bluuebunny/crossref_metadata_2025_split huggingface dataset:
Formulating Sag-Resistant, Low-Gravity Solids-Free Invert Emulsion Fluids
Authors: Wagle Vikrant , Maghrabi Shadaab , Kulkarni Dhanashree 
Published: December 2013

Abstract
Invert-emulsion fluid (IEF) systems formulated without organophilic clay have successfully addressed issues of barite sag and reservoir productivity. While ‘clay-free’ IEFs provide robust properties, additional materials in the form of low-gravity solids (LGS), like sized calcium carbonate or clay-type materials are required to bolster the rheological properties and suspension character of the system. This increases the plastic viscosity of the fluid, thereby resulting in a lower rate of penetration (ROP) and higher equivalent circulating densities (ECD). In the absence of LGS, the loss of suspension, especially in an inclined well, can lead to sag and cause a density gradient along the fluid column that may fracture the formation.
This paper presents a solution towards sag in an IEF that is free of LGS viz. fine sized calcium carbonate or clay-type material, and is formulated with a novel sag control additive to suspend barite. The additive was shown to prevent sag in 9-ppg, 12-ppg, and 16-ppg clay-free IEFs in a static-aging cell held vertical at 90° and then inclined at 45°. The additive provided sag control in different base oils with less than 5-mL oil separation. Extended sag testing with the sag-control additive at 250°F for 24 hours and at 150°F for 60 hours gave minimal oil separation and no barite sag. High temperature-high pressure (HTHP) testing on 9-ppg and 12-ppg demonstrates a flat rheological profile in the presence of this additive. Contamination testing of IEFs containing this additive shows that the suspension characteristics remain unaffected and the mud properties are tolerant to the presence of contaminants. The additive is North Sea compliant with a biodegradability of 71.4% in 42 days and LC50 of &gt;10 g/mL for aquatic organisms. Experimental data demonstrating both the environmental and anti-sag performance of the novel sag control agent is presented and compared to fluids without the sag control agent.
Field Experience in Identification of HIC in Pressure Vessels
Authors: Al-Sulaiman Saleh , Sardesai Vinayak , Al-Harbi Bader , Srinivasa Murthy Hari , George Saji A. , John Reji P. 
Published: December 2013

Abstract
Hydrogen Induced Cracking (HIC) is a damage mechanism that may cause extensive damage to the pressure vessels in sour service in crude oil & gas production facilities. HIC damages could occur and further propagate in the pressure vessels with inherent manufacturing defects due to the impurities in the steel plates. The decisions involving continuation of such vessels in operation after detecting the HIC damages are complex even after suitable engineering assessment. The results of periodic monitoring of defects during operation are assessed to infuse confidence for continued service.
This paper presents a case study for identifying service induced embedded defects in a Gas Interstage Separator Vessel by the application of selected NDT methods and allowing continued service of the vessel with the help of engineering evaluation and frequent periodic NDT inspection follow-ups. The pressure vessel, made of carbon steel, was manufactured to ASME Section VIII Div. 1 during the 1960s. The vessel was identified with embedded defects which had further grown into minor internal cracks along the thickness perpendicular to the surface as detected during initial follow-up inspections. The vessel was allowed to continue operation with very close monitoring, continuous engineering evaluation and frequent follow up inspection involving advanced NDT. This approach helped us extend the vessel service life by 8 years and gave us ample time to replace it with a new one.
The NDT methods adopted included Automated Ultrasonic Testing (AUT) Phased Array technique and the engineering evaluations involved the Fitness-for-Service approach as per API-579.
Sourceless Porosity and Permeability Estimation with NMR Logs While Drilling in a Carbonate Reservoir: A Case Study
Authors: Serry A. M. , Al-Mutwali O. , Al-Mansoori A. M. , Al-Marzouki M. I. , Budebes S. A. , Gueddoud A. G. , Balliet R. , Aki A. C. , Akopyan G. 
Published: December 2013

Abstract
Sourceless porosity estimation has become more attractive because of evolving government regulatory and HSE requirements. The use of wireline nuclear sensors and their HSE procedures have a 50-year history, while nuclear sensors for logging while drilling share the last 20 of those years.
Recently, the potential of using non-nuclear methods for porosity estimation has been explored in an offshore Abu Dhabi carbonate sequence. This paper presents a case study of nuclear magnetic resonance (NMR) logs while drilling, in comparison to conventional density and neutron logs using radioactive chemical sources. NMR T1 porosities were also compared to laboratory core results. Two approaches are investigated: Estimated hydrogen-index correction to NMR moveable-fluid volume using core-normalized porosities.An insight into an integrated NMR-acoustic approach, using the two sensor measurements to derive a corrected porosity.
A workflow is proposed for optimized job planning, operational procedures, data-acquisition parameters, and interpretation techniques. Permeability estimation with NMR is discussed, and a selection of methods are considered and contrasted to laboratory core permeability and wireline formation-tester results.
This paper explores the potential for sourceless porosity measurements through NMR and acoustic/NMR measurements in an offshore Abu Dhabi carbonate sequence in compliance with the HSE standards and government regulations, where the need for reconsidering reservoir characterization through sourceless porosity options will continue to grow.
Upstream Data Standards at Saudi Aramco
Authors: AlShehry M. A. , Al-Khudiri M. M. , Al-Sanie F. S. , Miyajan R. A. , AlTaiban A. A. , Al-Zawawi A. S. , Khakwani M. S. 
Published: December 2013

Abstract
This paper describes the upstream data standards that Saudi Aramco has recently implemented for Drilling and is in progress to implement them for other areas such as Production and Reservoir Characterization. These standards enable us to make wider use of our monitoring and collaboration centers through a common approach. It also allows us to leverage the evolving WITSML, PRODML and RESQML standards more effectively in our upstream operations.
Saudi Aramco relies on many service organizations to deliver the generated data which requires common and standard data classification when exporting data from source A then importing to destination B. Applying a common approach to information access on a global basis has enabled us to streamline our operations and make wider use of emerging analysis, monitoring and collaboration technologies.
Real-time technologies have been utilized to capture, monitor and analyze operational data from well sites so that critical decisions can be made in real-time to reduce and eliminate operational and safety problems, thus reducing non-productive time. That includes high-tech rigs, smart wells, monitoring & collaboration tools and real-time data visualization systems.
Our aim has been to implement standard upstream information architecture. Our full implementation of WITSML was the vehicle which allowed this to happen in Drilling & Workover operations. We still believe that over the next years with the advancements of technologies there will be more challenges to support open connectivity between different vendors and services supporting the increasing upstream functions.
A Pragmatic Approach for Promoting Local Proppant in International Business
Authors: Das Prasanta , Kothamasu Ramya , Karadkar Prasad 
Published: December 2013

Abstract
Because hydraulic fracturing applications are booming, the market availability of proppants plays a more significant role in the global oilfield economy. As a result, the demand for commercially manufactured proppants is increasing, fueling the construction of new production facilities around the world. Currently, there are only a handful of well-known suppliers of manufactured proppants that dominate the business globally.
This paper discusses a systematic approach to highlight and promote local proppant suppliers in international markets outside North America. This paper discusses how local suppliers from different regions within the Eastern Hemisphere were contacted for prequalification samples of their proppants. Submitted proppant samples were categorized, and a quality control (QC) method was established. Tests were performed as per ISO 13503-2 (2006) to pass the quality check. Comparisons, in terms of crush resistance and conductivity, were made between the products of standard international proppant suppliers and the local suppliers. Consistency and repeatability of the samples from different lots were measured; eventually, some of the vendors were certified to be a regular proppant supplier. A cost analysis was also performed to demonstrate how using local proppant could be beneficial.
This paper demonstrates in detail the procedure and testing cycle for establishing a local supplier in the Eastern Hemisphere, and then the global marketplace. A case study is included that illustrates the volume of proppant shipped for a specific area of field applications and the cost savings gained. A significant economic advantage was achieved because of the local availability of standard-quality manufactured proppant. The promising results of this study should encourage local suppliers to invest into the business and help convince the industry that more economic alternatives are available to meet the market demand for manufactured proppants.
Quick Gas Production Increment by Optimization of Pressure Control Valves on Gas Condensate Wells. A Field Case in Saudi Arabia.
Authors: Rodriguez Ruben Villegas , Jauregui Jairo Leal , Bolarinwa Simeon , Al-Driweesh Saad , Al-Buali Mustafa , Dhamen Mohammad A. 
Published: December 2013

Abstract
Evaluating pressure drop changes across Pressure Control Valves (PCVs) is a key element for identifying potential gas incremental opportunities and determining potential energy loss in maturing gas fields. This is more critical when the gas reservoir is being depleted without a pressure maintenance suport program. A dedicated production tracking and monitoring process is required for a full evaluation of every component in the gas production system; from downhole to the gas plant.
Operational data and choke valve erosion velocity calculations from 60 gas producing wells were evaluated to identify PCV’s needing replacement and optimize production strategy. These wells were experiencing high PCV pressure drops, constraining their ability to produce at maximum potential. Factors such as Cv; internal damage or plugging were evaluated to determine the cause of the under sized PCV’s. Additional efforts were required to verify the sizes of installed PCV’s and to ensure that flow rates could be properly calculated by recalibration of instrumentation and validation of venturi meter calculations. A PCV replacement program was then established to maximize the productivity of seven (7) critical high producing wells.
This paper describes the multi-disciplinary approach and methodology implemented in North Central Ghawar Gas field to optimize the performance of installed gas well pressure control valves. This methodology will continue to be implemented and expanded to cover more than 500 wells in other Saudi Aramco gas fields.
The paper discusses additional topics such as: proper design and metallurgy of pressure control valves, new evaluation model for pressure control valve flow equations, gas rate validation, building PCV simulator model using dedicated well performance tools, screening tools and an economic model.
Implementing this program is essential to maximizing gas rates and optimizing field production by identifying undersized PCV’s that need to be sent to the shop for internal inspection and maintenance or replacement.
Implementing Water Flood in the Greater Burgan Field, Kuwait: Improved Development Planning Through Pilot Testing and Field Appraisal Activities
Authors: Rajan S. , Al-Naqi M. , Al-Humoud J. , Ameen A. A. , Al-Qattan M. N. , Al-Hashash H. H. , Al-Enizi N. , Madhavan S. , Al-Qattan A. , Brooks A. D. 
Published: December 2013

Abstract
The Greater Burgan Field is the largest clastic oilfield and the second largest oilfield in the world. First discovered in 1938, and developed from 1946, production to date has relied on primary recovery methods. More recently secondary and enhanced recovery techniques have been investigated and water flood is now at an advanced state of implementation. The first such water flood project is being implemented in the Upper Cretaceous (Cenomanian) Wara Formation, which is one of the main producing reservoirs within the Greater Burgan complex. Here, production has been accompanied by steadily declining reservoir pressure.
The Wara Formation comprises multiple sandstone units deposited in a fluvial-tidal coastal system with a total thickness of approximately 140 – 180 feet. The reservoir exhibits a considerable degree of permeability heterogeneity. Lateral and vertical extent, and the pressure communication between sand bodies is highly complex. Understanding of hydraulic connection and volumetric sweep are therefore one of the key development challenges to address in this complex reservoir.
To avoid costly water disposal and to make best use of available resources the full field waterflood will re-inject produced water. Therefore project planning required an assessment of water injectivity using several water sources and an investigation of the required water quality requirements for the full field water flood.
A peripheral waterflood configuration has been selected for Wara reservoir taking advantage of some 1200 feet of vertical relief between the flanks and crest of the anticlinal structure. Prediction and optimization of this waterflood project required appraisal of structure, pressure, reservoir quality and fluid type in largely undrilled lower flanks areas.
This paper summarizes the pilot waterflood projects, flank appraisal activities and related study work to understand hydraulic connection, reservoir properties, injectivity and reservoir performance. It describes the approach taken and the learning points from each of the activities together with their implications for the full field water flood project.
Logging While Drilling Resistivity Images for Geosteering
Authors: Bazara Magdi , Maalouf Janine , Al-Sharafi Mohamed , basyouni Adnan , Farah Ahmed , Bulushi Waleed 
Published: December 2013

Abstract
Petroleum Development of Oman (PDO) is undertaking a waterflood development of one of their fields. This project requires drilling horizontal wells in heterogeneous carbonate formations. The water injection wells are planned to be drilled in the lower part of the reservoir which has high porosity and water saturation of minimum 40%.
Azimuthal density images have always been the approach for real time formation evaluation and steering. However, for this project, the operator has selected the high resolution LWD resistivity images due to their closer position to the bit, as well as their better stratigraphical resolution.
This shift in technology was due to the need for making proactive decisions and to address structural complexity of the targeted layers.
The resistivity images allowed readjusting the well path during geosteering. It helped precisely evaluate the dip of the formation, when even one degree can affect drastically the length of the reservoir exposed for production.
On a geological level, the resistivity images permitted the interpretation of features that could not be easily detected with other technologies. Different categories of faults, fractures and bed boundaries were detected, first time in this particular layer with an LWD technology.
The use of high-resolution resistivity images allowed optimal placement of the well in a more focused target (thinner zone for the entire drain section) and a better understanding of the geological environment. This not only helps in updating the overall field model of the client but also means improved strategic planning for better results in future wells.
A Field Trial to Assess Asphaltene Related Production Impairment—Marrat Reservoir, Magwa Field, Kuwait
Authors: Al-Qattan A. , Chimmalgi V. S. , Dashti H. H. , Haryono R. , Snasiri F. , Abdulla F. A. , Al-Humoud J. , Bond D. J. 
Published: December 2013

Abstract
Asphaltene deposition in the reservoir, wellbore and facilities has long been recognized as a problem in the Marrat reservoir in the Magwa field, Kuwait. One option of avoiding asphaltene problems in the reservoir, including the near wellbore region, is to maintain reservoir pressure and flowing BHPs above the asphaltene onset pressure (AOP).
Given that there is a large pressure difference between AOP and the bubble point pressure and that natural flow is possible at pressure well below AOP, there may be economic benefits in operating the reservoir at pressures below AOP. Benefits relate the reduced and delayed costs of water injection facilities. There may also be some additional recovery related to fluid expansion.
Potential problems relate to possible adverse changes to relative permeability due to asphaltene related wettability changes, productivity impairment due to near well-bore asphaltene deposition and increased asphaltene problems in the wellbore. The second and third of these potential problems have been assessed by a field trial.
This paper describes the selection of a candidate well and the design of a field trial to assess these problems. The selected well was produced first with FBHP well above the AOP. Asphaltene deposition in the tubing was monitored, fluid samples were taken and pressure transient tests were performed to diagnose well inflow performance. No decline in well productivity was seen in this period. Asphaltene deposition in the tubing was a problem and the well required cleaning during this period.
The well was then produced at high rate, with flowing BHP well below AOP and a similar surveillance program was carried out. Finally the well was returned to low rate production.
Analysis of the data from the high rate and subsequent low rate production periods indicated that there had been a limited decrease in well productivity. These data also showed that asphaltene deposition in the tubing was less of a problem during the high rate test than during the preceding low rate test.
Impact of New Wide Azimuth Seismic in South Oman on Development Decisions
Authors: Al Jahdhami Nafa , Healey Martin 
Published: December 2013

Abstract
The acquisition of new wide azimuth (WAZ) seismic data in South Oman has enabled improved subsurface imaging. Interpretations of these data have enabled optimal development decisions by ensuring wells are located optimally or not drilled.
The WAZ data was acquired in 2010 with a super crew operating in different terrain types in a 24/7 mode over a period of 13 months, covering a total surface area of 3,800 km2 and making this the largest ever recorded in PDO history. The data is currently being processed through a series of phases from Post Stack Time Migration, Pre Stack Time Migration to Pre Stack Depth Migration. Even early initial volumes of the Pre Stack Time Migration (PSTM) have already impacted development and appraisal drilling decisions on a deep carbonate field and the possible placement of future development wells on other fields.
The Pre Cambrian carbonate reservoirs at depths of 4500 km below the surface are not clearly imaged by conventional 3D seismic data, but now have been significantly improved by the WAZ data. New interpretation of these data has helped save the cost of at least one deep well that was initially planned. The new interpretation now enables a realistic match of material balance and simulation models with current production. In addition to the improved imaging and resolution of the deeper seismic events, the WAZ has also improved mitigation of the structural uncertainties of these reservoirs in areas where faults were previously not imaged by the conventional 3D seismic data.
The impact in this case was on the placement of previously planned miscible gas injectors and production wells in the field.
Oil Recovery Options for Waste Water Treatment Facilities
Authors: Al-Mebayedh Hamad 
Published: December 2013

Abstract
The ultimate goal of this study is to develop an environmentally and economically sound technology to manage and recover oil from waste water treatment facilities by studying the behavior of oil in water particularly at waste water facilities in Kuwait. The information available is diverse and widespread. Despite the necessity for such information, there’s no paper in the literature concerning the fate and behavior of oil in water concerning Kuwait’s environment. The actual frequency, magnitude, and consequences are unknown, which has proven to be a serious problem for the environment waste management in Kuwait’s Oil industry. Hence this Study attempt to correct that informational void by presenting waste management techniques, solutions, the behavior of oil in water within waste water facilities areas in Kuwait.
The methodology adopted was performed by carrying out a review of existing literature, contacting companies previously involved in recovering oil from water worldwide, holding discussions with operators, this is then applied to ADIOS2 the Automated Data Inquiry for Oil Weathering Model to develop the ideal scenario.
In a completion of this study we extrapolate that, Most of the existing mechanical recovery equipment was designed to collect oil using its property to adhere to the surface material of the recovery unit. This equipment can efficiently collect oil with certain physicochemical properties at standard conditions and cannot be used with equal competence both in warm and cold waters and on variable oil types and properties. The recovery efficiency significantly changes with time due to the oil slick property changes and emulsion formation. Therefore, multiphase interactions between oil, water, material of recovery unit need to be studied thoroughly due to their strong influence on the oil recovery process.
Well Integrity Management System (WIMS): Coupled Engineering Analysis
Authors: Samuel Robello 
Published: December 2013

Abstract
Managing well barriers and maintaining well integrity within limits is challenging for aging wells and has a major effect on extending the life of wells and reducing operational costs. This is important for both the design phase and the operational phase. As more real-time data become available, the efficient use of quality data for analysis has become important. Little has been done to include some of the important engineering analyses in this process. Standard methods and guidelines are traditionally used before or after they occur, but the key to savings and success is avoiding the risks associated with them. If risks are identified early, better solutions can be provided to reduce the associated costs and take remedial action. This paper will present the importance of engineering analyses, such as wellhead movement, trapper-annular pressure buildup, maximum allowable surface pressure, temperature and pressure effects on the integrity, casing wear, corrosion, and erosion significance, as well as zonal isolation and estimation of the tubing or casing safety factor as a quantifiable monitoring system. The presented threshold limits help to compare the actual and average values, either on a single-well or multiple-well basis in an asset. Continuous monitoring helps identify the risk involved with engineering analysis rather than setting simple limits and following the workflow process.