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Pierre Bettinelli is currently the fiber optics and geophysics technical director for Schlumberger's Reservoir Performance Division. Located in Bucharest, Romania, his role consists of defining and implementing new workflows (both operational and software related), technical competency and training programs, hardware, and overall digital architecture of borehole seismic and fiber optics services. He has authored more than 20 technical papers and patent applications related to those topics. Prior to that, Pierre was the Africa geophysics domain champion. Pierre earned his PhD in geophysics from the Institut de Physique du Globe de Paris, California Institute of Technology, and Commissariat a l'Energie Atomique.
Florea Minescu, a longstanding SPE member and senior scientific researcher in the upstream sector, died 8 November 2021. Minescu was a professor at University of Petroleum and Gas in Ploiești, Romania. He graduated in drilling and exploitation of oil and gas reservoirs in 1971 and was employed at Research and Design Institute for Petroleum and Gas of Câmpina as a junior scientific researcher from 1971 to 1975 in the laboratory of Physical Parameters of Hydrocarbon Reservoirs. In 1975, he joined as a teaching assistant in the Drilling-Extraction department at Institute of Petroleum and Gas Ploiești. He then advanced through the teaching degrees in the university education system to become a professor.
Student Chapter Excellence Award Akademi Minyak dan Gas Balongan Alexandria University Almetyevsk State Oil Institute American University of Ras Al Khaimah Anambra State University Azerbaijan State Oil and Industry University Baku Higher Oil School Bandung Institute of Technology Batman University Bayero University, Kano Beirut Arab University China University of Petroleum (East China) Colorado School of Mines Curtin University Dawood Univ. of Engineering & Technology, Karachi Dibrugarh University Enugu State University Escuela Superior Politecnica del Litoral Faculdades Metropolitanas Unidas Federal University of Alagoas Federal University of Sergipe Federal University of Technology Owerri Federal University of Technology, Akure Future University in Egypt Gubkin University Igbinedion University Okada Indian Institute of Technology (ISM), Dhanbad Institut Teknologi Kalimantan Institut Teknologi Sepuluh Nopember (ITS) Islamic University of Riau Kuwait University Lebanese American University Louisiana State University Mit-World Peace University Montana Tech Nile University of Nigeria Nkumba University Pennsylvania State University Politeknik Energi dan Mineral (PEM) Akamigas Saint Petersburg Mining University Stanford U The American University of Iraq, Sulaimani The University of Trinidad & Tobago UCSI University Ukhta State Technical University Universidad Central del Ecuador Universidad del Zulia Universidad Privada de Santa Cruz, Bolivia Universidad San Francisco Xavier Universidade Federal de Campina Grande Universidade Federal de Pelotas Universidade Federal do Espirito Santo Universidade Federal do Rio de Janeiro Universidade Federal do Rio Grande do Norte Universiti Teknologi Malaysia Universiti Teknologi MARA (UiTM) Universiti Teknologi Petronas University of Batna 2 University of Bucharest University of Clausthal University of Houston University of Indonesia University of Kurdistan, Hewler University of Nigeria University of Uyo
Natural gas supply worries and elevated prices in Europe this winter could have lingering benefits for LNG suppliers and oil companies considering the development of oil fields in Europe, according to predictions from Wood Mackenzie. There is a lot of overlap in predictions of changes ahead for Europe and the world because dwindling gas in storage there has been the big driver for higher gas prices this winter. The overshadowing variable is the uncertain future of the Nord Stream 2 pipeline, whose future is tangled up with fears of armed conflict between Russian and Ukraine. The outlook offered a range of near-term scenarios, from lower prices if there is normal winter weather and clarity regarding when gas will flow through Nord Stream 2, to much higher prices if it is colder and the pipeline startup remains uncertain. For now, the reality is somewhere in between those extremes.
Well construction must always be executed safely at reduced operational costs, while ensuring appropriate wellbore quality and placement, per asset team requirements. Consequently, analysis of drilling efficiency, a critical performance indicator, has moved from maximizing rate of penetration (ROP) to improving cycle time. This recognition establishes the need for holistic solutions that address drilling challenges and promote efficient improvement strategies. This endeavor achieves well construction objectives, with associated reductions in cycle time and operations costs. Holistic solutions must start with project analysis and comparisons to offsets to identify application differences and similarities.
Well construction must always be executed safely at reduced operational costs, while ensuring appropriate wellbore quality and placement, per asset team requirements. Consequently, analysis of drilling efficiency, a critical performance indicator, has moved from maximizing rate of penetration (ROP) to improving cycle time. This recognition establishes the need for holistic solutions that address drilling challenges and promote efficient improvement strategies. This endeavor achieves well construction objectives, with associated reductions in cycle time and operations costs. Holistic solutions must start with project analysis and comparisons to offsets to identify application differences and similarities. These evaluations establish project risks, which ultimately have positive or negative effects on well construction. Consequently, implications from these risks (limiters and potential dysfunctions) must be addressed in the planning phase, or preparations must be made for their remediation during project execution. It is not enough to know what worked or failed. Rather, it is essential to understand why and how specific trends, events, results, or relationships come about. Effective and permanent remediations for all drilling dysfunctions must focus on identification and analysis of their initiating risks. Additionally, holistic solutions require detailed analysis of drilling systems, which include bits and reamers, bottomhole assemblies (BHAs), drive systems, hydraulics considerations, and drilling-parameter ranges and roadmaps. In addition to establishing component relevance, this effort must ensure their functional compatibility and effectiveness at addressing project risks. Drilling-parameter roadmaps must focus on well construction objectives and cycle time reduction, not ROP maximization. In this regard, cycle time is defined as the cumulative time associated with the following operations: pick up the BHA, drill out, drill ahead, trip out of hole, and run casing. Bits and BHAs have a major role in this discussion. The industry’s fast-developing capabilities with modeling and deeper under-standing of downhole tools and systems, coupled with applications based on big data analytics, are leading these efforts. The door has been kicked open. Let’s walk through. Recommended additional reading at OnePetro: www.onepetro.org. SPE 205965 - Oil and Gas Drilling Optimization Technologies Applied Successfully to Unconventional Geothermal Well Drilling by Junichi Sugiura, Sanvean Technologies, et al. SPE 205993 - Using Downhole Sampled High-Frequency Torsional Oscillation Measurements for Identifying Stringers and Minimizing Operational Invisible Lost Time by Andreas Hohl, Baker Hughes, et al. SPE 206064 - Mud Motor PDM Dynamics: An Analytical Model by Robello Samuel, Halliburton, et al.
Mitrea, I. (M. Chraief OMV Petrom S.A.) | Cataraiani, R. (M. Chraief OMV Petrom S.A.) | Banu, M. (M. Chraief OMV Petrom S.A.) | Shirzadi, S. (M. Chraief OMV Petrom S.A.) | Renkema, W. (M. Chraief OMV Petrom S.A.) | Hausberger, O. (M. Chraief OMV Petrom S.A.) | Morosini, M. (M. Chraief OMV Petrom S.A.) | Grubac, G. (M. Chraief OMV Petrom S.A.)
Abstract This Upper Cretaceous reservoir, a tight reservoir dominated by silt, marl, argillaceous limestone and conglomerates in Black Sea Histria block, is the dominant of three oil-producing reservoirs in Histria Block. The other two, Albian and Eocene, are depleted, and not the focus of field re-development. This paper addresses the challenges and opportunities that were faced during the re-development process in this reservoir such as depletion, low productivity areas, lithology, seismic resolution, and stimulation effectiveness. Historically, production from Upper Cretaceous wells could not justify the economic life of the asset. As new fracturing technology evolved in recent years, the re-development focused on replacing old, vertical/deviated one-stage stimulations low producing wells with horizontal, multi-stage hydraulic fractured wells. The project team integrated various disciplines and approaches by re-processing old seismic to improve resolution and signal, integrating sedimentology studies using cores, XRF, XRD and thin section analysis with petrophysical evaluation and quantitative geophysical analyses, which then will provide properties for geological and geomechanical models to optimize well planning and fracture placement. Seven wells drilled since end of 2017 to mid-2021 have demonstrated the value of integration and proper planning in development of a mature field with existing depletion. Optimizing the well and fracture placement with respect to depletion in existing wells resulted in accessing areas with original reservoir pressure, not effectively drained by old wells. Integrating the well production performance with tracer results from each fractured stage, and NMR/Acoustic images from logs enhanced the understanding of the impact of lithofacies on stimulation. This has allowed better assessment and prediction of well performance, ultimately improving well placement and stimulation design. The example from this paper highlights the value of the integrating seismic reprocessing, attribute analysis, production technology, sedimentology, cuttings analysis and quantitative rock physics in characterizing the heterogeneity of the reservoir, which ultimately contributed to "sweet spot" targeting in a depleted reservoir with existing producers and deeper understanding of the development potential in Upper Cretaceous. The 2017-2021 wells contribute to more than 30 percent of the total oil production in the asset and reverse the decline in oil production. In addition, these wells have two to four times higher initial rates because of larger effective drainage area than a single fracture well. Three areas of novelty are highlighted in this paper. The application of acoustic image/NMR logging to identify lithofacies and optimize fracturing strategy in horizontal laterals. The tracers analysis of hydraulic fracture performance and integration with seismic and petrophysical analysis to categorize the productivity with rock types. The optimization of fracture placement considering the changes of fluid and proppant volumes without compromising fracture geometries and avoiding negative fracture driven interactions by customized pumping approach.
Cirstian, Felicia (OMV Petrom SA) | Sauter, Jason Patrick (OMV Petrom SA, currently moved to: Three60 Energy Norway AS) | Vintila, Constantin (OMV Petrom SA) | Albulescu, Gheorghe (OMV Petrom SA, current moved to F&R) | Badescu, Cosmin Constantin (OMV Petrom SA) | Ene, Maximilian (Octagon Fundatii Speciale SRL)
Abstract Control/Tracking Number 21 ADIP-P-4946-SPE Abstract Description This paper will present a case study to describe the well integrity complications of an onshore gas well in Romania affected by a landslide event, the challenges overcome during the land consolidation/excavation around the well, and the remediation solution of the well's casings. After being severely affected by a landslide, the subject well stopped production having a surface deviation from the original position of 5m and a landslide plane at cca 25m. The primary scope of the project was to restore the integrity of the well in order to safely abandon the well so that people and environment were not exposed to risk or danger. The project was elaborated through a collaborative effort of multidisciplinary teams including company personnel, such as well integrity engineers, completion engineers, geologists, abandonment team members, civil engineers, HSSE and construction, as well as several service providers. As part of the Phase to consolidate the well's surrounding area, additional risk mitigations were identified through HAZID workshops and implemented, such as creating gas drainage shafts, utilizing ATEX equipment and cold cutting tools for casings, tools, and organizing Rescue People Services. These elements and more aspects were elements of safety included in the project to better assure the success. The project has several milestones, the first being the consolidation of the well surroundings using 33 cement pillar rings with a total diameter of 8m and depth of 32m. A gas relief column was necessary to ensure the gas infiltration was exhausted from the soil. Once the ring was formed around the well, the excavation commenced inside the ring, avoiding impact with the conductor pipe of the well. This activity posed notable HSSE challenges, requiring solutions derived from HAZID workshops based on evaluations of the various discipline teams and certified parties. Following the excavation, the planned casing remediation included cold cutting the casing using diamond encrusted equipment, due to the gas presence at the well area. Casing restoration was planned for use of bolts to reconnect the casings, thus preventing welding.
Abstract In an effort of maximizing the production from low permeability reservoirs in mature fields, operators often strive to implement innovative technologies and engineering approaches that can help achieve that goal. This paper presents an analysis of the temperature responses from bottom hole gauges of several horizontal wells that have been stimulated offshore Black Sea. The analysis covers the fluid cool down and heat back profile during stimulation and production. Ultimately, the analysis’ goal being to better understand the rheological properties of the stimulation fluid and enhance well clean-up by avoiding miss-allocation of temperature ranges during fluid testing for when the well is brought on production. Based on available data from bottom hole gauges implemented in the horizontal wells stimulated in the Black Sea, an analysis of the temperature gauge responses has been performed. The analysis includes a workflow of temperature change validation per well, considering fluid pumped per port in stimulation phase and fluids produced per port in production phases. The fluid production allocation per port was done utilizing chemical tracer technology results. Stimulation treatments in the same reservoir offshore Black Sea, Romania have been analyzed in terms of bottom hole gauge readings of temperature during the stimulation fluid pumping and during the early production period of each well. A workflow was implemented on each well to correlate fluid per stimulation stage pumped to temperature changes during the treatments. Similar approach was used to correlate the temperature heat back profile during the shut in of wells in the initial 48 hours for proppant curing to the production phase clean-up of the wells. The observed cool down during pumping was of no surprise, but the heat back indicated a slower process of warm back that affects the stimulation fluid testing approach and the understanding of possible near wellbore pressure differentials caused by misallocation of temperature range testing of pre job rheology tests. A combination of temperature data with diagnostic tools and the pertaining analysis will provide a better description of wells’ performance. In conclusion, misinterpretation of modelled cool down and reservoir heat back can lead to erroneous understanding of fluid clean up, ultimately affecting reservoir fluid inflow. Understanding the areal temperature response helped optimize fluid testing approach and plan for better clean up. The approach and the sensitivity analysis results are beneficial in understanding the temperature behavior during treatment pumping and production of stimulated wells. This process can enhance an engineer's approach in scrutinizing stimulation fluid testing for improved post stimulation clean up.
Hydraulic proppant fracturing is an effective tool in mature, low-permeability reservoirs found in the Pannonian Basin. Fracture-geometry-control (FGC) techniques limit increases in water cut. The complete paper describes the first implementation of a solution to control fracture height for conventional wells in the Pannonian Basin.