bluuebunny/crossref_metadata_2025_split huggingface dataset:
Automated Fluid Rheology Measurement at the Drillsite
Authors: St.Michel Nathan , Xu Jianhui James , Harrist Jonathan , Zhan Guodong David , Aljohar Abdulwahab 
Published: October 2022

Abstract
With the increase of automation and process control requirements, a good real-time grasp of the drilling fluid rheology has repeatedly been flagged as a key requirement. Unfortunately, drilling fluid rheology is still mostly measured manually and reported only twice a day. Fluctuations in fluid composition and rheology due to wellbore/fluid interaction and temperature/shear/solids effects are generally missed.
This paper describes the field implementation and testing of an inline-design pipe rheometer that operates autonomously to continuously measure rheological properties of the drilling fluid in the rig's mud tanks. This data can be used to monitor the stability or indicate changes in these drilling fluids. The system employs a progressive cavity pump to draw drilling fluid from the mud tank and propel it, at varying controlled rates, through two different sizes of pipe. Differential pressure transducers are used to measure the pressure drop over a fixed length in each size of pipe, and this data, along with flow rate, is used to calculate fluid viscosity. All components are installed within a standard ISO shipping container for ease of transport and deployment at the wellsite. It is positioned next to the mud tanks where it continuously samples and measures the drilling fluid.
Field test results of the system are presented. The system was operated autonomously on location in Saudi Arabia for an entire drill stage (3.5 days) of 5-7/8" section for gas drilling. In this section, oil based mud was used and measured by the system. The system was controlled remotely via WiFi connection. During the test period, manual viscosity and density measurements were also taken using the Fann-35 and mud balance methods. Subsequent comparison shows excellent agreement between the automated and manual measurements.
Get Better Data to Drive Production Gains in Tight Gas Reservoir Through an Automated Multiphase Measurement Skid and Production Engineering Workflow Integration
Authors: Theuveny Bertrand Claude , Garay Andrade Carlos , Sanz Vera Julio , Salas Fabian , Pucci Claudio , Castro Alejandro 
Published: October 2022

Abstract
A novel implementation of an economical, self-sustainable and environmentally friendly solution for tight gas field production monitoring in a remote location in Tierra Del Fuego, allows early-stage production measurements necessary in the unconventional reservoir analysis for the field recovery process optimization
The paper demonstrates the gains obtained with the deployment in 12 pads of an automated well testing multiphase metering skids for enhancing the efficiency of production engineering workflows.
The replacement of traditional test separator and test manifold with a fully automated multiport selector valve manifold and a multiphase flowmeter enables a number of new production monitoring and surveillance workflows that can lead to additional production, while lowering both the capital expenditure and the operational costs.
The enhanced data coverage and data quality provides reliable input to advanced engineering processes. The high level of repeatability provided by the multiphase flowmeter establishes a strong foundation for systematic, automatable workflows.
We demonstrate the robustness of the data quality over time with the introduction of new indicators that can be automatically computed and deliver input to more evolved information algorithms.
Beyond the reduction of capital expenditure of 11% and gains over 1100 man-hours per year per installed pads, we enable a number of production insights that translate in better reservoir management and production practices. High quality rate transient analysis can be performed leading to reliable outputs that leads to actionable decisions.
Only few papers demonstrate actual multiphase flowmeter performance in tight gas fields and details how reliable production data is used on a daily basis to enhance reservoir management practices and leads to production optimization.
The definition of new quality indicators on the data streams enables the feed to advanced algorithms and leads to enhanced automation of field management processes.
Finally, we document and estimate the significant reduction on emissions enabled by the deployment of the multiport selector valve manifold and multiphase flowmeter.
Pipeline Integrty Management and the Invent of Analytics for Corrosion Threats
Authors: B. M. Ali M. Nazmi , B. M. Tuselim Ahmad Sirwan , B. Abu Bakar M. Hisham , Kalam Azad M. Fithri Azad B A. , M. Fuzi Nurazzura Binti , B. M. Suhot M. Afiq 
Published: October 2022

Abstract
PETRONAS Pipeline Predictive Analytics for Corrosion (PrAnCorr) is a cutting-edge cloud-based innovation that uses big data from near real-time operating data to predict internal and external corrosions for onshore and offshore pipelines. The technology which made up of multilayer system architecture allows seamless data integration which transform the traditional method of managing pipeline integrity from one where pipelines are typically inspected every 5 years to one in which pipeline corrosion behavior can predicted on near real time, thus reducing dependency of having in line inspection.
The motivation of the development which began in 2019 was derived from significant increasing trends of OPEX spending to control and monitor corrosion development and production losses due to corrosion failures. The formation of multidisciplinary team within PETRONAS had demonstrated proven results for a comprehensive life cycle machine learning system through collaborative efforts.
The system is powered by 2 main processing engines namely iCON (process simulation tool) as a real-time process simulation engine and Machine Learning engine. The prediction utilizes more than 13 operating variables simultaneously generated through integration from various data sources within i-PIMS (PETRONAS Integrated Pipeline Integrity Assurance Solutions) system, capable to perform continuous data ingestion & cleaning which eventually revealed corrosion behavior along the pipelines.
PrAnCorr was successfully deployed in March 2021 as a module in i-PIMS application and has already been used to predict corrosion for various pipeline system i.e., dry gas, multiphase, wet gas, condensate etc. The establishment of PrAnCorr is a significant step forward in the achievement of pipeline integrity performance, especially given that the potential savings derived from optimization of I&M. The positive value creation is estimated for long term application by 20% OPEX reduction over the life cycle. PrAnCorr is prospective for PETRONAS as a future of pipeline integrity solution that spans the company's operations with the capability from obtaining a quality pipeline real-time condition to subsequently performing integrity assessments.
Optimizing Extended Reach CT Intervention Efficiency with Increasingly Complex Operating Environments in Vaca Muerta, Argentina
Authors: Delgado Eduardo , Bivens Eric , Cuevas Stefania , Di Nardo Jose , Lorca Francisco , Beauregard Mario , Lock Benjamin , Godoy Soledad , Salazar Namir 
Published: October 2022

Abstract
Wells in the Vaca Muerta field have consistently hosted an array of technical challenges from downhole conditions in the extended lateral section, including casing collapse or restrictions developed during the hydraulic fracturing phase. With these factors in mind, an initiative was made to implement key operational parameters to improve efficiency during Coiled Tubing (CT) operations without sacrificing (Health, Safety, and Environment) HSE or (Service Quality) SQ during the completion life cycle associated with unconventional activities.
Operational optimizations based on ongoing diagnostic, design and delivery of CT well interventions are shown in this paper through a chronological compilation of 45 wells in 12 pads. Initially, CT milling job times were defined based on the minimum and maximum speeds while running in and pulling out of the hole, circulation fluid parameters to ensure turbulent flow and parameters for gel sweeps and wiper trips. Subsequently, a series of reviews of the data collected from operations was implemented, and the focus was shifted to operating times at the different job stages. This was followed by stream mapping the personnel and equipment assigned to each specific activity.
Additionally, Key Performance Indicators (KPIs) were defined, such as CT speed between the surface and the kick-off point, average speed between plugs, plug milling time, and time to return to surface while pulling out of the hole.
This journey to efficiency has been achieved by systematically introducing continuous improvements into our operations, utilizing on-site field personnel as the main driver and the engineering team as support, monitoring the execution, and taking action when needed.
After servicing 45 wells across 12 locations over two years, an 11% reduction of the total time in the well during frac plug mill out has been achieved. Considering that the lateral length of the wells and the number of stages has increased by 52% and 41%, respectively, this has enabled significant cost savings in a safe and effective way.
Operational efficiency has to be aligned with contemporary advances in the industry. As completion strategies evolve, so must our intervention methods. This paper documents how the completion life cycle of wells in a challenging, unconventional environment has been reduced through customized well interventions with CT.
Sulfur Deposition Phenomena in Gas Systems and Lessons Learnt
Authors: Gouhar Hatem Hamed , Ekaabi Abdulla Ahmed , Andru Prabhakar Reddy , Al Teneiji Bader Abdulla 
Published: October 2022

Abstract
This study is aiming to conclude the root cause of elemental sulfur formation in the Gas handling facilities for an Oil field development facilities. The study focuses on supporting the concluded root cause by actual field trials. Practical short-term, midterm and long term solutions were studied and recommended including an optimization strategy to maximize utilization of existing facilities. The lessons learned for future projects were listed to overcome and manage the elemental sulfur formation issue.
It was suspected that the root cause is related to potential oxidation of H2S due to the oxygen ingress associated with the generated nitrogen in the recycled low pressure gases. The study findings were achieved using actual field trials by either increasing the purity of the nitrogen source or by flaring (i.e. not recovering) the low pressure gases and monitoring changes in the operating conditions and the tendency of elemental Sulfur deposition for different N2 Purity levels. Accordingly, the mitigation measures were studied, assessed and the required modifications to overcome the problem are recommended.
The first field trial was conducted considering flaring low pressure gases and increasing the nitrogen purity from 97 % to 99.8 %. The second field trial was conducted considering only increasing the nitrogen purity to 99.8% without flaring. For both field trials the tendency of Sulphur deposition was monitored in the Gas lift system and findings were recorded. The nitrogen purity was reduced gradually from 99.8 % to test implications on operation and note the nitrogen purity level at which Gas lift choke valves and Gas lift/ gas injection compressors are chocked by the elemental sulfur formation.
According to the results of the field trials, the H2S oxidation due to the oxygen levels in the nitrogen stream was confirmed as the root cause for the elemental sulfur formation. All the lessons learnt to be considered at different stages of any project were captured and summarized in a typical checklist for the design of similar facilities at each project stage.
De-Salting Train Transformers Retrofitting and Optimization Study to Achieve Flexibility and Efficiency in Saudi Aramco
Authors: Bajuaifer Hatem A. , Khan Ashiff , Mutairi Khaled N. , Kothawala Amir A. 
Published: October 2022

Abstract
This paper covers and evaluates a retrofit work for desalting trains grids in Saudi Aramco Khurais facility to accommodate water cut increases due to field maturity. The main objective of this retrofit work is to accommodate the increase in water cut (emulsified and free water) while enhancing the de-salting process with minimum modification scope and cost effective approach.
This Paper is intended to:
Presents the retrofit basis and compare old and new grids design. Presents the results of this optimization study along graphical representations. Highlights how this initiative increased the desalting trains efficiency and redundancy.
The basic concept of the retrofit work is to change the grids in electrostatic separation vessels from the conventional tapered configuration to straight configuration. The original configuration was tapered configuration that is intended to maximize separation and balance the load on all transformers however the limitations of this configuration is in case of one grid shorted all other transformers will be shorted. Despite the available transformers capacity, however as the water cut increases the chances of water carry-over increases as well as emulsions which results in multiple outages of de-salting trains. Straightening the grids will help avoiding total outages of the transformer, so in case of one grid shorted, other two grids will be running with a higher load which provides redundancy, reliability and guaranteeing the quality targets.
This modifications were evaluated from safety, process, electrical and cost life cycle point of view and assessed post retrofitting for 1 year against there pre-defined success majors that includes:
Outage hours of dehydrator and/ or de-salter (Target less than 5 hours per quarter). Demulsifer chemical consumptions (Target reduction by 10% or more annually) Quality specification (Target maintaining BS&W and Salts within crude specifications of 0.2% and 10 PTB respectively even in case of 1 or 2 transformers shorted.
This modifications succeeded in achieving the predefined targets in addition to a cost saving equivalent to US$ 120,000 due to demulsifer injection reductions (i.e Regular and emergency dosage).
Figure 1 shows the change in grids configurations before and after retrofit work
Using a Hybrid Off-Grid Semi-Fixed Solar System to Power a Water Pump in a Water Supply Well in Remote Areas
Authors: Ruheili Sharifa Mohammed Al , Mahrami Khansaa Hamed Al , Wardi Khalid Hamood Al , Hashmi Mohammed Marhoon Al , Al-Jaaidi Omar Salim 
Published: October 2022

Abstract
ARA Petroleum Exploration and Production Company has successfully installed a hybrid off-grid semi- fixed solar system to power an Electrical Submersible Pump (ESP) for a water supply well in Oman's remote area (Oil North Field). The system is designed to provide the power output of a 40 KW water ESP pump. The pump usually runs for 10 hrs/day. The well is used for supplying water for drilling activities and other operational requirements with an actual power of 30 KW.
The uniqueness of this system is its ability to power the ESP well directly without an over-headline (OHL) with a synchronizing system and an automated switchover to a diesel generator when required. Moreover, a real-time operation system that can be downloaded on a mobile application. In addition, a CCTV camera, and solar lighting are available in the location to control and monitor the performance of the solar system.
Utilizing solar systems in this project provides a cost saving on diesel consumption and reduces its associated CO2/GHG emissions. The system runs in the daytime on solar for 6 hours. The rest of the 4 hours is compensated with diesel. The anticipated cost saving on diesel consumption and CO2 emission reduction is around 60%. The success of this project will allow the technology to be replicated in many locations in remote areas.
In order, to support the ICV and develop SME companies, the project was awarded to a local SME company, and the learning from this installation was shared between the vendor and ARA E & P, as this system was the first of its kind implemented in Oman.
Field Water Management Using Inline Water Separation
Authors: White Ramsey James , Alghunaimi Fahd I , Aljuryyed Norah W 
Published: October 2022

Abstract
Increasing water-cuts is inevitable for mature oil fields in which water flooding is used to achieve higher recovery targets. As water rates increase, significant investments are required to debottleneck water handling facilities and pipelines. This paper summarizes a detailed assessment to find the benefits of implementing a separation process to improve water separation efficiency. Inline Water Separator is considered here to optimize capital expenditures, building on the experience of a field demonstration of the technology.
A prototype pilot plant was installed demonstrating an Inline Water Separator technology. Using a set of different inlet conditions. The technology was able to achieve +70-80% separation efficiency and deoiled the water to a maximum oil-in-water concentration of 35 ppm reaching lower than the accepted oil in water discharge criteria for reinjection (Zhang et all). Building on the success of the prototype, a suggested roadmap was studied to expand the testing of the technology at further harsher conditions with heavier crude grades and test alternative Inline Water Separation Technologies. A business case assessment was also conducted to determine the feasibility of the Inline Water Separator solution versus conventional water handling upgrades.
Alternative Inline Water Separator technologies were also looked at as modularly designed skids that are easily transportable. The skids can be installed at different locations such as remote well manifolds or immediately pre-inlet processing facility. A technical and economic assessment of Inline Water Separator was conducted. It was found to be an economically attractive alternative to implementing conventional extensive oil-water separation, crude oil desalting, water deoiling & injection and pipeline network upgrades. The benefit of IWS besides reduction in capital expenditures, enhanced oil-in-water and a reduced overall energy and chemical consumption also results in reduced operating expenditures. When IWS is installed at the well manifold the stud shows a that the water rate will be reduced in the trunkline downstream the inline water separator and therefore a reduce the backpressure on the well will accrue, which can potentially increase the oil rate. Another benefit that was found, this design will potentially enhance distribution of field water injection as separated water from the inline water separator can be rerouted to another desired location or flank.
The study of the Inline Water Separator technology portfolio expansion is highly recommended as a strategy to optimize capital expenditures to manage increasing produced water rates. The paper provides the alternative solutions, potential benefits and business case assessment to justify potential deployment.
Early Detection of Compressor Liquid Carryover Enhanced by Multiple Facilities Monitoring
Authors: Pezzola Mattia , Turconi Fabio , Gamboa Ortiz Alfredo , Beduschi Francesco , Mosca Alessandro 
Published: October 2022

Abstract
This work aims to present a methodology based on a proactive approach for the early detection of possible liquids carryover towards compressors installed in upstream process plants where the presence of heavy hydrocarbon inside gas stream is a recursive problem. Analyzing trough remote monitoring some parameters of the facilities that are upstream to the compressor and, simultaneously, some machine critical instrumentation that was selected through early detection algorithms, it is possible to develop real time synthetic indicators that warn the possibility of liquid ingestion.
An in-depth analysis of the plant and of the process lines and facilities that are upstream to the compressors, permits to identify the critical parameters to monitor, which unequivocally indicate a change in both physical conditions and gas composition.
This methodology has been applied to create tailor made synthetic indicators that have been implemented in operating sites, to highlight the upset in the process parameters that could have led to liquid carry over with consequent possible mechanical breakdowns. These indicators enhance the deep analysis of these phenomena, resulting in the development of tailored operative adjustment to be applied at the early stage of the liquid carryover occurrence. The combined monitoring both on the upstream facilities and on the on-board instrumentation of compressors allows to have an early detection of the liquid carryover events, giving time to the operators to understand the situation and act accordingly to avoid hazardous conditions.
The methodology innovative feature is the ability to monitor, by remote, a combination of critical parameters at "plant level", together with cross-check trough machine-learning algorithms of the relevant on-board instrumentation at "compressor level" to have a complete picture of the phenomena and prevent the compressors from unplanned damages due to liquid carryover.