ABP wells in close

Rig on the move to the well pecuk 01 Lamongan

White Albatros oil wells (ABP) in the village of Jamprong, Sub-District Kenduruan drilled PT Pertamina EP Cepu Field Asset 4 is declared closed. Drilling was discontinued settlement like any other oil wells following the drilling constraints.

"Drilling has reached a depth of peak, but was not pursued at the stage of completion or completion of the said Field Manager of PT Pertamina EP Cepu Field Asset 4 Agus Amperianto yesterday (6/3).

Therefore, rig or drilling tool at the location will be moved. Furthermore, the well is capped and casted. Closure of these wells to safeguard potential underground pressure that may arise. Also, securing the operation and the environment. Therefore, the unpredictable potential emerging from underground. "Completion or completion of the work did not proceed because management wants to evaluate potential problems at a depth of 1,100 meters.

Furthermore, continued the former public relations manager of PT Pertamina, the institute will move to the exploration to other areas, namely in the Well Pecuk-01 in Lamongan. It was to see the potential for oil and gas in the basin East cross beam. One of them in the region in Lamongan.

"Because there is some correlation and estimated surface that should be revisited. several times the problem still occurs dawn hole well bore, ".

Because of its nature or proving exploration drilling and surveys, so could only predicted the problems that occur and how to map the problem. So is the problem underground will appear.

"In the case of wells in this Jamprong, issues that arise at a depth of 1,100 meters that we will have correlated at that depth with drilling plans in the Well Pecuk," he stated.

     Although closed, there is still the possibility of wells ABP reopened. That was done after the known problems that occurred and solutions in accordance with the conditions of the well drilling in Lamongan. "It is possible we will work again on the well ABP by leveraging the data we've gained when driling in ABP01". 

Reported earlier, approaching the peak depth, drilling exploration wells White Albatros 01 obstacles had emerged. From the bursts appear jetted wells or down hole and a spray of water (water kick). So many days officers in the field to focus on completing these constraints. Drilling was conducted from December 20 to a depth of 1,275 meters.

IN INDONESIAN

Sumur ABP Di tutup

Sumur minyak Albatros Putih (ABP) di Desa Jamprong, Kecamatan Kenduruan yang dibor PT Pertamina EP Asset 4 Field Cepu dinyatakan ditutup. Pengeboran itu tidak dilanjutkan penyelesaiannya seperti layaknya sumur minyak lain menyusul terjadinya kendala pemboran. 

"Pemboran sudah mencapai kedalaman puncak, namun tidak dilanjutkan pada tahap komplesi atau penyelesaian ujar Field Manajer PT Pertamina EP Asset 4 Field Cepu Agus Amperianto kemarin (6/3).

Karena itu, rig atau alat bor di lokasi akan dipindahkan. Selanjutnya, sumur ditutup dan dicor. Penutupan sumur tersebut untuk mengamankan potensi tekanan bawah tanah yang mungkin timbul. Juga, mengamankan operasi dan lingkungan. Sebab, tidak bisa diprediksi potensi yang muncul dari bawah tanah. "Komplesi atau pekerjaan penyelesaian itu tidak dilanjutkan karena manajemen ingin mengevaluasi potensi permasalahan pada kedalaman 1.100 meter.

Selanjutnya, lanjut mantan manajer humas PT Pertamina itu, pihaknya akan pindah untuk eksplorasi ke daerah lain, yakni di Sumur Pecuk-01 di Lamongan. Hal itu untuk melihat potensi migas di cekungan lawa Timur. Salah satunya di kawasan di Lamongan tersebut.

“Karena ada beberapa korelasi dan perkiraan surface yang harus ditinjau kembali. beberapa kali masih terjadi problem dawn hole well bore,".

Karena sifatnya pengeboran eskplorasi atau pembuktikan serta survei, sehingga hanya bisa memerkirakan masalah yang terjadi dan bagaimana memetakan persoalan. Begitu juga masalah di bawah tanah yang akan muncul.

"Dalam kasus sumur di Jamprong ini, persoalan yang muncul pada kedalaman 1.100 meter itu akan kita korelasikan pada kedalaman tersebut dengan rencana pengeboran di Sumur Pecuk ," tegas dia. 

    Meski ditutup, masih ada kemungkinan sumur ABP dibuka kembali. ltu dilakukan setelah diketahui persoalan yang terjadi dan solusinya sesuai dengan kondisi pengeboran di sumur Lamongan. "Tidak menutup kemungkinan kita akan bekerja lagi di sumur ABP dengan memanfaatkan data-data yang telah kita peroleh saat driling di ABP01,".

Diberitakan sebelumnya, mendekati kedalaman puncak, pengeboran eksplorasi di sumur Albatros Putih 01 sempat muncul kendala. Dari dalam sumur muncul semburan air deras atau down hole serta semburan air (kick water). Sehingga berhari-hari petugas di lapangan fokus untuk menyelesaikan kendala tersebut. Pengeboran dilakukan sejak 20 Desember dengan kedalaman 1.275 meter.

Radar Jenu, Page-32, Tuesday, March, 7, 2017

Pertamina Needs Fund's Rp 500 Trillion

PT Pertamina requires more than Rp 500 trillion for investment construction of two new refineries and increased capacity of four old refineries. The program is part of a megaproject refineries to reach the target production capacity of 2 million barrels per day in 2023

Vice President Corporate Communications of Pertamina Wianda Pusponegoro said, in addition to using capital company, Pertamina also need third-party funds to build new refineries and increase the capacity of the old refineries. Pertamina will be attracting investors through a scheme of joint venture (joint venture) or consortium.

"To build a new refinery needs to invest 10-12 billion dollars, while for up grading (increased capacity) need 5-6 billion US dollars. So, if there were plans to build two new refineries and four refineries which you want to up grade, need at least 40 billion US dollars, "said Wianda, Monday (6/3), in Jakarta.

Assuming Rp 13,000 per US dollar, the investment needs of 40 billion US dollars, equivalent to more than Rp 500 trillion. The number is far below Pertamina capital expenditure is on average less than US $ 4 billion per year, or around Rp 52 trillion.

Two new refineries to be built in Tuban, East Java, and in Bontang, East Kalimantan. The four oil refineries are included in refinery development program, is the Balongan refinery in West Java, Cilacap refinery in Central Java, refinery Dumai refinery in Riau and Balikpapan, East Kalimantan.

"For the refinery Tuban in East Java, we use the scheme of joint venture with Rosneft (Russian oil company), while the development of the Cilacap refinery joint venture with Saudi Aramco (Saudi Arabian oil company)," said Wianda.

Oil refinery construction-related schemes, Executive Director of the Institute Komaidi ReforMiner Notonegoro said, need to prudential regulations implementing the Minister of Energy and Mineral Resources (ESDM) on the implementation of the construction of oil refineries in the country by private entities. In the ruling, the domestic oil refineries could be built entirely by the private sector

"Fuel oil is a commodity that dominate the life of many. Therefore, the production branch is mandated by the constitution to be controlled by the state. These rules need to be reviewed, "said Komaidi.

Submission to the private sector to make state control is becoming weaker. It is different from SOE assignment scheme or a scheme of cooperation of government entities (KPBU) as stipulated in Presidential Decree No. 146 Year 2015 on the Implementation of Construction and Development of Domestic Refinery. The scheme allows no state control.

IN INDONESIAN

Pertamina Butuh Dana Rp 500-an Triliun

PT Pertamina membutuhkan dana lebih dari Rp 500 triliun untuk investasi pembangunan dua kilang baru dan peningkatan kapasitas empat kilang lama. Program itu merupakan bagian dari megaproyek kilang untuk mencapai target kapasitas produksi 2 juta barrel per hari pada 2023

Vice President Corporate Communication Pertamina Wianda Pusponegoro mengatakan, selain menggunakan modal perusahaan, Pertamina juga butuh dana pihak ketiga untuk membangun kilang baru maupun peningkatan kapasitas kilang-kilang lama. Pertamina akan menjaring investor lewat skema joint venture (perusahaan patungan) atau konsorsium.

”Untuk membangun kilang baru perlu investasi 10-12 miliar dollar AS, sedangkan untuk up grading (peningkatan kapasitas) membutuhkan 5-6 miliar dollar AS. Jadi, kalau ada rencana membangun dua kilang baru dan empat kilang yang hendak di-up grade, setidaknya butuh 40 miliar dollar AS,” ujar Wianda, Senin (6/3), di Jakarta.

Dengan asumsi Rp 13.000 per dollar AS, kebutuhan investasi 40 miliar dollar AS tersebut setara dengan lebih dari Rp 500 triliun. Angka tersebut jauh di bawah belanja modal Pertamina yang rata-rata kurang dari 4 miliar dollar AS per tahun atau sekitar Rp 52 triliun.

Dua kilang baru yang akan dibangun berlokasi di Tuban, Jawa Timur, dan di Bontang, Kalimantan Timur. Adapun empat kilang Pertamina yang masuk dalam program pengembangan kilang, adalah kilang Balongan di Jawa Barat, kilang Cilacap di Jawa Tengah, kilang Dumai di Riau dan kilang Balikpapan, Kalimantan Timur.

”Untuk kilang Tuban di Jawa Timur, kami menggunakan skema joint venture dengan Rosneft (perusahaan migas Rusia), sedangkan pengembangan kilang Cilacap joint venture dengan Saudi Aramco (perusahaan migas Arab Saudi),” kata Wianda. 

Terkait skema pembangunan kilang minyak, Direktur Eksekutif ReforMiner Institute Komaidi Notonegoro mengatakan, perlu kehati-hatian melaksanakan peraturan Menteri Energi dan Sumber Daya Mineral (ESDM) tentang pelaksanaan pembangunan kilang minyak di dalam negeri oleh badan usaha swasta.  Dalam peraturan itu, kilang minyak di dalam negeri bisa dibangun sepenuhnya oleh pihak swasta 

”Bahan bakar minyak merupakan komoditas yang menguasai hajat hidup orang banyak. Oleh karena itu, cabang produksinya diamanatkan oleh konstitusi agar dikuasai negara. Aturan ini perlu ditinjau ulang,” ujar Komaidi.

Penyerahan kepada swasta membuat kontrol negara menjadi lemah. Hal itu berbeda dengan Skema penugasan BUMN atau skema Kerja sama Pemerintah Badan Usaha (KPBU) seperti yang diatur dalam Peraturan Presiden Nomor 146 Tahun 2015 tentang Pelaksanaan Pembangunan dan Pengembangan Kilang di Dalam Negeri. Skema itu memungkinkan ada kontrol negara. 

Kompas, Page-18, Tuesday, March, 7, 2017

Oil Prices Rise Thin

ICP Moving

The average price of oil Indonesia (Indonesian crude price / ICP) in February 2017 rose to US $ 0.62 per barrel or 1.2%, to US $ 52.5 per barrel compared to the previous month of US $ 51.88 per barrel.

The rise in oil prices is influenced by several things such as the strengthening of world crude oil as the reference, the level of production, projected demand and commercial stock. Based DG page Oil and Gas Kementenan EMR, Monday (6/3), from the aspect of the price of the Brent crude oil benchmark, West Texas Intermediate (WTI) and the OPEC Basket, three types of oil rose.

The average oil price in February for Brent of US $ 56 per barrel, up US $ 0.55 from US $ 55.45 per barrel. Meanwhile, WTI rose US $ 0.85 a barrel to US $ 53.46 per barrel from US $ 52.61 per barrel in January. Then, the OPEC Basket was up US $ 0.97 per barrel to US $ 53.37 and US $ 52.4 per barrel in January.

On the production side that recorded lnternational Energy Agency (IEA) in February 2017, states that are members of the organization of oil exporting countries (OPEC) to reduce production reached 1 million barrels per day (bpd). Meanwhile, world oil production in February dropped 1.48 million bpd to 96.39 million bpd from 97.87 million bpd the previous month.

Based on the projection data set demand OPEC, world oil demand is expected to increase by 0.25 million bpd to 94.84 million bpd in the first quarter / 2017. The projected increase in crude oil demand was seen from the data IEA estimates that demand in the first quarter / 2017 was up 0.1 million bpd to 97 million bpd.

Meanwhile, gasoline stocks fell 0.7 million barrels to 256.4 million barrels. Senior vice president of Moody's Investors Service Teny Marshall said, based on the results of the review, crude oil prices will be maintained in the range of US $ 40-US $ 60 per barrel until 2018 for Brent and WTI.

"Expectations of our medium-term was extended until 2018 the most relevant price used to estimate the financial performance and demonstrate corporate rating and the oil-exporting countries," he said through a press release on Monday (6/3).

Pertamina Finance Director Arief Budiman said, this year's special pertained to the position of oil prices range from US $ 40-US $ 60 per barrel. The reason, the company had to face the possibility of switching oil price of $ 40 towards $ 60 a barrel that will affect the business activities of upstream and downstream oil and gas.

Oil prices in the range of US $ 40 per barrel, will bring benefits in the downstream business lines. That, which occurred in 2016 when the downstream sector accounted for 60% of revenue. Low oil prices eventually push fuel sales of non-subsidized Pertamax and Pertalite so positive performance throughout 2016.

IN INDONESIAN

Pergerakan ICP

Harga Minyak Naik Tipis

Rata-rata harga minyak Indonesia (Indonesian crude price/ICP) pada Februari 2017 naik US$ 0,62 per barel atau 1,2% menjadi US$ 52,5 per barel dibandingkan dengan bulan sebelumnya US$ 51,88 per barel.

Kenaikan harga minyak dipengaruhi oleh beberapa hal seperti penguatan minyak mentah dunia yang menjadi acuan, tingkat produksi, proyeksi permintaan dan stok komersial. Berdasarkan laman Ditjen Minyak dan Gas Bumi Kementenan ESDM, Senin (6/3), dari aspek harga minyak mentah acuan yakni Brent, West Texas Intermediate (WTI) dan Basket OPEC, ketiga jenis minyak itu naik.

Rata-rata harga minyak pada Februari untuk jenis Brent US$ 56 per barel atau naik US$ 0,55 dari US$ 55,45 per barel. Sementara, jenis WTI naik US$ 0,85 per barel menjadi US$ 53,46 per barel dari US$ 52,61 per barel pada Januari. Kemudian, Basket OPEC pun naik US$ 0,97 per barel menjadi US$ 53,37 dan US$ 52,4 per barel pada Januari.

Dari sisi produksi yang dicatat lnternational Energy Agency (IEA) pada Februari 2017, negara yang tergabung dalam organisasi negara pengekspor minyak (OPEC) menurunkan produksi mencapai 1 juta barel per hari (bph). Sementara itu, produksi minyak dunia pada Februari turun 1,48 juta bph menjadi 96,39 juta bph dari bulan sebelumnya 97,87 juta bph. 

Berdasarkan data proyeksi permintaan yang ditetapkan OPEC, permintaan minyak dunia diperkirakan naik 0,25 juta bph menjadi 94,84 juta bph pada pada kuartal I/2017. Proyeksi kenaikan permintaan minyak mentah pun terlihat dari data IEA yang memperkirakan permintaan pada kuartal I/2017 naik 0,1 juta bph menjadi 97 juta bph. 

Sementara itu, stok gasoline turun 0,7 juta barel menjadi 256,4 juta barel. Senior Vice President Moody’s Investors Service Teny Marshall mengatakan, berdasarkan hasil review, harga minyak mentah dunia masih akan bertahan di kisaran US$ 40-US$ 60 per barel sampai 2018 untuk Brent dan WTI. 

“Ekspektasi jangka menengah kami diperpanjang sampai 2018 merupakan harga yang paling relevan yang digunakan untuk mengestimasikan performa keuangan dan menunjukkan rating korporasi dan negara-negara pengekspor minyak,” ujarnya melalui siaran persnya, Senin (6/3).

Direktur Keuangan Pertamina Arief Budiman mengatakan, pada tahun ini tergolong spesial dengan posisi harga minyak berkisar US$ 40-US$ 60 per barel. Alasannya, perseroan harus menghadapi kemungkinan peralihan harga minyak dari US$ 40 menuju US$ 60 per barel yang akan berpengaruh terhadap kegiatan usaha hulu dan hilir migas.

Harga minyak di kisaran US$ 40 per barel, akan memberi keuntungan di lini usaha hilir. Hal itu, yang terjadi pada 2016 ketika sektor hilir menyumbang 60% pendapatan perseroan. Rendahnya harga minyak akhirnya mendorong penjualan bahan bakar minyak non-subsidi seperti Pertamax dan Pertalite sehingga kinerja sepanjang 2016 positif.

Bisnis Indonesia, Page-30, Tuesday, March, 7, 2017

Waiting Beleid Fiscal lnsentif

Upstream Investment

The planned revision of Government Regulation No. 79/2010 on the cost of operation Refundable Income Tax and the Treatment in the Field Upstream Oil and Gas has emerged since the beginning of the formation of the Cabinet Works.

Upstream oil and gas business actors are still awaiting the results of the revision of PP 79. meskiun Director General of Oil and Gas Ministry of Energy and Mineral Resources Wiratmaja Puja explained that the draft revision of a regulation that has been in the Palace.

Regulation that regulates the upstream oil and gas operating costs that can be restored or cost recovery and taxation. In fact, today is no longer valid regime of production sharing scheme cost recovery because it has been replaced with dirty or gross revenue share split.

However, government regulations cost recovery are still needed because there are still 288 working areas using a scheme for the results. Split gross scheme will be used for new oil and gas blocks or working areas which returned to government (termination), whereas the old block contracts continue to use cost recovery scheme.

Through the issuance of such a regulation, businesses hope that the principle or principles assume and discharge responsibility and liberation Additional taxes by governments other than that recorded in the same employment contract can be re-applied as when a regulation has not yet been issued.

Currently, the upstream activities of oil and gas is currently taxed as land and building tax (PBB), tax (income tax), the tax value addition (VAT), the VAT for the costs of shared facilities, local taxes, and the tax transfer of shares of participation working area.

Thus, the contractors do not need to spend money to pay additional taxes although eventually be refunded through the cost recovery scheme.

Expenditure is considered unbalanced because there is a change in the nominal value and the costs incurred at the moment and will be replaced by the government. Contractors may obtain reimbursement if the field already in production which has a range of up to 10 years from the time of the search or exploration of oil and gas resources.

Executive Director of the Indonesian Petroleum Association (IPA) Marjolijn Wajong said it could not comment further regarding the impact of the issuance of the revised Regulation 79 of the upstream oil and gas industry.

According to him, it needs to see in advance whether a revision which will published in accordance with industry expectations. "We have not seen the latest draft. So, we wait, "he said.

Meanwhile, Director General of Oil and Gas at the Ministry of Energy and Mineral Resources (ESDM) IGN Wiratmaja Puja said it was waiting for the publication of such a regulation. Because the entire discussion with the Ministry of Finance has been completed.

IRR UP

He also hoped that the project could go up the economic field. As an illustration, in general, the ratio of return on capital (internal rate of return / IRR) field ranging from 5% -34%. Field crickets in the Muara Bakau block (ENI), has a lower IRR of around 5% -6%. IRR variation of the field, due to the condition and the risk of developing different field. Therefore, it wants to be a contractor can get a minimum 12% IRR. "IRR varies the pitch there is a very low Crickets 5%, 6%" said Wiratmaja.

There is high to 34%. Because of different pitch, different challenge. We wanted an average pitch of 12%, but there are very low. "

Head of State Revenue Policy Fiscal Policy Office (BKF) Ministry of Finance Goro Ekanto said tax privileges will not be given freely. However, he said, will be given facilities equivalent to assume and discharge that ensures the upstream business activity tax is not charged during the contract period runs.

In addition to publishing the revision of Government Regulation No. 79, it will be issued the Finance Minister Regulation (PMK) to regulate the taxation details. However, he admitted, with these instruments, all taxes can not simply be eliminated because it refers to Article 31 of Law No. 22/2001 on Oil and Gas, a business entity that upstream business activity must pay taxes.

Meanwhile, with tax facilities, there will be no mechanism to recover taxes paid on a regulation before the change is made. According to him, all the changes made will not be contrary to the oil and gas law.

"There should be no refund, assume and discharge in the Act are also not allowed. We adjust there, but we give similar facilities. "May revision of Government Regulation No. 79 forthcoming and more exciting upstream oil and gas investment climate in the country.

IN INDONESIAN

Menanti Beleid lnsentif Fiskal

Rencana revisi Peraturan Pemerintah No. 79/2010 tentang biaya Operasi yang Dapat Dikembalikan dan Perlakuan Pajak Penghasilan di Bidang Usaha Hulu Minyak dan Gas Bumi sudah muncul sejak awal terbentuknya Kabinet Kerja. 

Pelaku usaha sektor hulu migas hingga saat ini masih menunggu hasil revisi PP 79. Meskiun Dirjen Minyak dan Gas Bumi Kementerian ESDM Wiratmaja Puja menjelaskan bahwa draf revisi beleid tersebut telah berada di Istana.

Regulasi itu mengatur soal biaya operasi hulu migas yang dapat dikembalikan atau cost recovery dan perpajakan. Padahal, saat ini sudah tidak berlaku lagi rezim skema bagi hasil produksi cost recovery karena telah digantikan dengan bagi hasil kotor atau gross split. 

     Namun, Peraturan Pemerintah cost recovery masih tetap dibutuhkan karena masih ada 288 wilayah kerja yang menggunakan skema bagi hasil tersebut. Skema gross split akan digunakan untuk blok migas baru atau wilayah kerja yang dikembalikan ke pemerintah (terminasi), sedangkan kontrak blok lama tetap menggunakan skema cost recovery.

Melalui penerbitan beleid tersebut, pelaku usaha berharap agar prinsip assume and discharge atau prinsip penanggungan dan pembebasan pajak-pajak tambahan oleh pemerintah selain yang tertulis dalam kontrak kerja sama bisa kembali diterapkan seperti ketika beleid tersebut belum dikeluarkan. 

Saat ini, kegiatan usaha hulu minyak dan gas bumi saat ini dikenakan pajak seperti pajak bumi dan bangunan (PBB), pajak penghasilan (PPh), pajak penambahan nilai (PPN), PPN untuk biaya fasilitas bersama, pajak daerah, dan pajak pengalihan saham partisipasi wilayah kerja.

Dengan demikian, kontraktor tidak perlu mengeluarkan biaya untuk membayar pajak tambahan meskipun akhirnya bisa dikembalikan melalui skema cost recovery.

Pengeluaran biaya tersebut dianggap tidak seimbang karena terdapat perubahan nilai dan nominal biaya yang dikeluarkan saat ini dan nantinya diganti pemerintah. Kontraktor bisa mendapat penggantian  biaya bila lapangan sudah berproduksi yang memiliki jarak hingga 10 tahun dari masa pencarian sumber migas atau eksplorasi. 

Direktur Eksekutif  Indonesian Petroleum Association (IPA) Marjolijn Wajong mengatakan, pihaknya belum bisa berkomentar lebih lanjut terkait dampak penerbitan revisi PP 79 terhadap industri hulu migas. 

Menurutnya, pihaknya perlu melihat terlebih dahulu apakah revisi yang nantinya terbit sesuai dengan harapan industri. “Kami belum melihat draf yang paling akhir. Jadi, kami tunggu dulu,” ujarnya.

Sementara itu, Direktur Jenderal Minyak dan Gas Bumi Kementerian Energi dan Sumber Daya Mineral (ESDM) IGN Wiratmaja Puja mengatakan, pihaknya pun menanti terbitnya beleid tersebut. Pasalnya, seluruh pembahasan dengan Kementerian Keuangan telah selesai.

IRR NAIK 

Dia pun berharap agar keekonomian lapangan proyek bisa naik. Sebagai gambaran, secara umum, rasio pengembalian modal (internal rate of return/ IRR) lapangan mulai dari 5%-34%. Lapangan Jangkrik di Blok Muara Bakau (ENI), memiliki IRR yang rendah yakni sekitar 5%-6%. Bervariasinya IRR lapangan, disebabkan kondisi dan risiko pengembangan lapangan yang berbeda-beda. Oleh karena itu, pihaknya menginginkan agar kontraktor bisa mendapat IRR minimum 12%. “IRR lapangan itu bervariasi ada yang rendah sekali Jangkrik 5%, 6%" kata Wiratmaja.

Ada yang tinggi sampai 34%. Karena beda lapangan, beda tantangannya. Kami inginnya rata-rata lapangan 12%, tetapi ada yang sangat rendah sekali.”

Kepala Pusat Kebijakan Pendapatan Negara Badan Kebijakan Fiskal (BKF) Kementerian Keuangan Goro Ekanto mengatakan, fasilitas perpajakan tidak akan diberikan secara bebas. Namun, dia menyebut, akan diberikan fasilitas yang setara dengan assume and discharge yang menjamin kegiatan usaha hulu tidak dibebankan pajak selama masa kontrak berjalan. 

Selain menerbitkan revisi Peraturan Pemerintah No. 79, pihaknya akan mengeluarkan Peraturan Menteri Keuangan (PMK) untuk mengatur secara detail perpajakan itu. Namun, dia mengakui, dengan instrumen tersebut, semua pajak tidak bisa begitu saja dihilangkan karena mengacu pada Pasal 31 Undang-Undang No. 22/2001 tentang Minyak dan Gas Bumi, badan usaha yang melakukan kegiatan usaha hulu wajib membayar pajak.

Adapun, dengan pemberian fasilitas perpajakan, tidak akan ada mekanisme pengembalian pajak yang telah dibayarkan sebelum perubahan atas beleid tersebut dilakukan. Menurutnya, semua perubahan yang dilakukan tidak akan bertentangan dengan Undang-Undang Migas.

“Seharusnya tidak ada pengembalian, assume and discharge secara Undang-Undang juga tidak diperbolehkan. Kita sesuaikan disitu, tetapi kita berikan fasilitas setara.” Semoga revisi Peraturan Pemerintah No. 79 segera terbit dan makin menggairahkan iklim investasi hulu migas di Tanah Air.

Bisnis Indonesia, Page-30, Tuesday, March, 7, 2017

Government to Increase Impor LPG from Iran

Ministry of Energy asking price discount.

Ministry of Energy and Mineral Resources is exploring the addition of imported liquified petroleum gas (LPG) from Iran, next year. Procurement volume will be increased from currently approximately 600 thousand metric tons to 1 million tons of LPG.

"We are currently evaluate," said Director General of Oil and Gas of the Ministry of Energy, I Gusti Nyoman Wiratmaja, told Tempo yesterday. Indonesia's efforts to lobby the additional volume of imports was accompanied by a demand for discount prices. Known, the value of LPG supply contract signed in May last year reached US $ 60 million. But the realization of new deliveries in the last year amounted to 88 thousand tons. The rest will be delivered this year.

Wiratmaja said the additional import aims to anticipate the surge in LPG consumption. The Ministry of Energy noted LPG subsidy spending rose an average of 13 percent each year.

Based on the State Budget (APBN) in 2017, the quota of subsidized LPG set of 7.09 million metric tons, an increase compared to last year's quota at 6.25 million metric tons. Increasing the quota granted in line with the policy division of 537 thousand packages of the prime LPG conversion program from kerosene.

Pertamina marketing director, Alexander predicts fund subsidy borne by the government this year increased. Therefore, assuming Crude Price Aramco, which is used as the benchmark price in the state budget, only US $ 300 per metric ton. And now prices have gone up slowly in the range of US $ 320 per metric ton. "The energy subsidy in the amount of LPG," said Iskandar.

Deputy Minister of Energy Arcandra Tahar hope Iran can meet 10 percent of domestic LPG import requirement or about 700 thousand tons per year. Today, almost the entire supply of LPG imports from Saudi Arabia. "We expect a maximum of about 10 percent of the LPG import requirement."

Arcandra argued the government is also eyeing management cooperation two Iranian oil fields, the Ab-Teymour and Mansouri. Two field holds the potential of up to 3 billion barrels of oil. That figure is equivalent to the entire Indonesia's proven oil reserves were 3.8 billion barrels.

If cooperation is realized, production from the two fields will reach 400 thousand barrels per day. The amount is equivalent to 37 percent of oil production the national average a year. According Arcandra, Iran responded positively to the plan.

Pertamina Upstream Director Syamsu Alam previous said oilfield management proposals already submitted in the last month. Syamsu said Pertamina has sent a team to Iran several times to start the preliminary technical studies for approximately four months. Another aspect in the review are technical issues and legal compliance.

"We hope this proposal became the foundation of both companies to negotiate on the management of both large field," said Syamsu.

Iran is the country with the fourth largest oil reserves in the world. The country has proven oil reserves of 157 billion barrels, or 9.3 percent of total proven reserves in the world. While the proven gas reserves, which is as much as 1,200 trillion cubic feet, is the largest in the world, or the equivalent of 18.2 percent of the total global gas reserves.

Iran is also committed to supply crude oil by 150 thousand barrels per day with an investment commitment of US $ 5 billion. But waiting for certainty of supply of oil refinery construction in Situbondo, East Java. Two companies, namely PT Kilanindo Golden Star and the National Iranian Oil Company (NIOC), has signed a financial agreement

IN INDONESIAN

Pemerintah Naikkan Impor LPG dari Iran

Kementerian Energi meminta harga 

diskon.

Kementerian Energi dan Sumber Daya Mineral sedang menjajaki penambahan impor liquified petroleum gas (LPG) dari Iran, tahun depan. Volume pengadaan akan ditambah dari saat ini sekitar 600 ribu metrik ton LPG menjadi 1 juta ton.

“Kami sedang mengevaluasinya,” kata Direktur Jenderal Minyak dan Gas Bumi Kementerian Energi, I Gusti Nyoman Wiratmaja, kepada Tempo, kemarin. Upaya Indonesia melobi tambahan volume impor itu disertai dengan permintaan diskon harga. Diketahui, nilai kontrak pengadaan LPG yang diteken pada Mei tahun lalu mencapai US$ 60 juta. Tapi realisasi pengiriman pada tahun lalu baru sebesar 88 ribu ton. Sisanya akan dikirimkan pada tahun ini. 

Wiratmaja mengatakan penambahan impor bertujuan untuk mengantisipasi lonjakan konsumsi LPG. Kementerian Energi mencatat pengeluaran subsidi LPG naik rata-rata 13 persen setiap tahun.

Berdasarkan Anggaran Pendapatan dan Belanja Negara (APBN) 2017, kuota LPG bersubsidi ditetapkan 7,09 juta metrik ton, atau naik dibanding jatah pada tahun lalu sebesar 6,25 juta metrik ton. Peningkatan kuota diberikan seiring dengan kebijakan pembagian 537 ribu paket perdana LPG dalam program konversi minyak tanah.

Direktur Pemasaran Pertamina, Iskandar memprediksi dana subsidi yang ditanggung pemerintah pada tahun ini bertambah besar. Sebab, asumsi Crude Price Aramco, yang digunakan sebagai patokan harga dalam APBN, hanya US$ 300 per metrik ton.  Padahal saat ini harga sudah naik secara perlahan di kisaran US$ 320 per metrik ton. “Subsidi energi besarnya di LPG,” kata Iskandar.

Wakil Menteri Energi Arcandra Tahar berharap Iran bisa memenuhi 10 persen kebutuhan impor LPG domestik atau sekitar 700 ribu ton per tahun. Saat ini, hampir seluruh pasokan LPG impor berasal  dari Arab Saudi. “Kami berharap maksimal sekitar 10 persen dari kebutuhan impor LPG.”

Arcandra mengemukakan pemerintah juga mengincar kerja sama pengelolaan dua lapangan minyak Iran, yaitu Ab-Teymour dan Mansouri. Dua lapangan ini menyimpan potensi minyak hingga 3 miliar barel. Angka itu setara dengan cadangan minyak terbukti seluruh Indonesia yang mencapai 3,8 miliar barel.

Jika kerja sama terealisasi, produksi dari kedua lapangan itu akan mencapai 400 ribu barel per hari. Jumlah itu setara dengan 37 persen produksi minyak rata-rata nasional setahun. Menurut Arcandra, Iran menyambut positif rencana itu.

Direktur Hulu Pertamina Syamsu Alam sebelumnya mengatakan proposal pengelolaan ladang minyak sudah diajukan pada bulan lalu. Syamsu mengatakan Pertamina sudah mengirim tim ke Iran beberapa kali untuk memulai studi teknis pendahuluan selama kurang-lebih empat bulan. Aspek lain yang di tinjau adalah persoalan teknis dan kepatuhan hukum.

“Kami berharap proposal ini menjadi landasan kedua perusahaan untuk bernegosiasi pada pengelolaan kedua lapangan besar itu,” kata Syamsu.

Iran merupakan negara dengan cadangan minyak terbesar keempat di dunia. Negeri itu memiliki cadangan minyak terbukti sebesar 157 miliar barel, atau 9,3 persen dari total cadangan terbukti di dunia. Sedangkan cadangan gas terbukti, yang sebanyak 1.200 triliun kaki kubik, adalah terbesar di dunia, atau setara 18,2 persen dari total cadangan gas global.

   Iran juga berkomitmen memasok minyak mentah hingga 150 ribu barel per hari dengan komitmen investasi sebesar US$ 5 miliar. Tapi pasokan menunggu kepastian pembangunan kilang minyak di Situbondo, Jawa Timur. Dua perusahaan, yakni PT Kilanindo Golden Star dan National Iranian Oil Company (NIOC), sudah meneken persetujuan finansial

Koran Tempo, Page-21, Monday, March, 6, 2017

Aramco’s Rapid entry benefits selected companies

The participation of Saudi Arabia’s state-owned oil company Aramco in the refinery and cracker project within the Pengerang Integrated Petroleum Complex (PIPC) has spillover benefits on companies that are already active in and around the 8,903-hectare development in Johor.

Acccording to analysts, these companies will include Dialog Group Bhd, Petronas Chemicals Group Bhd (PetChem) and Petronas Gas Bhd (PetGas).

“The companies benefit in various ways from potentially seeing higher demand for their products and services, and increased job fiows to enjoying lower risk and seeing less pressure on their capital expenditure [capex] requirement,” one analyst tells StarBizWeek.

“This is based on our expectations of increased business activities and investor interest, driven by the entry of Aramco into the massive project,” he adds. Over the week, Aramco signeda deal with Petroliam Nasional Bhd (Petronas) to invest US$7 billion for a 50 percent stake in Petronas’ Refinery and Petrochemical Integrated Development (Rapid) project, which is now under construction at the Pengerang Integrated Complex (PIC) within the PIPC development.

Notably Dialog, whose Pengerang Deepwater Terminal (PDT) is located just next to the PIC development, stands to gain the most.

For one thing, the Petronas-Aramco partnership could potentially result in higher demand for tank terminals and deepwater marine facilities in the PDT. The increased demand for these facilities will be to cater to the requirements of the Rapid refinery and other dovimstream petrochemical plants within the PIPC.

Further development of the PDT will also provide Dialog with more opportunities in areas such as engineering and procurement, construction and commissioning (EPCC), fabrication, plant main-

tenance and catalyst handling services.

According to a source, the potential investments into tank terminals in the PDT include an expansion of the existing independent tank terminals owned by the Pengerang Independent Terminal (SPV1), by an additional one million cubic metres. 

The group also looks to benefit from the potential expansion of the dedicated tank terminal owned by Pengerang Terminals (Two) Sdn Bhd (SPV2), to be used by the Rapid refinery and petro-chemical plants, as well as the development of new tank terminals with deepwater jetty facilities capable of handling ultra and very large crude carriers.

In terms of EPCC, the source says, Dialog will benefit from the expansion works for the existing SPV 1 and SPV 2 as well as any new tank terminals to be built within the PDT.

“Dialog Group has successfully completed SPV 1 and the construction of SPV 2 is progressing within schedule. 

“The group may also benefit from potential EPCC works for selected portions of the petrochemical plants in PIPC,” the source explains.

According to the source, Dialog looks to reap the benefits of recurring income from its SPVs due to the increased usage or expansions.

“With the ongoing operations of SPV 1 and current construction of SPV 2, Dialog is now working towards securing new potential partners for future phases, which will include the development of more petroleum and petrochemical storage terminals,” he explains.

Meanwhile, Dialog’s plant maintenance and catalyst handling services division will also gain from the Petronas-Aramco partnership, when the works in the Rapid project and the petro-chemical plants come on stream, as it could lead to increased demand for the group’s technical services.

As it stands, Dialog still has another 243-ha of land within the PDT as well as 81-ha of land that can be reclaimed in the PIPC. The group also has sufficient land to support the presence of downstream oil and gas companies in PIPC, where its Sungai Rengit Industrial Estate has 320 acres of industrial park which can accommodate petroleum and chemical storage facilities and warehouses, petrochemical manufacturing industries, bottling and drumming plants and open year storages.

According to an industry source, Aramco’s involvement in the Rapid project, which has attracted worldwide attention, will likely draw more downstream oil and gas companies to set up operations in the PIPC.

On that note, some fabrication yards nearby could benefit. Amlnvestment Bank.Research points out that Malaysia Marine and Heavy Engineering Holdings Bhd (MMHE), which has a fabrication yard in Pasir Gudang, could be a likely candidate to gain through new job flows coming from the Pengerang development. 

However, another analyst is not so optimistic about MMHE’s potential benefit due to the stiff competition. amid an oversupply of fabrication yards in the area. At present, there are about eight fabrication yards around the Pengerang area and an industry source says jobs will likely be given to only a handful of them. Separately, Amlnvestment points out there could be prospects for some other companies such as Barakah Offshore Petroleum Bhd and Muhibbah Engineering (M) Bhd to secure some outsourced contract works.

Jakarta Post, Page-15, Monday, March, 6, 2017

2017, Turning Point National Oil Production

National oil production continues to fall every year since seven years ago. In 2010, the national oil production reached 942 thousand barrels per day (bpd). However, this number dropped to 898 thousand bpd in 2011, then 859 thousand bpd in 2012, and stagnant 786 thousand bpd in 2014 and 2015.

However, this condition changed in two years, when production Cepu reach the top. In 2016, oil production can propagate rose to 822 thousand bpd. In 2017, though only 815 thousand bpd target, the realization of production in the beginning of the year has reached 825.7 thousand bpd. Furthermore, oil production will be maintained in order to plateau at around 820 thousand barrels per day until 2020.

"With the support of all parties, we are optimistic that oil and gas production target in 2017 could be exceeded," said Head of Public Relations of SKK Migas Taslim Z Yunus.

Taslim optimism is not without basis. Along with crawling rising crude oil prices, domestic oil and gas investments also increased. National oil and gas investment had plummeted from US $ 20.3 billion in 2014 to US $ 12.01 billion in 2016 due to a significant cut in oil prices.

But this year, oil and gas investment is projected to rise slightly to US $ 13 billion. Increased investment means that the number of oil and gas exploration and production activities more and more. This year, the planned drilling development wells as many as 223 wells, re-work (work-over) 907 wells, well maintenance 57 512 wells, 40 seismic survey activities and exploration drilling 134 wells. This is to ensure the production target of 815 thousand bpd of oil and gas 6439.4 million standard cubic feetper day / MMSCFD.

This indicates the rate of decline in oil production can be suppressed. He explained that if there is no new activity, the decline in oil production this year is projected at 16.2%. To maintain the level of production, carried out activities such as drilling, maintenance and rework wells, as well as the optimization of facilities.

"With these efforts, the decline in oil production compared to 2016 can be reduced up to 2.8%," he said.

Not only that, SKK Migas also targets there are four new oil and gas projects that will come on stream this year. In the first quarter, there are two projects namely Fields Madura BD by Husky Oil and Field Cikarang Tegal Pacing by PT Pertamina EP The production of each project is the 5,980 bpd of oil and 100 MMSCFD in the Madura BD, as well as gas production 14 MMSCFD in Field Cikarang Tegal Pacing.

Furthermore, in the third-quarter 2017 Cricket Field project is planned to operate 200 bpd and 142 MMSCFD gas from the gas well as Cricket North East (Muara Bakau ENI) of 60 MMSCFD. Currently, production facilities, storage and offloading floating (floating production, storage, and offloading / FPSO) This project will be shipped from Karimun in March. "This March Karimun to sail away from East Kalimantan and is expected pfoduksinya July," he said.

In addition to these four projects, there will also be two other projects which began operations in 2017. Both of these projects should start production in the last year:

First, the Project Wasambo by Energy Equity Epic Sengkang with 80 MMSCFD gas produks planned to come on stream this year's first quarter. However, Taslim estimates the project will return back and will be on stream by year end. His next project is Matindok project done by Pertamina EP, Schedule on stream this project backwards from last year to the first quarter of 2017. The planned Matindok project will produce 65 MMSCFD gas and 800 bpd. Pertamina had called the project is late because of a problem in the execution of its gas processing facilities.

Not Down

Not content production is only growing up, the Ministry of Energy and Mineral Resources (ESDM) wants to survive the oil production in the range of 820 thousand to 2020. In fact, based on projections, the national oil production will continue to fall to 670 thousand bpd in 2018, 610 thousand bpd in 2019, and reached only 550 thousand bpd by 2020. gas production is projected to be stable at around 6,500 mMSCFD.

To increase oil production to be higher involvement, according to Deputy Minister of Energy and Mineral Resources (ESDM) Arcandra Tahar, is a difficult thing to do in the near future. As it can take quite a long wait for a new project started producing oil. However, oil production will be controlled so as not to freefall to reduce the rate of production decline (decline rate). "In five years, (oil production) of 800 thousand barrels per day should not go down," he said.

To that end, the government made a short-term program to achieve these targets. The program includes three things, namely the identification of technology, organization of workshops (workshop), and program activities. The Government will ensure what technology should be used to be able to increase oil production, and then to introduce the technology to the oil and gas companies, and together determine what activities are needed.

"For that we need cooperation between the Ministry of Energy, SKK Migas, and Production Sharing Contractors (cooperation). KKKS executor, so we call, said Arcandra.

Related to oil and gas investment in the future, the Director General of Oil and Gas Ministry of Energy and Mineral Resources I Gusti Nyoman Wiratmaja optimistic will improve starting this year. Crude oil prices started to creep up did help the government's efforts to boost domestic oil and gas upstream investments. However, the implementation of cooperation contracts (production sharing contract / PSC) scheme for gross proceeds (gross split) also played a role.

With the gross split, Wiratmaja said, the government wants to improve Indonesia's competitiveness in the oil and gas attract investors. This scheme will be applied in the oil and gas auction this year. "We hope more competitive, more in the middle (rank). We are now almost at the end (ranking), "he said.

According to him, the scheme gross split can improve the return on capital (internal rate of return / IRR) of oil and gas projects. Because, considering the location and condition of oil and gas field, the accumulated amount of production, and oil prices in determining the outcome ration oil and gas contractors. Thus, any marginal oil and gas fields can still be economical.

"If the marginal, so there is an extra split its order IRR can be achieved. We can give KKKS minimum IRR of 12%, "said Wiratmaja. Scheme split also made a gross profit of oil and gas companies will be even greater if they do efficiency.

IN INDONESIAN

2017, Titik Balik Produksi Minyak Nasional

Produksi minyak nasional terus turun setiap tahunnya sejak tujuh tahun yang lalu. Pada 2010, produksi minyak nasional mencapai 942 ribu barel per hari (bph). Namun, angka ini terus turun menjadi 898 ribu bph pada 2011, kemudian 859 ribu bph pada 2012, dan stagnan 786 ribu bph pada 2014 dan 2015.

Namun, kondisi ini berubah dalam dua tahun ini, ketika produksi Blok Cepu mencapai puncak. Pada 2016, produksi minyak dapat merambat naik menjadi 822 ribu bph. Pada 2017, meski ditargetkan hanya 815 ribu bph, realisasi produksi di awal tahun telah mencapai 825,7 ribu bph. Selanjutnya, produksi minyak akan dipertahankan agar plato di kisaran 820 ribu bph sampai 2020.

“Dengan dukungan Semua pihak, kami optimis target produksi migas tahun 2017 dapat terlampaui,” kata Kepala Humas SKK Migas Taslim Z Yunus.

Optimisme Taslim ini bukan tanpa dasar. Seiring dengan merangkak naiknya harga minyak mentah, investasi migas nasional juga ikut meningkat. Investasi migas nasional sempat terjun bebas dari US$ 20,3 miliar pada 2014 menjadi US$ 12,01 miliar pada 2016 lantaran harga minyak terpangkas signifikan. 

Namun pada tahun ini, investasi migas diproyeksi naik tipis menjadi US$ 13 miliar. Peningkatan investasi berarti jumlah kegiatan eksplorasi dan produksi migas semakin banyak. Pada tahun ini, direncanakan kegiatan pengeboran sumur pengembangan sebanyak 223 sumur, kerja ulang (work over) 907 sumur, perawatan sumur 57.512 sumur, survei seismik 40 kegiatan, dan pengeboran eksplorasi 134 sumur. Hal ini guna memastikan target produksi minyak 815 ribu bph dan gas 6.439,4 million standard cubic feetper day/mmscfd.

Hal ini menandakan laju penurunan produksi minyak dapat ditekan. Dia menjelaskan, apabila tidak ada kegiatan baru, penurunan produksi minyak tahun ini diproyeksikan sebesar 16,2%. Untuk menjaga tingkat produksi, dilakukan kegiatan seperti pengeboran, perawatan, dan kerja ulang sumur, serta optimasi fasilitas.

“Dengan upaya tersebut, penurunan produksi minyak dibanding tahun 2016 dapat ditekan hingga menjadi 2,8%,” ujarnya. 

Tidak hanya itu, SKK Migas juga menargetkan terdapat empat proyek migas baru yang akan on stream tahun ini. Pada kuartal pertama ini, terdapat dua proyek yakni Lapangan Madura BD oleh Husky Oil dan Lapangan Cikarang Tegal Pacing oleh PT Pertamina EP Besar produksi masing-masing proyek ini yakni 5.980 bph minyak dan 100 mmscfd di Madura BD, serta produksi gas 14 mmscfd di Lapangan Cikarang Tegal Pacing.

Selanjutnya, pada kuartal-III 2017 direncanakan beroperasi proyek Lapangan Jangkrik 200 bph dan gas 142 mmscfd Serta gas dari Jangkrik North East (ENI Muara Bakau) sebesar 60 MMscfd. Saat ini, fasilitas produksi, penampungan, dan bongkar muat terapung (floating production, storage, and offloading/FPSO) proyek ini akan dikapalkan dari Karimun pada Maret nanti. “Maret ini sail away dari Karimun ke Kalimantan Timur dan diharapkan pfoduksinya Juli nanti,” tuturnya.

Selain empat proyek ini, juga akan ada dua proyek lain yang mulai operasi pada 2017. Kedua proyek ini seharusnya mulai produksi pada tahun lalu :

Pertama, Proyek Wasambo oleh Energy Equity Epic Sengkang dengan produks gas 80 mmscfd direncanakan on stream kuartal pertama tahun ini. Namun, Taslim memperkirakan proyek ini akan kembali mundur dan baru dapat on stream akhir tahun. Proyek berikutnya adalah Proyek Matindok yang dikerjakan oleh Pertamina EP, Jadwal on stream proyek ini mundur dari tahun lalu menjadi kuartal pertama 2017. Proyek Matindok direncanakan akan menghasilkan gas 65 mmscfd dan 800 bph. Pertamina sempat menyebut proyek terlambat karena ada masalah dalam pengerjaan fasilitas pemrosesan gasnya.

Tidak Turun

Tidak puas produksi minyak hanya tumbuh ke atas, Kementerian Energi dan Sumber Daya Mineral (ESDM) menginginkan produksi minyak bertahan di kisaran 820 ribu sampai 2020. Padahal, berdasarkan proyeksi, produksi minyak nasional akan terus turun menjadi 670 ribu bph pada 2018, 610 ribu bph pada 2019, dan mencapai hanya 550 ribu bph pada 2020. Sementara produksi gas diproyeksikan akan stabil di kisaran 6.500 mmscfd.

Menaikkan produksi minyak menjadi lebih tinggi Iagi, menurut Wakil Menteri Energi dan Sumber Daya Mineral (ESDM) Arcandra Tahar, adalah hal yang sulit dilakukan dalam waktu dekat. Pasalnya, butuh waktu cukup lama menunggu proyek baru mulai memproduksi minyak. Namun, produksi minyak akan bisa di kendalikan agar tidak terjun bebas dengan menekan laju penurunan produksi (decline rate). “Dalam lima tahun ini, (produksi minyak) 800 ribu bph tidak boleh turun," kata dia. 

Untuk itu, pemerintah membuat program jangka pendek untuk mencapai target tersebut. Program ini mencakup tiga hal, yakni identifikasi teknologi, penyelenggaraan loka karya (workshop), dan program kegiatan. Pemerintah akan memastikan teknologi apa yang harus dipakai untuk dapat menaikkan produksi minyak, kemudian memperkenalkan teknologi itu kepada perusahaan migas, dan bersama-sama menentukan kegiatan apa saja yang diperlukan.

“Untuk itu perlu kerja sama Kementerian ESDM, SKK Migas, dan KKKS (kontraktor kontrak kerja sama). Eksekutor KKKS, jadi kami panggil, kata Arcandra.

Terkait investasi migas ke depannya, Direktur Jenderal Minyak dan Gas Bumi Kementerian ESDM I Gusti Nyoman Wiratmaja optimis akan membaik mulai tahun ini. Harga minyak mentah yang mulai merangkak naik memang membantu upaya pemerintah menggenjot investasi hulu migas dalam negeri. Namun, penerapan kontrak kerja sama (production sharing contract/ PSC) skema bagi hasil kotor (gross split) juga ikut berperan. 

Dengan adanya gross split, Wiratmaja menuturkan, pemerintah ingin memperbaiki daya saing Indonesia dalam menggaet investor migas. Skema ini akan diterapkan dalam lelang migas pada tahun ini. “Kami harap lebih kompetitif, lebih di tengah (rankingnya). Kita sekarang hampir di ujung (ranking) ,” ujarnya.

Menurutnya, skema gross split dapat memperbaiki tingkat pengembalian modal (internal rate of return/IRR) proyek migas. Pasalnya, mempertimbangkan lokasi dan kondisi lapangan migas, jumlah akumulasi produksi, dan harga minyak dalam menetapkan bagi hasil jatah kontraktor migas. Sehingga, lapangan migas marjinal pun masih tetap bisa ekonomis.

“Kalau marjinal, makanya ada tambahan split-nya supaya IRR-nya dapat dicapai. Kami memberi minimum KKKS dapat IRR 12%,” kata Wiratmaja. Skema gross split juga membuat keuntungan perusahaan migas akan semakin besar jika mereka melakukan efisiensi.

 Investor Daily, Page-9, Monday, March, 6, 2017