The New Rule of the ESDM Minister Causes Controversy

The new Minister of Energy and Mineral Resources (ESDM) NO 42/2017 regulation on Business Control in Business Activities in ESDM Sector sparked controversy. This rule can complicate the movement of energy business.

In such a regulation, energy companies are required to obtain permission if they reimburse directors and commissioners to share transfer.

"It's better just to report it, no need to get approval," said Deputy Executive Director of Indonesian Coal Producers Association (APBI) Hendra Sinadia, Friday (21/7).

The sale of shares and the replacement of the board is a corporate action. If this has to wait for government approval it is feared this could hamper corporate action. Entrepreneurs are also doubtful with the Ministry of Energy and Mineral Resources's ability to handle this. Because the current number of companies with Mining Business License (IUP) reached 10,818. The number of companies holding Contract of Work 34

Meanwhile, the company holding the Coal Mining Concession Working Agreement (PKP2B) is 73, then there is a Contractor Cooperation Contract (KKKS) in the oil and gas sector 68, as well as private power plants amounting to 40. Vice Chairman of the Indonesian Processing and Refining Association (APSI), Jonathan Handojo also questioned This policy motif.

"This Minister wants to be a sole ruler?" He said half-questioned.

Jonathan suspects the background of the emergence of this rule the government has often been deceived fake companies that want to enjoy natural resources. Daily Chairman of the Association of Indonesian Private Electric Manufacturers (ASI) Arthur Simatupang said, this rule can be troublesome businessmen.

"Making uncertainty," he said.

Energy Observer Fahmi Radhi considers that ESDM Minister should not take care of corporate actions.

"This could trigger moral hazard in any decision-making," he said

However, APBI and APLSI have not planned to sue this rule. They are now awaiting the hearing and socialization of this rule.

IN INDONESIA

Aturan Baru Menteri ESDM Menyebabkan Kontroversi

Aturan baru Menteri Energi dan Sumber Daya Mineral (ESDM) No 42/2017 tentang Pengawasan Pengusahaan pada Kegiatan Usaha di Sektor ESDM memantik kontroversi. Aturan ini bisa menyulitkan gerak pelaku bisnis energi.

Dalam aturan itu semisal, perusahaan bidang energi wajib mendapatkan izin jika melakukan penggantian direksi dan komisaris hingga pengalihan saham. 

"Sebaiknya hanya melaporkan saja. Tidak perlu mendapat persetujuan," kata Deputi Direktur Eksekutif Asosiasi Produsen Batubara Indonesia (APBI) Hendra Sinadia, Jumat (21/7).

Penjualan saham dan penggantian pengurus merupakan aksi korporasi. Jika ini harus menunggu persetujuan pemerintah dikhawatirkan ini bisa menghambat aksi korporasi. Pengusaha juga sangsi dengan kemampuan Kementerian ESDM mengurusi hal ini. Pasalnya, saat ini jumlah perusahaan dengan Izin Usaha Pertambangan (IUP) mencapai 10.818. Adapun jumlah perusahaan pemegang Kontrak Karya 34

Adapun perusahaan pemegang Perjanjian Karya Pengusahaan Pertambangan Batubara (PKP2B) ada 73, lalu ada Kontraktor Kontrak Kerja Sama (KKKS) bidang migas 68, serta pembangkit listrik swasta jumlahnya ada 40. Wakil Ketua Asosiasi Pengolahan dan Pemurnian Indonesia (APSI), Jonathan Handojo juga mempertanyakan motif kebijakan ini. 

"Ini Menteri mau menjadi penguasa tunggal?" kata dia setengah bertanya. 

Jonathan menduga latar belakang munculnya aturan ini pemerintah selama ini sering tertipu perusahaan palsu yang hendak menikmati sumber daya alam. Ketua Harian Asosiasi Produsen Listrik Swasta Indonesia (ASI) Arthur Simatupang bilang, aturan ini bisa menyusahkan pebisnis. 

"Membuat ketidakpastian," ujar dia.

Pengamat Energi Fahmi Radhi menilai, tidak semestinya Menteri ESDM mengurusi corporate actions. 

"Ini bisa memicu moral hazard dalam setiap pengambilan keputusan," kata dia

Meskipun begitu, APBI maupun APLSI belum berencana untuk menggugat aturan ini. Mereka kini sedang menunggu audiensi dan sosialisasi atas aturan ini.

Kontan, Page-14, Saturday, July 22, 2017

ExxonMobil exit warning of waning oil, gas industry

The sudden exit of United States-based oil and gas giant ExxonMobil from the East Natuna energy block has become a major blow to Indonesia’s already struggling upstream oil and gas industry.

Investors’ appetite in the sector has long been waning even before ExxonMobil’s withdrawal. announcement on Tuesday, due to concerns on regulatory uncertainties and lengthy red tape, in addition to the persistently low global oil prices.

While the government has visibly made some effort to freshen up the industry with new policies, BMI Research oil and gas analyst Peter Lee said that Indonesia’s attractiveness as an investment destination was still below par in comparison to other markets in Asia, Africa, Europe and the Gulf of Mexico.

“Investors have yet to be impressed by the government’s gradual attempts at upstream reform, which includes the decision to eliminate exploration-related taxes in September 2016 and the introduction of a new PSC [production sharing contract] in January 2017 that significantly increases the companies’ take of profits from oil and gas sales, although it does not offer any cost-recovery mechanism,”

he said.

Block East Natuna

ExxonMobil Indonesia announced that it no longer wished to continue any discussions or activity in the East Natuna block. for which it had joined a feasibility study consortium otherwise consisting ofstate-owned energy firm Pertamina and Thailand’s PTT EP.

Its exit follows in the footsteps of two other former consortium members Malaysia’s Petronas and France’s Total. The Energy and Mineral Resources Ministry has confirmed ExxonMobil’s wish to halt its participation in the negotiations, saying thatthe latter had deemed the project economically unfeasible under the current terms offered.

The East Natuna block, located in Riau Islands, has total proven reserves of 46 trillion cubic feet (tcf) of gas and is deemed to be one of Asia’s largest reserves. However, the gas field has a high carbon dioxide (CO2) level of 72 percent, which requires an estimated US$20 billion to $40 billion for development and the advanced technology needed to maximize extraction.

Moreover, a previous government-commissioned study showed that East Natuna would only be economically feasible if future contractors obtained 100 percent of the profit share, leaving the government only to reap revenues from taxes.

Wood Mackenzie research analyst forthe Asian upstream sector, Johan Utama, said the latest company’s move to leave the East Natuna block has made the list of international companies exiting or reducing their presence in Indonesia even longer.

East Natuna Seismic Survey

“Marathon, Anadarko, Murphy, Hess and Lundin have disposed of their Indonesian portfolios, as they focus their capital on more attractive projects in their portfolios,” he told the Post.

Utama also cited the decision of ConocoPhillips and Inpex to sell their stakes in the South Natuna Sea Block B and Chevron’s move not to extend the operation of its shallow-water blocks in East Kalimantan as signs of a poor investment atmosphere in the Southeast Asian country.

While ExxonMobil’s decision to pull out may not directly affect this year’s total upstream investment, the governments failure to attract sufficient foreign investment is expected to burden Pertamina. The government has assigned eight expiring fields to the state-owned firm to be operated under the recently introduced -gross-split scheme.

“While its state-owned nature will see investment into domestic fields sustained, pumping capital into domestic mature assets, all the while advancing its overseas and downstream expansion agenda, will prove increasingly taxing,” BMI Research’s Lee said.

The Upstream Oil and Gas Regulatory Special Task Force (SKK Migas) recently announced that investment in the sector in the first half of the year only reached $3.99 billion, 28.84 percent of the full-year target of $13.8 billion. Most analysts agree that a shortfall in investment will likely happen by the end of the year.

Jakarta Post, Page-13, Friday, July 21, 2017

Two Gas Pipeline Projects Soon Auctioned

The Downstream Oil and Gas Regulatory Agency (BPH Migas) immediately auctioned two gas pipeline projects in Sumatra and Java. This is done based on the proposal of two companies to BPH Migas namely Regional Mining and Energy Company (PDPDE) South Sumatra and PT Berkah Kawasan Manyar Sejahtera.

According to the Head of BPH Migas Fanshurullah Asa, this is in accordance with Regulation of Oil and Gas Regulatory Agency (Nomar) 15 year 2016 about auction of transmission segment and or gas distribution network area. Beleid stated that the determination of the transmission segment and / or gas distribution network area to be auctioned, one of which can be a business proposal based on the Master Plan of National Gas Transmission and Distribution Network.

"There are two companies proposing the pipeline project to be auctioned, there is already a feasibility study," he said in Jakarta.

First, the South Sumatra Regional Energy and Mining Enterprise (PDPDE) submits an application to manage the Tanjung Api-Api Fire to Muntok transmission segment along 138 kilometers (km) with a 20 inch diameter pipe. Secondly, PT Berkah Kawasan Manyar Sejahtera requested to manage the fulfillment of natural gas needs for power plants and industries in Manyar, Gresik. On both these proposals, he said BPH Migas immediately held an auction.

"BPH Migas will follow up by carrying out the auction of the sections in question," said Fanshurullah.

Although later auctioned and not appointed directly, Fashurullah explained that the proposing business entity still has the privilege (privilege). Still under the Regulation of BPH Migas 15/2016, the auction committee shall provide an opportunity for the initiating entity to bid the amount of investment expense (capital expenditure) and operational expenditure equal to or lower than the business entity having the highest evaluation value.

According to data from the Ministry of Energy and Mineral Resources (ESDM), until 2016, the length of gas pipes that have been installed recorded along 14,417, 18 km. Detailed, open access pipes 4,296.59 km, dedicated downstream 5,453.13 km, dedicated upstream 4,649.89 km, as well as pipes built for own benefit 71.57 km. The length of this gas pipeline is targeted to increase every year. Target Ministry of Energy and Mineral Resources, the national pipe length can reach 17 584 29%, "he said.

Admittedly, there are a number of obstacles in the construction of Pipe Gresik-Semarang this. One of them is a land area of ​​unexualed project location, which is 60 km long. However, this time has been followed up by increasing the number of teams. Thus, Land acquisition is expected to be resolved soon.

The next project is the Grissik-Pusri Pipe. The 176 km pipe has a diameter of 20 inches and a gas flow capacity of 160 million standard cubicrfeet per day / mmscfd. The pipeline is planned to be used to meet the gas needs of PT Pupuk Sriwijaya (Pusri), PT PLN km in 2020. The pipeline consists of open access pipes of 5,665 km, dedicated downstream of 7,095 km, dedicated upstream of 4,697 km, and own pipe 127 km.

Keep Building

In addition to auctioning new projects, Fanshurullah added, there are five gas pipeline projects that are currently under construction. First, the transmission pipeline Gresik-Semarang is done by PT Pertamina Gas (Pertagas). As of mid-May, the project's engineering progress has reached 93%, 99% procurement, and 37.5% conservation.

"As for the pipe that has been embedded along 77.75 km of target 266.26 km or new saga start construction of this pipe.

"The Tanjung Api-Fire Muntok Pipe went ahead with this pipe. So Pertagas build up Pusri, then proceed to Muntok and Bangka, "explained Fanshurullah.

Next is the Duri-Dumai Pipe Project. The 67km pipeline is targeted to start operating in 2018. The project, with a total investment value of US $ 76 million, will begin construction in the third quarter by PT PGN and PT Pertamina. Lastly, Pipe PK

52-Tanjung Batu done by PLN. The 55 km pipeline is targeted to start operating by the end of 2017.

Oil and Gas Infrastructure

IN INDONESIA

Dua Proyek Pipa Gas Segera Dilelang

Badan Pengatur Hilir Minyak dan Gas Bumi (BPH Migas) segera melelang dua proyek pipa gas di Sumatera dan Jawa. Hal ini dilakukan berdasarkan usulan dua perusahaan kepada BPH Migas yakni Perusahaan Daerah Pertambangan dan Energi (PDPDE) Sumatera Selatan dan PT Berkah Kawasan Manyar Sejahtera.

Menurut Kepala BPH Migas Fanshurullah Asa, hal ini sesuai Peraturan BPH Migas Nomar 15 Tahun 2016 tentang lelang ruas transmisi dan atau wilayah jaringan distribusi gas bumi. Beleid ini menyebutkan bahwa penetapan ruas transmisi dan atau wilayah jaringan distribusi gas bumi yang akan dilelang,  salah satunya dapat merupakan usulan badan usaha berdasarkan Rencana Induk Jaringan Transmisi dan Distribusi Gas Bumi Nasional.

“Sudah ada dua perusahaan yang mengusulkan proyek pipa untuk dilelang, ini sudah ada studi kelayakannya,” kata dia di Jakarta.

Pertama, Perusahaan Daerah Pertambangan dan Energi (PDPDE) Sumatera Selatan mengajukan permohonan untuk mengelola ruas transmisi Tanjung Api-Api sampai Muntok sepanjang 138 kilometer (km) dengan diameter pipa 20 inch. Kedua, PT Berkah Kawasan Manyar Sejahtera meminta untuk dapat mengelola pemenuhan kebutuhan gas bumi untuk pembangkit listrik dan industri di daerah Manyar, Gresik. Atas kedua usulan ini, dikatakannya BPH Migas segera menggelar lelang. 

“BPH Migas akan menindaklanjuti dengan melaksanakan lelang ruas yang dimaksud,” tutur Fanshurullah.

Meski kemudian dilelang dan bukan ditunjuk langsung, Fashurullah menjelaskan bahwa badan usaha pengusul tetap memiliki keistimewaan (privilege). Masih berdasar Peraturan BPH Migas 15/2016, panitia pelaksana lelang memberikan kesempatan kepada badan usaha pemrakarsa untuk melakukan penawaran besaran biaya investasi (capital expenditure) dan biaya operasi (operational expenditure) sama atau lebih rendah dari badan usaha yang mempunyai nilai tertinggi hasil evaluasi.

Menurut data Kementerian Energi dan Sumber Daya Mineral (ESDM), hingga 2016 lalu, panjang pipa gas yang telah terpasang tercatat sepanjang 14.417 ,18 km. Rincinya, pipa open access 4.296,59 km, dedicated hilir 5.453,13 km, dedicated hulu 4.649,89 km, serta pipa yang dibangun untuk kepentingan sendiri 71,57 km. Panjang pipa gas ini ditargetkan terus bertambah setiap tahunnya. Target Kementeri ESDM, panjang pipa nasional bisa mencapai 17.584 29%,” kata dia.

Diakuinya, ada sejumlah kendala dalam pembangunan Pipa Gresik-Semarang ini. Salah satunya terdapat sebagia lahan lokasi proyek yang belum dibebaskan, yakni sepanjang 60 km. Namun, saat ini telah ditindaklanjuti dengan menambah jumlah tim. Sehingga,

pembebasan lahan diharapkan dapat segera diselesaikan.

Proyek selanjutnya adalah Pipa Grissik-Pusri. Pipa sepanjang 176 km ini memiliki diameter 20 inch dan kapasitas alir gas 160 million standard cubicrfeet per day/mmscfd. Pipa ini rencananya akan digunakan untuk memenuhi kebutuhan gas PT Pupuk Sriwijaya (Pusri), PT PLN km pada 2020. Pipa tersebut terdiri pipa open acces 5.665 km, dedicated hilir 7.095 km, dedicated hulu 4.697 km, dan pipa untuk kepentingan sendiri 127 km.

Terus Membangun

Selain melelang proyek baru, Fanshurullah menambahkan, terdapat lima proyek pipa gas yang kini sedang dibangun. Pertama, pipa transmisi Gresik-Semarang yang dikerjakan oleh PT Pertamina Gas (Pertagas). Hingga pertengahan Mei lalu, progres rekayasa (engineering) proyek ini telah mencapai 93%, pengadaan 99%, dan konsiruksi 37,5%.

“Sementara untuk pipa yang telah tertanam sepanjang 77,75 km dari target 266,26 km atau baru baru saga memulai konstruksi pipa ini.

“Pipa Tanjung Api-Api Muntok tadi meneruskan pipa ini. Jadi Pertagas membangun sampai Pusri, kemudian dilanjutkan ke Muntok dan Bangka,” jelas Fanshurullah.

Berikutnya yakni Proyek Pipa Duri-Dumai. Pipa sepanjang 67 km ini ditargetkan mulai beroperasi pada 2018. Proyek dengan nilai investasi sebesar US$ 76 juta tersebut akan mulai konstruksi pada kuartal ketiga ini oleh PT PGN dan PT Pertamina. Terakhir, Pipa PK 52-Tanjung Batu yang dikerjakan PLN. Pipa sepanjang 55 km ini ditargetkan mulai beroperasi pada akhir 2017.

Investor Daily, Page-14, Friday, July 21, 2017

Every Year, Arun Regasification Continues to Increase

The number of liquefied natural gas (LNG) cargoes occupied by the Arun Receiver and Regasification Terminal in Aceh continues to increase from year to year. In this year there were 17 cargo which were classified. While last year reached 14 cargoes and in 2015 as many as 11 LNG cargoes.

Production Plan & Process Engineering Manager of PT Perta Arun Gas Surkani Manan said that the terminal will start operation in 2015 which was inaugurated by President Joko Widodo.

"Initially we regasifikasi 11 cargo sourced from Tangguh 10 cargo and Donggi 1 cargo. It is now 17 cargoes, "Surkani said during a media visit in Lhokseumawe, Thursday (7/20).

"Surkani said the majority of LNG cargoes are absorbed by PT PLN power plant. He said the need for industry is only one cargo from year to year. The average gas distribution from Arun regasification facility in 2015 is 87.9 mmscfd with 86.05 mmscfd for PLN and 1.85 mmscfd for Industry in Medan. Then in 2016 for the period January-October reached 88.81 mmscfd with details of 85.86 mmscfd for PLN and 2.95 mmscfd absorbed by the industry.

"Gas for PLN is for PLTMG Arun and Belawan. We and PLN have a mutual commitment. PLN has a big interest in regasification, "he said.

He said the regasification terminal was previously an Arun LNG plant operating since 1978 and ending on October 15, 2014. It recorded that for 35 years the total shipment reached 4,269 cargoes to a number of countries such as Japan, Korea and Taiwan. Pertamina has conducted an in-depth study since 2011 before the refinery ceased operations. The option of transferring functions into regasification is chosen taking into consideration the viability of the industry and the power plant which has soaked Arun gas.

"In 2011 Pertamina has conducted a study to be taken wherever this great asset there are 6 train LNG condesate tank, so some business initiation that developed Pertamina, all directed customer expression, pursed the first priority which decided by regasification," he said.

According to him Lhokseumawe could become a dead city say LNG assets are not used. He called during the Arun refinery

Operate to absorb up to 5,000 workers including to its derivative industry.

"With employment can sustain economic and political stability, because if many are unemployed will increase criminality," he concluded.

IN INDONESIA

Tiap Tahun, Regasifikasi Arun Terus Meningkat

Jumlah kargo gas alam cair (LNG) yang digarap Terminal Penerima dan Regasifikasi Arun, Aceh terus meningkat dari tahun ke tahun. Pada tahun ini tercatat sebanyak 17 kargo yang diregasifikasi. Sedangkan tahun lalu mencapai 14 kargo dan pada 2015 sebanyak 11 kargo LNG.

Manager Production Plan & Process Engineering PT Perta Arun Gas Surkani Manan mengatakan Terminal ini mulai beroperasi pada 2015 yang diresmikan oleh Presiden Joko Widodo. 

“Awalnya kami regasifikasi 11 kargo bersumber dari Tangguh 10 kargo dan Donggi 1 kargo. Sekarang sudah 17 kargo,” kata Surkani dalam kunjungan media di Lhokseumawe, Kamis (20/7).

”Surkani menuturkan mayoritas kargo LNG tersebut diserap oleh pembangkit listrik PT PLN. Dia mengatakan kebutuhan untuk industri hanya satu kargo dari tahun ke tahun. Rata-rata penyaluran gas dari fasilitas regasifikasi Arun di 2015 sebanyak 87,9 mmscfd dengan rincian 86,05 mmscfd untuk PLN dan 1,85 mmscfd untuk Industri di Medan. Kemudian di 2016 untuk periode Januari-Oktober mencapai 88,81 mmscfd dengan rincian 85,86 mmscfd untuk PLN dan 2,95 mmscfd diserap industri. 

“Gas untuk PLN itu untuk PLTMG Arun dan Belawan. Kami dan PLN punya komitmen bersama. PLN punya kepentingan besar dengan regasifikasi," ujarnya. 

Dikatakannya terminal regasifikasi ini sebelumnya merupakan kilang LNG Arun yang beroperasi sejak 1978 dan berakhir pada 15 Oktober 2014. Tercatat selama 35 tahun tersebut total pengapalan mencapai 4.269 kargo ke sejumlah negara seperti Jepang, Korea dan Taiwan. Pertamina melakukan kajian mendalam sejak 2011 sebelum kilang tersebut berhenti operasi. Opsi pengalihan fungsi menjadi regasifikasi dipilih dengan mempertimbangkan kelangsungan hidup industri dan pembangkit listrik yang selama ini menyerap gas Arun. 

"Pada 2011 Pertamina sudah lakukan kajian mau dibawa kemana aset besar ini ada 6 train tangki LNG kondesat. Jadi beberapa inisasi bisnis yang didevelop Pertamina, semua diarahkan ekspetasi pelanggan, mengerucut yang prioritas dulu yang diputuskan regasifikasi,” ujarnya.

Menurutnya Lhokseumawe bisa menjadi kota mati bilang aset-aset LNG tidak dimanfaatkan. Dia menyebut selama kilang Arun beroperasi menyerap hingga 5.000 pekerja termasuk ke industri turunannya. 

“Dengan lapangan kerja bisa menopang stabilitas ekonomi dan politik, karena kalau banyak yang nganggur akan meningkatkan kriminalitas,” tutupnya.

Kontan, Page-14, Friday, July 21, 2017

Director General of Oil and Gas Rejects Total EP Desire

The Directorate General of Oil and Gas of the Ministry of Energy and Mineral Resources (ESDM) refuses the Letter of Total EP lndonesie. This company's additional shares of Mahakam Block to 39% from previously only 30% stake. After conducting an evaluation of additional demand of Mahakam Block shares by Total EP, finally in reply letter from the Ministry of Energy and Mineral Resources declared rejected the desire of Total EP.

"The Director General of Oil and Gas who declined the letter has been sent to the Minister of Energy and Mineral Resources lgnasius Jonan.I do not know whether the minister refused or even received?" Unfortunately, the news about the three incentives demanded, namely the first tranche petroleum incentives to 0%, from which is usually 10% of gross production. Then investment credit to 17%, the acceleration of the depreciation period from five to two years has not been clarified.

Oil and Gas Director General IGN Wiratmaja Puja only laughed when asked about himself who rejected the request of Total EP. "The authority is at the Minister, the letter is immediately answered," he said, Thursday (20/7).

The Deputy Minister of Energy and Mineral Resources Arcandra Tahar revealed, he has signed a letter for the three incentives requested by Total EP. However, related to the request for additional shares of the ESDM Minister who will decide.

"The three incentives I have signed, I do not know what the Minister said, do not go ahead of the Minister," he said.

Vice President Corporate Communications PT Pertamina Adiatma Sardjito said it was still looking for info about the rejection of the Total EP request.

Energy Observer Fahmi Radhi stated that the government's decision to refuse Total E & P's request is correct. He considered Pertamina able to manage the Mahakam Block.

"If still needed some experts can be paid. If you need technology can be purchased, "he said.

MAHAKAM BLOCK

IN INDONESIA

Dirjen Migas Tolak Keinginan Total EP

Direktorat Jenderal Minyak dan Gas Bumi Kementerian Energi dan Sumber Daya Mineral (ESDM) menolak Surat Total EP lndonesie. Perusahaan ini tambahan saham Blok Mahakam menjadi 39% dari sebelumnya hanya 30% saham. Setelah menggelar evaluasi terhadap permintaan tambahan saham Blok Mahakam oleh Total EP, akhirnya dalam surat balasan Kementrian ESDM menyatakan menolak keinginan Total EP.

"Dirjen Migas yang menolak. Surat sudah dikirim ke Menteri ESDM lgnasius Jonan. Saya tidak tahu apakah menteri menolak atau malah menerima?"  Sayang, kabar soal tiga insentif yang diminta, yakni insentif first tranche petroleum menjadi 0%, dari yang biasanya 10% dari produksi kotor. Lalu investment credit menjadi 17%, percepatan masa depresiasi dari lima menjadi dua tahun belum ada kejelasan.

Dirjen Migas IGN Wiratmaja Puja hanya tertawa ketika ditanya soal dirinya yang menolak permintaan Total EP. "Kewenangan ada di Menteri. Suratnya segera dijawab," kata dia, Kamis (20/7).

Adapun Wakil Menteri ESDM Arcandra Tahar mengungkapkan, dirinya sudah meneken Surat untuk tiga insentif yang diminta oleh Total EP. Namun terkait permintaan penambahan saham Menteri ESDM yang akan memutuskan. 

"Tiga insentif itu saya sudah tanda tangani. Saya tidak tahu Menteri menjawab apa. Jangan mendahului Menteri," katanya. 

Vice President Corporate Communication PT Pertamina Adiatma Sardjito mengatakan, pihaknya masih mencari tahu soal info penolakan permintaan Total EP tersebut. 

Pengamat Energi Fahmi Radhi menyatakan bahwa keputusan pemerintah yang menolak permintaan Total E&P Sudah tepat. Dia menilai Pertamina sanggup mengelola Blok Mahakam. 

“Kalau masih dibutuhkan beberapa ahli bisa dibayar. Kalau butuh teknologi bisa dibeli," ujarnya.

Kontan, Page-14, Friday, July 21, 2017

More LNG Regasification in Perta Arun Gas

PT Perta Arun Gas seeks to increase the number of cargo of LNG / LNG through the receiving and regasification terminal of Arun, Nanggroe Aceh Darussalam. Three years, the trend is increasing. This year, there were 17 cargo that were classified, up from last year's 14 cargoes.

In 2015, the regasification process is only 11 LNG cargoes. Arun LNG plant had stopped on October 15, 2014, after 37 years of operation because the gas there is exhausted. The last LNG exported from the refinery was about 4,469 cargoes. Now Perta Arun Gas is beginning to convert refineries into receiving and regasifying LNG terminals.

Production Plan & Process Engineering Manager of PT Perta Arun Gas Surkani Manan said the receiving and regasification terminal of Arun began to operate again in 2015, inaugurated by President Joko Widodo.

"We initially regasification of 11 cargoes is sourced from Tangguh 10 cargo and Donggi 1 cargo, now it is 17 cargoes," said Surkani, during a media visit in Lhokseumawe on Thursday (20/7).

The majority of LNG cargoes are absorbed by power plants PT Perusahaan Listrik Negara (PLN). The need for industry is only one cargo from year to year. The average of gas distribution from Regasification facility

Arun in 2015 as much as 87.9 mmscfd. In addition, 6.05 mmscfd for PLN and 1.85 mmscfd for industries in Medan. Then in 2016, precisely in the period January to October reached 88.81 mmscfd with details of 85.86 mmscfd for PLN and 2.95 mmscfd absorbed by the industry.

"The gas for PLN is for PLTMG Arun and Belawan, and PLN has a mutual commitment and PLN has a great interest in regasification," said Surkani.

IN INDONESIA

Makin Banyak Regasifikasi LNG di Perta Arun Gas

PT Perta Arun Gas berupaya meningkatkan jumlah kargo gas alam cair/LNG melalui terminal penerima dan regasifikasi Arun, Nanggroe Aceh Darussalam. Tiga tahun ini, trennya meningkat. Tahun ini tercatat sebanyak 17 kargo yang diregasifikasi, naik dari tahun lalu yang sebanyak 14 kargo. 

Tahun 2015, proses regasifikasi hanya 11 kargo LNG. Kilang LNG Arun sempat berhenti pada 15 Oktober 2014, setelah 37 tahun beroperasi karena gas di sana habis. LNG terakhir yang diekspor dari kilang tersebut sekitar 4.469 kargo. Kini Perta Arun Gas mulai mengubah kilang menjadi terminal penerima dan regasifikasi LNG.

Manajer Production Plan & Process Engineering PT Perta Arun Gas Surkani Manan mengatakan, terminal penerima dan regasifikasi Arun ini mulai beroperasi kembali pada tahun 2015, diresmikan oleh Presiden Joko Widodo.

"Awalnya kami regasifikasi 11 kargo bersumber dari Tangguh 10 kargo dan Donggi 1 kargo. Sekarang sudah 17 kargo," kata Surkani, dalam kunjungan media di Lhokseumawe, Kamis (20/7).

Mayoritas kargo LNG tersebut diserap oleh pembangkit listrik PT Perusahaan Listrik Negara (PLN). Kebutuhan untuk industri hanya satu kargo dari tahun ke tahun. Adapun rata-rata penyaluran gas dari fasilitas Regasifikasi

Arun di 2015 sebanyak 87,9 mmscfd. Rincfiannya, 6,05 mmscfd untuk PLN dan 1,85 mmscfd untuk industri di Medan. Kemudian pada tahun 2016, tepatnya di periode Januari-Oktober mencapai 88,81 mmscfd dengan rincian 85,86 mmscfd untuk PLN dan 2,95 mmscfd diserap industri. 

"Gas untuk PLN itu untuk PLTMG Arun dan Belawan. Kami dan PLN punya komitmen bersama. PLN punya kepentingan besar dengan regasifikasi," kata Surkani.

Kontan, Page-14, Friday, July 21, 2017

Year 2030 Indonesia Become Importer

Indonesia is expected to become an energy importer by 2030 because the deficit between supply and consumption in the year is getting bigger. Imports of energy are not only fossil energy, but also from renewable energy sources. Therefore, it needs innovation in developing new renewable energy that its potential in Indonesia is abundant.

This was raised in the discussion "The Future of Energy Security in Indonesia and the Role of Renewable Energy" on Thursday (20/7), on the campus of Multimedia Nusantara University Tangerang, Banten.

According to the Head of Center for Energy Studies of Gadjah Mada University, Yogyakarta Deendarlianto, if Indonesia's economic growth is above 5 percent per year, then the energy deficit will be bigger in 2030. It is estimated that in that year Indonesia will become non-fossil energy importer, besides remain oil importer And gas.

"The current condition, the dependence on fossil energy, namely oil and gas is very large. This will make the national energy mix target for new renewable energy types in 2025 difficult to achieve, "said Deendarlianto.

Expert Staff of the Supervisory Commission of SKK Migas, Abdul Muin, added that, as crude oil prices plummet today, the development of new renewable energy in Indonesia faces severe challenges. The cost of renewable energy production can not compete with oil that currently costs less than 50 US dollars per barrel.

Secretary of the Directorate General of New Energy, Renewable Energy and Conservation at the Ministry of Energy and Mineral Resources, Dadan Kusdiana, confirms that the priority of national energy development is to maximize the use of renewable energy.

"The challenges of its development are business schemes and incentives that are not yet optimal. In addition, the technology dependence from abroad is still large and the selling price of renewable energy is more expensive than fossil energy. Equally important is the similarity of mindset about the importance of developing new renewable energy in society, "said Dadan.

Regarding the development of nuclear energy into the new energy category, according to members of the National Energy Council, Tumiran, until now still a polemic. From the government's point of view, nuclear development as a source of energy is still a last resort. Without nuclear, achievement of 23 percent of renewable energy in the national energy mix is ​​difficult to achieve by 2025.

"If my academic view is personal, nuclear must enter. However, the political situation is not so. Though technologically the benefits of nuclear use are proven.

IN INDONESIA

Tahun 2030 Indonesia Jadi Importir

Indonesia diperkirakan menjadi pengimpor energi pada 2030 lantaran defisit antara pasokan dan konsumsi di tahun tersebut semakin membesar. Impor energi itu tidak hanya energi fosil, tetapi juga dari sumber energi baru terbarukan. Oleh karena itu, perlu inovasi dalam mengembangkan energi baru terbarukan yang potensinya di Indonesia melimpah.

Hal itu mengemuka dalam diskusi ”Masa Depan Ketahanan Energi Indonesia dan Peranan Energi Baru Terbarukan”, Kamis (20/7), di kampus Universitas Multimedia Nusantara Tangerang, Banten.

Menurut Kepala Pusat Studi Energi Universitas Gadjah Mada Yogyakarta Deendarlianto, jika pertumbuhan ekonomi Indonesia di atas 5 persen per tahun, maka defisit energi akan semakin besar di 2030. Diperkirakan, di tahun itu Indonesia akan menjadi pengimpor energi non-fosil, selain tetap menjadi pengimpor minyak dan gas.

”Kondisi sekarang ini, ketergantungan terhadap energi fosil, yaitu minyak dan gas bumi sangat besar. Hal ini akan membuat target bauran energi nasional untuk jenis energi baru terbarukan di 2025 sulit dicapai,” ujar Deendarlianto.

Staf Ahli Komisi Pengawas SKK Migas, Abdul Muin, menambahkan, di saat harga minyak mentah yang anjlok saat ini, pengembangan energi baru terbarukan di Indonesia menghadapi tantangan berat. Ongkos produksi energi baru terbarukan kalah bersaing dengan minyak yang saat ini harganya kurang dari 50 dollar AS per barrel.

Sekretaris Direktorat Jenderal Energi Baru, Terbarukan, dan Konservasi Energi pada Kementerian Energi dan Sumber Daya Mineral, Dadan Kusdiana, membenarkan, prioritas utama pengembangan energi nasional adalah dengan memaksimalkan penggunaan energi baru terbarukan.

”Tantangan pengembangannya adalah skema bisnis dan insentif yang belum optimal. Selain itu, ketergantungan teknologi dari luar negeri masih besar dan harga jual energi baru terbarukan lebih mahal daripada energi fosil. Yang tidak kalah penting adalah penyamaan pola pikir mengenai pentingnya pengembangan energi baru terbarukan di masyarakat,” kata Dadan. 

Mengenai pengembangan nuklir yang masuk dalam kategori energi baru, menurut anggota Dewan Energi Nasional, Tumiran, sampai saat ini masih menjadi polemik. Dari sudut pandang pemerintah, pengembangan nuklir sebagai sumber energi masih menjadi pilihan terakhir. Tanpa nuklir, pencapaian 23 persen dari energi baru terbarukan dalam bauran energi nasional sulit dicapai pada 2025.

”Kalau pandangan akademik saya pribadi, nuklir harus masuk. Namun, situasi politiknya tidak demikian. Padahal secara teknologi manfaat penggunaan nuklir banyak terbukti.

Kompas, Page-17, Friday, July 21, 2017

Enough Incentives?

The Ministry of Energy and Mineral Resources is intensively promoting incentives in the upstream oil and gas sector. The incentives are regulated in the issuance of Government Regulation No. 27 of 2017 which is the result of amendment to Government Regulation No. 79/2010 on Refundable Operating Costs and the Treatment of Income Tax in Upstream Oil and Gas Business Fields. Is that incentive enough?

The government said the issuance of Government Regulation No. 27/2017 is a big leap in the midst of challenges of upstream oil and gas industry in Indonesia and around the world which is getting heavier due to the crash of oil prices since late 2014. This Government Regulation is also referred to as government response to complaints submitted by contractors Oil and gas operating in Indonesia.

Tax incentives in Government Regulation No. 27/2017 include the abolition of import duty, Value Added Tax, Sales Tax on Luxury Goods (PPnBM), as well as the full abolition of Land and Building Tax (PBB). Special period of exploitation, still given based on economic considerations.

Previously, the government imposed a Land and Building Tax levy on upstream oil and gas exploration activities, including offshore exploration. These charges are complained of the Indonesian Petroleum Association because exploration is a search stage, not a risky production. The reason is, if exploration does not find oil, the cost that has been spent to be borne by the contractor. Already out trillions of rupiah, not producing oil, but still subject to Land and Building Tax. Once the contractor objected.

Upstream oil and gas business climate in Indonesia is sluggish. Oil prices that had touched above 100 dollars per barrel in early 2014, are slowly falling dramatically, even now less than 50 US dollars per barrel. This situation forces contractors to tighten their investments and apply efficiency.

Some contractors even returned the exploration block commitments to the government on the grounds that it is not economical. In ranking the easiness of investing in upstream oil and gas sector, Indonesia's position is not exactly good. Auction Oil and gas working areas in 2016, both conventional and non-conventional, do not get a single winner alias not in interest. In short, this business is no longer attractive, if it does not want to be called bleak.

In addition to the issuance of Government Regulation No. 27/2012, the government has also issued a response in the form of a revenue sharing model from the previous concept of cost recovery to gross split (profit sharing based on gross production). The concept of gross split is called government more efficient and attractive for investment.

Nevertheless, the government should not forget about the complexity of licensing that the contractor complained about. Based on data in 2015, there are 373 types of licenses to be dealt with by contractors, both at the central and regional levels. The Ministry of Energy and Mineral Resources has cut permits, from the original 42 species, to only six types. The spirit of change at the central level is positive, but not necessarily in the regions.

One of the things that the contractor still complains about, due to the poor coordination of central and regional, is the matter of land acquisition. Dozens of oil and gas contractors caught on this issue, either due to licensing in devious areas, to overlapping issues

The solution to the downturn of investment in upstream oil and gas sector must be integrated, from central to regional. The contribution of state revenues following the multiple effects of this sector can not be taken lightly. The government is on the right track although it still needs proof.

IN INDONESIA

Cukupkah Insentif?

Kementerian Energi dan Sumber Daya Mineral sedang gencar mempromosikan insentif di sektor hulu minyak dan gas bumi. Insentif itu diatur dalam penerbitan Peraturan Pemerintah Nomor 27 Tahun 2017 yang merupakan hasil perubahan Peraturan Pemerintah No 79/2010 tentang Biaya Operasi yang dapat Dikembalikan dan Perlakuan Pajak Penghasilan di Bidang Usaha Hulu Minyak dan Gas Bumi.  Cukupkah insentif itu?

Pemerintah menyebut, penerbitan Peraturan Pemerintah No 27/2017 ini sebagai sebuah lompatan besar di tengah tantangan industri hulu migas Indonesia dan di seluruh dunia yang semakin berat akibat keterpurukan harga minyak sejak akhir 2014. Peraturan Pemerintah ini juga disebut sebagai respons pemerintah terhadap keluhan yang disampaikan kontraktor migas yang beroperasi di Indonesia.

Insentif perpajakan dalam Peraturan Pemerintah No 27/2017 antara lain penghapusan bea masuk, Pajak Pertambahan Nilai, Pajak Penjualan atas Barang Mewah (PPnBM), serta penghapusan penuh Pajak Bumi dan Bangunan (PBB). Khusus periode eksploitasi, masih diberikan berdasarkan pertimbangan keekonomian.

Sebelumnya, pemerintah menerapkan pungutan Pajak Bumi dan Bangunan dalam kegiatan eksplorasi hulu migas, termasuk eksplorasi yang dilakukan di lepas pantai. Pungutan ini dikeluhkan Asosiasi Perminyakan Indonesia lantaran eksplorasi adalah tahap pencarian, bukan produksi yang penuh risiko. Pasalnya, jika eksplorasi tidak menemukan minyak, ongkos yang sudah telanjur dibelanjakan menjadi tanggungan kontraktor. Sudah keluar triliunan rupiah, tidak menghasilkan minyak, tetapi masih dikenakan Pajak Bumi dan Bangunan. Begitu keberatan kontraktor.

Iklim bisnis hulu migas di Indonesia sedang lesu. Harga minyak yang sempat menyentuh di atas 100 dollar AS per barrel di awal 2014, secara perlahan turun drastis, bahkan kini kurang dari 50 dollar AS per barrel. Situasi ini memaksa kontraktor mengetatkan Investasi dan menerapkan efisiensi.

Beberapa kontraktor bahkan mengembalikan komitmen blok eksplorasi kepada pemerintah dengan alasan tidak ekonomis. Dalam pemeringkatan kemudahan berinvestasi di sektor hulu migas, posisi Indonesia tidak bisa dibilang bagus. Lelang Wilayah kerja migas pada 2016, baik konvensional maupun non-konvensional, tidak mendapat satu pun pemenang alias tidak di minati. Ringkasnya, bisnis ini tidak lagi menarik, kalau tidak ingin disebut suram.

Selain penerbitan Peraturan Pemerintah No 27/2012 pemerintah juga sudah mengeluarkan respons berupa perubahan model bagi hasil dari sebelumnya berkonsep cost recovery menjadi gross split (bagi hasil berdasar produksi bruto). Konsep gross split disebut pemerintah lebih efisien dan menarik untuk investasi.

Meski demikian, pemerintah tidak boleh lupa mengenai kerumitan perizinan yang dikeluhkan kontraktor. Berdasarkan data di 2015, ada 373 jenis perizinan yang harus diurus kontraktor, baik di pusat maupun daerah. Kementerian ESDM sudah memangkas izin, dari semula 42 jenis, menjadi hanya enam jenis. Semangat perubahan di tingkat pusat sudah positif, tetapi belum tentu di daerah.

Salah satu hal yang masih dikeluhkan kontraktor, akibat buruknya koordinasi pusat dan daerah, adalah soal pembebasan lahan. Belasan kontraktor migas tersangkut masalah ini, baik karena perizinan di daerah yang berbelit-belit, hingga masalah yang tumpang tindih

Jalan keluar mengatasi kelesuan investasi sektor hulu migas harus terpadu, mulai dari pusat sampai daerah. Kontribusi penerimaan negara berikut efek berganda dari sektor ini tidak bisa dianggap sepele. Pemerintah sudah berada di jalur yang tepat meskipun masih perlu pembuktian. 

Kompas, Page-17, Friday, July 21, 2017

Arun LNG Revitalized

Perta Arun Gas is a subsidiary of PT Pertamina Gas. Perta Arun manages the regasification of liquefied natural gas / Arun LNG. PT Perta Arun Gas Production Plan & Process Engineering Manager Surkani Manan said the Arun LNG Plant last delivered LNG cargoes in October 2014.

The refinery, which previously produced 224 LNG cargoes in 1994, is no longer able to deliver gas because there are no more supplies from the nearest gas wells.

The LNG plant through PT Arun Natural Gas Liquefaction (NCL) previously received gas supplies from the North Sumatera Offshore Block and Block North Sumatra Block B. After the decline in production occurred, the government commissioned Pertamina to utilize the assets and built the regasification and receiving facility of LNG or floating storage regasification Unit (FSRU).

Arun FSRU processes LNG from Tangguh and Donggi-Senoro. The average production of Arun regasification facility in 2015 is 86.05 million cubic feet per day (MMscfd), which is distributed for PLN needs and 1.85 MMscfd for industries in Medan such as glass and ceramics producers.

In 2016, the regasification result for PLN 85.86 MMscfd and other gas users industries was 2.95 MMscfd. In fact, in terms of capacity, maximum regasification capability up to 405 MMscfd. Thus, the utilization of the Arun FSRU facility is only in the range of 20%. FSRU is a floating LNG receiving facility and converts liquefied natural gas back to natural gas.

The Tangguh refinery converts natural gas into LNG to be transported by ship. Then the LNG is classified in the FSRU to be returned to natural gas. To optimize the assets available in Arun, it will revitalize a number of gas storage tanks. Of the five LNG tanks, only two are still in use. Then, there will be four tanks that are enabled to store LPG or liquefied petroleum gas (LPG).

The capacity of LPG processing is planned 2x84.000 cubic meters from existing tanks and 60,000 cubic meters is the construction of new facilities. The plan, in the quarter I / 2018 tank can operate.

"The plan of I / 2018 is completed. Now it's still construction, "he said

PRICES GO DOWN

The government's move to lower gas prices downstream in Arun makes gas absorption slows down. This is a result of government efforts to reduce gas prices from US $ 12.22 per MMBtu to US $ 9.50 per MMBtu.

The decline in gas prices comes from the cuts in regasification costs, toll fees and lower gas prices (Tangguh and Donggi-Senoro). In addition to LNG supplied from Papua (Tangguh) and Central Sulawesi (Donggi-Senoro), Perta Arun Gas also obtains gas pipelines from NSO and NSB Blocks, so there is no need to go through the regasification process.

Gas delivered directly from the mouth of the well to the consumer through the pipeline is often called the gas pipe so there is no need for regasification process. Meanwhile, for the last 3 months gas of 33,000 cubic meters has not been absorbed. According to him, in terms of company revenue is reduced, but from the cargo side increased because of increasing demand for LNG by PLN.

IN INDONESIA

LNG Arun Direvitalisasi

Perta Arun Gas merupakan anak usaha PT Pertamina Gas. Perta Arun mengelola regasifikasi gas alam cair/LNG Arun. Manager Production Plan & Process Engineering PT Perta Arun Gas Surkani Manan mengatakan bahwa Kilang LNG Arun terakhir kali mengirimkan kargo LNG pada Oktober 2014.

Kilang yang sebelumnya pernah memproduksi 224 kargo LNG pada 1994 itu tidak lagi bisa mengirim gas karena sudah tidak ada lagi pasokan dari sumur gas terdekat.

Kilang LNG melalui PT Arun Natural Gas Liquefaction (NCL) sebelumnya mendapatkan pasokan gas dari Blok North Sumatra Offshore dan Blok North Sumatra Block B. Setelah penurunan produksi terjadi, pemerintah menugaskan Pertamina untuk memanfaatkan aset tersebut dan membangun fasilitas regasifikasi dan penerimaan LNG atau Floating Storage Regasification Unit (FSRU).

FSRU Arun mengolah LNG dari Tangguh dan Donggi-Senoro. Rerata produksi dari fasilitas regasifikasi Arun pada 2015 sebesar 86,05 juta kaki kubik per hari (MMscfd) yang disalurkan untuk kebutuhan PLN dan 1,85 MMscfd untuk industri di Medan seperti produsen kaca dan keramik.

Pada 2016, hasil regasifikasi untuk PLN 85,86 MMscfd dan industri pengguna gas Iainnya 2,95 MMscfd. Padahal, dari sisi kapasitas, kemampuan regasifikasi maksimum hingga 405 MMscfd. Dengan demikian utilisasi fasilitas FSRU Arun hanya di kisaran 20%. FSRU merupakan fasilitas penerima LNG terapung dan mengubah kembali gas alam cair ke gas bumi. 

Kilang Tangguh mengubah gas bumi menjadi LNG agar dapat diangkut dengan kapal. Kemudian LNG itu diregasifikasi di FSRU untuk dikembalikan menjadi gas bumi. Untuk mengoptimumkan aset yang tersedia di Arun, pihaknya akan merevitalisasi sejumlah tangki penyimpanan gas. Dari lima tangki LNG, hanya dua yang masih digunakan. Kemudian, akan terdapat empat tangki yang difungsikan untuk menyimpan elpiji atau liquefied petroleum gas (LPG) .

Kapasitas pengolahan elpiji itu direncanakan 2x84.000 meter kubik berasal dari tangki yang sudah ada dan 60.000 meter kubik merupakan pembangunan fasilitas baru. Rencananya, pada kuartal I/2018 tangki bisa beroperasi. 

“Rencananya kuartal I/2018 selesai. Sekarang masih konstruksi,” katanya 

HARGA TURUN

Adapun langkah pemerintah menurunkan harga gas di tingkat hilir di Arun membuat penyerapan gas melambat. Hal itu akibat dari upaya pemerintah menurunkan harga gas dari US$12,22 per MMBtu menjadi US$9,50 per MMBtu.

Penurunan harga gas berasal dari pemangkasan biaya regasifikasi, sewa pipa (toll fee) dan penurunan harga gas di tingkat hulu (Tangguh dan Donggi-Senoro). Selain LNG yang dipasok dari Papua (Tangguh) dan Sulawesi Tengah (Donggi-Senoro), Perta Arun Gas juga mendapatkan pasokan gas pipa dari Blok NSO dan NSB sehingga tidak perlu melalui proses regasifikasi.

Gas yang disalurkan langsung dari mulut sumur ke konsumen melalui pipa sering disebut dengan gas pipa sehingga tidak perlu ada proses regasifikasi. Sementara itu, selama 3 bulan terakhir gas sebanyak 33.000 meter kubik belum terserap. Menurutnya, dari segi pendapatan perusahaan berkurang, tetapi dari sisi kargo naik karena bertambahnya permintaan LNG oleh PLN. 

Bisnis Indonesia, Page-30, Friday, July 21, 2017