bluuebunny/crossref_metadata_2025_split huggingface dataset:
CO2 Detection Using Graphene Based Micro Sensors
Authors: Al Shehhi A. , Al Suwaidi M. , Al Hammadi I. , Saadat I. 
Published: November 2016

Abstract
Oil and gas industry encounters challenges whenever EOR/EGR is being introduced; numerous methodologies have been looked upon at an early stage of analyzing the recovery solution. Generally, there are numerous types of pipelines used in the oil industry; and each has its associated operational issues. There are certain mitigation plans for the oil production pipelines that have to be adopted, especially after implementing the CO2 injection as an EOR methodology into selected depleted reservoirs.
CO2 injection is used to enhance oil recovery (EOR); henceforth it is consequently commingled with other gases like the H2S. Such commingled gases are considered corrosive and may lead to cracks and fractures to the pipelines. The thermodynamic property of CO2, influenced by the temperature and pressure during pipeline transportation, with the existence of other gases (such as H2S), makes the presence of CO2 to be a coorosion driver in the pipeline. Therefore, such pipeline operation is considered to be more complicated than any other service pipelines.
This paper will represent the joint research conducted in Masdar Institute and ADCO, which deals with the fabrication of graphene micro sensors. These micro sensors are based on graphene as active material for the transistor like sensor systems. Graphene has unique sensing/electronic properties along with physical and chemical stability in corrosive and hostile environments required for the oil and gas application. The graphene films are synthesized and optimized using Chemical Vapor Deposition (CVD) reactor in various substrates with different surface finishes. Three different types of architectures of micro sensors are fabricated and will be reported, which are Kelvin, Backgated and Memberane. The response of each of these architectures helps triangulate and identify the presence (and concentration) of each of the targeted gases. For example, the membrane device will detect the presence of any physical precipitation in the oil/gas mix. While the backgated device allows for detection of ionic and polar species. This will help to give a high-level assessment and early warning for the pipeline integrity.
Our current delegated results include the fabrication of the three sensor types in Masdar’s clean room. This included the development of the various processing steps, design and fabrication of test devices and structures. This was followed up with development and characterization of the performance in various environments (gaseous and liquefied). These results have demonstrated the capability of graphene, as an active sensor material, to sense and determine the concentration of gases within different pressures, down to the 100’s of ppm level. Additional characterization assessments in different gaseous mixtures are ongoing and the results will be reported in the final paper.
Enhancing Smart Completion Capabilities by Integration With Digital Oil Field Real Time Monitoring System in a Green Field of ADMA-OPCO
Authors: Hussain Asim , Vega Juan Carlos , Hassane Mohamed Abdel , Yusaf Shabeer Ali , Abdul-Halim Abdulla Adam 
Published: November 2016

Abstract
This paper demonstrates enhancement of smart completion capabilities by integrating with digital oil field platform for effective performance management of dual lateral wells. Single smart completion with ICVs for controlled comingled production among two reservoirs was successfully deployed and commissioned for 03 oil producers in one of Abu Dhabi green fields.
The multi-position ICVs with customized flow trim design enabled regulating flow from reservoirs downhole and performance monitoring in real time. Additionally with launch of digital oil filed (DOF) in ADMA-OPCO, it is recognized as beneficial using the real time data monitoring to remotely control and operate smart wells for better reservoir management; helping to enhance the smart well system operating reliability. Production performance for one of the EPS smart well is also presented in this paper as a successful case history where the water production for the well was managed below 5% to keep the well flowing and resulted in saving the operating expense (OPEX) by US$ 478 K.
Three approaches were evaluated for flow allocation modeling among the two reservoirs and are presented in this paper i.e. a steady-state nodal analysis network model built in-house, virtual flow estimator (VFE) to provide real time results based on general choke equation and NETFlow (an alternate to VFE) based on a steady state simulator NETool capable of modeling complex lower completions; with later two approaches provided by the vendor and being optimized jointly with ADMA-OPCO. The steady state models are calibrated against the available PLT and real time downhole and surface flow- test measurements.
In the end, some unique issues observed with smart well completions, especially the functionality of the ICVs, are highlighted including the observed anomaly description and associated solutions implemented to restore functionality of some of the smart completion components.
Deployment of smart completions in this green field has resulted in simplifying the completion design and optimizes the number of wells required for field development. Integration of DOF with smart completion system has enabled the team to effectively manage the performance of the reservoirs (especially water production); in the absence of gas lift and continuous down-hole chemical injection during EPS tenure.
Operational and Asset Integrity Implications on Sour Gas Processing Facilities of Higher than Design H2S Carryover in Sweet Gas Leaving the Acid Gas Removal Unit Amine Absorber
Authors: Whateley Thomas 
Published: November 2016

Abstract
This paper presents the findings of a study into the consequences of H2S slip into sweet gas from an Acid Gas Removal (AGR) unit amine absorder. Whilst the study was initiated to investigate consequences to downstream consumers with respect to sales gas product specification, during this assessment the implications from a plant operational and metallurgical perspective were also investigated and found to be of critical significance and defined the maximum permissible H2S concentration in the sweet gas leaving the amine absorber.
The study assessed the maximum H2S concentration permissible in the sweet gas leaving the AGR amine absorber when considering stress corrosion cracking regions for the downstream plant materials of construction to determine maximum allowable H2S content in sales gas from a metallurgical perspective. The paper also investigated a multitude of operational implications regarding higher than design H2S in the plant sweet gas, including high H2S in the plant fuel gas network.
The study found that while the normal operating concentration of 3ppm(mol) H2S in the sweet gas is normally respected, the maximum allowable H2S concentration limit must not exceed 15ppm(mol) due to the risk of stress corrosion cracking in the downstream processing facility. This maximum limit from a metallurgical perspective also avoids all of the operational concerns identified.
In the event of an AGR amine absorber operational upset (e.g. loss of lean amine feed), after a relatively short duration, the concentration of H2S in the sweet gas leaving the AGR amine absorber rises rapidly beyond the normal operational concentration and will significantly exceed the 15ppm(mol) minimum limit. As such, plant modifications have been implemented to trip the AGR unit whenever process operating conditions exceed the normal operating envelope due to the potential of the sweet gas to go off spec.
This paper will be of interest to sour gas plant operators who remove H2S from their raw gas to meet a gas product specification using amine absorption processes. This paper presents findings of as study in to the operational and metallurgical consequences of exceeding H2S specification in Sweet Gas for a sour gas processing facility.
Successful Implementation of Flare Gas Recovery Systems in Gasco Plants
Authors: Allamaraju JagannathRao P , Mukherjee Rahul 
Published: November 2016

Abstract
Environmental issues such as global warming and economic considerations have resulted in the use of flare gas recovery systems to reduce flaring by capturing and either compressing the flare gases for other uses or recycling the flare gases to low-pressure process equipment.
Gasco requirement is to recover the flare gases of the three hydrocarbon flares instead of being continuously burnt. This should be through the installation of Flare Gas Recovery Systems (FGRS). This recovered gas should be either used as a fuel gas or injected back into the processing facilities.
World Bank has introduced the initiative "Zero Routine Flaring by 2030". In line with the above initiative, within Gasco there are KPIs which aim at reducing flaring and to recover the flared gases.
This is achieved through the successful implementation of Flare Gas Recovery Systems (FGRS) at GASCO Plants A, B and C.
Targeting Process Safety (PS), enhancement in HSE and performance monitoring, starting 2008, Gasco embarked on an ambitious Project requiring state of the art Flare gas recovery systems.
This Paper details the stages involved and detailed plan, i.e. Study, FEED and EPC. Optimization methodology necessary when designing or operating a reliable Flare Gas recovery Systems on existing Gas Plants to recover hydrocarbon gases over wide range of gas compositions without affecting the existing facilities.
A study was conducted on Hydrocarbon Flares of Gasco Plants A, B and C in order to predict the various continuous flow rates through the three Hydrocarbon Flare headers. It was predicted that for each of above plants the recovered gas could be in the order of ~1 to 2 MMscfd.
In FEED, considering the future additional flare gases, the design capacity of the individual flare gas recovery systems fixed at 5 MMscfd per train for each of above plants. EPC Package was developed to execute project on turnkey basis.
Proper FEED, EPC Detailed Design Review, HAZOP and SIL sessions produced an inherently safe Design.
In 2013 the project was successfully commissioned. The FGR system was found capable of operating at flowrates up to the design flowrate across the full range of molecular weights.
Actual recovery of Flare Gas post implementation on a yearly average basis for a period of three years (2013/2014/2015) are reproduced below:Plant A - 1.40 / 1.75 / 2.17 MMscfdPlant B - 1.58 / 1.78 / 1.86 MMscfdPlant C - 1.36 / 1.65 / 1.81 MMscfd
Improving Driving Safety at Rumaila Operating Organisation
Authors: Jacobs Louis , Clark Tony , Cornish Robert , Hughes Martyn , Jack William 
Published: November 2016

Abstract
The Rumaila Oilfield is the second largest oilfield in the world and is operated by the Rumaila Operating Organisation (ROO) a joint venture between South Oil Company (SOC), BP, PetroChina and the State Oil Marketing Organisation (SOMO). ROO has in the region of 6,800 personnel located at various locations throughout the Rumaila Field. With over 5,000 vehicles travelling across this area, occupying a foot print of around 1,300 sq. kilometres, driving is one of the most significant safety risks faced at ROO.
The road network in Rumaila covers 220 kilometres of roadways, comprising of asphalt, graded and ungraded roads. The Rumaila Field is split by an asphalt road, commonly referred to as the Spine Road, approximately 80 kilometres in length which is fed by five asphalt link roads from the surrounding towns of Al Zubair, Al Qurna and the city of Al Basra.
Whilst the Rumaila Field is operated by ROO, the Spine Road is traversed by local residents whose dwellings are encompassed by the geographical foot print of the contract and also by various service companies working on adjacent oilfields of West Qurna, Majnoon and Zubair. Those are in addition to the 300 companies operating on the Contract Area who are providing services to ROO.
Novel Approach in the Design of Friction Piles Resting on the Rock – Reverse Engineering
Authors: Yadla Nanda Kishore , Agrawal R. K , Oussama H. Takieddine 
Published: November 2016

Abstract
Offshore structures are supported by pile foundations to transfer vertical and lateral loads to the sub-soil. Based on the type of sub-soil, pile foundations are designed as driven or drilled & grouted piles. Design of the offshore pile foundation generally follows the guidelines of API RP 2A and API RP 2GEO. However, these guidelines being general it's applicability for complex soil-rock stratifications need to carefully reviewed. For the soils with sand/clay layers in upper stratum and rock or hard carbonate rock layers below these soft stratums, combined pile foundations are generally followed. These include driven pile in top soil with drilled & grouted insert pile in the rock below. However, this combined pile foundation has great impact on offshore installation time which directly influences cost of the project. From the design point of view, drilling through soil plug of driven pile has major impact on pile frictional and end bearing capacity. New design approach was developed for one of the platforms in the Arabian Gulf, where top soil is sand and clay up to 40 m followed by 10 m of Gypsum and 10 m of sand layers. Based on soil strata, composite pile option was recommended in the soil report with driven piles up to 40 m below mudline and insert piles of lesser diameter up to 55 m. However, this recommendation had an impact on project cost and also there was uncertainty in achieving required design pile capacity. For safe and economical design, a novel design was proposed by making use of rock end bearing to achieve the required capacity. However, in the geotechnical report rock design parameters for axial capacity were not reported and design guidelines are silent on capacity computation of driven piles in the rock. Therefore, end bearing capacity in the rock was back-calculated from the pile driveability analysis using the GRLWEAP software. With this back calculations and required design changes, composite pile option was eliminated and pile was designed with minimum penetration into the rock. This paper includes discussion on methodology, results, pre-cautionary measures, other additional requirements and cost comparison with conventional method. This new approach of pile design in complex soil-rock system is cost-effective and safe. This can be implemented for future platforms with the similar type of soil strata.
Advanced Well Modeling and Diagnostics to Manage Annulus Pressure
Authors: Srivastava Manish , Spuskanyuk Oleksandr , Abdulhai Walid , Alshehhi Ali S. 
Published: November 2016

Abstract
In order to monitor and diagnose B annulus pressure in the recently drilled extended reach drilling (ERD) and maximum reservoir contact (MRC) 30,000-35,000 feet-long wells a systematic study was conducted to understand causes of this pressure and to develop pressure management guidelines that will allow safe operation of these wells.
Newly-drilled wells were monitored from the construction phase to the well completion, handover, clean-up and then production phase with the focus on the following: Monitoring well parameters on daily basisBleed-off analyses (volumes and sample analysis)Review of the cementing job and the logs for 9-5/8" casing and 13-3/8" casingDiagnostic analyses including modeling and logs if necessaryMaximum allowable wellhead operating pressure (MAWOP) calculations
Detailed descriptions have been provided on how the annular fluid expansion volume due to a thermal effect was estimated using a computer modeling calibrated and history-matched to the field data. Results of modeling along with diagnostics using tools like spectral noise log (SNL), high precision temperature log combined with distributed temperature sensing have provided conclusive evidence that the wells are integral and safe to operate.
This unique combination of modeling and diagnostic tools allowed to optimize logging duration, minimize well shut-in time and improve fidelity of diagnostics through more detailed logging in the areas of interest. It was concluded that the main factors contributing to the B annulus pressure are the thermal effect seen during the well start up, the quality of cement job for the production casing, the volume of fluid in the annulus and the connectivity to the formation, if any. The study demonstrated that the wells are safe to operate with pressures below MAWOP and that B annulus is not in communication with the reservoir.
New Dry Thread Coating Reduces Risk and Costs
Authors: Klarner J. , Schalkhammer T. , Zacharias H. , Schaffer M. , Winkler P. 
Published: November 2016

Abstract
This paper describes a new developed dry coating for threaded Oil Country Tubular Goods (OCTG) premium pipe connections. An overview of the development is presented including the setup of the coating system and technical parameters. The basic structure of the coating system is described. The advantages of the coating compared to commonly used thread compounds are illustrated. Finally the operational areas of the coating system are presented. Different coating systems, their galling resistance and thermal stability were characterized employing tribological methods. The results of best-ranked coating systems were verified with make-up and break-out tests (M&B) on horizontal coupling application machines. Several dimensions and grades of OCTG premium connections were investigated regarding M&B capability under different conditions (e.g. deep temperature). Additionally the M&B capability was investigated with a vertical power tong, in order to simulate real life stabbing conditions on rig site. Parallel shortand long-term corrosion test series were performed to investigate the storage behavior. Finally tests according standard ISO 13679 were performed on threaded dry-coated specimens. An asymmetric coating system showed the best performance in surface adhesion and wear protection by several tribological tests. The M&B results of the dry-coated connections – without any additional lubricants – showed a stable behavior regarding torque turn monitoring. Premium connections coated with the new system were successfully made-up 15 times without initial and intermediate treatment. Recorded torque-turn diagrams revealed an unbelievable steady behavior after each make-up. In contrast to the standard procedure with doped threads the dry-coated connections haven’t to be cleaned and lubricated after each break-out. Thus, the use is significantly less time-consuming and a major risk of failure can be avoided. Additional the M&B tests with a vertical power tong and long pipes provide as well this steady behavior. The new coating system performs in a temperature range from -60°C to +60°C. Also the elevated temperatures according to ISO 13679 tests do not influence the behavior of the coating. ISO 13679 tests on a premium connection with applied dry thread coating were successfully performed. Short and long-term corrosion tests showed that dry-coated connections have enhanced corrosion stability than uncoated connections with storage compound. Hence long storage times before first make-up have no impact on the performance of the dry-coated pipe connections. A new ready-to-use product is introduced to the gas and oil industry. With the described new dry thread coating system no other lubricant is needed for the make-up of OCTG premium tubing and casing connections. This reduces risks and costs at the rig site due to easier handling. Additional there is also a positive environmental impact by replacing commonly used thread compounds through the new dry thread coating system.
Psyllium Husk in Water-Based Drilling Fluids: An Environmentally Friendly Viscosity and Filtration Agent
Authors: Salmachi Alireza , Talemi Pejman , Tooski Zahra Yarmohammad 
Published: November 2016

Abstract
Natural polymers are traditionally added to water based mud to improve rheological and filtration characteristics. Psyllium husk which is widely used in the health and food industries is produced from seeds of a plant which is grown and produced commercially in cool and dry weather. This study evaluates the performance of Psyllium husk as an environmentally friendly additive in water-based mud. Psyllium husk is added to pure water at various concentration to prepare water-based Psyllium husk mud. The optimal concentration of 0.75 to 1% by weight of Psyllium husk is found to have adequate rheological properties comparable with 5% by weight of bentonite. It has a fragile gel structure forming rapidly with time. Filtrate volume is reduced by 13% when Psyllium husk mud with a concentration of 1% by weight is used compared to the base bentonite mud. The insoluble parts of Psyllium husk create a very thin filter cake which are capable of blocking large pores to minimize the water loss into formations. Psyllium husk is more resistant to salinity of make-up water compared to the bentonite based mud and can develop higher viscosity when added to saline water. The advantage of Psyllium husk over currently used water soluble polymers such as Starch and CMC (Sodium Carboxymethylcellulose) is insoluble parts that can possibly block large pores and reduce filtrate volume. The laboratory findings of this research create a groundwork to use Psyllium husk as a viscosity and filtration agent in water-based drilling fluids and may facilitate further research and field trials.