bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Novel Strategy to Identify Potential Savings in Digitized Oilfields Through Automated Drilling Data Analysis
Authors: Ansari Arsalan , Watfa Mohamed 
Published: November 2018

Abstract
Digital oil fields implementation is ongoing in various oil fields around the world since the last few years. There are many research initiatives focusing on performance improvements trying to eliminate Non-productive time (NPT) caused by equipment failures or drilling conditions but the Invisible Lost Time (ILT), which accumulates when common drilling operations such as drill pipe connections are not carried out efficiently, is neglected. This makes it difficult to compare well delivery time and performance discrepancies for each activity across a field. The main challenge in optimizing drilling performance is deciphering the rich data streams in real time to make informed business decisions. This study focuses on the integration and analysis of real-time drilling data in order to evaluate the drilling performance via Invisible Lost time.
The methodology starts with analysing the effectiveness of the Remote Monitoring (the backbone of Digital Oil Field) of critical drilling operations as the actual performance is compared with predefined operation practices in terms of Rig Performance, Individual Crew Performance and Section Performance over four unknown drilling wells located within Field-X in the North Sea. The Invisible Lost Time is quantified from selected drilling activities such as tripping, drilling, running casing and flat time operations that can result in significant potential savings other than the main drilling operations.
Histograms were utilized to improve rig performance which indicated that the Connection time can lead to significant days’ savings as Tripping time contributes to approximately 60% of the Invisible Lost Time (ILT). Additionally, the effect of various factors such as hole sections and well depth on potential savings was also studied. This strategy may be developed as a cost-effective technology for any drilling or workover wells, as it results in improving drilling key performance indicators (KPI's) leading to performance improvement, risk mitigation and cost efficiency in real-time drilling activities.
Optimization of Models for Rapid Identification of Oil and Water Layers During Drilling - A Win-Win Strategy Based on Machine Learning
Authors: Sun Jian , Li Qi , Chen Mingqiang , Ren Long , Sun Fengrui , Ai Yong , Tang Kang 
Published: November 2018

Abstract
The identification of oil and water layers (OWL) from well log data is an important task in petroleum exploration and engineering. At present, the commonly used methods for OWL identification are time-consuming, low accuracy or need better experience of researchers. Therefore, some machine learning methods have been developed to identify the lithology and OWL. Based on logging while drilling data, this paper optimizes machine learning methods to identify OWL while drilling.
Recently, several computational algorithms have been used for OWL identification to improve the prediction accuracy. In this paper, we evaluate three popular machine learning methods, namely the one-against-rest support vector machine, one-against-one support vector machine, and random forest. First, we choose apposite training set data as a sample for model training. Then, GridSearch method was used to find the approximate range of reasonable parameters' value. And then using k-fold cross validation to optimize the final parameters and to avoid overfitting. Finally, choosing apposite test set data to verify the model.
The method of using machine learning method to identify OWL while drilling has been successfully applied in Weibei oilfield. We select 1934 groups of well logging response data for 31 production wells. Among them, 198 groups of LWD data were selected as the test set data. Natural gamma, shale content, acoustic time difference, and deep-sensing logs were selected as input feature parameters. After GridSearch and 10-fold cross validation, the results suggest that random forest method is the best algorithm for supervised classification of OWL using well log data. The accuracy of the three classifiers after the calculation of the training set is greater than 90%, but their differences are relative large. For the test set, the calculated accuracy of the three classifiers is about 90%, with a small difference. The one-against-rest support vector machine classifier spends much more time than other methods. The one-against-one support vector machine classifier is the classifier which training set accuracy and test set accuracy are the lowest in three methods.
Although all the calculation results have diffierences in accuracy of OWL identification, their accuracy is relatively high. For different reservoirs, taking into account the time cost and model calculation accuracy, we can use random forest and one-against-one support vector machine models to identify OWL in real time during drilling.
Standardizing the Data Structure and Formats to Meet the Business User Requirement
Authors: Kumar Pranav 
Published: November 2018

Abstract
Data Management concept is well understood now a days, in Oil and Gas industry. General workflow of data management starts with data generation, its processing (if required), followed by data loading into specific datastore, database or location (on file system), with the aim of for sharing it with the end user. A lot of integration happens with different systems and the corporate database, to perform various studies. This is all done under defined data governance rules and Service level agreement. This paper focusses on standardizing the data structure and formats, so that end users have to spend less time in getting the data for their daily use and interpretation. Additionally, the proposed work shows the ability to fix the data quality issues at the source. At the later stage, no one has to run the data quality checks, tools or scripts for fixing any data quality issues, separately.
The below steps can optimize the data quality and format issues: Data management team to coordinate and meet the end users to know the subsurface software used, data type used, problem while loading the data in the applications.Make listing and categorization of the data format required by the subsurface applications.Make listing of the units, coordinate system, and reference datum of data type as a standardCoordinate with contract administrators, vendor, contractors, data loaders to setup guidelines and instructions to deliver the data in the required formats.Create automated workflows for loading the data
The vendor or contractors have been generating data as per defined parameters in the service contracts. It is suggested to modify the contracts, so that the data is received as per the end user requirement. The benefit of using the method will aid the following: Each stakeholders involved in the data flow will gain knowledge about the dataData Quality and completeness checks will be improved.The end users of the data who are actually working on the data will find it easier to load or do interpretation.Data Standard will be implemented with much easier way.Issues related to data loading will be resolved in a better way.It will be easier to automate the process of receiving the data.
Dare to Change: PETRONAS New Approach to Implement Artificial Intelligence of Wells Activity Performance and Benchmarking Tool
Authors: Mohamad Azlan , Radzlan Raihana , Wan Hassan Wan Helmi 
Published: November 2018

Abstract
PETRONAS Carigali Sdn. Bhd. (PCSB) Wells Department (formerly known as Drilling Division) has long realized the importance of drilling and delivering most cost-effective Wells for the Exploration and Development segment, by establishing the PETRONAS Digital Collaboration Centre (PDCC), which serves as a decision support platform for stakeholders to monitor, reduce, and eliminate operational and safety problems during drilling, but a piece of the puzzle is still missing - to measure the well activity performance.
The earlier arrangement heavily relied on human factors such as the time-consuming logs that were completed manually by the PDCC personnel within 7 days after each completed well section. The analysis was done manually using excel spreadsheets, only focusing on major well activities, for example running the casing/liner and connection time. However, no pro-active action was taken during the operations to improve the performance. Furthermore, there is no ability to intervene with the rig performance in real time and adapt a technical limit approach. The Operational Excellence coach has limited experience and no tools to measure the technical limit, which also leads to a knowledge gap in wells performance and benchmarking areas of the drilling engineer's portfolio.
The implementation of the new artificial intelligent tool, presents revolutionary management challenges for people, process, and technology within the PCSB, aligning with Well's House vision to be "World Class Well Delivery – Preferred Solutions Partner".
This paper presents the business requirements and implementation of the PETRONAS Wells Performance Tool, and also describes the comparison between the previous approach and the challenges faced with implementing the new solution.
Field Trial Results for New Sand Control Technology for Water Injectors
Authors: Fipke Steven , Charles J. E. , Green Annabel 
Published: November 2018

Abstract
In 2014, an R&D project was intitiated to develop an innovative technological solution to improve the performance and reliability of Deepwater Gulf of Mexico assets. The objective was to increase the life expectancy of Miocene and Lower Tertiary water injection (WI) wells, several of which had suffered a severe loss of injectivity within only a few years of completion.
Before scoping out the project, an internal study was conducted to compile and analyse the available data. The root problem was identified as an accumulation of formation solids inside the lower completion; principally fine matrix sand that had been pulled in from the reservoir. These formation solids are normally stationary during steady injection, but can be mobilized during shut-ins (maintenance, pump problems, environmental conditions, etc.) due to powerful transient flow effects such as back-flow, cross-flow and even water-hammer. Eventually, enough solid fill can accumulate inside the lower completion as to diminish the injection rates. At this point the operator must consider some very expensive options such as to sidetrack or re-drill a new injector well.
The obvious solution to this problem was to find a way to prevent the fine material from getting inside the completion. The challenge was to do so while sustaining high injection rates, with no loss of injection pressure or requirement for additional horsepower. Therefore, the goal of the project was to find a practical, efficient method of stopping the formation material from entering the lower completion during a shut-in cycle. To achieve this, a new flow control device (FCD) and completion system was developed with intrinsic non-return valves (NRV) that are designed to prevent any back-flow or cross-flow during the shut-ins. Also, depending on well conditions, the system will minimize the damaging effects of water-hammer: rapid, high-amplitude pressure cycles that can occur during a sudden stoppage of flow.
Improving Field Development Through Successful Installation of Intelligent Completion on Water Injector Well
Authors: Yanez Eglier , Uijttenhout Mattheus , Zidan Maher , Salimov Rail , Al-Jaberi Salem , Al-Shamsi Al Anoud , Al-Sereidi Amnah , Amer Mohamed Mostafa , Al-Hammadi Yousef , Abdul-Halim Abdullah , Caletti Giovani , Adli Mustapha , Al-Hammadi Yousif Hasan , Al-Hosani Fahad Mustafa 
Published: November 2018

Abstract
Including "smartness" in your field does not necessarily add additional expenditures. ADNOC Offshore piloted a new well completion design combining Interval Control Valves (ICVs) in the shallow reservoir and Inflow Control Devices (ICDs) in the deeper reservoir, both deployed in a water injector well for the first time in the company. The objectives were to improve reservoir management, reduce well construction complexity and achieve one of the main business targets of cost optimization. This paper covers the subsurface study, detailed well construction design, completion deployment, well intervention and overall well performance in commingled injection mode.
A multi-disciplinary study was conducted based on updated reservoir data available after the first two years of production in a heterogeneous multi reservoir field. This study showed the possibility of replacing the upper horizontal drain by a deviated perforated section. The authors identified the need of completion compartmentalization to overcome challenges such as high reservoir heterogeneity and uneven pressure depletion enforced by non selective acid stimulation. As part of the evaluation, a simulation was performed to evaluate the expected injection performance across the four zones with different combinations of ICVs and ICDs in order to cater for different injection scenarios.
As a result of the integrated analysis, a new well completion design was deployed to optimize a Dual Horizontal Water Injector into a Single Smart Completion with 3 Inflow Control Valves (ICVs) covering the upper perforated zones and 14 Inflow Control Devices (ICDs) with sliding sleeves across lower lateral reservoir. Cost savings and reduction of rig time was achieved with this new completion design demonstrating very pro-active participation from all involved teams, ADNOC Offshore and Service Companies.
The requirements to complete high and low permeability zones in one single well can be successfully accomplished. Firstly, mitigation of early water breakthrough is achieved by incorporating surface water injection control in high permeable zones and secondly, the injection target for the low permeable reservoir is also delivered.
Building on the successful results and captured lesson learnt, this new well completion design provided the capabilities to optimize the water injection plan while reducing costs. Therefore, the project has passed the trial phase and the team proposed its implementation.
How Targetless Local Position Reference Sensors will Change and Improve the Experience of DP Operators
Authors: McKnight David 
Published: November 2018

Abstract
Position reference sensors (PRS) in dynamic positioning systems have either been global systems, such as GNSS, or targeted local PRS, such as laser, radar, or taut-wire. Local PRS operate by placing an artifact into the environment and tracking that. For a laser or radar local PRS that artifact is a reflector or a responder. For a taut wire that artifact is a heavy weight. Once this artifact is in position then the sensor tracks where it is relative to the artifact.
This method of operation, where an artifact is tracked, is understood throughout the DP industry. Targetless local PRS disrupt this as the system no longer relies on targets placed within the nearby environment, but on the environment itself. They may rely on self-mapping technologies or they may be looking for specific structures or features in the environment. These both result in a method of operation which may hold surprises for one trained in traditional DP sensors.
This paper discusses the nature of the changes and what a DPO should be aware of as they approach the use of these sensors. We will also look at particular scenarios where this new operating paradigm will convey particular advantages to the user.
Update in Development of Advanced Plasma-Based Technology for Rigless Well Intervention
Authors: Kristofic Tomas , Kocis Igor , Gajdos Matus , Horvath Gabriel 
Published: November 2018

Abstract
Plasma-based technology for various upstream applications has been under development for a couple of years. The first commercial application is for wellbore tubular removal or "milling" for Well Plug and Abandonment the main focus being the North Sea and Gulf of Mexico. In parallel to this process, the technology can be applied also for other well intervention applications E.G. Slot Recovery, Fishing and Re-entry, where removal of long tubulars sections is required.
The initial presentation of this novel idea for the Middle East was at ADIPEC 2015 where the development team presented the paper titled Non-contact Approach in Milling Operations for Well Intervention Operations. The main objective of the paper was to present the possibility of non-contact approach, based on electrical plasma in downhole milling or cutting operations. The present paper follows this paper from 2015 and summarizes recent achievements in progressing the development and commercialisation. It focuses mainly on successful milling tests of long tubing sections.
A Cost-Effective Dual-Element Metering System for Wet Gas Flowrate Measurement
Authors: Halilah Sami , Mokhtari Kahila 
Published: November 2018

Abstract
A wet gas flowmeter based on field-proven flowmeters and flow computers has been developed. The flowmeter is engineered by integrating the well-established SmartCone meter, a Pitot tube meter and filed mounted Flow Computer technologies in one wet gas metering solution. This combination exploits the characteristics of these two flow metering elements in wet gas flowrate measurement; The Cone measurement in wet gas is characterized by its relatively large gas measurement over-read with increasing liquid-loading, whereas this has a significantly lower impact on the gas flowrate measured by the Pitot tube.
The DynaCone wet gas flowmeter has been in development over the past several years with particular emphasis being placed on developing a flexible flowmeter for broad operating conditions and applications including high turndown ratio, minimal pressure loss, measurement quality diagnostic, and performance characterization in industry-recognized wet gas flow loop.
The wet gas performance has been demonstrated at CEESI wet gas flow loop yielding gas flowrates better than ±3% in Type I wet gas range, and better than ±5% in Type II without the input of liquid flowrate to correct for over-reading. Furthermore, uncertainties better than 2% and 3% for Type I & II respectively can be achieved if periodic liquid flowrate information is available for input.
Use of NanoActive® Sulphur Scavenger NASS for H2S Removal in the Oil and Gas Industry
Authors: Whittaker S. L. 
Published: November 2018

Abstract
This paper introduces the advanced technology NanoActive® Sulphur Scavenger (NASS), a Zinc Oxide (ZnO) based nanostructured material, and examines its applications across a range of problems faced by the petroleum industry. Principally, the neutralization of hydrogen sulphide (H2S) from crude oil and gas phases, resulting in the reduction of operational risks, environmental impact and pollution, and increased productivity and profitability.
NASS is a non-toxic, non-hazardous, non-dangerous substance. It is manufactured using advanced chemistry nanotechnology processes, creating unique properties (such as increased surface areas, large porosities, unique morphology, additional surface functional groups) causing enhanced chemical reactivity and increased chemical selectivity. The inherent chemical reactivity centers on a high surface area. Due to their exceptional porosity, NanoActive® materials have demonstrated the ability to destructively adsorb a wide range of harmful chemicals and odor causing compounds.
NASS’ two-step decomposition mechanism (adsorption by physisorption, followed by nonreversible chemical decomposition) substantially enhances its detoxification abilities because decomposition is less dependent on temperature. Use of NanoActive® technology improves scavenger efficacy between 4 and 6 times, depending on feed composition.
Currently, the range at which NASS stand-alone systems are economical is up to 10,000 ppm H2S in liquid streams, and 1,000 ppm H2S at 320 m3/hr to 10,000 ppm H2S at 30 m3/hr in gas streams. At these levels, NASS reduces H2S to 0 ppm. For higher concentrations, NASS is used in combination with existing removal technologies.

NASS mode of operation
Containment. Chemicals and vapors are taken up by adsorption into the large, porous surface of the NASS molecule.
Adsorption. Chemicals and vapors bind to the surface of the NASS molecule.
Neutralization. Chemical reaction occurs to change the toxin to non-hazardous.
NASS solutions can be applied to a wide range of challenges:
The earlier in the process NASS is deployed (for example, near the wellhead), the better for the process overall, with many downstream problems eliminated altogether.
Removal or reduction of H2S in upstream production improves safety, and reduces corrosion and byproducts, thereby reducing flaring and disposal, and producing sweet gas for power.
Reacted NASS is transformed into zinc sulphide (ZnS), which, along with any surfactant and inorganic materials, is non-toxic and does not require hazardous waste disposal, except where mandated by local legislation.
With the adoption of this technology, the current philosophy of H2S "containment and control" changes to "elimination by neutralization". It delivers significant HSE benefits, and reduces operational risk. It is today's Best Available Technology Not Entailing Excessive Cost (BATNEC). It allows development where currently there are technical, regulatory or economic barriers.
Innovative People Diversity & Inclusion Program - Key PDO FDC Business Enabler
Authors: Muhiddin Junaid G , Al Adhoobi Azza , Al Shukri Ibrahim , Unal Emre , Hersby Mette , Al Hinai Hannat 
Published: November 2018

Abstract
Three years ago, People Survey scores on PDO Field Development Center (FDC) Diversity and Inclusion (62%) were well below Top Quartile & PDO ‘Petroleum Development Oman’ average. The FDC were determined to turn this around. D&I was made integral part of FDC's people program.
The PDO D&I vision was firmly embraced by FDC and the statement is "to promote an inclusive workplace free from discrimination, bullying and harassment which celebrates diversity & provides all with an equal opportunity to succeed".
A three prong FDC D&I strategy was developed and enforced by a newly energized FDC People Team, the 3a strategy is: awareness, absorb, action and engage staff.
Raise AWAREness by: Prioritizing group learning events within FDC hosted by in-house subject experts, acknowledging key nation/religious events of employees in FDC, introductory talks on key processes and standards related to D&I. ABSORB is the soak & reflect mechanism driven by: voluntary circulation/rotation of the FDC Family Values Trophy to colleagues exhibiting one or more of D&Ivalues, ensure ADPs/coaching plans in place & perform people capability reviews twice a year. ACTION out the values through and engage the staff through: regular coaching/mentoring sessions, organizing FDC family day out event, Leader to Employees birthday acknowledgement gifts and increase staff Engagement through sustaining ‘Lunch with leader event, ‘leader Assist Day’ and introduction of ‘Talented People coffee corner event’.
As a result of this structured approach to tackle the D&I performance. The Field Development Center achieved Top Quartile performance with noticeable improvements such as: 2017 FDC People Survey D&I score was 85% which is Top Quartile. (in comparison to 2014 score of 62%).High level of engagement (85% response rate for whole FDC on last People Survey).High level of energy in FDC community as acknowledged by line director and observed in technical and social events.