bluuebunny/crossref_metadata_2025_split huggingface dataset:
Optimized Isochronal Flow Tests
Authors: Franco Francy , Rincon Alexander , Useche Marcos 
Published: November 2018

Abstract
An Optimized Isochronal Test (OIT) is presented to evaluate the deliverability of a reservoir eliminating the need of shut-in periods during a multirate well test, which represents an operational constraint for classical isochronal tests and in some instances for modified isochronal tests.
The proposed technique is based on the effect of several consecutive and different production rates over the well-reservoir model during both transient flow and pseudo-steady state flow; thus, it is possible to estimate the reservoir pressure at different radius of investigation, and the ratio between production volume and pressure drop. This method does not require stabilization of static reservoir pressure after a flowing period since it is calculated using a mathematical procedure based on the transient pressure equation.
A reservoir simulation model with known petrophysical parameters, fluid properties, pressure and temperature, is used as a reference to evaluate the accuracy of the proposed methodology. Two types of fluids are tested, a low compressible black oil and a high compressible gas condensate, with the objective to demonstrate the optimized isochronal test applicability with pressure, pressure squared P^2, and pseudo-pressure Ψ(P) equations. The production deliverability is evaluated applying four different analysis: flow after flow test, isochronal flow test, modified isochronal flow test and the proposed optimized isochronal flow test; the results are compared and analyzed using the percentage of error found for every method.
The optimized isochronal analysis provides the option to avoid shut-in periods during a multipoint well test and provide reliable production deliverability curves. OIT has a direct impact in reduction of costs and deferred production for companies involved in oil and gas operations.
Take a Closer Look to Maximize Energy Savings
Authors: Nambakkam Harindranath , Al Jenaibi Eisa Salem , Sajjad Saqib , Al Sayegh Farah 
Published: November 2018

Abstract
Comprehensive Energy studies entices in identifying potential energy savings in gas processing industry.
The approach is to study, measure, analyze and quantify: Current energy situations with regards to processes and equipment operations;Sources or areas of energy losses in processes and equipment;Productive use of waste heat/energy;Alternative (cost-effective) energy substitutes;Modalities for augmenting energy losses and energy wastage in processes and plant equipmentMeasures which do not require large investments, but can lead to 8 to 10 percent savings in energy consumption.
The Comprehensive Energy study has resulted in the identification of 31 potential energy saving opportunities, which could allow the company to achieve expected savings of up to 20%. Out of thirty one savings opportunities, seven were identified as potential quick wins with 10% saving potential, eight opportunities would require further analysis and investigation and sixteen opportunities were kept in abeyance due to economic factors. Quick wins, such as: Review of Advanced Process Control (APC), Sniffer Valve Leakage Survey, Plant wide control tuning, Efficiency check on LP and Residue gas Compressors, HP Feed gas discharge pressure control and Propane compressors Desuper heater Fan Controls which contributed to 10% energy savings were identified during the study. Payback periods are very attractive, in the range of 3 months, for these quick wins.
Cleaning and Retrieval of Spilled Crude Oil and its Application as a Refinery Feedstock Using Highly Efficient Polymeric Nanofibrous Sorbents
Authors: Alnaqbi Mohamed , Alblooshi Afra , Greish Yaser 
Published: November 2018

Abstract

Objectives/Scope
The objectives of this project are to develop novel and more efficient materials to be used as sorbents for crude oil spills and to explore their potential for retrieval.

Methods, Procedures, Process
A number of remedies have been explored for the collection of spilled crude oil, which is one of the major environmental problems. Sorbents of different forms are being used as one of these remedies. However, adsorbed oil spill and used sorbents provide a secondary source of pollution. In our laboratories, we have developed polymeric nanofibrous sorbents that showed a high affinity towards the sorption of spilled crude oil. Moreover, the water-free adsorbed oil as well as the used sorbent were completely recycled into a homogenous solution that can be added to the refinery feedstock.

Results, Observations, Conclusions
Polymeric materials of various origins were converted into micro- and nanofibrous sorbents using a novel nanotechnology approach. Those fibers are characterized by their high surface area, and interconnected porosities. The homogeneity of the fiber size and pore size distributions was optimized in order to maintain a high degree of reproducibility. Fibrous sorbents were therefor applied to crude oil spills that were intentionally made over a simulated sea water medium. Results showed that sorption of the crude oil spill started within seconds of contact between the fibrous sorbent and the spilled oil. The water-free adsorbed oil showed a sorption capacity of up to 217 g/g of the fibrous sorbent. Moreover, the adsorbed oil as well as the used fibrous sorbent were completely converted to a homogeneous solution that can be directly forwarded as a feedstock to the refinery, hence provide a high economic value of retrieving the spilled oil and minimizing secondary sources of pollution.

Novel/Additive Information
The current approach is solely developed and tested in our laboratories and provides a more efficient approach to the cleanup and retrieval of crude oil spills from aqueous media. Our sorbents are competitively less expensive than those imported with a higher sorption efficiency. Moreover, our approach provides an additional solution to spilled oil and used sorbents through their recycling and re-use in the refinery feedstock.
Seismic Inversion and Tectonostratigraphy Integration in the Reservoir Model: A Case Study of Giant Carbonate Reservoir Characterization and Modeling, Onshore Abu Dhabi
Authors: Latief Agus Izudin , Syofyan Syofvas , Grover Anurag , Ali Shabibi Tariq 
Published: November 2018

Abstract
The carbonate reservoir properties distribution can be completely different from what expected of the depositional framework. The subsequent diagenesis processes, often multi stages, commonly overprint the primary porosity-permeability system. Therefore, comprehensive understanding of both depositional and diagenesis processes is very crucial to produce robust reservoir model.
In the case of mature field development with abundant data availability, reservoir modeling should be more data driven and integrate multi-discipline observation and understanding. The objective is to yield less-subjective and data-consistent model with better prediction quality. However, the understanding of geological processes governing reservoir heterogeneity shall be made as foundation in all cases.
The case study discusses on how a comprehensive multi-discipline review unravels and presents a completely new reservoir heterogeneity framework. Diagenesis processes were investigated from both burial and tectonic evolution/ tectonostratigraphy perspective. The 3D reservoir rock type framework as net product of deposition and diagenesis process is created by combining well vertical heterogeneity and seismic lateral information into 3D trend model.
The integrated and data-driven modeling approach reconciles process origin and the resulted reservoir heterogeneity. The inclusion of tectonostratigraphy component leads to better prediction result. Multi-disciplines integration provides an interpretation corridor, hence minimizing error due to subjectivity and/or limited level of experience.
The newly built reservoir model serves as basis for development plan optimization in the respective reservoir. The drilling result of some recently drilled wells shows a very good consistency with model prediction.
Alternative Method for Pressure Transient Analysis
Authors: Franco Francy , Rincon Alexander , Useche Marcos 
Published: November 2018

Abstract
An alternative method is presented for estimation of reservoir properties that are usually estimated in a classic buildup test are obtained using flowing conditions thereby eliminating the need for shut-in periods and measurement of static pressure data.
The proposed approach is based on the effect of two consecutive periods of production with different rates in a single well-reservoir model. The well is initially produced at a constant rate until pseudo-steady state conditions are reached, followed by a different rate that will generate a pressure transient response measured at bottom of the wellbore. A mathematical formulation is applied to estimate the reservoir pressure as function of radius of investigation, which is equal to the bottom hole pressure observed during a shut-in buildup test.
A single well-reservoir model with known petrophysical parameters, fluid properties, pressure and temperature is used as a reference to evaluate the proposed methodology. The reservoir (i.e. the simulation model) is tested by applying two methods: the first one, is the simulation of a classic buildup test, and the second one, is the simulation of two flow rates periods according to the new theory; the results are compared with the model of reference, calculating percentage of error for permeability, skin, and average reservoir pressure. Additionally, it is demonstrated that a shut-in period is not required to obtain data equivalent to a classic buildup test since it is possible to calculate it from dynamic behavior.
The ability to complete a well pressure transient analysis test from flowing conditions and provide valid and reliable results has a direct impact in reduction of cost and deferred production for companies involved in oil and gas operations.
A Study on the Effect of Biological Processes on Trapping Mechanisms and Storage Capacity for High Temperature Depleted Gas Field
Authors: Mohd Amin Sharidah 
Published: November 2018

Abstract
One of the most secure storage sites for CO2 injection is in depleted gas reservoirs. To ensure that the CO2 is trapped securely and will not escape to the surface, storage in such formations must be study carefully prior to injection in such formations. After the injection, the injected CO2 will undergo several trapping mechanisms; namely: hydrodynamic, solubility and mineral trapping. The extend of geochemical reactions involved depend on the composition of the injected fluid introduced in the aquifer, the composition of the initial minerals assemblage and the aquifer brine. In this paper, the importance of biological/microbial mechanisms towards the impact on the storage capacity was studied using reactive transport modelling. The results obtained shows that the presence of microbial compound such as organic matter contributes to the enhancement of mineral precipitation, resulting in secure long-term storage.
Mud Losses Estimation Using Partial Least Squares Algorithm
Authors: Al-Hameedi Abo Taleb , Alkinani Husam H. , Dunn-Norman Shari , Flori Ralph E. , Hilgedick Steven A. , Alsaba Mortadha T. , Amer Ahmed S. 
Published: November 2018

Abstract
Lost circulation is a very expensive drilling problem and very common in highly permeable formations, fractured formations or depleted reservoirs. Estimates of annual cost worldwide for lost circulation are over a billion for lost time and materials, and remediation costs. The drilling industry has a large toolbox from which to customize lost circulation responses. However, putting a value on the effectiveness of these lost circulation mitigation methods is harder to quantify.
The Rumaila field, Iraq, is one of the world's largest oilfields with overlying formations that are notorious for lost circulation issues as the formations are depleted, highly permeable and fractured. Because of the significance of the Rumaila field and the common lost circulation problems faced in drilling any well in the area, it is an ideal candidate for a statistical study to model anticipated mud losses and compare the model with actual mud losses. The resulting model should be able to predict average mud losses, along with other drilling parameters affecting lost circulation, and compare the different lost circulation methods used to mitigate known losses.
This study provides a larger data set and different models, using a machine learning algorithm than previous studies in the Rumaila field. Data of key drilling parameters for more than 500 wells are gathered from daily drilling reports, technical reports, final wells reports, and drilling programs. Sensitivity analysis identified the most critical parameters and provides insight into the impact of those parameters on mitigating lost circulation. The models of mud loss, equivalent circulating density (ECD) and drilling rate (ROP) are then tested with new data and compared with previous regression models developed for the area.
Using the same techniques, modeling of any formation can be used to analyze the current situation and develop techniques for mitigating lost circulation by controlling drilling fluid properties, the rate of penetration, response to lost circulation events, and other field parameters.
Digital Rock Physics Combined with Machine Learning for Rock Mechanical Properties Characterization
Authors: Saad Bilal , Negara Ardi , Syed Ali Shujath 
Published: November 2018

Abstract
Rock mechanical properties is essential for several geomechanical applications such as wellbore stability analysis, hydraulic fracturing design, and sand production management. These are often reliably determined from laboratory tests by using cores extracted from wells under simulated reservoir conditions. Unfortunately, most wells have limited core data. On the other hand, wells typically have log data, which can be used to extend the knowledge of core-based mechanical properties to the entire field. Core to log integration of rock mechanical properties and its interpretation is limited by our current understanding of rock physics. The gap is clearly evident where approximations such as empirical relationship between dynamic and static mechanical properties are used for rock failure estimation. This paper presents a hybrid framework that combines advances in digital rock physics (DRP) and machine learning (ML) to predict rock mechanical propertiy (e.g., Young's modulus) from rock mineralogy and texture to improve the accuracy of mechanical properties determined from log data.
In this study, mineralogy, density, and porosity data are obtained from routine core analysis and rock mechanical property from triaxial compression tests. In our methodology, we utilized DRP models which were calibrated against core data and then generate rock mechanical property, for intervals for which triaxial measurements were not available. Mineralogy and texture data are used to create DRP models by numerically simulating rock-forming geological process including sedimentation, compaction, and cementation. Rock mechanical properties derived from DRP are used to enhance the set of training data for the ML algorithm to establish a correlation between rock mineralogy, texture, and mechanical property and construct the ML-based rock mechanical property model. The ML model generates Young's modulus predictions and are compared with the laboratory measurements.
The predicted Young's modulus of rock models from the combined approach has a good agreement with the laboratory measurements. Two quantitative measures for estimation accuracy are calculated and examined including the correlation coefficient and the mean absolute percentage error. Cross-correlation plots between the Young's modulus predicted from the ML model and experimental results show high correlation coefficients and small error. The results of the study show that DRP model can be used to feed the ML model with reliable data so that the prediction accuracy can be improved. The results of this work will provide an avenue of learning from the formation lithology and using the knowledge to predict rock mechanical properties.
Integrated Analysis and Optimization for Progressing Cavity Pump Systems in Greater Burgan Field
Authors: Najaf A. A. , Ramchandra A. , Al-Yetama M. , Ledesma F. , Al-Salman A. , Suleiman N. 
Published: November 2018

Abstract
Progressing cavity pump (PCP) systems are widely used in the oil and gas industry. Continuously evaluating PCP performance helps to maximize and sustain fluid production and increase pump run-life. This paper focuses on integrating a real-time platform and advanced software to model, troubleshoot, and optimize PCP systems and their operation.
More than 50% of installed PCP systems located in Great Burgan Field in southeast Kuwait are connected to a real-time SCADA platform. These connected systems are monitored to support daily operations and to identify underperforming wells for troubleshooting. Special attention is given to wells exhibiting critical behaviors or wells with optimization opportunities. Before implementing any actions on these wells, real-time data history is used along with nodal analysis to predict the outcomes. This paper presents an intensive optimization analysis through the following field case studies: Preventing sucker rod string failureEvaluating pump submergenceOptimizing fluid productionIdentifying optimum operating conditions
Software is used to perform simulations of flow under different operating conditions and to generate a full analysis report based on PCP equipment configured in the well model. The sharp-edge results are not limited to the production rate. They also extend to pump performance and other surface and downhole parameters such as pump torque, intake pressure, and discharge pressure. The outcome of these results assists with making well-informed decisions with the following benefits: Operating conditions have been improved by estimating the production rate at different speeds.Pump life has been improved by evaluating rod load, lift load, and efficiency.Down-time has been reduced by preventing pump-off conditions.
The procedure serves as a proven guide for analysis and optimization of PCP systems. Improving pump efficiency, achieving the target production rate, identifying problems, and preventing potential failures all help to optimize PCP system performance.
The innovative integration of PCP analysis and optimization provides a means to increase production and reduce the load percentage of surface and subsurface equipment parameters. A real-time SCADA platform combined with the optimization software created an ideal solution to keep wells operating at peak performance levels.
A Case Study from a 53 Year Old Asset - The Importance of Integrity and Risk Management for a Mature Asset
Authors: Jadoon Ammer 
Published: November 2018

Abstract
BP is a joint venture partner in GUPCO, which operates in the Gulf of Suez, Egypt. The asset is over 50 years old and has a large operational foot print. This includes 3 onshore process facilities handling over 450,000 barrels of fluid per day from over 100 offshore structures and 200 pipelines. The field is supported by gas lift and water injection from two onshore facilities.
The asset presents a challenge from an integrity perspective, namely corrosion and production chemistry threats. These are managed through an inspection program and anomaly management process.
This case study presents how our asset integrity is managed and forward plan for improvement. The important relationship with the risk management process is highlighted.
Thinking Differently Ensures Integrity of Fire Water Network
Authors: Qamar Shahid , Al Maskari Juma , Narayana Sathyanath , Nath Nahum Kant , Rafiq Shahid , Albraiki Ahmed 
Published: November 2018

Abstract
With focus on enhancing Integrity and efficiency, ADNOC Gas Processing identified an opportunity for optimization of existing FRP firewater system in Ruwais. A comprehensive study of complete firewater network and review of operating and control philosophy performed in order to optimize the system performance and mitigate pressure surge problems. This paper presents measures that ADNOC Gas Processing have adopted to achieve improved system efficiency and lower operating cost.
A study was undertaken by GASCO to review issues with existing Fire Water network (FWN) at Ruwais to enhance overall performance of system in terms of design, operation and control. Initiative was to identify problems, evaluate root cause and think of optimization including some cost saving solutions. Study explored various operating configurations of existing 4-working+ 4-standby pumps with active involvement of operation personnel followed by hydraulic and surge analysis with different operating scenarios. Study revealed reduction in flow, head and pressure to mitigate fire water piping surge problems. Study also engaged pump vendors to establish feasibility of modifying the existing pumps.
The study identified that each existing fire water pump is suitable to deliver 1400 m3/hr against required flow of 1000 m3/hr. Additional flow may create pressure spikes and surges in FWN. Hydraulic analysis found that pressure was above minimum requirement of 7bar (g) at the most remote point in network. Simulation indicated that fluid velocity was above 3.5 m/s at specific sections on the ring main. Increase in pipe sizes is required to arrest velocity within recommended limit in these areas. Option of lowering the operating pressure of main fire water pumps without the fire water network pressure falling below 7bar (g) at the most hydraulically remote point in the network was studied. Also the option of 3W+3S and 4W+4S [working (W) and standby(S)] pumping configuration was studied so as to establish that system can work with less number of pumps. Hydraulic study concluded that rated pressure should be reduced along with shut-off pressure. The maximum worst case fire water demand is 3200 m3/hr. The demand is found to be achieved with three Fire Water Pumps. During study pump vendors were engaged to arrive at the conclusion that 3W+3S configurations are hydraulically acceptable with pump / impeller modifications and de-staging options.