bluuebunny/crossref_metadata_2025 huggingface dataset:
Oxidative Stress-Induced Misfolding and Inclusion Formation of Nrf2 and Keap1
Authors: Ngo Vy , Karunatilleke Nadun C. , Brickenden Anne , Choy Wing-Yiu , Duennwald Martin L.
Published: December 2021

Cells that experience high levels of oxidative stress respond with the induction of antioxidant proteins through the activation of the transcription factor Nrf2. Nrf2 is negatively regulated by Keap1 which binds to Nrf2 to facilitate its ubiquitination and ensuing proteasomal degradation under basal conditions. Here, we study protein folding and misfolding in Nrf2 and Keap1 in yeast, mammalian cells, and purified proteins under oxidative stress conditions. Both Nrf2 and Keap1 are susceptible to protein misfolding and inclusion formation upon oxidative stress. We propose that the intrinsically disordered regions within Nrf2 and the high cysteine content of Keap1 contribute to their oxidation and the ensuing misfolding. Our work reveals previously unexplored aspects of Nrf2 and Keap1 regulation and dysregulation by oxidation-induced protein misfolding.
Relativistic Mass of Gravitational Field
Authors: zhu yin
Published: December 2021

It is discovered that the gravitational field on the surface of a neutron star is with a relativistic mass density of 2.65*1016~5.87*1018kgm-3 which can be larger than the mass density of the neutron star (~1017kgm-3). And, the total relativistic mass of the gravitational field of the Sun is ~107 times the mass of the Sun. For different stars, the relativistic mass of the gravitational field is larger as the mass density of the star is larger. In the Milky Way, the total relativistic mass of the gravitational fields is much larger than the total mass of the stars, planets and gas. And, the relativistic mass density of the observed strongest magnetic field is 2.17*108kgm-3. This discovery should be a new frame to understand the fundamental problem of physics.
One-Point Statistics Matter in Extended Cosmologies
Authors: Gough Alex , Uhlemann Cora
Published: December 2021

The late universe contains a wealth of information about fundamental physics and gravity, wrapped up in non-Gaussian fields. To make use of as much information as possible it is necessary to go beyond two-point statistics. Rather than going to higher order N-point correlation functions, we demonstrate that the probability distribution function (PDF) of spheres in the matter field (a one-point function) already contains a significant amount of this non-Gaussian information. The matter PDF dissects different density environments which are lumped together in two-point statistics, making it particularly useful for probing modifications of gravity or expansion history. Our approach in Cataneo et. al. 2021 extends the success of Large Deviation Theory for predicting the matter PDF in ΛCDM in these “extended” cosmologies. A Fisher forecast demonstrates the information content in the matter PDF via constraints for a Euclid-like survey volume combining the 3D matter PDF with the 3D matter power spectrum. Adding the matter PDF halves the uncertainties on parameters in an evolving dark energy model, relative to the power spectrum alone. Additionally, the matter PDF contains enough non-linear information to substantially increase the detection significance of departures from General Relativity, with improvements up to six times the power spectrum alone. This analysis demonstrates that the matter PDF is a promising non-Gaussian statistic for extracting cosmological information, particularly for beyond ΛCDM models.
Effects of Dietary Organic and Inorganic Sulfur on Laying Performance, Egg Quality, Ileal Morphology, and Antioxidant Capacity in Laying Hens
Authors: Kim Yoo Bhin , Lee Sang Hyeok , Kim Da-Hye , Lee Hyun-Gwan , Choi Yongjun , Lee Sung-Dae , Lee Kyung-Woo
Published: December 2021

The present study was conducted to investigate the comparative effects of organic and inorganic forms of sulfur, methyl sulfonyl methane (MSM) and sodium sulfate (SS), on laying performance, egg quality, ileal morphology, ileal volatile fatty acids, and antioxidant and stress markers in various biological samples in aged laying hens. A total of 144, 73-week-old Lohman Brown-Lite laying hens were randomly assigned to one of three experimental diets: basal diet (CONT), CONT + 0.2% MSM (MSM), and CONT + 0.3% SS (SS). The trial lasted for 12 weeks. MSM and SS groups contained 0.07% of sulfur, either organic or inorganic. Dietary MSM did not affect egg production and feed conversion ratio at 12 weeks compared with the CONT group. Dietary sulfur did not affect egg quality except for Haugh unit at 4 weeks which was lowered (P < 0.05) in the SS group. Compared with the CONT group, higher (P < 0.05) villus height and crypt depth ratio was observed in the SS group. None of dietary sulfur affected the percentages of short-chain fatty acids in the ileum. Total antioxidant capacity of liver increased (P < 0.05) in laying hens fed MSM- and SS-added diets compared with the CONT group. The MSM and SS groups lowered (P < 0.05) malondialdehyde (MDA) concentration in serum samples compared with the CONT. Finally, dietary MSM had the lowest (P < 0.05) MDA concentrations in yolk samples. Taken together, our study showed that dietary organic and inorganic sulfur have positive effects on ileal morphology and antioxidant capacity in laying hens. However, SS-mediated inhibition in laying performance needs to be clarified.
Experimental investigation of the generator mode for a brushless dc motor at an increased rotational speed
Authors: Kortunov Vyacheslav , Masliennikov Andrii , Yehorov Andrii , Duniev Oleksii
Published: December 2021

This article deals with a commercially available direct drive brushless DC motor that was investigated in the generator mode at an increased speed above the rated one. During the conducted experiments the increase of the generator rotational speed was carried out due to a three-phase asynchronous motor with 5.5 kW rated power and 2920 rpm rated speed, which was further increased by a two-stage belt gearbox with a reduction ratio from 0.16 to 1.6. However, with an increase in the rotational speed, the magnetic losses also increase, which in turn increase the required value of the input mechanical power and lead to thermal overload of the brushless DC machine. An increase the generator rotational speed leads to an increase of the EMF value and, at the same value, of the stator current, leads to an increase the generated power. Throughout the experiment, the voltage was rectified using a diode bridge and bulk capacitor, after that it was connected to a load resistance. The presented calculations of the magnetic power losses for different electrical steel grades clearly demonstrate the nonlinear dependence between the magnetic field frequency and its magnitude. Experimental studies were carried out at different speeds of rotation of a brushless DC machine in a very wide range from 140 rpm to 5228 rpm, moreover, the values of the output power were obtained depending on the rotational speed. It is concluded, that in the generator mode of the brushless DC machine, it is necessary to take into account the feature of the operation at wind power plants, autonomous power supply such as hybrid power plants. In the first case, it is worth limiting the rotational speed from the driven mechanism, and in the second case, this mode of operation may be necessary for partial boosting of output power for short-term use.
Experience of implementation in educational process modern technologies of FDM 3D printing
Authors: Andrienko Petr , Vasilevskij Vladimir , Vittsivskyi Ivan
Published: December 2021

Fused Deposition Modeling is an additive manufacturing technology where a temperature-controlled head extrudes a thermoplastic material onto a build platform in a predetermined path. Standard, advanced thermoplastics and composites are used for printing. Among the areas of application for FDM printing, the main ones are rapid prototyping, as well as small-scale and batch production. The purpose of the work is the implementation of FDM 3D printing technology in the educational process of students in specialty 141 "Electroenergy, electrotechnics and electromechanics". The features of the technology of additive manufacturing of electrical apparatuses parts by the method of FDM printing have been investigated. Parts of four standard sizes were printed using ABS + and PLA plastics, namely, current transformer carcasses in the amount of 110 pieces and sensor bodies in the amount of 100 pieces. For printing, an FDM 3D printer was used built on the XZ Head Y Bed kinematic scheme with an open working chamber. The analysis of defects in finished products was carried out, which showed that the main defects are deviations of the actual dimensions and geometric shape of the finished products. Ways to prevent the occurrence of these defects are considered, namely, correcting the size of the model at the stage of preparing the model for printing, minimizing the filling density of the model, using brims in models, setting the optimal temperature of the working platform and simultaneously printing several products. The results of the study o features of the technology of additive manufacturing of electrical apparatuses parts by the method of FDM printing made it possible to develop a set of laboratory works for students of the specialty 141 "Electroenergy, electrotechnics and electromechanics".
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

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.
Significance and Challenges of Physical Security in Oil & Gas
Authors: Mookonil Vijay
Published: December 2021

Objective

The objective of this paper is to provide a general understanding and awareness of the physical security requirement in Oil & Gas Industry, explore various Physical security solutions and how the same is different from Network Security and highlight its importance followed by explaining how same can be achieved in industrial environment by implementing different layers of security measures.
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

In 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

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

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

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

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

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

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

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.
Numerical Simulation of Gas Lift Optimization Using Artificial Intelligence for a Middle Eastern Oil Field
Authors: Al-Janabi Mohammed Ahmed , Al-Fatlawi Omar F. , Sadiq Dhifaf J. , Mahmood Haider Abdulmuhsin , Al-Juboori Mustafa Alaulddin
Published: December 2021

Artificial lift techniques are a highly effective solution to aid the deterioration of the production especially for mature oil fields, gas lift is one of the oldest and most applied artificial lift methods especially for large oil fields, the gas that is required for injection is quite scarce and expensive resource, optimally allocating the injection rate in each well is a high importance task and not easily applicable. Conventional methods faced some major problems in solving this problem in a network with large number of wells, multi-constrains, multi-objectives, and limited amount of gas. This paper focuses on utilizing the Genetic Algorithm (GA) as a gas lift optimization algorithm to tackle the challenging task of optimally allocating the gas lift injection rate through numerical modeling and simulation studies to maximize the oil production of a Middle Eastern oil field with 20 production wells with limited amount of gas to be injected. The key objective of this study is to assess the performance of the wells of the field after applying gas lift as an artificial lift method and applying the genetic algorithm as an optimization algorithm while comparing the results of the network to the case of artificially lifted wells by utilizing ESP pumps to the network and to have a more accurate view on the practicability of applying the gas lift optimization technique. The comparison is based on different measures and sensitivity studies, reservoir pressure, and water cut sensitivity analysis are applied to allow the assessment of the performance of the wells in the network throughout the life of the field. To have a full and insight view an economic study and comparison was applied in this study to estimate the benefits of applying the gas lift method and the GA optimization technique while comparing the results to the case of the ESP pumps and the case of naturally flowing wells. The gas lift technique proved to have the ability to enhance the production of the oil field and the optimization process showed quite an enhancement in the task of maximizing the oil production rate while using the same amount of gas to be injected in the each well, the sensitivity analysis showed that the gas lift method is comparable to the other artificial lift method and it have an upper hand in handling the reservoir pressure reduction, and economically CAPEX of the gas lift were calculated to be able to assess the time to reach a profitable income by comparing the results of OPEX of gas lift the technique showed a profitable income higher than the cases of naturally flowing wells and the ESP pumps lifted wells. Additionally, the paper illustrated the genetic algorithm (GA) optimization model in a way that allowed it to be followed as a guide for the task of optimizing the gas injection rate for a network with a large number of wells and limited amount of gas to be injected.
Optimizing Location of CO2 Recovery Units
Authors: Dutt Indrajit , Allamaraju Jagannathrao
Published: December 2021

In line with ADNOC Sustainability policy, reduction of GHG emissions, AGP has initiated projects for recovery of CO2 from existing plants. The extracted CO2 is planned to be used for Enhanced Oil Recovery. The current paper highlights method used for evaluation of various location and technology options for implementation of the new CO2 recovery units, considering existing plants flow schemes along with their interfaces and associated challenges.

Key Performance Indicators (KPIs) were identified based on Inherent Safety, Economics, Technology Maturity, Product Quality, Operability / Flexibility, Constructability. Identified options were further developed and subsequently evaluated based on preliminary economic analysis and available technical information. Accordingly, weighted scores of the KPIs developed for option selection. Major criteria used for ranking were unit cost of CO2 product, adherence to required H2S and COS specifications, technology maturity and deployment in industry.For one location, the options considered included installation of new Acid Gas Removal Unit (AGRU) upstream of existing AGRU, revamp of existing Acid Gas Enrichment Unit (AGEU), new AGEU, and direct feed of Acid gas to new CO2 recovery unit to supplement falling upstream reservoir profile.For another location, the options included new CO2 recovery plant upstream of existing Sulphur Recovery Unit (SRU) or downstream of existing Tail Gas Treatment Unit (TGTU), compression of TGTU gases upstream of proposed CO2 recovery unit, installation of new unit downstream of existing incinerators, combination of CO2 recovery units of both plants, were also assessed.In addition, new CO2 Dehydration and Compression units considered to meet CO2 product specifications and B/L requirements.

Based on project requirements, physical methods of CO2 removal like membranes and molecular sieves deemed unsuitable. Further to discussions with various licensors, emphasis remained on chemical and physical solvent technologies. Based on assessment, solvent swap for AGEU (upstream of existing SRUs) with reduced lean solvent temperature at one location, solvent swap in TGTU followed by a new polishing unit at another location combined with common high pressure compression facility, was selected for engineering development.
Drilling Automation – Benefits of the New Drilling Model
Authors: Heredia Jorge , Tengesdal Jan Egil , Hobberstad Rune , Marck Julien , Kleivenes Harald , Ngueguim Marcel Emile
Published: December 2021

A pilot program for automated directional drilling was implemented as a part of the roll out plan in Norway to drill three dimensional wells in an automated mode, where steering commands were carried out automatically by the automation platform. The rollout plan also targeted the use of remote operations to allow personnel to be relocated from the rig location into remote drilling centers.

The goal of the program was to optimize the directional drilling performance by assessing the benefits of automation using the latest rotary steerable system technologies and machine learning smart algorithms to predict and manipulated the BHA performance, as well as the ability to predict the best drilling parameters for hole cleaning.

The automation was implemented on three different rigs and the data was compared with the drilling performance from the last two years, with three dimensional wells drilled in the conventional method.

The main benefits between drilling wells in the conventional method versus drilling wells with the new drilling automation model include the following.

Reduce the overall cost per meter –  Improve the rate of penetration –  Improve running casings Consistence process adherence –  Reduce human errors –  Reduce POB without sacrificing lost of technical experience Optimize workforce resources –  Allows continuity of service (COVID-19 restrictions)

Drilling automation can drill smoother wells by reducing the friction factors and tortuosity. This is translated in direct cost savings per meter and reduction in the overall well delivery time, with the advantage of performing the execution and monitoring of the well performance remotely.

This new drilling model open the door of new opportunities, especially for the challenges where the work force resources, and drilling performance is a priority for the operations.
Upgrade of Plate Heat Exchanger at Optimal Cost Through Core Pack Plate Welding Modification
Authors: Al Khoujah Khaled M. Mazen , Medina Antonio - , Al Qaydi Juma Rashid , Kaleem Jawwad , Al Mansoori Fatima Hassan , Nisar Muhammad , Lentz Markus
Published: December 2021

An innovative design was implemented as a solution for the repetitive failure of a plate heat exchanger installed at Gas Processing Facilitates due to weld cracking, the new design was introduced for the first time in the facility, demonstrating the novelty of utilizing new technologies and enhanced designs in Heat Exchangers used for gas processing. The main challenges were in accommodating various operating modes and ensure the prevention of reoccurrence of the failures. The success was achieved through the collaboration between the operating company and Industry experts in heat transfer equipment to replace the existing design at the gas processing Facilitates with no change in piping layouts, hence, performing the replacement at optimal cost and maximum benefit.
Maximize Asset Utilization by Effectively Identifying and Removing Bottlenecks
Authors: Nagwani Dheeraj , Al Katheeri Sara
Published: December 2021

ADNOC Gas Processing Ruwais NGL Fractionation plant receives and fractionates the NGL produced in upstream gas processing plants. After operation of newly designed upstream NGL plants, composition of NGL feedstock has become richer in Ethane and Propane. Consequently, nameplate capacity were reduced by~25%. In view of future increased NGL production, nameplate capacity of fractionation trains needs to be re-instated. Alternatively, a new fractionation train needs to be installed to accommodate additional NGL.

To explore the opportunity for maximum utilization for existing trains, in line with the ADNOC strategy of enhancing profitability and asset utilization, a technical study was conducted to increase the processing capacity back to original nameplate capacity with lighter NGL composition. This was to identify the potential bottlenecks in the facility and suggest debottlenecking options with a reasonable investment.

The Technical study covers the following activities:

Simulation:

Rigorous process simulation including the licensor units of DEO/Propane amine units

Adequacy checks and identification of bottlenecks: Line sizing adequacy check and detailed hydraulic evaluation of the major piping Equipment adequacy check Relief & blowdown and flare system adequacy check Proprietary equipment/design evaluation of licensed units Adequacy check for In-line instruments like control valves, flow elements/transmitters, thermowells Rotating equipment adequacy checks performed with the concurrence from OEMs. Licensor Endorsement: Obtained the endorsement of AGRU licensor (Shell) for the increased flow rate with revised contaminant levels with recommendations of removing identified bottlenecks. Bottlenecks mitigation: Various options for bottleneck mitigation was studied and most optimum solution was selected to remove the identified bottleneck.

The study has concluded that current capacity limitation was mainly due to bottlenecks in Ethane loop. Therefore, by mitigating the identified bottlenecks (i.e. replacing lines with bigger size, providing high performance trays, high performance internals, replacing few equipment's with new one etc.), the original nameplate capacity can be re-instated.

The study concludes that increased NGL forecasted flow with lighter composition could be processed in existing Ruwais fractionation trains by doing minor modifications (as compared to new train).

A capacity increase of ~25% was achieved with minimum investment and requirement of new fractionation train could avoided.

If extensive adequacy studies are carried out to identify the bottlenecks, the capacity enhancement in existing facilities can be achieved with minimum investment and major cost for new plants/trains can be avoided.
A Comparative Emissions Assessment - Drill Cuttings Treatment Alternatives
Authors: Innes Gareth , Nesse Steinar , Eia Jan Thore
Published: December 2021

The offshore industry has for many years been cognisant of its impact on the marine environment. Since 1991, strict regulations relating to oil-based drill cuttings discharge have been in force in the signature countries to the OSPAR (Oslo/Paris) Convention. As the impact of greenhouse gas (GHG) emissions on climate change has become better understood, global carbon dioxide (CO2) emission reduction targets and how to meet them have risen up operators’ agendas. Offshore operations, which involve marine logistics, are also subject to limits on nitrogen dioxide (NOx) emissions, an indirect GHG that's toxic to humans and contributes to soil and water acidification. The choices that operators make today in how they operate, including the disposal of drill cuttings, must therefore address an increasing number of environmental and climate targets, in addition to health, safety and cost.

This paper will outline the results of a comparative study between the offshore processing of drill cuttings and relevant conventional alternatives, including skip and ship, bulk transfer and cuttings reinjection (CRI). It is the first paper to show a direct emissions comparison between offshore processing and all other alternative methods for drill cuttings processing. The study assessed the carbon footprint and NOx emissions for each of the different alternatives for the treatment of drill cuttings. The values were then used to create an interactive emissions calculator that can be easily applied to specific projects to clarify the actual potential for emissions reduction within the drilling waste management process.

A number of case studies were then run, comparing the different alternatives. For the examples run, the comparative assessment showed that wellsite thermal processing technology was the favourable alternative in terms of emissions, with an emission reduction in the order of 14 - 48%, compared with the onshore alternatives. Emissions of the alternatives, skip and ship and bulk transfer, were highly dependent on sailing and road transport distances, as well as power source for the onshore treatment facility. The assessment showed that CRI has the highest emissions of CO2 per tonne of cuttings. Alternatives involving onshore treatment had the highest NOx emissions when sailing distance was high, however this was highly dependent on the machinery and fuel source of the transport vessel - and for the offshore alternatives, the on-site energy production solution.
First Successful Smart Liner Deployed in a Side-Tracked Gas Well, Offshore Abu Dhabi
Authors: Ladmia Abdelhak Mohamed , Alhammadi Hamdan A , Draoui Dr. Elyes , Mogensen Dr. Kristian , Al Hosani Fahad Mohamed.M , Edmonstone Graham , Aldhanhani Ahmed Mohamed , Ballaith Faisal Jamaan , Mohamed Ayman , Juvarajah Navindran
Published: December 2021

This paper presents a summary of the deployed Smart Liner- SL equivalent to the Limited Entry Liner- LEL as lower completion for the first time in a sidetracked Gas well, Offshore Abu Dhabi. R-1 is subdivided into several sub-layers, the reservoir properties are characterized by low porosity & low permeability (Tight). Reservoir quality in the Upper part is better in terms of porosity & permeability than the lower part. The gas production is mainly from top part of R-1 reservoir, no contribution from Lower part. In 2017, Data gathering was conducted on well A-1 (Coring, Logging & Pressure Points). Actual Gas production Offset wells are restricted from optimal production due to Well Integrity Sustainable Annulus Pressure, to compensate the restricted aged wells due to Well Integrity, Gas production can be increased to 3 times using SL as a stimulation method.

The Smart Liner was selected as a lower completion and as a stimulation method for better flow distribution, improved well performance, effective Acid stimulation, also to ensure hole accessibility, allowing aggressive bullhead stimulation at high rate/pressure and high acid concentration at less time ~ 1.5days/job, in addition to eliminating high risk and high cost Coiled Tubing (CT) intervention for stimulation.

The first step was to design the SL Completion Workflow with a representative well trajectory for the selected well to be fed and reservoir properties to be extracted from the dynamic model, and then to create a representative stimulation model utilizing property numerical software with all possible scenarios; open hole that represents PPL and suggested SL compartmentalization and holes distribution based on reservoir parameters along the lateral. Once the well model is created, different scenarios for different completion designs are to be run versus different acid concentrations and volumes till achieving the optimum results from stimulation point of view in addition to formation and facilities limitations. Drilling operations were very challenging; fortunately, we succeed to deploy the SL after final adjustment based on FMI Natural Fractures. The Smart Liner as stimulation has proved to be a cost-effective solution for gas wells comparing to advanced stimulation methods in addition to eliminating the high risk and high cost of the Coiled Tubing (CT) intervention for stimulation a huge savings in well construction with maximizing performance.