bluuebunny/crossref_metadata_2025_split huggingface dataset:
Optimize the Spares and Spare the Resources
Authors: Gongade Ashish , Al Awadhi Ibrahim , Narayana Sathyanath , Al Ahmad Alya , Miranda Robert , Oka Sameer 
Published: November 2017

Abstract
GASCO (Abu Dhba Gas Industries Ltd) commenced design and construction of processing facilities since 1978. The main plants and subsequent expansions were engineered in phases by different EPC Contractors. Piping Material Specifications (PMS) were developed for each Project as per EPC Contractor’s engineering understanding and as per the Project need. This resulted in having different PMS for similar fluid services in an identical process Units/Trains. This paper presents the outcome of the study to optimize the number of PMSs and generate a common PMS to satisfy all the existing plant requirements.
GASCO has around 800+ Piping classes across all the sites. The selection of right PMS was a challenge during the modification projects in existing plants. It was also difficult for Store/Ware house personnel to maintain the inventory and track spares as because of large number of stock codes. A comprehensive study was undertaken to develop a master set of PMS involving following steps; data collection & review, checking the compatibility with latest Codes and Standards, study lessons learnt, generate back up calculations, documentation and publish the Design General Specification (DGSs).
Through this comprehensive study, 800+ piping classes were optimized to 150 number of piping classes in a common PMS to suit overall GASCO’s requirement. The co-relation of existing piping classes having outdated materials with newly developed classes made the selection of required piping class much easier and user friendly. The new PMS, with new material classes ensuring good engineering practices and adapting the lessons learnt over the years of operation. This optimization campaign facilitated GASCO to formulate a definitive approach towards the selection of common piping material for specific fluids across the plants.
The new PMS has segregated the material requirement for various fluids with different operating temperature and pressure conditions from different Units/Trains. Some of obsolete components had been taken out from PMS based on GASCO’s operating experience over last 30+ years. The selection of material has become easy at all level of work force when doing the modification work.
Use of right piping material will save material cost with engineered material solution with minimal failures. Alignment with all the Plants with common piping classes will maintain optimum inventory across GASCO plants. The same philosophy can be used within all the OPCOs under ADNOC directives of cost saving and standardization.
The Study of Effects from Small Bore Connection Geometry for High Vibrational Excitation
Authors: Pewkliang S. , Janbanjong P. , Rahong P. , Muangsuankwan N. , Nokjib S. 
Published: November 2017

Abstract
The objective of this paper is to study the effect among the branch pipe to main line ration, the overall length of Small Bore Connection (SBC) and the high frequency vibration excitation on SBC.
The process of this study is to analyze the cause of high vibration excitation due to effect of SBC geometry and operating condition by gathering data from "SBC Integrity Management Program. All relevant data which is used for this study is comprised of dimension data from Likelihood of Failure (LOF) for SBC geometry, vibration result and operating condition of piping. The total amount of 3,391 sets of SBC data, which is collected from four (4) offshore production platforms. The study is conducted by noticing of the display for the data set, which cause is pointed on high vibration result. The graphs relation among the branch pipe to main line ration, overall length of SBC, frequency and velocity of vibration are plotted to define the parameter range of high vibration excitation.
The result from this study is presented that the high vibration excitation from all SBC data is in line with the ENERGY INSTITUTE's guideline. Most of anomaly and high vibration on SBCs are found at branch pipe to main line ration ≤13% and overall length of SBC ≤ 2m. High frequency vibration is found at operating pressure ≤ 5 barg. The major root cause is from the resonance of natural frequency and excitation frequency at low pressure condition.
Working together for Successful Drilling through a Fault: Risk Management, Planning and Execution
Authors: Yanez_Banda M. , Ruzhnikov A. , Kasimin A. , Husien M. , Malagon C. , Al-Wahedi K. 
Published: November 2017

Abstract
Since the start of drilling campaign at new field in the United Arab Emirates the operator faced the challenge to drill across faults, what can lead to well control, wellbore instability, total losses and stuck pipe. To minimize the impact, a risk management plan was developed and implemented during drilling and completion stages, which allowed to execute wells in trouble-free manner.
The operator gathered the respective teams (geomechanics, seismic, operation geologists, drilling engineering and operations) and service companies with the objective of understanding the nature and potential operational impact of the faults. Afterwards, a very detailed risk management plan (RMP) was developed, which included different options with mitigation measures on how to deal with losses. This included changes in the well design, drilling fluid, BHA and casing setting depth. The compromises and benefits of each scenario was worked until a primary option was determined. Also, detailed procedures in case of non-standard situations were developed with contingencies.
Based on the measures developed as part of the risk management plan the drilling of the sections through the fault and completion (casing run, cementing, etc.) were conducted in trouble-free manner. The prevention measures were implemented as per plan, what allowed to avoid mitigations measures and there was no non-productive time associated with fault.
Successful Troubleshooting to Improve RFCC LPG Amine Absorber Performance
Authors: Thamizhan Velavan Sikkampatti , Darak Nikhil Dwarakanath 
Published: November 2017

Abstract
LPG Amine absorbers are being used for removal of H2S from RFCC LPG stream prior to process in downstream LPG MEROX unit. The underperformance of the LPG amine absorber has adverse impact on downstream unit operation and meeting product specification. Since commissioning of RFCC Unit, LPG product was observed to be consistently off spec with respect to H2S content (&gt;100 ppm against the design of 10 ppm). This high H2S slippage was severely impacting the Refinery operation as below, High caustic consumption in downstream LPG Treating unit & impacting Spent Caustic Treatment unitOff spec LPG product with respect to Disulphide content from LPG Treating UnitRFCC LPG product was not meeting the intermediate LPG sphere storage criteria of H2S content &lt;50 ppm.
In order to troubleshoot and identify the possible reasons for high H2S slippage from LPG Amine Absorber, a team was formed comprising of representatives from various dicipilne and agencies. Systematic way of troubleshooting was adopted with several brainstorming sessions between all the stakeholders. Following actions points evolved out of brainstorming session, Review column operating conditions for any deviation from design operating conditionDesign review of the column internals
Based on in-house simulation and design review of LPG amine absorber, it was observed that existing column internals were inadequate to avoid mal-distribution and the same was deliberated in details with Licensor. Licensor concurred with the findings and packing vendor was engaged for further review. Column internals (Packing, Disperser plate and Distributor) has been redesigned and replaced with new internals. After replacement of column internal LPG product H2S content was observed to be within product specification.
Competency Development for the Next Generation of Petroleum Engineers
Authors: Lau Hon Chung 
Published: November 2017

Abstract
Competency development in petroleum engineers is a life-long process. It starts with the undergraduate education and continues on throughout the career of the petroleum engineer. In this paper, we have identified the key competencies that need to be developed in the next generation of petroleum engineers in light of the increasingly complex, interdisciplinary and global nature of petroleum projects. These key competencies include dimensionsnot found in traditional petroleum engineering and geoscience (PE&G) programs such as leadership, health, safety and environment (HSE), interdisciplinary and intercultural competencies. Our research has shown that geophysics training is missing in most undergraduate PE&G programs. In addition, leadership training at the undergraduate level is a key need for future readiness of petroleum engineering students. The remaining core competencies, HSE, interdisciplinary and intercultural competency, are mostly learned at the workplace. Both university educators, corporate trainers and managers need to adapt their pedagogical methods to build competencies in Generation Y petroleum engineers. Suggestions of what they can do are given. To be effective trainers, they need to act more like mentors than teachers and supervisors.
Subsurface Competencies Verification & Management Model, a Case Study of Upstream Oil & Gas Company
Authors: Al-Daihani Eisa , Nandi Arun Kumar , Razaa Syed Mohammad 
Published: November 2017

Abstract
In order to link all subsurface trainings and staff development activities with HR Strategies of the company, subsurface competencies "Verification & Management" model has been attempted. The objective of the model is to provide a quality "Assurance" and "Control" tool to the management. Besides, this will provide "Internal Verification Process" to ensure acquiring "Competencies" related to specific jobs and provide standard criteria and tangible measures.
There are many definitions of competency. What we have selected for our company is the ability to apply "Knowledge", and "Skills" to perform a Specific Task Effectively and Consistently within Time Frame and demonstrated by "Relevant Behavior".
We need certified competencies to achieve company strategic goals and objectives more effectively by developing competent work force, to select the right people for the right career paths based on competency criteria, to enhance the culture to recognize performance based on knowledge skills and behavior within time frame as per the company personnel policy. The other reasons to have certified competencies are to have consistent approach from joining to retirement, to identify young professionals and Discipline Experts at early stages for "Fast track development" and to execute succession planning effectively.
The paper emphasized on benchmarking the entire model with internationally available resources and came out with a robust recognition flow chart. The implementation processes and workflow has been defined among six stake holders. Besides, roles and responsibilities of different stake holders are defined. Recognition guidelines have been illustrated for progression of an employee from one grade to other. And evidence tools have been designed which will help to verify the competencies.
The model will be helpful in linking subsurface trainings and staff development activities of an employee with HR strategies and will bring transparency in the career progression of an employee.
A Cohesive Technique to Optimize an Openhole Multistage Acid Frac in Unconventional Oil Reservoir - North Kuwait
Authors: El-Aziz Sabry Abd , Chin Chao , Ashqar Ayham , Al-Ajmi Moudi , Mauro Rick , Nada Mohamed , Nada Mohamed 
Published: November 2017

Abstract
The combination of horizontal wells and multistage fracturing enabled the development of tight carbonate reservoirs. The successful completion of these reservoirs can be challenging. Correct placement of multistage intervals plays a critical role in improving and sustaining production. Openhole (OH) multistage (MS) technologies enhances reservoir contact and productivity by optimizing the distribution of the stages across the openhole. This paper presents an engineering technique to optimize OH fracture stages and cluster placement distribution within heterogeneous unconventional oil carbonate reservoirs based on formation, completion properties, and reservoir fluid distribution.
Completion technology is based on distributing intelligent packers along the lateral section to develop the MS fracturing stages. Intelligent packer displacement influences fracture effectiveness and conductivity. Equal spacing packer placement can undermine formation potential and productivity results. The placement of the packers and their ports is based on the petrophysical and mechanical properties of the formation to increase the cumulative production in a shorter timeframe and to help improve recovery. The method followed is based on an analysis of the reservoir properties (porosity and permeability). These were later integrated with the measured rock mechanical properties. The developed integrated model was used to categorize the rock into segments that share similar properties.
The use of an advanced azimuthal sonic tool with a high signal-to-noise ratio and wider frequency response helped to improve the accuracy in assessing formation mechanical properties. In addition, conventional logs, when combined with formation mobility measurements, help to calibrate the permeability model and classify the formation into distinctive clusters. These clusters are then grouped according to their mechanical and brittleness properties to form a separate unit with a selected fracture port to help ensure the necessary fracture length. The developed method provides an opportunity to determine the necessary fracture stages and to reduce the risks of overor underplacement. It also improves stage integrity, helps to ensure better distribution of the acid across the formation matrix, and provides effective propagation of the fracture network.
The applied procedure follows an innovative approach to optimize the fracture stage and cluster placement distribution across the reservoir using a new combination of advanced and conventional data acquisition and interpretation. The case study presented in this paper demonstrates the benefits of engineered fracturing stage placement, as compared to a geometric displacement.
Importance of Borehole Images and Dipole Sonic Data for Optimal Stimulation in a Tectonic Compressive Setting
Authors: Gamero Diaz H. , Mohsin L. , Desroches J. , Waters G. A. , Peralta J. D. , Al Zeidi O. 
Published: November 2017

Abstract
Interpretation of logs from an exploration pilot well and a lateral drilled from the pilot in the Late Cretaceous Natih formation in the Sultanate of Oman was used for designing a multistage hydraulic fracturing treatment. A high-tier logging suite including borehole image, advanced dipole sonic, geochemical, and triple combo data was acquired in both wellbores. The objective of the pilot hole was to select the best landing point in terms of reservoir quality (RQ) and completion quality (CQ) so that a horizontal well could be drilled and multistage stimulations performed in the organic-rich Natih B source rock.
In contrast to much of North America, significant tectonic forces are frequently present in this region. The geomechanical setting might thus strongly affect hydraulic fracture initiation, propagation and proppant placement. It therefore plays an important role in lateral landing point selection. Borehole images, integrated with petrophysical and geomechanical log properties, were used to identify the optimum landing zone. Breakouts as well as longitudinal and transverse drilling-induced fractures were identified on the pilot borehole images over the Natih Formation, indicating a large horizontal stress anisotropy and a compressional tectonic setting. An interval from which vertical hydraulic fractures would initiate at low initiation pressure and grow vertically to contact intervals with good RQ was selected as the target lateral landing point. Image and dipole sonic data were acquired in the horizontal well, and both longitudinal and transverse induced fractures were identified. Those data were used to selectively place hydraulic fracturing stages. Diagnostic injection tests on each stimulation treatment confirmed low fracture initiation pressures and the creation of vertical hydraulic fractures, thus validating the selection of both the landing point and the location of the hydraulic fracture initiation points. All treatments were successfully placed to completion.
This paper demonstrates that a workflow based on the combination of image and dipole sonic logs in both a pilot well and a lateral drilled from the pilot enables the creation of vertical hydraulic fractures at moderately low initiation pressures and successful placement of stimulation treatments in the lateral. This technique shows promise for effective hydraulic fracturing in regions where significant tectonic forces are present.
Integrated Workflow For Building 3d Digital Outcrop Models Using Unmanned Aerial Vehicles - Drones: Field Case Thamama Group, Wadih Rahbah, UAE.
Authors: Parra Humberto , Salgado Gomes Jorge , Shebl Hesham 
Published: November 2017

Abstract
The aim of this paper is to provide an insight on the usage of unmanned aerial vehicles (drones) for capturing 3D photorealistic images of geological outcrops which can be used as digital analogs during 3D geological modelling.
Recognizing the potential of the use of drones in many other fields has opened the doors for an endless variety of applications in the geoscience world as well. Specifically, in geological mapping and 3-D modeling activities, the use of these technologies can be seen as a cost-effective method of quickly and accurately surveying, mapping and capturing surface geological phenomena and processes that were more difficult and expensive for been surveyed in the past.
Combining aerial and ground photography acquisitions, the image of geological outcrops can be captured and modelled in 3D using photogrammetry techniques, generating Digital Elevation Models (DEM). With DEM the users can perform measurements in multiple azimuths and compare and overlay geological, geophysical and petrophysical data at different scales and obtain multi-point statistics (MPS) for MPS modelling or conventional spatial statistical information for variogram analysis. Jumping ahead from the past where data was used for only qualitative comparison through pictures, the outcrop data can be used directly as a cloud of points to be used as 3-D wireframes into modelling software for enhancing reservoir architecture procedures (designing vertical layering schemes on grids) capturing reservoir heterogeneities at different scales.
The creation of digital outcrop models using drone technologies is a cost effective solution to introduce the advantage of the field observations into more accurate subsurface models. The advantage of incorporating outcrop information into the geological modelling workflow is the ability to understand, based on direct observations of the complexity of the geological drivers, which one plays the major control on the property distribution and flow processes in the subsurface.
The Successful Application of One Run Drilling Technology in Big-Thickness Halite Formation of Ultra-Deep Water
Authors: Liqiu Ping , Xi Wang , Rong Li , Rui Yang , Chenchao Liu 
Published: November 2017

Abstract
The drilling operation in the more than 2000m thickness pre-salt formation with more than 2000m water depth faced great challenges from the beginning in X. Project of Atlantic due to drill string stuck caused by salt creeping and low ROP, so efforts were concentrated to obtain a better drilling performance as a consequence of the high daily rates of drilling ships.
In this paper, we look for a combination of high performance PDC bits, near bit reamer stabilizer, synthetic based-based mud, MPD, RSS and LWD systems to increase the drilling performance, both in ROP and salt creeping control in salt formations. ROP has been increased by more than three hundred percentages by high performance PDC bits. Near bit reamer stabilizer and synthetic based-based mud made drill string stuck frequency decrease drastically. The combination of MPD, RSS and LWD systems has improved drilling performance. The above-mentioned integrated drilling technology has been successfully applied in two pre-salt wells in one run whose halite formation thickness is 1870m and 2062m respectively in 2016.
The drilling duration for 2062m salt section has decreased to from 14 days to 7 days which saved about 14 millions dollars for the two wells. The average ROP record of the two wells by use of the integrated drilling technology is 24.6 m/h that has been improved 3.4 times comparing the completed four wells in 2015 in X. Project. The NPT caused by drill string stuck has been decreased from the average 11.7 days to zero that can save about 12 millions drilling cost. So the integrated halite drilling technology can not only solve the drilling problems in halite formation in ultra-deep water such as bore hole collapse and drill string stuck but also increase the ROP. The drilling performance in halite formation has been improved and the integrated halite drilling technology has been widely applied in big-thickness pre-salt formation Santos basin and will decrease the drilling duration of ultra-deep water pre-salt reservoirs wells and lower the oil cost per barrel in ultra-deep water development.
The method to increase drilling efficiency in halite formation of this paper presented will make a reference for deep water salt formation drilling and offshore oilfields high efficiency development. Also the method to control salt creeping and drill string stuck might give a light to the drilling operation in gypsum formation in onshore oilfields.
The First Successful Combination of an Electro-Mechanical Pipe Cutting Tool with the Intelligent Coiled Tubing System to Perform Cuts at a Deep-Water Horizontal Well in Brazil
Authors: Carvalho Ricardo de , Barrros Robledo Wakin , França Cícero Rondinelli , Silva Deylla Gomes 
Published: November 2017

Abstract
This paper describes the efficiencies of deploying the electro-mechanical pipe cutting (EMPC) tool with intelligent coiled tubing, highlighting the advantages of this tool compared to existing ballistic, chemical and other mechanical tools in terms of precision, time cost savings and HSE performance. The paper also covers the added advantages generated through the use of intelligent coiled tubing on the overall operation.
The recent introduction of intelligent coiled tubing equipment, incorporating real-time downhole tool capabilities, data communication transfer and power supply, has made possible the deployment of the electro-mechanical multiple cutting tool on coiled tubing. The emergence of this technology enables the cutting tool to perform operational applications previously unachievable in long horizontal wellbores. In the deepwater environment, there is an expectation of an increase in plug and abandonment projects. This increase will create new challenges relative to cutting and retrieval of the completion tubing. The electro-mechanical cutting tool has been proven in recent years to be an extremely reliable, efficient, and safe method to perform cutting operations in tubulars, sand screens, as well as releasing packers in high-pressure environments. The paper presents a case history detailing this methodology and the involved pre-job planning, deployment risk and management modeling, demonstrating and concluding the completeness of this solution and its reliability.
The paper shows how the combination of intelligent coiled tubing with the electro-mechanical cutting technology can render the usage of ballistic, chemical and other mechanical devices as unnecessary and outdated/inefficient.