bluuebunny/crossref_metadata_2025_split huggingface dataset:
Overcoming Technical Assurance Challenges in Executing Parallel Mega Projects
Authors: Awda Hisham , Almadhoun Wael , Al-Shehhi Khaled Mohamed , Shahin Malik Mohamed , Kotey Anthony 
Published: November 2015

Abstract
The successful delivery of mega projects is a challenging terrain. ADMA-OPCO continues to face numerous challenges of providing technical assurance to multiple mega projects running in parallel while meeting not only short and medium term expansion goals, but also ensuring a sustainable long term future.
The objective of this paper is to share ADMA-OPCO’s experience and success factors in driving Technical Assurance during projects execution.
At ADMA OPCO, the Discipline Engineering Division (DED) acts as the center of technical expertise in support of all ADMA’s business activities and in particular, in the delivery of the ongoing complex project programs. The DED is part of the Projects and Engineering Business Unit, in a seamless integration with the multiple project teams. DED is a custodian of Technical Assurance,Providing engineering & subject matter experts (SME) expertise to projects,Participating in project reviews and witnessing selected functional and performance testsDeveloping and updating relevant engineering technical codes & standards and assuring their compliance in all ADMA-OPCO projectsBeing actively involved in the technical evaluation and selection external contractors,Reviewing and evaluating project changes through a Management of Change (MOC),Ensuring consistency across projects in terms of technical compliance,Being actively involved in all project phases from idea development to execution,Managing inter projects interface issues utilizing access to overall long term plansActing as an authority for novel technology selection and adoptionAssuring the continuous improvement of the technical skill set within the company.
At ADMA OPCO, the current organizational setup of an integrated technical assurance provider and project teams is a model that is proving to be successful when executing multiple parallel mega projects.
Challenges & Complexity of World's Largest Flares Reduction Project
Authors: Howell Christopher , Vincent Andy , Goel Deepak , Hilleshiem Andrew 
Published: November 2015

Abstract
700 million standard cubic feet of valuable natural gas are flared each day in South Iraq as a byproduct of the region's oil production. At the same time, residents of southern Iraq suffer from a significant lack of power and at times can have as little as only a couple of hours of electricity per day. Iraq is now the 4th largest gas flaring country in a world of increased environment consciousness and the greenhouse gas emissions from these flares are equivalent to Croatia's total emissions.
Basrah Gas Company (BGC), a joint venture between South Gas Company (51%), Shell (44%) and Mitsubishi (5%), is a midstream gas company that aims to capture associated gas from three supergiant oil fields in southern Iraq – Rumaila, West Qurna 1 and Zubair. BGC is processing gas into valuable products of condensate, LPG, and dry gas to be used for power generation to the domestic grid. Approximately 5,000 Iraqi employees are seconded into BGC; these are much needed jobs and a valuable opportunity to transfer skills and capabilities into the region.
In 2015, just two years after commencement of BGC operations, much learning has been gained and progress has been made on all themes on the journey to increase safety, production capacity and operational excellence. This includes: Installation of new compressor configurations and rental machines to quickly add compression capacity.Priority scoping to rehabilitate the gas plants.Urgent work to recover process safety systems and safe work practices.Forecasting and planning projects to stay connected to the upstream gas supply from new oil developments.Maturing alternate growth projects - including a new green field gas plant.Developing operations systems that will assure production and maintain integrity.
From these examples it is clear that executing the world's largest flares reduction project requires novel thinking and excellence in project management. Furthermore, overcoming the increased challenges specific to the region, impacted by decades of war and economic sanctions, has brought enriched learning for the company and beyond. These capabilities in project execution built on this early experience are a sound foundation for project delivery.
Innovation to Bring a Pivotal Gas Capturing Project to Iraq
Authors: Kock Arne de 
Published: November 2015

Abstract
The residents of Basrah, Iraq, suffer from a significant lack of power and at times can have as little as only a couple of hours of electricity per day. Utilising one of Iraq’s most abundant natural resources is a key value driver as Shell works closely with the Iraqi Government, the National Oil and Gas Company (SOC & SGC), and several other significant stakeholders, to deliver more gas to the domestic grid, faster than previously thought possible.
The Tigris First Commercial Production (FCP) Gas project scope involves gathering sweet associated gas produced from the Majnoon field, before sending it to a newly built 1.2 GW power station at North Rumaila. In addition to major improvements to the current energy infrastructure, impacted by decades of wars and sanctions, the project will reduce emissions associated with flaring by putting the gas to use.
Traditional methods for building a gas plant would not deliver on the needs of our major stakeholders - to have access to gas on the shortest possible timeline for local power. The project demanded a radical approach. An answer was found in a novel, fully modularised marine barge concept which had potential to deliver on the tight timeline required.
The final concept for Tigris (FCP Gas) involved building a fully modularised 140 MMSCFD gas plant with our partners, Solar in Houston. The plant was equipped with compression and dehydration capability. The system was built, tested and dismantled into smaller structures. In addition to a fully modularised gas plant, a fully-modular, six-finger slug catcher was manufactured in Kansas for installation at the power station in North Rumaila. All these modular pieces, assembled in two separate locations across the United States, had to be made for easy re-assembly and to fit within the space and payload restrictions of the Antonov aircraft. The Antonov made 40+ round trips between the U.S. and Iraq to transport all the equipment for final installation and commissioning.
Innovating to a novel, modularised concept that would be fabricated in America and airlifted to Iraq by multiple Antonov roundtrips, proved to be extremely successful and has allowed the team to work towards an achievable timeline, about half the original duration, to domestic gas delivery.
An Economic Approach to Horizontal Well Length Optimization
Authors: Dosunmu Idowu , Osisanya Samuel 
Published: November 2015

Abstract
Horizontal wells offer higher productivity when compared to vertical wells due to increased contact area with the reservoir. It is now accepted that an increase in well length is not proportional to higher productivity after a certain critical well length because of frictional pressure losses in the wellbore. As the well length increases, so does the frictional pressure loss. In most cases there is an optimal well length beyond which a productivity decline will occur. The purpose of this study is to present findings on horizontal well optimization taking into consideration frictional pressure loss effects with and without perforations in the wellbore. Several horizontal well productivity equations can be found in the literature. In this study a productivity equation based on an elliptical drainage area is assumed. Other assumptions include single-phase incompressible oil, isothermal condition, and homogeneous reservoir with directional change in permeability. Parametric studies were conducted to investigate the effects of pressure drawdown, wellbore diameter, horizontal permeability, formation anisotropy, and oil viscosity on well performance. A probabilistic economic approach based on net present value (NPV) is used to determine the optimal well length for a particular set of reservoir and well parameters that will be useful for planning and designing horizontal wells.
Results show the following: Horizontal well productivity is significantly affected by oil viscosity, horizontal permeability, and well diameter. Those parameters must be considered for the optimization of horizontal well length.Frictional pressure losses have a significant effect on the productivity of small diameter wellbores in high permeability formations containing relatively low viscous oil.Sensitivity analysis of economic parameters indicates that oil price had the greatest effect on NPV at a particular well length. Production taxes and operating costs ranked second and third, respectively, with negative effects on NPV.
Development of Tightly-Coupled Integrated Asset Model For Use in Production Optimization, De-Bottlenecking and Flow Assurance of Multiple Gas Reservoirs
Authors: Zadeh Seyamak Gholam , Barzanji Diyar , Brock Nigel , Ateeq Budour Omar , Bloch Gerard , Abu-Snaineh Adel 
Published: November 2015

Abstract
This paper presents the development of a tightly-coupled Integrated Asset Model (IAM) to capture the surface-subsurface interactions of 5 gas condensate reservoirs producing through a common surface facilities network. The objective of the exercise is to develop a tool that is built to combine existing compositional simulation models and the surface network model in a single platform/environment that could be used in production optimization, de-bottlenecking, field development and flow assurance.
The success criteria included providing a solution that can ensure: Adequate representation of the different fluids of the 5 reservoisFull adherence to existing network constraints and field development guidelinesProviding optimal network configuration based on the use of automatic production optimization procedures.Flexibility to add complex network elements and decision logic
The most powerful and unique feature that enabled all of the above was the effective use of procedures and built-in functions in Nexus that offer the capability to incorporate operational considerations into the solution.
The first step involved developing a common fluid components basis to be used for the surface and subsurface models. This was achieved through adopting a suitable lumping scheme that involved minimal adjustment to the existing equations of state (EOS) and no compromise of the fluid description or the quality of the history matches
Next step involved converting all the five reservoir models and their surface network model into the same simulation environment. The final step involved developing the procedures that carried out production optimization and proposed the optimal settings to fully utilize the available compression capacity.
Finally, the surface elements of the IAM were calibrated to the results of production capacity tests. The calibration involved matching the observed gas production rates, tubing head pressures and flowline pressures. This step is required to validate the constrained model performance and prediction.
The results showed the magnitude of interaction between the reservoirs and clearly identified the system bottlenecks. The model can be used to propose the best tie-in location of future wells in addition to providing first-pass flow assurance indications by highlighting elements of the network at risk of erosion throughout the field's life and under different network configurations.
Connected Destinies: Reducing Road Trauma in Basrah by Highlighting Family Bonds
Authors: Macklin Stephen 
Published: November 2015

Abstract
This paper describes the production of a seatbelt safety media campaign which is a joint initiative of Shell, Iraq and the Basrah Traffic Police Directorate. The media campaign enhances existing road safety initiatives in the Basrah Province of Iraq implemented in partnerships with government, non-government and multi-lateral agencies.
Inorganic Scale Challenges and their Mitigation in an Onshore Abu Dhabi Field
Authors: Abdallah Dalia , Elechi Collins , Graham Gordon , Simpson Caroline , Kidd Sam , Hoeth Laurien Wichers 
Published: November 2015

Abstract
Inorganic scale precipitation has been observed in an increasing number of wells in an onshore Abu Dhabi field. Mitigation strategies have historically concentrated on laboratory analysis of scale samples and design of remedial acid treatments in combination with mechanical methods to clean out the wellbore. To evaluate success, well accessibility and production improvement checks are made before and after the job. This reactive strategy has had mixed results, and the emphasis is now shifting towards use of preventative techniques especially with the increase in Water Alternate Gas (WAG) and Artificial Lift (AL) operations, increased water injection and produced water re-injection.
Detailed evaluation of the scale risk has been conducted via scale prediction modelling identifying that the major risk relates to calcium carbonate scale due to pressure reduction during production. In order to mitigate this risk, and to be able to minimise productivity losses and increasing costs associated with remediation treatments, the decision was made to evaluate the potential for scale prevention via downhole scale inhibitor application by squeeze treatments for naturally producing wells and by continuous injection for artificially lifted wells with Electrical Submersible Pump (ESP). Extensive 3rd party laboratory qualification of 8 different vendor recommended scale inhibitors for each application were carried out and the results will be presented in this paper. There were challenges faced during the testing of the scale inhibitors for squeeze application because the vendor supplied formulations had poor injectivity and led to formation damage during initial core flood tests. The 3rd party lab re formulated the vendor chemicals to minimise the potential for formation damage. Further core flood testing with the re formulated chemicals resulted in minimal formation damage while maintaining relatively long scale inhibitor squeeze return lifetimes. This work illustrates the importance of extensive chemical testing prior to field application to avoid any problems in the wells.
The laboratory qualified scale inhibitor chemicals are planned to be trialed in wells which have been identified with a carbonate scale risk based on historical data or on results from prediction models under particular production conditions. The ultimate goal is to have in place a robust inorganic scale mitigation strategy as part of the field development plan to minimise well intervention and increase well availability.
ADCO First Hydraulic Fracturing Campaign Strategy in Unconventional and Tight Migrated Oil Reservoirs from Planning, Designing to Execusion, Challenges and Mitigation
Authors: Hegazy Gehad M. , Noufal Abdel Wahab , Shedid Shedid A. 
Published: November 2015

Abstract
Unconventional reservoirs in North America showed excellent results through the late decade. Tight carbonate and source rocks in the UAE with very low clay content involve more comparative challenges. Evaluation and application of Fracturing technology on these reservoirs require accurate designing, planning and execution. These three phases are followed by a unique strategy for cost optimization especially when oil price drops.
To enable a detailed understanding of these formations and the applicable fracturing methodology, a complete study and strategic map is required. Unconventional reservoirs in North America have been studied extensively. The challenge is to adapt this technology locally to our tight reservoirs at ADCO-UAE. Creating a fracturing workflow and strategy that is applicable to the tight and unconventional formations in the UAE is the main target.
Fracturing technology evaluation of these reservoirs has their own set of challenges, ranging from creating valid geomechanical properties to building the Mechanical Earth Modeling (MEM) for successful execution. Screening of suitable candidates as sweet spots and unique data gathering under cost effective programs is presented in details. The first five wells' plan, design and execution are highlighted. Furthermore, the integration of fracturing steps and the lessons learned are elaborated in this paper.
The paper highlights complete evaluation of the fracturing process of tight carbonate reservoirs that reveals the unique challenge of developing these reservoirs from a Reservoir Quality point of view. Furthermore, the paper presents complete study, strategic map, screening, fracturing workflow, and strategy for several wells fractured.
Precipitating Carbonate Process for Post-Combustion CO2 Capture. Techno-Economic Evaluation
Authors: Davila Ytalo , Grigoriadou Katerina , Olfos Tomas , Schoon Lodi , Infantino Melina , Last Tim , Mitkidis Georgios , Martavaltzi Christina 
Published: November 2015

Abstract
Commercially available post-combustion CO2 capture technologies are based on aqueous amine solutions. One of the main cost drivers of such processes is the energy required for solvent regeneration. Most advanced technologies currently claim regeneration energies between 2.7 and 3.2 MJ/kg of CO2 for separation of CO2 from a Natural Gas Combined Cycle (NGCC) power plant flue gas. A system comprising a precipitating carbonate-based solvent has been claimed to have energy consumption well below 2.5MJ/kg of CO2. Here, the concept is evaluated to quantify its potential to bring down the cost of CO2 capture. A process model is developed based on correlation of available thermodynamic data to perform heat and material balances and to define the process operating window. Furthermore, experiments were carried out in a bench scale unit of 25kg/d (2.77x10−4 kg/s) CO2 capture capacity to demonstrate the integrated process concept. Finally, a techno-economic evaluation is performed based on the design of a commercial scale unit of one million tons per year (33.07 kg/s) CO2 capture capacity. The results indicate that the technology has not only higher energy requirements than originally claimed, but also higher capital cost than state of the art amine based systems. Thus, it is decided to stop further development of the technology.
Bending Rules with High Build Rate RSS
Authors: Tipu Imran , Alawadhi Eman , Kumar R. , Amanov Batyr , El Gebaly Mohamed A. , Al-Hammadi A. M. , Shamlan A. M. , Danche Ali M. , Ganda Sukesh , Dua Rajan , Hariri Nour 
Published: November 2015

Abstract
The introduction of a high build rate rotary steerable system (HRSS) capable of delivering in excess of 18°/100 ft DLS resulted in the expectation that this will lead to drilling more wells with higher DLS with RSS. While this paper is not to explore this expectation, it is obvious that this rotary steerable system (RSS) has been used by E&P Operators in the Middle East Region for so many different applications within the operating window of the other existing RSS system. This paper aims to explore in details the unique and ingenious applications, benefits and value of these HRSS systems to the clients in the UAE in terms of optimizing costs and improving drilling efficiency.
The traditional method of utilizing a motor for kick-off, sidetrack and exit whipstock was challenged and the broadened operating limits of HRSS were utilized to its full potential to find ingenious ways to perform such operation. The major benefits from these applications are a result of the ability to overcome challenging drilling environments or operational requirements. 22 jobs have been completed in the UAE from Q1, 2012 to date using the HRSS with 100% success rate across the range of applications described below:- Dogleg severity assurance in complex 3D trajectories or through incompetent formations.Kick-off from vertical in various formations with different comprehensive strengths.Cement plugs sidetrack from vertical and shoe to shoe drill ahead to section TD.Sidetrack from whipstock with15 ft rat hole and shoe to shoe drilling with full suite of logging tools.
The increasing demand for this service and creation of a niche, even in the current environment of demanding cost optimization and value based technology, the application of this technology has led to an estimated saving in excess of 40 days. The non-tangible benefits include better hole cleaning and smoother wellbores leading to less wellbore tortuosity and improved ability trip post drilling with drilling, logging and casing assemblies. The asset teams are not left out as the near bit measurements in theses assemblies also aid in reduction of the uncertainties and enable better decision making, especially while landing the well or at TD point selection.
The applications of HRSS described in the paper are innovative applications designed through immaculate planning and risk mitigation. As a result of which significant achievements in cost optimization and drilling efficiency enhancement have been realized.
The Road to Digital Asset Reality
Authors: Elnaggar Basem , Farshoukh Ahmad , Almadhoun Wael , Al-Amry Mohamed 
Published: November 2015

Abstract
As-built engineering information is mission critical to safe, reliable operations. Due to inevitable modifications throughout an asset's life, the quality and availability of as-built information erodes over time and is no longer indicative of the actual as-operated facility. This paper highlights the new technology, methods and processes in as-built campaigns. Also, it explains why it is necessary to move from a document-centric to data­ centric approach in engineering information management.
Abu Dhabi Marine Operating Company (ADMA-OPCO) as-built approach is illustrated utilizing laser scanning technology, consolidating the legacy engineering information combined with site survey data capture to build intelligent databases, 3D models and 2D engineering deliverables. ADMA-OPCO leverages these data silos into an ElMS (Engineering information Management System) to provide a single source of organized and interlinked as-built asset Information. ADMA-OPCO implemented procedures for quality assurance through data completeness, consistency across various sources, reporting and solving the issues impacting information integrity and reliability.
Having a digital asset throughout the life cycle of an operating plant creates a sound basis for asset modifications, reduces the need of site visits for data collection and site surveys, minimizes the exposure of engineering personnel to potentially hazardous environments and provides quick and high quality input for decision making. The paper reveals the limitations of a document centric approach to management of asset information and explains how rigid, non-integrated information databases lead to data silos and the impact on the as-built information quality, resource productivity and operational safety.
This paper raises awareness of the benefits of utilizing the digital asset to gain instant access to asset engineering objects and their associated references. The digital asset can be used to support effective decision making and ensure data is centralized, accurate, change-controlled and highly accessible in the context of the processes it supports.