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Abstrak :
Tesis ini membahas tentang analisa menentukan lokasi fasilitas pengolahan gas dari sumur "A, B dan C" di Sulawesi Selatan dengan opsi fasilitas pengolahan gas ditempatkan didekat sumur gas atau mendekati pembeli dengan tujuan mendapatkan biaya investasi yang minimum. Data kedua opsi dianalisa dengan analisa teknoekonomi yang meliputi net present value, internal rate of return dan payback period. Hasil analisa teknoekonomi menunjukkan bahwa Opsi-2 dengan penempatan fasilitas pengolahan gas mendekati pembeli merupakan Opsi yang terbaik dengan biaya investasi US$ 173,199,155.65.

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This thesis discusses an analysis to determine the location of the gas processing facility wells "A, B and C" in South Sulawesi with 2 (two) options to locate gas processing facilities near gas wells or buyer in order to get a minimum cost of investment. Both options data were analyzed by teknoekonomi analysis which include net present value, internal rate of return and payback period. Teknoekonomi analysis results indicate that Option-2 with the placement of the gas processing facilities close to the buyer is the best option with capital cost expenditure of US$ 173,199,155.65.

Abstrak :
ABSTRAK
Struktur pasar gas bumi di Indonesia pada saat ini sedang dalam fase peralihan dari non-kompetitif menuju kompetisi penuh. Pada fase itu, konsep pasar hybrid market yang didalamnya terdapat segmen pasar regulated dan segmen pasar market based dapat diterapkan. Untuk dapat menentukan kategori segmen pada pasar hybrid market perlu dilakukan optimasi nilai harga hub pada pasar gas bumi tersebut yang merupakan trade off antara nilai netback produsen dan social welfare pengguna. Apabila hasil optimasi nilai netback dan social welfare gas bumi terjadi trade off, maka pasar gas bumi di kategorikan sebagai pasar market based, namun apabila tidak maka pasar gas bumi dikategorikan sebagai pasar regulated. Untuk segmen market based, pada titik hub ditentukan ceiling price yang melindungi keekonomian pengguna dan floor price untuk memastikan keekonomian produsen tercapai. Produsen yang masuk kategori regulated umumnya adalah berbasis LNG, sedangkan sektor pengguna yang masuk kategori regulated umumnya adalah pupuk dan listrik. Formula harga gas bumi pada pasar market based ditetapkan menggunakan mekanisme oil price escalation (OPE) yang dikaitkan dengan dinamika harga minyak bumi dimana slope (B1) berada pada rentang 0,08 ? 0,1 untuk semua region pada semua periode

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ABSTRACT
Nowadays, Indonesia?s natural gas market structure has been changing from non-competitive into fully competition market. In this phase, the hybrid market concept which constitute regulated segment and market based segment together in the market is applicable. In order to determine the segment category, it is necessary to find the optimal hub price which is the trade off beetween producer netback value and end user social welfare. If the results of the optimization resulting trade off, then the market is categorized as market based, if not then the market is categorized as a regulated market. In the market based segment, on the hub the ceiling price for protecting the end user economic and floor price for ensure producer economic can be determined. Producers within regulated category generally are LNG based, while the user which is regulated generally are fertilizer and electricity. Gas prices formula on the market are set using a market based mechanism of oil price escalation (OPE), which is associated with the dynamics of oil prices where the slope (B1) is in the range of 0,08 ? 0,1 for all regions in all periods

Abstrak :
Saat ini kebutuhan industry minyak dan gas bumi di Indonesia terhadap pekerja selam (commercial diver) untuk melaksanakan pekerjaan dalam air masih mengacu pada standar internasional. Welding Center (Sub Sea) University of Indonesia (WCSS) didirikan dengan tujuan untuk menghasilkan pekerja selam yang memiliki kualifikasi untuk melaksanakan pekerjaan inpeksi bawah air dengan metoda NonDestructive Testing (NDT). Tujuan dari penelitian ini adalah mencari kesenjangan terhadap kualifikasi yang dimiliki oleh pekerja selam WCSS UI saat ini dengan standar internasional yang diacu untuk pekerjaan inspeksi bawah air dengan metoda NDT dan memberikan rekomendasi perbaikannya. Hasil dari penelitian ini adalah masih ditemukan kesenjangan antara kualifikasi pekerja selam WCSS UI dengan standar internasional yang diacu. Untuk kualifikasi sebagai pekerja selam yaitu memperoleh nilai pemenuhan standar sebesar 70% sedangkan untuk kualifikasi sebagai personel inspeksi NDT bawah air level 3.1U dan 3.2U sebesar 73.33% dan 33.33%. Rekomendasi perbaikan untuk menutup kesenjangan yang ditemui antara lain dari sisi materi latihan dan pelatihan yang sesuai standar, penambahan fasilitas pendukung pelatihan praktek dan tenaga pengajar professional yang tersertifikasi. ...... Today, commercial diver requirements for underwater jobs in Indonesian oil and gas industry are still refer to international standards, such as qualification and certification from well-known international association. Welding Center (Sub Sea) University of Indonesia (WCSS) established to generate qualified and competent commercial diver for underwater NDT inspection jobs. The objectives of this research are to analyze qualifications gap between WCSS UI commercial diver and international standards for underwater NDT inspection jobs. The result shows that WCSS UI commercial diver still has qualifications gaps from international standards. For commercial diving category 70% compliance, for underwater NDT inspector level 3.1U and 3.2U are 73.33% and 30% respectively. Recommendations to improve qualification gaps such as to add training syllabus as per standards, training facilities and last but not least is having real world qualified and certified professional instructors.

Abstrak :
Sistem Ketenagalistrikan Provinsi Aceh dipasok oleh Pembangkit Listrik Tenaga Mesin Gas (PLTMG) berbahan bakar Liquefied Natural Gas (LNG), PLTU Batubara dan PLTD berbahan bakar solar serta transfer dari sistem Sumatera Utara saat beban puncak. Dimana bahan bakar LNG mendapat kiriman dari Kilang Tangguh Papua yang diregasifikasi di Perta Arun Gas, Lhokseumawe Provinsi Aceh, sehingga biaya produksi nya mahal karena jauhnya sumber pasokan gas. Untuk mendapatkan biaya produksi listrik yang lebih murah dapat dilakukan dengan menggunakan potensi gas yang ada di provinsi Aceh. Pada penelitian ini akan menghitung nilai keekonomian dengan membandingkan pemakaian dua jenis bahan bakar gas yaitu bahan bakar gas mulut sumur dan gas LNG untuk pembangkit listrik PLTG dan PLTMG, untuk mengetahui biaya produksi listrik masing-masing pembangkit dengan bahan bakar yang sama. Berdasarkan hasil perhitungan, Pembangkit listrik tenaga mesin gas dengan bahan bakar gas mulut sumur memiliki biaya produksi dengan nilai keekonomian paling baik yaitu 1,231.12 Rp/kWh lebih rendah dari tarif listrik sebesar 1,467 Rp/kWh, serta memiliki IRR sebesar 21,15% dan waktu pengembalian modal 5,54 tahun. Dengan mengetahui nilai yang paling ekonomis untuk pembangunan pembangkit dengan bahan bakar gas mulut sumur maka dapat dijadikan dasar untuk pengambilan kebijakan dalam pemilihan pembangunan pembangkit listrik yang ekonomis untuk daerah dengan potensi gas seperti di provinsi Aceh.

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The Aceh Province Electricity System is supplied by Gas Engine Power Plant (GEPP) fuelled by Liquefied Natural Gas (LNG), Coal-fired power plant and Diesel Engine with Diesel fuel and transfers from the North Sumatra system during peak loads. LNG fuel is sent by ship from the Tangguh Papua Refinery which is regasification in Perta Arun Gas, Lhokseumawe, Aceh Province, so the production costs are expensive due to the distance from the gas supply sources. To get cheaper electricity production costs, it can be done by using the gas potential in Aceh province. In this study, the economic value will be calculated by comparing the use of two types of gas fuel, namely wellhead gas fuel and LNG gas for Gas Turbine and Gas Engine power plants, to determine the cost of electricity production for each power plant with the same fuel. Based on the calculation results, gas engine power plant with fuel from the Wellhead Gas has the best production costs with value of IDR 1,231.12/ kWh lower than the electricity tariff of IDR 1,467 /kWh, and has an IRR of 21,15% and a payback period of 5,54 years. By knowing the most economic value for the construction of power plant with Wellhead Gas, it can be used as a basis for policy making in choosing an economical power plant development for areas with gas potential, such as in Aceh province

Abstrak :
Pengembangan lapangan migas marjinal wilayah lepas pantai pada skema Production Sharing Contract (PSC) gross split memiliki tantangan teknis dan ekonomis. Pada penelitian ini berfokus pada analisis secara ekonomis terhadap pengembangan lapangan migas lepas pantai marjinal. Metode pengembangan lapangan menggunakan tiga skenario yaitu skenario I dengan Konvensional Platform; skenario II dengan Floating Production Storage and Offloading (FPSO); skenario III dengan Sea Moveable Platform (SMP). Analisis ekonomis menggunakan indikator penganggaran modal, seperti NPV, IRR, dan Payback Period. Evaluasi keekonomian dilakukan untuk mencari metode terbaik pengembangan lapangan migas marjinal dengan menerapkan skema PSC Gross Split. Diharapkan dari skenario pengembangan tersebut, mampu meningkatkan keekonomian perusahaan. Selanjutnya dilakukan analisis sensitivitas untuk mengetahui sensitivitas perubahan parameter berikut: biaya kapital (CAPEX), biaya operasi produksi (OPEX), dan harga minyak dan gas berpengaruh terhadap nilai NPV, IRR, dan bagian pemerintah. Hasil penelitian menunjukkan bahwa skenario terbaik adalah Skenario I untuk produksi 7 tahun maupun produksi 10 tahun. Analisis keekonomian menunjukkan bahwa Skenario I dengan waktu produksi 7 tahun memberikan NPV sebesar USD 37,6 juta, IRR sebesar 30,1% dengan Payback Period 3 tahun. Sedangkan untuk waktu produksi 10 tahun diperoleh NPV sebesar USD 35,9 juta, IRR sebesar 25,2% dengan Payback Period 3 tahun. ......The development of marginal oil and gas fields in the offshore area in the gross split Production Sharing Contract (PSC) scheme has technical and economic challenges. This research focuses on economic analysis of the development of marginal offshore oil and gas fields. The field development method uses three scenarios, scenario I with Conventional Platforms; scenario II with Floating Production Storage and Offloading (FPSO); scenario III with Sea Moveable Platform (SMP). The duration of production time uses 7 years and 10 years. Economic analysis uses capital budgeting indicators, such as NPV, IRR, and Payback Period. An economic evaluation was carried out to find the best method for developing marginal oil and gas fields by applying the Gross Split PSC scheme. It is expected from the development scenario, it can improve the companys economy. The sensitivity analysis is then performed to determine the sensitivity of the following parameter changes: capital costs (CAPEX), production operating costs (OPEX), and oil and gas prices affect the value of NPV, IRR and the Government take. The results show that the best scenario is Scenario I both of production time 7 years and 10 years. The economic analysis show that Scenario I with production time 7 years is attributed to NPV of USD 37.6 million, IRR of 30.1% with Payback Period of 3 years. While for production time 10 years, NPV of USD 35.9 million, IRR of 25.2% with Payback Period of 3 years.

Abstrak :
ABSTRAK
ANRI-Indoflesia Company has been facing a problem in selling natural gas to domestic industry due to the Indonesia monetary crisis. ANRI has discovered big gas in several contract areas in Indonesia under Pertamina concession. In addition, ANRI mission is becoming leadership in gas producer in next years. Therefore, a management strategy has to be formulated in order to achieve a sustainable competitive advantage and earnings above average during the Asia economic turmoil condition.

Many customers have bought gas in US dollar contracts to ANRI but currency fluctuation has hurt the customers earning. Furthermore, low purchasing power of people has drastically decreased during crisis. Some firms therefore, such as PLN, have delayed in payment to ANRI.

ANRI has worldwide reputation in upstream and downstream business, especially in Indonesia that ANRI has only focussed in upstream business. Meanwhile, economic gas reserve has been discovered in Irian Jaya, Bali and Java. In addition the ANRI has been facing uncertainties gas market in both domestic and overseas during the crisis. Therefore ANRI-Indonesia is interested for research study.

The research method of the thesis will use two types of research sources:

1. Primary data

Data were collected by survey using a questionnaire form for human resource, SPACE matrix, Internal-External matrix and QSPM.

2. Secondary data

Data were gathered using internal and external data.

The data, consists of general environment, industry environment, competitive environment and internal analysis, is formulated with applying SWOT, SPACE, Grand Strategy and Internal External Matrices. Finally, recommendation for the ANRI strategic management during crisis is divided into three, short-term, medium-term and long term. Short-term strategic management is prioritized on Market Penetration, Market Development, Backward Integration, Retrenchment, 1-lorizontal Integration and Suspended gas development.

Medium-term strategic management is focused on vertical chain alliances in downstream business, Divestiture, Liquidation and Forward Integration.

Long-term strategic management is established on searching new fields. A research weakness of the thesis is not provided equivalence number of energy demand in domestic and overseas. Therefore gas demand in market will not exactly be known how much of domestic and overseas need.

Future studies are suggested to research how much gas demand in domestic and overseas market. Then gas development can be accurately predicted in future, in addition gas price can be negotiated in right profit for sustainable of the business.

Abstrak :
ABSTRAK
Ketahanan energi nasional memberikan dukungan pada kelangsungan pertumbuhan ekonomi Indonesia yang pesat. Salah satu strategi yang direkomendasikan untuk meningkatkan ketahanan energi nasional adalah dengan melakukan diversifikasi energi. Indonesia memiliki cadangan gas yang cukup, namun akibat kurangnya infrastruktur gas maka permintaan domestik masih rendah. Biaya investasi infrastruktur gas cukup tinggi sehingga investor kurang berminat. Lampung memiliki potensi pasokan dan pasar gas yang besar dan kondisi geografis yang mendukung pengembangan jaringan pipa gas. Pemilihan jalur distribusi gas dan spesifikasi pipa yang optimal dapat meminimalkan nilai investasi sehingga dapat menarik minat investor untuk mengembangkan jaringan gas bumi di Lampung. Penelitian ini bertujuan untuk mengoptimasi jaringan distribusi gas bumi di Lampung menggunakan analisis Least Cost Path LCP dan Travelling Saleman Problem TSP untuk memperoleh jalur pipa transmisi dan pipa distribusi optimal. Dari hasil simulasi hidrolika gas didapatkan diameter pipa minimal 4 sampai 14 inch dengan total panjang pipa 209,87 km. Total biaya investasi pembangunan wilayah jaringan distribusi Lampung sebesar 85.137.910 USD dengan kapasitas 129.5 MMscfd. Dengan kondisi tersebut, tarif pengangkutan gas dihitung sebesar 0,9057 USD/Mscf dengan nilai IRR14,85 , NPV 8.129.449 USD, Payback Period 5,46 tahun dengan volume gas yang mengalir 65.23 MMscfd. Probabilitas NPV positif adalah 99,04 . Tarif, volume aliran gas, dan nilai investasi berpengaruh besar terhadap IRR dan NPV. Investasi ini layak dilakukan jika variabel tarif lebih dari 0,8246 USD/Mscf, volume aliran gas terkontrak lebih dari 58,7 MMscfd, atau nilai investasi kurang dari 94.597.677 USD.

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ABSTRACT
Strong national energy security will support Indonesia rsquo s rapid economic growth. To improve national energy security we have to diversify energy. Indonesia has sufficient gas reserves, but due to lack of gas infrastructure, domestic demand is still low. Gas infrastructure investment cost is not feasible for the investor. Lampung has potential supply, large gas market and geographical conditions that support the development of gas pipelines. Optimal gas distribution route and pipeline specifications will minimize the value of investment and support the development of gas distribution pipelines in Lampung. This study aims to optimize natural gas distribution pipeline using Least Cost Path LCP and Travelling Saleman Problem TSP analysis on spatial data to the select optimal paths for transmission pipelines and distribution pipelines. From the gas hydraulic simulation, we obtained 209.87 km long of pipe with diameter range from 4 14 inch. Total investment cost for development of Lampung distribution network area is 85,137,910 USD with capacity of 129.5 MMscfd. Under these conditions, the gas transportation tariff calculated at 0.9057 USD Mscf with IRR14.85 , NPV 8,129,449 USD, Payback Period 5.46 year with 65.23 MMscfd gas flow. The probability of a positive NPV is 99.04 . Tariff, gas volume, and investment cost have a strong effect on IRR and NPV. To be feasible, the tariff should be more than 0.8246 USD Mscf, the contracted gas volume were more than 58.7 MMscfd, or the investment cost were less than 94,597,677 USD.

Abstrak :
Proses distribusi LPG berawal dari pengadaan LPG yang diproduksi mulai dari kilang, selanjutnya di distribusikan ke depot terus SPPBE. Dari SPPBE ini, produk LPG mulai dilakukan pengisian ke tabung (3, 12 dan 50 Kg) yang selanjutnya di salurkan ke agen-agen. Kemudian agen LPG ini mendistribusikan ke sub agen. Mata rantai pendistribusian LPG yang dilakukan berjenjang tersebut perlu diatur secara sistematis dan perlu dilakukan analisa optimasi distribusi dari titik utama suplai sampai mata rantai dibawah-nya untuk mengetahui ke-efektifan dan ke-ekonomian dari sistem distribusi tersebut. Perhitungan optimasi sistem distribusi ini dilakukan menggunakan Solver aplikasi dari microsoft office excel. Dari hasil perhitungan di dapat bahwa untuk mencukupi kebutuhan sampai dengan tahun 2020, perlu dilakukan penambahan tanki penyimpanan di Depot Tanjung Priok dan penambahan unit SPPBE di masing-masing daerah yang menjadi unit operasinya. Penambahan yang perlu dilakukan yaitu 2 unit tanki kapasitas 250 MT dan 2 unit tanki kapasitas 2500 MT. Dengan total biaya pengembangan kapasitas dan biaya operasional dari tahun 2010 sampai dengan tahun 2020 sebesar Rp. 670.35 Milyar. Sedangkan untuk penyediaan SPPBE perlu juga dilakukan penambahan unit SPPBE sebanyak 29 unit yang tersebar di masing-masing daerah yang menjadi daerah penyaluran distribusi LPG dari Depot Tanjung Priok. Dengan total biaya pengembangan unit SPPBE, operasional dan biaya penyaluran dari Depot ke SPPBE dari tahun 2010 sampai dengan tahun 2020 adalah sebesar Rp. 1,007.25 Milyar. ......LPG distribution process begins with the procurement of LPG produced from refinery, subsequently distributed to the depot continued to SPPBE. From this SPPBE, LPG products started filling the tube (3, 12 and 50 Kg) and then distributed to the agents. LPG agency then distributes to the sub-agent. LPG distribution chain which is made by stages needs to be regulated systematically and optimization analysis of the distribution needs to be done from the main point of supply to the underlying chain to determine the effectiveness and economy of the distribution system. Distribution system optimization is done using the Solver application from Microsoft Office Excel. From the calculation results acquired that in order to provide requirement for up to 2020, Tanjung Priok Depot needs to add storage tanks and also needs to add SPPBE units in distribution areas. The additions are 2 units tank with capacity of 250 MT and 2 units tank with capacity of 2500 MT. Total amount that needs to invest (capex&opex) from 2010 up to 2020 is Rp. 670.35 Billion. As for the supply of SPPBE should also be added 29 units in LPG distribution area from Tanjung Priok Depot. The total cost of distribution (capex+opex+transportation cost) from Depot to SPPBE from 2010 up to 2020 is Rp. 1,007.25 Billion.

Abstrak :
Skripsi ini membahas mengenai empat permasalahan. Pertama, mengenai konsep cost recovery pelaksanaan bioremediasi di dalam industri hulu minyak dan gas bumi dalam keuangan negara berdasarkan peraturan perundang-undangan. Kedua, mengenai penerapan konsep cost recovery pelaksanaan bioremediasi di dalam industri hulu minyak dan gas bumi dalam keuangan negara pada Putusan Kasasi Nomor 2330 K/Pid.SUS/2013. Ketiga, mengenai konsep kerugian negara atas cost recovery bioremediasi berdasarkan peraturan perundang-undangan. Keempat, mengenai penerapan konsep kerugian negara atas cost recovery bioremediasi pada Putusan kasasi Nomor 2330 K/Pid.SUS/2013. Berdasarkan hal tersebut, kasus yang tertuang di dalam Putusan Kasasi Nomor 2330 K/Pid.SUS/2013 menjadi objek dalam penelitian skripsi ini. Aparat penegak hukum memutuskan bahwa kasus ini telah merugikan keuangan negara. Namun, ketidak cermatan aparat penegak hukum membuat kasus ini dalam mengidentifikasikan kerugian negara penting untuk diteliti dan dianalisis dengan cermat.

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This Thesis is discussing about four problems. First, it discuss about cost recovery in bioremediation concept in the oil and gas industry based on the positive law. Secondly, it discuss about the concept in bioremediation cost recovery in the oil and gas industry in public finance based on Putusan Kasasi Nomor 2330 K/Pid.SUS/2013. Thirdly, it discuss about the concept of state loss in the bioremediation cost recovery based on the positive law. The last one, it discuss about the concept of state loss in the bioremediation cost recovery based on Putusan Kasasi Nomor 2330 K/Pid.SUS/2013. Based on those things, the case inside Putusan Kasasi Nomor 2330 K/Pid.SUS/2013 will be the object of this thesis. The law enforcer decide that this case has been made some loss for the state. However, the incautious act of law enforcer made this case important to be researched an analyzed further.