bluuebunny/crossref_metadata_2025_split huggingface dataset:
Hydrogen Integration For Petroleum & Power Industries
Authors: Naim Mohammed , Muharrami Fawaz Al , Lamki Bader Al 
Published: February 2011

Abstract
With the increasing global awareness for the preservation of the environment, Governments became convinced that our industrial practices had an impact towards environmental deterioration through an anthropogenic climate change, which mandated Governments to demonstrate actions towards serious cutting back of carbon emissions.
It is accepted that the Petroleum and Power industries are among the highest sources of Carbon Dioxide (CO2) emissions and whilst they have an impressive record of constantly searching for ways to meet the energy supply with cleaner and more efficient technologies; they continue to be challenged to meet the energy demand under increasing local and global regulations to reduce their Carbon footprint forcing them to consider alternative approaches for facilities design and operation.
Apart from proceeding challenge; these two industries have something else in common namely: their need for Hydrogen generation. Hydrogen demand is evidently increasing in Petroleum industries for various uses in Refineries, Petrochemicals and Fertilizer industries. Similarly; demand for Hydrogen as clean source of energy is growing in the Power industry. It is this common need for Hydrogen that directed our attention to identify an opportunity for cross industrial integration through Hydrogen production resulting in various substantial environmental & business benefits in an affordable and reliable way.
Pilot of Gas-Lift System as Building Block in the Development Strategy for a Super Giant Field
Authors: Yaslam Maged Mabrook , Fahim Mohamed , Abdallah Dalia , Helmy Hamdy , Mansoori Yousof Al 
Published: February 2011

Abstract
A super Giant field production sustainability is essential and has to be sustained for longer period of time, therefore different techniques have been introduced and tested to overcome the various reservoir issues. Gas Lift technique (GL) has been considered as one of the effective mitigation actions to reactive the dead wells, enhance recovery factor (RF) and accelerate the production from both technical and economical points of view. Prior the full field implementation, it was decided to select a GL Pilot for testing and data gathering, the planned GL Pilot consists of 10 wells which have been selected from various reservoir units and completions to analyze the differences in the performance. The selected Pilot wells were inactive prior to GL implementation (with no oil production) as per set strategy which calls for using of the GL system to reactive the dead wells only. The Pilot started production in November 2008 with almost a total oil production rate of 14 Mstb/d using GL system and the current average rates of the pilot (as of Jan. 2010) are as follow; average oil rate~ 13,000 bbl/d, average water rate of~ 19,000 bblw/d, average gross rate of 32,000 bbl/d and average W.C%~ 60%. The pilot performance was achieved with total gas lift injection~ 6 MMSCFD (which means 0.6 MMSCFD per well in average). The total oil recovered from the current GL pilot, during a period of one year (330 producing days) is 4.15 MM bbl, this can be roughly turned in to cash amount equal to $ 207.5 MM (assuming 50$/bbl).
These resulted values from the GL wells have been surging up and down as a result of the optimization process in order to minimize the W.C% and increase the oil rate. Real Time Optimization (RTO) process is important and currently is ongoing (last stage) to be fully implemented to optimize especially the GL produced water (amount and treatment) in addition to the oil production. Gas quality, availability and conditions have been ensured with the current available field facilities.
Pilot Modeling is vital to assess each well behavior, therefore every well has been modeled using Inflow/Outflow Software and pertaining data has been continuously validated and updated according to the production tests and actual findings. Different monitoring tools have been used such as RST, PLT and Gas Lift surveys to identify the actual well performance. The Pilot modeling results have been used as a guidance to predict the full field future GL performance.
Generally, the Pilot results revealed the important questions and achieved the core objectives related the GL system for full field implementation.
Application of Digital Core Description Methods in a Reservoir Characterisation Study: A Review of Traditional Versus Potential Future Method
Authors: Al-Suwaidi M. , Williams M. , Ottinger G. 
Published: February 2011

Abstract
Core description is a fundamental step in the reservoir characterization process. Quality core descriptions are not only important for depositional and diagenetic understandings, but also critical to the development of sequence stratigraphic frameworks. This can have significant effects on development strategies for a reservoir through their impact on geological and simulation models.
There are increasing pressures to integrate large volumes of data rapidly and efficiently into geological models, especially in development and production settings. Traditional methods of core description using pen and paper are generally slow to produce the quality-controlled digital data required for geologic models. Digital core description has long been seen as a potential tool to speed up the integration of core data. However digital description tools have often been found to be cumbersome and slow, leading to questions about the practicality of the process and the reluctance of many describers to use the tool.
In a recent effort to describe a large amount of core as part of a large carbonate reservoir characterization study, initial efforts were carried out using traditional methods while later phases of the study used direct digital description. Due to the extensive footage of core that was to be described a large group of describers, with varied backgrounds and experience levels, were tasked to complete the work in a timely manner. The study was divided into two phases. In the first phase descriptions were carried out in a traditional manner with pen and paper and later digitized, while in the second phase a major effort was undertaken to introduce direct digital description. It was therefore of key importance to establish systems that would guide the describers in the information that they collected and to ensure consistency in the descriptions. Using a digital data entry system helped ensure consistency in description as well as integration of other data such as log and porosity/permeability data into a convenient format that could be viewed by the describer. While traditional methods were found to be much faster initially the resulting product was only available for analysis after digitization had been carried out in the office, in some cases months later, and was only usable after quality control editing, which was often not carried out by the describers themselves. Due to varying styles of description different characteristics of the core were emphasized by different describers and often described differently, creating challenges later when the data was analyzed.
In this paper we will discuss the advantages and disadvantages of traditional methods compared to our attempts at direct digital core description. Here we will show that the
Determination of Critical In-situ Stress Parameters for Future Well Placement: An Integrated Case Study From C-Series Fields of Tapti-Daman Block, Mumbai Offshore, India
Authors: Parashar Sarvagya , Sikdar Koushik , Roy Dipanka B , Shrivastva Chandramani , Kumbhar V. B. , Majithia P. P. , Baishya R. C. , Avtar Ram 
Published: February 2011

Abstract
Tapti-Daman is one of the major hydrocarbon-producing clastic sub basins situated in the northeast region of the Mumbai High structure in Western offshore India. Tapti-Daman sub-basin hosts more than 6 Km of clastic dominated sediments ranging from late Paleocene to Recent, underlained by basement rocks.
Drilling failure has been reported in few wells in Tapti-Daman block in the past, which subsequently resulted in well collapse and abandoning the drilled section. The limitation of stress computation in the deviated and horizontal wells further introduced complexity in overcoming the wellbore stability issue. To address this, an innovative methodology was developed to assess the stress regime in this field. An accurate estimation of the stress parameters in the backdrop of geological information led to a more accurate and reliable geomechanical model.
Using a multiwell dataset from the C-Structure in the Tapti-Daman block, stress azimuth from vertical and deviated wells was determined with an advanced interpretation module. The module utilizes the borehole microresistivity image-derived azimuths of drilling failure signatures (i.e. breakouts, induced fractures, etc.) to decipher the shape of the stress tensor (Q-factor) and azimuth of minimum horizontal stress. The detailed analysis of the Q-factor and Sh leads to determining stress regime and anisotropy (as a function of well trajectory).
The analysis revealed that the present day in situ stress in the study area is compressional in nature, where S3 is vertical (sH&gt;sh&gt;sV) and the minimum horizontal stress azimuth is towards NE-SW. This critical information is represented in 2D stereographic stress plots considering the Sv/Sh or Smax/Smin ratios to ascertain the safe window for various wellbore stability parameters such as sanding, breakout, mudloss, tensional fractures, anisotropy and probability of fracture opening with respect to insitu stresses.
The inferences derived provide an edge in optimizing the well trajectories to avoid wellbore stability issues.
Well Integrity Management System WIMS Development
Authors: Daghmouni Hamdi , El Manci Magdy , Abdel rady Sayed Aly , Shattawa Yousef 
Published: February 2011

Abstract
Operator’s continuing success depends on the ability to manage its reservoirs and to exploit them in the most efficient manner to sustain production targets, while maintaining a high level of safety performance. Ensuring the integrity of wells is essential to achieve these requirements. Some of operated wells are reaching an age where an increasing frequency of integrity issues is becoming a concern. In addition, new wells may face greater threats to their integrity, for example due to the more corrosive reservoir fluids often encountered in existing and new developments. Wells operating under high annulus pressure are at risk of loss of pressure containment either in the form of releasing formation fluids to atmosphere or cross flow and charging up shallow reservoirs or aquifers. When monitoring trends of annulus pressures it should be taken into account that even with relatively low sustainable pressure there is a possibility that cross flow to shallow reservoirs could be taking place. This is especially true for C-C annulus "B" of most oil and water injection wells where shallow water reservoirs are straddled by one casing. Any sustainable annulus pressure on this annulus is undesirable and is to be critically reviewed.
A well may also show annuli pressure due to thermal effect and this must always be checked for when a new well is being produced for the first time or when a well is brought into production after being shut in for a long period. It should be remembered that pressure increase due to thermal effect could be considerable.
One of the most key integrity challenges is the Sustained Annuli Pressure in A, B and C casings.
The asset–specific Well Integrity Management System must ensure that there is adequate isolation between the formations fluids (hydrocarbon-bearing reservoirs) and the surface environment at all times during well life. Responsibility for the well and its integrity is transferred between different parts of the organization during these activities, and this must be reflected in the integrity management system.
The development and implementation of Well Integrity Management System (WIMS) will assist effective management of wells and hence to contribute to the achievement of its business objectives.
The Well Integrity Management System (WIMS) shall provide direction regarding the manner in which wells are to be designed, constructed, operated, work-over up to abandonment. This is to assure the integrity during the well life cycle through monitoring, preventive, corrective practices and assurance system, which would reduce frequent work-over, operating down time, extend life cycle for wells, and secure asset integrity & safety and environment.
Inline Water Separation IWS Field Prototype Development and Testing
Authors: Xiao J. J. , White Ramsey , Aramco Saudi , Wang Shoubo , Gomez Luis 
Published: February 2011

Abstract
A compact multiphase Inline Water Separation (IWS) field prototype system has been developed and trial tested. The system consists of a Gas-Liquid Cylindrical Cyclone (GLCC), a Liquid-Liquid Pipe Separator (LLPS), a Liquid-Liquid Cylindrical Cyclone (LLCC) and a two-stage Liquid-Liquid Hydrocyclones (LLHC). The function of the system is to separate a significant portion of the produced water from a production stream while the remaining production fluids of gas, oil and reduced water are still sent to existing processing facilities. The quality of the separated water meets the requirement for water injection or direct disposal. The compact IWS can be installed either at the wellhead or downstream of a production manifold to handle multiple wells on land, offshore platform. The benefit of such a system includes increasing field water handling capacity, reducing the size and cost of the downstream separation facility, and reviving dead low-pressure wells.
The field prototype has been susccefully tested in the field. The overall water separation efficiency, defined as the percentage of water removed from the total water production, averages at 70%. The outlet water quality is less than 35 ppm oil concentration. The results of the tests show that it is feasible to integrate GLCC, LLCC, LLPS and LLHC into a compact multiphase separation system for bulk produced water removal from a production stream.
Crossing Barriers In Language And Comprehension To Improve Worker Safety
Authors: Campbell Hugh , Duguay Alexandra , Lecoindre Christelle 
Published: February 2011

Abstract
Transferring information that is critical to safe work is very difficult in culturally diverse work sites. Language and reading comprehension differs greatly from person to person, with increasing complexity when sharing information outside of the native language of the receiver. The challenge - to simplify the message while not diluting the salient points. The opportunity - creation of a short form material safety data sheet using pictograms and graphics rather than high amounts of text. The benefit - Higher degree of worker understanding and confidence resulting in lower incidents of near miss and injury on-site.
Total Abu Al Bukhoosh (TABK) has launched a new short-form Material Safety Data Sheet (SMSDS) system that addresses pre-existing boundaries to effective communication of chemical hazards and risks. The pictorial form overcomes limitations of reading comprehension and language to ensure the highest degree of health and safety for our workers.
The SMSDS is a single page, easy to read document that contains key information regarding the potential health effects, hazards and response measures of any particular chemical. The SMSDS was created by TABK in order to summarize the standard Material Safety Data Sheets while maintaining compliance with regulatory requirements. All with the aim of improving the usability of information made available to the end user of the chemical.
In addition to the safety precautions that should be taken when working with the chemicals (e.g. wearing gloves, goggles or a masks etc.) another important issue that the SMSDS addresses is the correct response protocols that should be taken when a problem occurs, whether it is a spill, an accident or a fire.
While kept within easy access of the work site, the information is also available online. The intranet database provides efficient management of information regarding the potentially hazardous materials in use at TABK, and offers a simple means to re-print sheets for convenience.
Optimal Strategies to Enhance Oil Recovery in Under-Saturated Carbonate Reservoirs: A Case Study
Authors: Jamshidnezhad M. , Ghazvinian T. 
Published: February 2011

Abstract
Gas injection seems to be an important method for increasing recovery in declining oil reservoirs. The method can be applied especially in the reservoirs with oil-wet rocks. Although sweep efficiency of injected gas is poor due to high gas mobility, in most cases gas is injected together with or alternating with water to increase its sweep efficiency. Gas injection into under-saturated carbonate reservoirs is still challenging. This paper studies different strategies to find the optimum method to recover more oil from a huge under-saturated carbonate reservoir. The reservoir locates in the Southern part of Iran and remains under-saturated for all its life. Giant gas resources in the area and the wettability characteristic dictate gas injection. In this paper, we build the reservoir model and simulate three different strategies: natural depletion, immiscible natural gas injection, and miscible enriched gas injection. In case of miscible gas injection, enrichment is done so that the minimum miscibility pressure (MMP) is set equal to initial reservoir pressure. Simulations are conducted with two commercial simulators to investigate the effects of different reservoir simulators. Detailed of simulation and results are elucidated in the paper.
Environmental Assessment of CO2 Storage Site: Specific Monitoring Program and Study Needed to Assess Environmental Impacts
Authors: Quisel N. , Rampnoux N. , Thomas S. 
Published: February 2011

Abstract
Ensuring societal acceptance of Carbon Capture and Storage (CCS) projects is strongly linked to the environmental impact assessment of projects. CCS implementation should not only be considered a technical solution to the carbon emissions issue as societal issues play at least an equal role in the full acceptance of the technology. CCS projects should be designed to minimize environmental impacts to the highest degree possible and prove that the environmental issues can be monitored during development and operational phases.
As a consequence, CCS projects must integrate appropriate monitoring programs and develop environmental studies in order to gather and analyse required information and to communicate with stakeholders.
This paper proposes to prioritize processes and techniques that can be implemented to monitor environmental impacts of CO2 storage sites. The first part of the paper focuses on the key monitoring techniques and assesses monitoring programs that can be used to gather required information.
The second part of the paper presents the importance of the additional studies needed to assess environmental, health, and safety impacts in the event of a leak from the storage site that should be recommended as part of the environmental methodology. This study can be viewed as the starting point for the decision analysis related to CCS projects and provides some guidance in establishing a specific monitoring program and an environmental assessment plan. It could be considered as an important step in the identification of the development options and optimization of the investment strategy that is required at the front end of any large and complicated project.
Making Real-Time Fluid Decisions with Real-Time Fluid Data at the Rig Site
Authors: Broussard S. , Gonzalez P. , Murphy R. , Marvel C. 
Published: February 2011

Abstract
Critical decision making is a common occurrence in oilfield production, and operators depend on accurate drilling-fluid data to determine the appropriate course of action for the success of their drilling program. Many critical downhole decisions made by operators are based on drilling-fluid data that could be up to 24 hours old and do not accurately reflect the current fluid conditions in the wellbore. During these potentially hazardous situations, the rig site drilling-fluids representative must contend with drilling fluid issues and may not have the time to conduct repeated, consecutive, and consistent tests on the fluid to offer accurate recommendations to the operator. Decisions may be impacted or delayed by using fluid properties measured before or after issues are identified, and problems may escalate. Automating routine fluid-property tests provides access to more precise and dependable drilling-fluid properties in real time, which, in turn, can lead to real-time data that becomes vital when crucial decisions must be made.
A major oilfield service company recently conducted field trials of its automated drilling-fluids measurement equipment in South Texas. Automated measurements of density and rheological properties were conducted on water-based and oil-based drilling fluids. Traditional measurement routines were also conducted throughout the field trials for the purpose of comparative analysis with the automated equipment. Automated and traditional measurement recordings were compiled at the rig site, and data were exchanged to the service company’s laboratory facility for analysis. Data exchanges were accomplished via the service company’s proprietary software, which can be used for analysis, data transmission, and data display.
This paper discusses the results of these field trials and focuses on the comparative analysis of the automated measurements and traditional measurements, strengths and limitations of the instruments, the integration of the instrument package into the routine functions of a drilling rig, the service company’s capabilities of presenting the real-time data, and the overall lessons learned during the course of the field trials.
Operational Experience Using Acoustic Reflectometry to Detect Blockages in Gas Pipelines
Authors: Wang Xuesong , Lennox Barry , Short Gordon 
Published: February 2011

Abstract
This paper will provide an overview of a novel acoustic reflectometry method that has been developed to detect features, such as blockages and leakages in industrial gas-filled pipelines. The basic concept of the technique is to inject a pulse of sound into a pipeline and then measure the reflections produced as this signal travels along the length of the pipe. Wherever the cross sectional area of the pipeline changes, such as points of partial or full blockage, there will be a reflection produced. By measuring these reflections and using knowledge of the speed of sound in the gas, the location of any features in the pipeline can be identified. The technique is non-invasive and can be used remotely to accurately detect many pipeline features, such as holes, blockages and other objects including valves and even girth welds.
The paper will present the results from laboratory tests and field trials which will show the accuracy of the technique in detecting and locating blockages and valve status in industrial pipelines containing high pressure gas. In particular details of a test where the method was used to locate an obstruction in a live offshore pipeline containing high pressure will be provided. The difficulties associated with detecting abnormalities in industrial gas pipelines will be discussed and suitable signal processing methods will be described which should enable the technique to be applied as a continuous monitoring tool for offshore gas pipelines.