Arrange Gas Gas Price Revision Government Regulation Minister

Not until a semester has been published, the Ministry of Energy and Mineral Resources (ESDM) will revise Ministerial Regulation No. 11 of 2017 on gas prices for power plants. Through this regulatory change, the final gas price at the power plant will be ensured to remain affordable.

Deputy Minister Arcandra Tahar said, based on Regulation 11/2017, PLN will have the option to use gas pipelines, liquefied natural gas / LNG or LNG import to get the lowest price. However, the regulation has not yet calculated the cost of transportation and regasification.

"It seems the same, the selected gas pipeline must be selected. So the logic in the Ministerial Regulation is useless, "he said in Jakarta.

In Regulation 11/2017, the price of gas for power plants are built near the mouth of the gas well is set at 8% of the price of crude oil Indonesia (Indonesian Crude Price / ICP) per million British thermal unit (mmbtu).

While the price of gas for pipe plant far from oil and gas projects, set at 11.5% of ICP. However, when the price of piped gas exceeds that limit, PLN has the option of using domestic LNG. Even this LNG price is set to not exceed 11.5% ICP with a freight on board (FoB) scheme. If this limit is exceeded, subsequent PLN is allowed to import LNG with Indonesia's landed price not exceeding 11.5% ICP

But logically, Arcandra states, this does not guarantee PLN get the lowest price. The reason is when using domestic LNG and import LNG, the final price in the power plant will potentially exceed the 11.5% pipe gas price set ICP. This is because PLN still has to bear the cost of regasification and transportation.

"For example, 11.4% of ICP LNG can not possibly be used as well because there are the costs of transportation and regasification so that the price can be 11-12% PLN ICP will not be taken because it is more expensive," he explained. The same is true for imported LNG.

This concept will be revised. According to him, the current standard used as a limitation does not guarantee the price at the other end, at power plants, will be more affordable. The 11.5% constants may need to be changed considering the price of gas at the mouth of the well at present reaches 11.5% ICP

"We are being discussed, which should be checked for the end price, not the price of landed price or FOB," said Arcandra.

Secretary of the Directorate General of Oil and Gas of the Ministry of Energy and Mineral Resources, Susyanto, added that Ministerial Regulation 11/2017 was revised because the gas price determined was less suitable with upstream investment.

"It does not match the interests of upstream oil and gas with electricity," he said.

In Project 35 Thousand MW, the portion of Steam Power Plant (PLTU) is fueled dominate, reaching 19,940 MW or 56.13%. However, the share of PLTG / PLTGU is also quite large, which amounted to 12,867 MW or 36.22%.

In addition, the Electricity Supply Business Plan (RUPTL) from 2016 to 2025, the share of the power plant / power plant also magnified 9,700 thousand MW to 18,900 MW. In line with the increase in generating capacity, PLN's gas demand is mainly in the form of LNG, projected to increase every year.

In 2016, LNG needs an estimated 147 billion cubic feet and gas pipelines of 429 billion cubic feet. This figure will skyrocket to 838 billion cubic feet for LNG and 473 billion cubic feet for pipe gas in 2025.

The Ministerial Regulation on Power Purchase Agreement / PPA is not only Ministerial Regulation 11/2017, the ESDM Ministry will also amend Regulation of the Minister of 10/2017 which regulates the principles of Power Purchase Agreement (PPA). Just like Ministerial Regulation, Electricity Gas Price, this Regulation of Minister of PPA was also issued at the beginning of this year.

Director General of Electricity Ministry of Energy Andy Sommeng said that the main revision will be done related to the term government force majeure as stated in the regulation. This clause raises uncertainty among investors and financial institutions.

"The lenders that matter is whether it is bankable or not. Problem bankability, "he said.

The clause concerning government force majeure in this rule is stated in Article 8 and Article 28. Article 8 Paragraph 2 mentions One of the risks to be borne by a business entity is a change in policy or regulation (government force majeure). 

    Whereas Article 28 Paragraph 7 states that in force majeure due to government force majeure that caused the project to be terminated or the power plant can not operate, PLN and business entity shall be exempted from their respective obligations.

Andy Sommeng revealed, actually Ministerial Regulation 10/2017 is pretty good. This Ministerial Regulation divides the risks borne by PLN and private power producers (Independent Power Producer / IPP). 

     In addition to the matter of government force majeure it is mentioned that there will not be many other provisions that are amended in this Ministerial Regulation. One of them is about the contract period.

"The contract period will not be changed," he said.

Ministerial Regulation 10/2017 stipulates the contract of electricity purchase agreement between PLN and IPP maximum 30 years. Where based on the Ministerial Regulation, after 30 years of contract, the plant will belong to the state by constructing, owning, operating and transfer (BOOT) mechanisms. This has never been arranged before.

In addition, this rule also regulates the issue of sanctions for private power developers who can not fulfill their obligations under the contract. Meanwhile, the Ministerial Regulation stipulates the penalty for the delay of IPP to operate the commercial power (COD). 

     The amount of the fine will be adjusted to PLN's cost of providing replacement power because of the delay. On the other hand, PLN should also provide incentives to the IPP requested to speed up the operation process.

Then, PLN is required to purchase electricity in accordance with the capacity agreed upon in PPA, otherwise it will be charged a take or pay fee to PLN in accordance with the agreed capacity value. Conversely, if the IPP is not able to supply electricity in accordance with the agreed capacity, then it will be subject to a fine delivery or pay

IN INDONESIA

Atur Harga Gas Pembangkit Pemerintah Revisi Peraturan Menteri

Belum sampai satu semester diterbitkan, Kementerian Energi dan Sumber Daya Mineral (ESDM) akan merevisi Peraturan Menteri No 11 Tahun 2017 soal harga gas untuk pembangkit listrik. Melalui perubahan aturan ini, harga gas akhir di pembangkit listrik akan dipastikan tetap terjangkau. 

Wakil Menteri ESDM Arcandra Tahar mengungkapkan, berdasarkan Peraturan Menteri  11/ 2017, PLN memiliki opsi menggunakan gas pipa, liquefied natural gas/ LNG maupun impor LNG untuk mendapatkan harga termurah. Namun aturan tersebut belum menghitung biaya transportasi dan regasifikasi.

“Jadinya sama saja, yang dipilih pasti gas pipa. Jadi logika yang ada di Peraturan Menteri tidak ada gunanya,” kata dia di Jakarta.

Dalam Peraturan Menteri 11/2017, harga gas pipa untuk pembangkit listrik yang dibangun dekat dengan mulut sumur gas dipatok sebesar 8% dari harga minyak mentah Indonesia (Indonesian Crude Price/ICP) setiap juta british thermal unit (mmbtu).

Sementara harga gas pipa untuk pembangkit yang jauh dari proyek migas, ditetapkan sebesar 11,5% dari ICP. Namun ketika harga gas pipa melebihi batas tersebut, PLN memiliki opsi menggunakan LNG domestik. Harga LNG inipun diatur tidak boleh melebihi 11,5% ICP dengan skema freight on board (FoB) . Jika batas ini terlampaui, PLN berikutnya diizinkan mengimpor LNG dengan ketetapan harga di Indonesia (landed price) tidak melebihi 11,5% ICP

Namun secara logika, Arcandra menyatakan, hal ini tidak menjamin PLN memperoleh harga paling rendah. Pasalnya ketika memakai LNG domestik maupun LNG impor, harga akhir di pembangkit berpotensi akan melebihi harga gas pipa yang dipatok 11,5% ICP. Hal ini lantaran PLN masih harus menanggung biaya regasifikasi maupun transportasi.

“Misal dapat LNG 11,4% ICP tidak mungkin dipakai juga karena masih ada biaya transportasi dan regasifikasi sehingga harganya bisa jadi 11-12% ICP PLN tidak akan diambil karena lebih mahal,” jelasnya. Hal yang sama berlaku juga untuk LNG yang diimpor.

Konsep inilah yang akan direvisi. Menurutnya, standart yang sekarang ini digunakan sebagai batasan tidak menjamin harga di ujung, di pembangkit listrik, akan lebih terjangkau. Konstanta 11,5% bisa saja perlu diubah mengingat harga gas di mulut sumur saat ini ada yang mencapai 11,5% ICP

“Kami sedang dibicarakan, yang harus dicek harga end-nya, bukan dibandingkan harga landed price atau FOB,” tutur Arcandra. 

Sekretaris Direktorat Jenderal Minyak dan Gas Bumi Kementerian ESDM Susyanto menambahkan, Peraturan Menteri 11/2017 direvisi juga lantaran harga gas yang ditetapkan kurang sesuai dengan investasi hulu. 

“Tidak match antara kepentingan hulu migas dengan listrik,” ujarnya.

Dalam Proyek 35 Ribu MW, porsi Pembangkit Listrik Tenaga Uap (PLTU) yang berbahan bakar memang mendominasi, yakni mencapai 19.940 MW atau 56,13%. Namun, porsi PLTG/ PLTGU juga cukup besar, yaitu sebesar 12.867 MW atau 36,22%.

Selain itu, dalam Rencana Usaha Penyediaan Tenaga Listrik (RUPTL) 2016-2025, porsi PLTG/PLTGU juga diperbesar 9.700 MW menjadi 18.900 ribu MW. Seriring dengan pertambahan kapasitas pembangkit, kebutuhan gas PLN utamanya dalam bentuk LNG, diproyeksikan naik setiap tahunnya. 

Pada 2016, kebutuhan LNG diperkirakan 147 miliar kaki kubik dan gas pipa 429 miliar kaki kubik. Angka ini akan melejit menjadi 838 miliar kaki kubik untuk LNG dan 473 miliar kaki kubik untuk gas pipa pada 2025.

Peraturan Menteri tentang Power Purchase Agreement/PPA tidak hanya Peraturan Menteri 11/ 2017, Kementerian ESDM juga akan mengubah Peraturan Menteri 10/2017 yang mengatur pokok-pokok dalam perjanjian jual beli listrik (Power Purchase Agreement/PPA). Sama seperti Peraturan Menteri, Harga Gas Kelistrikan, Peraturan Menteri PPA ini juga baru terbit pada awal tahun ini. 

Direktur jenderal Ketenagalistrikan Kementerian ESDM Andy Sommeng menuturkan, revisi utamanya akan dilakukan terkait istilah government force majeure yang tercantum dalam aturan tersebut. Klausul ini menimbulkan ketidakpastian di kalangan investor dan lembaga keuangan. 

“Para lender itu isunya adalah apakah ini bankable atau tidak. Soal bankability,” ujarnya.

Klausul soal government force majeure dalam aturan ini dinyatakan dalam Pasal 8 dan Pasal 28. Pasal 8 Ayat 2 menyebutkan Salah satu risiko yang harus ditanggung oleh badan usaha adalah perubahan kebijakan atau regulasi (government force majeure). 

     Sementara dalam Pasal 28 Ayat 7 tertulis, dalam keadaan kahar (force majeure) yang dikarenakan perubahan kebijakan pemerintah (government force majeure) yang menyebabkan proyek dihentikan atau pembangkit tenaga listrik tidak dapat beroperasi, maka PLN dan badan usaha dibebaskan dari kewajiban masing-masing.

Andy Sommeng mengungkapkan, sebenarnya Peraturan Menteri 10/2017 ini cukup bagus. Peraturan Menteri ini membagi risiko yang harus ditanggung PLN dan produsen listrik swasta (Independent Power Producer/IPP). Selain soal government force majeure itu disebutnya tidak akan banyak ketentuan lain yang diubah dalam Peraturan Menteri ini. Salah satunya soal periode kontrak. 

“Tidak akan diubah periode kontrak,” tuturnya.

Peraturan Menteri 10/ 2017 menetapkan kontrak perjanjian jual beli listrik antara PLN dan IPP maksimal 30 tahun. Dimana berdasarkan Peraturan Menteri, setelah 30 tahun kontrak, pembangkit akan menjadi milik negara dengan mekanisme membangun, memiliki, mengoperasikan, dan mengalihkan (build, own, operate, and transfer/ BOOT).  Hal ini sebelumnya belum pernah diatur.

Selain itu, aturan ini juga mengatur masalah pemberian sanksi bagi pengembang listrik swasta yang tidak dapat memenuhi kewajibannya sesuai dengan kontrak. Adapun, dalam Peraturan Menteri diatur pengenaan pinalti atas keterlambatan IPP mengoperasikan pembangkit secara komersial (commercial operation date/ COD). 

     Besaran dendanya, akan disesuaikan dengan biaya PLN menyediakan tenaga listrik pengganti karena keterlambatan tersebut. Di sisi lain, PLN juga harus memberikan insentif kepada IPP yang diminta mempercepat proses operasi.

Kemudian, PLN diwajibkan membeli listrik sesuai dengan kapasitas yang telah disepakati dalam PPA, jika tidak maka akan dibebankan denda take or pay kepada PLN sesuai dengan nilai kapasitas yang telah disepakati. Sebaliknya, jika IPP tidak mampu memasok listrik sesuai dengan kapasitas yang disepakati, maka pihaknya akan terkena denda delivery or pay.

Investor Daily, Page-9, Wednesday, July 12, 2017

BBS Bojonegoro Can not Manage Oil Wells

PT Bojonegoro Bangun Sarana (BBS), Regional Owned Enterprise (BUMD) The Bojonegoro regency government of East Java has not been able to manage the old oil well field in some villages in Kedewan sub-district because there has been no submission from SKK Migas.

Head of Department of Industry and Manpower of Bojonegoro Regency, Agus Supriyanto, in Bojonegoro, Tuesday (11/7) explained that SKK Migas and Pertamina EP Asset 4 Field Cepu, Central Java should have handed the field of old oil wells to PT BBS earlier in the year then.

But the handover of old oil field wells in Kedewan sub-district is not working properly, due to technical problems.

"We do not know for sure the cause has not been submitted to the management of the old oil well field to PT BBS," he said and justified Director of PT BBS BUMD Bojonegoro Regional Government Toni Ade Irawan.

Therefore, the local district government will invite SKK Migas, Pertamina EP Asset 4 Field Cepu, Central Java, and Pertamina EP Cepu to discuss the management of the old Dutch oil well field in Kecamatan Kedewan today. In fact, according to him, the District Government has made legal protection in the form of Regent Regulation (Perbup) Bojonegoro for the ratification of miners.

"Regent Regulation Bojonegoro it to verify the miners," he said.

In accordance with the decision of the Regent of Bojonegoro Suyoto, PT BBS which replaces the miners' association only receives "fee", so there is no need to spend in the field management of oil well field.

Appropriate data in Wonocolo Village, Hargomulyo, and Beji, Kedewan Sub-district according to the contract of 222 points of oil wells. However, in the development of the number of oil wells developed into 724 points of oil wells with an average production of about 1,200 barrels per day.

Production of the oil well is only about 400 barrels per day which is deposited to Pertamina EP Asset 4 Field Cepu, while others are sold out, including distilled to diesel.

IN INDONESIA

BBS Bojonegoro Belum Bisa Kelola Sumur Minyak

PT Bojonegoro Bangun Sarana (BBS), Badan Usaha Milik Daerah (BUMD) Pemerintah Kabupaten Bojonegoro, Jawa Timur belum bisa mengelola lapangan sumur minyak tua pada sejumlah desa di Kecamatan Kedewan karena belum ada penyerahan dari SKK Migas.

Kepala Dinas Perindustrian dan Tenaga Kerja (Disperinaker) Kabupaten Bojonegoro Agus Supriyanto, di Bojonegoro, Selasa (11/7) menjelaskan, SKK Migas dan Pertamina EP Asset 4 Field Cepu, Jawa Tengah seharusnya sudah menyerahkan lapangan sumur minyak tua itu kepada PT BBS awal tahun lalu.

Tapi penyerahan pengelolaan lapangan sumur minyak tua di Kecamatan Kedewan tidak berjalan sebagaimana mestinya, karena terhambat masalah teknis.

“Kami tidak tahu pasti penyebab belum diserahkan pengelolaan lapangan sumur minyak tua itu kepada PT BBS,” ujar dia dan dibenarkan Direktur PT BBS BUMD Pemerintah Kabupaten Bojonegoro Toni Ade Irawan.

Karena itu Pemerintah Kabupaten setempat akan mengundang SKK Migas, Pertamina EP Asset 4 Field Cepu, Jawa Tengah, dan Pertamina EP Cepu untuk membahas pengelolaan lapangan sumur minyak tua peninggalan Belanda di Kecamatan Kedewan hari ini. Padahal, menurut dia, Pemerintah Kabupaten sudah membuat perlindungan hukum berupa Peraturan Bupati (Perbup) Bojonegoro untuk pengesahan penambang.

“Peraturan Bupati Bojonegoro itu untuk melakukan verifikasi penambang,” ujarnya.

Sesuai keputusan Bupati Bojonegoro Suyoto, PT BBS yang menggantikan paguyuban penambang hanya menerima “fee”, sehingga tidak perlu mengeluarkan biaya dalam pengelolaan lapangan sumur minyak.

Sesuai data di Desa Wonocolo, Hargomulyo, dan Beji, Kecamatan Kedewan sesuai kontrak sebanyak 222 titik sumur minyak. Namun, dalam perkembangan jumlah sumur minyak berkembang menjadi 724 titik sumur minyak dengan produksi rata-rata sekitar 1.200 barel per hari.

Produksi sumur minyak itu hanya sekitar 400 barel per hari yang disetorkan kepada Pertamina EP Asset 4 Field Cepu, sedangkan lainnya dijual keluar, termasuk disuling menjadi solar.

Investor Daily, Page-9, Wednesday, July 12, 2017

ESDM Not Discussed Share in Block Down Mahakam

The Ministry of Energy and Mineral Resources (ESDM) admits that it has not been able to answer any of the contents of the Letter of Total EP lndonesie requesting 39% of Mahakam Block shares. The government is currently focusing on discussing the incentives that were also asked in the letter.

At the end of April 2017, Total E & P Indonesie sent a letter to ESDM Minister Ignasius Jonan. The letter contains several requests, namely share down in the Mahakam Block of 39% from the previous 30%, First Tranche Petroleum (FTP) which is usually 20% to 0%, from gross production, and investment credit 20%.

Total EP also requested the acceleration of the depreciation period from five years to two years. Last Total EP is willing to pay a signature bonus of about US $ 13 million from the amount of US $ 41 million. It's on record, can get 39% stake in the block.

Deputy Minister of Energy and Mineral Resources (EMR), Arcandra Tahar, said that the government will answer the request of Total-Inpex related to the Mahakam block as soon as possible. The government has even prepared a decree regarding the share down.

"We will answer this year as soon as possible," said Arcandara on Monday (10/7).

However, before answering the 39% share down demand in the Mahakain Block, the government will first answer three incentive requests submitted by Total and Inpex.

"The first thing we have to answer are the three incentives they ask, we need to answer, after the incentive decision will be discussed about the Mahakam" explained Arcandra.

IN INDONESIA

ESDM Belum Bahas Share di Blok Down Mahakam

Kementerian Energi dan Sumber Daya Mineral (ESDM) mengaku belum bisa menjawab salah satu isi Surat dari Total EP lndonesie yang meminta 39% saham Blok Mahakam. Pemerintah mengaku saat ini fokus membahas insentif yang juga diminta dalam surat tersebut.

Pada akhir April 2017, Total E&P Indonesie mengirimkan surat kepada Menteri ESDM Ignasius Jonan. Surat itu berisi beberapa permintaan, yakni share down di Blok Mahakam sebesar 39% dari sebelumnya 30%, First Tranche Petroleum (FTP) yang biasanya 20% menjadi 0%, dari produksi kotor, dan investment credit 20%.

Total EP juga meminta percepatan masa depresiasi dari lima tahun menjadi dua tahun. Terakhir Total EP bersedia membayar bonus tandatangan sekitar US$ 13 juta dari jumlah US$ 41 juta. Ini dengan catatan, bisa mendapatkan 39% saham di blok tersebut. 

Wakil Menteri Energi dan Sumber Daya Mineral (ESDM), Arcandra Tahar mengungkapkan, pemerintah akan menjawab permintaan Total-Inpex terkait Blok Mahakam secepatnya. Pemerintah bahkan telah menyiapkan Surat keputusan terkait share down tersebut. 

"Akan kami jawab tahun ini juga, secepatnya," ujar Arcandara pada Senin (10/7). 

Namun, sebelum menjawab mengenai permintaan 39% share down di Blok Mahakain, pemerintah akan terlebih dahulu menjawab tiga permintaan insentif yang juga diajukan oleh Total dan Inpex.

"Yang pertama yang harus kami jawab itu tiga insentif yang mereka minta, ini perlu kami jawab. Setelah keputusan insentif, akan dibahas soal Mahakam" jelas Arcandra.

Kontan, Page-14, Wednesday, July 12, 2017

Management Submitted Pertamina EP and BUMD

Post-Contract Sumur Tua Wonocolo Ends

The Government of Bojonegoro Regency along with SKK Migas and PT Pertamina EP held a follow-up meeting discussing the problems of old wells management in Wonocolo Village, Kedewan Sub-district, Bojonegoro. In accordance with the previous meeting between the District Government and SKK Migas and PT Pertamina EP, an agreement was reached that the management of the old wells will be managed by the BUMD.

Head of Department of Industry and Manpower of Bojonegoro, Agus Supriyanto as chairman of the meeting, Tuesday (11/07) explained that in the near future the old well contract will end and require certainty for the continuation of the old well management.

"Following the end of old well management contracts over the next few years, we want to see how the implementation of old wells such as existing management in Blora Regency", explained Agus.

"Soon, this miner can run in accordance with the Minister of Energy and Mineral Resources Regulation No. 1 of 2008 on Well Management Old, we need certainty this contract can be continued with PT Pertamina EP ".

Tony Ade Iriawan as President Director of PT Bojonegoro Bangun Sarana, Bada Usaha Milik Daerah (BUMD) of Bojonegoro Regency said that BUMD has prepared the concept that has been submitted to the Regent of Bojonegoro and PT Pertamina EP.

"We have prepared the concept as a miner's companion, we have approached the miners to join the BUMD." Of the 16 miners, 14 figures have agreed to join the BUMD, "said Tony.

Meanwhile, Chalid Sa'id Salim, Operation & Production Director of PT Pertamina EP explained that in relation to the problems of the old wells in Bojonegoro District, the Board of Directors of PT Pertamina EP decided to manage the Old Well under the Minister of Energy and Mineral Resources Regulation No. 1 of 2008, With Village Unit Cooperative (KUD) or BUMD.

"Nevertheless we remain committed to maintaining petroleum production managed by miners to enter the country, with remittance through PT Pertamina EP," Chalid added.

IN INDONESIA

Pengelolaan Diserahkan Pertamina EP dan BUMD

Pasca Kontrak SumurTua Wonocolo Berakhir

Pemerintah Kabupaten Bojonegoro bersama SKK Migas dan PT Pertamina EP menggelar rapat lanjutan membahas permasalahan pengelolaan sumur tua di Desa Wonocolo, Kecamatan Kedewan, Bojonegoro. Sesuai pertemuan sebelumnya antara Pemerintah Kabupaten dan SKK Migas serta PT Pertamina EP, didapatkan kesepakatan yang intinya pengelolaan sumur tua akan dikelola oleh BUMD.

Kepala Dinas Perindustrian dan Tenaga Kerja Bojonegoro, Agus Supriyanto selaku pemimpin rapat, selasa siang (11/07) menjelaskan, bahwa dalam waktu dekat kontrak sumur tua akan berakhir dan membutuhkan kepastian untuk kelanjutan pengelolaan sumur tua.

"Menindak lanjuti akan berakhirnya kontrak pengelolaan sumur tua beberapa waktu ke depan, kami ingin melihat bagaimana implementasi sumur tua seperti pengelolaan yang ada di Kabupaten Blora", jelas Agus.

"Sebentar lagi, agar penambang ini bisa berjalan sesuai dengan Peraturan Menteri ESDM No 1 Tahun 2008 tentang Pengelolaan Sumur Tua, kami membutuhkan kepastian kontrak ini bisa dilanjutkan dengan PT Pertamina EP".

Tony Ade Iriawan selaku Direktur Utamaa PT Bojonegoro Bangun Sarana, Bada Usaha Milik Daerah (BUMD) Kabupaten Bojonegoro menyampaikan bahwa BUMD telah mempersiapkan konsep yang sudah disampaikan kepada Bupati Bojonegoro dan PT Pertamina EP.

"Kami sudah menyiapkan konsep sebagai pendamping penambang, kami sudah melakukan pendekatan kepada para penambang agar mau bergabung dengan BUMD. Dari 16 tokoh penambang, 14 tokoh telah setuju untuk bergabung dengan BUMD," jelas Tony. 

Sementara itu, Chalid Sa'id Salim, Operation & Production Director PT Pertamina EP menjelaskan bahwa terkait dengan permasalahan sumur tua di wilayah Kabupaten Bojonegoro, jajaran Direksi PT Pertamina EP memutuskan untuk pengelolaan Sumur Tua mengacu pada Peraturan Menteri ESDM No 1 Tahun 2008, yaitu bekerjasama dengan Koperasi Unit Desa (KUD) atau BUMD.

"Namun demikian kami tetap berkomitmen untuk menjaga produksi minyak bumi yang dikelola oleh penambang untuk masuk kepada negara, dengan disetorkan melalui PT Pertamina EP," tambah Chalid.

Harian Bangsa, Page-9, Wednesday, July 12, 2017

Bad odor Successfully Handled

JOB-PPEJ Ensure that residents can have activities as before

Villagers Sambiroto, Kecas Kapas, Bojonegoro District have started to do activities such as days after exposure to odor. This normal activity occurs after Joint Operating Body of Pertamina PetroChina East Java (JOB-PPEJ) handles gas leak during work over process or well maintenance at Pad A.

The unpleasant smell caused 27 residents to receive treatment for complaining of nausea. One other resident who was referred to the hospital because of vomiting and dizziness has also returned.

"One person who was referred to Ibn Sina Hospital has also returned," said Sambiroto Village Chief, Sudjono.

Sudjono added, people's bodies reactions due to bad smell are different. If her weakened immune system can nausea dizziness and vomiting, even fainting.

The residents who smelled bad were in RT / Block 9 to RT / Block 12. The village together with the JOB-PPEJ operator immediately evacuated the people to get medical treatment. They were then observed in their homes. One person, Supiatun (52), resident of Rt / Blok. 11 Rw. 02 in referring to Ibn Sina Hospital.

Contacted separately, the Joint Operating Body Contractor (JOB-PPEJ) Joint Operating Body of Pertamina Petrochina East Java (JOB-PPEJ) ensured the odor of the residents was not due to a leaking gas pipe. The unpleasant smells of the residents on Monday (10/7) occurred during the work over (well work) at PAD A, precisely when the revocation of cubing.

"The odor of odor that we have successfully overcome. Handling of the start-nauseated citizens was immediately done. In essence, the situation is safe and under control. Even so we apologize for the inconvenience caused by the odor, "said Field Admin Superintendent (FAS) JOB PPEJ, Akbar Pradima, Monday (10/7).

Akbar Pradima explained that well work or work over work is a routine activity in oil and gas industry. Although it has been careful and careful, but there is still the risk of odorous odor. Therefore, the JOB-PPEJ every year always conducts emergency response situations training with residents in the area around the operation area.

The speed of handling this unpleasant odor distribution is the result of simulated handling of emergency response situation that is routinely done with the residents.

"The management of JOB PPEJ thanked the community for supporting the simulation of the handling of emergency response situation. We are also grateful for the support and cooperation that has been provided by the people so that JOB-PPEJ can operate with

Smoothly, "he said

IN INDONESIA

Bau Tak Sedap Berhasil Ditangani 

JOB-PPEJ Pastikan warga bisa beraktifitas seperti semula

Warga Desa Sambiroto, Kecamatan Kapas, Kabupaten Bojonegoro sudah mulai melakukan aktivitas seperti hari-hari setelah terpapar bau tidak sedap. Aktivitas normal ini terjadi setelah Joint Operating Body Pertamina PetroChina East Java (JOB-PPEJ) melakukan penanganan terhadap kebocoran gas saat proses work over atau perawatan sumur di Pad A.

Bau tidak sedap yang timbul itu membuat 27 warga mendapat perawatan karena mengeluh mual-mual. Satu warga lainnya yang sempat dirujuk ke rumah sakit karena mengalami muntah-muntah dan pusing juga sudah pulang. 

“Satu orang yang sempat dirujuk ke Rumah Sakit Ibnu Sina juga sudah pulang,” ujar Kepala Desa Sambiroto, Sudjono.

Sudjono menambahkan, reaksi tubuh warga akibat bau busuk memang berbeda-beda. Jika sistem kekebalan tubuhnya lemah bisa mual pusing dan muntah, bahkan pingsan. 

Warga yang mencium bau tidak sedap itu berada di RT/Blok 9 hingga RT/Blok 12. Pihak desa bersama dengan operator JOB-PPEJ langsung mengevakuasi warga untuk mendapat penanganan medis. Mereka kemudian diobservasi di rumah masing-masing. Satu orang, Supiatun (52), warga Rt/Blok. 11 Rw. 02 di rujuk ke Rumah Sakit Ibnu Sina.

Dihubungi terpisah, Kontraktor Kontrak Kerjasama (KKKS) Joint Operating Body Pertamina Petrochina East Java (JOB-PPEJ) memastikan bau tidak sedap yang tercium warga bukan akibat adanya pipa gas yang bocor. Bau tidak sedap yang tercium warga pada Senin (10/7) itu terjadi saat dilakukan kegiatan work over (perawatan sumur) di PAD A, tepatnya saat pencabutan cubing.

“Semburan bau tidak sedap itu sudah berhasil kami atasi. Penanganan terhadap warga yang mulai-mual pun sudah langsung dilakukan. Intinya, situasi sudah aman dan terkendali. Meski begitu kami meminta maaf atas ketidaknyamanan akibat bau tidak sedap itu,” kata Field Admin Superintendent (FAS) JOB PPEJ, Akbar Pradima, Senin (10/7).

Akbar Pradima menjelaskan, pekerjaan perawatan sumur atau work over adalah kegiatan rutin dalam industri migas. Meski sudah berupaya hati-hati dan cermat, tetapi tetap ada risiko semburan bau tidak sedap. Karena itulah, pihak JOB-PPEJ tiap tahun selalu melakukan pelatihan situasi tanggap darurat bersama warga di daerah sekitar wilayah operasi.

Kecepatan penanganan penyebaran bau tidak sedap ini merupakan hasil simulasi penanganan situasi tanggap darurat yang rutin dilakukan bersama warga.

“Manajemen JOB PPEJ mengucapkan terima kasih karena warga selama ini mendukung simulasi penanganan situasi tanggap darurat. Kami juga berterima kasih atas dukungan dan kerjasama yang selama ini diberikan warga sehingga JOB-PPEJ bisa beroperasi dengan

lancar,” katanya

Duta Mayarakat, Page-15, Wednesday, July 12, 2017

Gas Imports Will Be More Easier

Imports of liquefied natural gas or LNG will be easier with the Iokal gas price requirement in the hands of consumers above 11.5% of the price of Indonesian oil.

Provisions concerning gas import are regulated in Minister of Energy and Mineral Resources Regulation no. 11/2017 on Gas Utilization for Power Generation which was issued on January 30, 2017. The regulation states that gas import can be realized if domestic price is above 11.5% of Indonesian crude price (ICP).

However, the ICP 11.5% provision is not confirmed whether when it is in the hands of consumers, at the gas terminal (excluding the cost of regasification and transportation) or at the mouth of the well

Under the regulation, PT Perusahaan Listrik Negara and private electricity producers may be allowed to import gas destined for generator fuel. Meanwhile, power plants outside the well (well head), if gas prices are higher and 11.5% ICP, PLN and private developers are allowed to use liquefied natural gas (LNG).

Prices for LNG apply in accordance with the market, ie 11.5% of ICP and excluding transportation costs. If the imported LNG price is greater than 1I, 5% ICP, PLN and private Iistrik developers are allowed to purchase domestic gas which costs higher than 11.5% ICP. If IGP is assumed to be US $ 50 / barrel, the maximum gas price the developer can buy is US $ S, 7 / MMBtu.

Deputy Minister of Energy and Mineral Resources (ESDM) Arcandra Tahar said the price of gas that became the reference should be when it is in the hands of consumers. The reason is that the provisions in the regulation have only touched on gas price in the regasification terminal or landed price also FOB.

In fact, to utilize the gas there are other business chains such as LNG must go through the process of regasification and delivery through pipelines that require additional costs.

"So the final price compared is not the price of landed price or FOB because there is still transportation and regasification," he said After attending a Working Meeting at Commission VII DPR, Monday (10/7).

According to him, if still using the same formula, the actual gas price for the electricity sector will not be cheaper. For example, he calls PLN getting 11.4% LNG price from ICP.

However, the price still needs to take into account the cost of regasification also toll fee or the cost of delivering gas through the pipeline. The price can reach US $ 11 per MMBtu even US $ 12 per MMBtu in the hands of the end consumer. Thus, the price formula stipulated in Ministerial Regulation 11/2017 still does not meet the capabilities of PLN.

"There are still transportation and regasification costs can be about US $ 11 or even US $ 12. Meaning that PLN would not? PLN does not want because the price is more expensive "

Director General of Electricity, Andi Noorsaman Sommeng, said that in the revision, the regulation will be given an explanation of the condition for the gas pricing formula to be determined in accordance with the conditions in the field.

IN INDONESIAN

Impor Gas Akan Lebih Mudah Direalisasikan

Impor gas alam cair atau LNG akan semakin mudah dengan persyaratan harga gas Iokal di tangan konsumen di atas 11,5% dari harga minyak Indonesia.

Ketentuan soal impor gas diatur dalam Peraturan Menteri ESDM No. 11/2017 tentang Pemanfaatan Gas untuk Pembangkit Listrik yang terbit pada 30 Januari 2017. Dalam aturan itu disebutkan bahwa impor gas bisa direalisasikan jika harga di dalam negeri di atas 11,5% dari harga minyak Indonesia (Indonesian crude price/ICP).

Namun, ketentuan 11,5 % ICP itu tidak ditegaskan apakah ketika sudah di tangan konsumen, di terminal gas (belum termasuk biaya regasifikasi dan transportasi) atau di mulut sumur

Melalui aturan itu, PT Perusahaan Listrik Negara dan produsen Iistrik swasta boleh untuk mengimpor gas yang diperuntukkan bagi bahan bakar pembangkit. Sementara itu, pembangkit di luar mulut sumur (well head), jika harga gas Iebih tinggi dan 11,5 % ICP, PLN dan pengembang swasta diperbolehkan untuk menggunakan gas alam cair (LNG). 

Harga untuk LNG berlaku sesuai dengan pasar, yakni 11,5% dari ICP dan belum termasuk biaya transportasi. Jika harga LNG impor lebih besar dari 1I,5% ICP, PLN dan pengembang Iistrik swasta diperbolehkan membeli gas dalam negeri yang harganya Iebih tinggi dari 11,5% ICP. Jika diasumsikan IGP US$50/barel, harga gas maksimal yang bisa dibeli pengembang listrik adalah US$S,7/MMBtu.

Wakil Menteri Energi dan Sumber Daya Mineral (ESDM) Arcandra Tahar mengatakan, harga gas yang menjadi acuan seharusnya ketika sudah berada di tangan konsumen. Pasalnya, ketentuan dalam aturan itu baru menyinggung harga gas di terminal regasifikasi atau landed price juga FOB.

Padahal untuk memanfaatkan gas masih terdapat rantai bisnis lainnya semisal dari LNG harus melalui proses regasifikasi serta penghantaran melalui pipa yang memerlukan biaya tambahan. 

“Jadi harga akhirnya yang dibandingkan bukan harga landed price atau FOB karena masih ada transportasi dan regasifikasi," ujarnya

usai menghadiri Rapat Kerja di Komisi VII DPR, Senin (10/7).

Menurutnya, bila masih menggunakan formula yang sama, sebenarnya harga gas bagi sektor ketenagalistrikan tidak menjadi Iebih murah. Sebagai contoh, dia menyebut PLN mendapatkan harga LNG 11,4% dari ICP.

Namun, harga tersebut masih perlu memperhitungkan biaya regasifikasi juga toll fee atau biaya penghantaran gas melalui pipa. Harganya bisa mencapai US$ 11 per MMBtu bahkan US$12 per MMBtu di tangan konsumen akhir. 

Dengan demikian, formula harga yang ditetapkan dalam Peraturan Menteri 11/2017 masih belum memenuhi kemampuan PLN.

“Masih ada biaya transportasi dan regasifikasi harganya bisa menjadi sekitar US$11 bahkan US$12. Artinya PLN mau tidak? PLN tidak mau karena harganya Iebih mahal"

Dirjen Ketenagalistrikan Andi Noorsaman Sommeng mengatakan, dalam revisi aturan itu nantinya diberi penjelasan kondisi agar formula harga gas yang ditetapkan sesuai dengan kondisi di lapangan.

Bisnis Indonesia, Page-30, Wednesday, July 12, 2017

Aramco Prediction Happens Drastic Depreciation

World oil supply is expected to shrink drastically due to the decline in new investment activity in the sector. The condition is also augmented by the slow growth of new refinery discoveries. This was revealed by Saudi Aramco chief executive Amin Nasser. According to him, new discoveries in the form of shale oil and new alternative energy sources will be an important factor to meet the energy demand in the future.

However, he asserted it was too early to assume that the new energy products would quickly replace The supply space abandoned by conventional oil and gas so far.

"If we look at the long-term oil supply situation, we'll see an increasingly worrying picture. Financial investors avoid major investments in oil exploration, long-term development and related infrastructure. Investation In smaller quantities such as shale oil will not be too helpful, "said Nasser, as quoted by Reuters on Monday (10/7)

According to company data, about US $ 1 trillion of investment in the oil sector has disappeared since a fall in oil prices Globally by 2014. Studies show that a new oil production of 20 million barrels per day will be needed over the next five years to meet demand growth and offset a decline in supply at the old refinery.

"The new findings are also experiencing a large downward trend. The volume of conventional oil found worldwide over the last four years has been reduced by more than half compared to the previous four years, "continued Nasser.

Aramco, himself claimed to continue to increase investment in maintaining oil production capacity of 12 million barrels per day. The company plans to invest more than US $ 300 billion over the next decade to maintain its production capacity.

Nasser said the investment would include both conventional and non-conventional oil products. According to him, one of Aramco's priorities is the direct conversion of crude oil to petrochemicals. In addition the company also plans to focus on solar and wind power projects.

Aramco's plan to release its 5% stake to the public in 2018 is also one of the company's efforts to increase investment in the energy sector, especially oil. To smooth the Initial Public Offering (IPO) step, HSBC Holdings Plc. Was officially appointed as an advisor to the corporate action of the oil company belonging to the kingdom of Saudi Arabia.

HSBC Chief Executive Stuart Gulliver said the decision, issued in April, had been approved by the company's shareholders in Hong Kong. HSBC itself will later join other finance companies such as JP Morgan Chase 81 Co and Morgan Stanley, which has been designated first by Aramco.

As is known, the Government of Saudi Arabia plans to sell a 5% share ownership of Saudi Aramco in 2018. In terms of government targeting the corporate action in the second half of 2018. The stock release action is planned to use a dual listing scheme.

    With the company capitalization of US $ 2 trillion, the sale of 5% of the company's shares will make the company based in Dhahran will get US $ 100 billion.

IN INDONESIA

Aramco Prediksi Terjadi Penyusutan Drastis

Pasokan minyak dunia diperkirakan mengalami penyusutan drastis lantaran turunnya aktivitas investasi baru di sektor tersebut. Kondisi itu juga ditambah oleh melambatnya pertumbuhan penemuan kilang baru. Hal itu diungkapkan oleh Kepala Eksekutif Saudi Aramco Amin Nasser. Menurutnya, penemuan baru yang berupa shale oil dan sumber energi alternatif baru akan menjadi faktor penting untuk memenuhi permintaan energi di masa depan.

Namun, dia menegaskan terlalu dini untuk berasumsi bahwa produk-produk energi baru itu akan secara cepat menggantikan

ruang pasokan yang ditinggalkan oleh minyak dan gas konvensional selama ini.

“Jika kita melihat situasi pasokan minyak jangka panjang, kita akan melihat gambaran yang semakin mengkhawatirkan. Investor keuangan menghindari investasi besar dalam eksplorasi minyak, pembangunan jangka panjang dan infrastruktur terkait. Investasi

dalam jumlah yang lebih kecil seperti shale oil tidak akan terlalu menolong,” kata Nasser, seperti dikutip dari Reuters, Senin (10/7)

Menurut data perseroan, sekitar US$1 triliun investasi di sektor minyak telah menghilang sejak terjadi penurunan harga minyak

global pada 2014. Studi menunjukkan, produksi minyak baru sebesar 20 juta barel per hari akan dibutuhkan selama lima tahun ke depan untuk memenuhi pertumbuhan permintaan dan mengimbangi penurunan pasokan di kilang lama.

“Penemuan baru juga mengalami kecenderungan penurunan yang besar. Volume minyak konvensional yang ditemukan di seluruh dunia selama empat tahun terakhir telah berkurang lebih dari separuhnya dibandingkan dengan empat tahun sebelumnya,” lanjut Nasser.

Aramco, sendiri mengaku terus menambah investasi dalam mempertahankan kapasitas produksi minyaknya sebesar 12 juta barel per hari. Perusahaan tersebut berencana menginvestasikan dana lebih dari US$300 miliar selama sedekade ke depan untuk mempertahankan kapasitas produksinya.

Nasser menegaskan, investasi itu akan meliputi produk minyak konvensional maupun non-konvensional. Menurutnya, salah satu prioritas Aramco adalah konversi langsung minyak mentah menjadi petrokimia. Selain itu perusahaan juga berencana memusatkan perhatian pada proyek tenaga surya dan angin.

Adapun rencana Aramco untuk melepas 5% kepemilikan sahamnya ke publik pada 2018 juga merupakan salah satu upaya perusahaan untuk meningkatkan investasi pada sektor energi terutama minyak. Untuk memuluskan langkah penawaran umum perdana (Initial Public Offering/IPO) tersebut, HSBC Holdings Plc. secara resmi ditunjuk sebagai penasihat aksi korporasi perusahaan minyak milik kerajaan Arab Saudi tersebut.

Chief Executive HSBC Stuart Gulliver mengatakan, keputusan yang diterbitkan pada April lalu itu telah mendapat persetujuan dari para pemegang saham perusahaan di Hong Kong. HSBC sendiri nantinya akan bergabung dengan perusahaan keuangan lainnya seperti JP Morgan Chase 81 Co dan Morgan Stanley, yang telah ditunjuk terlebih dahulu oleh Aramco.

Seperti diketahui, Pemerintah Arab Saudi berencana menjual 5% kepemilikan saham dari Saudi Aramco pada 2018. Dalam hal pemerintah menargetkan aksi korporasi tersebut pada semester II/2018. Aksi pelepasan saham perdana tersebut rencananya akan menggunakan skema dual listing.

       Dengan nilai kapitalisasi perusahaan yang mencapai US$2 triliun, penjualan 5% saham perusahaan akan membuat perusahaan yang berbasis di Dhahran ini akan memperoleh dana US$100 Miliar.

Bisnis Indonesia, Page-5, Tuesday, July 11, 2017

Hopes mount for gas production in Makassar Strait

Gas production from various fields in the Makassar Strait might be bigger than expected, raising hopes that gas from this area could soon substitute declining production rates at depleted gas fields in other parts of the country, including the aging Mahakam field in East Kalimantan.

Such hopes emerged following the start of production at the Jangkrik complex, comprising the Jangkrik field and the Jangkrik North East field, at the Muara Bakau block in late May.

The complex, operated by Italian energy firm Eni SpA, is expected to reach a peak production rate of 600 million standard cubic feet per day (mmscfd) by the end of the year, up from only 450 mmscfd in the first week of July. In addition to this, it also produces 1,500 to 2,000 barrels of condensate per day

“To reach the production rate of 600 mmscfd, Eni should add several more production platforms [at the complex],” Up-stream Oil and Gas Regulatory Special Task Force (SKK Migas) deputy for operation control Fatar Yani Abdurrahman told reporters recently

Moreover, Fatar said Eni planned to submit to SKK Migas a plan of development (POD) for the newly discovered Marakes field nearby the Jangkrik complex in September. The Marakes field is projected to start producing 150 mmscfd of gas by the end of 2018, or early 2019, by using the Jangkrik floating production unit (FPU) built by Eni at the Muara Bakau block.

"As the facility has a maximum capacity of 600 mmscfd, Eni might have to re-adjust gas production at its fields. For instance, if the Marakes field has started producing 150 mmscfd of gas, the production from the Jangkrik complex might only reach 450 mmscfd,” Fatar said.

He said Eni was also in discussion with Chevron Indonesia, the local branch of American oil and gas giant Chevron, to share some of its production facilities, including in electricity and water supply, to help support Chevron’s Indonesia Deepwater Development project at the Gendalo and Gehem fields in the Makassar Strait.

The Gendalo and Gehem fields, expected to have a combined production rate of 1,000 mmscfd, are slated ,to begin production around 2023.

“So, Chevron doesn’t need to invest a large amount of money to build the same facilities. That way there will be no duplication and the company can start producing faster than expected,” Energ and Mineral Resources Minister Ignasius Jonan said in a statement during a visit to the Jangkrik FPU in early June.

In total, gas production from the Jangkrik, Marakes, Gendalo and Gehem fields reached a peak of 1,750 mmscfd, or 23.3 percent of Indonesia’s entire production, as of June.

This comes as good news for PT Badak NGL, which operates a major liquefied natural gas plant in Bontang, East Kalimantan. The company is bounded by a 20-year agreement with Eni to supply gas to the Tanjung Benoa regasification terminal in Bali. 

The company previously projected declining cargo output for the next few years due to insufficient supply from the depleted Mahakam field. Mahakam, the country’s biggest gas-producing field, yielded 1,504 mmscfd of gas in the first half of this year, down 14 percent compared to a production rate of 1,752 mmscfd recorded throughout 2016.

Jakarta Post, Page-13, Monday, July 10, 2017