JOURNAL OF EARTH ENERGY ENGINEERING
Journal of Earth Energy Engineering (eISSN 2540-9352) is a Bi-annual, open access, multi-disciplinary journal in earth science, energy, and engineering research issued by Department of Petroleum Engineering, Universitas Islam Riau. The journal is peer reviewed by experts in the scientific and engineering areas and also index in Directory of Research Journals Indexing (DRJI) and CrossRef Member.
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186 Documents
<![CDATA[Optimalisasi Production Well Test Untuk Mendukung Performance Produksi Dengan Cara Tiering System Pada Area X Lapangan Y ]]>
<![CDATA[Novia Rita]]>;
<![CDATA[Novrianti Novrianti]]>
<![CDATA[ Journal of Earth Energy Engineering Vol. 5 No. 1 (2016): APRIL ]]>
Publisher : <![CDATA[Universitas Islam Riau (UIR) Press ]]>
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DOI: 10.22549/jeee.v5i1.459
<![CDATA[Area X merupakan salah satu area yang terdapat di Lapangan Y PT. Chevron Pacific Indonesia, dimana area X terdiri dari 563 sumur. Pada Area X ini dilakukan pekerjaan tes terhadap sumur sebanyak 2 kali per bulan, sehingga untuk 563 sumur diperlukan 1126 kali tes perbulan. Fasilitas yang tersedia untuk production well test pada Area X hanya mampu 960 kali tes per bulan. Sehingga 116 sumur tidak akan mendapatkan jadwal tes pada setiap bulannya. Apabila prosedur seperti ini tetap dilakukan secara terus menerus maka akan selalu terdapat sisa sumur yang belum terpenuhi untuk dilakukan tes di setiap bulannya. Untuk mengatasi permasalahan ini dilakukan Tiering system. Tiering system adalah suatu metode dalam proses pengujian sumur dimana dalam metode ini sumur-sumur akan dikelompokkan berdasarkan produksi terbesar hingga terkecil. Sumur yang tergolong big production akan berada pada urutan teratas untuk dilakukan Well Testing (Tier #1) dan diikuti Tier #2, Tier #3 dan Tier #4 (Tiering System merupakan metode atau proses yang digunakan untuk mengelompokan data-data production well testing sumur yang banyak menjadi kelompok kelompak kecil, yang bertujuan untuk membantu mengoptimalisasi proses pekerjaan well test di Lapangan (Human Resources Sumatra Operation, 2012).. Kuantitas test sumur setiap bulan akan disesuaikan dengan kebutuhan data dan kategori Tier, hal ini bertujuan untuk mendapatkan data yang valid secara continue pada sumur, sehingga cepat diketahui dan di follow up jika terjadi permasalahan penurunan produksi pada sumur-sumur tersebut. Dengan Tiering System, maka 563 sumur yang harus dilakukan well testing setiap bulannya di Area X jadi terpenuhi karena hanya membutuhkan 777 kali tes perbulan. Bahkan waktu pelaksanaan well test masih tersisa untuk 183 kali tes, hal ini juga berdampak pada kenaikan produksi sebesar 5441 bbl per hari dengan keuntungan sebesar US$ 217.621,75.]]>
<![CDATA[Perhitungan Analisis Sistem Nodal Untuk Menentukan Laju Alir Minyak Dengan Meningkatkan Range Efesiensi Electric Submercible Pump Pada Sumur di Lapangan Minyak PT. BOB. BSP - Pertamina Hulu ]]>
<![CDATA[Ali Musnal]]>;
<![CDATA[Richa Melisa]]>
<![CDATA[ Journal of Earth Energy Engineering Vol. 5 No. 1 (2016): APRIL ]]>
Publisher : <![CDATA[Universitas Islam Riau (UIR) Press ]]>
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DOI: 10.22549/jeee.v5i1.460
<![CDATA[Dengan berjalannya waktu produksi, tekanan reservoir akan mengalami penurunan. Untuk mengatasi hal tersebut diatas dipergunakan pengangkatan buatan yang dikenal dengan “Artificial Lift”. Pada sumur di BOB PT.BSP- Pertamina Hulu Zamrud pada umumnya mempergunakan pompa electric submercible pump (ESP) sebagai pengangkatan buatan. Pompa ESP ini pada periode tertentu juga mengalami penurunan kemampuan untuk mengangkat fluida. Hal ini disebabkan karena berkurangnya kemampuan dari tekanan reservoir, terjadinya over load atau under load pada pompa, karena jumlah stages yang dipasang tidak tepat, dan disamping itu terjadinya kerusakan pada peralatan produksi itu sendiri. Penelitian ini menghitung Range efesiensi pompa terpasang, mengevaluasi kemampuan pompa ditandai besarnya laju produksi, menghitung jumlah stages dan Horse power pompa yang terpasang. Perhitungan mempergunakan metoda Analisa System Nodal, dimana titik nodalnya terletak didasar sumur. Berdasarkan hasil perhitungan range efesiensi pompa dari 4 sumur kajian, terdapat 2 pompa yang bekerja sesuai range efesiensinya dan pompa pada 2 sumur lainnya yaitu sumur F-02 dan F-04 mempunyai laju produksi 2500 stb/d dan 1450 stb/d. Pompa ini bekerja di bawah range efisiensi kalau kondisi ini diabaikan terus akan terjadi kerusakan pada pompa karena “downthrust” pada sumur F-02 dan F-04 agar meningkatkan laju produksi dan menghindari pompa bekerja pada kondisi downtrush maka dari hasil analisa sebaiknya ditambahkan panjang stage dari 44 stage menjadi 75 stage pada sumur F-02 dan 120 stage menjadi 150 stage pada sumur F-04.]]>
<![CDATA[Perbandingan Kinerja Reservoir Gas Konvensional dengan Coal Bed Methane (CBM) ]]>
<![CDATA[Ahmad Muraji Suranto]]>
<![CDATA[ Journal of Earth Energy Engineering Vol. 5 No. 1 (2016): APRIL ]]>
Publisher : <![CDATA[Universitas Islam Riau (UIR) Press ]]>
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DOI: 10.22549/jeee.v5i1.461
<![CDATA[Reservoir gas konvensional yang dikenal oleh masyarakat luas adalah reservoir yang terdiri dari jebakan reservoir (cap rock), batuan reservoir dan isi (gas). Sedangkan perangkapnya bisa berupa perangkap struktur, stratigtafi, patahan atau kombinasi dari ketiganya. Sedangkan reservoir yang menghasilkan gas methane batubara (Coal Bed Methane yang disingkat CBM) merupakan zona batubara yang terisolasi, memiliki rekah alam dan terisi oleh air. pada kondisi awal kedua tipe reservoir ini (reservoir gas konvensional dan CBM) mempunyai karakteristik yang berbeda, sehingga teknik perhitungan cadangan, cara memproduksikan dan kinerjanya akan berbeda pula. Karena mempunyai latarbelakang yang berbeda maka kiranya perlu dilihat kinerjanya seberapa jauh perbedaannya karena keduanya memproduksikan gas hidrokarbon. Untuk melihat kinerja reservoirnya baik reservoir gas konvensional atau CBM maka dalam kajian ini menggunakan simulator. Dari kedua model, volume masing-masing reservoir dibuat sama, dan dilakukan sensitivitas karakteristik reservoirnya terhadap masing-masing model. Hasil akhir yang dibandingkan adalah kinerja dari masing-masing reservoir tersebut. Hasil yang didapat dari kajian ini adalah bahwa reservoir CBM mempunyai laju produksi gas lebih rendah, daerah pengurasan lebih kecil dan recovery factor lebih sedikit bila dibandingkan dengan reservoir gas konvensional. Tetapi karena cadangan gas konvensional semakin lama semakin menipis, maka reservoir CBM sebagai alternatif yang perlu dikembangkan setelah gas konvensional. Kebijakan pajak pemerintah sangat penting untuk kelangsungan produksi CBM.]]>
<![CDATA[Studi Laboratorium Pengaruh Nanocomposite Nanosilika dan Arang Cangkang Kelapa Sawit Dengan Variasi Temperatur Pemanasan Terhadap Free Water dan Kekuatan Semen Pemboran ]]>
<![CDATA[Novrianti Novrianti]]>
<![CDATA[ Journal of Earth Energy Engineering Vol. 5 No. 1 (2016): APRIL ]]>
Publisher : <![CDATA[Universitas Islam Riau (UIR) Press ]]>
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DOI: 10.22549/jeee.v5i1.465
<![CDATA[Semen merupakan salah satu parameter penting dalam proses pemboran. Parameter keberhasilan penyemenan sumur migas antara lain adalah apabila nilai free water, compressive strength (CS) dan shear bond strength (SBS) telah sesuai dengan standar penyemenan American Petroleum Association (API). Menurut API Nilai Free water maksimal adalah 3.5 ml, nilai Compressive strength minimum yang direkomendasikan oleh API untuk dapat melanjutkan operasi pemboran adalah 500 Psi sedangkan shear bond strength lebih dari 100 psi. Beberapa additive telah dipergunakan untuk meningkatkan kekuatan semen. Studi ini dilakukan untuk mengetahui pengaruh nanocomposite antara additive nano silika dan arang cangkang kelapa sawit yang dipanaskan dengan variasi temperature terhadap nilai free water, compressive strength (CS) dan shear bond strength (SBS) semen pemboran. Eksperimen ini menggunakan konsentrasi arang cangkang kelapa sawit dengan variasi temperature pemanasan 400 oC, 500 oC, 600 oC, 700 oC, 800 oC dan 900 oC sebesar 3% by weight on cement dengan tambahan nano silika sebesar 0,019%. Setelah suspense semen selesai dibuat, free water ditentukan dengan menggunakan gelas ukur yang diisi oleh suspensi semen sebanyak 250 ml. Mendiamkan selama 2 jam sehingga terjadi air bebas pada bagian atas gelas ukur. Sedangkan untuk compressive strength (CS) dan shear bond strength (SBS) suspense semen dituangkan kedalam cetakan dan dikeringkan selama 24 jam dan setelah kering maka sampel akan diuji pembebanan dengan menggunakan alat hydraulic Press. Uji pembebanan ini dilakukan sampai sample pecah. Tekanan pada saat sample pecah dicatat sebagai data pembebanan maksimum untuk menentukan compressive strength (CS) dan shear bond strength (SBS). Hasil penelitian menunjukkan bahwa nilai free water, compressive strenght dan shear bond strenght maksimum diperoleh pada saat arang cangkang kelapa sawit dipanaskan pada temperature 700 oC. Nilai free water yang diperoleh adalah 3.2 ml, compressive strength yang diperoleh adalah 1433.01 Psi dan shearbond strength 163.45 Psi.]]>
<![CDATA[Analisis Sensitivitas Salinitas dan Adsorbsi Injeksi Surfaktan-Polimer Menggunakan Simulasi Reservoir Pada Reservoir Berlapis Lapangan NA ]]>
<![CDATA[Novia Rita]]>
<![CDATA[ Journal of Earth Energy Engineering Vol. 5 No. 2 (2016): OCTOBER ]]>
Publisher : <![CDATA[Universitas Islam Riau (UIR) Press ]]>
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DOI: 10.22549/jeee.v5i2.476
<![CDATA[Increasing the time, the condition of the oil in reservoir increasingly difficult for production to the surface, this is caused by diminishing reservoir pressure and the condition of a viscous oil. While the technology used can no longer urged oil to surface. NA field is a field that is old, the production process is done on the field NA has been through the stages of primary and secondary recovery, where this stage is not optimal in increasing oil production on the field. While OOIP on the field is still economically viable. Of screening criteria that has been done on NA Field, the oil production stage to do next is to EOR method. The EOR methods that can be applied is by chemical injection method of surfactant and polymer. Before the surfactant and polymer injection method performed on NA Field, the first done through the stages of planning reinjection reservoir simulation. Fields of reservoir simulation models NA will be analyzed four scenarios conducted for sensitivity to salinity and adsorption of surfactant-polymer. Scenario 1 simulation with values varying salinity, Scenario 2 adsorption value simulation with different surfactants, Scenario 3 sensitivity to polymer adsorption, Scenario 4 see changes impairment influences the permeability to polymer injection. The results of all four scenarios simulations obtained optimum value of cumulative production of 72 548 STB with a recovery factor (RF) of 30.9% at the price of 0.075 surfactant salinity mEq / ml, adsorption of surfactant 0.3 mEq / ml, 0.1 wt polymer adsorption % cuft, and changes in permeability due to 80wt% polymer solution cuft.]]>
<![CDATA[Analisis Performance Sumur X Menggunakan Metode Standing Dari Data Pressure Build Up Testing ]]>
<![CDATA[Novrianti Novrianti]]>
<![CDATA[ Journal of Earth Energy Engineering Vol. 5 No. 2 (2016): OCTOBER ]]>
Publisher : <![CDATA[Universitas Islam Riau (UIR) Press ]]>
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DOI: 10.22549/jeee.v5i2.477
<![CDATA[The number of production wells refers to the performance of the well, which is shown in the graph of inflow performance relationship (IPR). Reservoir characteristics influence on performance of the well, type of welltest and methods that be used in the determination of IPR. By using the IPR curves, maximum flow rate and the optimal flow rate of the well will be known. Pressure Build Up test is used to know performance and a maximum flow rate of the X well. Well test conducted for 15 hours. The well produced at a constant flow rate than close the wellhead. The Pressure data and time data obtained from the well test. The result of Pressure build-up testing analysis among permeability, skin and flow efficiency. After analyzing the Pressure build-up testing permeability obtained 190 mD, skin + 1,68 and 0,83 flow efficiency. Based on the value of flow efficiency Standing method is the most appropriate method is used to analyze the productivity of X well. Standing appropriate method for wells with skin ≠ 0 and flow efficiency ≠ 1. The maximum flow rate of the X well using Standing Method on the 0,83 flow efficiency was 13,91 MMSCFD]]>
<![CDATA[Prediksi Kinerja Steamflood Dengan Metode Myhill-Stegemeier dan Gomaa di Area R Duri Steamflood (DSF) ]]>
<![CDATA[Rycha Melysa]]>
<![CDATA[ Journal of Earth Energy Engineering Vol. 5 No. 2 (2016): OCTOBER ]]>
Publisher : <![CDATA[Universitas Islam Riau (UIR) Press ]]>
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DOI: 10.22549/jeee.v5i2.478
<![CDATA[Steamflood constitutes one of method Enhanced Oil Recovery (EOR) by injected steam with quality and particular flow rate kontinyu into reservoir. Its aim is increase oil mobility at reservoir by downs viscosity to produced passes through producer. Before does simulation exhaustively, there is it is better does to predict performance a steamflood's reservoir by analytic simple one. This studies compares two simple methods in prediction steamflood's reservoir performance by use of data historical on area R Duri Steamflood (DSF). Gomaa's method utilizes many graph have already at previous generalizing but just applies on field with given characteristic limitation. Then Myhill Stegemeier modifies equation that made by Mandl and Volek to interpose that displacement form in reservoir is frontal displacement one dimension yawns to oil. Both of that method have excess and its lack each. Compares two simple methods in predicting reservoir performance steamflood using historical data on the area "R" Steamflood Duri. Gomaa method using some charts that have been generalized before but only apply to the courts to limit certain characteristics. Myhill-Stegemeier then modify the equations created by Mandl and Volek to argue that the form of displacement in the reservoir is a one-dimensional frontal displacement steam to oil. Both methods have advantages and disadvantages of each. Both methods produce a number of different oil recovery. The cumulative oil recovery methods amounted to 1378917 Stegemeiers Myhill-STB (76% of OOIP) and Method Gomaa of the STB 999 072 (55% of OOIP). Comparison of steam-oil (FSO) obtained in Method Myhill is a comparison of cumulative, it is evident from the constant value (FSO) obtained from the first year until the 10th year. Gomaa is different from the method they are relatively oil-vapor ratio (FSO) obtained.]]>
<![CDATA[Perbandingan Analisis Decline Curve antara Metode Trial Error dan Decline Type Curve Matching Untuk Menentukan Cadangan Minyak Sisa ]]>
<![CDATA[Guntur Setiawan]]>
<![CDATA[ Journal of Earth Energy Engineering Vol. 5 No. 2 (2016): OCTOBER ]]>
Publisher : <![CDATA[Universitas Islam Riau (UIR) Press ]]>
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DOI: 10.22549/jeee.v5i2.479
<![CDATA[Decline curve analysis often used to determine remaning reserves in a reservoir. To analyze with this method, the decline type curve from production period (trend) must be known. To determine decline type curve, in this paper will use two methods there are: trial error & x2 chisquare test and decline type curve matching. Both of methods have different way to determine decline type curve. Trial error done by making tabulation and calculation, while decline type curve matching done by overlay. The calculation are aimed to determine decline type curve, Remaining Reserves (RR) and Estimate Ultimate Recovery (EUR). Analysis done by taking sample of data well X which is a new well produced since September 2013 till the last data is Febuary 2016. First step of this study done by making type curve from equations and assumptionin literature then plot production rate vs time and choose production period (trend) to be analyzed. After that, determine decline type curve by trial error and decline type curve matching and do forecast until get remaining reserves and estimated ultimate recovery if economic limit rate production known. From calculation of both methods, resulted exponential decline type curve. For the error method obtained RR 41322,3 STB and EUR 240328,9 STB, while for decline type curve matching obtained RR 40534,2 STB and EUR 239540,8 STB]]>
<![CDATA[Analisis Kinerja Tenaga Pendorong Reservoir dan Perhitungan Water Influx pada Perolehan Minyak Tahap Primer (Studi Kasus Lapangan Falipu) ]]>
<![CDATA[Ira Herawati]]>
<![CDATA[ Journal of Earth Energy Engineering Vol. 5 No. 2 (2016): OCTOBER ]]>
Publisher : <![CDATA[Universitas Islam Riau (UIR) Press ]]>
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DOI: 10.22549/jeee.v5i2.480
<![CDATA[Primary recovery is the stage of oil production by relying on the natural ability of the driving force of the reservoir. Kind of driving force that is water drive reservoir, depletion drive, segregation drive and a combination drive. The pressure drop occurred along its produced oil from the reservoir. Reservoir so that the driving force is the main parameter in maintaining reservoir pressure balance. Through the concept of material balance is the determination of the type of propulsion quifer reservoir and the power that generates driving force parameter analysis capability and aquifer in oil producing naturally. Then do the forecasting production to limit the ability of primary recovery production phase. Combination drive depletion of water drive and the drive is a driving force in the dominant reservoir Falipu Fields with a strongly water aquifer types of drives obtained through material balance equation. Calculations using the method of water influx Havlena & Odeh used as a correction factor for determining the type of propulsion reservoir and aquifer strength. Forecasting production in the Field Falipu generate recovery factor of 41% with a pressure boundary in 2050.]]>
<![CDATA[Analisis Peningkatan Produksi Pada Sumur Minyak Dengan Metode Partial Water Shut Off Dalam Meningkatkan Rasio Keberhasilan Partial Water Shut Off Pada Lapangan Hawa ]]>
<![CDATA[Fitrianti Fitrianti]]>
<![CDATA[ Journal of Earth Energy Engineering Vol. 6 No. 1 (2017): APRIL ]]>
Publisher : <![CDATA[Universitas Islam Riau (UIR) Press ]]>
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DOI: 10.22549/jeee.v6i1.535
<![CDATA[From year to year the number of oil production will be reduced and the amount of water production will grow, so will cause problems in managing the water. Some of the problems that arise are limitations in the surface water treatment systems, the availability of water treatment chemicals, and declining well productivity. Doing some work over to lower the value of water production and increase the value of oil production, one of which is the partial water shut off. On the hawa field, some job well done partial water shut off. The results of such work nothing works and nothing failed. Analysis performed on the job partial water shut off with the observation of the historycompletion and the processing of data and calculation of the value of production history OOIP to get the value of remaining reserves. After analysis, it was found some causes of work partial water shut off the well would be successful if it fulfills several criteria such as: the value of remaining reserves are still large enough, she had never done work partial water shut off in the layer and selecting the type of isolation right tool. While the cause of such failures is that the well had done work partial water shut off the same perforation interval. The criteria are very important and necessary in deciding the work partial water shut off the a better well done or not.]]>
