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"ABSTRAKKilang LNG Terapung (FLNG) merupakan salah satu solusi yang efektif untukmonetisasi lapangan stranded gas. Pemilihan teknologi dan kapasitas LNGoptimal yang disesuaikan dengan jumlah cadangan gas terbukti, dibutuhkan untukmenghasilkan Pendapatan Negara (GT) yang optimal. Selain itu, denganmempertimbangkan kebutuhan energi dalam negeri yang terus meningkat, makariset ini juga melakukan optimisasi untuk mendapatkan persentase alokasi LNGdan harga LNG untuk domestik. Perhitungan optimisasi pada riset inimenggunakan program Microsoft Excel Solver dengan metode GRG Non-Linier.Pada kasus pengembangan FLNG di Blok Masela, Laut Arafura, Maluku, danasumsi cadangan gas terbukti sebesar 6 TCF, didapatkan Teknologi LNG yangoptimal adalah Single Mixed Refrigerant (SMR) dengan kapasitas optimal sekitar3 MTPA, dan berpotensi menghasilkan Pendapatan Negara (GT) selama masaproduksi 30 tahun sebesar US$ 31,9 Milyar. Hasil ini didapat dengan asumsipersentase optimal LNG untuk domestik sebesar 25% dari bagian gas Kontraktor,dengan harga 50% dari harga ekspor. Upaya lebih lanjut untuk memaksimalkanPenerimaan Negara, sekaligus juga Penerimaan Kontraktor adalah denganmenetapkan harga LNG untuk domestik yang sama dengan harga ekspor. Selainitu, hasil estimasi Biaya Pencairan Gas untuk FLNG adalah sekitar US$ 4 –5/MMBTU.

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ABSTRACTFloating LNG (FLNG) is one of the effective solutions for monetizing strandedgas field. The selection of the optimum technology and capacity of LNG adjustedby proven gas reserves is needed to optimize Government Take (GT). Moreover,with consider domestic energy consumption continues to increase, objective of theresearch is also to obtain optimum LNG allocation for domestic and its price. Theoptimization done by using the Microsoft Excel Solver program with GRG Non-Linear Method.In case of FLNG development in Masela Block, Arafura Sea, Maluku, withassumption of proven gas reserves is 6 TCF, it results the optimum LNGtechnology is Single Mixed Refrigerant (SMR) with optimum capacity isapproximately 3 MTPA, and it potentially generates Government Take (GT)during 30-year production period is US$ 31.9 billion. These results were obtainedwith the assumption that optimum percentage of LNG for domestic is 25% ofContractor’s gas portion with a domestic price of 50% of the export price. Furtherefforts to maximize Government Take, as well as the economics of LNG, is to setthe domestic price equal with the export price. In addition, the estimation resultsfor FLNG Liquefaction Cost is approximately US$ 4 - 5/MMBTU."

"Skripsi ini membahas mengenai sejauh apa negara pantai dapat menerapakan yurisdiksinya terhadap anjungan minyak lepas pantai yang terpancang di landas kontinennya. Penelitian ini berbentuk yuridis-normatif dengan desain deskriptif analitis, yang bertujuan untuk pemahaman lebih lanjut mengenai konsep yurisdiksi negara pantai terhadap anjungan minyak lepas pantai secara komprehensif baik dalam the 1958 Geneva Convention on the Continental Shelf, the 1982 United Convention on the Law of the Sea, dan hukum nasional negara pantai. Berdasarkan analisis yang telah dilakukan dalam kasus Arctic Sunrise (Kingdom of the Netherlands v. Russian Federation), negara pantai dalam menerapkan yurisdiksi pada anjungan minyak lepas pantai di landas kontinennya, tidak dapat diberlakukan sepenuhnya karena sudah berbatasan dengan rezim hukum laut lain yaitu rezim hukum laut lepas.

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The focus of this study is about the extent to which a coastal state may exercise its jurisdiction to offshore oil platforms which fixed on its continental shelf. This normative juridical with analytical descriptive, is aim for the further understanding of the concept of jurisdiction of coastal states to offshore oil platforms comprehensively which regulated in the 1958 Geneva Convention on the Continental Shelf, the 1982 United Convention on the Law of the Sea and the national law of the coastal State. Based on the analysis that has been done in the case of the Arctic Sunrise (the Kingdom of the Netherlands v. Russian Federation), a coastal state in the exercise of its jurisdiction to offshore oil platforms on the continental shelf, can not be fully enforced because it is bordered by the other legal regime of the sea, which is high sea."

"Fokus pada penelitian ini adalah melakukan kajian tekno-ekonomi sistem purifikasi minyaktransformer untuk industri migas lepas pantai. Tantangan yang dihadapi adalah merancangsebuah desain sistem purifikasi yang cocok untuk area operasi yang terbatas, tidakmengganggu operasi (secara online), dan dilakukan tanpa keluar dari pipa / sistemtransformer sesuai dengan regulasi yang berlaku (closed loop). Metodologi yang digunakanpada penelitian ini adalah menggunakan studi literatur penelitian-penelitian sebelumnya,penelusuran pasar, dan data kontrak yang berlaku di industri migas Indonesia. Kajiandiawali dengan melakukan review metode purifikasi yang dapat dilakukan secara onlinedan closed loop terhadap lima (5) metode antara lain: sedimentasi alami, filtrasi, adsorpsi,degassing & dehydration¸dan penambahan zat aditif. Metode-metode purifikasi yangmemenuhi syarat online dan closed loop (yaitu filtrasi, adsorpsi, dan degassing &dehydration) kemudian dikombinasikan menjadi tiga (3) sistem purifikasi dan dievaluasikesesuaiannya terhadap kontaminan. Penelitian ini menyimpulkan bahwa sistem purifikasiyang cocok untuk industri hulu migas lepas pantai Indonesia adalah kombinasi metodefiltrasi (pre-filter dan filter primer) – degassing & dehydration – filtrasi sekunder denganflow rate 10 liter per menit. Sistem yang paling sesuai adalah yang terdiri dari proses prefilterdan filtrasi primer yang memiliki kemampuan penyaringan partikel hinnga 50 mikrondan penurunan tekanan 0,01 MPa, dilanjutkan proses degassing & dehydration beroperasipada tekanan vakum -0,08 MPa gauge dan suhu 65 0C, dan diakhiri dengan filtrasi sekunderdengan spesifikasi filter sama dengan filtrasi pertama. Investasi sistem purifikasi ini cukupmurah dan ekonomis dengan biaya kapital Rp107.305.658,50, nilai IRR 43,33%, NPVRp340.315.914,00, dan payback period selama 2,47 tahun.

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The focus of this research is to conduct techno-economic analysis for investment on

purification system of transformer oil in offshore oil and gas industry. The challenges of the

purification system are the design shall be appropriate for limited space area, no production

disruption (works online), and conducted without discharging from the pipe / transformer

system in accordance with regulations (closed loop). The methodology of this research is

conducting literature study and review to previous researches, market assessment, and

existing contract data which applied in oil & gas industri of Indonesia. The study begins

with a review to purification methods which can be conducted online and closed looply into

five (5) methods which are: natural sedimentation, filtration, adsorption, degassing &

dehydration¸ and the additives. Purification methods that meet the online and closed loop

requirements (which are filtration, adsorption, and degassing & dehydration) are then

combined into three (3) purification systems and evaluated for their contaminant suitability.

This research conclude that the most appropriate purification system is the combination of

filtration (pre-filter & primary filter) – degassing & dehydration – filtration methods with

flow rate 10 liters per minute. The most appropriate system is consisting of pre-filter and

primary filtration process which can filter the partikel up to 50 microns with drop pressure

0.01 MPa, followed by degassing & dehydration process which operated at pressure -0.08

MPa gauge and temperature 65 0C, and finalized by secondary filtration process with the

same specification with primary filter. The purification system investment is quite cheap

and economical with capital expenditure Rp107.305.658,50, IRR value 43,33%, NPV

Rp340.315.914,00, and payback period 2,47 years."

"ABSTRAKKeselamatan dari bahaya arc flash telah menjadi persyaratan dalam pengoperasiansuatu instalasi listrik di lapangan migas lepas pantai. Kejadian arc flash tidak hanyamengancam keselamatan pekerja dan fasilitas tersebut tetapi juga bisa mengakibatkankegagalan produksi yang sangat mahal. Salah satu cara untuk mengurangi bahaya arc flashini ialah menurunkan trip setting alat proteksi sehingga alat proteksi bisa berkerja secepatmungkin untuk menghilangkan kejadian arc flash. Namun penurunan trip setting alat proteksiini harus optimal sehingga tetap bisa menjamin kehandalan alat proteksi terhadap ganguan,selain juga bisa mengurangi energi arc flash. Pada penelitian ini dilakukan analisispengurangan energi arc flash dengan mengoptimasi koordinasi alat proteksi pada instalasilistrik di lapangan ABC, sebuah lapangan migas lepas pantai di Laut Natuna. Hasil analisismemperlihatkan energi arc flash system bisa dikurangi sampai batas yang diperbolehkantanpa mengorbankan kehandalan alat proteksi terhadap gangguan. Pada bagian akhirdipaparkan analisis ekonomi yang memperlihatkan pengurangan energi arc flash denganoptimasi koordinasi alat proteksi di lapangan migas ABC dapat diterima secara bisnis karenamemberikan keuntungan yaitu mengurangi biaya tidak tetap akibat kejadian arc flash denganNPV (Net Present Value) sebesar USD 675.932.

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ABSTRACTElectrical safety from arc flash hazard has become requirement for operation of anoffshore oil platform. During it?s operation, arc flash is always become potential hazard thatnot only threaten personal and facility safety, but also can cause very expensive productionloss. One solution to reduce arc flash hazard is reducing protection device trip setting tomake it working faster to isolate fault. But reducing protection devices shall be optimum thatit shall be able to maintain reliability from inadvertant trip as well as reducing arc flashenergy. In this research, analysis of arc flash reduction by optimizing protection devicecoordination will be conducted at electrical instalation in field ABC, offshore oil platform inLaut Natuna. Study result shows optimizing protection device setting can reduce arc flashincident energy till meet allowable limit without sacrifice realiability of power supply. At theend, economical analysis is also carried out that shows above investment can be accepted dueto give benefit for preventing loss due to arc flash equivalent with cost NPV (Net PresentValue) USD 675.932."

"[ABSTRAKPengembangan lapangan gas laut dalam memiliki tantangan teknis, terkait fasilitasproduksi dan teknologi untuk dapat memproduksikan migas pada kondisilingkungan yang ekstrem. Disamping itu, biaya yang diperlukan lebih besardibandingkan pengembangan lapangan laut dangkal. Dalam penelitian inidilakukan analisa secara teknis dan ekonomis terhadap pengembangan lapangangas laut dalam di Selat Makasar dengan metode subsea tieback, denganmemanfaatkan kapasitas tersedia dari floating production unit (FPU) yang sudahada. Analisa teknis meliputi penentuan ukuran pipa (flowline) optimal, yang dapatmemenuhi target deliverabilitas gas, memenuhi kriteria teknis lainnya, sertaanalisa flow assurance, khususnya mitigasi hidrat untuk menjaminkeberlangsungan aliran fluida dari sumur bawah laut hingga ke titik jual. Darianalisa teknis akan didapatkan beberapa konfigurasi ukuran pipa dan mitigasihidrat. Analisa ekonomi meliputi perhitungan biaya investasi untuk setiap opsiyang memenuhi kriteria teknis, kemudian dilanjutkan penghitungan parameterkeekonomian berdasarkan aturan Production Sharing Contract (PSC) yangberlaku di Indonesia. Dengan harga gas 6 US$/mmbtu, didapatkan nilaiGovernment Take (GT) 609 juta US$ dan Internal rate of Return (IRR) 15.13%.Sensitivitas analisis dilakukan dengan variasi harga jual gas dan mengubahbesaran kontraktor split untuk meningkatkan IRR sehingga dapat mencapai nilaiyang masih dapat diterima dari sisi Kontraktor. Untuk mendapatkan IRR yanglebih besar dari 20%, diperlukan kontraktor split sebesar 48%. Hasil analisakeekonomian dapat menjadi pertimbangan dalam penentuan besaran kontraktorsplit untuk pengembangan lapangan gas laut dalam.

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ABSTRACTDeepwater gas field development has technical challenges, related to productionfacilities and technology that can be used for producing oil and gas in the extremeambient conditions. The required cost is also higher than shallow water. Thisresearch analyzed technical and economical aspect of deepwater gas fielddevelopment at Makasar Strait using subsea tieback method, which utilize theavailable capacity from existing Floating Production Unit (FPU). Technicalanalysis include selection the optimum flowline size, which meet the gasdeliverability and other criteria as well. It also cover the flow assurance analysis,particularly hydrate mitigation, to ensure the flow continuity of oil and gas fromsubsea well to the sales point. Economic analysis include the calculation ofinvestment cost on each option that meet the technical criteria above. Thencontinued with calculation of economic parameter based on applicable IndonesiaProduction Sharing Contract (PSC) scheme. With gas price of 6 US$/mmbtu, willgive Government Take (GT) of 609 million US$ and Internal rate of Return(IRR) 15.13%. Sensitivity analysis has been done by varrying the gas sale priceand changing the percentage of contractor split to increase the IRR to meet thevalue that still acceptable from Contractor side. Contractor split of 48% isrequired to achieve IRR higher than 20%. This economic analysis result couldbecome a consideration in defining the percentage of Contractor Split fordeepwater gas development.;Deepwater gas field development has technical challenges, related to productionfacilities and technology that can be used for producing oil and gas in the extremeambient conditions. The required cost is also higher than shallow water. Thisresearch analyzed technical and economical aspect of deepwater gas fielddevelopment at Makasar Strait using subsea tieback method, which utilize theavailable capacity from existing Floating Production Unit (FPU). Technicalanalysis include selection the optimum flowline size, which meet the gasdeliverability and other criteria as well. It also cover the flow assurance analysis,particularly hydrate mitigation, to ensure the flow continuity of oil and gas fromsubsea well to the sales point. Economic analysis include the calculation ofinvestment cost on each option that meet the technical criteria above. Thencontinued with calculation of economic parameter based on applicable IndonesiaProduction Sharing Contract (PSC) scheme. With gas price of 6 US$/mmbtu, willgive Government Take (GT) of 609 million US$ and Internal rate of Return(IRR) 15.13%. Sensitivity analysis has been done by varrying the gas sale priceand changing the percentage of contractor split to increase the IRR to meet thevalue that still acceptable from Contractor side. Contractor split of 48% isrequired to achieve IRR higher than 20%. This economic analysis result couldbecome a consideration in defining the percentage of Contractor Split fordeepwater gas development., Deepwater gas field development has technical challenges, related to productionfacilities and technology that can be used for producing oil and gas in the extremeambient conditions. The required cost is also higher than shallow water. Thisresearch analyzed technical and economical aspect of deepwater gas fielddevelopment at Makasar Strait using subsea tieback method, which utilize theavailable capacity from existing Floating Production Unit (FPU). Technicalanalysis include selection the optimum flowline size, which meet the gasdeliverability and other criteria as well. It also cover the flow assurance analysis,particularly hydrate mitigation, to ensure the flow continuity of oil and gas fromsubsea well to the sales point. Economic analysis include the calculation ofinvestment cost on each option that meet the technical criteria above. Thencontinued with calculation of economic parameter based on applicable IndonesiaProduction Sharing Contract (PSC) scheme. With gas price of 6 US$/mmbtu, willgive Government Take (GT) of 609 million US$ and Internal rate of Return(IRR) 15.13%. Sensitivity analysis has been done by varrying the gas sale priceand changing the percentage of contractor split to increase the IRR to meet thevalue that still acceptable from Contractor side. Contractor split of 48% isrequired to achieve IRR higher than 20%. This economic analysis result couldbecome a consideration in defining the percentage of Contractor Split fordeepwater gas development.]"

"Perkembangan teknologi bidang kelautan semakin pesat seiring dengan kebutuhan zaman. Aktivitas eksploitasi sektor migas sudah merambah pada wilayah Deep Water sampai Ultra Deep Water. Namun pada realitasnya Indonesia belum mampu berperan aktif dalam pengembangan teknologi Mobile Offshore Platform Unit yang biasa digunakan untuk eksploitasi migas pada wilayah diatas. Hal ini dapat dilihat dari jenis anjungan yang digunakan pada eksploitasi migas lepas pantai masih banyak menggunakan struktur fixed platform dan lokasi eksploitasi masih terbatas pada wilayah perairan dangkal. Padahal Indonesia memiliki luas wilayah laut yang cukup besar, penggarapan cadangan migas pada wilayah perairan laut dalam harus mulai dilakukan, seperti di perairan Laut Arafura blok Masela yang diprediksi memiliki potensi gas alam hingga 20 tcf (trilion cubic feet) dan cadangan minyak bumi sebesar 24,36 mmstb (million stock tank barrels). Pada penelitian ini dilakukan studi kasus perancangan sebuah anjungan semi-submersible yang berfungsi sebagai Production Platform Unit yang digunakan pada eksploitasi migas di blok Masela, Laut Arafura. Rancangan tersebut dilengkapi dengan sistem pemosisian dinamik (dynamic positioning system) yang diuji pada skala model. Hasil dari eksperimen pada model uji tersebut digunakan untuk mengetahui tingkat akurasi dari penerapan sistem kontrol posisi Inertial Measurement Unit dan sensor ultrasonik terhadap beban lingkungan.

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Technology development in marine sector has a rapid development in line with the needs of the era. The exploitation activity of oil and gas sector has been expanded to the deep sea area until ultra deep sea area. Whereas in reality, Indonesia is unable to contribute actively in the technology development of Mobile Offshore Platform Unit which used for oil and gas exploitation in those area. It can be seen on the fact that the exploitation of offshore oil and gas still use fixed structure and the location of platform exploitation still limited to the shallow water areas. While Indonesia has a large sea area, the cultivation of oil and gas reserves in the sea area should begin to planned carefully, as in the Arafura Sea Masela block which was predicted have potential of natural gas reach out 20 tcf (trilion cubic feet), the petroleum reserves by 24, 36 MMSTB (million stock tank barrels). In this study, there is a study case of semi-submersible rig design that serves as a Production Platform unit used in oil and gas exploitation in the Masela Block, the Arafura Sea. The design is completed with a dynamic positioning system (DPS) which has been tested at scale models. Results of experiments on the test model is used to determine the accuracy of the application of a simple position control system that is using The Measurement Inertial Unit and ultrasonic sensors on the environment resistance."

"Sebagai salah satu negara anggota OPEC, di Indonesia banyak dilaksanakan proyek-proyek pembangunan fasilitas penunjang terhadap kegiatanpertambangan minyak dan gas bumi. Pengembangan fasilitas tersebut dimulai dari tahap perancangan engineering, fabrikasi & pengadaan, dan konstruksi & instalasi. Sebagai tahapan yang paling akhir dari sebuah pembangunan fasilitas,tahap konstruksi & instalasi memiliki resiko keterlambatan paling tinggi dalampelaksanaannya. Hal ini dipengaruhi oleh besarnya keterkaitan pekerjaan denganpihak diluar perusahaan. Kondisi ini mendorong penulis untuk dapatmengidentifikasi faktor-faktor dominan yang berpengaruh. Dengan teridentifikasinya faktor-faktor dominan tersebut dan dilakukannya langkahlangkah antisipasinya, diharapkan dapat mencegah keterlambatan pelaksanaan proyek konstruksi & instalasi tersebut

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As one of OPEC’s member, there are so many facilities development projects to support oil & gas mining activities in Indonesia. The development project is started from engineering design phase, to procurement and fabrication

phase, and ended by construction and installation phase. As the last phase, construction & installation, has more risks related to time performance during the execution. These things affected by big corelation between the contractor and other outside parties. Such condition motivate writer to identify the dominant factors. By identifying these factors and take responses

on them, delays on construction and installation performance will be avoided."

"Penelitian ini membahas mengenai implementasi asas cabotage dalam hukum positif Indonesia terhadap kapal penunjang Migas (Migas) atau anjungan Migas yang beroperasi di wilayah lepas pantai yang termasuk dalam wilayah laut zona ekonomi ekslusif (ZEE) maupun landas kontinen dimana ketentuan hukum internasional berlaku, kesesuainnya dengan ketentuan WTO yaitu ketentuan General Agreement on Trade In Services (GATS) dan schedule of commitment Indonesia. Penelitian ini menggunakan metode pendekatan yuridis normatif yang di dukung oleh penelitian empiris. Dengan rumusan pengertian kapal yang meliputi juga floating platforms di lepas pantai (dalam hal ini termasuk rig-rig, anjungan Migas lepas pantai) sepanjang berada dalam yuridiksi dan kedaulatan Indonesia yaitu berada di laut teritorial Indonesia beserta perairan kepulauan dan perairan pedalaman maka asas cabotage berlaku terhadap kapal dan floating platforms tersebut. Sedangkan menurut hukum positif Iindonesia asas cabotage tidak berlaku di landas kontinen dan ZEE namun dalam pelaksanaannya berlaku karena dalam operasional tersebut harus melalui Pelabuhan, laut teritorial, perairan kepulauan dan perairan pedalaman. Implementasi asas cabotage belum dapat dilaksanakan sepenuhnya karena pemerintah masih memberikan dispensasi terhadap penggunaan kapal asing untuk usaha Migas lepas pantai melalui Permenhub No.46 Tahun 2019, namun peraturan ini secara substansi tidak sejalan atau bertentangan dengan asas hukum lex superior derogate legi inferiori. Pengaturan asas cabotage merupakan bagian dari prinsip yang diatur dalam GATS tentang domestic regulation, dan WTO tetap mengakui eksistensi kedaulatan negara anggotanya. Hasil penelitian menyarankan perlu menyempurnakan hukum positif Indonesia sebagai peraturan domestik untuk menyesuaikan dengan perkembangan liberalisasi jasa angkutan laut khususnya penggunaan kapal asing untuk menunjang usaha Migas lepas pantai di Indonesia dan memberikan kelonggaran bagi armada angkutan laut asing pada kegiatan Migas lepas pantai.

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This focus of this study is assesed implementation of the cabotage principle in Indonesian positive law to offshore oil and gas supporting vessels or oil and gas platforms operating in offshore areas that are included in the exclusive economic zone (EEZ) sea area or the continental shelf where international law provisions apply, the compliance with WTO provisions namely the provisions of the General Agreement on Trade in Services (GATS) and Indonesias schedule of commitment. This research applies a normative juridical approach which is supported by empirical research. With the formulation of the definition of a vessel which includes offshore floating platforms (in this case including rigs, offshore oil and gas platforms) as long as it is within the jurisdiction and sovereignty of Indonesia, which are in the territorial sea of Indonesia, archipelagic waters and inland waters, the cabotage principle applies to vessel and floating platforms. Meanwhile, according to positive Indonesian law the cabotage principle does not apply to vessel and floating platforms on the continental shelf and EEZ, but in practice the cabotage principle also applies because vessel and floating platforms in these operations must go through ports, territorial seas, archipelagic waters and inland waters. Implementation of the cabotage principle cannot yet be fully implemented because the government is still giving dispensation for the use of foreign vessel for offshore oil and gas business through Permenhub No.46 of 2019, but this regulation is substantially not in line with or against the legal principle of the lex superior derogate legi inferiori. Implementation of the cabotage principle is part of the principles that is regulated in GATS regarding domestic regulation, and the WTO continues to recognize the existence of the sovereignty of its member countries. The results suggest that it is necessary to improve Indonesias positive law as a domestic regulation to adjust to the development of liberalization of sea transportation services, especially the use of foreign vessels to support offshore oil and gas businesses in Indonesia and to provide leeway for foreign marine transportation fleets in offshore activities."

"ABBSTRAKEvaluasi pasca operasi dari suatu proyek atau pabrik dilakukan untuk melihat ke belakang apakah suatu proyek yang sudah berjalan benar-benar menguntungkan atau tidak, untuk mendapatkan informasi yang berguna bagi manajemen dalam membuat keputusan-keputusan di masa datang. Seringkali evaluasi ini juga dilakukan untuk mendukung pengembangan bisnis yang sedang berjalan, dengan menunjukkan betapa untungnya investasi proyek itu dulu dilakukan.Kilang ekstraksi LPG di kilang LNG "Bravo", yang dibangun dengan investasi sekitar US$ 160 juta pada tahun 1986, adalah salah satu proyek PERTAMINA yang sudah beroperasi dan menghasilkan devisa bagi negara dan produk LPG-nya sejak tahun 1988. Proyek ini dibangun di kilang LNG "Bravo" untuk memperoleh devisa tambahan selain devisa dari produk utamanya yaitu LNG. Proyek ini dievaluasi terutama untuk melihat prospeknya sepuluh tahun mendatang (periode 1999 - 2008).Dengan memperhatikan data historis dari variabel pemasaran, khususnya harga dan volume penjualan selama sepuluh tahun terakhir (1988 - 1997) dari pengoperasian kilang ekstraksi LPG ini, evaluasi dengan membandingkan antara NPV dari pendapatan tambahan yang diperoleh dari penjualan LPG dengan pendapatan tambahan dari penjualan LNG excess (bib kilang ekstraksi LPG ini dihentikan) untuk periode 1999 - 2008, menunjukkan bahwa kilang ekstraksi LPG ini masih lebih ekonomis untuk dilanjutkan pengoperasiannya dari pada dihentikan.

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ABSTRACT

Post-installation evaluation of any project or process plant is conducted to look back whether the running project is really profitable or not, to gain some information needed by management for further decisions in the future. Sometimes this evaluation is also conducted to support the expansion of the running project or business, by showing how profitable this project was developed in the past.

LPG extraction plant in "Bravo" LNG plant was built in 1986, with investment around US$ 160 million. It is one of PERTAMINA's project which has been operated and gave revenue for Indonesia from its product , LPG, since 1988. This facilities was built in `Bravo' LNG plant in order to get additional revenue besides revenue from its main product, LNG. The project is evaluated mainly to see its prospect in the next ten years (1999 - 2008 period).

By considering to historical data of marketing variables, such as price and sales volume during last ten years (1988 - 1997) of commercial operation of this LPG extraction plant, evaluation which is made by comparing the NPV of additional revenue from LPG sales to the NPV of additional revenue from sales of excess LNG (due to termination of LPG extraction plant) of 1999- 2008 period shows that this LPG plant is still profitable to continue its operation rather than shut it down."