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Journal of Petroleum and Geothermal Technology
Published by Universitas Pembangunan Nasional Veteran Yogyakarta
ISSN : 27230988     EISSN : 27231496     DOI : https://doi.org/10.31315/jpgt.v1i1
Core Subject : Science, Engineering,
Earth & Planetary Sciences Energy Engineering
Journal of Petroleum and Geothermal Technology (JPGT) is a journal managed by Petroleum Engineering Department, Universitas Pembangunan Nasional "Veteran" Yogyakarta. This Journal focuses on the petroleum and geothermal engineering including; reservoir engineering, drilling engineering and production engineering.
Arjuna Subject : Teknik (semua kategori) - Teknik (Lain-Lain)
Articles 6 Documents
 1 
Search results for , issue "Vol 3, No 2 (2022): November" : 6 Documents clear
SOLUTIONS TO IMPROVE DATA ACCURACY OF IPR DETERMINATION BY USING EMR SWAB MODIFICATION INNOVATION Panji Ikhlasul Amal
Journal of Petroleum and Geothermal Technology Vol 3, No 2 (2022): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v3i2.7695

Abstract

Sangasanga Field is one of the mature fields in the East Kalimantan area; there is a depleted zone in the shallow section (oil zone) and an overpressured zone in the deep section, in which the majority has gas potential. Each layer has a different pressure gradient, so it could be crossflow if layers are produced simultaneously (commingle). Swab work is an essential job to determine the initial indication of whether the well is producing fluid or dry (Production test), in swab work uses standard equipment such as a swab tank, swab lubricator, swab head, swab mandrel, and downhole circuit. In addition to the influx indicator from the reservoir, swabs are used to reduce hydrostatic pressure, unload acid/stimulating fluid, and determine the fluid resulting from drilling or workover work. Swab work can provide an overview of the Inflow Performance Relationship (IPR); the drawback of this method is the calculation based on the approach of fluid level and rate where there are still inaccuracies due to using estimates.The Bottom Hole Pressure and Temperature survey have a high accuracy l because it uses a Downhole Gauge in the form of an Electric Memory Recorder (EMR). Still, this work requires additional equipment like a Slickline Unit. Bottom Hole Pressure and Temperature Job surveys using a slickline unit cannot be carried out simultaneously. This study is a breakthrough in obtaining more accurate Swab data using EMR in conjunction with a swab job. Keywords: Swabbing Job, Inflow Performance Relationship, Downhole Gauge, Electric Memory Recorder
Study and Evaluation of Loss Circulation Mitigation When Drilling Unconsolidated Formation, Batang Field Wewen Afterian; KRT Nur Suhascaryo; Suranto Suranto
Journal of Petroleum and Geothermal Technology Vol 3, No 2 (2022): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v3i2.7304

Abstract

Field development of Batang Field through infill drilling was an effort by PHE Siak to contribute to national oil production. Target formation of the drilling campaign was Bekasap Formation which is part of central Sumatera basin. During the drilling execution of these infill wells, loss circulation occurred on some of the wells especially when the drilling reaches 8.5 in hole section. The severity of loss circulation ranging from small partial loss to total loss. To optimize future drilling operation in Batang, analysis will be conducted to determine the cause, prevention, and mitigation of loss circulation event based on drilling history.Method used in this research begins with analysing the cause of loss circulation on 8.5 in hole section that commonly occurs. Analysis then proceeded to analyse historical drilling parameter, such as: pump (MW, ECD, Pump Rate, Yp, RPM, SPM, dan ROP) recorded when loss circulation events occurred. Finally, the effectiveness of current method to mitigate loss circulation will also studied.Based on the analysis, it is known that the possible cause of loss circulation on infill well drilling in Batang is the reservoir properties and condition which having depleted or sub-normal average reservoir pressure and the property of the rock itself which is unconsolidated. Based on the study on drilling parameter history, the severity of loss circulation might be minimized by keeping pump flow rate to under 190 gpm, RPM under 48 rpm, WOB under 2 klbs, and ROP under 135 ft/hr when drilling progresses to 8.5 in hole section. Meanwhile, other parameters have not shown any relation to severity of loss circulation.
PIPE STUCK CAUSES ANALYSIS AND PREVENTIVE ACTIONS IN GEOTHERMAL DRILLING WELL AWI FIELD GUNUNG SALAK BASED ON PREVIOUS DRILLING PROBLEMS Hezron Byrian Manurung
Journal of Petroleum and Geothermal Technology Vol 3, No 2 (2022): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v3i2.7415

Abstract

The stuck pipe incident occured four times in three wells located on pad AWI-9. The three wells that experienced the stuck pipe were occurred first at AWI well 9-3, then twice at AWI well 9-5 and finally at AWI well 9-7. The first stuck pipe incident occurred at AWI 9-3 at the depth of 4,248 ftMD or 1,294 meters. There is a change in elemental anomalies or mud properties, an increase in the chloride property from the presence of brine in the wellbore as well as the increase of torques as a result of the accumulation of cuttings around the drill pipe assembly which resulted in sloughing or formation collapse. The next stuck pipe incident came from the AWI 9-5 well which occurred at the depth of 3,478 ftMD or 1,060 meters and at 4,667 ftMD or 1,422 meters. The background of the stuck pipe in this well can be seen from the collapse of the Paleosoil formation, the decrease in pump rate due to damage of the mud pump and the absence of air use when drilling in a loss circulation circumstances. This latter hindrance also led to the stuck pipe incident in the AWI 9-7 well at a depth of 6,266 ftMD or 1,910 meters. The overall occurrence of stuck pipes in the three wells above can be overcome and the drill pipe series can be released through working pipe efforts, maximizing the use of air and conducting well heat-ups. The methodology used in this thesis is a study of sub-surface and surface data during and before the occurrence of the stuck pipe incident. The data are log data in the form of daily drilling report, drill cutting or cutting data, drilling parameters and periodic reports of drilling mud per well. From the analysis of the data above, it was found that preventive measures were taken to prevent the same thing from re-occuring. The form of adding a mud additives that function as a reduction or prevention of fluid loss so that the loss circulation conditions can be prevented and brine and formations that have sloughing properties as the cause of collapse will not enter the hole, maintaining the weight of the mud and viscosity so that the mud cake maintained and the hole wall remains strong and the importance of hole cleaning during the drilling process; this includes the time before the connection process or removing the pipe circuit and the importance of using air in geothermal drilling which has a loss circulation character.
Development of Torque and Drag Calculation Software for Oil Well Planning–Part 1: 2D Aadnoy Method Singgih Satrio Wibowo; Herman Yoseph Sutarto
Journal of Petroleum and Geothermal Technology Vol 3, No 2 (2022): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v3i2.7503

Abstract

With the increasing number of drilled ultra-extended reach wells and complex geometry wells, the drilling limitation caused by excessive torque and drag forces must be further investigated. The wellbore friction being a main limiting factor in extended reach well needs to be studied with the new developed models. The torque and drag software implement two methods: (1) 2D and 3D analytical model developed by Aadnøy (Aadnoy & Andersen, 1998; Aadnoy & Andersen, 2001; Aadnoy & Djurhuus, 2008; Aadnoy, et al., 2010; Aadnoy, 2010) and (2) Miska and Mitchel, for 2D wellbore (Mitchell, et al., 2011). This paper presents the theory and implementation of 2D Aadnoy method. Quite diverse wellbore trajectory and depth has been chosen for a better evaluation and comparison of the model with the measured data. In order to investigate the potential and limitation of the model, torque and drag analysis during the different operations such as tripping in, tripping out, rotating off bottom, combined up/down were investigated.
HYDRAULIC FRACTURING ANALYSIS OF LOW PERMEABILTY, HEAVY OIL RESERVOIR TELISA FORMATION, BENTAYAN FIELD Amril Anshary
Journal of Petroleum and Geothermal Technology Vol 3, No 2 (2022): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v3i2.7197

Abstract

There is no proven economic oil production yet from Bentayan’s part of Telisa Layer. However, open hole log from some wells in Bentayan field indicates hydrocarbon presence in TELISA in Bentayan field. GGR study also indicated low value in permeability of Telisa in Bentayan field. Production test in BN-62 indicates oil presence from Telisa with very low influx. To prove the hydrocarbon prospect of Telisa in Bentayan field, operator planned to develop Telisa in BN-62 and BN-21 by conducting hydraulic fracturing using approximately 80,000 lbs of proppant.Early screen out happened when fracturing both wells. After the job, these two wells could not prove economical hydrocarbon production from Telisa. Both wells only have AOFP of 3 BFPD with lack of hydrocarbon indication.Evaluation indicated that the cause this failure on the fracturing job may be caused by smaller value of flow efficiency than it was predicted due to the large permeability zones and formation of multiple fractures that caused pad volume and the slurry pumping flow rate to be less to create the expected fracture geometry. Based on rock property map, BN-95 is suggested to be a candidate to prove the prospect of economical hydrocarbon content in from Telisa. Keywords: well stimulation, hydraulic fracturing, low permeability reservoir, Telisa  
Sand Problem Handling Strategy On Well Ar-02 With Hydraulic Pumping Unit Ayu Regita Pramesti; Nur Suhascaryo; Boni Swadesi
Journal of Petroleum and Geothermal Technology Vol 3, No 2 (2022): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v3i2.7279

Abstract

AR-02 well is one of the oil production wells located in Structure X. This well is produced using the Hydraulic Pumping Unit (HPU) method due to low reservoir pressure as a result of the reduced production capacity of the Y Field formation. In addition, this well has sand problems because the fluid production rate of 96 bfpd exceeds the critical sand flow rate of 66.81 bfpd. The physical properties of reservoir rocks do not cause sand problems because they have a cementation factor of highly cemented (m = 1.99), relatively small clay content (5.4%), compact rock (∆t = 54.16 s/ft), and compact as well as stable formation rock (G/Cb = 14.85x1012 psi2). In solving the sand problem in the AR-02 Well, the Gravel Pack and screen were installed. The correct Gravel size according to the Saucier method is 0.035 inch and the correct screen size according to the Coberly & Wagner, Tauch & Corley, and H. J. Ayre methods is 0.016 inch. The value (G-S) ratio indicates that the selection of Gravel and screen sizes is correct (stable), namely the value (G-S) ratio is at number 5. Redesign of the production scheme due to the installation of the Gravel Pack with the use of HPU pumps at the same setting produces; P due to Gravel installation 40 psi, qfluid after Gravel installation 90 bfpd (previously 95 bfpd), PI after Gravel installation 0.188 (previously 0.198), Min allowable stress 8991.56 psi, Max allowable stress 23420.64 psi, Total stretch 55.42 inch, Over travel 0.391 inch, Plunger stroke 94.97 inch, and Pump Displacement 135.65 bfpd.

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