bluuebunny/crossref_metadata_2025_split huggingface dataset:
Seismic Characterization of the Shuaiba Formation in the Western Region of UAE, a Predictive Tool to unravel Shuaiba Facies Mosaic?
Authors: Zampetti Valentina , Perrotta Sonia , Chaari Ghassen , Krayenbuehl Thomas , Braun Matthias , Neves Fernando , Hu Jialiang 
Published: November 2017

Abstract
The Aptian Shuaiba Formation is among the most important reservoir units in the Middle East. Despite being extensively studied in recent years (Droste, 2016; Murris, 1980; Droste and van Steenwinkel, 2004; Yose et al., 2006;2010; van Buchem et al., 2002, 2010; Vahrenkamp, 1996), the interpretation of the Shuaiba depositional geometries, and specifically those associated with Shuaiba reservoirs, remains challenging in the seismic realm due to their intrinsic heterogeneity, variability and limited thickness.
An integrated and iterative analysis including regional geology, well and seismic data was conducted to unravel the internal depositional geometries and associated reservoir properties for the Shuaiba Formation in the western region of UAE. In the study area, spatial distribution and geometry of the Shuaiba seismic facies was mapped in detail using full-stack reflectivity, discontinuity, curvature and spectral decomposition seismic attributes and further integrated with available well data and analogues. The Shuaiba Formation is expressed on seismic by mounded facies characterized by an irregular appearance, with discontinuous outline of sub-transparent reflectors, crossing reflectors and a larger thickness than the surrounding facies. Reflectors may locally coalesce and form mounded features up to 70 ms thick. The areas between mounds are characterised by sub-parallel to inclined reflections. The latter could be interpreted as clinoforms, prograding from the isolated nucleation areas to their deeper surroundings. The base of the mounds is located just above the top Thamama B/base Shuaiba reflector and the top coincides with the top Shuaiba. Well data suggest that these mounds consist usually of Bacinella/Lithocodium facies and rudists. The detailed 3D seismic interpretation of the Shuaiba reservoir geometries indicates a complex depositional architecture, which results in a variety of potential stratigraphic trap geometries and a heterogeneous reservoir property distribution. The proposed integrated workflow can therefore be used as a predictive tool to unravel further prospectivity in the Shuaiba Formation and in similar complex carbonate reservoirs, as well as to significantly improve reservoir property distribution prediction in static models.
Benefits of Implementing Integrated Reservoir Management IRM Framework by Closing Gaps in People, Process and Technology - Second Act
Authors: Marzouqi Mohamed Al , Bahamaish Jamal , Saputelli Luigi 
Published: November 2017

Abstract
Integrated Reservoir Management (IRM) work processes enable upstream assets in sustaining production targets through the proper identification of performance improvement opportunities. IRM framework have been established since 2015 to assure quality and consistency in reservoir management best practices.
This paper shows the success cases where such complex management framework was deployed across 19 assets in a short period of time and minimum resources, reaching over 400 users including technical and business level personnel.
It was demonstrated through key examples how IRM helped the assets in (a) shortening learning curves, and hence reducing the total cycle time, resulting in increased productivity, (b) measuring KPI’s that cultivate proper behaviors to integrate the right multi-disciplinary efforts in delivering consistent results and (c) fostering a new culture that continuously challenge status quo with consistency.
1.800 Million $ Cost Optimization in ADNOC LNG Plant Maintenance by Applying Creative Ideas Kaizen
Authors: Ali Ahmed Al 
Published: November 2017

Abstract
Objective:
As UAE government has announced 2015 as innovation year and in line with ADGAS / ADNOC innovation strategy (kaizen) we have implemented creative ideas.
During day to day maintenance activities we came across many break downs and repeated problems.
These repeated problems consume a lot of man hours and materials.
To rectify these problems we have implemented many innovative solutions that resulted in plant reliability and cost optimization by using internal resources.
Method: This study explains the disadvantages of old system and how we resolved using innovative ideas of the following projects:Un availability of Instrument & plant air during compressor shutdown in utility plant, Consume more energy while using portable air compressor.Consuming energy for the VRU compressor panel which was not in use.Pilot flare Auto Ignition system fail to operate due to corroded tubing's and junction box.Un availability of pump well pressure valves feedback indication due to repeated mechanical lever failure.Maintenance team exposure to sulphur toxic gases.Delay the LNG / LPG & paraffinic naphtha ships loading during SOV failure.More energy consumption to remove the Sulphur blockage from the loading line.Consuming more manpower and materials.Non availability of deluge valve during fire emergency.Fuel gas loss for Utility plants due to Boil off Gas compressor trip.Failure of Sulphur inlet valve.
Results: Cost optimization of more than $ 1,800,000; enhance plant reliability and knowledge gained from accomplishing these projects. This knowledge will be shared with the audience.
Novel: The paper will encourage other Oil & Gas companies to implement innovative ideas to achieve maintenance and operational excellence.
Contents: General idea about Instrumentation in Oil & Gas General idea about our plant loaction and environement New back up air line Removal of redundant VRU panel Replace corroded SOV boxes at plant 19 Replace pump well pressure control valves limit switches Replace & Relocate Sulphur shore slope tank RTD junction boxes Sulphur loading line skin temperature Sulphur loading arm control panel LNG tank D-103 deluge valve cable fault Repeated trip of 49-K-0001 compressor Failure of Sulphur acid gas ESD valve. How much we have saved?
Enhanced Oil Spill Detection and Consequence Management Through Satellite Imagery
Authors: Ayasse Rob 
Published: November 2017

Abstract

Objectives/Scope
To outline how satellite technology can enhance oil spill detection and therefore consequence management, drawing on a comparative study of options by the Norwegian association of oil and gas operators; to use examples of successful detection in 2016 and 2017 in Saudi Arabia, the UAE and Qatar; to outline how collaborative satellite monitoring could be adopted by countries around the Arabian Gulf, possibly through ROPME/MEMAC or RECSO, patterned on Norway and the European Maritime Safety Agency's multistakeholder approach.

Methods, Procedures, Process
The presentation will begin with an explanation of the key benefits of using satellite technology for oil spill monitoring and enhanced consequence management, as well as the identification of likely polluters. It will use the case study method to demonstrate how it has been done successfully in 2016 and 2017 in Saudi Arabia, the UAE and Qatar; and finally, it will then provide a vision of how collaborative satellite oil spill monitoring and polluter identification could be used to great effect in the Arabian Gulf, by organizations such as ROPME and RECSO, modelled on examples from the Norwegian Clean Seas Association for Operating Companies (NOFO) and the European Maritime Safety Agency's (EMSA) multilateral monitoring program.

Results, Observations, Conclusions
The results of the paper will be twofold. First, the results of a recent 3year study by the association of Norwegian oil and gas operators, which looked at all the different technologies for detecting oil slicks (passive buoys, platform radar, maritime patrol aircraft, surface vessels and satellite imagery), examples will be summarized. That study concluded that satellite-based detection offers the best ratio of price to operational effect. Second, show examples of successes in identifying largescale oil spills in the Arabian Gulf with satellite imagery, such as the massive-scale blowout on an Iranian platform that happened on or about 8 March 2017, and which sent 9 separate oil slicks drifting towards the UAE. Other examples from Saudi Arabia, Qatar and the UAE will also be used, including how polluting vessels off the coast of Al Fujairah have been successfully identified. Against the background of these results, a conclusion will be drawn, which is that significant benefits would accrue from the countries in the Arabian Gulf adopting a collaborative oil spill monitoring program based on effective satellite technologies. This challenge is particularly pressing given that an oil spill at one end of the Gulf will inevitably threaten beaches and delicate marine ecosystems at the other end.

Novel/Additive Information
While standard in Europe since 2007, use of satellite-based monitoring in the Gulf is neither widespread nor wellknown. This presentation aims to address that knowledge gap.
A Field Case Study of an Interwell Gas Tracer Test for GAS-EOR Monitoring
Authors: Sanni Modiu , Abbad Mohammad , Kokal Sunil , Ali Razally , Zefzafy Ibrahim , Hartvig Sven , Huseby Olaf 
Published: November 2017

Abstract
Tracer technology has evolved significantly over the years and is now being increasingly used as one of the effective monitoring and surveillance (M&S) tools in the oil and gas industry. Tracer surveys, deployed as either interwell tests or single-well tests, are one of the enabling M&S technologies that can be used to investigate reservoir connectivity and flow performance, measure residual oil saturation, and determine reservoir properties that control displacement processes, particularly in improved oil recovery (IOR) or enhanced oil recovery (EOR) operations.
As part of a comprehensive monitoring and surveillance program for a GAS-EOR pilot project, an interwell gas tracer test (IWGTT) was designed and implemented to provide a better understanding of gas flow-paths and gas-phase connectivity between gas injector and producer pairs, gas-phase breakthrough times ("time of flight"), and provide pertinent data for optimizing water-alternating-gas (WAG) field operations. Additional objectives include the detection and tracking of any inadvertent out-of-zone injection, and acquisition of relevant data for gas reactive transport modelling. Four unique tracers were injected into four individual injectors, respectively, and their elution were monitored in four "paired" updip producers.
In addition to the reservoir connectivity and breakthrough times between the injector and producer pairs, the results showed different trends for different areas of the reservoir. The gas-phase breakthrough times are slightly different from the water tracer breakthrough times from a previous inter-well chemical tracer test (IWCTT). Residence times for the tracers indicate different trends for three of the injector-producer pairs compared to the last pair. These trends reflect and support conclusions regarding reservoir heterogeneities also seen from the previous IWCTT, which were not anticipated at the beginning of the GAS-EOR pilot.
This paper reviews the design and implementation of the tracer test, field operational issues, analyses, and interpretation of the tracer results. The tracer data has been very useful in understanding well interconnectivity and dynamic fluid flow in this part of the reservoir. This has led to better reservoir description, improved dynamic simulation model, and optimized WAG sequence.
An Automated Approach to Well Design: Using a Reservoir Simulator and Nodal Analysis
Authors: Noor Zainub , Khoriakov Vitaly , Boisvert Ian 
Published: November 2017

Abstract
Reservoir simulation is becoming increasingly complex because of more advanced wells in the fields, including intelligent and multilateral wells. Advanced completions are also evolving to increase recovery efficiencies. This increasing complexity presents two difficulties, which include the design of advanced completions within reservoir simulators and increased simulation runtime. To describe a well in a reservoir model, a reservoir engineer typically defines a network of hundreds of nodes using keywords and specifies properties for each node. This is a cumbersome and error-prone process. Additionally, detailed well models can slow down reservoir simulation and often cause poor convergence.
A new iterative round-trip approach has been implemented, in which an engineer imports an initial reservoir model into a nodal analysis simulator that models flow from the reservoir through complex completions to the wellhead. The simulator accurately models well production in steady state and designs completion strings in detail. After the design is complete, the nodal analysis simulator converts the well model into reservoir simulator keywords that are imported into full-scale simulations for transient analysis.
Using this method, reservoir simulators can also model multiple annuli, which was not feasible previously. Highly detailed well models of several thousand nodes that accurately describe completion strings can be generated automatically.
Reservoir engineers typically do not possess complex knowledge of well design because this is usually performed by completion/production engineers, who seldom have access to a reservoir simulator. Consequently, they have a limited ability to experiment with different well designs. This paper presents an approach that helps facilitate reservoir and production engineer collaboration, thus helping enable fine-tuning of final completion designs to maximize production, prevent early water/gas breakthrough, and increase overall recovery. This paper describes the application of the new process in an openhole well and presents various completion designs of the same well.
Oil Producer Tie-in Modular Skid
Authors: AlAwadhi Ammar 
Published: November 2017

Abstract
Abu Dhabi Company for Onshore Petroleum Operations (ADCO) manages all oil production reservoirs in all of its assets. Through ADCO's commitment to improvement, efficiency, and excellence, a new technology in the form of an Oil Producer Tie-in Modular Skid is being considered. The concept of the Tie-in Modular Skid is to integrate all wellhead tie-in and completion facilities into a single modular skid ready for field installment. Such wellhead facilities include: well head control panel (WHCP), SCADA RTU (telecommunications), chemical injection, solar panels, interconnected piping, field protection and safety equipment (SSV/ HIPPS), F&G detection, and finally a manual choke valve. The purpose of implementing this technology is to maximize production time by minimizing the tie-in period of conventional off pad oil producer wells, as well as maintain the high HSE standards associated with the wellhead area.
Safety, as always, remains the top priority in all of ADCO's processes; both surface safety valves (SSVs), making up the HIPPS, will maintain their location for the Christmas Tree's protection, while the flowline isolation valve will remain 100 meters away from the wellhead for the pipeline's safety. Accordingly, the Oil Producer Tie-in Modular Skid will be kept 80 meters away from the wellhead to allow for rig access during work overs without the necessary disassembly of all the piping and instrumentations as is the case in the current configuration or the business as usual (BAU). Moreover, the strategy deployed by ADCO for the integration of this production facility's technology is to free issue the critical items (WHCP, mechanical valves, SSVs, chokes, etc.) to the tie-in contractor whereas the bulk material will be included in his or her scope. Furthermore, the tie-in contractor will be responsible for the fabrication, assembly, transportation, tie-in, pre-commissioning, and commissioning of the skid.
Upon the implementation of the Oil Producer Tie in Modular Skid many advantages and benefits can be enjoyed. The skid's robust design is advantageous for enhanced operability and maintainability. Additionally, the implementation of this technology will decrease the wellhead facility's footprint, construction activities and commissioning time, tie-in schedule, storing inventory, procurement services and price agreements, HSE risks during construction, field service preparation for workovers, and finally logistics/mobilization. Lastly, the skid offers the convenience of relocation upon the depletion of the well.
High-Frequency Torsional Oscillation Laboratory Testing of an Entire Bottom Hole Assembly
Authors: Dennis Heinisch , Mathäus Winkler , Christian Herbig , Andreas Hohl , Hanno Reckmann 
Published: November 2017

Abstract
During the downhole drilling process, severe vibration loads can occur that affect the reliability and durability of tools in bottom hole assemblies (BHA) and may cause premature damage to the tools or their subcomponents. This paper presents a laboratory test setup for high-frequency torsional oscillations (HFTO) of a 23-meter BHA. Laboratory testing is highly important for investigating this phenomenon and developing appropriate mitigation strategies.
The paper provides a summary of the theoretical background for predicting the critical torsional eigenfrequencies, mode shapes, and the susceptibility of the BHA design to HFTO. In addition, the hardware and signal processing requirements for measuring HFTO and enabling differentiation of lateral and torsional vibrations are discussed. A laboratory test setup that emulates the critical mode shapes of the BHA is essential to thoroughly investigate HFTO, and to enable the development and testing of mitigation strategies.
The paper presents an appropriate test setup that has been optimized in advance by finite-element simulations. Additionally, the influence of boundary conditions (i.e., clamping the BHA) is discussed. A 240-kilowatt electromagnetic shaker system is used as an excitation source, and lateral and torsional vibration are measured by multiple triaxial accelerometers along the BHA. From the measurements, torsional vibration amplitudes and operational deflection shapes are derived and compared to results from simulation models.
The results from the presented laboratory HFTO test show an excellent correlation of the predicted critical frequencies and mode shapes from the simulation model to the corresponding operational deflection shapes of the tested BHA. The sensitivity of the BHA’s torsional dynamics to the boundary conditions is demonstrated by experimental variation of the string side boundary condition. Moreover, the test setup emulated the dynamic BHA’s characteristics and field-like vibration amplitudes were achieved during the test. Additionally, a method is proposed and applied to optimize correlation by variation of the excitation frequency. Using this method, a correlation of the critical HFTO mode shapes to the operational deflection shapes reproduced by the laboratory test of more than 96% can be obtained. The method demonstrates that the dynamic load profile to which the BHA is subjected during drilling operation due to HFTO can precisely be reproduced by the developed and presented laboratory setup. The ability to test entire BHAs with field-like vibration loads enables the development of fit-for-purpose drilling tools that can withstand extreme drilling conditions.
Optimizing the Secret Recipe to Drill Oman's Carbonate Reservoirs with Impregnated Drill Bit Technology
Authors: Lee Roger , Alshaqsi Khalfan , Richert Volker , Al-Ramadhani Asila , AlGharibi Bader , Al Sinawi Younis , Mohanty Ajay , AlMaktoumi Fahad , AlSabari Hilal 
Published: November 2017

Abstract
Amid suppressed oil prices, the Oman Ministry of Oil and Gas continues to invest in this country’s energy industry. Fortunately, upstream companies in Oman have the capabilities to help the ministry increase the country's output. Continued exploration and appraisal success allowed a private operator to rapidly increase production in the Shahad oil field. A key to this success in early production was reduction in drilling time – faster well delivery.
The operator's slimhole 6⅛-in. and 5⅞-in. sections are challenging directional build and lateral application drilling through dolomite and limestone. Polycrystalline diamond compact (PDC) bits were tested, but they did not show durability in distances drilled. The PDC bits used in this application experienced wear damage on the cutting structure that reduced bit efficiency to drill the longer distances and finish the section. Instead, the operator chose to deploy impregnated drill bits on turbine to drill longer distances and reduce tripping time. The next step was to drill faster. The operator partnered with a service company to develop and trial a new impregnated drill bit technology for improved drilling rates of penetration (ROP).
The service company uses an innovative process within a certified drilling optimization group that enables a structured approach for understanding the complete drilling environment. This successful process, founded on the continuous improvement cycle—plan, execute, analyze, and capture—delivers practices and technology recommendations to realize performance gains and significant well-time reduction. Areas of focus include proper hydraulics for cooling the cutting structure, accurate match of impregnated diamond materials to achieve improved penetration rates, and the correct gauge configuration to avoid bit sticking within the borehole. Using this process, two new impregnated drill bit designs were specially developed to drill the dolomite and limestone formation. The new technology was established to drill a lateral section with a turbine as the driving system in a carbonate formation with unconfined compressive strengths of 35k to 45k pounds per square inch.
The first trial of the 5⅞-in. impregnated drill bit matched the best field performance metrics of distance drilled and ROP. The second iteration continued to improve performance, delivering a 23% increase in ROP. The authors will present case studies to demonstrate how the latest technology impregnated drill bits contributed to faster well delivery for this operator's drilling program in Oman.