bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Computational Model for Simulating Proppant Transport in Wellbore and Fractures for Unconventional Treatments
Authors: Wu Hongfei , Madasu Srinath , Lin Avi 
Published: December 2014

Abstract
This paper presents a new and comprehensive model for proppant transport that is applicable inside both the wellbore and the fracture, along with an appropriate fast computational algorithm. This model can be used efficiently in both real-time and design modes of hydraulic fracturing processes.
The spatio-temporal proppant evolution is crucial in hydraulic fracturing processes as it directly affects production during shut-in and flowback. Yet, the computational cost is quite high because of multidimensional multiphase flow models, while most of the numerical approximations, such as the standard Galerkin finite element, are limited in their validity, prohibiting the numerical models from properly modeling the proppant dynamics correctly and practically.
This paper discusses a new one-dimensional (1D) two-phase flow model that accounts for the leading two-dimensional (2D) effects, such as proppant settling, resuspension, and bed transport, among others. Accounting for these effects helps ensure the conservation of momentum and mass conservation for the fluid flow for the proppant as well as for the proppant bed transport. The momentum conservation equations embed the interphase momentum transfer between the fluid and the solid phases, the momentum changes caused by proppant settling and resuspension, and the momentum exchange associated with the shear on the dynamic built-up proppant bed. This is accompanied by the mass conservations equations to include the fluid and the proppant mass flux induced by the settling and resuspension.
This computational model simulates proppant transport by using a first-order implicit scheme in time and first-order upwind scheme in space for the convection over a collocated grid for flow variables. The simulations demonstrate that the proppant bed is gradually formed and expanded downstream. These simulations also show that the formation of the proppant bed is caused mainly by proppant settling, and height change is determined by interactions among proppant settling and its resuspension during transport. Also, it is shown that the proppant properties strongly affect slurry transport and proppant bed dynamics.
The general results provide insight into the different mechanisms of the transport process, including gravitational settling and resuspension of proppant and proppant bed buildup and transport inside both the wellbore and fractures. This model provides a more pragmatic approach that enables field engineers to gain better insight into the proppant transport phenomena during a fracturing treatment.
Surface Safety System Enhances Gas Lift Safety and Optimizes Surface Line Architecture on Island Wells
Authors: Newton Daniel , Odom William , Burchell Graham , Kofoed Curtis , Harestad Kristian 
Published: December 2014

Abstract
The construction of drilling and production facilities for gas lift production and injection wells on artificial Islands provides a significant exposure to risk due to SIMOPS. Specifically, simultaneous drilling operations results in rig skidding operations over/near to live well cellars and production line trenches. This increases the risk of venting significant lift gas volumes to atmosphere in a manned area through dropped objects or other failures.
The authors describe a Lift Gas Safety System (LGSS) to be implemented that will prevent venting lift gas during both a dropped object and other unplanned incidents leading to loss of integrity (e.g. ESD). The system also provides benefits through improved annular pressure monitoring (APM) and confining barriers within the wellhead. Outlined is the implementation process by which the system was selected and which subsequently led to optimization of surface facilities from the well cellars through to the production manifold.
Integrity Management; Piloting of Gas-lift System in a Super Giant Field is building an accurate block in the development of effective strategy for well integrity management
Authors: Fahim Mohamed , Abdallah Dalia , Al Shemaili Sultan , Al Selaiti Iman Hamad , El Moghrabi Mohamed , Syed Aamir Aziz , Al-Kindi Zaid 
Published: December 2014

Abstract
In a super-giant field onshore Abu Dhabi; the production strategy is to maintain the sustainable capacity but due to increase in water production the need of artificial lift is mandatory to maintain the production plateau. However, accurate well integrity management in such field is critical due to fluid characterization, souring environment and field extension (35 X 20 Km).The selection of the artificial lift technique plays an important role in improving the ultimate recovery. However managing the integrity of the artificial lift wells is more challenging under the presence of H2S, CO2 and high P & T. The loss of production caused by integrity related issues and the need to determine specifications and accurate future integrity management plan lead to need for a gas lift pilot. For the future it is envisaged that integrity assurance plans needs to be an integral part of the field-development planning, ensuring that asset value is maximized.
More challenges will exist when dealing with Gas Lift as it is a long term artificial lift technique affecting well design for long life completion. Therefore, Gas lift was piloted to better understand real integrity challenges and measure corrosion trends with time to gain operational and technical experience and to compare them with initial theories.
The pilot was monitored closely with intensive program. An optimization process was followed, assisted by modelling. Although the initial thought that the corrosion might affect the top part of the completions because of the injected gas specification, but the time-laps corrosion logs gave a completely different and unexpected picture. The pilot results enabled the overall project to be concluded; the lessons learnt from the pilot were captured and used as building block for the full-field development options.
The paper describes the pilot results, the integrity challenges and the contoured problems, the philosophy of monitoring the corrosion evolution, the findings and how it was different from the initial expectation. Finally the clear impact on the integrity management process to ensure proper long-life well design and completion strategy.
Breakthrough in Field Development Planning of a Complex Reservoir by Designing and Drilling Highly deviated Wells Using Integrated 3D Geomechanics.
Authors: Azim Shaikh Abdul , Al-Awadi Abullah , Hussain T. , Al-Blayyes Mariam , Al-Anezi Salah , Al-Saad Bader A. , Imtiaz Saad , Shinde Ashok , Perumalla Satya 
Published: December 2014

Abstract
Zubair Formation is the deepest producing Cretaceous reservoir in North Kuwait. This 1,400 ft thick formation was deposited in deltaic to paralic depositional environment with complex sand/shale sequence, structural geometry, mineralogical composition and lateral extent. Drilling wells of any profile has witnessed high non-productive time due to severe wellbore instability issues in the form of stuck pipes, tight holes, hole pack-offs and jarring/fishing operations. So, a number of vertical wells were drilled to drain the reservoir– an economic challenge. Current strategic goal in this matured reservoir is to exploit multiple but thin pays by maximizing reservoir contact with high angle multi-lateral wells.
An integrated 3D Geomechanics study was carried out in two phases. In the first phase, responsible failure mechanisms for wellbore instability were identified: stress induced breakouts, washouts and cavings, failure and fluid invasion associated with shale bedding planes at high deviation and osmotic pressure transmission between Zubair shales and drilling fluid system. Water sensitivity of clays and presence of micro-fractures were also studied on cores of this trouble making formation. In the second phase, calibrated well based 1D Geomechanical models; 3D structural model with high definition faults, facies models indicating lithological changes and drilling experience of latest high angle wells were integrated into a 3D Geomechanical model. The 3D model was tested with data from several offset wells and it was capable of explaining the wellbore failure of these wells. This 3D geomechanical model also helped in predicting mud weight window for any proposed high angle well trajectories.
Mitigation measures from the study included drilling with Oil Based Mud or High performance water based mud systems with model derived mud weights, micronized sealing polymer to seal-off the laminations and micro-fractures, marble grade Calcium carbonate or resilient graphite to plug wider fractures and high salinity of mud to avoid time-sensitive osmotic flow.
After implementing these recommendations, six horizontal wells have been drilled successfully. The study has given further confidence to implement an aggressive field development plan for optimal depletion.
The paper discusses complex reservoir architecture, drilling complications and how the integrated study helped to achieve a breakthrough in development planning.
Nodal Analysis for a Transient Production System—Principles and Application
Authors: Zhou Wentao , Banerjee Raj , Proano Eduardo 
Published: December 2014

Abstract
Nodal analysis is the standard technique used to evaluate the performance of integrated production systems. Two curves represent the capacities of the inflow and of the outflow, and the intersection of the two curves gives the solution operating point. Limitations of traditional nodal analysis include that results are offered only at a snapshot, not as a function of timeinflow performance relationship (IPR) models are limited, with none available for shale gas wellsanalysis is performed on a well-by-well basis, with no account of multiwell interference.
We propose a new nodal-analysis method that enables the study of transient production systems in a multiwell context and at different timesteps, with IPR models generated from a high-speed semianalytical reservoir simulator and outflow curves output from a steady-state pipeline simulator. The use of analytical reservoir simulation allows accurate, reliable modeling of the real inflow system, including deepwater and unconventional wells. The new approach studies the time-lapse behavior of the system, with consideration of production history and neighboring well interference.
This new method enables the study of transient deliverability at the wellhead, where the measurement is usually available, and shows the time-lapse relationship between wellhead pressure and production rate. We provide examples of wellhead deliverability and choke management and explain advantages of the method with case studies involving tight and shale wells. The method is also applied to design and optimize artificial lift in unconventional wells and to study the method's validity over time. In addition, we discuss an example of operational well dynamics using time-lapse nodal analysis.
Additionally, this new method generates discussion about some concepts that are often taken for granted. For example, what should be the definition of IPR in a transient production system? On the IPR curve, is the zero-rate pressure the reservoir pressure? Can IPR curves at two different timesteps cross each other? Finding the answers to these questions will help us better understand production systems.
The commonly used productivity index (PI) method is reviewed and compared with the new method. Results show that the PI method should not be used when well operational conditions change.
Field Development Plan (FDP) Optimization of a Giant Field for Plateau Extension and Recovery Improvement
Authors: Azoug Youcef , Patel Harshad 
Published: December 2014

Abstract
This paper discusses a revised field development plan (FDP) of a giant complex carbonate reservoir located offshore Abu Dhabi which has been producing for more than 30 years. In recent years the target production of the field was raised. However, the target production plateau length and recovery factor remained high. This ambitious vision created a new environment and new challenges for field development.
Previous work has included a number of innovations (1,2,3): Implementation of a line drive pattern requiring a substantial drilling programIntroducing drilling from artificial islandsDrilling long extended reach (ERD) and Maximum Reservoir Contact (MRC) wellsIntroducing inflow control devices (ICDs) to maximize sweep and recovery, including advanced completion design workflowsIntroducing workflows to maintain evergreen simulation models
The paper describes the current work to optimize the development plan to extend the production plateau by many years and improve recovery. Detailed sector models have been used to facilitate the large number of required simulation runs. Sector models ran more quickly and provided the opportunity to test many development options and scenarios. This technique allowed focus on specific regions of the field, to improve their development scheme, before moving to other regions in a sequential manner. The findings from those sector models were then incorporated in the full field model (FFM).
In this paper we present the method used to optimize the plan by sector: Optimize well spacing and configuration, focusing on the advantages of infill drilling for improved aerial/vertical sweep efficiencyOptimize drilling timing for infill wellsOptimize vertical well placementOptimize injection strategy
An optimized field development plan is proposed where the desired production rate and plateau length are met while recovery is improved. The optimized solution involves a proposed infill drilling strategy and corresponding injection strategy. The injection strategy includes optimization of the future target reservoir pressure to achieve the best field performance.
Optimizing Waterflood Management in a Giant UAE Carbonate Oil Field Using Simulation-Based Streamlines
Authors: Khan Sameer , Al Zaabi Noura , Jani Zankar , Tariq Syed , Tee Aaron 
Published: December 2014

Abstract
Streamlines have been acknowledged as a powerful tool for modeling and optimizing waterfloods in oil reservoirs. Streamlines provide visualization of reservoir fluid flow and a unique way to conceptualize and quantify injector-producer well connectivity. Well allocation factors (WAFs) between injectors and producers as well as injection efficiency can be calculated and used to optimize water injection and reduce injection water cycling while focusing on maximizing oil recovery. The objective of this study was to develop a methodology, tool, and workflow for optimizing pattern waterflood management and to demonstrate application in a giant offshore carbonate reservoir. This methodology utilizes history-matched simulation models to generate streamlines from the pressure field and fluxes computed by a finite-difference reservoir simulator, EMpower. A finite-difference simulator is more rigorous than streamline simulators in terms of its ability to model complex fluid flow, and therefore, provides a more realistic solution. The streamlines thus obtained take into account the detailed geology, well locations, phase behavior, and flow behavior of the history-matched models. This methodology utilizes the concept of pair "injection efficiency" (IE) and pair "voidage replacement ratio" (VRR) which was necessary for the subject giant oil field and is equally applicable to other fields.
The optimization process is started by generating streamlines and associated WAFs at the current time using the simulation model. The injection efficiency is calculated and injector-producer well pairs are identified with high and low IE. New producer rates are then calculated by increasing producer rates in high IE well pairs and decreasing rates in low IE well pairs based on a weight factor. The injector rates are then calculated by applying a target VRR to each individual well pair. This results in redistribution of injection and production rates in a more balanced/optimal manner. The process is repeated at regular intervals (e.g., yearly or quarterly) while simulation is run in the prediction mode. Results show higher total oil production rates or lower water production and water injection rates. The WOR versus cumulative oil production clearly demonstrates that the overall injection efficiency increases as the optimization process is progressed.
Mature Field Rejuvenation Through 4D Seismic Application: Experience From Study To Execution
Authors: Ferdinandi Fabrizio , Cozzi Mauro , Di Giorgio Christian , Pirera Francesca , Rizzetto Catia , Onwubolu Godwin 
Published: December 2014

Abstract
Time-lapse or 4D methodology, that uses repeated 3D seismic surveys to monitor fluids saturations changes in reservoir, is a recommended tool for reservoir management in particular in deepwater fields where additional investments must be carefully evaluated due to the associated costs.
This paper presents a real case of a successful rejuvenation project of a deepwater field in West Africa, supported by integrated 4D and reservoir 3D studies. The field, located in 800 m of water depth, has been producing for 10 years with a rate currently equal to the half of the FPSO nameplate capacity. In 2010 a seismic acquisition specifically designed for 4D purposes was executed and, integrated with the historical production data, led to a revision of the levels’ potentiality. Reservoir barriers and fluids movements, water and gas in particular generated by the injection, have been modeled based on 4D acoustic impedance differences and were supported by history matching on the dynamic model. The strongly integrated approach supported a volumes in place revision that drove a sidetrack campaign on two wells to reach undrained areas. The integrated study highlighted also the possible risk of water encroachment on one of the targets of the two wells, that was therefore considered as a secondary target in the sidetrack plan. The result of the drilling campaign, combined with near field exploration, confirmed the expectations and contributed to double the production back to the initial peak plateau rate. Lesson learnt on this successful integration among disciplines are presented.
Fracture Optimization Applying a Novel Traceable Proppant and a Refined Mechanical Earth Model in the Congo Onshore
Authors: Martocchia Francesco , Perfetto Raffaele , Saldungaray Pedro 
Published: December 2014

Abstract
Fracture stimulation has been adopted as an integral part of the completion in the "M" field given the results achieved in enhancing well productivity, as well as the positive impact realized on field development economics. The fracturing process has been optimized over the years through improved reservoir understanding and ensuing implementation of technologies to address the uncovered challenges. Changes to the fracturing fluid formulation to prevent damaging the water sensitive reservoir rock, as well as modified proppant schedules to mitigate proppant embedment are examples of this improvement process.
This paper describes the successful ongoing process of optimizing hydraulic fracturing designs in "M" field. By applying an integrated approach combining various technologies, it was possible to better understand fracture propagation and coverage of the target reservoir. Implementation of a novel non-radioactive traceable proppant allowed accurate frac height measurement at the wellbore. When combined with rocks mechanics derived from sonic logs it led to redefining the mechanical earth model and ultimately the completion and fracturing strategy in the field. The process will be illustrated with examples from a 3-well campaign recently executed onshore Congo.
Solving the Dilemma - Life Saving Appliances in Oil & Gas Industry
Authors: El Sanabary Mohamed Awad 
Published: December 2014

Abstract
The purpose of this document is to provide Oil and Gas Offshore Companies with guideline or Code of Practice for Evacuation, Escape and Rescue and Life Saving Appliances at Offshore Installations in general with some added focus on Lifeboats that can be expressed as Totally Enclosed Motor Propelled Survival Crafts (TEMPSC).
Lifeboats have been involved in a number of serious/fatal incidents during maintenance, operations, testing, and training including drills/exercises; e.g. Offshore Drilling Rig AD22 working Saudi Arabia in 2009 - when the lifeboat has inadvertently fallen into the sea with personnel inside.
This document is not covering the Mobile Offshore Drilling Units (Drilling Rigs/Barges) as they are covered under different legislation which is the Code for The Construction and Equipment of Offshore Drilling Units.
Same applies for all other types of Marine Vessels as they shall comply with the latest requirements of the International Maritime Organization (IMO) and Convention of SAFETY OF LIFE AT SEA (SOLAS) taking into consideration any grace period for any new requirements.
Fully-Coupled Surface Network Model with Stacked Multi-Reservoir Model of a New Abu Dhabi Offshore Field
Authors: Marir Boualem , Allouti Abdelkader , Cobb David O. , Bedewi Mahmoud 
Published: December 2014

Abstract
A new field in offshore Abu Dhabi is currently being developed by ADMA-OPCO by combining the production from six distinct carbonate reservoirs, each of which has different characteristics. The production and injection streams from all the reservoirs will be mixed and processed using common surface facilities (Offshore Super Complex).
The development scheme was optimized based on the integration of the available geological, seismic, petrophysical, and dynamic reservoir data into six separate reservoir models. The optimized development plan was defined for each reservoir using its corresponding individual simulation model, where all reservoir models are compositional with similar pseudo-components.
Because the field will be developed as a gas self-sufficient field with no gas export line, all the produced gas from the six reservoirs has to be managed within the field. After removing the fuel gas, part of the total produced gas is used for gas lift; whereas, the remaining gas is compressed and re-injected into reservoirs D, F, and G to ensure full gas balance.
The facilities are shared by all reservoirs, so to further enhance field-development optimization modeling, especially with gas-recycling requirements, an integrated, multi-reservoir model with surface network was constructed. In this model, the six reservoirs were fully coupled with a single surface network, including wellhead towers, production/injection pipelines, and the Super Complex layout. This was accomplished by using a next-generation simulator that allows both surface and subsurface equations to be solved simultaneously.
This paper addresses the steps followed and the challenges encountered and then summarizes the main outcomes. In addition, it provides a comparison with the results obtained from the single-reservoir models when run individually.
The results obtained from the integrated model were slightly different when compared to those of the individual models because of the newly developed surface EOS model and the impact of the network on the individual reservoir's performance. The integrated reservoir model (IRM) proved its advantages, especially for gas recycling, by eliminating the previous iterative runs performed to achieve the field gas balance and by its ability to make the most effective usage of both water and gas plans to maximize recovery.