bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Potential of a New Distillation Process for the Upgrading of Acid Gas
Authors: Pellegrini L. A. , De Guido G. , Langè S. , Moioli S. , Picutti B. , Vergani P. , Franzoni G. , Brignoli F. 
Published: November 2016

Abstract
In this work, the potential of a new low-temperature distillation process for natural gas sweetening has been investigated. The proposed technology consists of a dual pressure distillation scheme, developed to bypass the SLV locus of the system CH4-CO2 in order to avoid the formation of a solid phase in all the parts of the process, while still being able to fulfill the required natural gas purity specifications.
The performances of the new low-temperature distillation process have been assessed for different case studies, considering gas feeds with a CO2 content and with a H2S content in the range 5-65 mol% and 0-15 mol%, respectively. The profitability of the proposed solution has been determined in terms of energy expenses when compared to the more traditional MDEA gas sweetening process. The work has been performed coupling the use of a commercial process simulator (Aspen HYSYS® V7.3) with in-house Fortran routines for the thermodynamic modeling also accounting for the presence of a solid phase.
The new solution has been studied and optimized in terms of energy savings related to the cooling duty consumptions. Results of the analysis have shown that the relative trade-off between the two technologies depends on the contents of the acidic compounds in the natural gas stream and on the geographic area where the gas field is located. The new low-temperature technology has shown higher performances and economic profitability when compared to the more traditional gas sweetening processes (such as absorption with alkanolamine solutions) when the CO2 and/or H2S content in the natural gas feed is high, thus possibly enabling the exploitation of extremely acid and sour gas fields.
The obtained results have been used for the design of both an industrial unit and a pilot plant that is going to be used to test the process on a lab-scale.
The increasing energy demand compels industry to design new solutions for the profitable exploitation of natural gas reservoirs with high CO2 and/or H2S content.
Low-temperature distillation technologies represent a cost-effective alternative when sweetening natural gas containing a high amount of acidic components.
The new process exploits a different and simpler approach from the ones known in the literature, being able to offer the competitive advantages of low-temperature technologies while avoiding CO2 solidification and solvent addition.
Simple and Reliable Innovative Fluid Dynamic Technology Maximizes Oil Recovery in Upper Burgan Reservoir
Authors: Al-Hajeri Nasser , Osamn Yasser , Safar Ahmad Ibrahim , Al-Muttar Bader , El Anany Sayed , Aman Bader , Karode Vijay , Kalyani Tejas , Kumar Ajit 
Published: November 2016

Abstract
Production in the Upper Burgan reservoir began in the Raudhatain and Sabriyah fields in 1959 and 1970, respectively. However, significant quantities of original oil remain in the reservoir; although the Upper Burgan fields have both been in production for more than 56 years, the offtake to date is a relatively small percentage of the potential ultimate recovery.
The sandstone of the Upper Burgan is typically fine grained. Porosities average 25% and can reach 30% in the best quality sands. Horizontal permeability values of 200 to 700 md are common, with variation in vertical permeability caused by changes in the texture and structure of the reservoir. In 1995, the operator initiated a strategy to significantly increase production from these North Kuwait fields by integrating a multidisciplinary team from within the operating company. Waterflooding was part of the Upper Burgan development plan, during which the heterogeneous reservoir was expected to encounter early water breakthrough compared to other North Kuwait reservoirs.
After 20 years of waterflooding in the Upper Burgan, the water cut reached 50%, and water management became crucial with reduced hydrocarbon recovery from the field.
Autonomous inflow control device (AICD) technology with screens was installed in a pilot well in the Upper Burgan reservoir to help reduce the water production and increase the oil recovery from the well. AICD technology uses fluid dynamics technology to differentiate the fluids flowing through the device. When water breaks through, the AICD creates a pressure drop to restrict production flow at that device, favoring the production of the healthy oil-statured zone, thus increasing expected ultimate recovery from the well. The AICD has no moving parts, electronics, or connections to the surface and employs a unique geometry that alters the flow path within the tool upon water and/or gas breakthrough.
This technology has helped improve recovery by reducing water cut from the high water-saturation zones, thereby increasing the overall oil recovery from the well. Forecasted well performance with AICD technology is in line with actual production and water cut.
Effective Workflow to Clean-Up Oil Spill Using Ferromagnetic Nano-Particles
Authors: Kakade R. , Bagga P. S. , Kamble P. D. , Patwardhan S. D. 
Published: November 2016

Abstract
Permanent environmental damage cannot be compensated in terms of money. Unfortunately, oil spills contaminate water, restraining marine species of their habitat and food supply. Despite the numerous methods available today to clean up the water body by separation of oil and water, none have restored water to its previous quality or saved marine animals from its deleterious effects to the full extent. The biggest hurdle to this cause is the sunken oil; the oil which may have either sunken mixed with sand and mud or by dispersion due to weathering. Mechanical containment with recovery and use of dispersants will always be the most widely used response option for surface clean up due to its capability to directly remove oil from environment till today. Another spill response tool is In situ burning which is under study from several decades. Efforts are being made to enhance In situ burning such as Aerial Ignition System (AIS) and Chemical Herders. Although it is expected that this oil will float right up due to the density difference and cleaning will hence be easy, this is not always the case.
The authors suggest the most effective workflow to clean up surface oil in marine oil spills as well as a way to tackle the sunken oil droplets. Choosing of an effective clean up method should always start with determining the amount of oil, density of oil, type of oil (crude or refined), salinity of water and the weather conditions. The authors thus propose an arrangement for real time tracking and mapping of an oil spill and then using most effective modern cleanup methods like booms, in situ burning, dispersants and skimmers followed by the use of polymer coated ferromagnetic nano particles to clean up sunken oil droplets. Magnetic nanoparticles are non-toxic nano sized sponges that sink deep inside the water body, absorb 10 times their weight of oil and float back up on the surface. Experiments with two samples of oil were conducted to check the effectiveness of ferrous nanoparticles in attracting oil out of water in various concentrations of nanoparticles to find the optimum level.
Sandstorm Contingency for Logging with Coiled Tubing: Coiled Tubing Cut, Site Evacuation and Safe Recovery - Success Story from Middle East Field
Authors: Subaihi M. H. , Benanjaya A. , Al Bloushi M. A. , Gali A. R. , Hashmi U. I. , Madi H. 
Published: November 2016

Abstract
Objectives/Scope: Operations in onshore fields at UAE are affected during the months of March through June by the weather, as sand storms are created and attack the area, there is always a need to plan abandonments to avoid harm to any personnel, environment and minimize damage to facilities.
In March 2016, while executing a logging with coiled tubing operation on a well at one of ADCO fields with 1.75'' coiled tubing (CT), a message from the field's safety team was communicated to terminate all operations and lower all cranes due to a severe storm approaching the area. It was required to evacuate the area within two hours. A team was formed at the base communicating with the in-charge engineer onsite to safely secure the CT string at surface, which would allow for abandonment while maintaining well control (WC).
Methods, Procedures, Process: During this process three options were analyzed: the first option was to add additional support to the injector head (IH) and leave the coiled tubing package rigged up; this option was rejected because it would not guarantee WC in the event that the storm takes down the crane along with IH. The second option was to secure the CT with lower Blow out Preventers (BOP), Combi type, then shear it and rig down the IH. This approach provided WC, but it created additional risk and limitations when resuming the retrieval operations after the storm. The third option was to secure the CT utilizing the upper BOP, Quad type, and keep the pipe held with the lower BOP while secured by the upper BOP. The removal of the IH would leave the section of pipe along with the logging tools held while the well is secured using the BOP provided WC. Furthermore, a cap was installed at the top of BOP and a pressure gauge was set to monitor pressure during retrieval of the pipe.
Results, Observations, Conclusions: After analyzing available options, the third alternative was selected by the team; as this option addressed WC and allowed safe recovery by rigging down the top BOP, reconnecting the pipe through double end connector into the IH, and rigging up the required equipment to proceed with the pipe recovery operation.
Novel/ Additive Information: Availability of two BOPs reduced the complexity of pipe recovery in addition of maintaining WC at all stages of the operation. Logging with CT is one of the most complicated rigless operations in terms of rig up and rig down, utilizing two BOPs provided the option of securing the well at any point of the operation with reduction in difficulties of pipe recovery. This paper illustrates contingency procedure for CT cut and recovery in abnormal situations through a certain rig up setup.
Energy Conservation and Equipment Reliability Improvement by Operations Excellence
Authors: Arif M. , Humayun N.A. 
Published: November 2016

Abstract
After successful commissioning of Full Field Development (FFD) project of an oil field in Southeast of Abu Dhabi in 2013, operations excellence played its role to optimize resources. Particularly, a number of initiatives were taken to optimize energy, conserve environment and to increase equipment reliability. As a result of numerous initiatives taken, a total of energy 2.85 MW saving, reduction of 37 tons CO2 per day emission along with other benefits like running machines at best efficiency point (BEP), reducing maintenance cost and increasing life of equipment achieved. Initiatives taken include provision of back pressure control valve for spiking gas compressor at final discharge; offline one of the three phase production separator; use of variable frequency drives (VFDs) instead of conventional fixed frequency switch boards; wide opening of chokes for wells having VFDs and reduction in operating frequencies; operation of spiking gas compressor at 75% capacity and stopping of over design vapor recovery compressor (VRC). The objective of this paper is to share successful optimization strategy to conserve energy and to enhance equipment reliability by running the machines nearer to best efficiency point. Team work and people involvement remained the key to success for all initiatives taken.
Cathodic Protection Rehabilitation for Buried Vessel
Authors: Kadikar Ratnakar 
Published: November 2016

Abstract
The purpose of this paper is to provide brief summary on rehabilitation work done for cathodic protection (CP) of seven buried vessel which were un protective due to CP system failure.
This paper addresses the design consideration, modification and refurbishment strategy implemented by Dolphin Energy to address the challenges associated with buried vessel. The information highlighted here may be helpful to other operators to evaluate their capabilities and protect their system in the same way.
This paper provides the insights for the reason of CP system failure and addresses the innovative solution to rehabilitate buried vessel CP system without isolating from the production facility and performing rehabilitation on live vessel, safely.
At Dolphin Energy, an Impressed Current Cathodic Protection (ICCP) system is used to protect against soli side corrosion for buried vessels, piping and tank bottoms. For buried vessels, Mixed Metal Oxide (MMO) anode loops are used around the vessel to achieve uniform protection. A routine survey revealed seven buried vessels unprotected needing CP refurbishment to protect and maintain the integrity of these vessels.
A bi-annual CP survey revealed out of various (two, three or four) MMO anode loops, initially one loop became non-functional followed by other loops which lead to zero current. However, applied voltage was normal.
Based on the survey and initial screening, it was understood that the CP system failure could either be due to anode deterioration, cathode cable damage, DC fuse failure or anode cable failure. However, detailed investigation and excavation revealed out of these four probabilities, anode cable failure at anode to cable splicing joint was the reason for CP system failure.
Given that all the buried vessels on-site are enclosed within a concrete pit and covered with a concrete lid, direct replacement of anode loops is impractical and unsafe. Hence, an alternative CP retrofit system was introduced for the seven buried vessels where, canistered MMO anodes were placed at diagonally opposite corners and other strategic locations around the vessel to achieve uniform protection. During rehabilitation, existing pit, junction boxes and transformer rectifiers were used which were in good condition, meeting the design requirement.
Enhancing Zakum Field’s Marine Safety To The Highest HSE Standards& Best Practices
Authors: Fahmy Ibrahim , Macaulay James , Benmebarek Samir , Al-shehhi Ahmed 
Published: November 2016

Abstract

Entry Overview
ZADCO Senior Management along with ADMA Initiated Project of Enhancing Zakum Field’s Marine Safety to the highest HSE Standards/best practices as a step forward in Risk Management by investigating all root causes of previous incidents, setting and implementing the recommendations to close the gap and strengthen the safety barriers.
Best Practices in Integrity Management of Safety Critical Systems
Authors: Pillai Sreejith 
Published: November 2016

Abstract
Process Safety assurance is built on the premise that all Safety Critical Elements [SCEs] / HSE Critical Equipment & systems [HSECESs] are operated and maintained so that they are functionally available on demand to prevent / mitigate / control process safety incidents. This means that, HSECES management is fundamental to process safety assurance, which is the essence of ADNOC COPV6-01, Verification of Technical Integrity. GASCO Technical Integrity or HSECES Assurance Management process is being continuously improved or optimized to make the process robust and practical incorporating the lessons learnt.
GASCO embarked on a journey to build assure management of HSECES into the day-to-day operations at all of its operational sites almost seven years ago and is sharing the best practices to hazardous industries through ADIPEC, the world's largest oil & gas conference.
This paper highlights the operationalization of HSECES management for operating plants in an integrated manner, in compliance with ADNOC COP6-01. The clear value-adding differentiators of this model includes the Technical Authority process, HSECES performance test report automation and maintenance of this model for new projects and changes to existing plants.
This pragmatic and optimized model brings in an integrated Technical Integrity approach to the region.
A Modern Touch Enabled Well Exception Analysis Interface with Trend and Prediction Analytics for Improved Field Management Including a Real Time Nodal Analysis Engine To Be Used in High Well Count Scenarios
Authors: Brown Ian , Gokdemir Metin , Stoddard Trevor , Said Saad A. , Kirkman Matthew A. 
Published: November 2016

Abstract
Traditional DOF solutions use a web portal or intranet dashboard as the primary means of data access and collaboration. For an engineer these portals are useful to help identify field problems, reduce the amount of time spent looking for data and enable quicker analysis of issues. However, these platforms do not offer the rich two-way communication environment that could enable real-time interaction between engineers, systems, and support functions. Web portals are generally loosely coupled to modelling and visualization solutions which together can adversely affect performance of the solution. This paper presents how a new approach was tried, tested and proven to offer a transformation in the way we interact with well production, model based analytics and collaborate with others. This paper provides a case study documenting how a foundational Digital Oilfield (DOF) platform was extended to include model based workflows and multi channel mobile device integration.
Pressure Equipment and Piping Integrity Management Systems in Digitalized World
Authors: Costa Francisco 
Published: November 2016

Abstract
Best results in professional communication are achieved with short and simple words as well as practical examples that may be enriched with photographs, drawings and now in our digitalized world era by 3D representations. "One Picture Is Worth a Thousand Words"
This paper focus in demonstrating how to ease and gain advantage of advanced digital technologies to add value to key subjects related to Mechanical Integrity of Pressure Equipment and Piping Systems in the Oil and Gas Plants, Refineries and Petrochemical industries while handling the following matters: Recording, Searching and Retrieval of a variety of Inspection Data, Asset History Verification, Reporting, Analysis, Tracking, Planning, preparation of Scope of Works and Budgets.Understanding of Design, Operational and Technical Integrity for Mechanical Integrity Risk Analysis, Risk Based Inspection (RBI) studies, identification and prioritization of different areas of concern requiring further attention and Engineering Support based on their criticality and classification.Enabling visualization in precise and detailed 3D representations for Searching and Grouping of Piping Systems by Material, Rate, Size, Degradation Mechanism, Repairs, Replacements, Upgrades, Insulated, non-Insulated, etc. the criteria is ours.
Adding a customized 3D software shall be able to strengthen and further improve the Integrity Management Systemfor Static Pressure Equipment and Critical Piping Systems with focus on Small Bore Piping, to enrich Inspection Record Keeping Systems and therefore enhancing our ability to manage the overall Inspection and Corrosion Business Process.
Moving the Oil and Gas Sector into the Video Age: Vision Assisted Well Interventions Reduce Cost and Add Value
Authors: Tymons Tobben , Moloney Susan 
Published: November 2016

Abstract
Economic challenges, within the oil and gas industry, make the optimization of production from existing wells more important than ever. Increasing the number of active wells and maximizing their production can be achieved through integrity-restoring and production-enhancing well intervention projects. The challenge faced by well operators under today’s economic conditions is achieving cost effective, high efficiency operations to maximize return on their investment. Through the presentation of case studies, this paper will demonstrate how the application of innovative downhole camera technologies enabled well operators to bring wells back on-line that had previously been shut in.
High definition, battery powered, memory cameras were deployed on slickline to provide cost effective operations without compromise to image quality. Full color video was downloaded and analyzed after each run to enable well site decision making regarding specific well issues, including tubing to annulus communication, a failed safety valve and diagnosing the results of multiple failed fishing attempts over several years. By providing fast-response, high-clarity visual information, an engineered solution would be tailored to suit the specific well conditions to maximize the effectiveness of remediation and increase the efficiency of restoration of production.
Results from the camera surveys immediately revealed clear evidence of the wellbore status in each case. Conclusive images of parted tubing, the position and condition of a fish and the top of a completion string provided valuable inputs into the decision making process for subsequent remedial work. As a direct result, fishing operations could be tailored to suit the specific situation and a work-over could be conclusively decided upon or avoided, providing significant time and cost saving as a result. In one case, a well, previously shut-in for several years, was brought back to life with a significant uplift in oil production.
Traditionally downhole cameras have been regarded as emergency tools to address immediate, unexpected problems. However, with advances in image clarity and data density, combined with carefully planned interventions, camera technologies provide highly intuitive and accurate diagnostic and surveillance information that reduces uncertainty and increases the effectiveness of resulting remedial work. Efficiency is now enhanced further through the integration of quantitative logging data with the camera in a single run to offer a truly robust interpretation answer and effectively provide vision to downhole data. The Oil and Gas sector has truly moved into the video age.
Sedimentology and Diagenesis of the Dense Zones Above and Below a Limestone Reservoir of the Kharaib Formation Lower Cretaceous, Abu Dhabi
Authors: Wu Q. , Ehrenberg S.N. 
Published: November 2016

Abstract
The "dense zones" (intervals of very low porosity) separating Lower Cretaceous reservoir zones have been studied in cores from a giant onshore oilfield. The topics addressed in this paper include the nature of gamma ray (GR) activity in the dense zones, lithofacies, the nature of bedding and depositional cycles, lateral variation in thickness and porosity within the field studied, the timing of porosity loss, and the causes of the very low porosity of the dense zones.