bluuebunny/crossref_metadata_2025_split huggingface dataset:
Cathodic Protection Effectiveness Evaluation in ADCO Wells Utilizing Multi-Barrier Magnetic Defectoscopy
Authors: Yugay A. , Daghmouni H. B. , Ali A. B. , Gupta T. K. , Grandhe S. P. , Volkov M. 
Published: November 2017

Abstract
The objective of the project is to evaluate effectiveness of the Cathodic Protection (CP) as a corrosion reducing solution after several years of implementation. The project has been initiated based on the Well Integrity Records and Requirements.
5 wells in different Company's fields have been selected to demonstrate the effectiveness of Cathodic Protection. The wells are characterized by different casing design, age, and time of CP installation. The wells represent distinctive fields, where similar integrity issues are observed, such as intense casing corrosion due to lack of isolation and exposure to corrosive environment. Analysis of CP performance is based on actual metal loss identified in 9-5/8″ and 13-3/8″ casings using multi-barrier electromagnetic metal loss evaluation tool. The statistical analysis was performed to correlate the corrosion rate with different key parameters and to evaluate how effective the CP is during the well life cycle.
Several observations were made based on the logging results and statistical analysis. The areas protected by CP demonstrated lower corrosion rates. A clear correlation was observed between the corrosion progress and the period of time the wells were operated without CP. 13 3/8″ casing is relatively more protected compared to 9 5/8″ since the CP effectiveness attenuates with depth and becomes less effective below the 13 3/8″ casing shoe. The corrosion zones identified in several wells in 9 5/8″ casing inside 13 3/8″ clearly confirm that CP is effective only for the outer casing surfaces and does not protect from internal corrosion. Cement quality and bonding also affect the CP performance. The recommendation was given to implement the CP system in all currently unprotected wells and those to be drilled in future.
The results of the conducted study clearly demonstrate effectiveness of Cathodic Protection system in reducing corrosion in well casings. It also helps to identify system limitations and key parameters affecting its efficiency. This paper might be interesting to other Companies with similar well integrity problems due to corrosion.
Oil Spill - Cleaning and Recovery by Multi-Layered Fibre Tube
Authors: Chaturvedi Manu , Adlakha Manan Manoj , Choudhary Animesh 
Published: November 2017

Abstract
In recent years, oil spills have been tremendously harming the environment. The major challenges that the world today faces is its cleaning and recovery. Our aim is to clean the spilled oil at a faster rate and recover it in an efficient manner.
Our idea aims at the use of a specially designed three layered tube, ‘Polycoweed’ which consists of three layers consisting of milkweed fiber, cotton fiber and finally a layer of polypropylene. The tube is mostly made up of naturally occurring substances and so is eco-friendly. 155g (5.7 oz) of milkweed fiber can absorb a total of 7 L (1.8 gal) of oil at a rate of 0.23 L (0.06 gallons) per minute, twice as fast as competing products made from polypropylene. Polypropylene is the outermost layer with milkweed and cotton placed sequentially inside to allow selective absorption.
Polycoweed will not only clean up the oil spill but at the same time recover the absorbed oil. The cotton fiber and the milkweed fiber that we have used have special ability to absorb about 30-40 times of oil of their own weight. Also the tube that has been designed can be reused 4-5 times.
The novelty lies in the fact that this tube ‘Polycoweed’ isn't only cost-effective but will also generate revenue from oil that is recovered. This tube is the solution to all the problems which this oil driven world was searching for.
A New Dual-Permeability Model for Naturally Fractured Reservoirs
Authors: Lu Jing , Qu Jinbao 
Published: November 2017

Abstract
Naturally fractured reservoirs (NFRs) are the reservoirs with two distinct types of porous media called the fracture and matrix. The pressure behavior of naturally fractured reservoirs is usually studied by using Warren and Root model (Warren and Root, 1963).
Warren and Root model assumes that production from the naturally fractured system goes from the matrix to the fracture and thence to wellbore (Warren and Root, 1963). However, this assumption is oversimplified if the contrast between the permeability of matrix system and that of fracture system is not significant. In order to estimate the limits of validity of solutions based on Warren and Root model and to study the behavior of a naturally fractured reservoir when the contrast between the two permeability are not significant, it is necessary to solve the original model proposed by Barenblatt and Zheltov (Chen 1989). But the analytical solutions to this model which were obtained by numerical analysis or numerical inversion are very complex and inconvenient to use (Lu, Zhu and Tiab, 2009).
Assuming that both of the matrix and fractures produce directly into the wellbore, a new mathematical model for dual-permeability naturally fractured reservoirs is presented in this paper. Based on our proposed model, it is concluded that there are four stages for the pressure behavior of NFRs; the double-permeability system behave like a reservoir with a constant pressure boundary when the dimensionless time approaches to infinite.
The solution procedure proposed in this paper is a fast tool to evaluate a vertical well performance in a dual-permeability naturally fractured reservoir.
Reduce Total Cost of Ownership and Improve Industrial Grid Stability at Oil and Gas Facilities with Integrated Power Management
Authors: Shamim Taiyab , Pineda Andrés Felipe 
Published: November 2017

Abstract
This paper will examine the benefits of using integrated power management systems for automatic load shedding and generation control at oil and gas facilities.
Many oil and gas facilities today, such as refineries, offshore installations, pipelines, and well pads located in remote areas operate their own autonomous or partially autonomous power networks to ensure that an adequate amount of electricity is available to run critical equipment in the event of a loss of the utility grid. Load shedding is an important procedure whereby non-essential loads, such as cooling and air conditioning units, motors, furnaces, compressors, pumps, and lighting systems are shut down in a strategic manner in order to ensure that the facility's core processes remain running and costly downtime is avoided if there is a generation failure or disturbance either onsite or within the public utility grid. To achieve this, many operators today use separate independent systems, which shed load in accordance with a predefined priority list. However, because these systems are often deployed in addition to an energy automation system, they have their own hardware, wiring, and maintenance requirements, which lead to inefficiencies, overlap between equipment, and higher lifecycle costs.
This paper will discuss the advantages of embedding applications in existing substation automation infrastructure and combining energy automation and power management applications like load shedding and automatic generation control (AGC). Doing so enables facilities to achieve substantial cost savings and improve the reliability of their onsite power networks. A case study will be presented on a major crude oil pipeline, where the use of an integrated power management solution helped an operator reduce CAPEX and OPEX, improve critical process uptime, and enhance safety by allowing personnel to control systems remotely.
The paper will also discuss how enterprises can use integrated power management systems for operator training and grid simulation purposes.
Enhanced Oil Recovery in a High Stratigraphic Complex Reservoir: Casabe Project Case Study
Authors: Gheneim Thaer , Azancot Annalyn , Acosta Tito , Zapata Jose Francisco , Chaparro Carlos , Lobo Adriano , Jimenez Ana María , Perez Gerson 
Published: November 2017

Abstract
Casabe field reservoir characteristics are multilayer, geological complexity, vertical/areal heterogeneity and commingled production. Due large difference in mobility between oil and water (M ~ 20) and the maturity of water flooding, several operational problems have arisen, such as, increase of water cut, channeling, sand production, etc. These problems together with the high remaining reserves and identification of bypassed oil, were the main reasons to evaluate EOR process as a solution to increase the recovery factor.
A reduced Cycle Time was created to reduce the time from design to full field implementation which involves the following phases: Screening/Conceptual Design, Pilot Design, Drilling-Workover and Facilities, Operation & Surveillance, Pilot Expansion, Full Field Development Plan, Reserves & FID. This strategy is based on multitask parallel process to allow fast track decision making and activities execution for a fast pilot implementation, which allowed to implement the EOR pilot in 24 months form the screening to pilot Operation & Surveillance. After the screening, polymer flooding was considered for mobility ratio modification to improve sweep efficiency and therefore increase RF.
The best producer layers were selected, based on the areal continuity and residual oil in place, as target sands for polymer injection. One pattern was selected for the pilot. Laboratory tests, along with reservoir simulation confirmed the potential of chemical EOR in the selected sands and pilot area. Polymer injection was performed in four injector wells of the selected pattern. The polymer flooding process was monitored in the central producer and in the eight producers of the second line.
A surveillance plan was implemented to collect the information required to evaluate, with the lowest uncertainty, the results of this pilot. An observation well was drilled to monitored changes in oil saturation. The surveillance plan was critical to be able to control the polymer injection process, to have a proper technical evaluation of the pilot and to optimize costs during the future expansion and full field implementation. Polymer flooding have increased the RF on the selected area.
The fast-tracking strategy for an EOR project execution was successfully implemented in Casabe Field and the pilot was delivered in 2 years proving the concept of 5-year road map it is possible. The reduced Cycle Time (5-year Road Map) could be used as reference for implementation of new EOR pilots in other fields in shorter time and optimizing resources.
The workflows used and the analysis procedures created for this pilot could be used as reference for the implementation of future pilots in fields with similar characteristics.
Fast Integrated Reservoir Modelling on the Gjøa Field Offshore Norway
Authors: Sætrom Jon , Morell Eirk , Ravari Reza Rostami , Maitre Claire Le , Seldal Mailin 
Published: November 2017

Abstract
In this paper, we combine reservoir data; reservoir physics; machine learning algorithms; and the "know-how" of the subsurface team in one efficient workflow to quickly build reservoir models that lead to an improved understanding of the Gjøa field offshore Norway. Key elements of the solution include:
Consistent integration of static and dynamic data – when they arrive – in one automated and repeatable modelling process. Ability to address uncertainty in all parts of the modelling chain – from G&G data interpretation to flow simulation and dynamic data conditioning. Single platform for multidisciplinary collaboration between the subsurface disciplines in the modelling and reservoir management efforts. Scalability and robustness – the workflow is equally applicable for small and large reservoirs.
Additionally, we implement a prescriptive analytics solution to quickly identify and rank robust infill-well targets using data conditioned reservoir models as input.
The amount of data we collect from a reservoir is rapidly increasing. Hence, it is more important than ever to utilize tools that address the shortcomings of the traditional reservoir modelling approaches. Having the ability to capture the information found in the collected static and dynamic data in a consistent manner when they arrive, while embracing the inherent uncertainty of the reservoir modelling process, will lead to improved reservoir management decisions, and ultimately an increase in the recoverable volume.
An Integrated Workflow to Close Out the Uncertainties in a Geomechanical Model in a Giant Onshore Carbonate Gas Field in Abu Dhabi, UAE
Authors: Masoud Rashad , Noufal A. , Ateeq B. , Al Ammari K. , El Gohary M. , Al Hammadi H. , Kumar S. , de Joussineau G. , Bois A. 
Published: November 2017

Abstract
A giant lean gas reservoir overlying a large oil rim is producing for more than 27 years became under depletion mode without any pressure maintenance. Formation collapse in reservoirs under depletion can cause permeability reduction, completion damage and well failure, reducing or even interrupting production and affecting the ultimate recovery from the reservoir. It is therefore critical to predict any risk in formation collapse. If such risks exist, recommendations are required to optimize reservoir management.
Stress measurements were acquired and core analysis were performed in intact rocks area and used for 1D MEM (Mechanical Earth Model) and 3D MEM. 1D MEMs for 10 wells were constructed. Rock mechanical tests were conducted on core samples. 3D MEM was created with 13 interpreted seismic overburden horizons and 105 seismic faults. Four scenarios were performed to identify formation failure during the scheduled production. The worst-case scenario will happen of reservoir depletion, in case of weak formation and reactivated faults.
Intensive logging, fracture modelling, coring program across the main fault corridor and RMT (Rock Mechanics Tests) were performed in vertical and horizontal holes across the fault corridor area to fulfil gaps of rock mechanical properties (elastic properties and rock strength) and field stresses. The acquired data were seeds for Lab testing, fracture network analysis and fault characterization which used to update the 3D MEM.
Additional Lab tests to fill gaps in rock samples with high porosity (&gt; 30%) were carried out and 1D MEM of 5 more wells were constructed, and the 3D MEM were updated.
The 2017 updated 3D MEM eliminates three of the 2013 four scenarios and ended up with one robust scenario that shows better reservoir integrity and very small localized areas of pore collapse in high porosity regions only (&gt; 30%) compare to the previous model. The reservoir can produce under depletion mode with production optimization in areas of expected compaction. Well integrity study and compaction monitoring are also considered to be commentary studies.
Enhancing Well Interventions with the Use of Transient Software - New Case Histories from Around the World
Authors: Craig Steven , Aitken Bill , Livescu Silviu 
Published: November 2017

Abstract
Since the mid-1980s, advances in coiled tubing (CT) modelling software have enhanced operational efficiency, reduced technical risks, expanded the acceptable operating envelope and improved well intervention success rates. Until relatively recently, models were the steady-state type. Since 2010 dynamic modelling for CT operations has been utilized. This paper, focusing exclusively on transient modelling, incorporates unpublished novel case histories showing pre-job optimization and post-job investigations. The focus is on showing the simulation advantages of transient versus steady-state conditions.
The transient model predicts the changes over time resulting from varying pumped and produced fluid rates, varying fluid types, two-phase relationships, location of solids, location of the CT and the wellhead choke size. Equations for the conservation of mass and momentum and a unified drift-flux model, valid for all flow regimes, are included in the model. Based on experimental testing on a full-scale flow loop, a critical gas flow velocity model was developed. It has been validated against published case histories and results of other transient models primarily developed for pipeline operations.
Several case histories are presented, showing phenomena that cannot be captured by steady-state CT models. First, a review of two cases of post-job investigations are presented: a re-calculation considering multiple well pressures and fluid content changes, to confirm that the CT weight was accurately recorded prior to an operational incident; and a re-calculation of a solids cleanout operation where incorrect execution resulted in stuck CT. Second, a review of two cases of pre-job analysis includes the modelling the switching of a tool with respect to time instead of pressure (required because high nitrogen rates mask surface pressure indications of downhole changes); and the modelling of a complex situation where the client requested an optimized dewatering operation with only a small volume of nitrogen available. Finally, cases of optimizing solids cleanout removal with multiple changes in fluid rheology are reviewed.
Three prior papers (Salim and Li 2009; Salim et al. 2010; Li et al. 2012) regarding this transient model were focused on the model theory and gas lift optimizations. The practical cases presented in this paper are novel to CT transient modelling papers and provide operators with a greater understanding of the value that the transient modelling can provide to their operations.
Fit-For-Purpose Roller Cone Bit Technology to Improve Performance in Highly Interbedded Carbonates and Anhydrite Application in Southeast Kuwait
Authors: Beheiry Karim , Al Heiny Ahmed , Malik Abdullah , AL Mayyan Haitham 
Published: November 2017

Abstract
A 16-in. section of a well, located in the Great Burgan field of southeastern Kuwait, presents multiple drilling challenges. The section is approximately 4,000 to 5,000 ft long and is drilled through a highly interbedded formation that consists of carbonate, shale, and anhydrite. The carbonate typically generates impact damage, causing high levels of thermal degradation that affect the gauge inserts. In addition, lost circulation is a hazard commonly encountered during this application. The drilling of this section requires control of drilling parameters, specifically the flow rate. Failure to maintain sufficient flow rate results in poor cuttings transmission and insufficient cutting structure cooling that can create further performance complications.
The challenge in this application is to drill the entire section with one bit run at a maximum rate of penetration (ROP).
This paper describes a new tungsten carbide insert (TCI) drill bit design that helped to improve the drilling performance in this challenging section in different well profiles.
This paper provides a detailed study of the challenging 16-in. section in Kuwait and discusses potential issues, problems, and solutions associated with the use of the new advanced roller cone design.
Spheroid Life Extension: Contemporary Approach, Advanced Simulation and Case Study
Authors: Al Omari Ammar , Herzallah Osama , Toubar Ashraf , Awda Zakaria , Mubarak Nouf 
Published: November 2017

Abstract
The spherical shaped tanks/separators represent a common type of equipment in the Oil & Gas industry. The spherical shape is preferred due to the robustness that the geometry offers, in addition to the large fluid surface area that maximizes the gravity separation process. However, these convoluted shapes introduce difficulties in routine inspection and integrity assurance. This paper studies a fitness for service (FFS) assessment of complex damage mechanisms which include localized bottom bulge formation, local shell buckling and underside soil corrosion.
This research analyzes a case study of atmospheric Horton Spheroid separation tank with 20,000 barrel capacity, 20 m diameter and 15 m height. The analysis includes a design calculation review of the spheroid via Finite Element Analysis (FEA), API 620 (API 620 1962-2014) standard review from 1962 to 2014 and simulation of the steam desludging maintenance procedure. 3D nonlinear Finite Element model (FEM) was introduced to analyze the spheroid fitness for service under several bulgings and localized buckling. The FEA results were compared to inspection results to validate and confirm the bulging locations, bulging sizing and spheroid integrity.
The FEA model results showed that the vacuumed spheroid is subjected to inward bulge formation at the crown upper shell and lower bottom plates. Due to the non-uniform curvature of the spheroid, the bulge locations are difficult to be predicted, however, the FEA results were able to detect precisely the location and geometry of bulges. The plastic strain failure criterion was used to assess the fitness for service of the spheroid for continuous operation with the presence of those deformations. The FEA model results showed excellent agreement with internal inspection results and findings. The FEA model results were used to conduct semi-qualitative risk assessment on other identical spheroids; an endorsement extension was granted based on the semi-qualitative assessment.
New Approach Using Dual Porosity Dual Permeability and Dissolved Pore Network to Simulation Modeling for Fractured Carbonate Reservoir in Abu Dhabi
Authors: Uematsu H. , Auxiette G. , Bellah S. , Virlan V. , Stojic T. 
Published: November 2017

Abstract
In this paper, we present a case study of using dual porosity dual permeability (DPDP) simulation for an offshore Abu Dhabi carbonate oil reservoir exhibiting complex flow behavior through matrix, fracture system and conductive faults. The main objective of the study is to present and explain the reservoir flow behaviors by constructing and using advanced reservoir geologic and simulation models. The results of the study will be utilized as part of the inputs for full field development plan.
Initially, an extensive work on the faults and fractures characterization was conducted to properly integrate this information into a dynamic model using DPDP modeling approach. However, the poor response of some wells or field sectors indicated the insufficiency of this concept to capture the full complexity of the reservoir system. Consequently, a new geological concept was proposed to represent the effect of enhanced matrix permeability related to facies dissolution process in the reservoir model properties distribution.
To perform such model modification, an innovative new approach was developed called "Dissolved pore network" concept, linking matrix permeability to the fraction of matrix rock macro pores system inferred from the pore size distribution of MICP plug analysis. This "Dissolved pore network" concept was originally developed by Schlumberger in previous projects based on their worldwide experiences. The concept was successfully implemented in this study using an empirical equation to enhance the permeability of a certain category of facies affected by the dissolution process.
The study successfully demonstrated that the proposed geological concept integrating the dissolved pore network concept with the faults and fractures system in the reservoir modelling workflow allowed better understanding and representation of the reservoir complexity and the well flow behavior. This smart combination of the two distinct systems was never implemented in a similar manner in the oil industry. Therefore, we strongly believe that this successful implementation will pave the way for constructing more realistic reservoir models for a complex reservoir with multiple pore systems.