bluuebunny/crossref_metadata_2025_split huggingface dataset:
Electric Properties and Its Effect on Microporosity Rocks
Authors: Sbiga Hassan 
Published: May 2012

Abstract
This study has been undertaken in three oil fields (A-Libya, B-Libya, and C-Libya) in sirte basin located in Libya. Nubian sandstone Formation is the main reservoir in the studied oil fields. Laboratory measurements methods were applied on the core samples that were selected from three different fields of Nubian Sandstone. Some of these measurements were conducted in Libyan Petroleum Institute (LPI Tripoli-Libya) laboratories in order to determine the resistivity parameters of the central graben reservoir cores and to investigate the effect of rock hetrogeneity and wettability on the resistivity parameters of Nubian sandstone reservoir rocks. The pore size distribution was estimated from generated capillary pressure curves. The samples belonged to Nubian sandstone, Sirt basin were selected to perform formation resistivity factor measurements.
The Pore size distribution and type of pores were calculated from mercury injection capillary pressure data. The results indicated that changes had been observed in formation resistivity factor and cementation exponent when overburden pressure was applied (slightly increases in cementation exponent with increasing O.B.P).Wettability played an important role in determining the fluid movement, distribution and electrical conduction during desaturation processes. Resistivity index effect has been observed after wettability measurement showing oil-wet tendency.
From the results obtained, a good relation between resistivity and type of pores (macro and micro pore system) was observed. When oil begins to penetrate micro-pore systems during the measurements, a significant change in slope of the resistivity index relationship occurs.
Productivity Index Change as a Result of Reservoir Compressibility
Authors: Anisimov Leonid 
Published: May 2012

Abstract
Variability in formation pressure during drilling, well tests, injection operations, oil and gas recovery are accompanied by changes in rock permeability and consequent changes in well productivity, oil recovery factor, and land subsidence. A number of laboratory experiments have demonstrated that decreasing the rock permeability may be defined as relative permeability in connection with fluid replacement in rocks. Other experiments have demonstrated the same results by increasing grain-to-grain stress for the clastic rocks and fracture closing for the fractured carbonate reservoirs. Assessment of these factors can be based on the relationship between well production and well bore pressure drop, and this interaction can be demonstrated by the results of test operations and production history. In order to segregate these processes, it is necessary to study a reservoir and fluids as an inclusive system. The rate of compaction in the different parts of a reservoir depends on hydrocarbon extraction and maintenance of reservoir pressure that can be changed through injection of water or gas. Phase transition in the fluid system can also depend on formation pressure. Reservoir compaction provides the additional drive energy for production, whereas decrease in permeability deteriorates the condition of field development. These effects can be considered for both low and high permeability reservoirs.
Precision for Bigger Diameters: The World's First 4 Tube Coriolis Mass Flowmeter
Authors: Nuber Michael , Huber Christof , Rieder Alfred , Anklin Martin , Drahm Wolfgang , Braun Marcel 
Published: May 2012

Abstract
The introduction of the Coriolis mass flow measuring principle was a milestone in instrumentation. By offering the most accurate direct mass flow measurement in situ, combined with the possibility of measuring density at the same time, it enabled customers in a variety of industries to profit from the most convenient metering even in challenging applications, where other measurement principles reached their limits.
Alas the geometrical designs of the meters on the market seemed to have reached a natural barrier at 12" pipe diameters. However, the higher the masses flowing through the pipelines, the more important the lowest error of measurement possible becomes. In hydrocarbon measurement this is apparent.
The paper presents the world's first commercial Coriolis mass flow meter with 4 tubes. The working principle is explained and the geometrical and physical advantages of the 4-tube design compared to existing 2-tube designs are highlighted. The paper also reflects on the mechanical construction of Coriolis mass flow meters in general and highlights the importance of a sophisticated mechanical concept.
Enhancing Production Allocation in Intelligent Wells via Application of Models and Real-Time Surveillance Data
Authors: Wu Xingru , Humphrey Kathryn , Liao Tony T. 
Published: May 2012

AbstractThe accuracy and precision of well rates are paramount in reservoir management, well performance surveillance, flow assurance, and any third party processing arrangements. Rate allocation is traditionally based on well rate tests and downtime. This method is usually time-consuming and thus performed relatively infrequently. This could be inadequate for proactive asset management especially with wells that may produce in transient state.This paper discusses methodology to improve well rate allocation quality and save engineering time. In practice, many fields face some or all of the following challenges that are related to well rate allocation: 1) reservoir communication, 2) well interference, 3) changing skin factors or other near wellbore boundaries, 4) uncertainties around reservoir fluid properties, and 5) difficulty in obtaining well rate tests for a variety of reasons. For many intelligent wells, it is a common practice to install permanent downhole gauges which are playing critical roles in field management. This paper describes a framework on how to capitalize on the real time data from well pressure and temperature sensors and use the data in Integrated Asset Modeling (IAM) to allocate the well rate with enhanced accuracy, increased frequency, and reduced processing time.The paper uses Atlantis in Gulf of Mexico as an example to demonstrate this process. The real-time data supported model based allocation process becomes virtual flow meters for the intelligent wells. For Atlantis, field-wide allocation accuracy has been improved from previously +/− 10% error using the traditional allocation method based on well rate test and downtime method to current +/−3% error using the new method. This paper also shows model maintenance is a journey that needs strenuous attention especially after water injections commences and more production wells come online.
Managing Uncertainty of Reservoir Heterogeneity and Optimizing Acid Placement in Thick Carbonate Reservoirs
Authors: Retnanto Albertus , Lynn Curtis , Orellana Edin 
Published: May 2012

AbstractEffective stimulation of thick, layered carbonate reservoirs is required to reach production targets for present and future demand. It is common that the completed intervals intersect several layered reservoirs, commingle multiple zones, and extend hundreds to more than a thousand feet in length. Even with the best petrophysical measurement and interpretation available in the industry, the key formation parameters considered in acid stimulation are still clouded by uncertainty. Several matrix acidizing techniques have been applied to stimulate these types of reservoirs based on the knowledge of petrophysical data. This paper strives to outline some of the key pitfalls that can occur due to the uncertainty in this data. Using reservoir simulations, the long term adverse impact of these pitfalls on both production and overall recovery can be shown.A new acid diverter, based on degradable fiber and visco-elastic surfactant technologies, has been applied, along with a placement model, to optimize treatment design and to maximize diversion in heterogeneous carbonate reservoirs. The system is robust, diverting from high permeability streaks, fissures and natural fractures with very little diverting effect from the low permeability zones, and therefore generates a more uniform stimulation than conventional fluid systems. This approach has been used to optimize various stimulation campaigns on carbonate fields throughout the Middle East.Maximizing treatment fluid coverage across the entire intervals can be achieved across thick, even naturally fractured, carbonate intervals using degradable fiber technology within a visco-elastic surfactant fluid. The diversion technique does not overly rely on certainty in petrophysical data, such as permeability and porosity, and can be successful in a variety of potential scenarios.
Integrated Production System Modeling of the Bahrain Field
Authors: Pothapragada Vijay , Al Kooheji Hamza , Al Hajri Said , Siyabi Ibrahim 
Published: May 2012

Abstract
The Bahrain Field, located onshore Bahrain, consists of multiple producing oil and gas reservoirs. The oil zones have been developed with approximately 1,040 wells flowing into 16 well manifolds and 6 tank batteries. Approximately 3,000 more wells could potentially be drilled in the future. The Khuff gas reservoir has an independent gathering network and has been developed with 45 wells.
Two separate integrated production system models have been built, one each for oil and gas. This paper describes how these models were built, the challenges in maintaining and calibrating these models and the value creation. Both models are used for day-to-day production management under various system constraints and also for long term field development planning.
The oil model has changed how well and system analysis is performed in the asset, as operational and development decisions are being implemented based on the model recommendations. The results are very encouraging, allowing more visibility and credibility for the model's use across various engineering disciplines.
The gas model, although relatively simple compared to the oil model, is the key tool used for optimization and development planning of the Khuff surface network. This model is used to calculate the capacity of the system, helping to ensure that demand requirements are met. The integrated gas model of the Khuff reservoir, wells, gas dehydration units and transmission system is currently being used for studying various long-term field development scenarios to identify the most cost effective way forward.
The concept of integrated production system modeling is gaining ground in the oil and gas industry. This work reiterates that this concept can be applied at any scale from large to small fields, while reaping significant benefits during the life of the field.
Comparison between Conventional and Intelligent Wells with Reactive and Proactive Controls under Economic Uncertainty
Authors: Sampaio M. A. , Barreto C. E. , Schiozer D. J. 
Published: May 2012

Abstract
The exploitation of an oil field in deep water presents many challenges related to high water production, high cost of frequent well interventions and many uncertainties. One of the technologies available, which can overcome these problems, is the use of intelligent wells (IW), which are capable of reducing water production rates, to avoid intervention in the well and to add operational flexibility to mitigate risk. However, the real benefits of this technology are not always clear due to the lack of a consolidated methodology in the literature. Moreover, there are also two main ways of controlling valves, i.e., reactive and proactive controls, making it necessary to better understand them to extract advantages and disadvantages from each one. Therefore, the objective of this work is the comparison between conventional wells (CW) and IW, using reactive and proactive controls. The first control is simpler to be used and quicker to be optimized but the second type can be more profitable, although more difficult to optimize. The optimization method used to solve the problem is an evolutionary algorithm, which is coupled to a commercial simulator to search for the maximum net present value (NPV), based on the ‘shut in’ water cut to determine the optimum time in which to close each valve and the well, in all types of controls. This work employs a model using an inverted five-spot configuration of wells to represent a part of a reservoir under a waterflooding recovery method. Some case studies are used considering different reservoir heterogeneities, type of oil and under economic uncertainty. The conclusion shows that IWs are able to increase production time, oil recovery and the NPV; as a consequence total water production is also increased. The results also show higher benefits in cases with more heterogeneity and light oil. Moreover, IWs using proactive control is better than IWs with reactive control and using either of them is better than CWs.
Safety Mangement in Oil & Gas Industry - The How's and the Why's
Authors: Rizwan M.. , Al-Marri H.. 
Published: May 2012

Abstract
Operation management in complex process plants such as major hazard facilities are regularly called upon to make decisions that balance the production and safety requirements of their organization. The process-based rules commonly used in manufacturing and process industries are permit to work systems, risk assessment and job safety analysis.
Job Hazard Analysis or Risk Assessment is a safety management tool in which the risks or hazards of a specific job in the workplace are identified, and then measures to eliminate or control on those hazards are determined and implemented. More specifically, a job safety analysis is a process of systematically evaluating certain jobs, tasks, processes or procedures and eliminating or reducing the risks or hazards to as low as reasonably practical (ALARP) in order to protect workers from injury or illness. It focuses on the relationship between the worker, the task, the tools, and the work environment. As the term ‘job safety analysis’ is not restricted to only identification of hazards, but the implementation of controls (Mitigation plans) and verification of the effectiveness of those controls, the term ‘safety’ will have a more appropriate meaning in the context of assessment of risk in a job. A JSA is a task oriented risk assessment which can be applied by a work team prior to undertaking a potentially hazardous activity. Risk Assessment is a planned procedure in which all hazards in the workplace are identified and their Risk Potential evaluated. The Risk Potential is a combination of the likelihood with the severity if an accident did happen. The first step in any risk assessment is to conduct a hazard analysis.
A Permit to Work System is an important part of an Oil and Gas company's Safety Management System and a key component of a Safe System of Work. A PTW System helps to ensure that all work is planned, communicated, controlled and carried out in a safe manner. Permit-To-Work is a proven best-practice method to ensure safety on dangerous hazardous worksites. A permit is a written, signed legal document and is a means of communication between site management, plant supervisors, operators and those who carry out the work. The most appropriate type of permit is determined and used according to the nature of the work to be performed and the hazards to be eliminated or controlled.
Therefore, it should be emphasized, however, that a ‘permit to work’ is not a replacement for robust risk assessment & hazard analysis, but can help bring the risk assessment ‘to life’, at the sharp end, where it matters.
Adaptation of Scope Challenge and Schedule Optimisation Techniques for Turnaround Optimization
Authors: AI-Kubaisi Nayef S. , AI-Ejji Hamad M. , Prasad Venkata R. 
Published: May 2012

Abstract
The Gas Recycling Plant (RG) of Qatar Petroleum (QP) produces Stabilized Condensate (DSC) and Raw Natural Gas Liquid (NGL). During Maintenance turnarounds (TA) in 2008 and 2012, QP employed new turnaround optimization techniques, which minimized the scope of work and the downtime duration of the plant outages. These two techniques were: Scope Challenge (SC): The complete scope of work of the TA is challenged in terms of monetary benefit to QP. The plant's integrity, Operation's requirement, shutdown sensitive items, mobilization requirements, and resources are given due consideration during the review process.Schedule Optimization (SO): The finalized scope of work is broken down into activities. The resources, costs and duration estimates are provided for each activity. The critical paths are identified and the duration of activities in them are re-evaluated using a systematic approach. Activities of various stake-holders are integrated into the schedule and interfaces are examined while optimizing the critical paths.
This paper discusses the approach, adaptation, implications, financial gains and benefits of utilizing the above techniques in gas recycling plant turnarounds.
DOST to ODVision2020
Authors: Al-Qahtani E.. , Soni R.. 
Published: May 2012

Abstract
DOST – Directorate Operations Strategy Team was formed in year 2007 to develop Operations Directorate long term vision. Inspired by Qatar National Vision – QNV2030 and fuelled by Qatar Petroleum "Commitment to Excellence", DOST has made significant strides in developing a shared Operations Directorate Vision – ODVision2020 under an innovative and unique LEADERSHIP concept.
This paper highlights the DOST journey in establishing the Operations Directorates Mission, Vision and Values as well as developing broad Objectives, Strategies and Roadmap based on SWOT analysis, cultural surveys and interviews carried out across the ranks. The paper will also present the challenges anticipated in realization of ODVision2020 and how organizational people, processes and systems would be transformed and Operations Directorate emerges as a leader in the industry in all aspects of its business.
Gas Flaring Reduction Initiatives in Dukhan Oil & Gas Field
Authors: Al-Bidaiwi M. S. , Beg M. S. , Al-Muhannadi M.. 
Published: May 2012

Abstract
Qatar Petroleum is committed to trying to achieve zero gas flaring. We have carried out important field changes to reduce it. As a result, we have significantly reduced gas flaring, recovered more hydrocarbons, protected the environment, and made financial gains by optimum utilization of the field existing infrastructure.
Gas Flaring is an important aspect of oil and gas field operations. It provides a safe relief for the production facilities whenever excess fluids or out of specification products need to be released. However, it has an adverse effect on the environment that needs to be resolved. Also valuable by-products could be recovered.
QP applied environmental regulations and drew on our experience to evaluate flaring sources and devise plans to mitigate flaring. We used recommendations from our evaluation studies to identify the necessary operational actions and plant changes.
We have identified four main factors affecting flaring: 1) field development planning 2) the design, construction, operation, and maintenance of field processing facilities 3) investment economics and 4) regulatory instructions. The operational actions and plant changes that we made have reduced gas flaring. Many other projects and studies are in progress to reduce flaring and ensure we comply with environmental protection requirements. This article explains the Qatar Petroleum flaring philosophy and the changes and modifications completed or in progress in Dukhan field that reduce flaring as we aim to achieve ‘Zero Flaring.’
The First Relief Well Drilled in Qatar to Intersect, Kill, and Abandon an Underground Blowout
Authors: Al-Murri Talib , El-Faghi Fawzi , Al-Meer Khalid 
Published: May 2012

Abstract
While executing a workover operation, one of the wells in Dukhan oil field experienced a well control problem. Water, Oil and gas from underground started to flow to surface through the production tubing. The BOP shear rams where activated to stop the flow. During the attempts to bring the well under control, an uncontrolled flow of oil, water and gas with considerable H2S concentration occurred from the ground.
A relief well, which was the first relief well in the State of Qatar, was drilled to intersect the blowout well and stop the flow.
A considerable amount of engineering and planning was involved to bring the well under control, along with stringent operational and safety controls. The operation was implemented in a safe and professional manner in 46 days, and resulted in an effective and long-term isolation of the blowout well.
The objective of this paper is to discuss the blowout well, the relief well, and the intersecting and killing operation.
Success Story of Solvent Swap in Acid Gas Removing Unit
Authors: Al-Ruwaili Soud Jaleel , Das Beni Prosad 
Published: May 2012

Abstract
This article explains how Qatar Petroleum faced the difficulties using diethanolamine solvent in its operating acid gas removing unit and were resolved them by solvent swap.
Gas recycling department's specialized team conducted root cause analysis to identify the operating problems encountered using diethanolamine solvent. Furthermore, the team carried out techno-economic feasibility studies to establish selection of suitable solvent to minimize and control filtration, plugging and foaming in the acid gas removing unit.
In addition, the team asked different suppliers to submit selection of alternative solvent to compare benefits and viability of replacing diethanolamine solvent. After analyzing the benefits, specialty methyldiethanolamine (Aminosol CST 115) was selected among other alternative solvent and finally solvent swap was carried out. The result of replacing diethanolamine with specialty methyldiethanolamine reduced yearly maintenance and operating cost with a full amount of to 0.52MM QAR, yearly cost savings with a full amount of 1.5MM QAR and expected a payback period within 10.5 months.
This paper will discuss acid gas removing unit facility and process overview, root cause analysis, investigation and troubleshooting of operation problem and challenges, the selection of alternative solvent and operational benefits of solvent swap.