bluuebunny/crossref_metadata_2025_split huggingface dataset:
Practical Solution for Rigless Water Shut off Without Using Thru- Tubing Bridge Plug in offshore Gas Lift Well, GUPCO - Egypt
Authors: Abdulmageed Mohamed , Elkordy Aly , Vazquez Maria 
Published: March 2022

Abstract
The Gulf of Suez Petroleum Company (GUPCO) is one of the main production Companies in Egypt. Most of production rate in GUPCO is dependent on gas lift method for lifting reservoir fluid to the surface. Many reservoirs in Gulf of Suez are depletion (solution gas drive); so GUPCO injects about 150,000 BWPD to compensate reservoir pressure, and GUPCO has several active water drive reservoirs which water increasing comes from bottom intervals in some cases. As the water cut increases in the well, water shut off (WSO) is required; based on production logging tool (PLT) data, to avoid water loading (backpressure on formation), allow low quality sand/ intervals to share in production, avoid corrosion of wellbore tubing, and scale build up in the tubing which may cost a lot of money for cleaning.
In general, GUPCO uses thru-tubing bridge plug (TTBP) and capping it with sufficient length of cement column for rigless WSO. As all fields of GUPCO are offshore; so WSO and other jobs are costly in comparison to onshore fields. Based on this, any cost saving, innovation, or idea lead to maximize output in safe manner (e.g. increasing well production oil) is highly appreciated and recommended for execution. Water shutoff techniques are either mechanical methods or chemical methods. These methods can be used individually or together in one job. Mechanical methods are usually used in wellbore WSO, and chemical methods are used in near wellbore (NWB) for plugging perm zones or restricting water flow as relative permeability modifier (RPM) chemical. Water shut off selection depends on many factors as well deviation, well completion type, and others that should be taken in consideration.
This paper details some of the challenges associated with performing conventional WSO using electric-line and how to overcome these challenges. For our interested case, there is no common thru-tubing bridge plug (TTBP) in the market can be set in 9 5/8" and pass through minimum tubing restriction (XN- nipple 2.63" ID). Therefore, the well was planned to perform WSO using CTU with high cost, which is low priority for the time being. The practical WSO method provides solution for these challenges with low cost, and high percentage of success.
Waterflooding Optimisation Using a Multi-Action Technology in the Mature West Siberian Oil Field
Authors: Matveev Sergei , Gazizov Aidar , Shastina Elena , Ishkinov Salavat , Kuznetsov Maxim 
Published: March 2022

Abstract
In mature fields developed by water flooding, oil companies keep trying to fight premature water encroachment in producing wells caused by heterogeneous reservoir permeability and non-uniform displacement front advance. Changes in pressure gradients and flow rates and increased effects of adsorptive, osmotic and capillary forces result in significantly reduced oil permeability and low production from low-permeability intervals.
The chemical technology has been developed for the combined effect of selective water shut-off and change of rock properties from water wet to oil wet or visa versa to form a new phase on the rock surface, which produces significant excess energy used to recover residual oil.
The effectiveness of this technology has been tested in a reservoir modelling laboratory by studying the compatibility between the agents employed and reservoir fluids and flow tests conducted on three areal heterogeneous reservoir models.
Tests have shown that the agents used in the technology retain their functionality at high temperatures of up to 120°C and a formation water salinity of 10–127 g/l with no adverse effect on oil quality. The ultra-fine reagent reducing interfacial tension at the oil-water interface under reservoir conditions to 0.005 mN/m was studied in the laboratory.
Geological and production data show that the main problem of the pilot areas is early encroachment of production wells by injected water because of its breakthrough and subsequent unwanted flow through the most permeable and depleted layers. Tracer studies, conducted in injection wells using tracers that moved through flushed channels towards wells with high production rates and high-water cuts, identified zones of ineffective injection.
Treatments using multi-action technology in four pilot areas of the field produced the following effects: Redistribution of injected water flows by increasing the residual resistance factor in high-permeability zones and redirection of flows into previously inactive reservoir zones.Incremental oil production from four areas over 10 months was 2745 tonnes with a lasting effect.
The novelty of the multi-action technology consists in targeted treatment of oil reservoirs and displacement of residual oil through selective isolation of water-encroached zones. The energy produced at the phase interface is used to separate film-bound oil, move globular oil through pore throats and increase oil flow rate and oil permeability in the reservoir irrespective of its geological and mineralogical characteristics or formation fluid properties.
Successful Implementation of FAL in PDO Gas Wells
Authors: AlYhayaai Faisal , Veeken Cornelis , Razvi Mohammed , Ardia Kusela , AlDaraai Thabit , AlKindi AlMuntaser 
Published: March 2022

Abstract
Saih Nihayda (SN) cluster is one of Petroleum Development Oman (PDO) gas assets that contributes by ∼25% out of the overall PDO gas asset's production. SN Deep is one of the biggest SN cluster fields, which was brought on stream since 2006 and started seeing water breakthrough and liquid loading as some of the late field life challenges. This paper provides an overview of successful application of foam-assisted lift (FAL) for deliquification in some wells in SN Deep field that suffered from water production where their production & uptime were heavily impacted. This paper sheds light on the challenges associated with the successful implementation of FAL in SN Deep.
Qualitative & Quantitative Digital Frac Platform for Reservoir Stimulation Operations in Oman Fields
Authors: Al Hinai Adnan Saif , Florez Juan Chavez , Al Hinai Mohamed Said , Al Raisi Khalid Hassan , Budur Guru P. , Gopalappa Anandraju , Al Ghaithi Ali Mohammed 
Published: March 2022

Abstract
The ultimate goal of hydraulic stimulation in terms of business value is "production", especially in those cases where the well is approaching the economic limit, is to increase the hydrocarbon flow, improve the ultimate recovery and make it profitable.
During a sing stage fracturing operation, extensive data is produced. Unfortunately, less than 10% of the data are properly preserved. Finally resides in corporate repositories. Comparable is the case of knowledge, where just in few cases, previous lessons learned are taken into consideration when designing a new job. Data Quality and human talent dedication are not the exception; data completeness levels of just 40% has been estimated. While Production Technologist and Frac Engineers during a normal Frac design, dedicate nearly much of their time on searching for data.
It was identified the need for having a centralized database, and avoid the dissemination of "local" customized spreadsheets to track the fracturing activities. At the same time, there were no fracturing workflow identified, instead, multiple version depending on each well/cluster approach. Hydraulic Fracturing Project emerged as a corporate initiative to support the HF evolution, and the vision to provide the business the best tools (knowledge, standard process, data, and technical resources) to get the maximum benefit from this broadly adopted technology.
The paper discusses the analytical aspects, operational workflow and administrative and quality control for properly managing the Frac data, from pre-Frac (job design) to post-Frac (job performance evaluation), embedding Frac execution, and including workflow. The data base allowed efficient management of hydraulic fracturing operations, better identification of the fracture candidates, and better design of fracturing treatment, Hence, Frac Platform will improve efficiency, performance & delivery well targets that could essentially reduce resources in data management.
Modeling Supercritical CO2 and Hydrocarbon Adsorption in Nanopores
Authors: Haghshenas Alireza , Hamedpour Mohammad 
Published: March 2022

Abstract
Secure storage of carbon dioxide in underground reservoirs has been an increasingly interesting topic for the researches in the recent decade. The literature includes great works covering the idea of storing CO2 in depleted oil and gas fields or deep saline aquifer. In this study, long-term adsorption of CO2 and hydrocarbon gases is discussed as another opportunity to permanently store greenhouse gases and reduce the amount of the carbon dioxide that enters atmosphere.
The simplified local-density (SLD) theory was used for matching the experimental data and providing predictions of high-pressure supercritical adsorption isotherms of CO2 and hydrocarbon gases. The SLD model is able to capture the contributions from the fluid-fluid and fluid-solid interactions and, despite the typical assumption of uniform bulk phase density, the model plots the variable density profile of the fluids in nanopore. An extensive set of adsorption measurements available in the literature is used in this evaluation. The slit and cylindrical pore geometry are assessed and the effect of the pressure, temperature, pore size and fluid composition is also discussed in detail.
The results show that the SLD-PR model can predict absolute adsorption of the CO2 and hydrocarbon gases within the experimental uncertainty range. For heavier components (C3+), the model illustrates a thicker adsorbed wall close to the pore surface, the adsorption is enhanced while the pressure is increased to a certain point. This observation is in line with the pore-fluid interaction energy which shows a positive trend in terms of molecular size and pressure. In addition, it is concluded that the pore size lower than 2 nm show an exponentially high interest in adsorbing the gas molecules at supercritical conditions. Finally, the results recommend that the simplified local density model gives promising estimates for converting excess adsorption data to absolute adsorption data and calculating the storage capacity of the reservoir rock.
Using the outcomes of this study, millions of tons of carbon dioxide can be safely stored in carefully selected high-organic content rocks. The proposed method can also have some applications in predicting the hydrocarbon-in-place and production behavior in shale reservoirs with high organic carbon content.
Surfactant Adsorption on Carbonate Rocks
Authors: Bolourinejad Panteha , Groenendijk Dirk , Van Wunnik Johannes , Mooijer- van den Heuvel Miranda 
Published: March 2022

Abstract
In order to improve the waterflooding efficiency, surfactants and polymers are added to the water; this process is called surfactant–polymer (SP) flooding. One of the problems for this process is high adsorption of surfactants to the rock surface and specially to carbonate rock surfaces. The focus of this work is: to quantify experimentally the adsorption of anionic surfactants to carbonate rock surfaces, obtain a qualitative understanding of the mechanisms at play and identify suitable adsorption inhibitors.
The main outcomes of the work are: the adsorption of the surfactants used can be around three times higher (mg per g of rock) on calcite than on sandstone and dolomite. Higher concentrations of divalent ions lead to higher adsorption, and the adsorption also depends on the monovalent ion concentration. Several adsorption inhibitors are identified that can reduce the adsorption substantially, of which polyacrylate showed the most significant reduction. The divalent ions are thought to form a bridge between the anionic surfactants and the charged rock surfaces. The adsorption inhibitors capture the divalent ions, reducing their concentration in solution and, consequently, the adsorption of surfactants. More work is needed on the effectiveness of this concept at higher salinities before a first-pass technical and economic evaluation on the use of adsorption reducing agents on a field-scale can be performed.
Downhole Monitoring Using Distributed Acoustic Sensing: Fundamentals and Two Decades Deployment in Oil and Gas Industries
Authors: Soroush Mohammad , Mohammadtabar Mohammad , Roostaei Morteza , Hosseini Seyed Abolhassan , Fattahpour Vahidoddin , Mahmoudi Mahdi , Keough Daniel , Tywoniuk Matthew , Mosavat Nader , Cheng Li , Moez Kambiz 
Published: March 2022

Abstract
Distributed Acoustic Sensing (DAS) through fiber optic has been deployed in downhole monitoring for over two decades. Several technological advancements led to a wide acceptance of this technology as a reliable surveillance technique. This paper presents a comprehensive technical review of all the applications of DAS.
The paper starts with the fundamentals of fiber optic deployment. Then, an overview of all the applications of DAS including seismic application (vertical seismic profiling), microseismic (hydraulic fracturing characterization), well and pipe integrity (such as leak detection and cement quality), and well and pipe flow monitoring is provided. Flow monitoring contains injection and production flow estimation, phase determination, gas and water breakthrough identification, gas lift surveillance, pump and flow control device performance evaluation, sand production detection, and flow regime recognition.
This paper reviews the basics of DAS, fiber types, installation methods, types of recorded data, data processing, historical development, current applications and limitations. The paper provides a concise review using several field cases from over two hundred published papers of Society of Petroleum Engineering (SPE) and journal databases. The applications of DAS in downhole monitoring can be generally divided into the qualitative and quantitative applications. The study discusses deployment methods, case by case worldwide field performance and interpretation/modeling. It also summarizes main lessons, key results, and challenges including data quality, signal to noise ratio effect, and operational conditions such as the installation of the fiber and the complexity of quantitative production prediction and flow profiling. In addition, a comparison between deployment of DAS and other methods is reviewed.
This study is the foundation for an ongoing study on wellbore and reservoir surveillance through real time distributed fiber optic sensing (DAS) records along the wellbore. It summarizes the historical development and current limitations to identify the existing gaps and reviews the lessons learned during the two decades of the application of DAS in downhole monitoring.
The Petrophysical Basis of Gas Transportation in Coal Reservoirs-Implications on Sorption and Diffusion
Authors: Naveen Paul , Ojha Keka 
Published: March 2022

Abstract
Comprehensive and systematic analysis of complex pore networks is vital in elucidating the transportation of gas in coal reservoirs. In this study, multiscale heterogeneity of high volatile bituminous (hvBb) coal was reconstructed to replicate the pore connectivity. Furthermore, LPA-N2 data provides information about pore characteristics. With the digital and physical data, reliable pore-scale modelling was developed for the prediction of pore filling, sorption and diffusion of gases, including the network of pores and flow paths. The results obtained from this systematic approach is informative and gives complete details about the internal structure of coal that is viable for transportation of gas. Pore-scale modelling replicates familiar lab results. Consequently, geoscientists and reservoir engineers will be able to shorten traditional cycle times dramatically, better understand increasingly complex heterogeneous coal reservoirs, and evaluate exploratory wells, asses field development potential, and investigate early production strategies, as well improved recovery scenarios.
Incident Learning: Addressing the Functional Safety Life Cycle Requirements in PDO
Authors: Kannan Palaniappan , Aziz Abri Abdul 
Published: March 2022

Abstract
The complete lifecycle of Safety Instrumented Functions (SIFs) in process industry should be well managed to achieve the right level of risk reduction. The lifecycle phases in accordance to IEC60511 can be broadly divided in to Analysis, Realization and Operation. Normally, the main focus is on the Analysis phase wherein Safety Integrity Levels(SILs) are determined, Probability of Failure on Demand (PFD) is calculated to arrive at the optimum design, and Safety Requirement Specification is developed for detailed design. However, the rest of the phases in the lifecycle are not addressed with the same vigor. The lesser attention given to later phases of safety lifecycle worsen the PFD calculated in design phase and keeps safety systems vulnerable to failures. When failures become certain, incidents happen and can lead to catastrophic effects.
During a vessel level high-high (LZHH) demand in PDO, the inlet valves (two in series) failed to close leading to carry over of liquid hydrocarbon to the flare stack that led to liquid release from flare in a form of fire balls. The incident investigation revealed that even though required risk reduction levels were achieved in design by installing two valves in series, the rest of the Safety Instrumentation lifecycle phases were not rigorously adhered to resulting in the incident. In this paper the Authors endeavor to present various actions taken by PDO in order to make sure that what is designed, is operated and maintained as intended and in the process fulfilling the SIF lifecycle requirements.
Production Optimisation by Retrofitting Autonomous Inflow Control Devices into an ICD Well in a Oil Reservoir Offshore China
Authors: Gao Xiaofei , Dai Ling , Liu Jia , Zou Xinbo , Xu LiQian , Yang Guang , Moradi Mojtaba , Konopczynski Michael , Hua Jingheng 
Published: March 2022

Abstract
In the 2018 intervention campaign, CNOOC aimed to improve production by retrofitting a horizontal well offshore of China. Water mobility in the reservoir was at least 20 times higher than oil mobility and a strong aquifer was located below the well. The well was drilled along a heterogeneous formation with varying properties resulting in an uneven reservoir influx toward the wellbore. Although the well was already completed with passive ICDs, oil production from the well started suffering severely from an early water breakthrough in a couple of weeks after starting production.
It was recognized that the challenges could be mitigated by deploying Autonomous Inflow Control Devices (AICDs) which can control the reservoir fluid influx toward the wellbore and therefore optimise the well performance. An AICD is an active flow control device that delivers a variable flow restriction in response to the properties of a fluid and the rate of flow passing through.
An integrated workflow comprising history matching and performance evaluation of the existing completion and sensitivity analyses was adopted to determine the best retrofit completion for the well. A well with a horizontal length of 300m was drilled in a thin formation with the oil column averaging 15ft. The optimum retrofit completion was to install a 2 3/8″ inner string consisting of AICD subs, swellable packers inside the existing ICD completion. The well was segmented in three compartments and a tailored AICD completion based on log data from the well was designed to properly restrict the production of water. The string was then connected to a redesigned ESP pump lifting the fluids to the surface. Through teamwork between the companies, the well was successfully re-completed with RCP AICD completions.
Over a 9-month period of production, the well performance has been optimised with AICD devices. The AICDs significantly reduced the water cut (WC) of the well from 97% to 87% helping produce 200% more oil compared to production prior to re-completion. This application not only saved the cost of treating extra water but also added value by producing more oil. It also facilitated the connection of another well to the production system due to the enhanced capacity of the system which was then producing a lower volume of liquid.
This well is an example that demonstrates the possibility of retrofitting AICDs in existing screens successfully. AICD completions ensured a balanced contribution from all reservoir sections and limited water production significantly. The lessons learnt from pre and post-installation studies will be discussed throughout. The AICD completions enabled the operator to implement an optimum reservoir drainage strategy that uses downhole control that can be manipulated autonomously based on well dynamic conditions to produce more oil.
Evaluation of Corrosion Inhibitor Batch Treatment Using Newly Developed Downhole Monitoring Tool in Sour Gas Wells
Authors: Chen Tao , Liang Feng , Chang Frank , Mukhles Amro 
Published: March 2022

Abstract
Iron sulfide scale deposition in sour gas wells is a corrosion induced flow assurance issue. Corrosion inhibitor batch treatment is one of the techniques used to mitigate corrosion and iron sulfide deposition on downhole tubing. The objective of this study is to introduce the newly developed Downhole Corrosion and Scale Monitoring tool (DCSM) to evaluate the performance of batch treatment of corrosion inhibitor under real downhole conditions.
An advanced DCSM tool has been designed and developed to monitor and evaluate the performance of the corrosion inhibitor batch treatment in a sour gas well under actual downhole environment and multiphase flow regime. The tool was retrieved after 3-5 months of exposure to the reservoir condition for post-laboratory analysis. The retrieved coupons were thoroughly characterized to assess the performance of corrosion batch treatment and to understand the mechanisms of corrosion and scaling. X-ray diffraction (XRD) was used to analyze the mineraological composition of the surface scale deposition. Scanning electron microscopy (SEM) and energy dispersive x-ray spectroscopy (EDS) analyses were performed to characterize the morphology and elemental analysis of the surface deposition. A surface profilometer was used to quantify the size/depth of the general or localized corrosion, as well as the surface deposition.
To evaluate the performance of the corrosion inhibitor batch treatment, two sets of trial tests were conducted in a selected high-temperature sour gas well. One set of the coupons was retrieved after three-month exposure without corrosion inhibitor batch treatment; the other one was retrieved after five-month exposure with corrosion inhibitor batch treatment. The results showed that a very thin layered iron sulfide scale was formed on the surface of test coupons in both cases. General and localized pitting corrosion were found which indicates that corrosion happened first followed by scale layer deposition on metal coupon surface. Less harsh general and localized pitting corrosion were observed in the presence of corrosion inhibitor batch treatment. The corrosion inhibitor treatment did reduce the general corrosion and localized pitting corrosion under scale deposit at a certain level.
The newly developed DCSM tool is an advanced design which allows direct corrosion and scaling monitoring for metal coupons under downhole conditions. Combined with post-laboratory analysis, it provides corrosion and scale mechanism, evaluation on the performance of mitigation, and proper corrosion and scale management programs to minimize corrosion and scale. The DSCM tool can also be deployed and applied in sweet gas wells, oil wells, and water supplier wells to monitor the corrosion and scale under real downhole conditions.