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"Shale hidrokarbon masih menjadi salah satu topik hangat dalam industri perminyakan. Indonesia memiliki potensi shale gas yang cukup besar yaitu sekitar 574 TCF. Pemerintah bersama investor sedang memulai pengusahaan shale hidrokarbon. Parameter-parameter geokimia dan geomekanik merupakan aspek penting dalam eksplorasi potensi shale hidrokarbon dan memberikan informasi penting dalam rangka optimasi produksi. Namun demikian, masih cukup terbatas penelitian-penelitian terkait hubungan parameter-parameter petrofisik untuk shale hidrokarbon. Area penelitian berada pada bagian tepi selatan cekungan Sumatera Utara. Formasi Baong dipercaya sebagai target pengusahaan shale hidrokarbon dengan dominan litologi adalah shale. Formasi Baong berada pada kisaran kedalaman 1.465 ndash;3.224 m dengan mudstone tebal, didominasi oleh calcareous shale berwarna abu-abu coklat hingga hitam yang kaya foraminifera, mengindikasikan pengendapan pada lingkungan laut. Umur Formasi Baong bervariasi dari Miocen Bawah hingga Miocen Tengah dan secara vertikal dapat diklasifikasikan menjadi 3 unit, yaitu : Baong Bagian Atas, Baong Bagian Tengah dan Baong Bagian Bawah yang didominasi oleh shale. Penelitian ini bertujuan untuk mengidentifikasi potesni shale hidrokarbon dengan menganalisa Total Organic Carbon TOC , Brittleness Index BI , Hydrogen Index HI dan parameter-parameter kematangan. Berbagai metode dilakukan untuk menganalisa beberapa parameter tersebut, diantaranya dengan geokimia, mineralogi, petrofisik, cross plotting, dan interpretasi seismik. Hasil analisa Rock-Eval dan petrografi menunjukkan bahwa TOC bervariasi antara 0,1 ndash;2,3 , vitrinite reflectance Ro berkisar 0,4 ndash;0,9, HI bervariasi antara 31 ndash;171 dan temperatur maksimum Tmax berkisar antara 432 ndash;461oC. TOC menunjukkan kategori cukup hingga baik. Crossplot antara HI dan Tmax pada diagram van Krevelen menunjukkan dominasi kerogen tipe II dan III. Kerogen dapat diklasifikasikan sebagai early mature hingga mature. BI pada shale termasuk pada kategori less brittle hingga brittle. Area prospektif untuk pengembangan shale hidrokarbon yaitu pada sekuen MFS-2, MFS-3, SB-2 dan SB-3 dengan potensi berupa shale oil.

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Shale hydrocarbon remains one of the hot topics in the petroleum industry. Indonesia has a great potential shale gas resource 574 TCF , and both government and oil companies have promoted the development of shale gas. Geochemical and geomechanical parameters are important aspects for exploring new shale gas play, and it provides significant information to optimize production plan and stimulation design. However, there is limited research on correlations inter petrophysical parameters for shale hydrocarbon reservoirs. The study area is located on the southeast border of the North Sumatra Basin. Lower Baong Formation shales are believed to be favorable shale gas targets with a dominant shale lithology. The Baong Formation occurs at depths from 1.465 ndash 3.224 m in the study area with the thick mudstone, dominated by gray, brown to black calcareous shale rich in foraminifera, indicating a marine environment. The Baong Formation age varies from the Lower Miocene to Middle Miocene can split into three vertical units the Upper Baong, Middle Baong, and the dominantly shale Lower Baong. This research is aimed to characterize and identify shale hydrocarbon by examining the Total Organic Carbon TOC , Brittleness Index BI , Hydrogen Index HI and maturity parameters. Various methods were used to analyze these parameters, including geochemistry, mineralogy, petrophysics, cross plotting, and seismic interpretation. Our analysis on Rock Eval and petrographic data shows that TOC varies between 0.1 ndash 2.3 , vitrinite reflectance of 0.4 ndash 0.9 , HI varies from 31 ndash 171, and maximum temperature Tmax from 432 ndash 461oC. TOC resulted in a poor to good category. A cross plot of the HI and Tmax in the van Krevelen diagram revealed the dominant kerogen types as II and III. The kerogen can be considered as early mature to mature. The BI of the shale formation of the research area is categorized in less brittle to brittle. The prospective areas for the development of shale hydrocarbon are the sequences of MFS 2, MFS 3, SB 2 and SB 3 with the potential of shale oil."

"A detailed combined geological and geophysical study in North Sumatra basin has shown that prospective formations for shale play containing gas sweet spots are found to be shales from Bampo, Belumai, and Baong Formations. Bampo Formations Exhibits low shale gas potential with very low to medium in organic material contents, maturity index of immature to mature, and moderate brittleness. Rocks within the formation tent to be reactive to highly reactive to water, with a moderate degree of swelling capacity. Porosity varies within 5.8-7.4% with permeability raging from 0.37 to 3.2 mD. Sweet spots in the formation found around Basilam-l and Securai-l wells occupy about 21% of the formation. On the other hand, Belumai Formation shows moderate to good shale gas potential, with low to high organic material contents, immature to mature levels of maturity, and moderately brittle to brittle. Sweet spots areas in the formation fpund around the two wells are about 29% of the formation. For Baong Formation, analysis reveals moderate to good shale gas potential, with low to medium contents of organic material, immature to mature in maturity index, moderately brittle to brittle in brittleness, and tendency of being reactive to highly reactive to water but with low degree of swelling capacity. Sweet spots in the formation found around two wells occupies are roughly 11% of the total formation volume in the area. Basin modeling leading to gas resources estimation for Baong, Belumai, and Bampo Formations has led to estimated volumes of 6, 379 TCF, 16, 994 TCF, and 25,024 TCF, respectively, with a total amount of 48, 397 TCF. The resources figures are speculative in nature and do not incorporate any certainty and efficiency factors."

"Oil Shale merupakan salah satu bahan bakar non konvensional berbentuk sedimen batuan halus, yang dapat menjadi sumber energi alternatif. Dalam proses retorting, Oil Shale dapat dikonversi menjadi shale oil dan shale gas. Sebelumnya, terdapat beberapa penelitian yang membahas potensi shale gas untuk memproduksi gas hidrogen. Pada penelitian ini, dilakukan pemodelan sistem menggunakan Aspen Plus untuk mengetahui potensi pemanfaatan keseluruhan shale oil beserta shale gas hasil dari retorting untuk memproduksi hidrogen menggunakan teknologi chemical looping. Selain itu, penelitian ini bertujuan untuk mengetahui efisiensi energi dari sistem apabila meneruskan tahapan produksi hidrogen hingga ke tahap produksi ammonia untuk penyimpanan. Berdasarkan hasil simulasi, produk retorting dari 0,126 kg/s bahan baku oil shale komposisi New Albany, yaitu 0,0063 kg/s shale oil dan 0,0024 kg/s shale gas, dapat memproduksi hidrogen sebanyak 0,0037 kg/s. Hidrogen ini dapat dikonversi menjadi ammonia sebanyak 0,012 kg/s dengan sisa hidrogen sebanyak 0,00089kg/s. Berdasarkan analisis energi, didapatkan efisiensi dari keseluruhan proses oil shale retorting hingga produksi ammonia adalah sebesar 55%.

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Oil shale is one of the non-conventional fuel in the form of fine rock sediments, which can be utilized as an alternative energy resource. In the retorting process, Oil Shale is converted into shale oil and shale gas. Previously, there were several studies that discussed the potential utilization of the shale gas product to produce hydrogen gas. In this study, a simulation was carried out using Aspen Plus to determine the potential of using both shale oil and shale gas products from the retorting process, to produce hydrogen using a chemical looping system. In addition, this study is aimed at analysing the energy efficiency of the system with the additional process of converting hydrogen into ammonia for storage. Based on the simulation results, the retorting product from 0,126 kg/s of oil shale, respectively 0,0063 kg/s and 0,024 kg/s of shale oil and shale gas, could produce 0,0031 kg/s of hydrogen. This amount of hydrogen could be converted into 0,012 kg/s of ammonia, with a remaining hydrogen product of 0,00089 kg/s. Based on the energy analysis, the efficiency of the entire system from the oil shale retorting process up to the ammonia production is 55%."

"[Saat ini, jumlah kandungan minyak dan gas konvensional yang tersedia semakin terbatas sedangkan cadangan semakin rendah. Oleh karena itu diperlukan eksplorasi akan sumber daya baru, salah satu solusinya adalah dengan memperluas eksplorasi hidrokarbon dengan cara konvensional maupun unconvensional, dan untuk mengurangi tingginya kegagalan dalam tahapan eksplorasi ini maka diperlukan pembelajaran petroleum system terutama source rock. Source rock yang memiliki potensi tinggi harus mempunyai kandungan kerogen yang cukup untuk dapat mengenerateminyak maupun gas ke perangkap-perangkap hidrokarbon disekitarnya.Dalam penelitian ini memaparkan aplikasi metode Passey dan untuk memetakan source rock dengan kandungan TOC yang berbeda-beda di setiap kedalaman dan responnya pada seismik inversi, kemudian dihitung potensinya sehingga didapat peta penyebaran source rock dan total hidrokarbon yang sudah tergenerate ke perangkap-perangkap struktur maupun yang masih tersisa di dalam source rock itu sendiri.Penelitian ini pun mengintegrasikan data geokimia, analisa petrofisika, dan teknik seismik inversi dalam mengkarakterisasi zona yang berpotensi. Tahapan awal eksplorasi dalam penentuan sweetspot adalah dengan menggunakan metode passey untuk menghasilkan data log pseudo TOC. Kedua, melakukan analisa petrofisika untuk mendapatkan parameter fisis yang sensitif pada formasi target.Ketiga adalah dengan mengaplikasikan seismik inversi Impedansi akustik (AI) untuk mengetahui persebaran batuserpih yang mengandung potensi gas berdasarkan nilai TOC dan parameter fisis yang sensitif pada formasi target.Keempat melakukan penghitungan sumber daya yang sudah tergenerate dan yang masih tersisa dalam tubuh shale sebagai source rock;Currently, the amount of available conventional gas and oil content are more limited while the amount of reserves has been decreased. Therefore we need an exploration of new resources, one solution is to expand the exploration of hydrocarbons by means of conventional or unconvensional, and to reduce the high failure in the exploration phase of the learning required for this petroleum system primarily source rock. Source rock that has high potential must have a sufficient content of kerogen to oil or gas can be generate to the hydrocarbon traps nearby. In this research exposes Passey Method and application method to map the source rock TOC content varies with each depth and seismic inversion, the response was then calculated its potential so obtained a map of the spread of source rock and hydrocarbon that already total generated to structures trap as well as those still remaining in the source rock itself. In this study integrates geochemical data, analysis of petrophysic, and seismic inversion technique to characterize potential zones. Early stages of exploration in the determination of sweetspot is using Passey Method to generate pseudo TOC. Second, petrophysical analysis to obtain physical parameters that are sensitive to the target formation. Third is by applying accustic impedance seismic inversion to determine the distribution of shale rock that contain gas potential based on the value of TOC and physical parameters that are sensitive to the target formation. Fourth do calculating resources have generated and remaining in a shale as source rock;Currently, the amount of available conventional gas and oil content are more limited while the amount of reserves has been decreased. Therefore we need an exploration of new resources, one solution is to expand the exploration of hydrocarbons by means of conventional or unconvensional, and to reduce the high failure in the exploration phase of the learning required for this petroleum system primarily source rock. Source rock that has high potential must have a sufficient content of kerogen to oil or gas can be generate to the hydrocarbon traps nearby. In this research exposes Passey Method and application method to map the source rock TOC content varies with each depth and seismic inversion, the response was then calculated its potential so obtained a map of the spread of source rock and hydrocarbon that already total generated to structures trap as well as those still remaining in the source rock itself. In this study integrates geochemical data, analysis of petrophysic, and seismic inversion technique to characterize potential zones. Early stages of exploration in the determination of sweetspot is using Passey Method to generate pseudo TOC. Second, petrophysical analysis to obtain physical parameters that are sensitive to the target formation. Third is by applying accustic impedance seismic inversion to determine the distribution of shale rock that contain gas potential based on the value of TOC and physical parameters that are sensitive to the target formation. Fourth do calculating resources have generated and remaining in a shale as source rock, Currently, the amount of available conventional gas and oil content are more limited while the amount of reserves has been decreased. Therefore we need an exploration of new resources, one solution is to expand the exploration of hydrocarbons by means of conventional or unconvensional, and to reduce the high failure in the exploration phase of the learning required for this petroleum system primarily source rock. Source rock that has high potential must have a sufficient content of kerogen to oil or gas can be generate to the hydrocarbon traps nearby. In this research exposes Passey Method and application method to map the source rock TOC content varies with each depth and seismic inversion, the response was then calculated its potential so obtained a map of the spread of source rock and hydrocarbon that already total generated to structures trap as well as those still remaining in the source rock itself. In this study integrates geochemical data, analysis of petrophysic, and seismic inversion technique to characterize potential zones. Early stages of exploration in the determination of sweetspot is using Passey Method to generate pseudo TOC. Second, petrophysical analysis to obtain physical parameters that are sensitive to the target formation. Third is by applying accustic impedance seismic inversion to determine the distribution of shale rock that contain gas potential based on the value of TOC and physical parameters that are sensitive to the target formation. Fourth do calculating resources have generated and remaining in a shale as source rock]"

"Penelitian ini melakukan identifikasi lapisan shale gas menggunakan Inversi Impedansi Akustik dan Dekomposisi Spektral. Penelitian dilakukan di Lapangan "AP", Cekungan Barito dan formasi target yaitu Formasi Tanjung. Nilai Total Organic Carbon (TOC) ditentukan dengan menggunakan Passey's Number dan data geokimia. Selanjutnya, zona shale gas ditentukan dengan mengorelasikan Log Gamma-ray dengan Log Densitas, Sonic, NPHI, dan Resistivitas pada dua sumur. Hasil korelasi menunjukkan terdapat zona shale gas pada masing-masing sumur, yaitu dikedalaman 7130-7370 ft (Sumur A-1) dan 3100-3280 ft (Sumur P-1). Zona shale gas Sumur A-1 dan Sumur P-1 memiliki TOC rata-rata 5.4 wt% dan 2.8 wt%. Hasil tersebut didukung oleh hasil inversi impedansi akustik (AI) yang menujukkan nilai impedansi rendah untuk zona shale gas antara 5000-8000 m/s*g/cc (Line A-1), dan 7200-8900 m/s*g/cc (Line P-1). Selain itu, hasil tersebut juga didukung oleh hasil dekomposisi spektral yang menunjukkan anomali Continuous Wavelet Transform (CWT) tinggi pada frekuensi 18 Hz (untuk Line A-1) dan 20 Hz (untuk Line P-1). Analisis terintegrasi antara data seismik, hasil inversi AI dan CWT menunjukkan terdapat daerah potensial shale gas pada punggungan antilkin di Line A-1 dan Line P-1.

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This study identify shale gas layer using acoustic impedance (AI) and spectral decomposition. The object of this study is Field ‘AP’, Barito Basin, and the formation target is Tanjung Formation. Total Organic Carbon (TOC) values was determined using Passey’s Number and geochemical data. Furthermore, shale gas zone was determined by correlating Gamma-ray log with Density, Sonic, NPHI and Resistivity log in two wells.

Correlation result showed there are a shale gas zone in each well, which is at 7130-7370 ft (Well A-1) and 3100-3280 ft (Well P-1). Shale gas zone Well A-1 and P-1 has average TOC of 5.4 wt% and 2.8 wt%. These results are supported by calculation of AI inversion, which showed a low impedance values for shale gas zone between 5000-8000 m/s*gr/cc (Line A-1) and 7200-8900 m/s*gr/cc (Line P-1).

Besides, spectral decomposition also showed high CWT anomaly at 18 Hz (Line A-1) and 20 Hz (Line P-1). Integrated analysis of seismic data, AI, and CWT indicates there are potentials area of shale gas on the anticline ridge on Line A-1 and Line P-1."

"ABSTRAKIndonesia memiliki cadangan gas non konvensional berupa shale gas yangcukup besar yaitu sebesar 574 Tcf (hypothetical resources), yang belumdiexplorasi hingga saat ini. Potensi shale gas ini perlu untuk segera dimanfaatkanuntuk memenuhi kebutuhan gas dalam negeri yang diperkirakan akan meningkatdengan pesat di masa akan datang. Data-data biaya CAPEX dan OPEX akandiambil dari contoh pengembangan shale gas di Marcellus basin sebagaibenchmark. Profil produksi gas diestimasi dengan menggunakan modelpersamaan exponensial menurun.Dari hasil analisa keekonomian diketahui bahwa pengembangan shale gas diSumatera Selatan akan potensial menguntungkan secara komersial apabila salesgas dijual pada harga awal 10 USD/MMBTU, FTP (first trance petroleum)sebesar 0% dan profil produksi sedang atau tinggi. Sedangkan bila sales gas dijualdengan harga awal 6 USD/MMBTU akan kurang menguntungkan bahkan padaprofil produksi tinggi sekalipun. Hasil analisa sensitivitas menunjukkan bahwaperubahan besaran harga gas dan produksi gas memberikan pengaruh positifterhadap IRR dan BEP, sedangkan perubahan besaran CAPEX memberikanpengaruh sebaliknya. Perubahan besaran harga gas memberikan pengaruh yanglebih besar baik terhadap IRR maupun BEP dibandingkan perubahan produksigas. Pemberian insentif berupa penetapan FTP sebesar 0% (dibandingkan dengankondisi normal FTP sebesar 20%) memberikan pengaruh yang relatif kecilterhadap IRR dan BEP. Apabila gas dijual pada harga awal 10 USD/MMBTU danFTP sebesar 0%, maka pada recovery factor sebesar 10% dari potensi kandunganshale gas di Sumatera Selatan, dapat diperoleh potensi pemasukan buatpemerintah Indonesia sebesar 352 trilyun rupiah.

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ABSTRACTIndonesia has hypothetical resources of unconventional shale gas about 574tcf that has not been explored yet. The potential of shale gas resources should beutilized to fulfill the fast growing demand of natural gas expected in the future.CAPEX and OPEX cost will be adopted from example of shale gas developmentof Marcellus shale as a benchmark. Gas production profile will be estimated byusing declining exponential model of equation.The economic analysis result shows that shale gas development in SouthSumatera will be feasible if initial price of sales gas is 10 USD/MMBTU, FTP is0% and gas production profile is medium or high type. On the other hand if initialsales gas price is at 6 USD/MMBTU then it will not be feasible even at highproduction profile. Sensitivity analysis result shows that sales gas price andproduction profile will give positive impact to IRR and BEP. In contrary, CAPEXwill give negative impact. Sales gas price will give higher impact than gasproduction. Government incentive like FTP at 0% (instead of 20% at normalcondition) will give insignificant impact to IRR and BEP. In case sales gas is at 10USD/MMBTU and FTP at 0%, with recovery factor of 10% from hypotheticalshale gas resources in South Sumatera, it is estimated that the potential income toIndonesian Government is about 352 trillion rupiah."

"ABSTRAKHasil dekomposisi spektral dengan menggunakan metode Smoothed Pseudo Wigner-VilleDistribution (SPWVD) digunakan untuk mengestimasi nilai atenuasi pada data seismik.Tujuan tugas akhir ini adalah untuk mengkarakterisasi reservoar shale pada formasiGumai yang terletak di Lapangan Abiyoso yang berada di sub cekungan Jambi, cekunganSumatera Selatan dengan menggunakan dekomposisi spektral. Tahapan pertama yangdilakukan adalah analisis petrofisika dan analisis crossplot untuk mengarakterisasi lapisanreservoar shale. Karakterisasi lebih lanjut dilakukan dengan overlay kurva DlogR dankurva Transit time sonik. Dari ketiga zona shale yang diprediksi, diperlihatkan bahwalapisan batuan lempung pada zona Shale 1 merupakan lapisan batuan lempung yangdiduga reservoar. Hasil tersebut didukung pula oleh estimasi nilai atenuasi daridekomposisi spektral. Selanjutnya dekomposisi spektral diteruskan untuk data seismiksecara keseluruhan sehingga didapatkan estimasi persebaran reservoar lapisan batuanlempung pada data seismik.

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ABSTRACTThe results of spectral decomposition using Smoothed Pseudo Wigner-Ville Distribution(SPWVD) is used to estimate the value of attenuation on seismic data. The purpose of thisthesis is to characterize shale reservoir in Gumai Formation at Abiyoso Field in JambiSub Basin, South Sumatera Basin. The first stage,it is carried out petrophysical analysisand crossplot analysis to characterize shale reservoir layer. Further characterization isdone by overlaying DlogR and Sonic transit time curve. Based on the three predictedshale zone, it is shown that shale layer at Shale zone 1 is estimated the layer of shalereservoir. These results are confirmed also by the estimated value of the attenuation ofspectral decomposition. Further spectral decomposition is applied to seismic data set tomap distribution of shale reservoir."

"ABSTRAKJumlah pasokan dan kebutuhan gas bumi di Indonesia masih dalam kondisi defisit yang diakibatkan jumlah pasokan gas bumi semakin menurun dan kebutuhan akan gas bumi yang semakin meningkat setiap tahunnya. Namun, defisit antara pasokan dan kebutuhan dapat diperkecil seiring penemuan cadangan gas bumi konvensional yang baru atau dengan mengembangkan lapangan gas nonkonvensional seperti shale gas. Potensi shale gas Indonesia diperkirakan mencapai 574 TCF yang tersebar di Sumatera, Kalimantan, Jawa dan Papua. Formasi Naintupo yang berada di Cekungan Tarakan memiliki sumber daya shale gas yang bisa dihasilkan secara teknis sebesar 5 TCF darigas-in-place resiko sebesar 35 TCF. Penelitian ini akan membahas mengenai aspek teknoekonomi dari pengembangan lapangan shale gas di Formasi Naintupo, Cekungan Tarakan dengan menggunakan skema Kontrak Bagi Hasil (Production Sharing Contract) dan skema kontrak gross split.Tiga profil laju alir akan dikembangkan dengan menggunakan kurva penurunanhiperbolik Arps, yaitu profil produksi rendah dengan laju alir awal (qi) sebesar 150 mmcf/mo, profil produksi sedang (qi=250 mmcf/mo) dan profil produksi tinggi (qi=350 mmcf/mo) . Perkiraaan biaya investasi berdasarkan benchmarking biaya pengembangan lapangan shale gas di Amerika Serikat dan pengembangan lapangan migas di Cekungan Tarakan. Pada kondisi analisis kontrak bagi hasil dan kontrak gross split memiliki NPV>0, IRR>10% pada profil produksi sedang dan tinggi. Bagi kontraktor, kontrak bagi hasil akan lebih menguntungkan pada profil produksi rendah dan kontrak gross split lebihmenguntungkan pada profil produksi tinggi. Analisis sensitivitas menunjukkan bahwa faktor yang lebih berpengaruh terhadap peningkatan NPV dalam kontrak bagi hasil adalah harga gas dan dalam kontrak gross split adalah profil produksi. Untuk mendapatkan nilai NPV yang positif pada Kontrak Bagi Hasil, gas bumi harus dijual pada harga $12,05/MMBTU pada profil produksi rendah, $7,88/MMBTU pada profil produksi sedang dan $6,03 pada profil laju alir tinggi. Pada kontrak gross split, NPV yang positif dicapai ketika gas bumi dijual pada $8,42/MMBTU pada profil produksi sedang dan $6,52/MMBTU pada profil produksi tinggi.

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ABSTRACTThe amount of supply and demand of natural gas in Indonesia is still in deficitcondition due to the decreasing supply with increasing demand each year. This deficit of supply and demand could be minimized by new reserve discovery of conventional natural gas or by developing unconventional gas field like shale gas. Shale gas potential in Indonesia was predicted reached 574 TCF which spread in Sumatra, Kalimantan, Java and Papua. Naintupo Formation, located in Tarakan Basin has shale gas potential in which 5 TCF is technically recoverable with 35 TCF risked gas in place. This study will discuss technoeconomic aspect of shale gas field development in Naintupo Formation in Tarakan Basin by using production sharing contract scheme and gross split contract scheme.Three flow profiles would be developed by using Arps hyperbolic decline curves, consist of low production profile with initial production (qi) of 150 mmcf/mo, medium production profile (qi = 250 mmcf/mo) and high production profile (qi = 350 mmcf/mo). Costs estimation were based on benchmarking cost of developed shale gas field in United States and nearby oil/gas field development in Tarakan Basin. On the base case, production sharing contract and gross split contract gave NPV>0, IRR>10% on middle and high production profile. For contractor, production sharing contract was more profitable in low production profile and gross split contract was more profitable on highproduction profile. Sensitivity analysis showed that the NPV increase was more affected by gas price in production sharing contract and production profile was more influential in gross split contract. To develop positive NPV in production sharing contract, gas price should be $12.05/MMBTU in low production profile, $7.88/MMBTU in middle production profile and $6.03 in high production profile. In gross split contract, positive NPV was reached when gas price was $8.42/MMBTU in middle production profile and $6.52/MMBTU in high production profile."

"ABSTRAKSelisih antara jumlah pasokan dan kebutuhan gas bumi di Indonesia yang semakin meningkat setiap tahunnya diakibatkan jumlah pasokan gas bumi semakin menurun dan kebutuhan akan gas bumi yang semakin meningkat serta kurangnya penemuan cadangan gas terbaru. Hal ini mendorong pemerintah Indonesia untuk mengembangkan sumber daya gas lainnya seperti shale gas sehingga dapat diproduksi secara komersial. Potensi shale gas Indonesia diperkirakan mencapai 574 TCF yang tersebar di Sumatera, Kalimantan, Jawa dan Papua. Formasi Meliat yang berada di Cekungan Tarakan memiliki sumber daya shale gas yang bisa dihasilkan secara teknis sebesar 3.8 TCF dari gas-in-place resiko sebesar 25.1 TCF. Tujuan penelitian ini mengkaji skema kontrak gross split terhadap aspek keekonomian dari pengembangan lapangan shale gas di Formasi Meliat, Cekungan Tarakan.Skenario dasar dalam penelitian ini yaitu membuat tiga profil laju alir yang dikembangkan dengan menggunakan kurva penurunan hiperbolik Arps, antara lain profil produksi rendah dengan laju alir awal (qi) sebesar 50 mmcf/mo, profil produksi sedang qi=125 mmcf/mo dan profil produksi tinggi qi=200 mmcf/mo. Amerika Serikat dan lapangan migas terdekat menjadi benchmarking dalam membuat biaya investasi pengembangan lapangan shale gas di Cekungan Tarakan. Pada kondisi analisis kontrak gross split memiliki NPV>0, IRR>10% pada profil produksi sedang dan tinggi. Analisis sensitivitas dilakukan pada profil produksi, biaya pengeboran dan harga gas. Hasil analisis menunjukkan bahwa faktor yang lebih berpengaruh terhadap peningkatan NPV dalam kontrak gross split adalah profil produksi. NPV positif dicapai ketika gas bumi dijual pada $9.24/MMBTU pada profil produksi sedang dan $6.43/MMBTU pada profil produksi tinggi.

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ABSTRACTThe difference between the amount of supply and demand of natural gas in Indonesia is increasing each year year due to the decreasing natural gas supply with increasing demand and the lack of discovery of the latest gas reserves. This encourages the Indonesian government to develop other gas resources such as shale gas so that it can be produced commercially. Shale gas potential in Indonesia was predicted reached 574 TCF which spread in Sumatra, Kalimantan, Java and Papua. Meliat Formation, located in Tarakan Basin has shale gas potential in which 3.8 TCF is technically recoverable with 25.1 TCF risked gas in place. The purpose of this study is to examine the gross split contract scheme on technoeconomic aspect of shale gas field development in Meliat Formation in Tarakan Basin.The basic scenario in this research is to create three flow rate profiles developed using the Arps hyperbolic decline curves, consist a low production profile with initial production (qi) of 50 mmcf / mo, medium production profile qi = 125 mmcf / mo and high production profile qi = 200 mmcf / mo. The The United States and the nearest oil and gas field in Tarakan Basin have become a benchmark in making investment costs for the development of this shale gas field. In the analysis condition, gross split contracts have NPV> 0, IRR> 10% on medium and high production profiles. Sensitivity analysis is carried out on the production profile, drilling costs and wellhead gas price. The analysis shows that the factor that has more affected on the increase in NPV in gross split contract is the production profile. A positive NPV is reached when gas price is $ 9.24 / MMBTU at medium production profile and $ 6.43 / MMBTU at high production profile."

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Analisis tekanan bawah permukaan dilakukan untuk mendeteksi adanya overpressure dan permasalahan pada sumur yang akan dilakukan pengeboran berdasarkan data sumur eksplorasi. Pada operasi pengeboran yang dilakukan pada sumur A, B, C, D ditemukan berbagai masalah pengeboran yaitu kick, sloughing shale, dan pipe sticking yang dapat mengakibatkan tingginya Non Productive Time (NPT). Penelitian ini dilakukan untuk: pertama mengidentifikasi mekanisme overpressure di Tight Sand Gas dan Shale Gas pada Sub-Cekungan Jambi. Kedua melakukan prediksi tekanan pori menggunakan metode Bowers dan metode Drilling Efficiency and Mechanical Specific Energy (DEMSE) dan selanjutnya  berdasarkan hasil analisis kuantitatif inversi seismik post-stack  dapat memodelkan tekanan pori di daerah tersebut. Hasil analisis tekanan pori di sumur dan model tekanan pori 3D mengindikasikan bahwa top overpressure terjadi pada Formasi Gumai, kemudian berangsur-angsur turun mendekati tekanan hidrostatik pada Basement. Mekanisme overpressure diakibatkan oleh undercompaction, fluid expansion (kerogen maturation). 4. Formasi Gumai dan formasi Talang Akar merupakan batuan shale sehingga jenis lumpur yang baik digunakan adalah oil based mud (OBM). Batuan shale memiliki sifat elasticity sehingga rate of penetration (ROP) dan weight on bit (WOB) yang digunakan semakin besar.

 

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The subsurface pressure analysis is used to detect the overpressure and problems in the well that will be drilled based on exploration well data. Various problems were found while drilling operations carried out on A,B,C,D wells, such as kick and pipe sticking which cause a high Non-Productive Time (NPT). This research is conducted to identify the mechanism of overpressure formation in tight sand gas and shale gas in the Jambi Sub-Basin. Furthermore, to predict pore pressure using the Drilling Efficiency and Mechanical Specific Energy (DEMSE) and Bowers methods. The final result will be a 3D pore pressure cube in the area based on quantitative analysis of post-stack seismic inversion. The results of the pore pressure analysis from the wells and the 3D pore pressure model indicate that top of overpressure occurs in the Gumai Formation, then it is decreasing gradually approaching the hydrostatic pressure on the Basement. The mechanisms of overpressure are caused by under compaction, fluid expansion (kerogen maturation). The Gumai Formation and Talang Akar Formation are shale rocks so the type of mud weight that is well used is oil based mud (OBM). Shale rocks have elasticity so that the rate of penetration (ROP) and weight on bit (WOB) that are used is getting bigger.

 

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