bluuebunny/crossref_metadata_2025_split huggingface dataset:
Closed-Loop Data & Business Intelligence Driven Approach of Well Performance Evaluation to Identify Changes in Well Behavior
Authors: Alsaeedi Ayesha Ahmed Abdulla Salem , Elabrashy Manar Maher Mohamed , Alzeyoudi Mohamed Ali , Albadi Mohamed Mubarak , Soni Sandeep , Isambertt Jose , Tripathi Deepak , Alkuwaiti Hamda 
Published: December 2021

Abstract
Asset engineers spend significant time in data validation on a daily basis by gathering data from multiple sources, manually collecting and analyzing these data points to deduce well behavior, and finally implementing the changes on the field. This paper proposes a closed-loop methodology that drastically reduces the time lost in low-efficiency activities, helps engineers to make faster decisions, and assists in efficiently implementing the changes in the field.
This well performance evaluation starts with direct integration with the corporate database to feed the field data into a hydraulic model. Next, Pre-configured well performance limits such as reservoir parameters, well calibration parameters, and surface parameters are used to validate the input data and alert the end-user to trigger a well performance evaluation workflow. This workflow is based on a business intelligence tool that integrates statistical information with physics-based model information. Finally, after the engineer makes a holistic decision, an integrated action tracking mechanism assigns an actionable item to the field operator to close the workflow.
This approach significantly reduces the time spent on data consolidation and analysis. Essentially this means more time for the engineers to focus on well behavior improvement strategies such as stimulation or re-perforation from more than three hundred strings with more than a thousand well data captured over a month. This approach is not entirely dependent on either static physics-based or statistical models; instead, this approach integrates both methods to enhance decision-making. Moreover, the dynamic behavior of the well is captured in the statistical model and validated against the estimated well behavior derived from the hydraulic model. Furthermore, the streamlined visualization tool helps engineers quickly identify well problems, such as lower productivity, reduced reservoir pressure, increased well scale, increased restrictions in the wellbore, etc. Another critical value addition of this closed-loop workflow is the actionable feedback that is well defined and stored within the system for common reference. For example, the asset engineers provide actionable feedback such as retesting requirement, well stimulation, artificial lift candidate, tubing clearance. Within the action tracking framework, field engineers can quickly filter the assigned action items to him or her for the day and take appropriate actions.
This new integrated action-based closed-loop workflow significantly reduces the time spent on daily validation tasks and well performance evaluation tasks by combining the statistical and hydraulic models supported with visualization and action tracking capabilities.
Advancement Towards the Full-Field Implementation of Marmul Alkaline-Surfactant-Polymer in the Sultanate of Oman
Authors: Mahrouqi Dawood Al , Sulaimani Hanaa , Farajzadeh Rouhi , Svec Yi , Farsi Samya , Baqlani Safa , Battashi Mundhir , Hadidi Khalsa , Kindi Osama , Balushi Abdullah , Karpan Volodimir 
Published: December 2021

AbstractIn 2015-2016, the Alkaline-Surfactant-Polymer (ASP) flood Pilot in Marmul was successfully completed with ∼30% incremental oil recovery and no significant operational issues. In parallel to the ASP pilot, several laboratory studies were executed to identify an alternative and cost-efficient ASP formulation with simpler logistics. The studies resulted in a new formulation based on mono-ethanolamine (MEA) as alkali and a blend of commercially available and cheaper surfactants. To expediate the phased full field development, Phase-1 project was started in 2019 with the following main objectives are confirm high oil recovery efficiency of the new ASP formulation and ensure the scalability and further commercial maturation of ASP technology; de-risk the injectivity of new formulation; and de-risk oil-water separation in the presence of produced ASP chemicals.The Phase 1 project was executed in the same well pattern as the Pilot, but at a different reservoir unit that is more heterogeneous and has a smaller pore volume (PV) than those of the Pilot. This set-up allowed comparing the performance of ASP formulations and taking advantage of the existing surface facilities, thus reducing the project cost. The project was successfully finished in December 2020, and the following major conclusions were made: (1) with the estimated incremental recovery of around 15-18% and one of the producers exhibiting water cut reversal of more than 30%, the new ASP formulation is efficient and will be used in the follow-up phased commercial ASP projects; (2) the injectivity was sustained throughout the entire operations within the target rate and below the fracture pressure; (3) produced oil quality met the export requirements and a significant amount of oil-water separation data was collected.With confirmed high oil recovery efficiency for the cheaper and more convenient ASP formulation, the success of ASP flooding in the Phase-1 project paves the way for the subsequent commercial-scale ASP projects in the Sultanate of Oman.
4D Seismic Detectability in a Brazilian Pre-Salt Carbonate Field
Authors: Agut Cyril , Blanchard Tom , Yin Ya-Hui , Adeyemi Adeoye 
Published: December 2021

Abstract
This paper is dedicated to a pre-salt carbonate field located within the Santos Basin, Brazil, comprising thick Aptian reservoirs interspersed with igneous rocks. One of the main challenges for reservoir management is the surface constraint on the gas, as all of the produced gas will have to be reinjected and can be miscible with the in-situ hydrocarbons. The recovery mechanism selected is mainly WAG (water alternating gas) injection, with both producers and injectors equipped with intelligent completions using Inflow Control Valves (ICVs). A 4D seismic monitoring survey is planned to delineate gas and water fronts in reservoir flow units about 10m thick, providing critical information to help piloting a planned 6-month WAG cycle for improved recovery.
Seismic imaging is challenging in this case and 4D signal is expected to be weak (±2% dIp/Ip). We propose here, a methodology, based on a 1-D Gassmann fluid substitution model at wells (only limited reservoir fluid PVT data available) to rapidly answer the following pertinent questions as posed by the asset team in charge of the field:
From a phenomenological stand-point and neglecting some possible processing, imaging and acquisition challenges, will 4D data (post 4D inversion) detect a gas streak from an injector to a producer? What is the 4D seismic detection limit based on reservoir thickness? What kind of seismic acquisition will assure this detectability?
Under the assumptions made in this work, this methodology shows that a permanent system of acquisition seems to be a fit-for-purpose technology for detectability. Further work is however recommended using full complement of a 3D static and dynamic simulation model coupled with a complete fluid PVT model in order to assess more complex 3D dynamic interactions between the injectors and producers.
Approach to Nav Aids System on Islands
Authors: Alblooshi Khalil Ibrahim , Singh Kamaljit , Paul Raju , Kamal Faris Ragheb 
Published: December 2021

Abstract
Offshore business is gradually moving from traditional Well Head Platforms to the concept of Artificial Drill Islands and use of renewable energy sources. Navigational Aids design for artificial drilling islands has unique challenges due to vast periphery. This paper highlights all such challenges along with recommendations for a reliable and cost effective solution. Clients as well as FEED/EPC Contractors can benefit from the experience shared in this paper.
The trend over the last decade has been to develop Navigation Aids that minimize maintenance requirements whilst maintaining stable and satisfactory performance. Although, Navigation Aids are automated there is still a need for regular visual inspections as there is always the risk of vandalism, ship impact or damage during significant storm events. Navigational Aids System shall be in strict compliance with International Association of Lighthouse Authorities (IALA) Guidelines. In addition to usual Visual & Audible Navigations Aids, artificial islands require break water lanterns (both red & green type). Also, number of Navigational Aids is much more than those required for a typical offshore platform. Requirement of interfaces with remote ends need to be clearly defined as these have impact on the design and ultimate cost. GSM monitoring and control system, GPS synchronization & AIS remote monitoring shall be considered. Cabling over the Island periphery is neither reliable nor cost effective solution. Standalone solar power based Navigational Aids Skids with all control and monitoring facilities can be more suitable solution. Considering that Island Contractor provides few Navigational Aids before the mobilization of EPC Contractor, it is essential to coordinate the Navigational Aids design aspects to ensure synergy in terms of compatibility.
Standardization Lead to Potential Cost Saving in the One of the Clusters in Southern of Sultanate of Oman
Authors: Akaramethakorn Nichapa , Mahruqi Issa , Aziz Mohammad , Radwan Mohamed , Amri Yahya , Arfi Zulfa , Al Balushi Mohammed , Harthy Ilham , Al Farsi Mohammed , Riyami Abdullah , Susatyo Yoseph , Sariri Aisha , Hamimi Saif , Azizi Issa 
Published: December 2021

Abstract
This paper is for people to realize a strategic way of continuous improvement though optimization and standardization process with a minimum of 10% target cost reduction while developing capability in the organization in the south of Oman.
BN area is one of the main production areas in PDO (Petroleum Development of Oman) and is being operated under BR cluster from 1980s. Approximately eleven fields in the BN area are contributing to the success today. Continuous improvement through optimization and cost reduction has always been a top priority, where long term production and safety has been fulfilled. In 2020, this team has been put together to look into the overall cost saving potential with the clear management steering of "Do not Leave any Stone Unturned". A mixture of experience and young team members are retained to ensure capability development in the organization.
One of the key items that this team looked at is to standardize of upcoming Oil Producers and Water Injectors well design. The well design in at least 7 fields in the BN area has been reviewed and realized the value and risk through competitive scoping exercise. By avoiding looking at the fields in isolation, the team has considered a similarity of well functionality and had identified where the standard well design can be applied. Minimum functional requirements lead to minimum technical specification and building into a staircase of option with clear associated risk for each option. Through the analysis, a potential optimization of an existing well design has been discovered and is currently undergone further maturation toward design endorsement. With the maturation of the uniformity of well design in the area, it is foreseeing as an opportunity to ensure improvement can be sustained in the long run.
Minimum 10% saving of well cost through standardization and efficiency in project management is a target set, aiming to provide stability in planning. In addition, the team are looking into even more than 10% cost saving through innovative contracting strategy. It could potentially help to speed up the delivery of the project, accelerate production with less waiting time i.e. improve material stock management, simplify procurement process, ensure that the experience remains in the organization and will allow for replication in the future.
The approach involves a combination of integrating team from subsurface, surface, wells, contract, and procurement to enhance cost saving to the company. This has proven to be effective and aligned with the company's focus to consolidate a commercial mind-set thinking in each development.
Water Compatibility and Scale Risk Evaluation by Integrating Scale Prediction of Fluid Modelling, Reservoir Simulation and Laboratory Coreflood Experiment for a Giant Oil Field in Offshore Abu Dhabi
Authors: Nomura Yukito , Almarzooqi Mariam Sultan , Makishima Ken , Tuck Jon 
Published: December 2021

Abstract
An offshore field is producing oil from multiple reservoirs with peripheral water injection scheme. Seawater is injected through a subsea network and wellhead towers located along the original reservoir edge. However, because its OWC has moved upward, wells from wellhead towers are too remote to inject seawater effectively, with some portion going to the aquifer rather than oil pool. Therefore, it is planned to migrate injection strategy from peripheral to mid-dip pattern. An expected risk is scaling by mixing incompatible seawater and formation water. Such risk and mitigation measures were evaluated.
To achieve the objective, the following methodology was applied: 1. Scale modelling based on water chemical analysis. 2. Define scale risk envelope with three risk categories 3. Tracer dynamic reservoir simulation to track formation water, connate water, dump flood water, injection seawater and treated seawater. 4. Review the past field scale history data 5. Coreflood experiment to observe actual phenomena inside the reservoir with various parameters such as water mixing ratio, sulphate concentration, temperature and chemical inhibitor 6. Consolidate all study results, conclude field scale risk and impact of mitigation measures.
Scale prediction modelling, verified by coreflood tests, found that mixing reservoir formation water and injection seawater causes a sulphate scale risk, with risk severity depending on mixing ratio and sulphate concentration. Reservoir temperature was also found to correlate strongly with scale risk. Therefore, each reservoir should have different water management strategy. Scale impact is limited in the shallower wide reservoir with cooler reservoir temperature. Such reservoir should therefore have mid-dip pattern water injection to avoid low water injection efficiency with possible scale inhibitor squeezing as a contingency option. On the other hand, deeper reservoir has higher risk of scaling due to its higher temperature, causing scale plugging easily in reservoir pores and production wells. For such reservoir, peripheral aquifer water injection, treated low-sulphate seawater with sulphate-removal system, or no water injection development concept should be selected.
By using modelling and experiment to quantify the scale risk over a range of conditions, the field operator has identified opportunities to optimize the water injection strategy. The temperature dependence of the scale risk means, in principal, that different injection strategy for each reservoir can minimize flow assurance challenges and maximize return on investment in scale mitigation measures.
Project Strategic Framing Approach - The Strategy Table
Authors: Paribelli Luigi , Guarino Marco 
Published: December 2021

Abstract
Considering the different drivers and constrains of each party within a Joint Venture, the strategy table is an effective tool that provides a structured workflow to guarantee objectives alignment and to maximize value creation for all the Stakeholders during a pre-feasibility study.
Eni used this opportunity framing approach to define alternative project development strategy options with the aim to create value for all the stakeholders.
Thanks to this guided and structured approach each party, within a Joint Venture, can present and compare his view with others.
Using the strategy table tool, as framing approach, allows to identify alternative development strategies (bookends) as a combination of strategic options applicable for a given strategy theme. Furthermore, a clear objectives (what) and rationale (why) associated to each strategy will be defined to support the evaluation.
The range of strategy themes identified helps to test the potential tradeoff between various fundamental objectives. Through a structured process, characterized by the definition, framing, evaluation and decision phases, it is possible to streamline the alternative strategy themes options and rank them in terms of value creation for the stakeholders.
Using the strategy table tool, as framing approach, implies a decision-making process that allows to choose the strategy that best achieves our goal while also reducing our exposure to risks. Frequently the decision structure of a problem is complex, especially when the decision being considered relates to a large of scale project involving many sub-decisions. The Strategy Table helps the project management team to achieve an informed decision since it allows to evaluate what we are planning to achieve, understanding what our options are and considering how each option performs with reference to our objectives and project risks.
Once the bookends for all the strategy themes are defined (i.e. selected strategic choices for each focus decision), a SWOT (Strengths, Weaknesses, Opportunities, Threats) analysis is performed to qualitatively assess the identified strategies against strategic objectives and a short-list of strategies on which focus on more in details is defined.
The final outcome represents the most promising development strategies to be tested during pre-feasibility and feasibility studies.
Health Management Challenges of the Pandemic - A Case Study from Recent Pipeline Repair Campaign
Authors: Hernowo Widi , Ridho Rosif , Sunarto Sunarto 
Published: December 2021

Abstract
Avoiding an offshore COVID-19 outbreak while executing an urgent and intricate pipeline repair campaign is a significant challenge, especially in a country that is experiencing a COVID-19 positivity rate of more than 20% on daily basis. Any minor mismanagement of health management on the DSV (diving support vessel) may lead to a COVID-19 outbreak with the risk of shutting down the campaign and significantly impacting the business continuity objectives. Therefore, the major health management challenge is to avoid a COVID-19 outbreak on the DSV to ensure the well-being of personnel during campaign and to achieve the necessary pipeline repair.
The approach taken was to deploy the DSV with team and tools/equipment as soon as possible to avoid a prolonged platform shutdown due to the pipeline leak event. In order to carry out the project, a detailed risk assessment taking account of medical, logistics and security considerations was undertaken in order avoid a COVID-19 outbreak on the vessel. The risk assessment enabled an adjustment to the quarantine requirements for the pipeline repair team before departure to the work location. A contingency plan was also developed to manage a scenario in which a member of the offshore team was infected with COVID-19, and in order to comply with applicable government regulation.
Through the effective implementation of a detailed risk assessment, the company was able to complete the pipeline repair campaign without any offshore COVID-19 outbreaks. On the DSV there were 65 personnel working on multiple activities to execute the pipeline repair works on time and on budget. The site team made a diligent effort to follow the mitigations identified in the risk assessment, under the direction of company Business Continuity Management Team (BCMT). As a result of this effort, the company was able to resume production from the offshore platform in a timely manner.
This paper discusses the effective implementation of detailed risk assessment on a DSV as part of company business continuity management amid COVID-19 pandemic in the country, including medical, logistics and security considerations. This project was implemented in a year-end period, beyond normal conditions and in a tight schedule.
COVID-19 Case Manager App for Oil & Gas Companies
Authors: Yaqoob Shamrose , Ali Khan Salman 
Published: December 2021

Abstract
As COVID-19 quickly spread across the globe to reach pandemic levels, companies across every industry had to quickly adapt their business practices to allow employees to connect virtually and work remotely. This addressed new complications in several areas, including contact tracing. This paper reviews an approach that Siemens Energy took to remove the errors and inefficiencies in manually conducting contact tracing by automating the process using an end-to-end case manager app.
The app, which provides full transparency, analytics, and support, fully digitizes contact tracing from each employee's mobile device or computer. We discuss the features of the app, how it has been used in the UAE region, and the benefits that the company has realized in automating contact tracing—including faster tracing time, improved accuracy, and greater compliance with UAE COVID requirements.
In just a few months’ time, the app went from an idea to a fully-developed and widely used application—which is now approved for use in company facilities and business units around the world.