bluuebunny/crossref_metadata_2025_split huggingface dataset:
Full-Automated Managed Pressure Drilling System Facilitates Unlocking Unconventional Gas Reservoir Potential in United Arab Emirates
Authors: Al Hadidy Khaled , Hamdy Ibrahim , Al Samahi Musabbeh , Hadj-Moussa Ayoub , Saleh Mujahed 
Published: November 2019

Abstract
Drilling wells in potential Unconventional gas reservoirs is coupled with challenges that expose these wells to costly failures. Elevated formation pressure and pressure ramps create uncertainty in determining the mud weight to use in drilling UC wells. Also, various sources of gas influxes create confusion in analyzing well control situations and prolong handling kicks.
This paper details the approach taken on an unconventional exploratory HPHT gas well onshore Abu Dhabi to mitigate these drilling hazards.
After a thorough analysis of the drilling challenges that were encountered on a previous well drilled in the same field (Well-A), the drilling team has identified Managed Pressure Drilling (MPD) a key enabling technology that can help in mitigating the drilling hazards of (Well-A). A task force was formed with the MPD service provider to plan the MPD system deployment on Well-B. The task force came up with a detailed MPD program to address the anticipated drilling challenges in Well-B with multiple scenarios mitigation plan.
MPD goal was to identify the right mud weight to drill the reservoir section, handle gas influxes and analyze the sources of the gas at surface to minimize well shut-in time and to enhance the overall safety of the operations by providing close-loop drilling.
Drilling the reservoir section utilizing MPD has resulted in avoiding unnecessary well shut-in and raising the mud weight. Gas influxes were handled utilizing a dedicated MPD Mud Gas Separator (MGS) instead of the rig’s one, this approach enabled smoother drilling and coring operations. The pilot hole reached the planned Total Depth (TD) across high pressure ramps, coring program was implemented without interruption and full cores were recovered as planned. Non-Productive-Time (NPT) was reduced by 60% comparing to Well-A and no well control events occurred, saving cost and building confidence in the system. Therefore, a decision was made to continue utilizing the MicroFlux MPD system in the horizontal section of Well-B.
The MPD implementation on Well-B proved that the reservoir pressure was less than anticipated by 3 ppg, thus the 15K psi BOP was not required as thought previously, resulting in reducing the drilling cost of the consecutive wells. The impact of using a lower mud weight is believed to have a positive impact on the reservoir productivity.
This paper show-cases the utilization of the Full-Automated MPD on well-B as the first application of this technology in ADNOC onshore fields. It sets a stepping-stone for future implementations and capture important lessons learned and best practices that will certainly facilitate the development of Unconventional resources fields in the United Arab Emirates. Even more, the knowledge management process applied on Well-B can support tackling similar drilling challenges in mature fields.
Optimizing Completion Parameters via a Synthetic Catalog
Authors: Zheng Xinquan , Liu Yuan , Huang Yongjie , Enkababian Philippe 
Published: November 2019

Abstract
Unconventional resource development is increasing quickly in many places worldwide. For unconventional resources, multistage completions play a key role for both reservoir performance and well economics, which makes completion optimization a critical technical and commercial decision. This work integrates the reservoir modeling, fracture simulation, production forecast, and synthetic data pool generation via Monte Carlo methods, and it simplifies the final optimization process into a selection from multiple options.
There are many approaches used to optimize completion parameters in shale gas development in the Sichuan basin. Although a trial and error method may work well with an adequate number of wells, this approach is not efficient with few wells because it would take many years to optimize the drilling and completion strategy. Also, such an approach may produce ambiguous results related to high uncertainty due to drilling quality and completion inconsistencies.
An innovative workflow is defined in this work that combines reservoir modeling, fracture network simulation, production matching, regression analysis, and Monte Carlo methods. The procedure begins with modeling of the reservoir using the proper geological environment and reservoir properties. Based on this model, the hydraulic fracture network is simulated with varied compl etion parameter sets, including fluid volume, proppant volume, perforation spacing, and stage spacing. Production forecasting is then performed for each of the fracture network simulations, and the result is matched with previous offset well performance. Regression analysis is used to simplify the relationships between the input (completion parameters) and the output (production results). Finally, based on the regression results, a Monte Carlo method is used to generate a large number of input and output pairs creating a type of synthetic completion choice catalog. This catalog provides a pool of completion options, effectively reducing the optimization process to a choice of the best fit-for-purpose options.
A synthetic model based on Sichuan shale gas is used in this study to validate the workflow on a single- well basis. It successfully produced many synthetic simulation results. With the large number of completion parameters—production result pairs—it is easy to filter the results and identify which combinations are preferred in terms of cost and production. This work also demonstrates that optimization is subject to the definition of purpose and duration of the objectives, which can be used as an important evidence to support different strategies.
Digital Solutions Using Advanced Computational Techniques to Simulate Hole Cleaning
Authors: Deshpande Kedar , Celigueta Miguel Angel , LaTorre Salvador , Onate Eugenio , Naphade Pravin 
Published: November 2019

Abstract
Cuttings transport and hole-cleaning is a challenging issue associated with the efficiency of wellbore hydraulics and drilling operation. Traditional methods used to understand hole cleaning problems are based on field observations and extensive flow loop testing to formulate empirical correlations and mechanistic models. The focus of this study is to create digital twin utilizing advanced simulation techniques that provides better insight for cuttings transport and hole-cleaning. This study explores the use of Eulerian-Lagrangian based numerical techniques to estimate critical flow rate needed for efficient hole cleaning. Digital twin for the cuttings transport is formulated utilizing three dimensional Navier stokes equations employing combination of Eulerian and lagrangian approaches to model the drilling mud flow and cuttings interaction with the drilling mud, wellbore walls and between cuttings themselves. One of the important model to estimate the drag force on cuttings is modified for non-spherical cuttings shape coupled with non-newtonian Herschel Bulkley behavior of the drilling mud in this work. The influence of important parameters, such as fluid rheology, rotation of drill-string, and inclination of wellbore on the hole-cleaning process is investigated. Digital solutions are compared against the published data for Newtonian and non-Newtonian drilling fluids under different wellbore configurations. The advanced computational simulation involving novel drag force correlation and unique combination of numerical methods allowed to create digital twin for cuttings transport process accurately. The numerical strategy utilizing modified drag law showed a very good match with experimental results for straight vertical wellbore, the cuttings transport velocity estimated by digital solutions was within 5% difference of experimental results. Further upon validation, numerical results are successfully computed for drill -string rotation effects which clearly showed physics of cuttings transported efficiently with added energy due to rotation. The phenomenon of cuttings bed sliding in inclined and horizontal wellbores is also correctly simulated with the proposed drag law and numerical methods. The proposed methodology works without any issues with high concentration of cuttings and provides detailed insight into cuttings flow path and effect of various operational parameters on hole cleaning. Advanced computational simulations and modification of drag force law assisted in formulating digital twin that provided excellent insights in understanding effects of operational parameters for efficient hole cleaning.
Lesson Learned from Production Enhancement Pilot for Medium Oil Viscosity Formation in Minagish Oil Field Kuwait
Authors: AL-Rashidi Hamad , Jamsheer Abdullah , AL-Azmi Talal , Muhsain Batoul , Abu-Eida Abdullah , AL-Methen Badriya , Mousa Saad , AL-Harbi Faseil , Duncan Bruce , Safar Abdulaziz , AL-Azmi Waled , Desoky Waleed , AL-Sabah Fahad , AL-Yaseen Musaeb , AL-Hajri Mohsen , AL-Hajri Abdulrahman , AL-Mutwa Bandar , AL-Awadhi Hisham , Almeida Dwane , AL-Zanki Farooq 
Published: November 2019

Abstract
The strategy of the Kuwait Oil Company (KOC) is to implement key/emerging technologies at a country wide scale to meet future oil demand and production targets as planned in KPC 2040 strategy through overcome the field's challenges. KOC's Optimization strategy focuses on: Increased and optimize oil production from production optimizationsExtension of field life
Production interruption associated with pressure build up in reservoir, wellbore and flow lines have observed among many wells in West Kuwait fields perforated in Upper Burgan formation, which has a great impact on the company strategy. Tight emulsion phenomena is consider one the most challenging problems in West Kuwait wells due to the nature of asphaltenic crudes and high water cut production percentage. Traditional approaches to reduce high pressure and break the emulsion phase through injecting chemical near wellhead or in annuls is usually not successful in most cases and require large amount of chemical. Due to the complexity of this issue, a novel approach was used in this study to identify the main causes of oil production reduction and overcome the challenge to maximize oil production in West Kuwait fields.
Experimental Study of Fractured Carbonate Rock Model for Oil Recovery Evaluation
Authors: Bernardes de Almeida Sarah , Pereira André , Ruidiaz Eddy , Winter Alessandra , Vidal Vargas Janeth , Koroishi Erika , Vidal Trevisan Osvair , Valladares de Almeida Rafael 
Published: November 2019

Abstract

Objectives/Scope
The aim of this work is the experimental study of a fractured carbonate rock model for oil recovery evaluation. For this, a new experimental routine regarding petrophysical characterization was developed and validated. The evaluation of oil recovery was performed by mass balance. Also, the heterogeneity of the fractured rock model and the distribution of the saturations was calculated by X-ray computed tomography.

Methods, Procedures, Process
An induced fractured was created adding a longitudinal spacer (Lie, 2013) at a reservoir carbonate rock plug from a Brazilian pre-salt reservoir. Drainage process was performed by forced displacement using synthetic formation water and oil from the same reservoir rock. The model was aged at 63°C for 28 days. X-ray computerized tomography was used for porosity and fluid saturations calculations. The initial injection rate was 0.1 cm3/min. After reaching the saturation plateau, the rate was decreased to 0.05 cm3/min to evaluate possible incremental recovery.

Results, Observations, Conclusions
The developed methodology allowed the construction of a porous media with an induced fracture representative from a naturally fractured reservoir. The rock sample was cut lengthwise with a metal saw. A POM spacer was used to represent the fracture, and glass beads filled the fracture in order to give a representative porosity to the fractured rock model. The petrophysical properties of the matrix and the fracture were obtained during each step of the fractured rock model construction. The matrices porosities obtained were 8% and 14%, and the permeabilities 68 mD and 40 mD, respective to each semicylinder of the plug. The fracture porosity and permeability obtained were 1.6% and 146 Darcy, respectively. For the entire fractured rock model, the porosity was 12.5% and the permeability 5 Darcy. The approach to mimic a drainage method reached an initial water saturation of 57%. The recovery factor obtained by the seawater injection at a 0.1 cm3/min flow rate was 30%. An increase of 3% was obtained when the flow was decreased to 0.05 cm3/min. The CT scan measurement yields additional information such heterogeneity of the model through the porosity profile in the fracture, matrix, and the entire fractured rock model.

Novel/Additive Information
This work presents an innovative methodology to mimic a natural fractured reservoir model which provided a full routine for petrophysical properties evaluation of a physical model. Besides, computed tomography (CT) scans validated porosity values. Thus, a better understanding of the effects of the flow rate in oil recovery on fractured carbonates rocks and the potential of the model developed for this type of studies could be verified.
Online Valve Replacement using Tethered TECNOPLUG on ADNOC Onshore Main Oil Line
Authors: Balakrishna Menon Unnikrishnan , Chandran Jimesh , G Bowie Angus 
Published: November 2019

Abstract
ADNOC Onshore 24" Main Oil Spurline -1 transferring stabilized crude from Buhasa field (BUH) to MP (Mile Point)-21 hub had a defective 24" Gate Valve on the upstream side of Pig Receiver at MP-21.
The Objective was to replace the defective valve with a refurbished 24" Gate Valve with minimum production impact and without the need for depressurizing /draining the entire 35km section of 24" pipeline from BUH to MP-21.
A novel isolation technique using Tethered TECNOPLUG was identified and utilized for successful replacement of the defective upstream valve without causing any impact on the oil production.
LWD Resistivity Tool Response Modeling in High Angle and Horizontal Maximum Reservoir Contact Wells and its Significant Impact on Water Saturation Calculation: Case Study in a Giant Carbonate Field in Middle East
Authors: Yin Hezhu , Nicholis Mike , Al Teneiji Ahmed , Aboud Nawal , Salem Ahmed 
Published: November 2019

Abstract
Resistivity is one of the most important log that is required in water saturation (Sw) calculation, reservoir characterization, field assessment and hydrocarbon production. However, borehole environmental and borehole-to-bedding geometric effects on LWD propagation resistivity logs are inevitable. For instance, severe "polarization horn" responses from LWD propagation resistivity logs are commonly encounted in High-Angle & Horizontal (HAHZ) wells near bed boundaries with high resistivity contrast. These "polarization horns" in LWD propagation resistivity responses in HAHZ wells are not accurate resistivity profile, and consequently, impacts Sw calculation.
In this paper, an innovative LWD propagation resistivity Tool-Response-Modeling (TRM) workflow has been developed and applied to six typical Maximum Reservoir Contact (MRC) wells drilled in a giant carbonate field in Middle East. The inverted resistivity profiles along the well path result in more accurate resistivity and, hence, more accurate Sw calculations (as compared to capillary pressure- and core-based Sw calculations). Additionally, TRM results yield new insights on to both maintain the well in the target formation and reduce these "polarization horn" responses during geosteering operations. The case studies demonstrated that TRM and this workflow has an important and critical roles in accurate Sw calculation, formation evaluation and field assessment, and hydrocarbon production.
Neural Network Assisted Seismic Velocity Editing
Authors: Simha Srungeer , Goudswaard Jeroen , Devarakota Pandu , Somawanshi Prakalp 
Published: November 2019

Abstract
Normal Move-Out (NMO) velocity pick editing is the segregation of good and bad picks from an unsupervised auto-picking algorithm. As not all these picks are correct, manual velocity editing is required. This is time consuming, repetitive and typically requires a seismic expert for days to weeks. Automating it would require an algorithm that mimics the domain knowledge and expertise of a seismic processor; a deterministic approach would therefore likely fail. Alternatively, we propose a machine learning algorithm to identify valid time-velocity picks.
The proposed approach is a supervised classification approach which utilizes human interpreted velocity picks (1-5% of all picks) as training data. The algorithm learns to recognize the features of a valid velocity pick from metadata such as semblance energy, depth, areal location etc. and utilizes said understanding to segregate valid picks from invalid ones (multiples etc.) amongst the remaining velocity picks. The algorithm has been trained using synthetic NMO picks created by finite-difference forward modelling CMP data, including multiples, in the Marmousi model and auto-picking the move-out. The ground-truth NMO picks were created directly from the velocity model.
The trained classification neural network shows a very high &gt; 97% accuracy on segregation of valid and invalid NMO velocity picks based on a 5% input data set. Further reduction of the training data set to 1% of velocity picks reduces test accuracy only by an additional 2 percentage points. Training and execution time of the neural network on a dataset of ~ 40000 velocity picks are also extremely fast (&lt; 5 mins). Initial results on RMO picks also show a very similar performance characteristic.
The metadata for all valid picks spans a multi-dimensional feature space, from which the neural network constructs a non-linear selection criterion. A human can either manually QC each pick or perform attribute-based selection using only lower dimensional linear selection criteria. The robustness and speed of the neural network outperforms the manual editing while also reducing cycle time; the resulting velocity models will be superior, leading to improved signal processing and imaging results further in the processing sequence.
Automating velocity picking and editing has been a research objective for many years now, but only since the availability of modern computation and optimization algorithms can we properly deploy this to augment the high-quality modern velocity picking software and significantly decrease turn-around time by automating the picking and QC process.
Real-Time Monitoring of a Green Digital Oil Field in Abu Dhabi Offshore: It's Benefits and Challenges
Authors: Javid Khalid , Ettireddi Srinivas , Mokhtar Hafez Yahia , Hossni Ali Mohamed , Marin Centurion Pedro Ronaldo , Gonzalez Cerrada Luis Oscar , Mohamed Mohamed Sayed , Zahaf Kamel , Ibrahim Alhosani Khalil , Al Qamzi Abdulla Gharib 
Published: November 2019

Abstract
This Green Field was recently commissioned and it was put on production last year. It is a model Digital Oil Field having two artificial islands built to drill all its wells with smart completions like ICVs, ICDs and Permanent Downhole Gauges in all Oil & Gas Producer Wells. This paper will describe the benefits of real-time data utilization for better and most efficient Field/Wells Monitoring along with Better and quick decision-making. Flow tests are performed 2-3 times a week using Multi phase flow meter (MPFM) for each of its wells.
Smart and Innovative Dashboard have been created for best screening and grouping of wells as per predefined business rules and alerting Asset Engineers for any wells, which are close to violating any of the Reservoir Management Guidelines, and therefore timely decisions, are made to avoid those violations. Miscible Gas Injection was started from the early days of Field life. Gas Tracers are planned to be injected by the end of this year to achieve the successful and improved surveillance and understandingly Reservoirs and better plan the future wells locations and completion strategy.
All Field/well Shut Down duration opportunities are utilized for Pressure Build-up analysis for Oil Producer wells and therefore considerable cost of running Memory gauges and intervention operations is also saved.
Successful Digital Oil Field is a result of collaborative and multiple discipline Team Work. Lessons learned and recommendation for any new Digital Oil Field are also presented in the paper.
Innovative Dashboards have been created to for best screening of wells and alerting for any wells, which are close to violating any of the Reservoir Management Guidelines, and therefore timely decisions, are made to avoid those violations.
The standardized data repository is developed as data integration layer using OSI PI platform products to seamlessly merge real time data with manual data to create a single data reference architecture. This has been a powerful enhancement to ensure a single version of the truth.
Safety Events: Broadening the Base to Increase Learning from Everyday Work With a Look at Return
Authors: Inchingalo Florinda , Capobianco Matteo 
Published: November 2019

Abstract
The term "safety" has become widespread, but since it is a big idea, it may result hard to grasp.
In managing safety, the focus is often on accidents and incidents, however, serious events are infrequent and with them the occasions to learn. Learning focuses on everyday events can take place continuously rather than being a reaction to a single serious event.
The aim has been to raise awareness of all our people and to provide them with tangible measurements of safety in absence of incidents.
In this work it has been detailed a method to quantify monetary returns associated to the continuous identification, analysis and evaluation of risk and relevant controls, based on the fact that management is traditionally focused on financial goals and therefore more inclined to understand such sort of a language.
Thus, it has been considered what a return on investment looks like in safety for transport operations.
Based on evidences collected from our Business Units, a business case was developed where a disruption occurred in the operating activities due to some issues (i.e. downtime, return to base…) that could have been prevented by incurring a particular investment; in other few cases simulations were run based on missed opportunity costs.
Whilst in other domains this tool is quite easy to use, when incorporated into transport safety it becomes much more difficult because of the number of elements that may be affected. Any investment into safety should eventually reduce risk, whether through technology or process improvements with the consequence of reducing post-occurrence expenses.
The cost efficiency of safety management was also confirmed in more quantifiable terms through interviews with logistic managers responsible for decisions on transport management.
With such objective evidence, the budgeting allocation process will be supporting safety as a worthwhile investment, not only in general but also for specific safety measures.