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PREDICTION OF ”RATE OF PENETRATION” (ROP) ON DRILLING FORMATION ”X” PROGNOSIS WELL ”YN2” BASED ON THE REPRESENTATIVE MODELLING FROM DRILLING FORMATION ”X’’ ACTUAL WELL ’’YN1’’ FIELD ’’IP’’ KRT. Nur Suhascaryo; Sudarmoyo Sudarmoyo; Inrianto Pratomo
Techno LPPM Vol 6, No 1 (2020)
Publisher : Universitas Pembangunan Nasional Veteran Yogayakarta

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Prediction value of the rate of penetration (ROP) in the drilling of the formation “X” well prognosis "YN2" in the field “IP” and the actual well "YN1" as a review of the selection of a representative Model-ROP at a depth of 2620 mbpl - 3000 mbpl in the "IP" field ". This study selected a representative Model-ROP from drilling the "X" formation of the actual well "YN1" in the "IP" field then predicting the rate of penetration (ROP) value in the drilling of the "X" formation of the "YN2" prognosis well in the "IP" field. ROPs used in this study include the Bingham Model (1966), Teale (2008) and Mottahari (2010). Prediction of the rate of penetration (ROP) value in the drilling of the "X" formation well "YN2" prognosis is done in stages including predicting the rate of penetration (ROP) value in the drilling of the "X" formation of the actual well "YN1" by collecting data including data on "YN1" actual well drilling includes bit records, drilling reports, well programs, and well profiles and then predicts the rate of penetration (ROP) value in the drilling of the "X" well formation "YN2" using drilling prognosis. Determine the drilling parameters needed to predict the value of the rate of penetration (ROP) has a difference in each model. In the Bingham model the parameters required include MD, WOB, RPM, T, and d-exp values. In the Teale model the required drilling parameters contain the actual MD, WOB, RPM, T, DB, and ROP values, MSE, μ and AB. In the Mottahari Model, the drilling parameters needed for MD, WOB, RPM, T, DB, actual ROP, σ, Wf (use function), G (model coefficients representing drillability), a = 0.50 and y = 1,50 is obtained from assumptions. In the Bingham Model has a coordination coefficient value (R2) = 0.9985, the Teale Model has a coordination coefficient value (R2) = 1 and the Mottahari Model has a co-coefficient value (R2) = 1. The ROP model that represents the drilling of the "X" formation Actual wells "YN1" can all be used or all Model-ROPs represent to predict the value of the penetration rate (ROP) in drilling the "X" formation prognosis of the well "YN2". Calculate the estimated penetration rate (ROP) in the drilling of the "X" formation prognosis of the well "YN2" using the Bingham, Teale and Mottahari models through the prognosis of the drilling "YN2".

Management Of Shallow Gas Kick At Syh-05 Well In West Java Area Sandy Candra Yudha Halilintar; KRT Nur Suhascaryo; AM Suranto
Journal of Petroleum and Geothermal Technology Vol 3, No 1 (2022): May
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v3i1.6297

SYH-05 Well Drilling Operation West Java Area, was planned to be drilled with a final depth of 1694.65 mMD / 1500 mbpl by directional well drilling. Drilling hazards on the 17½” trajectory were shallow gas, gumbo, and bit balling. Furthermore, on this trajectory, shallow gas handling and optimization of drilling were going to be executed through shallow gas kick countermeasures in the SYH-05 Well. The high gas readings from the SYH-03 Well and the SYH-04 Well are 867 units and 1275 units, respectively, at a depth of 500-520 mMD intervals.After carrying out mitigation for shallow gas mitigation, the SYH-05 Well would use a higher Mud Weight than the reference well in this study starting with MW 1.12 SG while the reference well started with MW 1.08 SG, and the use of Annular – Single Ram 21-1/ 4” 2K with 10” Ball Valve as Diverter System. Moreover, to overcome the Kick Volume which was larger than the 17-1/2” hole, a 12-1/4” Pilot Hole would be installed. Prepare High Density Mud as a Contingency Plan and 4 Mud Pumps to anticipate the implementation of High Flow Rate Dynamic Kill. In the Cementing Design process, Gas Tight Slurry Cement would be applied.Based on the Casing Setting Depth analysis in the SYH-05 well drilling operation, there were 4 trajectories, namely: Conductor Casing 20”, 0-80m; Surface Casing 13-3/8”, 80-663.69m; Production Case 9-5/8”, 663.69-1060m; and Production Liner 7”, 1060.50-1694.65m. The implementation of Well Control was aimed to tackle the shallow gas kick was successfully executed in less than 1 hour without incident or accident. Work on the 17-1/2” trajectory which was a shallow gas zone could be done with the planned timetable.Keywords: Drilling hazard, Shallow gas kick, Optimization, Countermeasures

Evaluation of Water Channeling Problems and Planning for Its Improvement Using the Remedial Cementing Method and Its Economics in Well AB-30 Field AB PT. Pertamina EP Deni Kurniawan; KRT Nur Suhascaryo; Boni Swadesi
Journal of Petroleum and Geothermal Technology Vol 3, No 1 (2022): May
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v3i1.6881

The AB-30 well is an oil producing well located in the AB Field. Production performance data shows that AB-30 shows excessive water production behavior or is a high water cut production well. In addition, the interpretation of CBL data shows an amplitude value of <10 mV in the productive interval. This condition is an indicator that the primary cementing activity in this well is not good. Therefore, a comprehensive and integrated analytical method is needed to identify the problem of excess water production and to design and plan water shut-off activities through squeeze cementing as an effort to mitigate the problem of high water cut to economic analysis.The research begins by identifying the problem of excess water production, whether caused by water channeling, water coning, changes in water oil contact, or by the physical properties of the reservoir rock. Identification is done through production analysis and water diagnostic plots. The next stage is to evaluate the interpretation of CBL Logging results to strengthen the results of production data analysis. After confirming that the problem of excess water production is caused by poor cement bonding cement, the next step is to calculate the cement work program in order to repair the bad cement bonding. Subsequently, the productive zone interval re-perforation was carried out according to the results of the OH Loh Co Log evaluation. No less important is to conduct an economic analysis as a basis for whether or not this work is feasible.The result of this research is that the water shut-off activity went well and was able to reduce the level of excess water production in the AB-30 well and optimize oil production so as to provide a good economic indicator of oil recovery. Remedial cementing work for bonding repair was carried out at well AB-30. The first work is to close the existing layer, followed by Logging evaluation (CBL-USIT). The evaluation results showed that the cement bonding was good with the CBL amplitude parameter < 10 mV. After that, the productive zone reperforation was carried out. The economy by considering the values of economic indicators such as Pay Out Time and Rate Of Investment showed positive results so that the priority and strategy of well intervention could be continued. The results obtained before the well intervention were 148 BOPD oil production, 97% water cut after well intervention was 880 BOPD average oil production, 0% water cut for 1.5 months

Gas Injection Optimization to Increase Oil Production at MRA PT. PHE ONWJ Harry Budiharjo Sulistyarso; KRT Nur Suhascaryo; Mochamad Jalal Abdul Goni
Journal of Petroleum and Geothermal Technology Vol 2, No 2 (2021): November
Publisher : Universitas Pembangunan Nasional "Veteran" Yogyakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/jpgt.v2i2.5519

The MRA platform is one of the offshore platforms located in the north of the Java Sea. The MRA platform has 4 production wells, namely MRA-2ST, MRA-4ST, MRA-5, and MRA-6 wells. The 4 production wells are produced using an artificial lift in the form of a gas lift. The limited gas lift at the MRA Platform at 3.1 MMSCFD makes the production of wells at the MRA Platform not optimal because the wells in the MRA Platform are experiencing insufficient gas lift. Optimization of gas lift injection is obtained by redistribution of gas lift injection for each. The results of the analysis in this study indicate that the optimum gas lift injection for the MRA-2ST well is 0.5552 MMSCFD, the MRA-6 well is 1.0445 MMSCFD, the MRA-5 well is 0.7657 MMSCFD, finally the MRA-4ST well with gas injection. lift is 0.7346 MMSCFD. The manual gas lift in the MRA-4ST is also replaced based on an economic feasibility analysis to ensure that the gas lift injection for each well can be kept constant. The redistribution of gas lift carried out by the author has increased the total production rate of the MRA Platform by 11,160 BO/year or approximately USD 781,200/year. Keywords: Gas lift; Insufficient; Optimization

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

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.

Strengthening the Competitive Advantages of the Batik Creative Industry During Pandemic Hiras Pasaribu; Karyono Karyono; H. KRT. Nur Suhascaryo; Alp. Yuwidiantoro
International Journal of Entrepreneurship and Sustainability Studies Vol. 1 No. 2 (2021): December 2021
Publisher : Research Synergy Foundation

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31098/ijeass.v1i2.773

The obstacle for the creative batik industry during the Covid-19 pandemic is that it is not easy to reach the market. Because before the pandemic, the agents, buyers, and consumers could come to the place where the product was made. To get out of these difficulties, business actors must adapt to innovate, including by using business digitization technology, so that market coverage will be wider and building innovations so that product quality can compete. In order for SMEs to quickly adapt during the COVID-19 pandemic, they must join forces to form a community portal that drives the batik industry. This study aims to determine the effect of corporate governance, product innovation, digitalization-based information technology, and the effectiveness of management control on the competitive advantage of SMEs in the creative industry of batik craftsmen in districts and cities in Yogyakarta. The research method used is a survey method to 55 managers of 127 Creative Industry SMEs batik craftsmen in all districts and city of Yogyakarta. Primary data collection using a questionnaire with the Likert Scale. In accordance with the consideration of data values and hypotheses, this study uses an appropriate statistical analysis, namely the Partial Least Square (PLS) method. The results show that corporate governance has no significant effect on the competitive advantage of SMEs, while product innovation, utilization of information technology based on business digitization, and the effectiveness of management controls have a positive effect on competitive advantage.

Comparative Study of Plug and Abandonment Using Balanced Plug Cementing Method: Case Study of Well “NV-01” Field “NS” KRT. Nur Suhascaryo; CIIQA; Andi Novita Mama Anugrah
Scientific Contributions Oil and Gas Vol. 46 No. 2 (2023): SCOG
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.46.2.326

The NOV-01 well is a directional well that has technical problems (fish), namely the stuck pipe problem and the problem of high land use operational costs. Based on the results of the evaluation of the economic and risk technical aspects, a plug & abandonment (P&A) was carried out for the NOV-01 well. The purpose of this research is to compare the 3 stages and 5 stages in P&A work and their influence on work program planning and budgeting. The research methodology is qualitative and quantitative. The NOV-01 well plug & abandonment activity is carried out by preparing a work program plan such as determining the depth interval of the well to be plugged, the volume of cement slurry & additives, as well as the rig method which all refer to the existing standards and regulations, namely SNI 13-6910-2002 and NORSOK D-010. The results of a comparative study on P&A planning at 3 stages required 279 sacks of cement and 450 sacks of cement at 5 stages with a density of 15.8 ppg. P&A on well NOV-01 uses the rig method with a capacity of 450 HP. For 3 stages it takes 9 days and 5 stages for 11 days. Comparison of estimated costs for P&A of NOV-01 well, namely 3 stages of IDR 6,062,977,890.31- and 5 stages of IDR 8,374,824,218.62-. Well NOV-01, P&A which is suitable is 5 stages because there is an overpressured zone so that the cement plug is isolated.

Laboratory Studies for The Development of a Demulsifier in Handling Production Fluid Emulsions in The “SRG” Field KRT Nur Suhascaryo; Halwin Ariandi Siregar; Ridwan
Scientific Contributions Oil and Gas Vol. 45 No. 2 (2022): SCOG
Publisher : Testing Center for Oil and Gas LEMIGAS

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The “SRG” Oil Field is located in the South Sumatra basin, and the oil produced is classified as heavy oil and generally water-oil emulsion occurs. As a result of the formation of this emulsion which will cause corrosion of equipment in the field. The samples that have been taken in the field are then investigated in the laboratory of PT Farca Risa Sejahtera. First, perform BS&W testing on GS-belimbing and GS-11 oil samples to determine the water content and deposits present in the oil. The second is to determine the ratio of the amount of oil and formation water to be used in subsequent tests. The third selection of demulsifiers for formulation materials is based on the ability of water drop, clear water and interface. The four demulsifier formulations combine the demulsifiers that pass the selection into 5 formulas with the hope of uniting the advantages and covering each other’s shortcomings of each demulsifier that passes the selection. The fifth test is overtreated to determine the appropriate dose for the use of a predetermined demulsifier formula. Emulsion sample testing was also carried out on CGS oil samples (GS-belimbing oil and GS-11) plus the oil present in the pits. The six BS&W tests after using the new formula. GSbelimbing has a production rate of ±22,000 BFPD with a water cut value obtained from the separator test in the field and validated by the BS&W test in the laboratory of ±92%, the value of oil production in GS Belimbing is ±1760 BOPD. While the GS-11 has a production rate of ±33,000 BFPD with a water cut value of ±91%, the value of oil production in GS 11 is ±2970 BOPD. While the CGS has a fluid production rate of ± 58,000 BFPD with a water cut of ± 90%, the value of oil production at the CGS is ± 5800 BOPD. Formula code H5 with a composition of 10% (F13; water drop) plus 10% (1030; interface) and 80% (F-16; clear water) which was selected for GS-belimbing. The formula with code A1 which has a composition of 80% F-8 plus 10% 1030 and 10% F-16 was chosen for the GS-11. For the CGS, the S5 formula is 10% (F-16 clear water) plus 10% (1030; interface) and 80% (F-8; water drop). The results of the BS&W test after the new formula showed that there was no water in the oil in the centrifuge tube and it was stated that the BS&W value was close to 0%. There are 3 demulsifier products from the formulation, namely HAS-1 for GS-belimbing, HAS-2 for GS-11, and HAS-3 for CGS plus pit. The amount of HAS-3 demulsifier that needs to be injected into the CGS is 7.31 gallons per day (GPD). The number of HAS-1 demulsifier injected into GS Belimbing was 2.22 GPD, while the number of HAS-2 demulsifier injected into GS-11 was 3.74 GPD

Utilization of Crude Oil as an Alternative Oil Base Mud Drilling Operation by “VICOIL” Standard Drilling Simulation Rig in MGTM Well UPN “Veteran” Yogyakarta Education Park Mineral Geotechnology Museum Field KRT Nur Suhascaryo; Endah Wahyurini; Yuan Cahyo Guntoro
Scientific Contributions Oil and Gas Vol. 44 No. 2 (2021): SCOG
Publisher : Testing Center for Oil and Gas LEMIGAS

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Shale is one of the rocks that often causes drilling problems because shale tends to swell or swell when in contact with mud filtrate, mainly Water-base Mud (WBM). This study aims to determine how the performance of Oil-base Mud (OBM) based on Crude Coconut Oil (CCO) in overcoming the swelling problem. The methodology used consists of drilling simulation and cutting analysis in the X-Ray Diffraction (XRD) laboratory. The series of activities in the study began with the preparation of rock layers, followed by testing the penetration rate using Water-base Mud as a comparison. After cutting analysis was carried out in the XRD laboratory of UPN “Veteran” Yogyakarta with the Rigaku tool, then replaced the type of drilling fluid Oil-base Mud with basic materials alternative to Crude Coconut Oil (CCO) and followed by a penetration test. Rate of Penetration (ROP) test results from WBM with Rheology 1 at interval A or a depth of 1.96 ft-4.92 ft is 442.8 ft/h, Rheology 2 at interval B or a depth of 4.92-10.5 ft is 118.5 ft/hr on the first day. Swelling occurred and results in pipe sticking at depth of 6.5 ft. Based on the Bulk Mineral analysis, clay mineral content is 23.84%. Based on the Clay Oriented, smectite dominates the clay by 29.09%. Based on MBT, shale belongs to class B (illite and mixed-layer montmorillonite illite), where this mineral can expand. Based on a Geonor As test, 5.18% of the cutting can develop when exposed to water. The drilling fluid was replaced with Oil-base Mud based on alternative Crude Coconut Oil (CCO), and obtained ROP Rheology 1 at Interval A of 492 ft/h and Rheology 2 at Interval B of 480 ft/h. The results of the Compressive Strength test interval A on the first, third, and fifth days were 31,699 psi, 42,265 psi, and 52,831 psi. The results of the Compressive Strength test interval B on the first, second, and third days were 31,496 psi, 41,517 psi, and 52,971 psi. Based on clay mineral analysis and magnitude of ROP value, is known that Crude Coconut Oil (CCO) based Oil-base Mud is effective because during the simulation, there are no drilling problems, and the resulting ROP value is greater than the first day Water-base Mud.

PREDICTION OF ”RATE OF PENETRATION” (ROP) ON DRILLING FORMATION ”X” PROGNOSIS WELL ”YN2” BASED ON THE REPRESENTATIVE MODELLING FROM DRILLING FORMATION ”X’’ ACTUAL WELL ’’YN1’’ FIELD ’’IP’’ Suhascaryo, KRT. Nur; Sudarmoyo, Sudarmoyo; Pratomo, Inrianto
Journal TECHNO Vol. 6 No. 1 (2020): November
Publisher : Universitas Pembangunan Nasional Veteran Yogayakarta

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.31315/journal techno.v6i1.4224

Prediction value of the rate of penetration (ROP) in the drilling of the formation “X” well prognosis "YN2" in the field “IP” and the actual well "YN1" as a review of the selection of a representative Model-ROP at a depth of 2620 mbpl - 3000 mbpl in the "IP" field ". This study selected a representative Model-ROP from drilling the "X" formation of the actual well "YN1" in the "IP" field then predicting the rate of penetration (ROP) value in the drilling of the "X" formation of the "YN2" prognosis well in the "IP" field. ROPs used in this study include the Bingham Model (1966), Teale (2008) and Mottahari (2010). Prediction of the rate of penetration (ROP) value in the drilling of the "X" formation well "YN2" prognosis is done in stages including predicting the rate of penetration (ROP) value in the drilling of the "X" formation of the actual well "YN1" by collecting data including data on "YN1" actual well drilling includes bit records, drilling reports, well programs, and well profiles and then predicts the rate of penetration (ROP) value in the drilling of the "X" well formation "YN2" using drilling prognosis. Determine the drilling parameters needed to predict the value of the rate of penetration (ROP) has a difference in each model. In the Bingham model the parameters required include MD, WOB, RPM, T, and d-exp values. In the Teale model the required drilling parameters contain the actual MD, WOB, RPM, T, DB, and ROP values, MSE, μ and AB. In the Mottahari Model, the drilling parameters needed for MD, WOB, RPM, T, DB, actual ROP, σ, Wf (use function), G (model coefficients representing drillability), a = 0.50 and y = 1,50 is obtained from assumptions. In the Bingham Model has a coordination coefficient value (R2) = 0.9985, the Teale Model has a coordination coefficient value (R2) = 1 and the Mottahari Model has a co-coefficient value (R2) = 1. The ROP model that represents the drilling of the "X" formation Actual wells "YN1" can all be used or all Model-ROPs represent to predict the value of the penetration rate (ROP) in drilling the "X" formation prognosis of the well "YN2". Calculate the estimated penetration rate (ROP) in the drilling of the "X" formation prognosis of the well "YN2" using the Bingham, Teale and Mottahari models through the prognosis of the drilling "YN2".

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