Pertamina Production Slightly Above Target

PT Pertamina EP, a subsidiary of PT Pertamina, listed oil and gas production as of May 15, 2018, reaching 256,619 barrels of oil equivalent per day (BOEPD). The production achievement exceeded the target in the Work Plan and Corporate Budget (RKAP) 2018 of 249,601 BOEPD or about 101.61%.

Nanang Abdul Manaf, President Director of PT Pertamina EP, said the realization of this production consists of 76,309 barrels of oil per day or 96.26% of the target of 79,275 bph. Meanwhile, gas production is 1,027.29 million standard cubic feet per day (MMSCFD).

"Gas production until mid-May 2018 reached 104.10% of the target 986.82 MMSCFD," said Nanang.

Pertamina EP Asset 5, Pertamina EP business unit based in Balikpapan, East Kalimantan contributed the largest production of oil, which is 18,369 bph. This production comes from five fields under the manager of Pertamina EP Asset 5, namely Sangatta Field, Bunyu Field, Tanjung Field, Sanga-sanga Field, and Tarakan Field. The second largest contributor is Pertamina EP Asset 2 in Prabumulih, South Sumatera, at 17,051 bph.

The oil supply comes from four fields in Pertamina EP Asset 2, namely Prabumulih Field, Pendopo Field, Limau Field, Adera Field. Meanwhile, gas production number one came from Pertamina EP Asset 2. Total gas produced by 442 MMSCFD, much higher than contribution from Pertamina EP Asset 3 based in Cirebon, West Java of 292 MMSCFD. Pertamina EP Asset 3 gas supply comes from three fields, namely Tambun Field, Subang Field, and Jatibarang Field.

To maintain and increase production, Pertamina EP completes drilling and work over programs and executes well operation plan program. In addition, it also performs a recovery plan (recovery plan) to achieve production targets. Nanang said, during January-March 2018, Pertamina EP recorded revenues of US $ 675 million.

"This revenue achievement is 115 percent of last year's revenue of US $ 586 million (year-on-year)," he said.

This revenue achievement is also supported by rising crude oil prices in global markets. In addition there is an efficiency policy, one of which reduces production costs. In total, the cost of oil production per March 2018 for onshore is around US $ 15.98 per barrel and gas at US $ 1.03 per MSCF. As of mid-May 2018, Pertamina EP has spent US $ 122 million in capital expenditures, primarily for drilling of US $ 83 million and US $ 39 million for surface facilities ie development, upgrading and maintenance.

IN INDONESIA

Produksi Pertamina Sedikit di Atas Target

PT Pertamina EP anak usaha PT Pertamina, mencatatkan produksi migas per 15 Mei 2018, mencapai 256.619 barrel oil equivalent per day (BOEPD). Capaian produksi tersebut melewati target dalam Rencana Kerja dan Anggaran Perusahaan (RKAP) 2018 sebesar 249.601 BOEPD atau sekitar 101,61%.

Nanang Abdul Manaf, Presiden Direktur PT Pertamina EP, mengatakan, realisasi produksi ini terdiri dari produksi minyak 76.309 barel per hari atau 96,26% dari target sebesar 79.275 bph. Sementara produksi gas 1.027,29 juta standar kaki kubik per hari (MMSCFD). 

"Produksi gas hingga pertengahan Mei 2018 mencapai 104,10% dari target 986,82 MMSCFD," ujar Nanang.

Pertamina EP Asset 5, unit bisnis Pertamina EP yang berbasis di Balikpapan, Kalimantan Timur memberi kontribusi terbesar produksi minyak, yaitu 18.369 bph. Produksi ini berasal dari lima field yang berada di bawah pengelola Pertamina EP Asset 5, yaitu Sangatta Field, Bunyu Field, Tanjung Field, Sanga-sanga Field, dan Tarakan Field. Kontributor terbesar kedua adalah Pertamina EP Asset 2 di Prabumulih, Sumatera Selatan, sebesar 17.051 bph.

Pasokan minyak itu berasal dari empat field di Pertamina EP Asset 2, yaitu Prabumulih Field, Pendopo Field, Limau Field, Adera Field. Sementara, produksi gas nomor satu berasal dari Pertamina EP Asset 2. Total gas yang dihasilkan sebesar 442 MMSCFD, jauh lebih tinggi dibandingkan kontribusi dari Pertamina EP Asset 3 yang berbasis di Cirebon, Jawa Barat sebesar 292 MMSCFD. Pasokan gas Pertamina EP Aset 3 berasal dari tiga field, yaitu Tambun Field, Subang Field, dan Jatibarang Field.

Untuk mempertahankan dan meningkatkan produksi, Pertamina EP menyelesaikan program pemboran dan work over serta melaksanakan program rencana kerja operasi sumur. Selain itu, juga melakukan rencana pemulihan (recovery plan) untuk mencapai target produksi. Nanang bilang, sepanjang Januari-Maret 2018, Pertamina EP membukukan pendapatan sebesar US$ 675 juta.

"Pencapaian pendapatan ini 115% dari realisasi pendapatan tahun sebelumnya US$ 586 juta (year-on-year)," ujarnya. 

Pencapaian pendapatan ini juga didukung oleh kenaikan harga minyak mentah di pasar global. Selain itu ada kebijakan efisiensi, salah satunya menekan biaya produksi. Secara total, biaya produksi minyak per Maret 2018 untuk onshore adalah sekitar US$ 15,98 per barel dan gas US$ 1,03 per MSCF. Hingga pertengahan Mei 2018, Pertamina EP telah merealisasikan belanja modal sebesar US$ 122 juta, terutama untuk pemboran sebesar US$ 83 juta dan US$ 39 juta untuk surface facilities yakni pembangunan, upgrading, dan perawatan.

Kontan, Page-14, Saturday, May 26, 2018

Pertamina Hulu Energi Gas Production Increases

PT Pertamina Hulu Energi, a subsidiary of PT Pertamina (Persero) in the upstream sector, recorded gas production of 777 million cubic feet per day (MMSCFD) during January-March 2018, up 2% over the same period of 2017 of 765 MMSCFD.

"In 2018, PHE set a production target for March of 767.8 MMSCFD, realization of 1.2% higher," said Director of PHE R. Gunung Sardjono Hadi in Jakarta.

PHE oil production in the first three months of 2018 was 63.037 barrels oil per day (BOPD), not much different from the same period of 2017 of 62,623 BOPD.

"PHE in 2018 targeted oil production in March at 65,243 BOPD, so production in March 2018 was 96.6% of the target," Gunung said.

According to Gunung, PHE will accelerate the monetization of PHE reserves by implementing a backup source clustering strategy. This strategy can be used in the Work Area which has gas reserves not too large, but can be monetized immediately. With PHE clustering no longer thinks just waiting for gas buyers, but innovates how to create a market. The reason, although having large reserves will be useless if there is no gas absorber.

"So it does not depend on the market, but it creates the market. That's what we're after now. The concept of gas monetization is clustered. So we also have to think how to get into the midstream, "he said.

He cited the development of gas in Senoro. Senoro gas will never be monetized if the facility does not build the refinery and regasification DSLNG in cooperation with several companies. PHE will also be more open to cooperate with other companies.

"Like Senoro if there is no DSLNG it will not be developed. That's one example for another development. We try to find, create new markets. So we do not sit sweetly waiting to come buyers, "he said.

Meanwhile, Director of Operations and Production of PHE Ekariza added that PHE gas production realization depends on absorption in the market. If the absorption of large markets, then PHE can increase gas production. In addition to the Tomori Block, PHE gas production contribution comes from the Offshore North West Java (ONWJ) block, Jambi Merang and West Madura Offshore (WMO).

"First quarter gas production is higher because there is an increase in absorption. The largest production contribution comes from Tomori, "he said.

Tuban Block

Meanwhile, PHE is also targeting production in Tuban block for oil of 8.11 MBOPD and gas production of 11.11 MMSCFD. Meanwhile, for Ogan Komering, PHE targets gross production for oil of 1.95 MBOPD and gas production of 8.21 MMSCFD.

The target of the production of PHE inigas in the Company's Work Plan and Budget (RKAP) 2018 has also included the production of four terminated block of contracts to be managed by PHE. The four blocks are Tuban, Ogan Komering, Offshore South East Sumatra (OSES) and North Sumatra Offshore (NSO). Two of the four blocks, Tuban and Ogan Komering, the production sharing contract (PSC) have been signed on April 20, 2018 and are effective as of May 20, 2018.

However, for the Sukowati unitization field previously managed by Joint Operation Body (JOB) of Pertamina-PetroChina East Java from 20 May 2018 submitted to PT Pertamina EP Another block, Ogan Komering, the contract has also been signed on 20 April 2018 and effective on 20 May 2018. For undepreciated balance of Tuban and Ogan Komering block has been submitted by PHE to the Special Unit for Upstream Oil and Gas Business Unit (SKK Migas) and is currently awaiting verification and approval.

(CNOOC)

Until the end of 2017, JOB PPEJ oil production gross reach 10.5 MBOPD and gas production of 14.2 MMSCFD. Meanwhile, the production of Ogan Komering gross reached 2.25 MBOPD and gas production of 8.64 MMSCFD. In addition to Tuban and Ogan Komering, starting in October 2018 PHE will also begin to take over the management of OSES which is currently managed by China National Offshore Oil Corporation (CNOOC) SES Ltd. For NSOs, PHE has now become operator after 2015 acquired 100 percent of ExxonMobil's participation rights.

Investor Daily, Page-9, Friday, May 25, 2018

2018, Pertamina EP Targets US $ 2.6 Billion Revenue

PT Pertamina EP, Same Contract Contractor under the coordination and supervision of SKK Migas, a subsidiary of PT Pertamina (Persero), targets revenue in 2018 to reach US $ 2.5-2.6 billion.

"The revenue is assumed that the average oil price this year is at US $ 80 per barrel and the production rate is the same, while last year the average price of world oil reached US $ 51 per barrel," said Pertamina EP President Director Nanang Abdul Manaf in Fasting Sharing event in Jakarta.

Meanwhile, until May 15, 2018, the company recorded a production of 256,619 barrels of oil equivalent per day (BOEPD). The production achievement exceeded the target in the 2018 RPAP of 249,601 BOEPD or about 101.61%. Nanang said the realization of the production consists of 76.309 barrels of oil per day (BOPD) or 96.26% of the target of 79,275 BOPD. While gas production reached 1,027.29 million standard cubic feet per day (MMSCFD).

"Gas production until mid-May 2018 reached 104.10% of the target of 986.82 MMSCFD," said Nanang.

Pertamina EP Asset 5, Pertamina EP business unit based in Balikpapan, East Kalimantan, contributed the largest production of oil, which is 18,369 BOPD. This production comes from five fields under the manager of Pertamina EP Asset 5, namely Sangatta Field, Bunyu Field, Tanjung Field, Sangasanga Field, and Tarakan Field. The second largest contributor is Pertamina EP Asset 2, based in Prabumulih, South Sumatera, at 17,051 BOPD. The oil supply comes from four fields in Pertamina EP Asset 2, namely Prabumulih Field, Pendopo Field, Limau Field, and Adera Field.

While the number one gas production comes from Pertamina EP Asset 2. The total gas produced is 442 MMSCFD, much higher than the contribution from Pertamina EP Asset 3 based in Cirebon, West Java at 292 MMSCFD. Pertamina EP Asset 3 gas supply comes from three fields, namely Tambun Field, Subang Field, and Jatibarang Field.

To maintain and even increase oil and gas production, Pertamina EP completed drilling program and Work Over (WO) and implemented a well operation plan program. In addition, the company also undertook a recovery plan to achieve production targets. Nanang explained, during January-March 2018, Pertamina EP recorded revenues of US $ 675 million.

"This revenue achievement is 115 percent of last year's revenue of US $ 586 million (year-on-year)," he said.

This revenue achievement is also supported by the start of rising global oil prices and company efficiency policies. One of them is to reduce production costs. In total, oil production cost (production cost) as of March 2018 for onshore is about US $ 15.98 per barrel, gas is US $ 1.03 per MSCF and oil and gas US $ 8.96 per MSCF.

"For offshore field, one of them is in Field Poleng, its production cost until end of March is US $ 10.47 per barrel, gas is US $ 1.81 per MSCE and oil and gas US $ 10.47 per MSCE" said Nanang.

He also asserted, Pertamina this year allocate capital expenditure (capex) of US $ 330 million. Meanwhile, operational expenditure (opex) amounted to US $ 1,648 million. "The funds are allocated for exploration, development, production, and General & Administration (G & A)," he said.

As of mid-May 2018, Pertamina EP has realized capex of US $ 122 million, primarily for drilling of US $ 83 million and US $ 39 million for surface facilities (development, upgrading and overhaul). Opex realization amounted to US $ 359 million, mainly used to support the company's operations, including exploration and exploitation activities.

Field Sukowati

Related to Sukowati field management in East Java, the field management is done by Pertamina EP Asset 4 based in Blora, Central Java. Chalid Salim Said, Pertamina EP's Director of Operations and Production expects Pertamina EP to raise Sukowati production by measures to be pursued by programs such as accelerating work plans by increasing the number of rigs, conducting new technology studies, and drilling production or injection wells.

According to Chalid, there are two strategic steps prepared by Pertamina EP regarding the transfer of Sukowati field from Joint Operating Body (JOB) Pertamina Petrochina East Java (PPEJ). In the short term, Pertamina EP will revive dead wells, artificial lifting improvements, optimization of production facility, well repair, dry docking Floating Storage Offloading Cinta Natomas, and completion of POD Phase 6 Sukowati.

"In the long run, we are planning POD Phase 6 Sukowati," he said.

As known, based on the Decree of the Minister of Energy and Mineral Resources No. 2800/13 / MEM.M / 2018 dated May 17, 2018, Sukowati field which was previously operated by JOB PPEJ on May 20, 2018 was handed over to Pertamina EP. Minister of ESDM lgnasius Jonan appointed Pertamina EP to become the new operator of Sukowati field as well as production facilities of Central Processing Asset Mudi, Palang Station up to FSO Cinta Natomas.

IN INDONESIA

2018, Pertamina EP Targetkan Pendapatan US$ 2,6 Miliar

 PT Pemamina EP, kontraktor Kontrak Kerja Same di bawah koordinasi dan supervisi SKK Migas yang juga anak usaha PT Pertamina (Persero), menargetkan pendapatan (revenue) pada 2018 mencapai US$ 2,5-2,6 miliar.

“Pendapatan itu dengan asumsi harga minyak rata-rata tahun ini mencapai US$ 80 per Barel dan tingkat produksi sama, sementara tahun lalu harga rata-rata minyak dunia mencapai US$ 51 per barel,” kata Presiden Direktur PT Pertamina EP Nanang Abdul Manaf dalam acara Buka Puasa Bersama di Jakarta.

Sementara itu, hingga 15 Mei 2018, perseroan mencatatkan produksi sebesar 256.619 barrel oil equivalent per day (BOEPD). Capaian produksi tersebut melewati target dalam RKAP 2018 sebesar 249.601 BOEPD atau sekitar 101,61%. Nanang mengatakan, realisasi produksi tersebut terdiri dari produksi minyak sebesar 76.309 barel oil per day (BOPD) atau 96,26% dari target sebesar 79.275 BOPD. Sementara produksi gas mencapai 1.027,29 juta standar kaki kubik per hari (MMSCFD). 

“Produksi gas hingga pertengahan Mei 2018 mencapai 104,10% dari target sebesar 986,82 MMSCFD," ujar Nanang.

Pertamina EP Asset 5, unit bisnis Pertamina EP yang berbasis di Balikpapan, Kalimantan Timur memberi kontribusi terbesar produksi minyak, yaitu 18.369 BOPD. Produksi ini berasal dari lima field yang berada di bawah pengelola Pertamina EP Asset 5, yaitu Sangatta Field, Bunyu Field, Tanjung Field, Sangasanga Field, dan Tarakan Field. Kontributor terbesar kedua adalah Pertamina EP Asset 2 yang bermarkas di Prabumulih, Sumatera Selatan, sebesar 17.051 BOPD. Pasokan minyak tersebut berasal dari empat field di Pertamina EP Asset 2, yaitu Prabumulih Field, Pendopo Field, Limau Field, dan Adera Field.

Sementara produksi gas nomor satu berasal dari Pertamina EP Asset 2. Total gas yang dihasilkan sebesar 442 MMSCFD, jauh lebih tinggi dibandingkan kontribusi dari Pertamina EP Asset 3 yang berbasis di Cirebon, Jawa Barat sebesar 292 MMSCFD. Pasokan gas Pertamina EP Aset 3 berasal dari tiga field, yaitu Tambun Field, Subang Field, dan Jatibarang Field.

Untuk mempertahankan dan bahkan meningkatkan produksi migas, Pertamina EP menyelesaikan program pemboran dan Work over (WO) serta melaksanakan program rencana kerja operasi sumur. Selain itu, perusahaan juga melakukan rencana pemulihan (recovery plan) untuk mencapai target produksi. Nanang menjelaskan, sepanjang Januari-Maret 2018, Pertamina EP membukukan pendapatan sebesar US$ 675 juta.

“Pencapaian pendapatan ini 115% dari realisasi pendapatan tahun sebelumnya US$ 586 juta (year-on-year)," ujarnya.

Pencapaian pendapatan ini juga ditopang oleh mulai naiknya harga minyak global dan kebijakan efisiensi perusahaan. Salah satunya adalah menekan biaya produksi. Secara total, biaya produksi (production cost) minyak per Maret 2018 untuk onshore adalah sekitar US$ 15,98 per barel, gas US$ 1,03 per MSCF dan migas US$ 8,96 per MSCF. 

“Untuk lapangan offshore, salah satunya ada di Field Poleng, biaya produksinya hingga akhir Maret sebesar US$ 10,47 per barrel, gas US$ 1,81 per MSCE dan migas US$ 10,47 per MSCE” kata Nanang.

Dia juga menegaskan, Pertamina tahun ini mengalokasikan belanja modal (capital expenditure/capex) sebesar US$ 330 juta. Sementara itu belanja operasi (operational expenditure/ opex) sebesar US$ 1.648 juta. “Dana itu dialokasikan untuk kegiatan eksplorasi, pengembangan, produksi, serta General & Administration (G&A) ,” ujarnya.

Hingga pertengahan Mei 2018, Pertamina EP telah merealisasikan belanja modal (capex) sebesar US$ 122 juta, terutama untuk pemboran sebesar US$ 83 juta dan US$ 39 juta untuk surface facilities (pembangunan, upgrading, dan overhaul). Sedangkan realisasi opex sebesar US$ 359 juta, terutama digunakan untuk mendukung kegiatan operasi perusahaan, antara lain kegiatan eksplorasi dan eksploitasi.

Lapangan Sukowati

Terkait pengelolaan lapangan Sukowati di Jawa Timur, pengelolaan lapangan tersebut dilakukan oleh Pertamina EP Asset 4 yang berbasis di Blora, Jawa Tengah. Chalid Salim Said, Direktur Operasi dan Produksi Pertamina EP berharap Pertamina EP dapat menaikkan produksi Sukowati dengan langkah-langkah yang akan ditempuh dengan program antara lain percepatan rencana kerja dengan menambah jumlah rig, melakukan kajian teknologi baru, dan melakukan pemboran produksi atau pun sumur injeksi.

Menurut Chalid, ada dua langkah strategis yang disiapkan Pertamina EP terkait alih kelola lapangan Sukowati dari Joint Operating Body (JOB) Pertamina Petrochina East Java (PPEJ). Dalam jangka pendek, Pertamina EP akan menghidupkan kembali sumur-sumur yang mati, perbaikan artificial lifting, optimasi production facility, reparasi sumur, dry docking Floating Storage Offloading Cinta Natomas, dan penyelesaian POD Phase 6 Sukowati.

“Dalam jangka panjang, kami merencanakan POD Phase 6 Sukowati,” katanya.

Sebagaimana diketahui, berdasarkan Keputusan Menteri Energi dan Sumber Daya Mineral Nomor 2800/ 13/ MEM.M/ 2018 tanggal 17 Mei 2018, lapangan Sukowati yang sebelumnya dioperatori oleh JOB PPEJ, pada 20 Mei 2018 diserahkan pengelolaannya kepada Pertamina EP. Menteri ESDM lgnasius Jonan menunjuk Pertamina EP menjadi operator baru lapangan Sukowati serta fasilitas produksi Central Processing Asset Mudi, Palang Station sampai dengan FSO Cinta Natomas.

Investor Daily, Page-9, Friday, May 25, 2018

Pertamina Search Partners Build Balikpapan Plant

Fund Requirement US $ 4 Billion

PT Pertamina (Persero) will partner with the Balikpapan Reinery Development Master Plan project. The project, targeted to be completed in 2021, will be done by the government-owned oil and gas company. Pertamina Managing Director Nicke Widyawati said the plan to partner with the company is a new strategy to complete projects that require large amounts of funding. In the calculation of the company the need for the development of the Balikpapan refinery reaches US $ 4 billion.

"We also open partnership we also do partner selection," said Nicke in the House of Representatives (DPR).

Nicke Widyawati

Nicke explained the initial stage of screening partners will be done market sounding. The same applies to the Bontang refinery. He mentioned that there has been an informal communication from several companies that expressed interest in participating in the development of the Balikpapan refinery.

"Yes, there is this year (market sounding). Of course we will see all aspects, we must recview, the council also ask to carefully choose a partner, "he said.

He said the process of determining the partners will also be accompanied by the calculation of valuation of assets to be listed for the inbreng process of shares. All of the existing assets belonging to Pertamina and already built so many percent will be divested into the value of share inbreng with the partner. But Nicke asserted Pertamina remains the majority shareholder.

"So instead of the government doing equity but this asset is our valuation of our value is so inbreng us with partners so the portion of our shares so paid in the form of asset inbreng," he said.

Furthermore Nicke explained that the development process that has been going on will not be stopped. Thus the selection of partners and the construction of refineries the process will take place in parallel.

"We operate just like a Cilacap refinery in Central Java. Saudi Aramco when all conditions are fulfilled setealh it then joined, so we operate just once there is no desire to delay, "he said.

The development of the Balikpapan refinery commenced in 2017 and is targeted to be completed by 2021. Currently, the Engineering Contractor, Procurement and Construction (EPC) engineering auction will be held until October. The Balikpapan Phase I RDMP is targeted to be completed by 2021, increasing the company's refinery capacity by 100 thousand barrels per day (bpd). 

      While the Balikpapan Phase II RDMP is targeted to be completed by 2025. The RDMP program will increase the capacity and complexity of the refinery. In the first phase, Balikpapan refinery capacity will increase from 260 thousand bpd to 350 thousand bpd.

In the second phase, the refinery becomes capable of processing oil until the sour type from the previous medium heavy. The investment requirement for RDMP of Balikpapan refinery reaches US $ 4.6 billion. In detail, the first phase requires US $ 2.6 billion and the second phase of US $ 2 billion.

IN INDONESIA

Kebutuhan Dana US$ 4 Miliar

Pertamina Cari Mitra Bangun Kilang Balikpapan

PT Pertamina (Persero) akan menggandeng mitra dalam proyek Reinery Development Master Plan Kilang Balikpapan. Proyek yang ditargetkan rampung pada 2021 itu sebelumnya akan dikerjakan sendiri oleh perusahaan migas milik pemerintah tersebut. Pelaksana Tugas Direktur Utama Pertamina Nicke Widyawati mengatakan rencana menggandeng partner merupakan strategi baru perusahaan dalam menyelesaikan proyek yang membutuhkan pendanaan dalam jumlah besar. 

Dalam kalkulasi perusahaan kebutuhan dana pengembangan kilang Balikpapan mencapai US$ 4 Miliar.

“Kita buka juga partnership kita juga lakukan partner selection,” kata Nicke di Dewan Perwakilan Rakyat (DPR).

Nicke menjelaskan tahap awal penyaringan mitra kerja itu akan dilakukan market sounding. Hal serupa diterapkan pada kilang Bontang. Dia menyebut sudah terjalin komunikasi informal dari beberapa perusahaan yang menyatakan minatnya ikut dalam pengembangan kilang Balikpapan.

“Iya, ada tahun ini (market sounding). Tentu kita akan melihat semua aspek, harus kita recview, dewan juga minta untuk hati-hati memilih partner,” ujarnya.

Dikatakannya proses penetapan partner juga akan dibarengi dengan perhitungan valuasi aset yang akan dicatatkan untuk proses inbreng saham. Seluruh aset yang ada milik Pertamina dan sudah dibangun sekian persen itu akan divaluasi menjadi nilai inbreng saham dengan partner tersebut. Namun Nicke menegaskan Pertamina tetap menjadi pemegang saham mayoritas.

“Jadi bukan pemerintah melakukan penyertaan modal tapi aset ini kita valuasi kita nilai ini yang jadi inbreng kita dengan partner jadi porsi saham kita jadi dibayarkan dalam bentuk inbreng aset,” ujarnya.

Lebih lanjut Nicke menjelaskan proses pembangunan yang sudah berlangsung tidak akan dihentikan. Dengan begitu pemilihan partner dan pembangunan kilang prosesnya akan berlangsung secara paralel.

“Kita beroperasi dulu saja seperti kilang Cilacap Jawa Tengah. Saudi Aramco ketika syarat semua sudah terpenuhi setealh itu kemudian bergabung, jadi kita beroperasi dulu saja tidak ada keinginan menunda,” ungkapnya. 

Pengembangan kilang Balikpapan dimulai sejak tahun 2017 dan ditargetkan rampung pada 2021. Saat ini sedang dilakukan lelang paket rekayasa, pengadaan, dan konstruksi (engineering, procurement, and construction/EPC) Contractor hingga bulan Oktober akan ditetapkan pemenangnya. 

      RDMP Kilang Balikpapan Tahap I ditargetkan selesai pada 2021 sehingga meningkatkan kapasitas kilang perseroan sebesar 100 ribu barel per hari (bph). Sementara RDMP Kilang Balikpapan Tahap II ditargetkan selesai pada 2025. Program RDMP nantinya akan meningkatkan kapasitas sekaligus kompleksitas kilang. Pada tahap pertama, kapasitas Kilang Balikpapan akan naik dari 260 ribu bph menjadi 350 ribu bph. 

Pada tahap kedua, kilang menjadi mampu mengolah minyak hingga jenis sour dari sebelumnya hanya medium heavy Kebutuhan investasi untuk RDMP Kilang Balikpapan ini mencapai US$ 4,6 miliar. Rincinya, tahap pertama membutuhkan US$ 2,6 miliar dan tahap kedua US$

2 miliar.

Investor Daily, Page-9, Friday, May 25, 2018

Gas Production PHE QuartaI 1-201 7 Increase by 2%

PT Pertamina Hulu Energi (PHE) noted that as of March, gas production was 777 million cubic feet per day (mmscfd). The achievement rose 2% over the same period in 2017 amounted to 766 mmscfd.

"In 2018, PHE set a production target for March of 767.8 mmscfd, realization of 1.2% higher," said R. Gunung Sardjono Hadi, Director of PHE.

While oil production PHE in the first three months of 2018 recorded 63,087 barrels per day is not much different from the same period of 2017 of 62,623 bpd.

"In 2018 PHE targets 65.243 barrels of oil production per day in March, so production in March 2018 is 96.6 percent of the target," said Gunung PHE will accelerate the monetization of PHE reserves by implementing a backup source cluster strategy. This strategy can be used in working areas that have less gas reserves, but can be monetized soon.

With clustering, PHE no longer thinks just waiting for gas buyers, but to innovate how to create a market. The reason, although having large reserves will be useless if there is no gas absorber. So, it does not depend on the market, but it creates the market.

"That is what we are now chasing, the concept of gas monetization is clustered, so we also have to think how to get into" midstream, "said Sardjono.

He cited the development of gas in Senoro. Senoro gas will never be monetized if the facility is not built as well as regasification Donggi Senoro LNG (DSLNG) in cooperation with several companies. For that PHE will also be more open in cooperation with other companies "Like Senoro if no DSLNG it will not be developed. That's one example for another development. We try to find, create new markets. So we do not sit sweetly waiting to come buyers, "said Gunung.

IN INDONESIA

Produksi Gas PHE KuartaI 1-201 7 Naik Sebesar 2%

PT Pertamina Hulu Energi (PHE) mencatat , hingga Maret, produksi gas 777 juta kaki kubik per hari (mmscfd). Pencapaian tersebut naik 2% dibandingkan periode yang sama tahun 2017 sebesar 766 mmscfd. 

"Pada tahun 2018, PHE mematok target produksi bulan Maret sebesar 767,8 mmscfd, realisasinya 1,2% lebih tinggi,” ujar R. Gunung Sardjono Hadi, Direktur Utama PHE.

Sementara produksi minyak PHE pada tiga bulan pertama 2018 tercatat 63.087 barel per hari tidak jauh berbeda dibanding periode yang sama 2017 sebesar 62.623 bph.

"Pada tahun 2018 PHE menargetkan produksi minyak bulan Maret sebesar 65.243 barel per hari, sehingga produksi Maret 2018 tercatat 96,6% dari target," kata Gunung PHE akan mempercepat monetisasi cadangan PHE dengan menerapkan strategi klaster sumber cadangan. Strategi ini bisa digunakan di wilayah kerja yang memiliki cadangan gas tidak terlalu besar, namun bisa segera dimonetisasi.

Dengan klasterisasi, PHE tidak lagi berpikir hanya menunggu pembeli gas, tapi berinovasi bagaimana menciptakan pasar. Pasalnya, meski memiliki cadangan besar akan percuma jika tidak ada penyerap gas. Jadi, tidak tergantung pasar, tetapi menciptakan pasar. 

"Itu yang sekarang sedang kami kejar, Konsep monetisasi gas dibikin klaster. Jadi kami juga harus berpikir bagaimana bisa masuk ke "midstream," kata Gunung Sardjono.

Dia mencontohkan pengembangan gas di Senoro. Gas Senoro tidak akan pernah dimonetisasi andai kata tidak terbangun fasilitas kilang serta regasifikasi Donggi Senoro LNG (DSLNG) yang bekerja sama dengan beberapa perusahaan. Untuk itu PHE juga akan lebih membuka diri dalam menjalin kerja sama dengan perusahaan lain “Seperti Senoro kalau tidak ada DSLNG itu kan tidak akan dikembangkan. Itu salah satu contoh untuk pengembangan lain. Kami mencoba mencari, menciptakan pasar baru. Jadi kami tidak duduk manis menunggu datang pembeli," kata Gunung.

Kontan, Page-14, Friday, May 25, 2018

Gendalo & Gehem Start Production 2023

Gendalo and Gehem Field in Indonesia deep water / IDD project managed by Chevron Makassar Ltd. is expected to begin production first in 2023. Currently, the IDD project immediately completes the pre-front end engineering and design (pre-FEED) phase of June 2018.

Head of Program and Communication Division of SKK Migas Wisnu Prabawa Taher said that so far the IDD project is still awaiting pre-FEED results which are expected to be completed in June 2018.

"Later, after this will enter the FEED stage first, then start the PoD [plan of development] he said.

Based on data from SKK Migas, IDD Gendalo and Gehem Project managed by Chevron Makassar Ltd. will start operating in 2024 and 2025. The gas production potential from Gendalo Field is estimated to reach 500 million cubic feet per day (MMscfd), while Gehem is around 420 MMsCfd.

The Ministry of Energy and Mineral Resources (ESDM) has received Chevron's representatives from the United States (US) and has promised an IDD project will be accelerated. EMR Deputy Minister of Energy and Mineral Resources Arcandra Tahar said Chevron's representative from Houston, USA, came and promised to accelerate the deep-sea oil and gas project. In June 2018, Chevron will include pre-FEED results.

"So, onstrearn first gas schedules [their first gas] is accelerated, can be in 2023 from the previous about 2024," he said.

Arcandra is optimistic that the acceleration plan can be achieved. It also provides some suggestions and contract strategy to the managers of oil and gas project in it.

"The contract strategy is like suggestions for EPC [engineering, procurement, construction] contractors at FEED preferring suitable contractors. This is being designed so that later execution can be faster, can save about 1 year-2 years, "he said.

However, SKK Migas explained that the acceleration of the second-phase IDD project Gendalo-Gehem is still awaiting pre-FEED results. The pre-FEED study of Gendalo and Gehem Fields has been started since December 2017. The optimization of the development concept and the basic simplification of rancanagan show significant capital development and operational cost reduction. Chevron, the IDD project operator, holds a 63% stake. The remaining shares are owned by another partner, Eni, Tip Top, PHE, and partners in Muara Bakau.

IN INDONESIA

Gendalo & Gehem Mulai Produksi 2023

Lapangan Gendalo dan Gehem dalam proyek migas laut dalam (Indonesia deep water/IDD) yang dikelola Chevron Makassar Ltd. diperkirakan akan memulai produksi pertama pada 2023. Saat ini, proyek IDD itu segera menyelesaikan tahap desain dan konstruksi awal (pre-front end engineering and design/pre-FEED) pada Juni 2018.

Kepala Divisi Program dan Komunikasi SKK Migas Wisnu Prabawa Taher mengatakan, sejauh ini proyek IDD masih menunggu hasil pre-FEED yang diperkirakan selesai Juni 2018.

“Nantinya, setelah ini akan memasuki tahap FEED terlebih dulu, lalu mulai PoD [plan of development/rencana pengembangan] katanya.

Berdasarkan data SKK Migas, Proyek IDD Gendalo dan Gehem yang dikelola oleh Chevron Makassar Ltd. akan mulai beroperasi pada 2024 dan 2025. Potensi produksi gas bumi dari Lapangan Gendalo diperkirakan mencapai 500 juta kaki kubik per hari (MMscfd), sedangkan Gehem sekitar 420 MMsCfd.

Kementerian Energi dan Sumber Daya Mineral (ESDM) telah menerima perwakilan Chevron dari Amerika Serikat (AS) dan mendapatkan janji proyek IDD akan dipercepat. Wakil Menteri ESDM Arcandra Tahar mengatakan, perwakilan Chevron dari Houston, AS datang dan menjanjikan akan mempercepat proyek migas laut dalam tersebut. Pada Juni 2018, Chevron akan memasukkan hasil pre-FEED.

“Jadi, jadwal onstrearn first gas [produksi gas pertama] mereka dipercepat, bisa pada 2023 dari sebelumnya sekitar 2024,” ujarnya.

Arcandra optimistis rencana percepatan itu bisa tercapai. Pihaknya pun memberikan beberapa saran dan strategi kontrak kepada pengelola proyek migas Iaut dalam tersebut.

“Strategi kontrak itu seperti saran untuk kontraktor EPC [engineering, procurement, construction] pada FEED lebih memilih kontraktor yang sesuai. Ini sedang didesain sehingga nanti eksekusinya bisa lebih cepat, bisa hemat sekitar 1 tahun-2 tahun,” ujarnya.

Namun, SKK Migas menjelaskan bahwa soal percepatan proyek IDD tahap kedua Gendalo-Gehem itu masih menunggu hasil pre-FEED. Studi pre-FEED Lapangan Gendalo dan Gehem itu sudah dimulai sejak Desember 2017. Optimalisasi konsep pengembangan dan dasar penyederhanaan rancanagan menunjukkan pengembangan modal dan pengurangan biaya operasional yang signifikan. Chevron sebagai operator proyek IDD itu memegang saham 63%. Sisa saham dimiliki oleh mitra lain, yaitu Eni, Tip Top, PHE, dan mitra di Muara Bakau.

Bisnis Indonesia, Page-30, Friday, May 25, 2018

Production of Tuban & Ogan Blocks is Lower

PT Pertamina Hulu Energi set a target of oil and gas production in Tuban Block and Ogan Komering Block this year is lower than the realization in 2017. Pertamina Hulu Energi (PHE) received an assignment from the government to manage Tuban and Ogan Komering at the end of February 2018 .

The Tuban Block contract expires on February 23, 2018 and the Ogan Block expires on February 28, 2018. The government decided to transfer the two blocks to PHE. However, Pertamina Hulu Energi has not started aggressively yet. PHE is beginning to be expansive next year. This year, the company is still focused on maintaining oil and gas production from both blocks.

Director of PHE Gunung Sardjono Hadi said that the company will not revise the production target of Tuban and Ogan Komering Block this year, which is no higher than the 2017 realization. The company proposes the target with the assumption that the company will focus on keeping the production in the block down This year.

"Most importantly, when take over becomes a new contract with a gross split scheme or a gross profit sharing contract there is no decrease in production. So, we are also difficult to directly first year promising big targets, "he said.

PHE targets the production of crude oil of Tuban Block in 2018 of 8,110 barrels per day (bpd), while natural gas is 11.11 million cubic feet per day (MMscfd). In fact, the oil production of Tuban Block in 2018 amounted to 10,500 bpd, while gas 14.2 MMscfd. 

       PHE estimates that the production of Ogan Komering Block crude oil in 2018 will be around 1,950 bpd, while gas is 8.21 MMscfd. In fact, oil production in Ogan in 2017 amounted to 2.250 bpd, while gas production 8.64 MMscfd. Gunung Sardjono Hadi noted that the current production in the Tuban and Ogan Komering blocks is already above the target.

"Although not much different from the target, about 1,200 barrels of equivalent per day to 2,100 barrels are equivalent per day above the target," he said.

PHE has not been able to act immediately when the transfer is done in April 2018 because the transition process is very short. In fact, the government has not yet decided on new operators until terminating the Tuban Block and Ogan Komering on February 28, 2018 so that there is a six month extension decision to the operators to exist. 

       Gunung said that the transfer of Tuban and Ogan Komering is different from Mahakam Block to PT Pertamina Hulu Mahakam (PHM). At that time, CMF has been approved in Mahakam contract so that when making a plan after the transfer in 2017 no problem.

the Mahakam Block

"In fact, in the transition period, Total as an existing operator still manages, but by using funds from CMF. If Tuban and Ogan Komering have even terminated and were renewed, it will be difficult to plan for the near term, "he said.

In contracts with a gross split scheme, PHE will issue US $ 42.25 million in Tuban Block as a definite commitment for the first 3 years. Then, a subsidiary of PT Pertamina (Persero) will also issue funds of US $ 23.3 million in the block Ogan Komering for the commitment of the first 3 years. Total PHE gas production in the first quarter of 2018 was 748 MMscfd, up 3% compared to the same period of 2017 of 7Z5.6 MMscfd.

IN INDONESIA

Produksi Blok Tuban & Ogan Lebih Rendah

PT Pertamina Hulu Energi memasang target produksi minyak dan gas bumi di Blok Tuban dan Blok Ogan Komering pada tahun ini lebih rendah dibandingkan dengan realisasi pada 2017. Pertamina Hulu Energi (PHE) menerima penugasan dari pemerintah untuk mengelola Blok Tuban dan Ogan Komering pada akhir Februari 2018.

Kontrak Blok Tuban berakhir pada 23 Februari 2018 dan Blok Ogan berakhir pada 28 Februari 2018. Pemerintah memutuskan untuk mengalihkan kedua blok itu kepada PHE. Namun, Pertamina Hulu Energi belum mulai agresif. PHE mulai ekspansif pada tahun depan. Pada tahun ini, perseroan masih fokus menjaga produksi minyak dan gas bumi dari kedua blok itu tidak turun.

Direktur Utama PHE Gunung Sardjono Hadi mengatakan, perseroan tidak akan merevisi target produksi Blok Tuban dan Ogan Komering pada tahun ini yang ditetapkan tidak lebih besar dibandingkan realisasi 2017. Pasalnya, perseroan mengajukan target itu dengan asumsi perseroan akan fokus menjaga produksi di blok tersebut tidak turun sepanjang tahun ini.

“Paling penting, saat take over menjadi kontrak baru dengan skema gross split atau kontrak bagi hasil kotor tidak ada penurunan produksi. Jadi, kami sulit juga secara langsung tahun pertama menjanjikan target besar,” ujarnya.

PHE menargetkan produksi minyak mentah Blok Tuban pada 2018 sebesar 8.110 barel per hari (bph), sedangkan gas bumi sebesar 11,11 juta kaki kubik per hari (MMscfd). Padahal, produksi minyak Blok Tuban pada 2018 sebesar 10.500 bph, sedangkan gas 14,2 MMscfd. 

      PHE menargekan produksi minyak mentah Blok Ogan Komering pada 2018 sekitar 1.950 bph, sedangkan gas sebesar 8,21 MMscfd. Padahal, produksi minyak di Ogan pada 2017 sebesar 2,250 bph, sedangkan produksi gas 8,64 MMscfd. Gunung Sardjono Hadi mencatat, saat ini produksi di Blok Tuban dan Ogan Komering juga sudah berada di atas target. 

“Walaupun tidak berbeda jauh dari target, sekitar 1.200 barel ekuivalen per hari sampai 2.100 barel ekuivalen per hari di atas target,” ujarnya.

PHE belum bisa langsung beraksi ketika alih kelola dilakukan pada April 2018 karena proses transisi sangat singkat. Bahkan, pemerintah belum memutuskan operator baru sampai melewati masa terminasi Blok Tuban dan Ogan Komering pada 28 Februari 2018 sehingga ada keputusan perpanjangan selama 6 bulan kepada operator eksis. 

     

Gunung menyebutkan, kondisi alih kelola Blok Tuban dan Ogan Komering berbeda dengan Blok Mahakam kepada PT Pertamina Hulu Mahakam (PHM). Saat itu, PHM sudah disetujui kontraknya di Mahakam sehingga ketika membuat rencana setelah alih kelola pada 2017 tidak ada masalah.

“Malah, pada masa transisi, Total sebagai operator eksis masih mengelola, tetapi dengan menggunakan dana dari PHM. Kalau Tuban dan Ogan Komering malah sudah terminasi dan sempat diperpanjang, jadi susah juga buat perencanaan jangka dekatnya,” sebutnya.

Dalam kontrak dengan skema gross split, PHE akan menggeluarkan sebesar US$ 42,25 juta di Blok Tuban sebagai komitmen pasti 3 tahun pertama. Lalu, anak usaha PT Pertamina (Persero) itu juga akan menggeluarkan dana US$ 23,3 juta di blok Ogan Komering untuk komitmen pasti 3 tahun pertama. Total produksi gas PHE pada kuartal I/2018 sebanyak 748 MMscfd naik 3% dibandingkan dengan periode yang sama 2017 sebesar 7Z5,6 MMscfd.

Bisnis Indonesia, Page-30, Friday, May 25, 2018

Pertamina: Block Production Termination 36%

PT Pertamina (Persero) said that the contribution to national oil and gas production increased from 23% in 2017 to 36% in April 2018 after managing the termination block. Acting Director of Pertamina Nicke Widyawati in Jakarta said that the termination block also contributes to Pertamina's contribution to the national oil and gas production level.

Nicke Widyawati

"With the additional Mahakam Block then 8 Working Areas (WK) termination given, this is the addition (Pertamina's contribution to national oil and gas production) to about 36%," said Nicke.

With the addition of 2 Working Areas (WK) again (2019 termination block), it is certainly expected in the next two to three years to be "double capacity", said Nicke.

In 2017, national oil and gas production reaches 2.16 million barrel oil equivalent per day (boepd), including Pertamina production around 498 thousand boepd. As per April 2018, national oil and gas production around 2.17 million boepd including Pertamina's production around 774 thousand boepd.

Meanwhile, since last year, information from the Ministry of Energy and Mineral Resources (ESDM) of 12 Working Areas (WK) that terminated its contract or termination has been decided to be transferred to Pertamina.

"12 terminating oil and gas blocks granted to Pertamina since last year's Offshore North West Java (ONWJ) Block in January 2017, Mahakam Block in early 2018, eight termination blocks granted in April 2018 (Central Block, Attaka, East Kalimantan, North Sumatera Offshore, Sanga-Sanga, Southeast Sumatra, Tuban and Ogan Komering) and two 2019 termination blocks given in May 2018 namely Jambi Merang Block and Raja / Pendopo Block, "said Head of Communications, Public Information Services and Cooperation Bureau Personal.

In this case he explained that the government continues to encourage Pertamina as a SOE to become bigger and competitive so as to be able to compete globally. However, it also remains optimal in carrying out the public service function of providing energy evenly in the country.

IN INDONESIA

Pertamina: Blok Terminasi Produksi 36%

PT Pertamina (Persero) menyatakan kontribusi terhadap produksi migas nasional meningkat dari 23% pada tahun 2017 menjadi 36% pada April 2018 setelah kelola blok terminasi. Pelaksana Tugas Direktur Utama Pertamina Nicke Widyawati di Jakarta menyampaikan bahwa pemberian blok terminasi turut meningkatkan kontribusi Pertamina terhadap tingkat produksi migas nasional.

"Dengan tambahan Blok Mahakam kemudian 8 Wilayah Kerja (WK) terminasi yang diberikan, ini penambahannya (kontribusi Pertamina terhadap produksi migas nasional) menjadi sekitar 36%,“ kata Nicke.

Dengan tambahan 2 Wilayah Kerja (WK) lagi (blok terminasi 2019) ,tentu diharapkan dalam dua sampai tiga tahun ke depan ini menjadi "double capacity", kata Nicke.

Pada tahun 2017 produksi migas nasional mencapai sebesar 2,16 juta "barel oil equivalen per day" (boepd) termasuk produksi Pertamina sekitar 498 ribu boepd. Sedangkan per April 2018, produksi migas nasional sekitar 2,17 juta boepd termasuk produksi Pertamina sekitar 774 ribu boepd.

Sementara itu, sejak tahun lalu, informasi dari Kementerian Energi dan Sumber Daya Mineral (ESDM) sebanyak 12 Wilayah Kerja (WK) yang berakhir kontraknya atau terminasi telah diputuskan untuk dialihkelola ke Pertamina.

"12 blok migas terminasi yang telah diberikan ke Pertamina sejak tahun lalu yaitu Blok Offshore North West Java (ONWJ) pada Januari 2017, Blok Mahakam pada awal 2018, delapan blok terminasi yang diberikan April 2018 lalu (Blok Tengah, Attaka, East Kalimantan, North Sumatera Offshore, Sanga-sanga, Southeast Sumatera, Tuban, dan Ogan Komering), dan 2 blok terminasi tahun 2019 yang diberikan Mei 2018 yaitu Blok Jambi Merang dan Blok Raja/Pendopo," kata Kepala Biro Komunikasi, Layanan Informasi Publik dan Kerja Sama Agung Pribadi.

Dalam hal ini ia menjelaskan pemerintah terus mendorong agar Pertamina sebagai BUMN menjadi semakin besardan berdaya Saing sehingga mampu berkompetisi secara global. Namun, juga tetap optimal dalam melaksanakan fungsi pelayanan publik menyediakan energi secara merata di Tanah Air.

Investor Daily, Page-9, Thursday, May 24, 2018