OMV Petrom SA
OMV Petrom SA
Agency: European Commission | Branch: FP7 | Program: CP-FP | Phase: FoF.NMP.2011-3 | Award Amount: 5.04M | Year: 2012
MiRoR aims to develop a fundamentally novel concept of a Miniaturised Robotic Machine (Mini-RoboMach) system, that equipped with intelligence-driven and autonomous abilities, will be demonstrated for holistic in-situ repair and maintenance of large and/or intricate installations. This will be done via the following research steps: -Develop a novel concept of Mini-RoboMach, with unique complementary miniature systems: (1) novel free-leg hexapod (i.e. without base platform) for providing both walking and 6-axis processing capability; (2) an original stiffness-controlled flexible-arm robot for enabling snaking and 6-axis light processing ability. The complementarily means that a hybrid configuration of Mini-RoboMach, i.e. walk & snake-in can be utilised. -Develop MiRoR intelligent controller equipped with following key abilities: Self-positioning: enable walk and/or snake navigations to/from work and calibration of end-effectors on required features; Reasoning: decide on methods of accessing the working area (walking and/or snaking-in mode) while learning from these experiences. Planning: schedule task successions and optimise Mini-RoboMach path in reference to intervention on different places within the installation Adaptation: modify the parameters of treatment procedures for developing a self-protection ability of Mini-RoboMach in case it encounters harmful/unfavourable conditions. -Develop a unique virtual test bench for the hardware (e.g. Mini-RoboMach) and software (intelligent controller) of MiRoR so that its robustness and capability to work unsupervised within required harsh/remote workspaces can pre-assessed and corrected before its effective utilisation. -Demonstrate MiRoR by performing in-situ holistic repair/maintenance works (e.g. inspection and processing material deposition, removal) on high investment, large and/or intricate industrial such as (power plants, aero-engines, construction / infrastructure, offshore platforms, etc).
Bojar A.-V.,University of Salzburg |
Bojar A.-V.,Universalmuseum Joanneum |
Barbu V.,OMV Petrom S.A. |
Bojar H.-P.,Universalmuseum Joanneum
Geological Quarterly | Year: 2012
Detailed litho strati graphic data from a borehole in the Abràmut Basin, located in the northwestern part of Romania, has revealed the presence of turbiditic deposits containing several layers with tuff/tuffaceous materials in the lower Badenian. The age of these deposits is determined by the presence of the foraminifera Praeorbulina glomerosa and Orbulina suturalis. Detailed quantitative and qualitative X-ray diffraction data (XRD) on 10 different tuff layers situated at depths between 2450 and 2640 m show a mineralogical association comprising analcime, quartz, volcanic glass, smectite, mica, calcite, K-feldspar, glass and minor quantity of chlorite and albite. The presence of analcime suggests that the albite isograd for the interval studied has been never reached and the maximum temperatures have been lower than c. 125°C since the early Badenian.
Bega Z.,OMV PETROM S.A
Journal of Petroleum Geology | Year: 2015
Geological and geophysical data generated during the mid-1990s and early 2000s indicate that the Montenegro - NW Albania area may have hydrocarbon potential. Thrust-related structures and sub-thrust autochthonous Mesozoic platform carbonates in the Dinaride-Albanide fold-and-thrust belt are potential exploration targets. Potential play types include structurally inverted autochthonous platform carbonates both on- and offshore Montenegro, and platform build-up closures located offshore. Potential source rocks are of Cretaceous age, analogous to those at oil discoveries in the Southern Apennines, and have been modelled to generate economic volumes of light oils which may be trapped in fractured shallow-water carbonates and sealed by deep-water Oligocene shales. The Neogene succession in Montenegro is dominated by turbidite sandstones which have the potential to contain biogenic gas. Structural and stratigraphic traps have been identified in 2D and 3D seismic reflection profiles but no wells have tested this play to date. However the biogenic gas play is considered to be of less importance than the potential oil play involving Mesozoic carbonates. © 2015 Scientific Press Ltd 38 3 July 2015 10.1111/jpg.12613 Original Articles Original Articles © 2015 The Authors. Journal of Petroleum Geology © 2015 Scientific Press Ltd.
Dumitrescu E.,OMV PETROM SA |
Andronescu E.,Polytechnic University of Bucharest
Revista Romana de Materiale/ Romanian Journal of Materials | Year: 2016
This paper presents experimental results for liquid waste inertization in chemicaly bonded phosphate ceramic (CBPC). This process turns waste hazardous in non-hazardous waste. It was studied the inertization of liquid wastes containing heavy metals (Ba, Cd, Cu, Ni, Pb) with concentrations between 3000 mg/l and 30000 mg/l in CBPC versus inertization in portland cement paste. As the CBPC is a fast setting system, it was also used boric acid as retarder in concentration of 3% (based on the amount of magnesium oxide and potassium dihydrogen phosphate). To increase the efficiency of cadmium inertization, phosphoric acid was added. Also it was studied the influence of sodium dimetilditiocarbamate. It was determined the maximum temperature of the obtained systems, the setting time and compression strength. To determine the effectiveness of waste inertization it was performed leaching tests in water and in acid solution, and the obtained values were compared with regulated limits. © 2016, Procema SA. All Rights Reserved.
Adam J.,Dalhousie University |
Adam J.,Royal Holloway, University of London |
Krezsek C.,Dalhousie University |
Krezsek C.,OMV Petrom S.A.
Geological Society Special Publication | Year: 2012
This study integrates seismic interpretation and 3D analogue experiments monitored by digital image correlation techniques to investigate the evolution of the salt structures and the related depositional systems in the Laurentian Basin offshore Atlantic Canada. During the late Triassic, a layer of more than 3 km thick salt was deposited locally in a set of interconnected rift half-grabens forming a 50-70 km wide evaporite basin in the northern part of the Scotian Basin salt provinces. High sediment input in the Jurassic and early Cretaceous mobilized the salt into complex salt tectonic features, which suggest four kinematic domains with: (1) salt welds and pillows; (2) extensional diapirs and canopies; (3) contractional diapirs and folds; and (4) allochthonous salt nappe. The landward grabens trapped most of the Early Jurassic sediments by passive downbuilding into the salt with local extension. The expelled salt has been evacuated basinwards into a large contractional salt massif. The rapid advance of the allochthonous nappe was coeval with the Late Jurassic extensional collapse of the inflated salt massif due to seaward sediment progradation. Late Cretaceous and Tertiary progradation over the salt nappe caused extensional deformation with growth faulting and formation of minibasins on the secondary salt detachment level. © The Geological Society of London 2012.
Lechner M.,OMV Petrom S.A |
Uspanov M.,OMV Petrom S.A |
Ilchibayeva A.,OMV Petrom S.A
Society of Petroleum Engineers - SPE Europec Featured at 78th EAGE Conference and Exhibition | Year: 2016
This paper tells the success story of the Komsomolskoye field which was brought on stream in 2008, some 24 years after its discovery in 1984. Ramp up of oil production to peak of some 7,000 bopd was achieved within only five years. The field is located in a remote location of Western Kazakhstan - onshore on the Buzachi Peninsula, some 350 km from the regional city of Aktau and 110 km from the nearest village Kyzan. Road access from Kyzan is available only through a gravel road. The subsurface field development since 2008 consists of five horizontal oil producers, five vertical water injectors and two vertical gas injectors. The horizontal producers contribute the bulk of the field's oil production and were drilled from two well pads due to the semi-offshore nature of the Komsomolskoye field - seasonal flooding restricts access to a large portion of the surface area during half of the year. Produced gas and produced water are re-injected at the periphery of the field for pressure support, in addition to a weak aquifer support. Moreover, additional injection water is sourced from two dedicated shallow water wells and likewise injected into the reservoir. In addition to the five major horizontal producers, there is a pre-2008 well stock of ten vertical producers, which were successfully re-entered and of which eight were brought online to date. The favourable areal layout of the composite vertical/horizontal pattern plus the improved/enhanced oil recovery effects of water injection and miscible gas injection, respectively are key factors which enabled the following achievements: a. fast track ramp up of oil production rate to some 7,000 bopd within only five years b. zero gas flaring, due to gas re-injection and own consumption for power generation c. reservoir pressure throughout the field being safely above bubble point pressure d. a current recovery factor of 12% as of July 2015 e. a projected recovery factor by year 2039 of 36% for a development scenario with no additional wells f. a projected recovery factor by year 2039 of some 45% for a development scenario with 5 additional vertical producers As a case study, this paper illustrates a recent "fit for purpose" development project and may serve as an example for sustainable oilfield development in remote locations. It could be of benefit to organizations and individuals who are involved in the operation of comparable assets. Copyright 2016, Society of Petroleum Engineers.
Salcu M.,OMV Petrom SA
NACE - International Corrosion Conference Series | Year: 2013
This paper promotes a proprietary approach meant to increase the operation lifetime of the J55 tubing. The project driver was the premature and repeated failures of the J55 tubing, under different environments and various operating conditions. Detailed failure analyses have been carried out revealing the following damage mechanisms: wear, corrosion or both, assisted at times by erosion. The tubing failures, macro and micro investigated in the laboratory, together with the material tests, revealed that the technological and mechanical properties of steels are directly correlated to their microstructure. After studying several variations of steel microstructure, in relation with the features of the damaged tubing, the root cause of the failures was established and a corrective measure was taken, respectively the type of steel was modified from low carbon steel to medium carbon steel. The newly designed carbon steel was assessed as able to result in tubing failure rate decreasing. The laboratory research findings were validated by field trials where, by using the J55 tubing manufactured according to the new steel design (chemical composition and heat treatment), the lifetime improved significantly. The average Mean Time Between Failures (MTBF) corresponding to the field trials has increased by a factor of 4.5 for the most aggressive conditions. There are tubing strings still operating after 969 days. © 2013 by NACE International.
Lechner M.,OMV Petrom S.A |
Iltukov R.,OMV Petrom S.A |
Mukushev M.,OMV Petrom S.A
Society of Petroleum Engineers - SPE Europec Featured at 78th EAGE Conference and Exhibition | Year: 2016
Tasbulat field was one of the fields discovered during Soviet times in the 1960's by the regional exploration drilling campaign in the South Mangyshlak basin. It consists of multiple stacked oil and gas reservoirs of lower to mid Jurassic and mid Triassic age. The main reservoir in terms of oil production, initial oil in place, reserves and development progress is the Jurassic 10b which is an anticline shaped tidal-fluvial channel which is filled with under saturated oil. The lateral extension of the productive Jurassic 10b reservoir has been defined by a number of wells. Moreover, towards both flanks of the field the oil-water contact has been penetrated. Production from the Jurassic 10b reservoir commenced in the 1970's under natural depletion. Water injection was started in 2003 and gradually increased in terms of volume and number of injection wells. Breakthrough of injection and/or aquifer water has been observed in parts of the field. At present, the Jurassic 10b is being developed with 13 oil producers and 7 water injectors. A large portion of the producers have been hydraulically fractured which adds another layer of complexity. A recent multidisciplinary approach has significantly improved understanding of the Jurassic 10b by integrating static and dynamic data sets. The approach entailed a systematic review and interpretation of production, injection and well history based on which the lateral extension of the water flood front was estimated and drawn. The position of the flood front was subsequently confirmed and refined using dynamic reservoir simulation. At the same time, sedimentological core description identified a number of lithofacies which identified the Jurassic 10b as a fluvial-tidal dominated system. Based on this knowledge a conceptual sedimentological model for the Jurassic 10b was obtained. In addition, seismic attribute analysis was performed and several channel features were identified and picked. The features were then projected on maps of different reservoir properties (e.g. net sand thickness, pressure, productivity index, water flood front etc.) and it was checked whether correlations existed between features and properties. Using the integrated approach it was shown that the Jurassic 10b channels exhibit hydraulic communication over a significant area, possibly in both, vertical and horizontal direction. And furthermore, that seismic attributes such as similarity and spectrum decomposition could potentially be used for predicting channel extensions. This paper describes a real example how different methods and techniques such as seismic attribute modelling, lithofacies modelling, production surveillance/engineering, reservoir simulation can be practically used to define a field development strategy. Copyright 2016, Society of Petroleum Engineers.
Roncea C.,OMV Petrom S.A. |
Peball U.,OMV Petrom S.A.
Society of Petroleum Engineers - SPE International Conference on Health, Safety and Environment in Oil and Gas Exploration and Production 2010 | Year: 2010
This paper will describe ways to change the understanding and approach towards Corporate Social Responsibility in a National Oil Company from dependency/reactive towards strategic stakeholder engagement. The key tools and techniques applied for this change will be shown and examples of general use for application in mid size companies given. The paper will present: examples, the size order and the outline of the material/feedback of key Line Managers, templates/ tools for measuring performance and also the way to work on a performance driven change, examples of projects, ongoing stakeholder engagement and impact on the business. The paper will describe how this has been achieved: Keeping focused on best practice in industry and building a CSR strategic approach Developing Management Systems Conflict / Claims Management Internal/ external Capacity Building Stakeholders Engagement and Partnerships Keeping the good relationships with local communities and building, in time, a new understanding of social projects, of local development, of local partnerships. Quick fixes Continuous emergency help between neighbors Sustainable social projects implementation Education Capacity building Based on a 150 years oil history, 50 of them in a communist government, Company's relationship with the local communities were started with building the local infrastructure (roads, electrical, water, health, educational) and, during operations development, changing the structure of the local work force, the local networking and creation of dependence on oil industry. After privatization of the Company the understanding of the new management related to community relationships was based on the best industry practice: CSR and stakeholders engagement. The most challenging task in integration this approach was to start to change the culture of the company and community, having as starting point their common history. Copyright 2010, Society of Petroleum Engineers.
Chirkov M.,OMV Petrom SA |
Gonzalez J.,OMV Petrom SA
Society of Petroleum Engineers - SPE Reservoir Characterisation and Simulation Conference and Exhibition, RCSC 2015 | Year: 2015
This paper presents the implementation of pattern water flood in a very complex field in Romania. It's a multilayer formation with thin 2-5 m highly permeable (up to 2 Darcy) unconsolidated sands and unknown fluid contacts. Additionally high mobility ratio (around 50) and unfavourable rock wettability complicate the water flooding process. Project considered different injection schemes like peripheral, line drive and pattern. Integrated approach includes depositional environment analysis, 3D seismic interpretation, acquisition of complex log to investigate current oil saturation, field injectivity tests, pilot water injection and intensive surveillance plan. Water injection is part of field redevelopment plan and will increase recovery factor by 7.3%. Copyright 2015, Society of Petroleum Engineers.