bluuebunny/crossref_metadata_2025_split huggingface dataset:
CO2 Capture From Natural Gas Combined Cycle Power Generation Using Carbonate Fuel Cells
Authors: Kiss Gabor , Barckholtz Timothy A. , Blanco Gutierrez Rodrigo F. , Han Lu , O'Neill Brandon , Rosen Jonathan , Sutton Clay R. , Davis Keith E. , Dobek Frank , Geary Timothy , Ghezel-Ayagh Hossein , Jolly Stephen , Willman Carl 
Published: November 2019

Abstract
Electrical power generation facilities account for a large share of global CO2 emissions. Because they are stationary single-point emitters, power plants are an obvious target for reducing anthropogenic CO2 emissions by CO2 capture. Capture from Natural Gas Combined Cycle (NGCC) power generation has been much less investigated than from coal power generation, despite having approximately half of the CO2 emissions per electrical unity of energy produced as compared to coal-fired power plants. Furthermore, the majority of carbon capture R&D has been devoted to the development of amine scrubbers, a process which incurs a significant energy debit because of its steam consumption in the sorbent regeneration step. Molten Carbonate Fuel Cells (MCFCs) can be used for CO2 capture from NGCC facilities without a significant energy debit. They are modular, thus flexible in fitting the required capture capacity. When using MCFCs for carbon capture, additional power is created by the fuel cells keeping the total efficiency of the power generation system at or near the efficiency of the NGCC plant without CO2 abatement.
This paper summarizes the current status of MCFC carbon capture technology for low-CO2 emission abatement. We developed modeling tools and performed process simulations to optimize MCFC performance and to develop and assess integrated solutions for power generation with carbon capture. We also obtained proof-of-principle data at the bench scale, using small button cells and lab-scale single cells. Additionally, we carried out process demonstration tests using pilot-scale fuel cell stacks. Our results indicate that the technology is feasible and effective.
State-of-the-Art Review of Lost Circulation Materials and Treatments — Part I: General Trends and Uses
Authors: Alkinani Husam H. , Al-Hameedi Abo Taleb , Dunn-Norman Shari , Al-Alwani Mustafa A. , Mutar Rusul A. , Al-Bazzaz Waleed H. 
Published: November 2019

Abstract
One of the major problems facing the oil and gas industry is the problem of lost circulation. Millions of dollars are spent every year to treat this problem. Lost circulation can be occurred due to high permeability, natural fractures, induced fractures, or caves and vugs. Many major oilfields in the world are susceptible to lost circulation while drilling troublesome formations. The aim of this work is to understand the current trends and uses of lost circulation treatments worldwide. This work will be the first part which only focuses on the trends and uses. The other part (Part 2) will be focusing on probability and cost analyses.
Lost circulation treatments data were collected from more than 2000 wells around the world. Various sources were utilized to gather data such as daily drilling reports, technical reports, petroleum literature, etc. The data were clustered based on the type of loss (e.g. partial, severe, and complete), the reason for lost circulation, and the location where the treatments applied. An interactive dashboard was created to better understand the trends and uses of the lost circulation treatments worldwide. The created dashboard is adaptive for the user's preference and can be utilized easily.
The results showed that the pill of LCM treatments was the highest treatments used to treat partial loss worldwide with a good probability of success. While the high concentration acid soluble LCM treatment showed the highest use among other treatment to treat severe loss with a good probability of success. Moreover, cement plug + high viscosity (HV) mud treatment had the highest uses to treat complete loss with an acceptable probability of success. In addition, cement plug was the leading treatment used to treat partial, severe, and complete loss with a good probability of success. Nonetheless, it is not a usual practice to use cement plug to combat partial loss since there are other cheaper alternative treatments. Finally, this work will give clear insights into the current trends and uses of lost circulation treatments worldwide.
A Comprehensive Scheme for Application of Low Salinity Waterflooding Technique in Mature Fields
Authors: Elmasry Hossam , Anwar Mohamed , Moussa Esraa 
Published: November 2019

Abstract
The main seek for the whole oil industry is to find a way to prolong the economic life of the existing mature fields, as a result of the difficulty of finding new big assets. The waterflooding efficiency can be dramatically enhanced by the application of new technologies with the target of sweeping higher amounts of unswept oil. IOR/EOR methods are investigated to improve the oil production from the giant Belayim Onshore mature field located in Gulf of Suez, Egypt. The field was previously developed by using sea water peripheral injection. The existing water injection strategy is found not be the optimum strategy to increase the sweep efficiency and the recovery factor as a result of the huge lateral heterogeneity and different mobility ratio.
This paper describes the work done to improve the efficiency of water injection by the application of different IOR/EOR technologies specifically Low Salinity water. First, Coreflooding experiments on porous medium have been performed in the tertiary mood to detect the effect of IOR compared to the sea water injection. It was found that LS can increase oil recovery nearly to 7% more. After finishing the lab phase, simulation runs have been performed to predict the enhancement on field scale. The coreflooding experiments have been simulated using a wettability alteration model to determine the LS parameters and the new relative permeability curves. These parameter were the input into a sector model of fine gridding. The model was history matched using the wells production and injection data for the LS pilot area under study. Different forecast scenarios have been run and the incremental increase in oil recovery was reported against the current water injection scheme
A number of Single Well Tracer Tests have been performed to detect the effect of Low Salinity water flooding on well scale. The test was designed to incorporate a number of injection, production and shut in cycles in the pilot well with the aim determining the residual oil saturation with the current scheme of sea water injection and after switching into low salinity water. It was found that Low salinity water has achieved very promising results that produced a remarkable reduction in Sor at the range of (5-11) saturation units.
In order to estimate the full-field effect of the LS waterflooding as a promising EOR method, all the major aspects have been taken into account including the expected reduction in residual oil saturation, permeability alteration as a result of possible fine migration or clay swell and the possible change in the sweeping efficiency.
Finally, all the produced results from the experimental and simulation work have been incorporated into an economic study to determine the feasibility of constructing a desalination plant for the full-field application phase
Utilization of Mud Logs for Oil Fraction Quantification in Transition Zones and Low Resistivity Reservoirs
Authors: Torlov Vladislav S. , Bonavides Clovis S. , Al-Qubaisi Khalid A. , Fernandes Alan K. 
Published: November 2019

Abstract
Accurate quantification of fluid fractions in transition zones and low resistivity pay reservoirs often poses a challenge to the interpreter. Dry oil production from low resistivity intervals, mixed flow production, or disparity between formation evaluation analyses and surface tests can lead to lower confidence in the downhole measurements or interpretation and increase the uncertainty of the calculated hydrocarbon volume in place. A variety of measurements may be exploited to mitigate these concerns and, in this paper, the authors present an assessment of the relationship between normalized hydrocarbon levels while drilling, and computed oil fraction from wireline logging of logging-while-drilling (LWD) measurements based on a comprehensive dataset of various surface and downhole measurements. The study investigated the validity of advanced mud logging data for oil fraction quantification for particular borehole and reservoir settings and found a consistent trend across the range of bulk oil proportions and normalized gas values. The results of the obtained regression, and alternative cluster-based models are presented. The sources of uncertainties and possible correction approaches are discussed. The findings suggest that in consistent environmental and reservoir settings, advanced mud logging data can be used for hydrocarbon fraction estimation while drilling to assist in pay zones delineation and identification of fluid contacts. Potential was also seen to identify intervals of fractional flow production in transition zone reservoirs, low permeability formations, and dry oil production in low resistivity pay cases. In addition, developing such relationships and models is useful for correct identification of mud log artifacts, such as produced hydrocarbons while drilling, gases from circulation, and zones of overpressure. Another application is to assist in defining petrophysical model parameters, aiding or replacing other supporting information.
Electrification of Offshore Oil & Gas Fields Using Offshore Power Distribution Hub: A Study of Submarine HVAC Power Cables Systems Solutions
Authors: Renaudin Fabien , Gaudissart Simon , Toulotte Maxime 
Published: November 2019

Abstract
Traditionally, offshore oil and gas installations have been electrified by means of power generation equipment installed on the platform themselves. In recent year however, more and more offshore assets have been electrified by transmitting them power generated onshore through high voltage submarine power cable.
The alternative solution studied in this paper is the use of an offshore electrical power distribution hub connected to onshore power generation with a high voltage submarine power cable and supplying power to other offshore assets.
The focus of this study is put on the high voltage submarine power cable system transferring a power of 300 MW from an onshore power plant to the offshore power distribution hub located in the Arabian Gulf region.
Cases considering different transmission length, ranging from 50 km to 100 km and different voltage levels, i.e. 220 kV, 275 kV and 380 kV, are defined, analysed and compared technically. An overview of the technology current state of the art is also presented.
In addition, an economical assessment including manufacturing, installation as well as cost of losses over a period of 30 years is performed for the various cases.
With the high focus on cost and increasing concern for environmental impact in the industry, alternative solutions for the electrification of offshore assets are necessary. This study aims to demonstrate that a offshore power distribution hub supplying offshore assets with power generated onshore is a technical and economic viable alternative.
Saturation Forecast Using Machine Learning: Enabling Smarter Decision-Making Capabilities
Authors: Saumya Sachit , Naqeeb Ibrahim , Vij Jitesh , Khambra Isha , Kumar Apoorva 
Published: November 2019

Abstract
In recent times, several machine learning algorithms have been utilized to analyze massive amount of data and provide fast and effective smart solution. To monitor the saturation over time, reservoir saturation tool is run in each well to provide the cased hole saturations. A single well may have as many has 15-20 runs over time which provides an estimate of present saturation, depletion across reservoirs or any other changes in saturation profile to EOR system in place and its impact. This paper demonstrates the idea of the use of machine learning algorithm to perform a time lapse saturation analysis and present a saturation forecast based on class-based machine learning combined with the time series modelling using multiple time lapse runs in a single well for a field. The first step involves using an unsupervised class-based machine learning model that classifies the input petrophysical data into set of classes with distinct similarity. The next step of the workflow involves using time series modeling on each of the obtained classes. Different methods were studied and eventually "Prophet" was used for time series modeling to forecast saturation over time. A way forward and game changer is propagating the classes to multiple wells with multi runs and predict the changes in saturation and pressure for a formation across a field to make holistic interpretation. Reversing the time series modeling can also provide an estimate of OH conditions and original hydrocarbon in place. The use of CBML and time series modelling for petrophysical saturation evaluation will open new doors to understanding of fields already under production and introduce smart decision-making capabilities. The idea presented in this paper can be implemented in different fields across the globe with different formation settings and EOR system in place and can be further advanced in terms of providing deep insight and interpretation like forecasting the change in reservoir pressure.
Hydraulic Fracturing: Best Remedy for Condensate Banking Effects in Tight Gas-Condensate Reservoirs
Authors: Al Habsi Ghaleb , Ghanbarzadeh Soheil , Motealleh Siyavash , Al Busafi Badar 
Published: November 2019

Abstract
Available headroom (difference between dewpoint and reservoir pressure) in liquid rich gas reservoirs and drawdown scenario affect the condensate dropout near the wellbore. Although effects of the liquid dropout are well understood in radial system, addition of hydraulic fracture in the low perm reservoirs complicates the saturation profile in reservoirs. Massive hydraulic fracturing in vertical tight sand wells adds effective surface area to flow and can mathematically be considered as placing long horizontal wells to reduce overall well draw downs. This work shows that this additional contact with matrix rock, therefore, can play a major impact in mitigating or postponing the impact of skin caused by condensate banking.
This paper presents a real case of Pressure Transient Analysis (PTA) for hydraulically fractured wells in unconventional gas-condensate reservoirs. Detailed analysis of PTA will be discussed and addressed using analytical and high-resolution numerical models in which compositional multi-phase flow is considered. The numerical model is history matched and fine-tuned on pre-frac and post-frac well test results. The impact of hydraulic fracture half-length, fracture conductivity and matrix relative permeability on condensate banking effects will be addressed via a numerical simulation study for various scenarios.
The paper will demonstrate the value of hydraulic fracturing in reducing condensate baking effect on well productivity and, by inference, the impact on the long-term economic value of gas-condensate wells.
Lean Thinking and Gap to Potential: Achieving Breakthrough Well Delivery Performance
Authors: Al Busaidi Faisal , Al Hinai Faisal 
Published: November 2019

Abstract
This paper discusses how Lean thinking approach has been used to develop a new way of measuring the drilling performance, called "Gap to Potential (GtP)". It describes the methodology of developing Gap to Potential and highlights the implication of using it in one of the fields in Sultanate of Oman.
One of the foundational components of Lean is to make performance visible to the team and organization. Hence, The GtP concept was initiated in 2017 as a new process performance measurement concept aimed at motivating and developing teams to problem-solve their way towards aspirational goals. The GtP measures the gap between the average time it takes to drill a particular well type in a certain field with the Best Composite-well Time (BCT) ever achieved. The aspirational goal is to beat the BCT; when the previous BCT is met, the GtP concept generates a new BCT to continually generate a problem-solving and improvement culture. The GtP measurement was digitalized and visualized using an advanced analytic tool. Making the GtP visible to key stakeholder at all levels creates a sense of ownership and pride within the organization.
In 2017, Well Engineering team achieved lowest cost per well for the last 10 years with a further 4% improvement on 2016 performance and 7% reduction in well cost compared to the Well Cost Catalogue of 2019. GtP has now become part of a common performance dialogue at all levels in the Well Engineering organization. Despite of being relatively simple it its development, it has proven to be a powerful catalyst for boosting team development, building problem-solving capabilities and visualizing success. Once teams become familiar with the GtP approach, performance analysis and improvement become part of a daily routine. The success of the GtP for drilling has now created further replication across the organization, such as GtP for well intervention and energy management GtP.
The concept of visualizing GtP creates a sense of ownership at all levels driving behaviors of increased engagement and collaboration between drilling teams and assets as well as other supporting teams. Better uptake of other Lean ways of working that help structure the work and drive performance such as Leaders Standard Work (LSW) and Standard Operation Procedures (SOP). This concept is now being replicated for well services operations and can be applied to any type of activity, either technical or non-technical.
Bridging the Natural Gas Gap: An Integrated Approach to De-Risking the Development of LNG-to-Power Infrastructure
Authors: Fangmeier Clark 
Published: November 2019

Abstract
This paper focuses on overcoming the challenges of developing integrated gas-to-power infrastructure. It discusses strategies for driving the viability of LNG-to-power megaprojects– providing considerations for financing and risk mitigation. Additionally, it examines the merits of adopting an integrated approach to project development, with a close look at the Gas Natural Acu (GNA-1) project in Rio de Janeiro, Brazil, which is the largest LNG-to-power development in Latin America. For the project, the power plant's original equipment manufacturer (OEM) became a 33% equity investor. This, along with commitments from other strategic equity investors, significantly de-risked GNA-1 and played an important role in reaching final investment decision (FID).
The paper offers detailed insight into the inherent risks and challenges LNG-to-power project stakeholders encounter during development. It also discusses how these risks can be addressed and how projects can be made more attractive to institutional investors through innovative project financing structures. The ability to secure financing from a variety of equity sources with strategic interests in the project is critical, as it allows the sponsors to raise a greater amount of debt than would otherwise be possible. In doing so, sponsors are able to assume limited recourse after project start-up and in many cases, enjoy customized loan repayment profiles, which contributes to better overall project economics. Co-financing also reduces investment risk and allows for capital to be raised at a relatively low cost, which benefits all stakeholders.
A Novel Approach Towards Cementing Design Achieved Significant Improvement in Long Term Zonal Isolation
Authors: Suleiman Ala , Hilal Bashar , Paila Phalgun , Abdelhadi Sahir , Alwahedi Khalid , Alkindi Rashid , Al Marzooqi Abdulmohsen , Khalifa Mahmoud , El Atrache Bassam , Singh Rudra , Ghulam Hammad 
Published: November 2019

Abstract
Well integrity is becoming more challenging with drilling of deeper, highly deviated and horizontal wells worldwide while the current market scenario is driving every stakeholder to execute their scope of work under ever revising AFEs. The scope of this paper is to present an optimized approach to improve quality of cement jobs while having a good long term zonal isolation across all the targeted formations and further eliminating the additional costs required for remedial jobs.
There are various challenges that need to be dealt with when cementing complex wells such as uneven cement distribution around the casing due to insufficient mud removal, inadequate hole cleaning and poor casing standoff. All these challenges were addressed by in-house developed optimization methodology. The elements of this methodology that positively influenced the quality of the cement bond were (i) Optimizing the rheological hierarchy between the cement, mud and spacer design to create optimum flow during the cement job (ii) Improving hole cleaning efficiency by applying tailor-made spacer technology with aid of modeling software (iii) Optimizing the centralizer profile by including non-survey stations.
The in-house developed optimized methodology has yielded excellent results with significant improvement in the cement bond logs when compared to the offset wells. This paper will present the methodology adopted in detail along with the field example of a well in an offshore island that has measured success against the key improved elements.
The rheology of the fluids was adjusted to improve the fluid displacement in the analytical software which has played a big role in improving the hole cleaning efficiency. In addition, application of tailored Spacer design has not only showed improved mud removal effectiveness but also helped with reducing the channeling alongside the best optimized centralization found in the field in terms of type, quantity and placement across various formations and direction profiles along the well bore.
This paper will also compare different logs in the same field to show the improvement against the new methodology and practices adopted that helped in achieving complete zonal isolation across all formations. The new optimization methodology has resulted in significant improvement in outcome of cement logs across production casing in offshore island indicating an excellent zonal isolation and adherence to well integrity requirements. The key elements that were improved are now being adopted across all the jobs in the field and nearby fields.