Awaiting Priority Effect 4 Gas Project

The government's decision to include four oil and gas projects into national priorities is expected to accelerate the realization of investment in the oil and gas sector.

The government hopes that priority project labels will have new powers so that the project can run quickly. The four oil and gas projects are the Eternal Field, Masela Block in Maluku; Field Jambaran-Tiung Biru in East Java; Indonesia Deepwater Develop ment (IDD) project in East Kalimantan; And Tangguh Train III in West Papua.

The basis for priority project design refers to several principles. First, conformity with Presidential Regulation no. 75/2014 on the Committee for the Acceleration of the Provision of Priority Infrastructure (KPPIP), projects that are economically or financially beneficial are greater than other projects in the same sector.

Secondly, according to the data KPPIP, of the 248 projects that dominated the road and dam construction, project investment of Rp 289 billion gas development project Masela gas (Inpex Masela Ltd), Rp 124.8 trillion for IDD (Chevron), liquefied natural gas / Tangguh LNG Train III (BP Tangguh) Rp 104 trillion, and Jambaran-Tiung Biru (Pertamina EP Cepu) Rp 26.7 trillion.

The total investment value of the four projects is Rp 545.4 trillion or equivalent to about eight projects of Jakarta-Bandung high speed train which cost Rp 68.7 trillion.

Third, the project needs support for problem solving from KPPIP and the government.

Fourth, projects that have a large private participation impact so that it is attempted to start construction in 2018, reaching the finan- cial close in 2019 and can trigger an interest

Private Investing.

Projects included in KPPIP radar has received support in the form of licensing such acceleration in Patimban Port project, the acceleration and completion of land acquisition constraints, and the achievement of such financial close on a power plant project stems.

Other support is the settlement of funding issues such as the Jakarta MKT project, preparation of the study of project preparation studies, publication of legal basis such as Government Regulation no. 27/2017 and solving the spatial problem problem as happened in the Java-1 steam power plant project.

In further examination, three of the four projects that have not reached the final stage of investment / FID decision-making, the main problem is the commercial aspect.

First, the Abadi field is currently being discussed between the government and contractors associated with any conditions that allow it to gas field development can go as economies of scale after President Joko Widodo decided change in LNG development scheme which was originally an offshore plant into a refinery ashore.

The government is still looking for potential buyers of gas in order to decide the capacity of the LNG plant to be built. Meanwhile, the first gas and Masela targeted the government in 2026.

Secondly, the Jambaran-Tiung Biru project which is still in the negotiation stage of price with PT Perusahaan Listrik Negara as a potential buyer of gas. The contractor's gas price has not been agreed yet because it has not been in accordance with the buyer's ability and economic development of the field. The project is targeted to produce its first gas by 2019.

Third, the IDD project since the government to submit the revised proposal development plan (plan of development / PoD) at the beginning of 2016 until now there has been no progress as a matter of economic assumptions the project is being evaluated by the contractor following the rejection of the proposed offering investment incentives in the form of credit.

In addition, it is also discussed about the use of shared facilities in the vicinity of IDD projects so that investment can be lower. At least, a project that needs only land acquisition and land acquisition is Tangguh Train III which is planned for the physical construction process by the end of this year so that gas starts to flow in 2020.

HARDER

The development of the gas field is actually more challenging than the oil field. Upstream Oil and Gas Gas Analyst Wood Mackenzie Johan Utama said that in addition to licensing and land acquisition, the contractor must ensure the infrastructure and buyers of gas. In addition, other issues to be solved are related to the gas price agreement with the buyer.

Not meeting the ability of buyers and economics of field development to make gas purchase agreement is canceled. Sometimes, buyers who have received allocations from the government can not buy gas from a field because the price in which the buyer wants has not been agreed by the gas producer.

"For the gas field, the most common factor being the bottleneck is the gas marketing factor."

Meanwhile, Upstream Director of Pertamina, Syamsu Alam said that there is currently no positive impact with the entry of the Jambaran-Tiung Biru project as one of the national priority projects. However, he believes the national priority label will have a positive impact on the development of the gas field in East Java.

"Influential for sure, but if not now. If it is a priority, there must be effort, "he said.

It would be better if the momentum of the entry of gas development projects into the list of national priority projects can show the seriousness of the government to secure domestic gas supply at the time of assumption of gas imports in 2020.

Licensing and access to land acquisition actually become what should be given by the government because it involves the aspect of ease of doing business.

Meanwhile, commercial and fiscal aspects should also be of concern as it concerns the competitiveness of investments when other countries are equally 'selling' to attract investors. So, whether the entry of four gas projects into the priontas project into a kind of simsalabim or abracadabra Spell?

IN INDONESIA

Menanti Efek Prioritas 4 Proyek Gas

Keputusan pemerintah dengan memasukkan empat proyek minyak dan gas bumi ke dalam prioritas nasional diharapkan mampu mempercepat realisasi investasi sektor migas.

Pemerintah berharap agar label proyek prioritas akan ada kekuatan baru sehingga proyek bisa berjalan dengan cepat. Keempat proyek migas tersebut adalah Iapangan Abadi, Blok Masela di Maluku; Lapangan Jambaran-Tiung Biru di Jawa Timur; Proyek Indonesia Deepwater Develop ment (IDD) di Kalimantan Timur; dan Tangguh Train III di Papua Barat.

Dasar penetapan proyek prioritas mengacu pada beberapa prinsip. Pertama, kesesuaian dengan Peraturan Presiden No. 75/2014 tentang Komite Percepatan Penyediaan lnfrastruktur Prioritas (KPPIP), proyek yang bermanfaat secara perekonomian atau secara finansial nilainya lebih besar dari proyek lain di sektor yang sama.

Kedua, sesuai dengan data KPPIP, dari 248 proyek yang didominasi pembangunan jalan dan bendungan ini, investasi dari proyek pengembangan gas Rp 289 triliun proyek gas Masela (Inpex Masela Limited), Rp 124,8 triliun untuk IDD (Chevron), kilang gas alam cair/LNG Tangguh Train III (BP Tangguh) Rp 104 triliun, dan Jambaran-Tiung Biru (Pertamina EP Cepu) Rp 26,7 triliun.

Total nilai investasi keempat proyek itu Rp 545,4 triliun atau setara dengan sekitar delapan proyek kereta cepat Jakarta-Bandung yang menelan biaya Rp 68,7 triliun.

Ketiga, proyek itu membutuhkan dukungan penyelesaian masalah dari KPPIP dan pemerintah. 

Keempat, proyek yang memberikan dampak partisipasi swasta yang besar sehingga diupayakan agar bisa memulai konstruksi pada 2018, mencapai penuntasan pendanaan (finanfial close) pada 2019 dan bisa memicu ketertarikan 

Swasta Berinvestasi.

Proyek yang masuk dalam radar KPPIP telah mendapat dukungan berupa percepatan perizinan seperti pada proyek Pelabuhan Patimban, percepatan dan penyelesaian kendala pengadaan lahan, dan pencapaian financial close seperti pada proyek PLTU Batang.

Dukungan lainnya yakni penyelesaian masalah pendanaan seperti pada proyek MKT Jakarta, penyusunan kajian kajian penyiapan proyek, penerbitan landasan hukum seperti Peraturan Pemerintah No. 27/2017 dan penyelesaian masalah penataan ruang seperti terjadi di proyek PLTU Jawa-1.

Jika ditilik lebih lanjut, tiga dari empat proyek yang belum menyentuh tahapan penyampaian keputusan akhir investasi/FID, masalah utamanya pada aspek komersial.

Pertama, Lapangan Abadi saat ini masih dibahas antara pemerintah dan kontraktor terkait dengan kondisi apa saja yang memungkinkan agar pengembangan lapangan gas bisa berjalan sesuai skala ekonomi setelah Presiden Joko Widodo memutuskan perubahan skema pembangunan kilang LNG yang semula kilang terapung menjadi kilang darat.

Pemerintah pun masih mencari calon pembeli gas agar bisa diputuskan kapasitas kilang LNG yang akan dibangun. Adapun, gas pertama dan Masela ditargetkan pemerintah pada 2026.

Kedua, proyek Jambaran-Tiung Biru yang kini masih dalam tahap negosiasi harga dengan PT Perusahaan Listrik Negara sebagai calon pembeli gasnya. Harga gas yang telah ditetapkan kontraktor belum bisa disepakati karena belum sesuai dengan kemampuan pembeli dan keekonomian pengembangan lapangan. Proyek itu ditargetkan bisa menghasilkan gas pertamanya pada 2019.

Ketiga, proyek IDD yang sejak pemerintah mengembalikan revisi proposal rencana pengembangan (plan of development/PoD) pada awal 2016 hingga kini belum terdapat progres karena hitungan asumsi keekonomian proyek sedang dievaluasi oleh kontraktor menyusul ditolaknya usulan pemberian insentif berupa investment credit.

Selain itu, dibahas pula soal opsi-opsi penggunaan fasilitas bersama di sekitar proyek IDD agar investasi bisa lebih rendah. Paling tidak, proyek yang hanya membutuhkan bantuan perizinan dan pembebasan lahan yakni Tangguh Train III yang rencananya proses konstruksi fisik pada akhir tahun ini sehingga gas mulai mengalir pada 2020.

LEBIH SULIT

Pengembangan lapangan gas sebenarnya lebih menantang dibandingkan dengan lapangan minyak. Analis Hulu Migas Asia Pasifik Wood Mackenzie Johan Utama mengatakan, selain soal perizinan dan pembebasan lahan, kontraktor harus memastikan adanya infrastruktur dan pembeli gas. Selain itu, masalah lain yang harus diselesaikan yakni terkait dengan kesepakatan harga gas dengan pembeli.

Belum bertemunya kemampuan pembeli dan keekonomian pengembangan lapangan membuat perjanjian jual beli gas batal dilakukan. Terkadang, pembeli yang sudah mendapat alokasi dari pemerintah batal membeli gas dari suatu lapangan karena harga yang di inginkan pembeli belum disepakati oleh produsen gas.

“Untuk lapangan gas, faktor yang paling sering menjadi penghambat adalah faktor pemasaran gas.”

Sementara itu, Direktur Hulu Pertamina, Syamsu Alam mengatakan bahwa saat ini belum terdapat dampak positif dengan masuknya proyek Jambaran-Tiung Biru sebagai salah satu proyek prioritas nasional. Namun, dia meyakini label prioritas nasional akan membawa dampak positif bagi pengembangan lapangan gas di Jawa Timur itu.

“Berpengaruh pasti, tetapi kalau sekarang, belum. Kalau itu prioritas, harus ada effort,” katanya.

Akan lebih baik bila momentum masuknya proyek pengembangan gas ke daftar proyek prioritas nasional bisa menunjukkan kesungguhan pemerintah untuk mengamankan pasokan gas domestik di saat asumsi impor gas pada 2020.

Perizinan dan akses pembebasan lahan sebenarnya menjadi apa yang semestinya diberikan pemerintah karena menyangkut aspek kemudahan berbisnis.

Sementara itu, aspek komersial juga fiskal seharusnya menjadi perhatian karena menyangkut daya saing investasi ketika negara lain sama-sama sedang ‘berjualan’ menarik investor. Jadi, apakah masuknya empat proyek gas ke dalam proyek priontas menjadi semacam mantra simsalabim atau abrakadabra? 

BISNIS INDONESIA, Page-30, Monday, July 17, 2017

Gas imports may not happen anytime soon

Indonesia may not have to import gas at all in the near future as it expects new production to make up for the declining output from various depleted gas fields, as domestic consumption remains modest.

The government previously predicted that the country might need to start importing liquefied natural gas (LNG) in 2019 as domestic demand was projected to skyrocket, especially considering the development of various gas fueled power plants across the country.

Data from state electricity firm PLN indicated that Indonesia’s annual gas demand for power generation would increase 81.2 percent to 2,805 billion British thermal units per day (bbtud) from 2017 to 2026.

On the other hand, Indonesia only produced 6,440 million standard cubic feet per day (mmscfd) of gas in 2016, 4.2 percent less than a year earlier. Previous projections showed that production might keep falling to about 6,000 mmscfd by 2030 because of aging fields and a lack of new discoveries, leading to a shortage of about 4,000 mmscfd, 32 tons of LNG, by then.

“However, we might not need to import gas in 2019, especially as new production from several fields, including the Jangkrik complex, could be higher than expected,” the Energy and Mineral Resources Ministry’s oil and gas director general, IGN Wiratmaja Puja, said on Wednesday. The Jangkrik complex comprising the Jangkrik field and the Jangkrik NorthEast field in the Muara Bakau block in the Makassar Strait has been on stream since late May.

The complex, which is operated by Italian energy firm Eni SpA, is expected to reach a peak production rate of 600 mmscfd by the end of the year, up from the previous estimate of only 450 mmscfd. 

Eni has also recently discovered the Marakes field near the Jangkrik complex that is projected to start producing 150 mmscfd of gas by the end of 2018 or early 2019.

“If Train 3 of the Tangguh LNG plant [in West Papua] is able to start operations in 2020, our gas supply will increase once again. If the Masela block [in the Arafura Sea] can also start production in 2026, I guess we don’t need to import gas after that,” Wiratmaja said.

Nonetheless, the government still has to find domestic buyers for all of the country’s LNG. According to the ministry, there were still 53.33 and 33.97 uncommitted LNG containers, each of which holds around 143,000 cubic meters of LNG, for 2017 and 2018, respectively, meaning that there were no buyers for this cargo as of Thursday

Moreover, uncommitted LNG averaged at 132.79 containers per year for the 2018 to 2035 delivery period, most of which came from the LNG Bontang relinery in East Kalimantan.

On the otherhand, Wiratmaja said domestic gas consumption for power generation might not be as high as expected because of Indonesia’s growing appetite for coal-Hred power plants.

PLN’s latest Electricity Procurement Business Plan (RUPTL) states that Indonesia intends to develop enough power plants to generate 77.9 gigawatts (GW) of electricity from 2017 to 2026.

About 40.9 percent of the generated electricity will come from coal fired facilities, 24.1 percent from combined cycle power plants and 7.2 percent from gas-fueled ones. State-owned energy giant Pertamina’s LNG vice president Didik Sasongko Widi shared the same view, saying that coal would still be the cheapest source of energ in the long run.

“The development of gas infrastructure faces a big challenge because of various problems, including ones related to land acquisition and permit issuance,” Didik said on Thursday.

The government has recently released the 2016 to 2030 road map for gas infrastructure development, estimated to have a total investment value of US$48.2 billion, Research and consultancy firm Wood Mackenzie has also estimated that Indonesia would need to build additional regasification infrastructure for LNG with a combined capacity of 25 million tons per annum (mtpa) by 2035.

Wood Mackenzie Asia Pacific senior analyst for gas and power Edi Saputra said that Indonesia did not have to import gas in the near future as there would only be a small gas shortage in 2020 and 2025.

“During the 2020 to 2025 period, many coal-fired power plants from the governments 35 GW program will commence operations, decreasing the LNG demand,” Edi said, adding that PLN would prefer to buy electricity from those plants because of their lower costs.

Jakarta Post,  Page-9, Friday, July 14, 2017

Acquisition of Oil and Gas Blocks Abroad Quits Target

PT Pertamina has the potential to not add new oil and gas blocks in other countries. This is because the process of acquiring oil and gas blocks in Iran and Russia is not expected to be completed this year.

Upstream Director of Pertamina Syamsu Alam said the company is still processing the acquisition of oil and gas blocks both in Iran and in Russia. For the acquisition of oil and gas blocks in Iran, Pertamina's team is now studying the commercial model of the country's oil and gas contracts. As for the acquisition in Russia, it still sees the prerequisites offered.

However, the acquisition of oil and gas blocks in these two countries is not expected to be completed this year. So the company does not get additional oil and gas blocks abroad by 2017.

"Not to add oil and gas blocks seems to have not been closing the acquisition," he said in Jakarta, Wednesday (12/7) night.

Pertamina initially targeted to add oil and gas blocks in Iran and Russia. In Iran, Pertamina will participate in an auction held by the Iranian Government to be the manager of two blocks at once, Ab-Teymour Field and Mansouri which is estimated to have oil reserves of 5 billion barrels.

In Russia, Rosneft said it had signed a memorandum of understanding with Pertamina for cooperation working on The Northern Tip of Chayvo Field and Russkoye Field. In the Field of The Northern Tip of Chayvo, Pertamina can take up to 20% stake, while at Russkoye Square up 37.5%.

Pertamina is targeting to get 35 thousand bpd of oil and oil and gas reserves of 200 million barrels oil equivalent from Russia. For the acquisition of oil and gas blocks this year, the company has set aside about US $ 1 billion from the 2017 investment budget of US $ 3.44 billion. Natural refusal, the addition of oil and gas blocks abroad this year is not realized because of financial problems.

"The process is not finished yet. In Iran and Russia it seems that no one is overtaken this year, "he said.

In Iran for example, due to join the auction, Pertamina called to learn Iranian Petroleum Contract (IPC). The reason, Iran has just changed the oil and gas contracts offered to investors. Pertamina has discussed the technical aspects of the development of blik with the Iranian side.

Now the company is discussing its commercial aspects. If it wins the auction, Pertamina and its partners will hold a majority stake and become the block operator. In accordance with regulations in Iran, Pertamina must hold a local company to join the auction.

"For now Pertamina is ahead of its two competitors," Alam said.

Next year, it will continue the process of adding oil and gas blocks in these two countries. Not only that, the company is also studying the prospects of other oil and gas abroad, namely in Africa and the Middle East. Africa is the choice one of them based on the political conditions in the continent. However, it has not confirmed whether there will be new oil and gas blocks to be acquired next year.

"We want to try Africa and the Middle East," he said.

Currently, Pertamina already has oil and gas blocks in several countries. In Iraq, the company owns shares in West Qurna Square 1. In Algeria, the state-owned oil and gas company owns 65% of MLN and 16.9% in EMK Field. In Malaysia, the company holds a stake in Block K, Kikeh Block, Block SNR Block SK309 and Block SK311. Most recently, Pertamina controls 72.65% of French oil and gas company, Maurel & Prom.

Maurel & Prom has oil and gas assets scattered in Gabon, Nigeria, Tanzania, Namibia, Colombia, Canada, Myanmar, Italy and other countries. However, the main assets that have been produced are in Gabon, Nigeria and Tanzania.

Previously, Pertamina said it would rely on oil and gas production from its overseas assets in the future, with a contribution target of 33% of total production of 2025 or equivalent to 650 thousand barrels of oil equivalent per day / boepd. Acquisitions abroad are needed to minimize the difference in domestic demand and supply of oil and gas in the future.

Oil production is targeted to reach 822 thousand bpd in 2025, which is 353 thousand bpd from domestic and 469 thousand bpd from abroad. As for gas, it is targeted to increase to 5.71 billion cubic feet per day, ie 4.23 billion cubic feet of domestic and 1.48 billion cubic feet of foreign assets. In the same year, oil demand reached 1.7 million bpd and gas 9.1 billion cubic feet per day. Without acquisitions abroad, the gap between oil and gas supply and demand could be greater.

IN INDONESIA

Akuisisi Blok Migas di Luar Negeri Mundur dari Target

PT Pertamina berpotensi tidak menambah blok migas baru di negara Iain. Hal ini lantaran proses akuisisi blok migas di Iran dan Rusia diperkirakan tidak dapat selesai pada tahun ini.

Direktur Hulu Pertamina Syamsu Alam mengatakan, pihaknya masih memproses akuisisi blok migas baik di Iran maupun di Rusia. Untuk akuisisi blok migas di Iran, tim Pertamina kini sedang mempelajari model komersial dari kontrak migas negara tersebut. Sementara untuk akuisisi di Rusia, pihaknya masih melihat prasyarat yang ditawarkan.

Namun, akuisisi blok migas di kedua negara ini diperkirakannya tidak akan bisa dirampungkan tahun ini juga. Sehingga perseroan tidak mendapat tambahan blok migas di luar negeri pada 2017 ini. 

“Belum menambah blok migas sepertinya, belum closing akuisisi,” kata dia di Jakarta, Rabu (12/7) malam.

Seperti diketahui, Pertamina awalnya menargetkan dapat menambah blok migas di Iran dan Rusia, Di Iran, Pertamina akan mengikuti lelang yang digelar oleh Pemerintah Iran untuk menjadi pengelola dua blok sekaligus, Lapangan Ab-Teymour dan Mansouri yang diperkirakan memiliki cadangan minyak mencapai 5 miliar barel.

Di Rusia, Rosneft menyatakan telah meneken nota kesepahaman dengan Pertamina untuk kerja sama menggarap Lapangan The Northern Tip of Chayvo dan Lapangan Russkoye. Di Lapangan The Northern Tip of Chayvo, Pertamina bisa mengambil saham sampai 20%, sementara di Lapangan Russkoye sampai 37,5%. 

Pertamina menargetkan bisa mendapat minyak 35 ribu bph dan cadangan migas 200 juta barel setara minyak dari Rusia. Untuk akuisisi blok migas tahun ini, perseroan telah menyisihkan sekitar US$ 1 miliar dari anggaran investasi 2017 sebesar US$ 3,44 miliar. Alam menampik, penambahan blok migas di luar negeri tahun ini tidak terealisasi lantaran masalah keuangan. 

“Prosesnya saja belum selesai. Di Iran maupun Rusia sepertinya tidak ada yang terkejar tahun ini,” ujar dia.

Di Iran misalnya, lantaran ikut lelang, Pertamina disebutnya harus mempelajari Iranian Petroleum Contract (IPC). Pasalnya, Iran baru saja mengubah kontrak migas yang ditawarkan ke investor. Pertamina telah membahas aspek teknis soal pengembangan blik dengan pihak Iran. 

Kini perseroan sedang membahas aspek komersialnya. Jika menang lelang, Pertamina bersama mitra akan memegang saham mayoritas dan menjadi operator blok. Sesuai regulasi di Iran, Pertamina wajib menggandeng perusahaan lokal untuk mengikuti lelang. 

“Untuk sementara ini Pertamina unggul dibanding dua pesainnya,” kata Alam.

Pada tahun depan pihaknya akan melanjutkan proses penambahan blok migas di dua negara ini. Tidak hanya itu, perseroan juga sedang mempelajari prospek migas lain di luar negeri, yakni di Afrika dan Timur Tengah. Afrika menjadi pilihan salah satunya berdasarkan kondisi politik di benua tersebut.  Tetapi, pihaknya belum memastikan apakah akan ada blok migas baru yang akan diakuisisi pada tahun depan. 

“Kami mau coba Afrika dan Middle East,” ujarnya.

Saat ini, Pertamina telah memiliki blok migas di beberapa negara. Di Irak, perseroan memiliki saham di Lapangan West Qurna 1. Di Aljazair, perusahaan migas milik pemerintah itu menguasai 65% saham di Lapangan MLN dab 16,9% di Lapangan EMK Sementara di Malaysia, perseroan memegang kepemilikan saham di Blok K, Blok Kikeh, Blok SNR Blok SK309 dan Blok SK311. Yang terbaru, Pertamina menguasai 72,65% saham perusahaan migas Perancis, Maurel&Prom.

Maurel&Prom memiliki aset migas yang tersebar di Gabon, Nigeria, Tanzania, Namibia, Kolombia, Kanada, Myanmar, Italia, dan negara lainnya. Namun, aset utamanya yang telah berproduksi yakni di Gabon, Nigeria, dan Tanzania.

Sebelumnya, Pertamina menyatakan akan mengandalkan produksi migas dari aset-asetnya di luar negeri di masa mendatang, dengan target kontribusi mencapai 33% dari total produksi 2025 atau setara dengan 650 ribu barel setara minyak per hari (barrel oil equivalent per day/ boepd). Akuisisi di luar negeri diperlukan untuk memperkecil selisih kebutuhan dan pasokan migas domestik di masa mendatang.

Untuk produksi minyak ditargetkan mencapai 822 ribu bph pada 2025, yakni 353 ribu bph dari dalam negeri dan 469 ribu bph dari luar negeri. Sementara untuk gas, ditargetkan meningkat menjadi 5,71 miliar kaki kubik per hari, yaitu 4,23 miliar kaki kubik dari domestik dan 1,48 miliar kaki kubik dari aset luar negeri. Pada tahun yang sama, kebutuhan minyak mencapai 1,7 juta bph dan gas 9,1 miliar kaki kubik per hari. Tanpa akuisisi di luar negeri, selisih pasokan dan permintaan migas ini bisa lebih besar.

Investor Daily,  Page-9, Friday, July 14, 2017

Pertamina Delays Imports of LNG

PT Pertamina will not increase imports of liquefied natural gas / LNG. This follows a government statement on gas imports that have not been needed until 2020.

Vice President of Pertamina LNG Didik Sasongko said based on the latest developments, the gas requirement for gas project in the 35 Million Megawatt (MW) program is expected to occur in 2020, retreating from early prediction in 2019. This prompted the company to refrain from signing the contract Import of new LNG for a while.

"We hold first, see the economic development and gas needs," he said in Gas Indonesia Summit and Exhibition 2017 in Jakarta, Thursday (13/7).

He explained that the company previously signed the LNG import contract because the PLTG with a total capacity of 14 thousand MW in the 35 Million MW Program will boost national gas demand by 1,100 million cubic feet per day / mmscfd. If there is no guarantee of gas supply, these projects are difficult to continue because they can not enter the Final Investment Decision / FID stage.

"If you do not want to secure (gas supply), how can FID power plant? Therefore we prepare imports, "he said.

Regarding LNG that has been contracted, it will not be a burden for the company. If it is not absorbed by domestic consumers, it will market this LNG in the international market. Pertamina is now looking for a market. Japan as the largest LNG consumer country has always been an attractive market. In addition, there are new markets such as Bangladesh, Pakistan, Myanmar and the Philippines. Even the company already has an agreement with the buyer.

"There is an agreement, but I can not mention it," said Didik. Alluded to the buyer country, he just answered to the whole world. "Along the way from the United States to Indonesia, we must have a market there," he said.

Based on the record, Pertamina has signed three LNG import contracts. Pertamina has signed a gas sale and purchase agreement with Cheniere Energy Inc. subsidiary Corpus Christi Liquefaction Liability Company to supply 0.76 million tonnes per year of LNG from 2019 for 20 years. Pertamina has also contracted with Cheniere Energy with the same volume but starts in 2018 with a duration of 20 years.

Then, Pertamina has contracted with Woodside with a volume of about 0.6 million tons per year which can be increased to 1.1 million tons per year. The supply of 0.6 million tons per year starts shipping from 2022 to 2034 and can be increased to 1.1 million tons per year in 2024-2038.

Finally, the company has an agreement (head of agreement / HoA) with ExxonMobil to supply 1 million tons per year for 20 years starting from 2025.

The purchase and sale of LNG in the international market is in line with Pertamina's policy to become an energy supplier that can guarantee supply resilience and mitigate risks. This does not mean that the company will be purely operating as a trading arm.

"But we must have a trading arm or portfolio player for security of supply or efficiency of supply," he said.

Building Infrastructure

Although not adding imports, Didik said it will continue to build LNG regasification facilities.

"There are several regasifikasi, such as in Cilacap, East Java and East Java. But [its development] depends on development Economic, "he said.

Senior Expert of Gas and Power Wood Mackenzie Edi Saputra revealed, based on the study of its institutions, Indonesia will need gas imports in 2020 and 2025. Thus, Indonesia does not need long-term LNG import contracts. However, Indonesia needs to build a regasification facility.

Regasification development should be done considering the growing need of LNG, from now 2.8 million tons per year, to 5 million tons per year by 2020, and reaching 15 million tons per year by 2030.

"With the growth of LNG demand, it will require a new regasification infrastructure. Otherwise, can not fulfill Demand, "he explained.

IN INDONESIA

Pertamina Tunda lmpor LNG

PT Pertamina belum akan menambah impor gas alam cair/LNG. Hal ini menyusul pernyataan pemerintah mengenai impor gas yang belum diperlukan hingga 2020.

Vice President LNG Pertamina Didik Sasongko menuturkan, berdasarkan perkembangan terbaru, kebutuhan gas untuk proyek pembangkit listrik tenaga gas dalam Program 35 Ribu Megawatt (MW) diperkirakan akan terjadi pada 2020, mundur dari prediksi awal pada 2019. Hal ini membuat perseroan menahan untuk tidak meneken kontrak impor LNG baru untuk sementara waktu.

“Kami hold dulu, melihat perkembangan ekonomi dan keperluan gasnya,” kata dia dalam Gas Indonesia Summit and Exhibition 2017 di Jakarta, Kamis (13/7).

Dia menjelaskan, perseroan sebelumnye telah meneken kontrak impor LNG karena PLTG dengan total kapasitas 14 ribu MW dalam Program 35 Ribu MW bakal mendongkrak kebutuhan gas nasional sebesar 1.100 juta kaki kubik per hari/mmscfd.  Jika tidak ada jaminan pasokan gas, proyek-proyek ini sulit dilanjutkan karena tidak bisa masuk tahap Keputusan Investasi Akhir/FID. 

“Kalau tidak mau secure (pasokan gasnya), bagaimana bisa FID itu power plant? Oleh karena itu kami siapkan impor," ujarnya.

Terkait LNG yang telah dikontrak, disebutnya tidak akan menjadi beban bagi perseroan. Jika memang tidak terserap oleh konsumen domestik, pihaknya akan memasarkan LNG ini di pasar internasional. Pertamina kini sedang mencari pasar. Jepang sebagai negara konsumen LNG terbesar selalu menjadi pasar yang menarik. Selain itu, terdapat pasar-pasar baru seperti Bangladesh, Pakistan, Myanmar, dan Filipina. Bahkan  perseroan sudah punya kesepakatan dengan pembeli. 

“Sudah ada agreement, tapi tidak mungkin saya sebutkan,” kata Didik.  Disinggung negara pembelinya, dia hanya menjawab ke seluruh dunia.  “Sepanjang perjalanan dari Amerika Serikat sampai Indonesia, kami harus punya pasar di situ,” tuturnya.

Berdasarkan catatan, Pertamina telah meneken tiga kontrak impor LNG. Pertamina telah menandatangani perjanjian jual beli gas (PJBG) dengan anak usaha Cheniere Energy Inc yakni Corpus Christi Liquefaction Liability Company untuk memasok 0,76 juta ton per tahun LNG mulai 2019 selama 20 tahun. Pertamina juga sudah berkontrak dengan Cheniere Energy dengan volume yang sama namun dimulai pada 2018 dengan durasi 20 tahun.

Kemudian, Pertamina telah berkontrak dengan Woodside dengan volume sekitar 0,6 juta ton per tahun yang bisa ditingkatkan menjadi 1,1 juta ton per tahun. Pasokan 0,6 juta ton per tahun mulai dikirim 2022-2034 dan bisa ditingkatkan menjadi 1,1 juta ton per tahun pada 2024-2038. 

Terakhir, perseroan memiliki kesepakatan (head of agreement/HoA) dengan ExxonMobil untuk pasokan sebanyak 1 juta ton per tahun selama 20 tahun mulai 2025.

Pembelian dan penjualan LNG di pasar internasional ini sejalan dengan kebijakan Pertamina untuk menjadi energy supplier yang dapat menjamin ketahanan pasokan dan memitigasi resiko. Hal ini bukan berarti perseroan akan murni menjalankan fungsi sebagai perusahaan dagang (trading arm). 

“Tetapi kami harus ada trading arm atau portfolio player untuk security of supply atau efficiency of supply,” tegas dia.

Membangun Infrastruktur 

Meski tidak menambah impor, Didik menuturkan pihaknya akan tetap membangun fasilitas regasifikasi LNG. 

“Ada beberapa regasifikasi, seperti di Cilacap, Jawa Timur dan Jawa Timur. Tetapi [pembangunannya] tergantung dari perkembangan

ekonomi,” kata dia. 

Senior Expert Gas and Power Wood Mackenzie Edi Saputra mengungkapkan, berdasarkan kajian lembaganya, Indonesia akan membutuhkan impor gas pada 2020 dan 2025. Sehingga, Indonesia belum perlu kontrak impor LNG jangka panjang. Meski demikian, Indonesia perlu membangun fasilitas regasifikasi.

Pembangunan regasifikasi harus dilakukan mengingat kebutuhan LNG terus membesar, yakni dari saat ini 2,8 juta ton per tahun, menjadi 5 juta ton per tahun pada 2020, dan mencapai 15 juta ton per tahun pada 2030. 

“Dengan pertumbuhan LNG demand tentunya dibutuhkan infrastruktur regasifikasi yang baru. Kalau tidak, tidak bisa memenuhi

demand,” jelasnya.

Investor Daily,  Page-9, Friday, July 14, 2017

Pertamina Can not Complete This Year

Acquisition of oil and gas blocks

PT Pertamina has not been able to complete the acquisition of several oil and gas blocks abroad this year, such as oil and gas blocks in Russia and Iran. Upstream Director of Pertamina Syamsu Alam said the completion of acquisition activities can not be achieved because there are still stages to be passed. Pertamina has been eyeing several oil and gas blocks overseas.

He also denied the absence of additional new blocks abroad because of the financial problems of the company. The plan to acquire oil and gas blocks in Russia by Pertamina is still under commercial discussion. Meanwhile, oil and gas blocks in Iran are still discussing the form of cooperation contracts that will be applied as the country has just started to open investment opportunities for foreign investors.

As part of a joint agreement with Rosneft, the Russian oil and gas company in the Tuban refinery project, Pertamina is entitled to evaluate Rosneft's two oil and gas fields in Russia. Based on his official statement, in a memorandum of understanding, Pertamina can control a 20% participation stake in The Northern Tip of Chayvo Field and up to 37.5% at Russkoye Square in Russia.

From these activities, Pertamina targets to get oil 35,000 barrels per day (bpd) and oil and gas reserves 200 million barrels oil equivalent from Russia. Therefore, Pertamina will enter two oil and gas production blocks in Russia with share ownership of approximately 10% -15%.

For oil and gas blocks in Iran, the Iranian Government through the National Iranian Oil Company (NIOC) offered to Pertamina to submit proposals to the two oil fields in a memorandum of understanding signed last year.

To get the two fields, Pertamina competes with other companies such as Lukoil from Russia. Meanwhile, Ab-Teymour and Mansouri's reserves in Iran are estimated at 5 billion barrels. Both fields are in the production stage of 48,000 bpd for Ab-Teymour Square and 54,000 bpd for Mansouri Field.

"Just the process. Iran has not, Russia also has not seemed. Nothing has been achieved this year, "said Syamsu Alam, Wednesday (12/7).

Currently, the company gets production from operations in three countries, namely Iraq, Algeria, and Malaysia. Pertamina's oil production in Iraq comes from the West Qurna 1 Project with 178 active wells. In the block, ExxonMobil owns 32.69% participating interest (PI) and operates PetroChina with 32.69%, Shell of 19.62%, Pertamina International Exploration & Production (PIEP) owns 10% and South Oil Company (SOC) Iraq 5%.

IN INDONESIA

Akusisi Blok Migas

Pertamina Tak Bisa Tuntaskan Tahun lni

PT Pertamina belum mampu menuntaskan akuisisi beberapa blok minyak dan gas bumi di luar negeri pada tahun ini, seperti blok migas di Rusia dan Iran. Direktur Hulu Pertamina Syamsu Alam mengatakan, penuntasan kegiatan akuisisi tidak bisa tercapai karena masih terdapat tahapan yang harus dilalui. Pertamina telah mengincar beberapa blok migas di luar negeri.

Dia pun membantah belum adanya tambahan blok baru luar negeri karena masalah finansial perseroan. Rencana akuisisi blok migas di Rusia oleh Pertamina masih dalam tahap pembahasan komersial. Sementara itu, blok migas di Iran masih membahas bentuk kontrak kerja sama yang akan diterapkan karena negara itu baru saja mulai membuka kesempatan investasi bagi investor asing.

Sebagai bagian dari kesepakatan bersama dengan Rosneft, perusahaan migas Rusia dalam proyek pembangunan Kilang Tuban, Pertamina berhak melakukan evaluasi terhadap dua lapangan migas milik Rosneft di Rusia. Berdasarkan keterangan resminya, dalam nota kesepahaman, Pertamina bisa menguasai saham partisipasi sebesar 20% di Lapangan The Northern Tip of Chayvo dan hingga 37,5 % di Lapangan Russkoye di Rusia.

Dari kegiatan tersebut, Pertamina menargetkan bisa mendapat minyak 35.000 barel per hari (bph) dan cadangan migas 200 juta barel setara minyak dari Rusia. Untuk itu, Pertamina akan masuk di dua blok migas produksi di Rusia dengan kepemilikan saham masing-masing sekitar 10%-15%.

Untuk blok migas di Iran, Pemerintah Iran melalui National Iranian Oil Company (NIOC) menawarkan kepada Pertamina untuk memasukkan proposal terhadap dua lapangan minyak tersebut dalam nota kesepahaman yang diteken pada tahun lalu.

Untuk mendapatkan dua lapangan tersebut, Pertamina bersaing dengan perusahaan lain salah satunya Lukoil asal Rusia. Adapun, total cadangan Lapangan Ab-Teymour dan Mansouri di Iran diperkirakan mencapai 5 miliar barel. Kedua lapangan tersebut dalam tahap produksi yakni 48.000 bph untuk Lapangan Ab-Teymour dan 54.000 bph untuk Lapangan Mansouri.

“Hanya prosesnya saja. Iran belum, Rusia juga belum sepertinya. Tidak ada yang tercapai tahun ini,” kata Syamsu Alam, Rabu (12/7).

Saat ini, perseroan mendapatkan produksi dari operasi di tiga negara, yakni Irak, Aljazair, dan Malaysia. Produksi minyak Pertamina di Irak berasal dari Iapangan West Qurna 1 dengan 178 sumur aktif. Pada blok tersebut, ExxonMobil menguasai saham partisipasi (participating interest/PI) sebesar 32,69 % dan menjadi operator, PetroChina sebesar 32,69%, Shell sebesar 19,62 %, Pertamina Internasional Eksplorasi&Produksi (PIEP) menguasai 10%, dan South Oil Company (SOC) Iraq 5%.

Bisnis Indonesia, Page-30, Friday, July 14, 2017

Regasification Will Rise

The government needs to continue to build regasification facilities to utilize natural gas in the country. Indonesia is projected to need additional regasification facilities capacity of 25 million tons per year by 2035.

Senior Expert of Gas & Power Wood Mackenzie Edi Saputra said, to be able to utilize gas in the country, the government needs to increase the capacity of regasification facilities 25 million tons per year / mtpa by 2035.

The projection is based on the assumption of LNG demand for liquefied natural gas in Indonesia. He calls the capacity of the installed regasification facility currently only about 8 mtpa. On the other hand, LNG consumption is expected to continue to rise. This year, LNG consumption in Indonesia is 2.8 mtpa, up by 2020 to 8 mtpa and to 15 mtpa by 2030.

"It needs an additional 25 mtpa regasification facility by 2035," he said

According to him, the addition of gas infrastructure is absolutely necessary in order to meet the needs. The reason is that there is a tendency of growth of LNG consumption in domestic especially and electricity sector. He explained that there is a period of supply shortages in small volumes by 2020 and 2025.

He also estimates that Indonesia does not need to make long-term import contracts of LNG. There are two reasons for influencing LNG import decisions to supply domestic needs. First, the achievement of projects and utilities of gas-fired power plants.

According to him, although from 35,000 megawatts (MW), about 14,000 MW is a gas power plant (PLTG), gas needs can not be calculated linearly. Because the use of gas will be confronted with several large-scale projects for coal-fired power plant (PLTU) which is sourced from coal operating. The lower cost of PLTU operation makes the tendency of gas utilization in PLTG could be lower.

Second, the end of the LNG export contract. He considered, if the government withdraw all the allocation of exports to the country, LNG imports in the long term is not necessary. He considers, the ability of the domestic gas field to meet the needs of domestic gas.

"We estimate that 2020 and 2025 are small gaps, but they are not significant so long term imports are not needed until 2025," he said.

On the other hand, there is a tendency that LNG prices will rise. Therefore, despite pressure from consumers such as electricity and industry to get cheaper gas prices, the government should not set too low a gas sales price. Governments in addition need to ensure affordability, but also availability.

If the price limit is set too low, the development of gas field in the upstream will be disrupted because the offered price has not met the economic scale. If the price is too cheap, there will be no gas supply because gas field development is stopped.

"If it's too restrictive, the results certainly do not get that but instead supply scarcity there is no supply that will be able to meet it," he said.

DELAYED

PT Pertamina LNG VP, Didik Sasongko, said that currently it will not increase LNG imports in the near future. He mentioned that currently, it is necessary to see the economic growth and domestic gas demand first.

"Let's go first, look at the economy and the necessities."

He assumes that when a 14 gigawatt (GW) power plant is built in 2019, a 1,100 million cubic feet per day (MMscfd) or LNG gas supply of about 8 million tonnes is needed for fuel. Behind the uncertainty of the development of the domestic gas field, it has secured supplies from abroad.

Pertamina has signed several LNG supply agreements from abroad. First, Total long term diligence with Pertamina for LNG supply of 0.4 to 1 million tonnes per year starting in 2020 and lasting for 15 years. The supply comes from the Corpus Christi Project, USA. Instead, Total will supply LNG to Pertamina with the same volune of 0.4-1 million tonnes per year.

Second, Pertamina has signed a Gas Sales Agreement (GSA/PJBG) with Cheniere Energy Inc. subsidiary. Namely Corpus Christi Liquefaction Liability Company to supply 0.76 million tonnes per year of LNG from 2019 for 20 years.

Thirdly, Pertamina has also contracted with Cheniere Energy with the same volume, but it starts in 2018 with a duration of 20 years.

Fourth, Pertamina signed an ExxonMobil LNG agreement of 1 million tons per year for 20 years starting from 2025.

Fifth, from Woodside Singapore will be supplied about 0.6 million tons per year which can be increased to 1.1 million tons per year. The supply of 0.6 million tons per year starts shipping from 2022 to 2034 and can be increased to 1.1 million tons per year in 2024-2035

He said, if the supply is excessive, the company will seek other buyers who will buy the LNG.

"If we do not secure, how can FID [Final Investment Decision] is a power plant? Therefore we prepare imports.

IN INDONESIA

Regasifikasi Bakal Naik

Pemerintah perlu terus membangun fasilitas regasifikasi untuk memanfaatkan gas alam di Tanah Air. Indonesia diproyeksikan butuh tambahan kapasitas fasilitas regasifikasi 25 juta ton per tahun pada 2035.

Senior Expert Gas & Power Wood Mackenzie Edi Saputra mengatakan, untuk bisa memanfaatkan gas di Tanah Air, pemerintah perlu menambah kapasitas fasilitas regasifikasi 25 juta ton per tahun/mtpa pada 2035.

Proyeksi tersebut dibuat berdasarkan asumsi pertumbuhan permintaan gas alam cair/LNG di Indonesia.  Dia menyebut kapasitas fasilitas regasifikasi yang terpasang saat ini hanya sekitar 8 mtpa. Di sisi lain, konsumsi LNG diperkirakan terus naik. Pada tahun ini konsumsi LNG di Indonesia sebesar 2,8 mtpa, naik pada 2020 menjadi 8 mtpa dan menjadi 15 mtpa pada 2030.

“Butuh tambahan fasilitas regasifikasi 25 mtpa pada 2035,” ujarnya

Menurutnya, penambahan infrastruktur gas mutlak diperlukan agar bisa memenuhi kebutuhan. Pasalnya, terdapat kecenderungan pertumbuhan konsumsi LNG di dalam negeri khususnya dan sektor ketenagalistrikan. Dia menjelaskan, terdapat masa kekurangan pasokan dalam volume yang kecil pada 2020 dan 2025. 

Dia pun memperkirakan Indonesia belum perlu membuat kontrak impor LNG dalam jangka panjang. Ada dua alasan yang memengaruhi keputusan impor LNG untuk menyuplai kebutuhan di dalam negeri. Pertama, ketercapaian proyek dan utilitas pembangkit listrik berbahan bakar gas. 

Menurutnya, meskipun dari 35.000 megawatt (MW), sekitar 14.000 MW merupakan pembangkit listrik tenaga gas (PLTG), kebutuhan gas tidak bisa dihitung secara linier. Pasalnya, penggunaan gas nantinya akan dihadapkan dengan beberapa proyek skala besar untuk pembangkit listrik tenaga uap (PLTU) yang bersumber dari batu bara yang beroperasi. Lebih murahnya biaya operasi PLTU membuat kecenderungan utilisasi gas pada PLTG bisa saja lebih rendah.

Kedua, berkhirnya kontrak ekspor LNG. Dia menilai, bila pemerintah menarik semua alokasi ekspor ke dalam negeri, impor LNG dalam jangka panjang tidak perlu dilakukan. Dia menganggap, kemampuan lapangan gas domestik dapat mememuhi kebutuhan gas dalam negeri.

“Perkiraan kami itu 2020 dan 2025 ada small gap, tetapi tidak signifikan jadi belum diperlukan long term import sampai 2025,” katanya.

Di sisi lain, tendapat kecenderungan bahwa harga LNG akan naik. Oleh karena itu, meskipun terdapat tekanan dari konsumen seperti ketenagalistrikan dan industri agar mendapat harga gas yang lebih murah, pemerintah sebaiknya tidak menetapkan batas harga jual gas yang terlalu rendah. Pemerintah selain perlu menjamin keterjangkauan, tetapi juga ketersediaan.

Bila batas harga yang ditetapkan terlalu nendah, pengembangan lapangan gas di hulu akan terganggu karena harga yang ditawarkan belum memenuhi skala ekonomi. Kalau harganya terlalu murah, tidak akan ada tersedia pasokan gas karena pengembangan lapangan gas terhenti.

“Kalau itu terlalu restriktif, hasilnya tentu bukan mendapat yang tetapi justru supply scarcity tidak ada suplai yang akan bisa memenuhi itu,” katanya.

DITUNDA

VP LNG PT Pertamina, Didik Sasongko mengatakan, saat ini pihaknya belum akan menambah impor LNG dalam waktu dekat. Dia menyebut, saat ini perlu melihat pertumbuhan ekonomi dan kebutuhan gas dalam negeri lebih dulu. 

“Kita hold dulu, lihat ekonomi dan keperluan.“

Dia mengasumsikan bila pembangkit berkapasitas 14 gigawatt (GW) terbangun pada 2019, pasokan gas 1.100 juta kaki kubik per hari (MMscfd) atau LNG sekitar 8 juta ton dibutuhkan untuk bahan bakar. Di balik ketidakpastian pengembangan lapangan gas dalam negeri, pihaknya telah mengamankan pasokan dari luar negeri.

Pertamina telah meneken beberapa kesepakatan pasokan LNG dari luar negeri. Pertama, kespekatan jangka panjang Total dengan Pertamina untuk pasokan LNG sebesar 0,4 sampai 1 juta ton per tahun yang dimulai pada 2020 dan berlangsung selama 15 tahun.  Pasokan tersebut berasal dari Proyek Corpus Christi, Amerika Serikat. Sebagai gantinya, Total akan memasok LNG ke Pertamina dengan volune yang sama yakni 0,4-1 juta ton per tahun.

Kedua, Pertamina telah menandatangani perjanjian jual beli gas (PJBG) dengan anak usaha Cheniere Energy Inc. yakni Corpus Christi Iiquefaction Liability Company untuk memasok 0,76 juta ton per tahun LNG mulai 2019 selama 20 tahun.

Ketiga, Pertamina juga sudah berkontrak dengan Cheniere Energy dengan volume yang sama, tetapi dimulai pada 2018 dengan durasi 20 tahun.

Keempat, Pertamina meneken kesepakatan LNG dari ExxonMobil sebanyak 1 juta ton per tahun selama 20 tahun mulai 2025.

Kelima, dari Woodside Singapore akan dipasok sekitar 0,6 juta ton per tahun yang bisa ditingkatkan menjadi 1,1 juta ton per tahun. Pasokan 0,6 juta ton per tahun mulai dikirim 2022-2034 dan bisa ditingkatkan menjadi 1,1 juta ton per tahun pada 2024-2035

Dia menyebut, bila pasokan berlebih, perseroan akan mencari pembeli lain yang akan membeli LNG tersebut. 

“Kalau tidak kita secure, bagaimana bisa FID [keputusan akhir investasi] itu power plant? Oleh karena itu kita siapkan impor.

Bisnis Indonesia, Page-30, Friday, July 14, 2017

Discuss Continuing the Old Well

The discussion of the old well problem continues. Corresponding previous meeting between the Government of Bojonegoro, SKK Migas and PT Pertamina EP obtained an agreement that essentially management of old wells will be managed by the Regional Owned Enterprises (enterprises). As stated by Agus Supriyanto Head of Industry and Labor Office of Bojonegoro Regency. He said that in the near future the old well contract will be over and require certainty for the continued management of the old wells.

"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 Kabupaten Blora", explained Agus.

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

Meanwhile, Tony Ade Iriawan as Director Utalna PT Bangun Sarana Bojonegoro, Bojonegoro enterprises said that enterprises have prepared a draft that has been submitted to the Regent 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.

Salim Sa'id Chalid Operation & Production Director of PT Pertamina EP explained that the problems associated with old wells in the district of Bojonegoro, Board of Directors of PT Pertamina EP decided to pengeloIaan, Old Wells refers to the Minister of Energy and Mineral No. 1 of 2008 is in collaboration with cooperatives or enterprises .

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

Bojonegoro Old Well Field

While aitu, Tony Wicaksono Head of Department Work and Care Re SKK Oil and Gas Wells explained that the proposal submitted by PT Pertamina EP has been according to the direction of the Ministry of the Coordinating Political, Legal and Security and the Ministry of Energy to get back to the Energy and Mineral Resources Regulation No. 1 of 2008.

"With the proposal of PT Pertamina EP to return to the Regulation of the Minister of Energy and Mineral Resources No. 1 of 2008 with the involvement of local enterprises and Village Unit Cooperatives (KUD) then it is in accordance with our expectations at SKK Migas That we all start again from the beginning to the management of old wells and Expected the future to be better.

IN INDONESIA

Bahas Lanjutan Sumur Tua

Pembahasan permasalahan sumur tua dilanjutkan. Sesuai pertemuan sebelumnya antara Pemerintah Kabupaten Bojonegoro, SKK Migas dan PT Pertamina EP didapatkan kesepakatan yang intinya pengelolaan sumur tua akan dikelola oleh Badan Usaha Milik Daerah (BUMD). Demikian dikatakan Agus Supriyanto Kepala Dinas Perindustrian dan Tenaga Kerja Kabupaten Bojonegoro. Ia menyampaikan bahwa dalam waktu dekat kontrak sumur tua akan berakhir dan membutuhkan kepastian untuk kelanjutan pengelolaan sumur tua.

“Menindaklanjuti 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

Sementara itu, Tony Ade Iriawan selaku Direktur Utalna PT Bojonegoro Bangun Sarana, 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”, kata Tony.

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 pengeloIaan, Sumur Tua mengacu pada Peraturan Menteri ESDM No 1  Tahun 2008 yaitu bekerjasama dengan KUD atau BUMD.

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

Sementara aitu, Tony Wicaksono Kepala Departemen Kerja Ulang dan Perawatan Sumur SKK Migas menjelaskan bahwa usulan yang disampaikan oleh PT Pertamina EP sudah sesuai arahan dari Kementerian Kordinator Politik Hukum dan Keamanan dan Kementrian ESDM untuk kembali kepada Peraturan Menteri ESDM No 1 Tahun 2008. 

“Dengan adanya usulan dari PT Pertamina EP untuk kembali ke Peraturan Menteri ESDM No 1 Tahun 2008 dengan melibatkan BUMD dan Koperasi Unit Desa (KUD) maka itu sesuai dengan harapan kami di SKK Migas Bahwa kita semua memulai kembali dari awal untuk pengelolaan sumur tua ini dan diharapkan kedepannya menjadi lebih baik.

Surabaya Pagi, Page-10, Friday, July 14, 2017