPP in Sumatra," he said.

Amir further explains the area of ​​Tanjung Pinang and Natuna growing. Currently the supply of Tanjung Pinang comes from Batam. As a tourist destination, PLN supports it by providing electricity supply not only from Batam.

     This is to avoid things that are not in want when the supply from Batam stalled. While Natuna region with the development of fishery industry required a qualified power supply to support it. Although there is currently a reserve margin of 4 megawatts.

"We think Natuna should be upgraded though there is a reserve margin of 4 MA. But we think the future needs to be prepared, "he said.

IN INDONESIA

April 2018 Hasil Studi PLN-Keppel Selesai

PT PLN menyatakan bahwa April 2018 menjadi tenggat waktu Studi bersama Pavilion-Keppel terkait studi logistik dan penyiapan infrastruktur LNG Skala kecil. Hasil kajian dengan Keppel akan dipakai untuk perencanaan pembangunan infrastruktur gas di Tanjung Pinang dan Kepulauan Natuna.

Direktur PLN Amir Rosidin mengatakan PLN dan Keppel telah menandatangani Head of Agreement (HoA) terkait kerjasama tersebut di Istana Singapura pada pekan lalu. Penandatangan berlangsung pada pertemuan bilateral pemimpin negara dalam rangka memperingati kerjasama Indonesia-Singapura yang ke 50 tahun.

“Kerjasama HOA ini didasarkan atas asas kesetaraan dan saling menguntungkan kedua belah pihak serta dilakukan selama 6 bukan sejak ditandatangani. Bila hasil studi yang dibuat tidak memberikan manfaat bagi kedua belah pihak maka HOA ini tidak dilanjutkan ke tahap menuju perjanjian,” kata Amir di Jakarta, Senin (11/9).

Amir menuturkan HoA berisi kegiatan dan diskusi intensif terkait peyusunan Studi kelayakan yang lebih mendalam terkait distribusi LNG untuk wilayah Tanjung Pinang dan Natuna. Kemudian pembuatan konsep kerangka kerjasama untuk mendistribusikan LNG milik PLN dari kontrak eksisting PLN dengan Sumber domestik ke pembangkit skala kecil di Tanjung Pinang dan Natuna. 

Selain itu HoA juga berisi pengembangan infrastruktur LNG Skala kecil untuk wilayah Tanjung Pinang dan Natuna yang letaknya berdekatan dengan Singapura.

“Jadi HoA ini bukan kontrak transaksi jual beli LNG. Melainkan untuk Studi penyiapan infastruktur mini LNG dengan tujuan mendapatkan solusi logistik yang paling handal dan efisien. Jika nantinya hasil studi diperoleh biaya lebih tinggi maka studi akan berakhir tanpa tindak lanjut implementasi,” ujarnya.

Dikatakannya melalui HoA ini dengan penawaran agar dapat memanfaatkan lokasi terminal LNG Singapura sebagai lokasi LNG hub. Mengingat lokasi Singapura yang berdekatan dengan beberapa lokasi pembangkit berbahan bakar gas di wilayah Sumatera. Dia menyebut kerjasama ini sebagai bentuk penurunan Biaya Pokok Produksi (BPP). 

“PLN tertarik untuk melihat apakah pemanfaatan terminal LNG Singapura yang akan diajukan Pavilion-Keppel dapat menurunkan BPP di wilayah Sumatera," katanya.

Lebih lanjut Amir menjelaskan wilayah Tanjung Pinang dan Natuna Semakin berkembang. Saat ini pasokan Tanjung Pinang berasal dari Batam. Sebagai destinasi wisata maka PLN menyokongnya dengan menyediakan pasokan listrik bukan hanya dari Batam. 

    Hal ini guna menghindari hal yang tidak di inginkan bila pasokan dari Batam terhenti. Sedangkan kawasan Natuna dengan berkembangnya industri perikanan diperlukan pasokan listrik yang mumpuni guna menunjang hal tersebut. Meskipun saat ini terdapat reserve margin Sebesar 4 megawatt.

“Kami berpikir Natuna harus ditingkatkan pelayanannya meskipun disana ada reserve margin 4 MA. Tapi kami berpikir kedepan memang perlu disiapkan,” ujarnya.

Investor Daily, Page-9, Wednesday, Sept 13, 2017

CEFC deepens oilties with Russia Rosneft deal

Chinese conglomerate CEFC has agreed to buy a 14.16 percent stake in oil major Rosneft for US$ 9.1 billion from a consortium of  Glencore and the Qatar Investment Authority strengthening energy partnerships with Moscow, according to an announcement by  Glencore released on Sept 8.

Following the deal, CEFC will become the third-largest share-holder in Rosneft after the Russian government and BR CEFC Chairman Ye  Jianming was quoted by www.yicai.com as saying that the deal, China’s second-largest oil and gas acquisition after the $15.1 billion purchase of Canada’s Nexen by CNOOC in 2013, will enable further cooperation between CEFC and Rosneft while meeting China's energy demand. 

The transaction is conditioned on the consortium electing to proceed following the completion of final negotiations and on receipt by CEFC of all necessary regulatory approval, Glencore said in the announcement.  Following the transaction, Glencore and QIA would retain an economic interest in Rosneft shares commensurate with their original equity investment announced in December 2016, which amounts to approximately 0.5 percent and 4.7 percent respectively it said.

CEFC was quoted by Reuters as saying the deal would give it annual equity oil production of 42 million metric tons and access to oil and  gas reserves of 2.67 billion tons. According to Han Xiaoping, chief information officer of China Energy Net Consulting, China and Russia complement each other as producers and exporters on the one hand and importers and suppliers on the other, which creates a perfect  atmosphere for win-win deals.

The deal will allow China, the world's second-largest energy consumer, to boost cooperation with the world's top oil producer, which  also tops the list of Chinese crude suppliers, he said. 

Rosneft CEO Igor Sechin was quoted by Reuters as saying CEFC would get access to Rosneft's oil fields and petrochemical projects in East Siberia to guarantee bigger synergies.

China and Russia have strengthened their oil and gas cooperation in recent years, including the Yamal liquified natural gas project in the Arctic region of Russia, the world's first integrated project for polar natural gas exploration, development, liquefaction and transportation. 

Earlier this decade, Beijing also loaned $25 billion to Russia to help it build a pipeline from Siberia. Moscow has been seeking to boost energy cooperation with China, especially since the United States sanctions on Russia, which also make it challenging for large Western firms including Glencore to-cooperate with state-owned firms such as Rosneft.

Despite the optimistic oil cooperation, the transactions have also raised questions among analysts over its lack of transparency Li Li, the  energy research director at ICIS China, a consulting company that provides analysis of the energy market, said the deal was arranged hastily and the details remain unclear.

Jakarta Post, Page-18, Wednesday, Sept 13, 2017

EXxonMobil’s LNG price cut to India bad omen for producers

India has won a price cut on a 20-year liquefied natural gas (LNG) deal with global giant ExxonMobil Corp in a rare contract renegotiation, a bad sign for producers in a heavily oversupplied global market.

In a trade-OH for ExxonMobil, India’s Petronet LNG (PLNG. NS) will increase its volumes from the Gorgon LNG project in Australia ‘by an extra 1 million tons a year to about 2.5 million tons a year, but at cheaper rates than initially agreed in 2009.

Long-term contracts are rarely revised in the LNG market, and for a big producer to cave in shows how supply from new plants 'in Australia and the United States over the past two years has transformed the market, analysts said.

“This trend is overall a negative for sellers, as they are forced to provide more flexibility to buyers’ needs to maintain their markets,” said Saul Kavonic, an analyst with energy consultants Wood Mackenzie.

India has been aggressive in seeking cheaper deals, also renegotiating a contract with Qatar in 2015, but the real pain for producers would come if major Asian buyers in Japan, Korea and China followed suit.

“Happy to share good news that India has, yet again been able to address the long term price issue of LNG from Gorgon to suit Indian market,” India’s oil minister, Dharmendra Pradhan, said on Saturday on social media.

Indian consumers would soon receive LNG at an “amicable price,” Pradhan said. India started receiving Gorgon supplies from January this year. Petronet said in a stock exchange announcement on Monday it had reached a “broad understanding of terms” with ExxonMobil, without giving further details.

Citing market sources, RBC analyst Ben Wilson estimated ExxonMobil would receive 15 percent less revenue per unit on its sales to Petronet under the new deal.

If ExxonMobil had not agreed to renegotiate, Petronet might have scrapped the agreement, leaving the major to pursue damages and resell the volumes on a weak spot market.

“They’ve probably taken the lesser of two evils,” said Wilson, adding that it did not bode well for other LNG producers such as Australia’s Woodside Petroleum which has targeted India to diversify its heavy exposure to Japan and South Korea.

In a major shift from previous contractual terms, Exxon has agreed to absorb shipping charges, two sources with knowledge of the matter told Reuters. The original LNG supplies would be priced at less than 14 percent of the Brent oil price, down from about 14.5 percent earlier, while the additional supplies would be priced about 12.5 percent of Brent, the sources said.

ExxonMobil, which controls about a quarter of the 15.6 million tons a year Gorgon project, had no immediate comment. Analysts said the fact India had managed to force ExxonMobil to renegotiate was the latest proof that buyers have the upper hand in a market where LNG spot prices are well below oil linked contract prices that were signed during the oil boom.

“The risk of price renegotiations will become more acute over the next couple years as spot LNG prices remain depressed, even if oil linked prices rise,” Wood Mackenzie’s Kavonic said.

“The elephant in the room will be how negotiations play out with traditional markets in Japan and Korea, and especially the Chinese national oil companies.”

The Jakarta Post, Page-20, Wednesday, Sept 13, 2017

Unraveling Polemic Energy in the Indonesia

The issue of liquefied natural gas (LNG) import from Singapore into a wild ball. The more wild when entering the political arena. Given that Indonesia is a gas exporter.

Moreover, the gas import discourse originated and Singapore, a neighboring country that actually has no gas source. Although imports are a natural thing in trade, the discourse becomes an irony. However, PT Perusahaan Listrik Negara directly denied the import plan from Singapore through Pavilion Energy and Keppel Corporation.

Central Business Division Director of PLN Central Java Amir Rosidin confirmed that PLN, together with the two Singapore-based companies, will build a small-scale LNG infrastructure in Natuna and Tanjung Pinang adjacent to the location of the LNG terminal hub in Singapore.

Related to the gas import plan, let's see the position of Indonesia as a gas producer. Indonesia's dependence on fossil energy such as petroleum, gas, and coal is still very large.

Based on data from the National Energy Board, conditions in 2015, the consumption of fuel oil (BBM) is still the highest (46%), followed by 26% coal, 23% natural gas, and renewable energy only 5%. Indonesia is also an importer of oil and fuel, about 50% of fuel needs in the country is still imported both in the form of crude oil and fuel.

The government is also still subsidizing the energy although it continues to fall since 2015 blessing from the weakening world crude oil prices. Energy subsidy in 2014 reached Rp 400 trillion, down to Rp 138 trillion in 2015, Rp 120 trillion in 2016, and this year around Rp 103 trillion.

The complicated issue is that some energy commodities such as natural gas are still exported (40%), and coal is still sold abroad (75%). In fact, both natural resources can be optimized for energy needs in the country.

Utilization of gas and coal could reduce the country's dependence on imports of BBM which emptied the country's large foreign exchange. This is the reason the government is serious enough to design an electric car road map, which is to reduce fuel consumption, which currently depends heavily on imports.

"Another goal to reduce carbon dioxide emissions is in line with the Paris 2015 Agreement on reducing global warming,

ENERGY ISSUES

Meanwhile, the polemic about energy in the country is almost never finished. There are several energy issues that need to be resolved soon. First, energy sources become the main capital in development. However, currently some of the main sources of energy are still widely exported, such as gas and coal despite generating extraordinary foreign exchange.

Second, oil and gas production is stagnant. The government needs to encourage business actors to intensify exploration activities to increase oil and gas reserves.

Third, the energy infrastructure is not massive. Refinery capacity is still 50% of national fuel needs. Gas pipelines and gas regasification storage facilities [FSRU] are still low so that the utilization of gas in the country has not been optimal.

Fourth, more than 50% of LPG (LPG) is still imported The government needs to encourage the construction of LPG refineries.

Fifth, the country is also endowed with abundant renewable resources. Sunlight, water source, wind, ocean currents, geothermal, biomass, biogas, and others, but not yet optimally utilized.

Meanwhile, the relatively high gas price in the country has become an industrial problem to date. I still remember very well when Sudirman Sa'id was still Minister of Energy and Mineral Resources at the time. He issued a regulation to root out gas traders who did not have the infrastructure of paper traders alias. They only rely on the allocation of government to be traded to

Other traders have infrastructure, such as gas pipelines.

This paper trader causes the distribution chain or gas trading to be long so that the final price at the consumer level soar. However, Sudirman Sa'id's regulation lasted only 2 months because it was immediately revised so that traders did not get the facility to get gas allocation from the government.

President Joko Widodo also saw a problem of gas prices in the country. The government finally released the Policy Package Volume III in early October 2015 about the gas price to be lowered to US $ 7 per MMBtu.

The decline in gas prices is done by sacrificing the state by giving up the profit sharing from oil and gas cut by US $ 2 per MMBtu. The current gas price cuts policy will be implemented starting January 1, 2016.

Efforts by the government to set up gas traders, the reduction of state profit sharing, and the regulation of gas prices from upstream to downstream are expected to create competitive and reasonable gas prices for consumers so that industrial competitiveness increases.

According to SKK Migas data, gas prices in East Java are around US $ 8.01-US $ 8.0S per MMBtu, western Java US $ 9.14-US $ 9.18 per MMBtu, while prices for Sumatra region above US $ 10 per MMBtu.

IMPORT OPTIONS

As one solution to overcome the high domestic gas prices, the government opens the LNG import option with quite difficult requirements. The Government has issued Regulation of the Minister of Energy and Mineral Resources no. 45/2017 on Gas Utilization

for the Listlik Plant on July 25, 2017. The regulation is a revision of the Minister of Energy and Mineral Resources Regulation no. ll / 2017 which was published in early 2017.

In essence, the regulation regulates the supply of gas for power generation. Not significantly regulating the import of gas. In Article 8, Paragraph (1) of Regulation of Minister of Energy and Mineral Resources No. 45/2017, it is mentioned that PLN and private power developers can purchase natural gas through pipelines at power plants at the highest price of 14.5% of the Indonesian oil price (ICP).

If the current ICP is US $ 50 per barrel, the maximum gas price at the power plant is US $ 7.25 per MMBtu. In paragraph (2) it reads that in the case of PLN and private power developers not obtaining natural gas through pipelines at power plants at the highest price of 14.5% of ICP, as long as there is access or LNG receiving facility, PLN and the developer can do several things.

First, PLN and private developers can buy LNG at a power plant under the pipe gas price bidding. Secondly, in the case of domestic LNG prices at power plants equal to imported LNG prices in power plants, PLN and developers are required to purchase domestic LNG.

Thirdly, in the event that the conditions referred to in the first and second points are not achieved, the Minister of EMR may stipulate a policy of providing natural gas for electricity. This means that if there is an imported LNG that costs below 14.5% ICP when it reaches the power plant, while the domestic LNG and gas pipeline prices are above 14.5%, PLN and the developer may import LNG.

The question of many parties, is imported LNG cheaper than gas? Overseas gas traders can sell cheaply because they make long-term contracts with large volumes to get relatively low prices.

Let's look at the current conditions when the ICP is US $ 50 per barrel. PLN or private power developers may import LNG at a maximum price of US $ 7.2S per MMBtu at the power plant site. The price includes the cost of transportation, regasification, and other costs. It seems a bit difficult to get the price of imported LNG at the plant site at US $ 7.25 per MMBtu considering many other cost components.

IN INDONESIA

Mengurai Polemik Energi di Tanah Air

Isu impor gas alam cair (liquefied natural gas/LNG) dari Singapura menjadi bola liar. Semakin liar ketika masuk ke kancah politik. Mengingat selama ini Indonesia menjadi eksportir gas.

Apalagi, wacana impor gas itu berasal dan Singapura, negara tetangga yang justru tidak memiliki sumber gas. Kendati impor merupakan suatu hal yang wajar dalam perdagangan, wacana itu menjadi sebuah ironi. Namun, PT Perusahaan Listrik Negara langsung membantah rencana impor dari Singapura melalui Pavilion Energy dan Keppel Corporation. 

Direktur Bisnis PLN Jawa Bagian Tengah Amir Rosidin menegaskan bahwa PLN, bersama kedua perusahaan asal Singapura itu akan membangun infrastruktur LNG skala kecil di Natuna dan Tanjung Pinang yang berdekatan dengan lokasi hub terminal LNG di Singapura.

Terkait dengan rencana impor gas, mari lihat posisi Indonesia sebagai produsen gas. Ketergantungan indonesia terhadap energi fosil seperti minyak bumi, gas, dan batu bara masih sangat besar.

Berdasarkan data Dewan Energi Nasional, kondisi pada 2015, konsumsi Bahan Bakar Minyak (BBM) masih yang tertinggi (46%), disusul oleh batu bara 26%, gas bumi 23%, dan energi baru terbarukan hanya 5%. Indonesia juga menjadi importir minyak dan BBM, sekitar 50% kebutuhan BBM di Tanah Air masih diimpor baik dalam bentuk minyak mentah maupun BBM.

Pemerintah juga masih menyubsisi energi meskipun terus turun sejak 2015 berkah dari pelemahan harga minyak mentah dunia. Subsidi energi pada 2014 mencapai Rp 400 triliun, turun menjadi Rp 138 triliun pada 2015, Rp 120 triliun pada 2016, dan pada tahun ini sekitar Rp 103 triliun. 

Persoalan yang cukup rumit adalah beberapa komoditas energi seperti gas alam masih diekspor (40%), dan batubara juga masih dijual ke luar negeri (75%). Padahal, kedua sumber daya alam itu bisa dioptimalkan untuk kebutuhan energi di dalam negeri.

Pemanfaatan gas dan batu bara bisa mengurangi ketergantungan negeri ini terhadap impor BBM yang mengosongkan devisa negara cukup besar. Ini menjadi alasan pemerintah cukup serius merancang peta jalan mobil listrik, yaitu untuk menurunkan konsumsi BBM, yang saat ini sangat bergantung terhadap impor. 

"Tujuan lainnya untuk mengurangi emisi karbondioksida sejalan dengan Kesepakatan Paris 2015 soal pengurangan pemanasan global,

PERSOALAN ENERGI

Sementara itu, polemik soal energi di Tanah Air hampir tidak pernah usai. Ada beberapa persoalan energi yang perlu segera diselesaikan. Pertama, sumber energi menjadi modal utama dalam pembangunan. Namun, saat ini beberapa sumber energi utama masih banyak diekspor, seperti gas dan batu bara kendati menghasilkan devisa yang luar biasa.

Kedua, produksi minyak dan gas bumi yang stagnasi. Pemerintah perlu mendorong pelaku usaha untuk menggencarkan kegiatan eksplorasi untuk menambah cadangan migas.

Ketiga, infrastruktur energi yang belum masif. Kapasitas kilang masih 50% dari kebutuhan BBM nasional. Pipa gas serta fasilitas penyimpanan regasifikasi gas [FSRU) masih minim sehingga pemanfaatan gas di dalam negeri belum optimal.

Keempat, lebih dari 50% elpiji (LPG) masih diimpor Pemerintah perlu mendorong pembangunan kilang LPG.

Kelima, negeri ini juga dikaruniai sumber alam terbarukan yang melimpah. Cahaya matahari, sumber air, angin, arus laut, panas bumi, biomasa, biogas, dan lainnya, tetapi belum dimanfaatkan secara optimal.

Sementara itu, harga gas yang relatif tinggi di Tanah Air menjadi persoalan industri hingga saat ini. Saya masih ingat betul ketika Sudirman Sa'id masih menjadi Menteri ESDM saat itu. Beliau mengeluarkan peraturan untuk membasmi para trader gas yang tidak memiliki infrastruktur alias trader kertas. Mereka hanya mengandalkan alokasi dari pemerintah untuk diperjualbelikan kepada

trader lain yang memiliki infrastruktur, seperti pipa gas.

Trader kertas ini menyebabkan rantai distribusi atau tata niaga gas menjadi panjang sehingga harga akhir di tingkat konsumen melambung. Namun, peraturan Sudirman Sa'id itu hanya bertahan 2 bulan karena langsung direvisi sehingga trader tidak berfasilitas tetap mendapatkan alokasi gas dari pemerintah.

Presiden Joko Widodo pun melihat ada persoalan harga gas di dalam negeri. Pemerintah akhirnya mengeluarkan Paket Kebijakan Jilid III pada awal Oktober 2015 soal harga gas yang akan diturunkan menjadi US$7 per MMBtu.

Penurunan harga gas itu dilakukan dengan cara negara berkorban dengan merelakan bagi hasil dari migas dipotong US$ 2 per MMBtu. Kebijakan pemotongan harga gas saat itu akan dilaksanakan mulai 1 Januari 2016.

Upaya-upaya pemerintah dengan menata trader gas, pengurangan bagi hasil negara, dan pengaturan harga gas dari hulu sampai hilir diharapkan mampu menciptakan harga gas yang kompetitif dan wajar bagi konsumen sehingga daya saing industri naik.

Menurut data SKK Migas, harga gas di Jawa Timur sekitar US$ 8,01-US$ 8,0S per MMBtu, Jawa bagian barat US$ 9,14-US$ 9,18 per MMBtu, sedangkan harga untuk wilayah Sumatra di atas US$ 10 per MMBtu.

OPSI IMPOR

Sebagai salah satu solusi untuk mengatasi harga gas yang tinggi di dalam negeri, pemerintah membuka opsi impor LNG dengan persyaratan yang cukup sulit. Pemerintah telah mengeluarkan Peraturan Menteri ESDM No. 45/2017 tentang Pemanfaatan Gas

untuk Pembangkit Listlik pada 25 Juli 2017. Peraturan itu merupakan revisi Peraturan Menteri  ESDM No. ll/2017 yang terbit pada awal 2017.

Pada intinya, regulasi itu mengatur soal pasokan gas untuk pembangkit listrik. Tidak secara nyata mengatur soal impor gas. Dalam Pasal 8, Ayat (1) Peraturan Menteri  ESDM No. 45/2017, disebutkan bahwa PLN dan pengembang listrik swasta dapat membeli gas bumi melalui pipa di pembangkit listrik dengan harga paling tinggi 14,5% dari harga minyak Indonesia (ICP). 

Jika saat ini ICP US$ 50 per barel, harga gas maksimal di pembangkit listrik adalah US$ 7,25 per MMBtu. Pada ayat (2) berbunyi, dalam hal PLN dan pengembang listrik swasta tidak mendapatkan gas bumi melalui pipa di pembangkit listrik dengan harga paling tinggi 14,5% dari ICP, sepanjang terdapat akses atau fasilitas penerima LNG, PLN dan pengembang dapat melakukan beberapa hal.

Pertama, PLN dan pengembang swasta dapat membeli LNG di pembangkit listrik di bawah penawaran harga gas pipa. Kedua, dalam hal terdapat harga LNG domestik di pembangkit listrik sama dengan harga LNG impor di pembangkit listrik, PLN dan pengembang wajib membeli LNG dalam negeri.

Ketiga, dalam hal kondisi sebagaimana dimaksud pada poin pertama dan kedua tidak tercapai, Menteri ESDM dapat menetapkan kebijakan penyediaan gas bumi untuk tenaga listrik. Artinya, jika ada LNG impor yang harganya di bawah 14,5% ICP ketika sampai di pembangkit listrik, sedangkan harga LNG dan gas pipa di dalam negeri di atas 14,5%, PLN dan pengembang boleh impor LNG.

Pertanyaan banyak pihak, apakah LNG impor lebih murah dibandingkan dengan gas? Trader gas di luar negeri bisa menjual dengan harga murah karena mereka melakukan kontrak dalam jangka panjang dengan volume besar sehingga mendapatkan harga relatif rendah.

Mari melihat kondisi saat ini ketika ICP US$ 50 per barel. PLN atau pengembang listrik swasta boleh impor LNG dengan harga maksimal US$ 7,2S per MMBtu di lokasi pembangkit listrik. Harga itu sudah termasuk biaya pengangkutan, regasifikasi, dan biaya lain. Sepertinya agak sulit untuk bisa mendapatkan harga LNG impor di lokasi pembangkit US$ 7,25 per MMBtu mengingat banyak komponen biaya lain.

Bisnis Indonesia, Page-28, Wednesday, Sept 13, 2017