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Panhar M.L.,ConocoPhillips | Rahmadona D.,Pertamina Hulu Energi
Society of Petroleum Engineers - SPE/IATMI Asia Pacific Oil and Gas Conference and Exhibition, APOGCE 2015 | Year: 2015

In September 2013, North Senoro development drilling of JOB PERTAMINA - Medco E&P Tomori Sulawesi operated Senoro Field - Central Sulawesi, Indonesia commenced when the rig was rigged up over a rig base in Well B Cluster with 8 new well slots available. The well slots were the 20″ conductors, piled when the project was still in site preparation phase. Drilling commenced with objectives of drilling, completing and testing 6 new directional wells and 1 re-entry wells. The objective of the Field development was to have high gas production rates available when JOB PERTAMINA - Medco E&P Tomori central processing facility and Donggi Senoro LNG Plant was completed and started in first week of January 2015. Since all wells had to be drilled before first production, and require few weeks to connect the wells with central processing facility then all effort was addressed to optimized operation, shortening operation time and avoid any incident or accident. Walker Rig and Batch Drilling System were implemented to fulfill the entire objective and minimize costs. The Batch Drilling System was applied based by the availability of designated well slots in Well B Cluster. These well slots position were placed based on planned operation which expected to complete 4 first wells (Batch Group 1) and do well testing while at the same time, the rig was moved to the other side of 3 remaining wells (Batch Group 2) and drill the wells. In planning this system, all risk had to be considered when performing simultaneous operation of drilling and well testing (SIMOP); including when there was well control situation since North Senoro Field is a gas field with total loss reservoir and 2,900 psi reservoir pressure. By utilizing Walker Rig and Batch Drilling System, JOB Pertamina - Medco E&P Tomori Sulawesi has been able to save moving days from 56 days to actual 15.56 days, saving at least +/- USD 1.3M and achieve HSE performance 1,923,683 man hours without loss time. Copyright 2015, Society of Petroleum Engineers.


Subekti N.,Pertamina Hulu Energi | Rifandi I.,Pertamina Hulu Energi
Annual Conference of the Australasian Corrosion Association 2014: Corrosion and Prevention 2014 | Year: 2014

Developing corrosion integrity management for forties oilfield requires an understanding of the specific threats, their relationship to the overall condition of the equipment, and the mitigating measures required to assure safe reliable operation. In order to ensure effective asset corrosion integrity management, it is imperative that a fully integrated corrosion and integrity management system should be established. The fundamental purpose of such a system is to regulate and co-ordinate all activities and bodies which play a part in the management of asset integrity. This approach generates a degree of synergism which is not afforded when seemingly discrete activities remain disparate. This paper presents a detailed discussion of how to manage corrosion and integrity management system and demonstrates the interaction of the various activities which comprise the corrosion and integrity management system. The case studies are included, present the method to assess the integrity of a pressure vessel and flowstation piping. It is the hope of the author that the approach presented in this paper will foster further developments and advance corrosion and integrity management system.


Widyatmoko A.B.,Pertamina Hulu Energi | Rahmadona D.,Pertamina Hulu Energi
Society of Petroleum Engineers - SPE/IATMI Asia Pacific Oil and Gas Conference and Exhibition, APOGCE 2015 | Year: 2015

North Senoro Gas Field is located onshore, operated by JOB PERTAMINA - Medco E&P Tomori Sulawesi. The aim of North Senoro Development is to produce gas from limestone reservoir (Mentawa reef), member of Minahaki formation to fulfill gas supply commitment to Donggi Senoro LNG Plant. This field was discovered by Well A wildcat well in April 1999. Afterward, five successful delineation wells have been drilled and tested in year 2001, 2003, 2005, 2007, and 2009 named Well B, Well C, Well D, Well E, and Well F. Those wells used 7″ liner carbon steel material. Fluid analysis shows existence of H2S up to 0.06 Mol %, CO2 up to 2.16 Mol % in gas stream and Cl content in produced water up to 15,531 mg/L. Reservoir pressure is 2900 psi and temperature is 2120 F. Based on North Senoro reservoir fluid characteristic which have H2S and CO2 content, best recompletion method should be chosen to convert old exploration wells into production wells with good performance and cost effectiveness. Well known recompletion methods are Monobore and Side Track. Recompletion methods using Tie Back Liner Mechanism was an alternative solution utilize in this project to convert 3 existing/exploration wells into production wells with good performance and cost effectiveness. Recompletion method using tie back liner mechanism was successfully installed in 3 wells. Those wells had been produced since December 2014 to supply Donggi Senoro LNG Plant. Copyright 2015, Society of Petroleum Engineers.


Yananto H.,Pertamina Hulu Energi | Girindra Y.,Pertamina Hulu Energi
Society of Petroleum Engineers - SPE/IATMI Asia Pacific Oil and Gas Conference and Exhibition, APOGCE 2015 | Year: 2015

A study was initiated to evaluate the benefit of low capital cost and low maintenance cost technologies to rehabilitate pipelines in marginal fields to keep them running profitably and with an attractive return on investment (and with no sacrifice to safety and environmental risks). The challenge is to have a new technology with lower "Total" cost from design, procurement, installation, operation and maintenance during its life time. In the appraise stage, several technology options were considered to select the best option to maintain the pipeline; API 17J Flexible Pipe with specific design for shallow water is the alternative option compared to traditional rigid carbon steel pipeline. The assessment process started with pipeline technology update, followed by technical compatibility/acceptance, commercially available pipe sizing, installation total cost comparison, installation schedule, and operation-maintenance. The decision will be taken by decision tree using Expected Value Decision Analysis. The expected value of each option included CAPEX, OPEX, NPV, and all quantified aspects and risk. From the assessment it was conluded that flexibles pipe has more advantages compare to rigid pipes in term of CAPEX, OPEX, resistance to corrosive fluid, ease of installation, ease of repair and maintenance, and ease of decommissioning. The capital cost for 6″ F2-FP Flexible pipe is US$ 8.5 million with NPV US$ 37.4 million and IRR 31.7%. The expected monetary value of 6″ flexible pipe in decision tree analysis is US$ 27.5 million, the highest among other two options. The flexible pipe is feasible to be applied in F2-FP pipeline replacement project. Copyright 2015, Society of Petroleum Engineers.


Tobing J.,Pertamina Hulu Energi | Tanjung E.,Pertamina Hulu Energi
Society of Petroleum Engineers - SPE Western Regional / Pacific Section AAPG Joint Technical Conference 2013: Energy and the Environment Working Together for the Future | Year: 2013

One of the drilling challenge in Kilo Field of Offshore North West Java Indonesia is unstable hole condition. The critical formation is named Main Massive with the dominant clay-rich shale lithology. The unstable hole had caused stuck pipe, casing delays, loss of expensive tools in the hole, and undesirable sidetracks. Recently, there were 2 wells was drilled in Kilo Area. Based on the offset wells data drilled from this platform, there were some wells running in normal operation and the others were having unstable hole problems. All of the offset wells were using dispersed water based mud system in which generally, the drilling operation of those offset wells could be managed until casing run to the bottom. The recent 2 wells encountered unstable hole problem are KKNA-5 and KKNA-3ST development wells. KKNA-5 was designed to drill from the new slot using the same mud system as the offset wells from surface until intermediate section. In production section, mud system was changed to inhibited polymer referred to laboratory test result of cutting samples from surrounding area. However the unstable hole problem was still happened causing stuck pipe and BHA lost in hole. KKNA-3ST as reentry well also encountered same problem. The production section was drilled using inhibited mud system; however the unstable hole was uncontrolled while running the casing. The casing was parted and left in hole. The sidetrack drilling was decided using previous dispersed mud system, but again the casing was set shallower due to unable to run until casing point. Preliminary root-caused analysis led to the mud material quality. However, following other drilling wells in other fields was drilled without similar drilling problem in Kilo area, which mean the uncertainty or material quality was diminished. The deeper engineering analysis was also conducted without carrying out unstable hole problems. This field case study presents a new drilling challenge in Kilo Field. Further drilling study especially related to time-dependent wellbore instability shall be conducted, considering drilling operation of some offset wells was running smoothly. The integrating geomechanic study with drilling fluid design shall mitigate unstable hole problems in this area. Copyright 2013, Society of Petroleum Engineers.


Rizkiyadi M.E.,Pertamina Hulu Energi | Setiawan M.A.,Pertamina Hulu Energi
Society of Petroleum Engineers - Abu Dhabi International Petroleum Exhibition and Conference, ADIPEC 2015 | Year: 2015

Objective of this paper is to highlight the problem of high concentration Hydrogen Sulfide (H2S) in depurator flotation unit system at Oily Water Treatment Plant (OWTP) Pertamina Hulu Energi Offshore North West Java (ONWJ), Central Plant Processing Facilty and identification impact quality of dry crude to storage. The methodology to reduce accumulation Hydrogen Sulfide in depurator unit is using venturi tube blower system. An innovation to install venturi tube blower has been tested based on degradation of concentration and dry crude quality in Floating Storage Offloading (FSO) Arco Ardjuna prior to export. The result of application venturi tube blower showed that accumulation of Hydrogen Sulfide gasses down to the lowest point and was found very effective. Conclusion from this paper are application of venturi tube blower has proven to capture and remove the concentration Hydrogen Sulfide up to 80% and in economical aspect the requirement cost for modification are very minimum. Copyright 2015, Society of Petroleum Engineers.


Yananto H.,Pertamina Hulu Energi | Girindra Y.,Pertamina Hulu Energi | Kennedy S.,Polyflow Global
Proceedings of the Annual Offshore Technology Conference | Year: 2015

A study was initiated to evaluate the benefit of low capital cost and low maintenance cost technologies to rehabilitate pipelines in marginal fields and apply artificial lift solutions to marginal wells to keep them running profitably and with an attractive return on investment (and with no sacrifice to safety and environmental risks). The challenge is to have a new technology with lower "Total" cost from design, procurement, installation, operation and maintenance during its life time. In addition, the technology must meet the required planned production flow, which, in some cases, can be higher than current flow. RTP per API15S was shown as the most cost effective solution in rehabilitation of pipelines in marginal fields. Introduction Offshore North West Java (ONWJ) field has been operated for more than 40 year and comprises 9 flow-stations and hundreds of NUI platforms. About 600 pipelines are used for transporting either fluid or gas. At least 5 pipelines have to be repaired or replaced due to integrity of aging facilities. As a mature field, any additional Capex to maintain base production shall be carefully assessed. Figures 1 and 2 show examples of "F" field network. The objective of this paper is to evaluate and select the right existing pipeline candidates that are suitable for pipe in pipe pull through method. Success criteria include acceptable hydraulics which meets line requirements, flow velocity minimum performance to minimize maintenance expenses, material selection to eliminate chemical treatment and capital cost estimates to demonstrate a beneficial return on investment to ONWJ. Pipeline Replacement Strategy The replacement strategies followed by ONWJ are according to the following steps, i.e. - To utilize the existing pipeline casing as the conduit for RTP flow line pull through method. Copyright © (2015) by the Offshore Technology Conference All rights reserved.


Abrar B.,Pertamina Hulu Energi
73rd European Association of Geoscientists and Engineers Conference and Exhibition 2011: Unconventional Resources and the Role of Technology. Incorporating SPE EUROPEC 2011 | Year: 2011

This Paper has presented the Workflow from a case study of Integration of Log Data Analysis And Facies Core to Define Electrofacies, Using MRGC (Multi Resolution Graph-Based Clustering) Method, in Galaxy Field, Central Sumatera Basin, Indonesia. With requires an accurate geological description of reservoir characteristics, especially porosity-permeability distribution and facies estimation. Gathered of Permeability, Porosity and Volume of Shale are then clustered by MRGC to simplify the determination of facies. So Far, in this field, the result of electrofacies used combination of porosity, permeability and volume of shale clustering, its useful for define facies. Application from this paper to gave us a better understanding of relationship among porosity, permeability, and sedimentary facies that to be used for geological and petrophysical modeling and proposed the reservoir for water injection project to improve oil recovery.


Utomo R.,Pertamina Hulu Energi
73rd European Association of Geoscientists and Engineers Conference and Exhibition 2011: Unconventional Resources and the Role of Technology. Incorporating SPE EUROPEC 2011 | Year: 2011

A detailed fracture characterization of Saraburi Limestone outcrops was made in a Muak Lek quarry and a Chumphae quarry in order to develop a facies-based understanding of fracture distribution in the exposed Permian limestones of Thailand. The work integrated petrographic, XRD, stable isotope determinations with three spectral gamma ray profile and pseudo-FMI log. In the Muak Lek area, it clear that fracture density has a strong match to the host rock type; the fine-grained lithofacies, with their thinner beds and smaller elastic moduli, show higher fracture density and smaller apertures compared to the coarser-grained lithofacies. In contrast to Muak Lek, the Chumphae outcrop, because of pervasive diagenetic-silica cementation, shows similar fracture densities across the various lithofacies. In summary, study of outcrop analogs to fractured Permian carbonates, which constitute potential reservoirs in the subsurface of central and northeastern Thailand, show that the fracture density and fracture aperture are responses to variations in the mechanical strength. In some diagenetic situations these relationships are resolvable in a gamma log, in others they are not. This has significant implications when a gamma log is used to cluster FMI-based fracture observations in wells penetrating subsurface platform carbonates.


Taufiqurrachman H.,Pertamina Hulu Energi | Tanjung E.,Pertamina Hulu Energi
Society of Petroleum Engineers - International Petroleum Technology Conference 2013, IPTC 2013: Challenging Technology and Economic Limits to Meet the Global Energy Demand | Year: 2013

Offshore North West Java (ONWJ) is one of Indonesia's mature fields. Mature field developments in this level require a simple, fast and cheap well design to be economically interesting. The highlight in this paper is drilling top-hole section optimization by applying Casing while Drilling (CwD). The main 2 challenges in drilling top-hole section in ONWJ are gumbo attack and loss circulation. Past mitigation was drilled a small pilot hole to reduce cutting amounts then enlarge the open-hole by hole opener. However it did not solve the problem completely. The gumbo attack still occurred, some associated non-productive rig times still happened and safety concern to clean the plugged flowline still existed. KCl Polymer mud system was not an option due to loss circulation existence, where hole will collapse when seawater is displaced to keep hydrostatic. CwD were executed successfully at 2 exploration wells in Q3 2011 by implementing Vertical-CwD (VCwD). First trial of VCwD was run only in surface section with a simple cutters casing shoe mounted on the end of a casing string. Further improvement in drillshoe, BHA and mud design was made on the second trial to extend the interval and improve overall ROP. The second trial of VCwD managed to safely drilled almost 3000ft of combine surface and intermediate vertical section with overall ROP of 60fph, where at surface section CwD was performed blindly due to total loss circulation and it was successfully cemented (no annulus pressure trap so far). The second trial has saved the company over 1MMUSD compared to conventional drilling. In 2012, numerous trials of Vertical Casing while Drilling (VCwD) have been performed for exploration and development wells in offshore North West Java. CwD is heralding the way to the future of drilling in mature fields of Offshore North West Java. Copyright 2013, International Petroleum Technology Conference.

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