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Jakarta, Indonesia

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. Source

Hamdi E.,Pertamina Hulu Energi | Dirgantara T.,Bandung Institute of Technology | Setiawan H.,Bandung Institute of Technology
ASME 2014 12th Biennial Conference on Engineering Systems Design and Analysis, ESDA 2014 | Year: 2014

Finite element method modeling for flexible coupling of gas turbine compressor package installed in one of PT. Pertamina Hulu Energi Offshore North West Java (PHE ONWJ) facility has been completed. The model delivered result which is in acceptable level of accuracy as compared to manufacturer operating guideline as well as follows in general to guidance of API 671 widely used as industrial code and standard for coupling. The scope of modeling is including the static and dynamic analysis for both perfectly aligned (used as base reference) and for misaligned condition. The scope covers as well the cyclic stresses which in turns determining the disc pack life time. The major challenge on the modeling is mainly to vary the degree of misalignment and how to distribute the additional load to the flexible part of the coupling causing deformation of disc pack. The static analysis modeling reveals that the stresses are still below the yield point when aligned perfectly even in high vibration situation, but when it reaches up to 0.1 degree of misalignment with maximum torque the Von-Misses stress has exceeded the yield. The dynamic analysis shows that for similar 0.1 degree the fatigue factor of safety also has exceeded API 671 requirement. Following the actual coupling failure events, the model has successfully indicated the location of highest stress correlated to crack initiation as compared to actual cracks found in existing discs specimen. The model has been validated as well with the result of material analysis of the damaged flexible discs showing that the failure occurred due to over misalignment. In addition to manufacturer manual description, the model is capable to recommend maximum angular misalignment that need to be monitored during compressor operation and provide basis to calculate safety factor to comply API 671 guideline. As oil and gas exploration and production company which focus on possible highest energy efficiency of its operating platforms- which all is located offshore, the work leads a way in integrity management of turbo-machinery equipment in order to maximize running time and minimize production shutdown. Copyright © 2014 by ASME. Source

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. Source

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. Source

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. Source

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