bluuebunny/crossref_metadata_2025_split huggingface dataset:
Breakthrough Technology for Produced Water Desalination
Authors: Baldoni-Andrey Patrick , Jacob Matthieu , Pedenaud Pierre , De Souza Guillaume , Callaud Pierre , Dautriche Bastien 
Published: November 2016

Abstract
The petroleum industry produces much more produced water than oil and this trend is accelerating constantly. Desalination is an option to recycle water for smart water injection, to make EOR much more economically attractive by reducing chemical doses, or to reuse water for the benefit of surrounding communities in the frame of a shared-value program.
In order to find an alternative to reverse osmosis and evaporation processes, Total initiated a collaboration with Adionics, which has developed a new technology based upon liquid-liquid extraction. The solvent is not soluble in water and has a stronger affinity than water for specific or all salts. By reversible displacement of the salts from water to the solvent, desalination takes place in a set of extraction reactors or column. A second set of reactors or column operating at higher temperature enables regeneration and recycling of the solvent.
The process efficiency was initially validated in 2014 on solutions containing sodium chloride, and other salts. Then, Total and Adionics decided to evaluate this technique on several produced water samples from oil fields and gas fields. A full experimental matrix was developed and carried out in 2015 at Total R&D center to evaluate performances of this new process. The presence of the mineral and organic components, such as hydrocarbons, did not affect the process’ performances. The results clearly demonstrated that it has the potential to be applied to produced water at salinity much higher than sea water and up to 150 g/L of Total Dissolved Solids.
In 2016, Total and Adionics are preparing a pilot test (around 100 m3/d) with other industrial partners to validate those promising lab results at a pre-industrial scale. The objective for all industrial partners is to qualify a new alternative for water desalination which has a lower cost and a smaller footprint on environment (energy consumption) than conventional treatments such as evaporation/crystallization.
Design Optimization of Anti Surge Control Valves on Turbocompressors
Authors: Doenni Markus , Grutesen Lothar 
Published: November 2016

Abstract
This article describes the development process for a new control valve by means of Parametric Modelling Technology for the inner geometry of the valve housing. Typically a development process starts with a fixed 3-D CAD model. Subsequently the hydrodynamic properties of the design (such as the flow resistivity of a pipe element) are then calculated by CFD using standard boundary conditions. Very often and based on the calculation results the engineer has to adjust the model and then starts the loop again. In our case the design object is defined by a variable parametric geometry only. In a computerized iteration process using an upfront CAE tool, the system will automatically converge to an optimum solution. The results are amazing.
Modified Intervention-Less Inflow Control Device for Water Management
Authors: Sadana Anil K , Agrawal Devesh K , Noui-Mehidi Mohamed N 
Published: November 2016

Abstract
Excessive water production shortens the life of producing wells and severely limits their economic viability. Inflow control devices (ICDs) are used to halt water output and compensate for permeability variation by shutting off the sleeve where water production increases. Traditional ICDs need activation and intervention for the water shut-off, which leads to non-productive time, increased cost, and reduced revenue. Intervention-less passive technology addresses this imbalance issue by designing an ICD that highly reduces water breakthrough into the wellbore in virtually any porous media.
The intelligent well completion technology presented in this paper focuses on a modified ICD with no movable parts for water management. The ICD annulus is packed with a porous Polytetrafluoroetheylene (PTFE) sleeve that exhibits water-sensitive control functions. The porous PTFE sleeve causes a differential pressure for water and oil through the modified ICD. Differential pressure occurs because hydrophobic material and brine form droplets due to their higher surface tension, whereas oil flows in a more streamline manner. This situation leads to choking of the pore throat and higher pressure in the flow loop for higher brine cut. Flow testing through porous a PTFE sleeve shows about 200 % increase in differential pressures for 70% brine cuts compared to 0% water cut, which means it can restrict flow when the brine cut increases. The porous PTFE material has high thermal and chemical stability and can tolerate salinities as high as 246,000 ppm for long periods of time. Tests have confirmed the efficacy of the tool remains unchanged, even after flowing brine and diesel through the material for more than 400 hours. Prototype testing indicates that the modified ICD significantly improves recovery performance. This innovative tool will be field tested shortly.
This modified inflow control device offers a novel intervention-less, reversible subsurface water management technology by reducing production from zones with high water cuts.
Innovative Solution in Reducing Turnaround Duration
Authors: Al Jaberi Awadh Brek , Al Shamsi Abdulla Saeed 
Published: November 2016

Abstract
Turnaround is a major task involving large number of manpower, machinery and enormous activities. Success of Turnaround requires effective planning and efficient execution. Since ADGAS has three LNG Trains and two ASR Facilities, every year any one train undergoes a major turnaround. As LNG Trains 1 & 2 have several inter-connections, both Trains have to be shut down for the maintenance work scope in common facilities.
In the year 2015 LNG Train-1 Turnaround was planned for 35 days period including 8 days for common facilities maintenance. The work scope for common facilities was estimated to be difficult to be achieved in the provided 8 days window, due to space constraints and limitations arising from adjacent work in live gas manifold lines at ADMA.
A detailed study was conducted and a strategy was worked out in completing some of the common lines replacement prior turnaround without affecting production. It required critical changes in operating conditions, which were tested initially prior to carrying out the job.
By this more than 35% of the common facilities work scope was completed prior turnaround, thus achieving turnaround completion within the stipulated period.
Technology Enhancements in Effectively Modeling Sour Gas Processing
Authors: Sheikh Saifuddin 
Published: November 2016

Abstract
In gas processing and refining industries, natural gas and petroleum based feeds frequently contain sulfur in the form of H2S, SO2, COS, CS2, and other components. Even in small quantities, these acid gasses are hazardous to health and the environment, and removal is regulated prior to product sales. The removal of sulfur in midstream and downstream applications typically involves a series of absorption, extraction, oxidation, and conversion processes to form elemental sulfur, which is removed in liquid form and used in chemical applications, such as the formation of hydrogen sulfide or cleaning agents, and in commercial applications, such as fertilizer. A typical sulfur removal plant will typically contain an acid gas treating step, sulfur recovery (modified Clause) step, and tail gas treating step, before sending by-products to the incinerator/flare.
SIF Failure Probability Calculations – Comparison of Methodologies and Uncertainty Evaluation
Authors: Altamimi Maitha , Constantini Ahmed , Singh Vinod Pal 
Published: November 2016

Abstract
Risk is inherent in the facilities associated with petroleum and natural gas industry and various safeguards are employed to reduce the risk to the tolerable level. This paper is about instrumented safeguards which are referred to as safety instrumented functions. Specifically, the paper is the survey & comparison of the standards used for evaluating failure probabilities of safety instrumented functions. In designing as well as in maintaining the safety instrumented functions it is pertinent to know the differences in the methodologies of various standards and ensure that the overall approach yield pessimistic result to account for the uncertainties associated with the evaluation model and the associated failure data.
The paper starts with the qualitative discussion concentrating on the methodologies described in the various standards. To further aid in the analysis one example of a typical safety instrumented function, generally found in upstream oil/ gas facilities, is presented and is subjected to failure probability evaluation using different methodologies. The failure probabilities are then further analyzed for uncertainties with respect to the change in inputs.
The evaluation results are used to generate generic conclusions covering the two important aspects of the evaluation, i.e., models employed as suggested by the different standards, and failure data used in conjunction with the models. Along with the conclusions the challenges are also identified wherein further works are required in the ever evolving subject of safety instrumented functions.
Development of Crosswell Electromagnetic Monitoring System Using the HTS-SQUID Magnetometer
Authors: Harada Makoto , Yoshimatsu Keita , Kunishi Yosuke , Chiba Hiroshi , Hato Tsunehiro , Tsukamoto Akira , Tanabe Keiichi , Watanabe Hidehisa , Ishikawa Hidehiro 
Published: November 2016

Abstract
For accurate and stable monitoring of the oil/gas and fluid distributions in the reservoir during the EOR (Enhanced Oil Recovery) operation even if the well distance exceeds a thousand meter, JOGMEC (Japan Oil, Gas and Metals National Corporation) is developing a crosswell electromagnetic survey system with applying a super-sensitive magnetic sensor "SQUID" (Superconducting Quantum Interference Device). In this study, we have developed the component technologies of borehole SQUID magnetometer and powerful transmitter coil. The SQUID sensor performs in the temperature condition of 77 K, where the liquid nitrogen is available for cooling. To deploy the SQUID sensor in the deep borehole safely, we designed and trial fabricated pressure- and heat-resistant vessel which contains the glass Dewar of liquid nitrogen, release tubes of vaporized nitrogen gas, electrical circuits, and other devices to control the SQUID sensors. The developed transmitter coil has magnetic moment of 27,500 Am2, which will satisfy the intensity for our purpose. We demonstrated the stable operations of the prototype models of borehole SQUID magnetometer and transmitter systems with using the research wells of the JOGMEC field, of which maximum depth is 300 m and cased with conductive tube. The SQUID magnetometer has the ability to be deployed in the environment of 3,000 ~ 4,000 m deep boreholes by the laboratory experiments. At the next stage, we will demonstrate the systems at the actual borehole, whose typical depth is greater than 1,000 m. On the other hand, we have been developing the algorithms to interpret and correct the effects of conductive casing tubes, and three-dimensional modeling of underground structure. For the demonstration of their performance, we will also conduct the crosswell measurement with using the test wells.
Facing the Big Crew Change: Fast Tracking the Technical Development of Emirati Nationals
Authors: Al Daghar Khadija Ahmed , Ramamoorthy Raghu , Gunter Gary W. , Al Ameri Shamma Qarran , Habib Amir 
Published: November 2016

Abstract
National and International Oil and Gas Companies are continually seeking and applying new technologies, processes, and methods to reduce their cost of finding and producing hydrocarbons in order to maximize Return-On-Investment (ROI), and remain competitive in the current and challenging global economy. Improving the efficiency of business processes and maximizing the productivity of the workforce is a key component for success. A key strategic component is to reduce the time it takes to develop technical staff abilities, skills and confidence to become independent contributors.
Although technology has helped companies utilize advanced measurements it remains a challenge to develop Operations and Reservoir Petrophysicists. Strategic non-conventional training that is based on technical competency management skills assessment has emerged as a fundamental tool. Frequently, traditional training that is not competency based may lack the proper vehicles for training, technology and transferring knowledge to developing subsurface professionals. In some circumstances the lack of knowledge transfer may be jeopardizing oil and gas field development efforts.
The technical complexities of Operations and Reservoir Petrophysics can only be effectively addressed through the selection, and application of appropriate technology using a multi-disciplinary approach, hands-on, custom designed attachment program and well trained competent personnel. The skill development process must be managed using competency based assessments.
Each individual develops new skills at different rates and learns differently. For strategic attachment programs to be successful in transferring skills and knowledge it is essential to systematically identify the technology gaps and design project-specific knowledge training.
An efficient and effective way to do this is to establish core competencies for different job profiles, develop skills matrices and competencies assessments, and design training or competency improvement events to address these needs. We present a recent case study where ten Emirati nationals – 3 gentlemen and 7 ladies – of a major oil operator underwent and successfully completed a one-year attachment program in Petrophysics.
Compositional Simulation for Time-Lapse Seismic Modelling on a Synthetic Reservoir With a High Content of CO2
Authors: Pinto P. , Azevedo L. , Ribeiro M. , Gomes J. 
Published: November 2016

Abstract
This work focuses on the creation of a refined workflow for 4D seismic modelling using compositional fluid flow simulation on the synthetic reservoir CERENA-I, which mimics some characteristics of a real Brazilian Pre-Salt field. This reservoir has a saturated oil leg with a retrograde condensation gas cap, both with a high content of CO2, for which a production strategy capable of dealing with large quantities of gas was required and developed.
A rock physics model was built for this reservoir in order to compute time-lapse seismic reflection data with data retrieved from the compositional fluid flow simulation. This allowed assessing the influence of pore fluid changes in the seismic response of the reservoir and the creation of a dataset of time-lapse seismic volumes correlated with a production strategy, which can later be used in multiple seismic inversion studies.
Fully Implicit Coupling of Multiple Reservoir Models with Common Water Injection Facilities
Authors: Patacchini Leonardo , Bedewi Mahmoud , Farouk Magdy 
Published: November 2016

Abstract
The building, calibration and validation of a coupled simulation model treating two giant subfields simultaneously with their common water injection facilities are presented. The primary objectives of the project were to develop a tool providing more accurate forecasts by consistently allocating injected volumes to both subfields, and to help identify network upgrades necessary to accommodate the long-term development plan. Simulation results presented in this paper are nevertheless based on an eight-years (2015-2023) drilling schedule, followed by no further activity.
Building of the model involved migration of separate reservoir and network models to a next generation simulator capable of treating both surface and subsurface flows fully implicitly. Coupled model operation without network (i.e., with wells constrained by guide-rates considering a common field injection target) and with network (i.e., with wells constrained by self-consistently calculated backpressures) are discussed and compared in detail. For the latter case, particular care is necessary in terms of modeling injection modules.
Calibration consisted of shifting the lift performance curves of more than 200 active injection strings, in order to make up for any mismatch in the flowing wellhead pressure and help ensure rate continuity at the transition from history to forecast. Tuning of the surface network, modeled "as is" according to its physical layout, was not necessary based on the good backpressure match obtained for the more than 40 active injection towers.
Validation was performed through a one-year blind test, from April 2015 (start of forecasts) to March 2016. The procedure first involved well-by-well comparison of injection rates, for which, because of allocation uncertainties, a qualitative match was accepted; it second involved a comparison of the injection split between the two subfields, for which less than a 1% mismatch was achieved.
Pore-Scale Experimental and Numerical Study on Permeability Characterization of Abu Dhabi Offshore Carbonate Micromodel
Authors: Li Hongxia , AlFarisi Omar , Voort Bob , Dimas Clara , Zhang TieJun 
Published: November 2016

Abstract
Carbonate rock exhibits great diversity in composition, pore size, and surface wettability, all of which significantly affect oil recovery process. In this work, we studied the pore size distribution, porosity, and permeability of the rock sample from one of the Abu Dhabi offshore reservoirs.
To characterize the rock sample, mercury intrusion porosimetry combined with microscopic techniques were used. A digital pore-throat network was reconstructed by processing x-ray images of the rock sample. In order to experimentally visualize liquid/solid interaction and flow patterns, a polydimethylsiloxane (PDMS) microfluidic device was fabricated with the same digital pore-throat network map. Both flooding experiment and numerical simulation were performed to quantify the permeability and multiphase flow behavior inside the rock.
From the oil-water displacement experiment, irreducible oil trapped in dead-end pores and narrow throats can be clearly observed. Furthermore, the numerical Lattice Boltzaman (LB) simulation results show the influence of surface wettability on the oil trapping and saturation change. The absolute and relative permeability of oil-water system were calculated from the direct water flooding simulation results. Furthermore, a three multiphase flow was simulated and oil saturation was monitored in order to understand the mechanism of water-alternating-gas enhanced oil recovery. This paper provides a feasible solution, which takes advantage of the recently developed micromodel fabrication and simulation techniques, on systematic permeability characterization of heterogeneous carbonate rocks.
Assessment of Miscible EOR in a Giant Offshore Carbonate Reservoir
Authors: Willingham Thomas W. , Kohata Akihiro , Irwin Drew , Buang Kamarul , Al Sowaidi Alunood 
Published: November 2016

Abstract
In this paper we present a comprehensive assessment of the EOR potential in a giant off shore carbonate reservoir including a novel screening methodology to assess reservoir, fluid and miscible characteristics across various reservoir and geologic units. We employed a multi-disciplinary approach to identify potential pilot locations within the leading geologic and reservoir units and assessed the miscible EOR uplift through both an analytical assessment of potential to screen for the broad uplift within the targeted geologic areas and developed compositional simulation models for the pilot areas utilizing a history matched simulation model to estimate the uplift for the specific pilots. In this paper we utilize a quantitative estimate of incremental EOR potential utilizing an analytical estimate of sweep efficiency which is based on the viscous to gravity ratio (VGR) coupled with SCAL measurements of the remaining oil saturations to estimate the uplift from miscible EOR based on core flood results using hydrocarbon separator gas, CO2 and enriched hydrocarbon separator gas.
To identify pilot areas within the leading geologic areas, a multi-disciplinary Task Force spanning Field Development, Projects, Drilling, Well Operations and Facilities was formed. Key assessment criteria include pilots are geologically representative of the broader geologic area, pilots are aligned with field development plans, pilots are sourced from drilling and production centers (in this case artificial islands) with appropriate facilities (including corrosion resistant alloys if required), pilots are optimally located considering drillability and anti-collision, and pilot areas are of higher maturity such that field implementation can be expedited.
Identified pilot areas were then assessed for miscible EOR uplift utilizing a history matched compositional simulations with a tuned Equation of State (EOS). Sector models for the pilot areas were created to investigate the uplift in incremental recovery under various WAG ratios, gas injection schemes, injection gas timing and PV injected. In summary, a unified methodology was created to access miscible EOR potential, rank various reservoir and geologic areas, specific pilot areas were identified, and miscible EOR potential was quantified for the identified pilot areas using compositional simulations based on a tuned EOS and history matched simulation model.