Projected Oil Price Trimmed

Although heating up to US $ 50 per barrel, oil prices are still vulnerable to a correction in line with the projected increase in the production of the Organization of the Petroleum Exporting Countries (OPEC) in July 2017. Even analysts revised down the 2017 oil price projection target.

On Tuesday's trading at 17.05 GMT, the price of West Texas Intermediate (WTI) oil contracted in September 2017 rose 0.16% or 0.08 points to US $ 50.2S per barrel. The October 2017 Brent oil price fell 0.04% or -0.02 points to US $ 52.71 per barrel.

CMC Markets analyst Ric Spooner said crude prices are heating up in the near future due to the projected loss of weekly US inventories. Suevei Bloomberg said stockpiles of oil inventories ended Friday at 3.3 million barrels. Official data from U.S. data The Energy Information Administration (EIA) will be released Wednesday (2/8). Throughout June 2017, US stocks have fallen 26 million barrels. The recent decline in US inventory levels is quite constructive and the market responds, "he said as quoted by Bloomberg on Tuesday (1/8).

Nevertheless, now the price rally has moved into an area at risk of correction. Meanwhile, the volume of shale oil supply will be one key to the sustainability of price growth.

According to him, oil prices are also supported by OPEC's plan to reduce export volume. Saudi Arabia will reduce oil shipments abroad by 1 million barrels to about 6.6 million barrels starting in August 2017. Nigeria also reduced exports when it reached production capacity of 1.8 million barrels per day (bpd). In June 2017, the country pumped 1.75 million bpd of oil.

Spooner added that the market is also concerned with the agenda of the discovery of several OPEC and non-OPEC countries in the United Arab Emirates on 7-8 August 2017. Both sides will discuss the commitment to reduce production. OPEC and non-OPEC earlier agreed to cut production by 1.8 million bpd in January 2017-March 2018. However, the new supply-reduction volume has yet to reach the 100% target.

According to a Reuters survey involving a number of oil companies and consultants, OPEC production volume actually increased to 33 million bpd last month which was the highest level in 2017. This figure exceeded the target organizations that seek new supply to the level of 32.5 million bpd, in accordance with the agreement with Non-OPEC. 

     The largest increase in OPEC production comes from Libya that spur supply to exceed 1 million bpd, compared with the previous month at 840,000 bpd. Other members such as Iraq, the United Arab Emirates, Gabon and Ecuador are also pumping more oil.

REVISED DOWN

In another Reuters survey involving 33 analysts and economists, the average projected WTI oil price in 2017 was revised to US $ 0.08 per barrel and Brent headed for US $ 52.4S per barrel. This figure is down from the projection in June 2017 amounting to US $ 51.92 per barrel and U $ 53.96 per barrel respectively.

Interfu's senior energy analyst Global Gas Analytics analyst Abhishek Kimiar said the slump in analysts' projections was due to concerns about trimming OPEC and non-OPEC oil production cuts. When production peaked in July 2017, market attitudes were increasingly skeptical of the agreement.

Citing data from the International Energy Agency (IEA), OPEC production cuts in June 2017 fell to 78 percent from 95 percent the previous month. Countries that do the most cuts are Saudi Arabia, Angola, and Kuwait.

Negative sentiment also came from Ecuador withdrawing from production cuts. However, the impact on the market is not large enough. Thomson Reuters Oil Research and Forecast analyst Giorgios Beleris said negative sentiment from Ecuador was quickly tackled as Saudi Arabia pledged to cut exports. Other countries such as Nigeria and Kuwait are also ready to reduce the volume of overseas shipments of oil.

IN INDONESIA

Proyeksi Harga Minyak Dipangkas

Meski kembali memanas ke level US$ 50 per barel, harga minyak masih rentan koreksi seiring dengan proyeksi meningkatnya produksi Organization ot the Petroleum Exporting Countries (OPEC) pada Juli 2017. Bahkan kalangan analis merevisi turun target proyeksi harga minyak 2017.

Pada perdagangan Selasa (1/8) pukul 17.05 WIB, harga minyak West Texas Intermediate (WTI) kontrak September 2017 naik 0,16% atau 0,08 poin menuju US$50,2S per barel. Adapun harga minyak Brent kontrak Oktober 2017 turun 0.04% atau -0,02 poin menjadi US$52,71 per barel.

Analis CMC Markets Ric Spooner menyampaikan harga minyak mentah memanas dalam waktu dekat akibat proyeksi berkurangnya persediaan mingguan Amerika Serikat. Suevei Bloomberg mengungkapkan persediaan stok minyak yang berakhir Jumat (28/7) turun 3,3 juta barel. Data resmi dari data U.S. Energy Information Administration (EIA) akan dirilis Rabu (2/8).

     Sepanjang Juni 2017, stok AS sudah turun 26 juta barel. Tingkat penurunan persediaan AS akhir-akhir ini cukup konstruktif dan pasar merespons itu,” paparnya seperti dikutip dan Bloomberg, Selasa (1/8).

Namun demikian, kini reli harga sudah bergerak ke area yang berisiko mengalami koreksi. Adapun, volume pasokan minyak shale akan menjadi salah satu kunci keberlanjutan pertumbuhan harga.

Menurutnya, harga minyak juga ditopang rencana OPEC mengurangi volume ekspor. Arab Saudi akan mengurangi pengapalan minyak ke luar negeri sebesar 1 juta barel menjadi sekitar 6.6 juta barel mulai Agustus 2017. Nigeria turut mengurangi ekspor ketika sudah mencapai kapasitas produksi sebesar 1,8 juta barel per hari (bph). Adapun pada Juni 2017, negara tersebut memompa minyak sejumlah 1,75 juta bph.

Spooner menambahkan, pasar juga memperhatikan agenda penemuan beberapa negara OPEC dan non-OPEC di Uni Emirat Arab pada 7-8 Agustus 2017. Kedua pihak akan membahas komitmen untuk mengurangi produksi. OPEC dan non-OPEC sebelumnya sepakat memangkas produksi sebesar 1,8 juta bph pada Januari 2017-Maret 2018. Namun, volume pengurangan suplai baru belum mencapai target 100%.

Menurut survei Reuters yang melibatkan sejumlah perusahaan minyak dan konsultan, volume produksi OPEC justru meningkat menjadi 33 juta bph pada bulan lalu yang menjadi level tertinggi sepanjang 2017. Angka ini melampaui target organisasi yang mengupayakan suplai baru ke level 32,5 juta bph, sesuai kesepakatan dengan non-OPEC. 

     Kenaikan produksi OPEC paling besar berasal dari Libya yang memacu suplai hingga melampaui 1 juta bph, dibandingkan dengan bulan sebelumnya di kisaran 840.000 bph. Anggota lain seperti Irak, Uni Emirat Arab, Gabon, dan Ekuador juga memompa lebih banyak minyak.

REVISI TURUN

Dalam survei Reuters lainnya yang melibatkan 33 analis dan ekonom, proyeksi rerata harga minyak WTI pada 2017 direvisi menjadi US$ 0,08 per barel dan Brent menuju US$ 52,4S per barel. Angka ini turun dari proyeksi pada Juni 2017 masing-masing senilai US$ 51,92 per barel dan U$ 53,96 per barel.

Senior energy analyst Interfax Energy’s Global Gas Analytics Abhishek Kimiar menyampaikan, merosotnya proyeksi analis disebabkan kekhawatiran menganai kepatuhan pemangkasan produksi minyak OPEC dan non-OPEC. Ketika produksi memuncak pada Juli 2017, sikap pasar semakin skeptis dengan perjanjian tersebut.

Mengutip data International Energy Agency (IEA), kepatuhan pemangkasan produksi OPEC pada Juni 2017 turun menjadi 78% dari bulan sebelumnya sebesar 95%. Negara yang melakukan pemangkasan paling banyak ialah Arab Saudi, Angola, dan Kuwait.

Sentimen negatif juga datang dari Ekuador yang menarik diri dari perjanjian pemangkasan produksi. Namun, dampaknya terhadap pasar tidak cukup besar. Analis Thomson Reuters Oil Research and Forecast Giorgios Beleris mengatakan sentimen negatif dari Ekuador cepat tertanggulangi karena Arab Saudi berjanji memangkas ekspor. Negara lain seperti Nigeria dan Kuwait juga siap mengurangi volume pengapalan minyak ke luar negeri. 

Bisnis Indonesia, Page-16, Wednesday, August 2, 2017

ExxonMobil Must Review Production Increase

ExxonMobil said it still needs review before ensuring it can raise Cepu Block oil production to 300 thousand barrels per day (bpd).

During his trip to the United States, Energy and Mineral Resources Minister Ignatius Jonan was in the company of Senior Vice President of Exxon Mobil Corporation Mark W Albers. In the meeting it was said that Banyu Urip Field production, Cepu Block can be boosted to 300 thousand bpd from the current 200 thousand bpd. ExxonMobil responded positively by conducting a further field development potential.

"In terms of production of 300,000 bpd, we will evaluate the capacity of CPF (central processing facility) and existing wells," said Vice President of Public and Government Affairs of ExxonMobil Cepu Limited Erwin Maryoto. If realized, this is the second time the production of Cepu Block is ramped up.

As is known, initially Cepu Block is only targeted to produce oil of 185 thousand bpd. However, then at the insistence of Commission VII of the House of Representatives after considering the proposal of ExxonMobil, the production of this block was requested to be raised to an average of 200 thousand bpd.

But this increased production requires approval of a revised environmental impact assessment from the Ministry of Environment and Forestry. According to Erwin, his party has obtained the environmental permit and allowed to produce oil up to 220 thousand bpd higher than the target on the work plan and budget (WP & B) of 200 thousand bpd.

"Permission is up to 220 thousand bpd. Currently we are producing in the range of more than 200 thousand bpd, "he said.

Increased production to 200 thousand bpd does not require the addition of a significant tool. Because the production capacity of existing facilities can still be adjusted. Similarly, the floating production, storage, and ofiloading (FPSO) capacity of Rimang Crow, which is designed with the assumed peak of Cepu Block production of 185,000 bpd, is anticipated by oil pickup using larger tankers.

The Banyu Urip field is expected to generate 450 million barrels of oil during the project's operational life. In the last few decades, Banyu Urip Field is the largest oil project in Indonesia. Currently, the composition of shares in Cepu Block is ExxonMobil Cepu Limited as the operator owns 45% shares, PT Pertamina EP Cepu 45%, and four Regional Owned Enterprises 10%. The four BUMDs are PT Blora Patragas Hulu, PT Petrogas Jatim Utama Cendana, PT Asri Darma Sejahtera and PT Sarana Patra Hulu Cepu. Minister Jonan hopes that increased production can have a positive impact on Indonesia.

"With the increase in production, I hope to be able to give a double effect to the surrounding area through the development of national and local companies, opening up jobs to community development," he said.

In addition to discussing Cepu Block, Jonan also expects ExxonMobil to make the downstream sector as a new investment land in Indonesia. Some of the offered investments include opening a Public Filling Station (SPBU) or aromatic development in Indonesia. Currently, PT ExxonMobil Lubricants Indonesia (PT ELMI) representing ExxonMobil company has developed downstream and petrochemical sectors in Indonesia.

Encourage Investment

Not only ExxonMobil, Jonan also met with other oil and gas companies, ChevronConocoPhilips, Schlumberger, and Baker Hughes GE Company. Jonan asked the entire company to boost its investment in Indonesia. While visiting Chevron, Jonan was greeted by President Chevron North America Exploration and Production Jeff Shellebarger and President of Chevron Environmental Management Company Mary Boroughs.

The meeting discussed the development of deep-sea gas in Kutai Basin, East Kalimantan, known as Indonesia Deepwater Development (IDD). IDD's first project, Bangka Field, has been in production since August 2016. Meanwhile, Gendaho-Gehem Field is targeted to start production in 2022. The discussions are held together.

"One of them is to discuss the development of IDD and the cooperation of the use of facilities (Float Production Unit / FPU) Jangrik with Eni for gas from Gendalo-Gehem," he said. Jonan wants the IDD Project to begin immediately.

When meeting ConocoPhilips CEO Ryan Lance, Jonan discusses the continued management of the South Jambi B Block, whose contract expires in 2020. ConocoPhillips is requested to submit a block management proposal with the option of partnering with PT Pertamina or other companies. ConocoPhillips stated immediately submit a proposal after conducting internal discussions including discussing economic issues.

In a meeting with Schlumberger Venture Fund Senior Vice President of Schlumberger Limited Imran Kizilbash, Jonan obtained two bids to increase oil and gas exploration and production activities in Indonesia.

First, through multiclient surveys in areas approved by the Government especially in the eastern offshore and upstream oil and gas management data management. Schlumberger also has an investment program in oil and gas field development as has been done in Latin America amounting to US $ 4.6 billion.

Jonan also met President & CEO Baker Hughes, Lorenzo Simonelli. At the meeting, Baker Hughes offered technology for upstream oil and gas activities, among others, reduction of cost drilling by utilizing digital technology through IntelliStream solution, as well as some enhanced oil recovery (EOR) technology in several oil and gas fields in Indonesia.

In addition, GE also offers barge power plant technology with comprehensive solutions that include gas infrastructure for islands with low electrification ratios and participation in geothermal development in Indonesia.

IN INDONESIA

ExxonMobil Harus Kaji Peningkatan Produksi

ExxonMobil menyatakan masih perlu kajian sebelum memastikan dapat menaikkan produksi minyak Blok Cepu sampai 300 ribu barel per hari (bph).

Dalam lawatannya ke Amerika Serikat, Menteri Energi dan Sumber Daya Mineral (ESDM) Ignasius Jonan menemuni Senior Vice President Exxon Mobil Corporation Mark W Albers. Dalam pertemuan itu disampaikan bahwa produksi Lapangan Banyu Urip, Blok Cepu dapat digenjot menjadi 300 ribu bph dari saat ini 200 ribu bph. Pihak ExxonMobil merespon positif dengan segera melakukan kajian potensi pengembangan lapangan lebih lanjut.

“Terkait produksi 300 ribu bph, kami akan evaluasi kapasitas CPF (central processing facility) dan sumur-sumur yang ada dahulu,” kata Vice President Public and Government Affairs ExxonMobil Cepu Limited Erwin Maryoto. Jika terealisasi, maka ini kali kedua produksi Blok Cepu digenjot produksinya. 

Seperti diketahui, awalnya Blok Cepu hanya ditargetkan memproduksi minyak sebesar 185 ribu bph. Namun, kemudian atas desakan Komisi VII DPR RI setelah mempertimbangkan usulan ExxonMobil, produksi blok ini diminta dinaikkan menjadi rata-rata 200 ribu bph.

Tetapi peningkatan produksi ini membutuhkan persetujuan revisi analisis dampak lingkungan dari Kementerian Lingkungan Hidup dan Kehutanan. Menurut Erwin, pihaknya telah memperoleh izin lingkungan tersebut dan diperbolehkan memproduksi minyak hingga maksimal 220 ribu bph lebih tinggi dari target pada rencana keria dan anggaran (work plan and budget/WP&B) 200 ribu bph.

“Izinnya sampai dengan 220 ribu bph. Sekarang ini kami produksi di kisaran lebih dari 200 ribu bph," tutur dia. 

Peningkatan produksi sampai 200 ribu bph ini tidak membutuhkan penambahan alat yang cukup signifikan. Pasalnya, kapasitas produksi fasilitas yang ada masih dapat disesuaikan. Demikian juga kapasitas fasilitas produksi, penampungan, dan bongkar muat terapung (floating production, storage, and ofiloading/FPSO) Gagak Rimang yang didesain dengan asumsi puncak produksi Blok Cepu 185 ribu bph,sudah diantisipasi dengan pengambilan minyak menggunakan kapal tanker yang lebih besar.

Lapangan Banyu Urip diharapkan dapat menghasilkan 450 juta barel minyak selama masa operasi proyek. Dalam beberapa dekade terakhir, Lapangan Banyu Urip merupakan proyek minyak terbesar di Indonesia. Saat ini, komposisi saham di Blok Cepu adalah ExxonMobil Cepu Limited sebagai operator memiliki saham 45%, PT Pertamina EP Cepu 45%, serta empat Badan Usaha Milik Daerah 10%. Keempat BUMD itu yaitu PT Blora Patragas Hulu, PT Petrogas Jatim Utama Cendana, PT Asri Darma Sejahtera, dan PT Sarana Patra Hulu Cepu. Menteri Jonan berharap peningkatan produksi dapat memberi dampak positif bagi Indonesia. 

“Dengan peningkatan produksi, saya harap mampu memberikan efek ganda bagi daerah sekitar melalui pengembangan perusahaan nasional dan lokal, membuka lapangan pekerjaan hingga pengembangan masyarakat,” ujarnya.

Selain membahas Blok Cepu, Jonan juga mengharapkan ExxonMobil bisa menjadikan sektor hilir sebagai lahan investasi baru di Indonesia. Beberapa investasi yang ditawarkan seperti membuka Stasiun Pengisian Bahan Bakar Umum (SPBU) atau pengembangan aromatik di Indonesia. Saat ini, PT ExxonMobil Lubricants Indonesia (PT ELMI) mewakili perusahaan ExxonMobil telah mengembangkan sektor hilir dan petrokimia di Indonesia. 

Dorong Investasi

Tidak hanya ExxonMobil, Jonan juga menemui petinggi perusahaan migas lain, yakni ChevronConocoPhilips, Schlumberger, dan Baker Hughes GE Company. Jonan meminta seluruh perusahaan ini untuk mendongkrak investasinya di Indonesia. Ketika berkunjung ke Chevron, Jonan disambut President Chevron North America Exploration and Production Jeff Shellebarger dan President Chevron Environmental Management Company Mary Boroughs. 

Pertemuan ini membahas pengembangan gas laut dalam di Kutai Basin, Kalimantan Timur yang dikenal dengan Indonesia Deepwater Development (IDD). Proyek pertama IDD, yakni Lapangan Bangka, telah berproduksi sejak Agustus 2016. Sementara itu, Lapangan Gendaho-Gehem ditargetkan akan mulai produksi pada 2022. Diskusi dilakukan bersama.

“Salah satunya adalah membahas terkait perkembangan IDD dan kerjasama penggunaan fasilitas (Floating Production Unit/FPU) Jangrik dengan Eni untuk gas dari Gendalo-Gehem,” kata dia.  Jonan menginginkan Proyek IDD segera dimulai.

Saat bertemu CEO ConocoPhilips Ryan Lance, Jonan membahas kelanjutan pengelolaan Blok South Jambi B yang kontraknya akan habis pada tahun 2020. ConocoPhillips diminta segera mengajukan proposal pengelolaan blok tersebut dengan opsi berpartner dengan PT Pertamina atau perusahaan lainnya. ConocoPhillips menyatakan segera menyampaikan proposal setelah melakukan pembahasan internal termasuk membahas masalah keekonomian.

Dalam pertemuan dengan Senior Vice President Schlumberger Venture Fund Schlumberger Limited Imran Kizilbash, Jonan memperoleh dua tawaran dalam meningkatkan kegiatan eksplorasi dan produksi migas di Indonesia. 

Pertama, melalui multiclient survey di daerah yang disetujui oleh Pemerintah khususnya di daerah timur offshore dan manajemen pengelolaan data hulu migas. Kemudian, Schlumberger juga mempunyai program investasi dalam pengembangan lapangan migas seperti yang telah dilakukan di Amerika Latin sebesar US$ 4,6 miliar.

Jonan juga menemui President & CEO Baker Hughes, Lorenzo Simonelli. Pada pertemuan tersebut, Baker Hughes menawarkan teknologi untuk kegiatan hulu migas antara lain pengurangan cost drilling dengan memanfatkan teknologi digital melalui solusi IntelliStream, serta beberapa teknologi enhanced oil recovery (EOR) pada beberapa lapangan migas di Indonesia. 

Di samping itu, GE juga menawarkan teknologi barge power plant dengan solusi komprehensif yang meliputi infrastruktur gas untuk pulau-pulau dengan rasio elektrifikasi yang masih rendah dan keikutsertaan dalam pengembangan panas bumi di Indonesia.

Investor Daily, Page-48, Monday, August 1, 2017

Exxon Obtains Government Permit

The government gave the green light to ExxonMobil Indonesia to raise its minnyak production from Banyu Urip Field, Cepu Block to 200,000 barrels per day.

Currently, crude oil production from oil and gas field located in Bojonegoro, East Java has reached 185,000 barrels per day (bpd). Meanwhile, based on work plans and budget (work pic & budget / WP & B) 2017, oil production from Banyu Urip is targeted at 200,000 bpd.

Vice President of Public and Government Affairs of ExxonMobil Indonesia Erwin Maryoto said it has received environmental permit (Amdal) from the Ministry of Environment and Forestry (KLHK) to increase production of Banyu Urip field. ExxonMobil has submitted an Environmental Impact Assessment (EIA) since March 2017.

According to him, with the release of the Environmental Impact Analysis, oil production from Banyu Urip can be raised up to 220,000 bpd. Based on data from Special Unit for Upstream Oil and Gas Business (SKK Migas), Banyu Urip Field oil production in Cepu Block contributes 25% of national oil production of 808,000 bph with the realization of 199,800 bph at the end of June 2017.

"The Environment and Forestry Department has issued an environmental license to produce up to 220,000 bpd," he said

Meanwhile, with the option of adding oil production up to 300,000 bph, there needs to be an evaluation of the capacity of the central processing facility (CPF) and the potential for the development of other wells in Cepu Block.

ExxonMobil does not need to increase its investment to raise oil production in Banyu Urip to 200,000 bpd, but it only adds an operating cost of about US $ 2 million.

The addition of previous production is proposed by ExxonMobil Cepu Limited due to the potential increase of reserves that can be lifted or recoverable reserve from 450 million barrels to 725 million barrels. With such reserves, the production volume is 200,000 bpd can last for 3-4 years. In the Cepu block, ExxonMobil controls 20.5% of participating interest, Ampolex 24.5%, Pertamina EP Cepu 45%, and several regional owned enterprises 10%.

DEVELOPMENT

Under the plan, Exxon will conduct geological and geophysical studies in phase 1 development, proposed drilling of delineation wells and exploration for the structure of Alas Tua West and Alas Tua East. In the first phase of development in 2019-2022, the development plan of Cendana Field and Alas Tua East Field is targeted can be delivered by 2018. In addition, exploration drilling of Giyanti and Pilang structures and Enhanced Oil Recovery (EOR) Banyu Urip field are also conducted.

In the development phase III (2022-2035), ExxonMobil will drill in Kalisari field, preparation of development plans for four structures (Giyanti, Kalisari, East Alas, and Pilang) as well as EOR Banyu Urip trials. Earlier, during his visit to the United States, Energy and Mineral Resources Minister Ignatius Jonan met Senior Vice President (SVP) ExxonMobil Corporation's Mark W Albers at Exxon Mobil Campus and Technology Center, Texas.

He expects ExxonMobil through ExxonMobil Cepu Limited to operate the Cepu Block to increase oil production. Banyu Urip oil production is expected to rise to 300,000 bpd.

The purpose of adding production says Jonan to add multiplier effects for the region through the development of national and local companies. Thus, he mentioned new open employment and community development could increase.

Meanwhile, Deputy Minister of Energy and Mineral Resources Arcandra Tahar said that the plan to increase oil production and Cepu Block up to 300,000 bph needs to be discussed further.

According to him, there is a potential decrease in oil production faster with the addition of production because of the character of the structure entered in the type of kabonat. If oil production is boosted to 300,000 bpd, production periods are expected to be shorter than production at 200,000 bpd.

Another consideration, he said, is the additional investment that may have to be done because oil production at the 300,000 level exceeds CPE capacity.

Separately, Upstream Director of Pertamina Syamsu Alam said that the price agreement with PT Perusahaan Listrik Negara related to gas supply from Tiung Biru-Tiung blast, Cepu Block has been reached. However, it is reluctant to mention how much the price and volume of gas agreed by PT Pertamina and PLN in a meeting held at the Ministry of Energy and Mineral Resources.

IN INDONESIA

Exxon Memperoleh Ijin Pemerintah

Pemerintah memberikan lampu hijau kepada ExxonMobil Indonesia untuk menaikkan produksi minnyak dari Lapangan Banyu Urip, Blok Cepu menjadi 200.000 barel per Hari. 

Saat ini, produksi minyak mentah dari lapangan migas yang berlokasi di Bojonegoro, Jawa Timur itu sudah mencapai 185.000 barel per hari (bph). Sementara ilu, berdasarkan rencana kerja dan anggaran (work pIan & budget/WP&B) 2017, produksi minyak dari Banyu Urip ditargetkan 200.000 bph.

Vice President Public and Goverment Affairs ExxonMobil lndonesia Erwin Maryoto mengatakan pihaknya telah mendapat izin lingkungan (amdal) dari Kementerian Lingkungan Hidup dan Kehutanan (KLHK) untuk menambah produksi lapangan Banyu Urip. ExxonMobil telah mengajukan Analisa Dampak Lingkungan (Amdal) sejak Maret 2017.

Menurutnya, dengan keluarnya Analisa Dampak Lingkungan, produksi minyak dari Banyu Urip bisa dinaikkan hingga 220.000 bph. Berdasarkan data Satuan Kerja Khusus Pelaksana Kegiatan Usaha Hulu Minyak dan Gas Bumi (SKK Migas), produksi minyak Lapangan Banyu Urip di Blok Cepu berkontribusi sebesar 25% dari produksi minyak nasional sebanyak 808.000 bph dengan realisasi 199.800 bph pada akhir Juni 2017.

“Kememerian Lingkungan Hidup dan Kehutanan telah mengeluarkan izin lingkungan untuk memproduksi sampai dengan 220.000 bph," ujarnya 

Sementara itu, terkait dengan opsi penambahan produksi minyak hingga 300.000 bph, perlu ada evaluasi terhadap kapasitas fasilitas pemrosesan pusat (central processing facility/CPF) dan potensi pengembangan sumur lainnya di Blok Cepu.

ExxonMobil tidak perlu menambah investasi untuk menaikkan produksi minyak di Banyu Urip hingga 200.000 bph, tetapi hanya menambah biaya operasi sekitar US$2 juta.

Penambahan produksi sebelumnya diusulkan ExxonMobil Cepu Limited karena naiknya potensi cadangan yang bisa diangkat atau recoverable reserve dari semula 450 juta barel menjadi 725 juta barel. Dengan cadangan tersebut, volume produksi 200.000 bph bisa bertahan selama 3-4 tahun. Di Blok Cepu, ExxonMobil menguasai saham partisipasi sebesar 20,5%, Ampolex 24,5%, Pertamina EP Cepu 45%, dan beberapa badan usaha milik daerah 10%.

PENGEMBANGAN

Berdasarkan rencana, Exxon akan melakukan kajian geologi dan geofisika dalam pengembangan tahap l, usulan pengeboran sumur delineation (pengeboran untuk mencari batas sumber migas) dan eksplorasi untuk stuktur Alas Tua West dan Alas Tua East.  Pada pengembangan tahap I pada 2019-2022, rencana pengembangan Lapangan Cendana dan Lapangan Alas Tua East ditargetkan

bisa disampaikan pada 2018. Selain itu, pengeboran eksplorasi struktur Giyanti dan Pilang serta kegiatan pengurasan lanjutan (enhanced oil recovery/EOR) lapangan Banyu Urip juga dilakukan.

Pada pengembangan tahap III (2022-2035), ExxonMobil akan mengebor di lapangan Kalisari, penyusunan rencana pengembangan untuk empat struktur (Giyanti, Kalisari, Alas Tua East, dan Pilang) juga uji coba EOR Banyu Urip. Sebelumnya, dalam kunjungannya ke Amerika Serikat, Menteri Energi dan Sumber Daya Mineral (ESDM) Ignasius Jonan bertemu Senior Vice President (SVP) ExxonMobil Corporation Mark W Albers di Exxon Mobil Campus and Technology Center, Texas.

Dia mengharapkan agar ExxonMobil melalui ExxonMobil Cepu Limited yang mengoperasikan Blok Cepu mampu meningkatkan produksi minyak. Produksi minyak Banyu Urip diharapkan agar naik menjadi 300.000 bph.

Tujuan penambahan produksi ujar Jonan untuk menambah efek pengganda bagi daerah melalui pengembangan perusahaan nasional dan lokal. Dengan demikian, dia menyebut lapangan kerja baru terbuka dan pengembangan masyarakat bisa meningkat.

Sementara itu, Wakil Menteri ESDM Arcandra Tahar mengatakan bahwa rencana penambahan produksi minyak dan Blok Cepu hingga 300.000 bph perlu dibicarakan lebih lanjut.

Menurutnya, terdapat potensi penurunan produksi minyak yang lebih cepat dengan penambahan produksi itu karena karakter struktur yang masuk dalam jenis kabonat. Jika produksi minyak digenjot hingga 300.000 bph, masa produksi di level tersebut diperkirakan lebih pendek dibandingkan dengan produksi di tingkat 200.000 bph.

Pertimbangan lainnya, katanya, penambahan investasi yang mungkin harus dilakukan karena produksi minyak di level 300.000 melampaui kapasitas CPE.

Secara terpisah, Direktur Hulu Pertamina Syamsu Alam mengatakan bahwa kesepakatan harga dengan PT Perusahaan Listrik Negara terkait dengan pasokan gas dari jambaran-Tiung Biru, Blok Cepu telah dicapai. Namun, pihaknya enggan menyebut berapa harga dan volume gas yang disepakati PT Pertamina dan PLN dalam rapat yang digelar di Kementerian ESDM.

Bisnis Indonesia, Page-30, Tuesday, August 1, 2017

Gas Flot Auction was postponed for Quarter III / 2017

UPSTREAM OIL AND GAS

The government plans to auction off the potential of flare gas or flare gas in the third quarter of 2017 withdrawal and initial target in the first half of 2017 as the Special Unit for Upstream Oil and Gas Business Executors is still preparing the gas supply potential mechanism.

Head of Oil and Gas Commercialization Division of SKK Migas Waras Budi Santosa said that the company is still improving the tender mechanism and the supply of flare gas. In accordance with Regulation of Minister of Energy and Mineral Resources No. 32/2017 on Utilization and Selling Prices of Gas Flares In Upstream Oil and Gas Business Activities, gas flare auctions will be established further through the Decree of the Head of SKK Migas.

According to him, SKK Migas will stipulate the provision of gas flotation bid mechanism in the second or third week of August 2017. Then the auction will be conducted simultaneously with the refinement of the potential data of flaring gas that can still be processed.

"September-October, we are still refining mechanisms and rules for bidding," he said

He mentioned that the potential supply of gas flare demanded by gas traders as well as small scale industries. Referring to the regulation, the flare gas is used for power generation, gas utilization through pipeline for industry or household, compressed gas / CNG, liquid oil / LPG, dimethyl ether, or other purposes according to its composition.

Currently, SKK Migas has just identified 10 gas fields that can be utilized by its flare gas. According to him, the 10 fields have not yet described the full potential of flare gas in Indonesia. Therefore, it continues to make improvements to the gas potential data before the auction is done. In the interim data, there are indications of potential flare gas with an estimated volume of 19.369 million standard cubic feet per day (MMscfd) of 10 such fields located in Riau, South Sumatra, West Java and Java.

The 10 fields are Zelda, Java Sea (CNOOC); Grissik and Suban, South Sumatra (ConocoPhiIlips); Rantau Bais and South Balam, Riau (Chevron Pacific Indonesia); Matra and Kaji, South Sumatra (Medco E & P Indonesia); Subang and Jatibarang (Pertamina EP Asset 3).

"The possibility of taking is a gas trader or a small scale industry," he said.

Meanwhile, the price of flare gas in accordance with Article 12 of Regulation of Minister of Energy and Mineral Resources Ngo. 32/2017 will be proposed SKK Migas based on the results of the offer. Furthermore, the ESDM Minister will fix the price and allocation of the gas. For the selling price of this flare gas, no escalation, take or pay, and Stand By Letter of Credit (SBLC) are required. In addition, there is no limit on the selling price of flare gas.

RESTRICTED

The government has set a price limit for government agencies, namely US $ 0.35 per million British thermal unit (MMBtu). On the other hand, in the transitional provisions, since no price agreement has been reached, the selling price of flared gas should not exceed US $ 3.67 per MMBtu.

Earlier, Director General of Oil and Gas at the Ministry of Energy and Mineral Resources, IGN Wiratmaja Puja, said that the new selling price will be determined through auction process. For an existing contract, he mentions that nothing will change with the new provisions.

In the appendix, we include a price formula that considers the hydrogen sulfide gas (H2S) and carbon dioxide (CO2) contents. The price correction range with H2S content of less than or equal to 1,400 ppmv ranging from US $ 0.1 to US $ 3.32 for more than 1,400 ppmv.

Meanwhile, the correction factor is also affected by the combination of CO2, ie less than 15% mol to more than 30% mol.

"If it is new, the price is set through an offer. If the existing one, the contract remains valid. Formula for the transition, "he said.

IN INDONESIA

Lelang Gas Suar Diundur Kuartal III/2017

Pemerintah berencana melelang potensi gas suar atau flare gas parla kuartal III/2017 mundur dan target awal pada semester I/2017 karena Satuan Kerja Khusus Pelaksana Kegiatan Usaha Hulu Minyak dan Gas Bumi masih menyiapkan mekanisme penawaran potensi gas.

Kepala Divisi Komersialisasi Minyak dan Gas Bumi SKK Migas Waras Budi Santosa mengatakan, saat ini pihaknya masih melakukan penyempurnaan mekanisme lelang dan penawaran gas suar. Sesuai dengan Peraturan Menteri ESDM No.1 32/2017 tentang Pemanfaatan dan Harga jual Gas Suar Pada Kegiatan Usaha Hulu Minyak dan Gas Bumi, lelang gas suar akan ditetapkan Iebih lanjut melalui Keputusan Kepala SKK Migas.

Menurutnya, SKK Migas akan menetapkan ketentuan mekanisme penawaran gas suar pada pekan kedua atau ketiga Agustus 2017. Kemudian lelang akan dilakukan bersamaan dengan penyempurnaan data potensi gas suar yang masih bisa diolah.

“September-Oktober, kami masih menyempurnakan mekanisme dan aturan untuk penawaran,” ujarnya 

Dia menyebut bahwa penawaran potensi gas suar diminati pedagang gas juga industri skala kecil. Mengacu pada aturan itu, gas suar dipakai untuk keperluan pembangkit listrik, pemanfaatan gas melalui pipa untuk industri atau rumah tangga, gas terkompresi/ CNG , gas minyak cair /LPG, dimetil eter, atau keperluan lainnya sesuai dengan komposisinya.

Saat ini, SKK Migas baru saja mengidentifikasi 10 lapangan gas yang bisa dimanfaatkan gas suarnya. Menurutnya, 10 lapangan itu belum menggambarkan seluruh potensi gas suar di Indonesia. Oleh karena itu, pihaknya terus melakukan penyempurnaan data potensi gas sebelum lelang dilakukan. Dan data sementara, ada indikasi potensi gas suar dengan perkiraan volume sebesar 19,369 juta standar kaki kubik per hari (MMscfd) dari 10 lapangan tersebut yang berlokasi di Riau, Sumatra Selatan, Jawa Barat, dan laut Jawa.

10 Lapangan tersebut yakni Zelda, Laut Jawa (CNOOC); Grissik dan Suban, Sumatra Selatan (ConocoPhillips); Rantau Bais dan South Balam, Riau (Chevron Pacific Indonesia); Matra dan Kaji, Sumatra Selatan (Medco E&P Indonesia); Subang dan Jatibarang (Pertamina EP Asset 3).

“Kemungkinan besar yang ambil adalah trader gas atau bisa juga industri skala kecil,” katanya.

Sementara itu, harga gas suar sesuai dengan Pasal 12 Peraturan Menteri ESDM Ngo. 32/2017 akan diusulkan SKK Migas berdasarkan hasil penawaran. Selanjutnya, Menteri ESDM akan menetapkan harga dan alokasi gas tersebut. Untuk harga jual gas suar ini ditetapkan tidak diberlakukan eskalasi, take or pay, dan Stand By Letter of Credit (SBLC). Selain itu, tidak ada batasan harga jual gas suar.

DIBATASI

Pemerintah telah menetapkan batas harga jual untuk lembaga pemerintah, yakni US$0,35 per million British thermal unit (MMBtu). Di sisi lain, dalam ketentuan peralihan, karena belum dilakukan kesepakatan harga, harga jual gas suar tidak boleh lebih dari US$3,67 per MMBtu.

Sebelumnya, Direktur Jenderal Minyak dan Gas Bumi Kementerian ESDM IGN Wiratmaja Puja mengatakan, harga jual baru nantinya ditetapkan melalui proses lelang. Untuk kontrak yang sudah berjalan, dia menyebut bahwa tidak akan berubah dengan adanya ketentuan baru itu.

Pada bagian lampiran, disertakan pula formula harga yang mempertimbangkan kandungan gas hidrogen sulfida (H2S) dan karbondioksida (CO2). Rentang koreksi harga dengan kandungan H2S sebanyak kurang atau sama dengan 1.400 ppmv mulai dari US$ 0,1 hingga US$3,32 untuk kadar lebih dari 1.400 ppmv.

Adapun, faktor koreksi juga dipengaruhi oleh kombinasi kadar CO2, yakni kurang dari 15% Mol hingga lebih dari 30% Mol. 

“Kalau masih baru, harga ditetapkan melalui penawaran. Kalau yang sudah ada, kontrak tetap berlaku. Formula untuk peralihan,” katanya.

Bisnis Indonesia, Page-30, Tuesday, August 1, 2017

Pertamina EP Submits the Assets of Elephant Nails and Kuang

PT Pertamina EP through PT Pertamina EP Asset 2 immediately operates the production facilities of GAC Pump Station (SPG) Paku Gajah and SPG Kuang. The operation of both SPG is part of the Paku Gajah Development Project (PGDP) in Muara Enim and Ogan Komering Ilir, South Sumatra.

Nanang Abdul Manaf, President Director of Pertamina EP, said that PGDP is a gas field development project around Pagardewa, Kuang and Paku Gajah, which is located in Muara Enim Regency and Ogan Komering Ulu Regency, South Sumatera Province.

"The current status of PGDP has been the handover of the SPG Paku Gajah facility with a capacity of 45 mmscfd and SPG Kuang with a capacity of 25 mrnscfd to PT Pertamina EP Asset 2," he said in a release on Monday (31/7).

The Paku Gajah project currently uses the complete production facility of Early Production Facility (EPF). Starting from producing natural gas from exploration wells and development wells that have been drilled since 2010.

The Paku Gajah development project will have a 12-inch truckline line along the 23 km. The pipe extends from SPG Paku Gajah to existing CO2 removal of SPG Merbau. Furthermore, the gas produced from SPG Paku Gajah and SPG Kuang will be distributed to consumers of PT Perusahaan Gas Negara Tbk (PGAS) and other gas consumers in South Sumatra.

IN INDONESIA

Pertamina EP Menyerahkan Aset Paku Gajah dan Kuang

PT Pertamina EP melalui PT Pertamina EP Asset 2 segera mengoperasikan fasilitas produksi Stasiun Pengumpul Gas (SPG) Paku Gajah dan SPG Kuang. Pengoperasian kedua SPG tersebut bagian dari Paku Gajah Development Project (PGDP) di Muara Enim dan Ogan Komering Ilir, Sumatra Selatan.

Nanang Abdul Manaf, Direktur Utama Pertamina EP mengatakan, PGDP adalah proyek pengembangan lapangan gas di sekitar Pagardewa, Kuang dan Paku Gajah, yang berada di Kabupaten Muara Enim dan Kabupaten Ogan Komering Ulu, Provinsi Sumatera Selatan. 

"Status saat ini PGDP sudah serah terima fasilitas produksi SPG Paku Gajah berkapasitas 45 mmscfd dan SPG Kuang dengan kapasitas 25 mrnscfd ke PT Pertamina EP Asset 2," kata dia, dalam rilis, Senin (31/7).

Proyek Paku Gajah saat ini menggunakan fasilitas produksi Early Production Facility (EPF) sewa lengkap. Mulai dari memproduksi gas bumi dari sumur-sumur eksplorasi maupun sumur pengembangan yang telah dibor sejak tahun 2010.

Proyek pengembangan Paku Gajah nantinya memiliki jalur pipa truckline 12 inci sepanjang 23 km. Pipa tersebut terbentang dari dari SPG Paku Gajah ke CO2 removal eksisting SPG Merbau. Selanjutnya, gas yang dihasilkan dari SPG Paku Gajah dan SPG Kuang tersebut akan disalurkan ke konsumen PT Perusahaan Gas Negara Tbk (PGAS) maupun konsumen-konsumen gas lain di daerah Sumatra Selatan.

Kontan, Page-14, Tuesday, August 1, 2017

Ten Oil and Gas Fields Potentially Got Gas Flares

Special Unit for Upstream Oil and Gas Business Activities (SKK Migas) stated that there are ten oil and gas fields that have potential for flare gas and can be utilized. There is currently an indication of the potential for flare gas with an estimated volume of 19.37 million standard cubic feet per harl (mmscfd) in 10 fields. Flare gas can be used as gas for household and LPG liquefied petroleum gas raw materials.

Head of Oil and Gas Commercialization Division of SKK Migas Waras Budi Santosa stated that the flare gas potential data of 19.37 mmscfd is still temporary.

"But it could be an indication of starting the study of the potential utilization of flare gas," he said

The potential data of flare gas to be offered according to Regulation of Minister of Energy and Mineral Resources No. 32 Year 2017 on Utilization and Selling Price of Gas Flares In Upstream Oil and Gas Business Activities. Then it will be further stipulated through the Decree of Head of SKK Migas.

There are 10 oil and gas fields that have potential for flare gas. Among these, the Zelda Block, the central business unit (offshore) with the CNOOC operator has a volume of 5.18 mmscfd, Grissik Field, ConocoPhillips Corridor Block has 2.14 mmscfd and Suban Field, Corridor Block has a potential of 0.92 mmscfd. Then, South Balam Rokan Block owned by Chevron Pacific Indonesia 1.69 mmscfd and Rantau Bais Field Rokan Block with an estimated volume of 1.69 mmscfd.

Medco EP also owns in Matra Block South Sumatra Field, and Pertamina EP in Subang Field.

IN INDONESIA

Sepuluh Lapangan Migas Berpotensi Punya Gas Suar

Satuan Kerja Khusus Pelaksana Kegiatan Usaha Hulu Minyak dan Gas Bumi (SKK Migas) menyatakan ada Sepuluh lapangan migas yang memiliki potensi gas suar dan bisa dimanfaatkan. Saat ini terdapat indikasi potensi gas suar dengan perkiraan volume sebesar 19,37 juta standar kaki kubik per harl (mmscfd) di 10 lapangan. Gas suar bisa dijadikan gas untuk rumah tangga dan bahan baku liquefied petroleum gas LPG.

Kepala Divisi Komersialisasi Minyak dan Gas Bumi SKK Migas Waras Budi Santosa menyatakan, data potensi gas suar sebesar 19,37 mmscfd itu masih bersifat sementara.

"Tapi bisa sebagai indikasi memulai kajian potensi pemanfaatan gas suar," ujar dia

Data potensi gas suar yang akan ditawarkan sesuai Peraturan Menteri ESDM No 32 Tahun 2017 tentang Pemanfaatan dan Harga Jual Gas Suar Pada Kegiatan Usaha Hulu Minyak dan Gas Bumi. Kemudian akan ditetapkan lebih lanjut melalui Keputusan Kepala SKK Migas.

Ada 10 lapangan migas yang memiliki potensi gas suar. Di antaranya, Blok Zelda, central business unit (offshore) dengan operator CNOOC memiliki volume 5,18 mmscfd, Lapangan Grissik, Blok Corridor ConocoPhillips memiliki 2,14 mmscfd dan Lapangan Suban, Blok Corridor memiliki potensi 0,92 mmscfd. Lalu, South Balam Blok Rokan milik Chevron Pacific Indonesia 1,69 mmscfd dan Lapangan Rantau Bais Blok Rokan dengan perkiraan volume 1,69 mmscfd.

Medco EP juga punya di Lapangan Matra Blok South Sumatra, dan Pertamina EP di Lapangan Subang.

Kontan, Page-14, Tuesday, August 1, 2017

Production of Old Wells Can Be Optimal

The Ecuadorian firm, Sertecpet, offers an integrated solution for the downstream oil and gas industry

The Ecuadorian firm, Sertecpet

The existence of old oil wells is a phenomenon faced by every oil and gas company around the world. The old wells are generally considered to lose productivity because to lift the crude oil to the surface requires a relatively high cost. Therefore, many oil and gas companies move and leave old wells. They prefer to find new wells because they are considered more productive.

Sertecpet Chairman and CEO, Eduardo Loperz Robayo, said that the old wells can still be improved by applying new technology. Armed with cutting-edge technology, efficient, and inexpensive, Sertecpet is capable Maintaining and improving the comprehensive production of old wells.

"Sertepec has a jet pump product called Jet Claw that already has patents from America and Russia, as well as Canada. This technology is a solution for many countries that have problems decreasing the amount of oil lifting, "Eduardo said in Jakarta last week. Jet Claw's propulsion capability can boost lifting activities to 2,000 barrels.

"Jet Claw can be applied to sliding sleeve, bottom hole assembly and coiled tubing," he explained.

Eduardo tells of the patented pump that can increase the productivity of old wells spread across Latin America in just 1 to 2 years.

"They do not take 5-7 years to transform the same technology, even more expensive after using Jet Claw," said Eduardo

Currently Sertecpet's Jet Claw technology is widely used in Latin America and Africa. They have won the trust of 14 countries and have representative offices in Mexico, Brazil, Colombia, Peru, Anggola, Middle East, Latin America, to North Africa. It is keen to help improve the productivity of old wells in the Asian region, in particular Indonesia. He is very confident that old wells spread all over Indonesia can be more productive with the pump owned by his company

Off taker Masela

the Masela Block

On different occasions, EMR Deputy Minister of Energy and Mineral Resources, Arcandra Tahar, said there are already several companies that have submitted to buy gas from the Masela Block. Those interested are local and foreign companies.

"There are already some who filed. Three months of this target can get buyers off taker it, "said Arcandra in Jakarta

The government prioritizes local companies to become the main offtaker of the Masela Block. As PT PLN is expected to absorb to flow in the region of Maluku.

"What is clear to us, if development in the framework of regional development, we need electricity,"

Based on a letter from the Oil and Gas Upstream Business Unit (SKK Migas) to Inpex Masela Ltd, LNG production capacity in Masela Block is planned to be 9.5 million tons per year (mtpa) and pipe gas of 150 mmscfd.

IN INDONESIA

Produksi Sumur Tua masih Bisa Optimal

Perusahaan asal Ekuador, Sertecpet, menawarkan solusi terpadu bagi industri hilir minyak dan gas

Keberadaan Sumur minyak tua merupakan fenomena yang dihadapi setiap perusahaan minyak dan gas di seluruh dunia. Sumur-sumur tua itu umumnya dianggap kehilangan produktivitas karena untuk mengangkat minyak mentah ke permukaan butuh biaya yang relatif mahal. Oleh karena itu, banyak perusahaan migas beralih dan meninggalkan sumur tua. Mereka lebih senang mencari sumur baru karena dianggap lebih produktif.

Chairman dan CEO Sertecpet, Eduardo Loperz Robayo, mengatakan sebenarnya sumur-sumur tua itu masih bisa ditingkatkan produktivitasnya dengan menerapkan teknologi baru. Berbekal teknologi mutakhir, efisien,dan murah, Sertecpet mampu mempertahankan dan meningkatkan produksi yang komprehensif bagi sumur-sumur tua.

“Sertepec memiliki produk pompa jet bernama Jet Claw yang telah memiliki hak paten dari Amerika dan Rusia, juga Kanada. Teknologi ini merupakan solusi untuk banyak negara yang memiliki masalah penurunan jumlah lifting minyak,” papar Eduardo di Jakarta, pekan lalu. Kemampuan daya dorong Jet Claw mampu mendongkrak kegiatan lifting sampai 2.000 barel.

“Jet Claw bisa diaplikasikan pada sliding sleeve, bottom hole assemby dan coiled tubing,” jelasnya.

Eduardo menceritakan pompa yang telah dipatenkan itu mampu meningkatkan produktivitas sumur-sumur tua yang tersebar di Amerika Latin hanya dalam hitungan 1 sampai 2 tahun.

“Mereka tidak butuh waktu 5-7 tahun untuk mentransformasikan teknologi yang sama, bahkan lebih mahal setelah menggunakan Jet Claw,” kata Eduardo

Saat ini teknologi Jet Claw milik Sertecpet banyak dipakai di Amerika Latin dan Afrika. Mereka telah mendapat kepercayaan dari 14 negara dan memiliki kantor perwakilan di Meksiko, Brasil, Kolombia, Peru, Anggola, Timur Tengah, Amerika Latin, sampai Afrika Utara. Pihaknya berkeingingan untuk membantu meningkatkan produktivitas sumur-sumur tua yang berada di kawasan Asia, khususnya

Indonesia. Dia sangat yakin sumur tua yang tersebar di seluruh Indonesia bisa lebih produktif dengan pompa milik perusahaannya tersebut

Off taker Masela

Dalam kesempatan berbeda, Wakil Menteri ESDM Arcandra Tahar mengatakan sudah ada beberapa perusahaan yang mengajukan diri untuk membeli gas dari Blok Masela. Mereka yang berminat itu merupakan perusahaan lokal dan asing.

“Sudah ada beberapa yang mengajukan. Tiga bulan ini target bisa mendapatkan pembeli off taker-nya,” ucap Arcandra di Jakarta

Pemerintah mengutamakan perusahaan lokal untuk menjadi offtaker utama Blok Masela. Seperti PT PLN yang diharapkan bisa menyerap untuk mengalirkan di wilayah Maluku.

“Yang jelas bagi kita, kalau pembangunan dalam rangka pengembangan wilayah, kita memerlukan listrik,” 

Berdasarkan surat dari Satuan Kerja Khusus Pelaksana Kegiatan Usaha Hulu Minyak dan Gas Bumi (SKK Migas) kepada Inpex Masela Ltd, kapasitas produksi LNG di Blok Masela direncanakan sebesar 9,5 juta ton per tahun (mtpa) dan gas pipa sebesar 150 mmscfd. 

Media Indonesia, Page-18, Monday, July 31, 2017