bluuebunny/crossref_metadata_2025_split huggingface dataset:
Novel High Viscus Acid System for Proppant Fracture Acidizing
Authors: Karadkar Prasad , Suzart Walter , Sabhapondit Anupom , Buenrostro Adrian , Jauregui Jairo Leal 
Published: November 2016

Abstract
Production decline in acid-fractured reservoirs result from the elastic, plastic, and creeping response of highly confined vertical stresses that can destroy the conductive channels created by the acid. This paper introduces a novel, highly viscous acid system having the potential to suspend proppant and perform simultaneous acid and proppant fracturing treatments.
During production, impure carbonates tend to decrease productivity as quartz and other minerals migrate, leading to channel closing and/or collapse. Conventionally, acid fracturing treatments are performed by fracturing without proppant followed by different acid stages, including gelled acid. The idea of proppant-fracturing-acidizing (PFA) system entails fracturing in a single stage operation, although to avoid post-treatment plugging of the propped fractures the application of the process would be limited to very clean carbonates. This paper describes PFA fluid prepared by emulsifying hydrochloric acid (HCl) in the internal phase using diesel as the external phase. PFA offers distinct advantages compared to conventional acid systems, namely high viscosity to carry proppant, simultaneously acid-etching the rock, while attaining deeper live acid penetration. Another potential advantage is lowering operational time because mixing can be performed on-the-fly.
Preliminary experimental studies have been carried out to investigate the performance of PFA fluid and validate its applicability to perform simultaneous acid and proppant fracturing. PFA was prepared at various HCl concentrations and tested up to 28%. PFA fluid viscosity under different shear rates was measured at high-pressure/high-temperature (HP/PT). It exhibited viscosity as high as 2424 cp at 100°F and 300 cp at 300°F at 50 1/s shear rate. The oil external nature and the stability of the PFA fluid were examined using HP/HT autoclaves at 300°F. The effectiveness of corrosion inhibitors in PFA fluid was determined at 300°F. Static proppant settling tests showed that PFA fluid has good proppant carrying capacity at different particle loadings. After spending PFA fluid in carbonate, the viscosity was reduced significantly, exhibiting breaker-free cleanup.
Carbonate reservoirs having closure stress of more than 5,000 psi could be propped to enhance conductivity using PFA system. Enhancing the stimulated reservoir volume could be plausible using PFA system as a single-fluid treatment option, particularly if acid leakoff control and diversion, deeper penetration, and acid and proppant fracturing can be simultaneously implemented.
Extending Early Life PVT Model to Match Production and Fluid Composition History of A Gas Condensate Reservoir
Authors: Kabir Akim H. , Ahmed Mahbub S. , Lehman Joel R. , Al-Malki Bandar H. 
Published: November 2016

Abstract
This paper presents results (a case history) of a comprehensive equation of state (EOS) PVT model validation and calibration study conducted on an extensive gas condensate reservoir. Previous PVT model, derived from the original condition PVT samples has been reviewed. PVT samples, separator test data and production history matching of subsequent producing years pose a significant challenge to any early life PVT model. A systematic approach has been taken to tackle the task, starting from trying to recalibrate the original EOS PVT model to conducting various quality control and sensitivity studies. We show all the challenges that we faced trying to match well tests, well stream samples and the long production history, and their solutions. This includes identifying and explaining anomalous data, filling in the gap of the data trends, making use of look-alike (pressure, temp, depth, area) reservoir fluid composition, minor compositional modulation to account for common and known sampling and testing inaccuracies etc. This study shows how a pre-development PVT model of a gas condensate can successfully be calibrated with a long production history with minor logical adjustments, thus spare the engineers from the agony of having to re-do a full-fledged PVT modelling work; therefore add confidence to their predictive modeling work.
Innovative Well and Field Uncertainty Analysis
Authors: Ahonsi Wilson 
Published: November 2016

Abstract
Uncertainty analysis is usually conducted during field development, in order to quantify the uncertainty within the field, its impact on the recovery and the development strategy used in developing the field. However, uncertainty analysis usually focuses on field level, with little or no analysis done on the direct impact of well placement within uncertain region and it's impact on the field recovery i.e. well level uncertainty analysis. In order to investigate this and as a part the field phase development strategy, a thorough uncertainty analysis was conducted both on the field and well level. The field level uncertainty was done in order to quantify the reservoir uncertainty, and its effect on the production plateau length. The well level uncertainty was done, in order to optimize well placement and its effect of future recovery.
In order quantify the uncertainty in the field, the main uncertain parameters and their respective ranges were first identified using the data available. Once defined their respective impact on stock tank oil initially in place (STOIIP) and cumulative production was calculated by sensitivity analysis. Monte Carlo simulation was then used to combine the different parameters, in order to obtain a pessimistic, base and optimistic case. Well level uncertainty analysis was conducted using FSCAT analysis, to ensure that based on the current well location, future well location and cumulative production to date, each well was capable of delivering the predicted rate forecasted. Wells within high uncertain regions or with lower potential in meet production plateau were highlighted for relocation in the field development strategy.
The main uncertainty parameters identified in the field based on existing data were, oil water contact (OWC), Pressure Volume Temperature (PVT) oil formation volume factor (Bo), saturation height (rock type), structure and reservoir connectivity (poro/perm). Sensitivity analysis showed that structure has the highest impact on the STOIIP, while reservoir connectivity showed the smallest impact. The well level uncertainty analysis used a combination of conventional and streamline simulator, in order to produce a more robust form of decline curve analysis (DCA) using FSCAT analysis. This analysis allowed the calculation of the remaining oil per well that can be produced.
This paper describes how the uncertainty analysis was conducted on a field and well level, by combining the conventional simulator (compositional) and streamline simulator. As a result of this uncertainty analysis, the P10, P50 and P90 cases were created. The base case (P50) showed it is possible to maintain plateau to 2043. The well level analysis showed that, each well could produce the forecasted production based on its current location in the base case (P50). Wells potential map could be used in optimizing well placement.
Novel/Additive Information: Combined conventional and streamline simulation, in order to conduct a more robust uncertainty analysis and improved well placement strategy in field development.
New Age of Coiled Tubing CT Oriented Perforation—World First Application for Intelligent Completion in Hostile High-H2S Well
Authors: Panferov Rostislav , Zhandin Alexander , Burov Anton , Ghioca Gelu , Boulter Derek 
Published: November 2016

Abstract
Well completion and commissioning operations offshore present a variety of technical and operational challenges in the quest to maximize well productivity and optimize the economic value together with focus on safety. This is very relevant to perforation operations performed in hostile and high-pressure reservoir conditions encountered in a complex development project in the Caspian basin. The degree of complexity is increased due to required oriented perforation in a deviated intelligent completion well equipped with well monitoring system mounted on the outer side of the production liner. We describe the developed innovative technical solution for oriented perforation, challenges encountered, lessons learned, and results of this first-time-in-the-world implementation.
To meet job objectives, we selected electric-line enabled (e-line enabled) coiled tubing (CT) for precise depth control, the latest-generation advanced gun deployment system (15,000-psi working pressure 5.12-in. ID H2S-rated) for conveyance of long gunstrings under pressure paired with specially developed hostile oriented gun system, and newly designed CT perforation string components, such as the perforation-shock-resistant bottomhole assembly (BHA), two independent emergency disconnects, high-tensile CT logging head disconnect weak points, perforation passive casing orienting device, and tuned software to predict and evaluate shock load and dynamic underbalance.
The oriented perforation job was successfully completed with this innovative oriented method for perforation applications—passive casing orienting device for deviated wells. This perforation technique proved capable of providing desired orientation accuracy and effectively minimized operational time and associated risks. Such approach allowed safe and efficient perforation in a controlled well environment and provided perforation in the desired direction away from downhole well monitoring equipment and with accurate depth control, and managed detonation shock load in overbalanced conditions, which avoided any well fluid influx or H2S release. The developed solution is a seamless integration of e-line enabled CT, the CT logging head, a gun deployment system for pressurized well conditions, and a set of wireline tools and specialized perforation equipment for passive orientation.
This is the first time that the described oriented CT perforation operation using such innovative techniques has been performed in the world. The experience demonstrates a method to safely and efficiently facilitate challenging oriented perforation jobs in the future for intelligent completion applications and a great opportunity for well performance evaluation through distributed temperature-sensing analysis.
Bridging Gaps: Establishing Safety Culture within Young Engineers
Authors: AlKazimi Mohammad A. , Altabbakh Hanan M. 
Published: November 2016

Abstract
The inherent complexity of the processes and the volatile nature of petroleum products compel the petroleum industry to continually seek and develop tools and techniques to identify, evaluate, and mitigate potential risks that can negatively impact their process operations. Additionally, government agencies and nonprofit professional societies guide the petroleum industry with regulatory guidelines, standards, and recommended best practices. The industry and these agencies and societies work to improve operational management, to ensure safe working conditions, and to minimize risk of all kinds, so that if failures occur, damage is contained within tolerable limits.
This paper defines the establishment of "Health, Safety and Environment Risk Management System in the Oil Industry" course in Kuwait's Academic institutes. Not only it is designed to cover the technical aspects of HSE in the oil and gas industry, but it also enhances soft skills many students tend to overlook such as communications skills, safety awareness, ethical responsibilities, and most importantly, creating safety culture by exposing HSE awareness and knowledge to cater to the oil and gas industry. In a vision to invest in the human capital, this course will be a starting point to bridge academic gaps between academia and the oil industry throughout different disciplines, as well.
Cementing Practices to Solve Well Integrity Challenges of Ultra Deep High Temperature Wells in Western China
Authors: Guo Yabin , Li Xiaochun , Feng Shaobo , Zhang Changduo , Liu Rui , Zhang Zhi , Li Tan , Guo Peng , Wang Rui , Taoutaou Salim , Lee Junn Shyong 
Published: November 2016

Abstract
Ultra-deep wells (maximum measured depth of 8000 m) located in the Tarim Kuqa foreland oil field in western China pose significant challenges to well integrity because of the high temperature (maximum bottom hole static temperature of 180°C), high pressure (maximum 145 MPa), and a deeply buried, thick, salt-gypsum formation (maximum measured depth of 7800 m). An engineering cementing approach with continuous improvements has been applied in the cementing operations in over 200 wells from 2008 to 2015.
The ultra-deep casing program was designed to meet the complex drilling and high-pressure completion requirements. Meanwhile, fit-for-purpose cement systems have been developed to seal the long, high-pressure interval of the salt-gypsum formation. In addition, a procedure on spacer optimization and evaluation has been established to optimize target zone cementing in oil-base mud. Tailored cementing procedures from well preparation to post-job remedial work were developed to meet the severe lost circulation challenge caused by the narrow pore-fracture pressure window in the reservoir.
Since 2008, various problems related to well integrity have been encountered in the field, including casing leaks, incomplete zonal isolation post cementing and sustained casing pressure (SCP) during the exploration and development activities. Substantial local operational practices have been accumulated to solve these intractable problems through the 1200 primary and remedial cementing operations undertaken to the present. A comprehensive pool of cement slurry formulations has been established with optimized properties including extreme high density with good pump-ability, saturated salinity resistance, and cement setting under an extended temperature difference to meet the various cementing requirements resulting from complex and extreme downhole conditions. A design-execution-evaluation (DEE) cycle of cementing operation has been implemented to achieve continuous improvements and shorten the learning curve in the face of the new challenges continuously encountered during the extended exploration activity of this region. The annual average percentage of qualified cementing jobs has been enhanced steadily from an initial 55% in 2008 to the present 73%.
The nature of this ultra-deep reservoir limited the application of lessons learned from other oil fields. A series of cementing practices developed empirically to address the challenges of this field have been documented and optimized over the years. They have proven to be successful in the field and form the foundation of designs going forward.
Well Integrity Management: Analysis of Multi-Barrier Corrosion in Mature Wells Using Advanced Magnetic Impulse Technology
Authors: Jain S. , Al Hamadi M. A. , Alghasra A. M. , Saada M. , Amin A. H. 
Published: November 2016

Abstract
Cost effective management of Well Integrity is crucial for maintaining O&G production economics particularly in mature fields. Optimization of Workover resources, cost, time and associated production outage is the key for maximizing productivity. Monitoring wellbore completion through multi-tubular corrosion scanning provides the ability to operators in making this critical decision. Objective of this field trial conducted in the SNOC Sajaa field, onshore Sharjah, United Arab Emirates; was to determine thru-tubing high resolution metal loss across multiple barriers for well integrity assurance in single completion wells.
Wells operating in a low pressure envelope during later life cycle are susceptible to collapse against the original pore pressure due to the loss in wall thickness from corrosion, particularly in the case of legacy packerless completions. Quantitative measurement of thickness in the tubing and casing strings independently was addressed by a real time Magnetic Impulse Defectoscope tool. Scanning metal thickness by measuring magnetic impulse decay including the qualitative detection of the fourth barrier was achieved in the downhole gas-condensate environment. The results were interpreted to classify the average wall loss profile in this pilot project. The results analyzed and presented in this paper demonstrate the effectiveness of continuous corrosion inhibitor using ¼″ capillary strings and direct annulus injection. In addition, a deterioration comparison of tubular integrity over 10+ years of production in a high temperature low pressure corrosive (H2S & CO2) system is presented. Effectiveness and limitations of the Electromagnetic survey against Multi-Finger Caliper is compared and the importance of repeatability in well integrity testing is also demonstrated.
An insight into the metal detection accuracy through multiple tubulars and the fundamentals of well integrity assurance in mature assets is presented. Finally, evaluating the true need for intervention- method and timing, resulting in the reduction of mature well life cycle costs in the current low oil price environment.
Thermal Activated Resin to Repair Casing Leaks in the Middle East
Authors: Sanabria A. E. , Knudsen K. , Leon G. A. 
Published: November 2016

Abstract
The challenge was with wells where the casing had lost its barrier/integrity because of casing leakage. There the result was that production wells were closed in. These problems are often caused by cementing failure when the well was drilled and cemented, lost zone, experienced corrosive formation fluid from the formation, treads leakage or other reasons for this integrity failure. There have been tried out serial methods for how this casing leakage can be repaired safely and in a cost-effective manner.
Casing damage/leakage with low or non-injectivity have been squeezed and repaired with Thermal activated resin. Thermal activated resin is a nonreactive polymer with qualities that are resistant to all formation corrosives/hazard fluids. Thermal activated resin will reinstall a good well barrier and integrity to protect casing from future corrosion. Thermal activated resin has been used in serial wells in Saudi Arabia in both onshore and offshore fields. In a small volume, with a controlled setting and short operation time, a high success rate has been achieved.
The solution to these challenges was developed by designing thermal activated resin casing repair liquid plug with a density equal from 64 pcf to 152 pcf. The setting time can also be adjusted accurately. This new treatment slurry was able to be bullheaded and displaced with polymer mud/brine at 64 pcf to 152 pcf. The slurry was easily able to be pumped through the drill pipe. This novel product possesses low elastic modulus and high flexibility in density, viscosity and fast setting time according to requirements. The well barrier elements made of this product have no risk of shrinking, cracking, gas channeling or deterioration upon exposure to harsh reservoir environments.
This paper presents a case history and field application of this novel polymer based casing repair material for successful treatment of full losses or when there is no/low injectivity in formations in most of the critical oil and gas fields in Saudi Arabia. Also, the paper includes a discussion of the methodology, material properties and applications.
Sulphur Recover Unit Condenser External Tube Failure Investigation
Authors: Sabry Houssam 
Published: November 2016

Abstract
Abu Dhabi Gas Liquefaction Company Ltd (ADGAS) operates three sulphur recovery units (SRU). Units are aimed at reducing acid gas flaring. Sulfur is produced from these units. Units follow the Calus and Super Calus process. Each unit is composed of a main combustion chamber, waste heat boiler, series of condenser, reactors, line heaters and an incinerator. In one of the SRU units, one of the sulphur condensers had a tube failure. Failure investigation showed that one tube failed externally (water side). Tube internal surface revealed no tube degradation. Root Cause Analysis exercise revealed that failure was attributed to a corrosion assisted steam blanketing phenomenon. Damage was only confined to the first few centimetres away from the tube sheet hot side. Furthermore signs of Boiler Feed Water (BFW) corrosion was there. Corrosion control of the BFW quality was ensured through continuous intermittent blow down of the condensed BFW in addition to introducing an additional chemical injection skid to control the BFW quality in the SRU. These actions were able to control the quality of the BFW. Furthermore, ADGAS initiated a Computational Fluid Dynamics Exercise (CFD) through a specialised consultant to understand the possible scenario of the steam blanketing. CFD was done for normal operation ns cases in addition to transient conditions. CFD was able to prove that steam blanketing actually took place during one of the transient conditions. Actions were hence considered to prevent the recurrence of such transient condition.
Technology Trial Review: Selective Coiled Tubing Re-Entry of Two Open Hole Multilateral Wells Using Intelligent Electromechanical Arm
Authors: Abubaker Saeed , Abdelaziz Mohannad , Noui-Mehidi Mohamed N. , Zarea Marwan 
Published: November 2016

Abstract
A maximum reservoir contact (MRC) well, by definition, is a single or a multilateral horizontal well with more than five km of total contact with the reservoir rock. Planning of these wells requires extensive modeling studies to optimize total length, placement and configuration of branches.
The main objective behind the MRC well concept was to improve individual well productivity and hence reduce the unit development cost and to better develop hydrocarbon assets. In fact, oil fields developed using MRC wells shows significant improvements in those wells performance in terms of increased PI, lower drawdown, and significantly delaying water and gas conning.
A major challenge that faces production engineers in their daily operations is identifying and accessing laterals windows in those MRC multilateral wells, in order to preform rigless downhole sensing and intervention jobs (logging, stimulation, etc.). This challenge varies in difficulty based on the technology advancement of multilaterals (TAML) level, for example in TAML level 2 wells (cased mainbore) metal logging tools such as casing collar locator can be used to identify and confirm the access of laterals, while this of course is not an option in TAML Level 1 multilateral wells (open hole mainbore and lateral). Another reason selective re-entry of TAML Level 1 is considered very difficult is due to the shape and quality of the wellbore near the junction (window), post drilling and after distortion of hydrocarbon flow.
This paper presents an intelligent electromechanical tool, jointly developed to address this issue. The tool consists of a sensing package that can identify and locate the depth and orientation of the lateral window using US and EM sensors, and an electromechanical arm that can be easily rotated and actuated with a wide range of angle, to lead and steer the bottom-hole assembly into the required lateral. This paper also presents the discoveries, challenges, and results of testing this intelligent tool in two TAML Level 1 multilateral oil producers, one fishbone well with a mainbore and six open hole laterals branching from it (shut in conditions) (Mohannad Abdelaziz, 2016), and the other is an open hole well mainbore with a lateral branching from it (shut in, flowing conditions). In Both trials the tool was successfully used to guide a production logging tool into different wells laterals.