bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Novel Approach for Improving Water Injection Performance in Oil Field by Applying Lean Six Sigma
Authors: Al Ghafri Zaaima Sulaiman , Al Mandhari Sulaiman Saad , Al Aamri Ghusun Amur , Al Zaabi Yousuf Salim 
Published: October 2022

Abstract

Objectives/Scope
Water injection (WI) is very critical in Oil Fields to improve pressure build up; hence maximizing oil recovery and increase volume.
In X field in South Sultanate of Oman, Water Injection is a key factor to stabilize Oil production. In 2018, rapid pressure decline has been seen in oil producing wells. Since then, a clear decline is seen in water injector wells which resulted in Oil lost up to 100 m3 of Oil per day.

Methods, Procedures, Process
To arrest WI decline, a ‘Lean Six-Sigma’ study was carried out using the DMAIC (Define, Measure, Analyze, Improve & Control) approach. The DMAIC approach is a proven improvement approach in global industries successfully utilized outside of Oil and Gas for number of years, but never utilized in this context until now.
The application of this approach helped significantly to enhance and reduce the defect, decline and variation, of the injectivity process. The DMAIC approach helped the team to understand the problem, analyze it and identify the root cause of the injection decline, to reach an optimized solution which is replicated across the field.

Results, Observations, Conclusions
The study showed that, due to the reservoir having low permeability and porosity, even a small amount of TSS (Total Suspended Solids) in the formation can have a significant negative impact on well injectivity. As a result, optimized acid stimulation was recommended for X wells until water is treatment facility is on stream by end 2023. A new acid recipe showed a lower defect, decline and variation in injection rate trend for the piloted WI wells. This had a significant improvement on X field injection and acceptance for the water and hence increase overall production and sustainability of pressure support across the field.
The results have proven that, by using this structured approach, the unwanted variation in injectivity and the level of process defects were reduced significantly which resulted in major oil gains.

Novel/Additive Information
Using this novel Lean Six-Sigma approach to improve injection managed to obtain the following impressive results on increase in Oil gain by 25 m3/day (9.8k/day $) 3.6 Million $ / Year.
Along with the impressive oil gain, this study will provide opportunities to many organizations for healthier and enhanced implementation of Lean Six-Sigma projects for Water Injection issues in Oil and Gas Fields. Furthermore, it has opened new era to the way similar problems are tackled.
Advancements in CO2 Membrane Separation Technologies: Reducing Emissions and Enabling CCS
Authors: Choudhury Tanzim Ahmed , Mahley George , Sanghani Pinkesh , Kumar Hans 
Published: October 2022

Abstract
To overcome production restraints caused by CO2 and H2S in mature basins, operators require more cost-effective gas treatment to effectively remove these impurities from natural gas. Cellulose triacetate (CTA) based CO2 separation membranes have already been used extensively in acid gas treatment and associated enhanced oil recovery. A new technical challenge was to provide a horizontal membrane element that could easily replace poorly performing existing flat-sheet spiral-wound membranes with minimal operational changes to debottleneck existing hardware capacity, minimize hydrocarbon loss, and reduce membrane replacement frequency. Existing CTA vertical hollow fiber CO2 separation membranes were further developed and modified into the form of 8-in./8.25-in diameter horizontal packaging.
Qualification testing was performed at an in-plant gas test loop using full-scale membrane elements. Test programs included varying inlet parameters such as feed gas pressure, temperature, and a wide range of CO2 concentrations. Results showed that the horizontal configuration of the hollow fiber gas separation membrane exhibited superior separation characteristics in terms of gas throughput and hydrocarbon retention in the sales gas, when compared to alternative currently available CO2 removal membrane technologies. The robustness of the membrane polymer was confirmed throughout several startup and shutdown scenarios, with stable gas flux and selectivity observed during rigorous and long-term testing.
The membrane elements can be deployed in existing installations as a "drop-in" solution to overcome production constraints, whilst driving down the cost of excessive membrane replacements. In brownfields, more efficient acid gas removal and enhanced hydrocarbon recovery will reduce emissions by lowering gas flaring and limiting the potential release of methane. Upfront capital expenditure and ongoing operational expenses in greenfield projects can be significantly reduced by the greater natural gas treatment capacity per membrane compared to alternative membrane solutions. The high-purity CO2 permeate stream can also support the implementation of carbon capture and sequestration (CCS), thereby helping to reduce the assets carbon footprint and overall emissions.
The advancements in horizontal CTA membranes have been proven in operation at several facilities, where they have improved the economics of the assets via reduced hydrocarbon flaring and increased gas throughput. An intelligent, automated digital membrane monitoring tool has been developed and deployed to further optimize membrane operations. Operators have also been able to actively pursue acid gas fields previously considered uneconomical for production. Such greenfield and brownfield case studies will be presented as part of this paper.
The Failure Predictive Index, an Algorithm that Exposes Pre-Failure Conditions on Electrical Submersible Pumps
Authors: Bermudez F. , Shono M. , Alnahhas N. , Letan M. , Yazdani H. , Almubarak A. 
Published: October 2022

Abstract
As one of the most widely used artificial lift methods, ESPs represent an important target system for failure prediction tools. Statistical analyses of ESP failures show that their frequencies vary considerably as multiple factors affect these pumps’ running life including reservoir characteristics, handled fluids, presence of solids, presence of free gas, and even improper design & installation.
Due to the variety of completion configurations, manufacturers specifications, and operating conditions under which ESPs are operated around the globe, the most practical approach to predicting their failures must be one that uses features built exclusively on real time data from sensors, independently of manufacturers specs and field conditions such as fluids and reservoir characteristics.
The Failure Prediction Index (FPI) algorithm presented in this paper uses specific proprietary features to differentiate the behavior of data during normal operation from the behavior patterns that have been detected in the days and weeks preceding such failures.
By displaying a single number between 0 and 1 on each calculation cycle, the trained FPI model presents the degree of correlation between the current behavior of the field sensors’ data and those whose patterns have been created from the failures during the training of the algorithm.
A number of wells where the FPI has been successfully implemented in pilot projects, has demonstrated the accuracy of the algorithm to predict failures. This tool is continuously trained with every new deployment on a project, field, and/or reservoir. Its algorithms are constantly refined, and its operating boundaries redrawn, providing the industry with an exceptionally useful tool for failure prediction and for adding true value only possible through the capabilities of Artificial Intelligence.
Two Decades of Mangala Field Journey - Key Highlights, Learnings and Recommendations
Authors: Prasad Dhruva , Singh Aditya Kumar , Shekhar Sunit , Kumar M Suresh , Pandey Amitabh 
Published: October 2022

AbstractThe Mangala field in India was the first major oil discovery in the Barmer Basin having a STOIIP of nearly 1.3 billion barrels in multiple stacked fluvial reservoirs. It contains medium gravity (20-28 °API), waxy, viscous crude (9-17 cP) in high permeability (1-25 Darcy) clean sandstone reservoirs.The field was discovered in 2004 and brought online in 2009, one of the fastest from discovery to production phase. Hot water injection was started within few months of first production to sweep and maintain pressure. The hot water was essential considering wax appearance temperature (59 degC) close to reservoir temperature (65 degC). The hot water is also used as power fluid for jet pump (main lift system in field) and for annulus circulation in case of shutdown to avoid oil congealing. Jet pump application is the largest in the world with ~160 active wells lifting ~400,000 blpd reservoir liquid with ~500,000 bbls of power fluid.Plateau production of 125k bopd was achieved within 14 months from production start, which is one of the fastest among large onshore fields. The initial average oil rates in wells were ~2000-15000 bopd. Given the high well productivity, the field plateau rate was revised to 150k bopd within a year of achieving 125kbopd.Due to adverse mobility ratio with water, EOR screening and lab study was started right after discovery. Chemical EOR was identified as the most suited with polymer in the first phase followed by surfactant-based flood. Considering the EOR importance, a 5-spot polymer pilot was started almost simultaneously with the start of the field production. Basis pilot results, full-filed polymer flood was started from 2015 which is again one of the fastest EOR implementations. The polymer flood is one of the largest in world with 165 tons/day polymer consumption through ~500000 bwpd of polymerized water injection. Polymer flood reversed the production decline and is expected to give ~8% incremental recovery of STOIIP (~100 MMbbls) by 2030. Following polymer, a successful ASP pilot was conducted in the same wells/pattern which resulted in 20-25% incremental recovery of pilot STOIIP over polymer flood. Planning for large scale ASP implementation is underway.There have been several challenges and important learnings along the way including vertical conformance, areal VRR management, polymer development, degradation, viscosity and quality control over time, jet pump and ESP operations etc.Mangala field recovery has been quite fast with ~37% recovery within 13 years field life. Multiple infill campaigns have been conducted with ~280 wells drilled over 165 base development wells.The paper presents the development journey of Mangala from discovery to date with key achievements, many firsts, learnings and recommendations based on waterflood and polymer flood performance for other similar fields.
Investigations in Separator Modelling & Performance in ADNOC, Utilizing Equation of State (EOS) Fluid Models
Authors: Hoda Mohammad Faizul , Asarpota Jyotsna Deepak 
Published: October 2022

Abstract
The objective of this paper is to share the results of investigations carried out in the area of separator modelling and performance within the context of ADNOC's Integrated Capacity Model (ICM). Field production from wells is collected via multiple sets of remote degassing stations (RDS) or towers to a centralized separation facility where single or multiple separators allow the separation of the lighter components (contributing to a gas stream) from the heavy components (contributing to the oil stream). We share the investigation results on the following areas related to this separation:
Range of pressure and Temperature of 1st stage separators Range of feed (field/asset) compositions & contributing well compositions Effect of separation performance of streams ExclusiveIn presence of other streams Effectiveness of using pseudo k-values in separation performance compared to full EOS separation Use of EOS based approach to production back allocation Comparison of GOR correction methods
The primary method used is the performing of simulations with an Equation of State (EOS) model. For the purpose of this study, the single EOS model developed for ADNOC's Integrated Capacity Model (ICM) is used. This model has 15 components and their associated properties. The relative molar content of each component (i.e. the composition of a stream) determines its behavior. The difference in behavior is due to the difference in compositions of streams originating from the various fields/reservoirs/wells. An off-the-shelf software package dedicated to fluid modelling with an EOS is used, with automation, to efficiently execute the EOS computations for thousands of streams. This type of automation is necessary for the purpose of this investigation.
The paper depicts the range of compositions from different assets/fields and shows the impact on the range when the streams are aggregated. The paper also shows result of investigation on the efficiency and separation of components in the gas or oil stream if a single well is routed through a separator and when the same well is commingled with other wells. The use of k-values for the separation of streams and their accuracy is also demonstrated in this paper.
Novel/Additive Information: A methodological investigation into the performance of separators and the use of k-values in the use of EOS-based production allocation solutions is presented. Secondly, the difference in well stream separation performance when done individually and when in combination with other well streams is computed.
Enhancing Upstream Oil Water Separation Efficiency Through Microwave Energy
Authors: Alamoudi Saeed M. , Alwani Mohammed Abdo 
Published: October 2022

Abstract
The objective of this paper is to showcase the innovative method for the dehydration of wet crude oil using a novel gravity separation vessel and associated systems in upstream gas oil separation plant. The new configuration uses microwave radiation along with other conventional separation methods such as chemicals, heat and electrostatic coalescers.
This new technique is intended to be used to tackle major and chronic issues associated with the operation of wet crude handling units that can lead to overall facility production bottleneck and reduced capacity. This issue is common in aging oil fields in which water-oil ratio increases and tight emulsions form. As a result, meeting oil product specification requires major facility upgrade and capital investment that could be difficult to justify. In order to avoid costly upgrades, the addition of microwave energy assisted water separation to existing gravity dehydrator vessel, along with upstream heat exchanger, electrostatic coalescers metallic grids and demulsifer injection is being considered. Microwave electromagnetic radiation offers selective treatment of water molecules when designed for operation in 840 MHz or 2.4 GHz frequencies. This is due to dielectric constant being lossless for oil at selected frequencies while being lossy for water, resulting in high energy dissipation in the form of microwave induced movement of water molecules. To further enhance separation, Faraday cage made from metallic mesh is employed to focus microwave radiations in targeted area, which in our case is the oil-water emulsion area. The mesh structure is also designed to maintain laminar movement and prevent interferences with electrical signals from electrostatic coalescers. Finally, control scheme is also going to be described for optimizing the operation of different separation techniques with the ultimate objective of reducing operating expenses.
The vessel offers enhanced treatment through the utilization of microwave energy and mesh structure forming a Faraday cage enabling oil producer to increase throughput while avoiding costly capital expenditures.
The novel microwave dehydration design described in this paper was filed under US patent number 17/652,942 and titled "MICROWAVE ASSISTED OIL-WATER SEPARATOR".
Rethinking the Flow Management Strategy: Introducing Advanced Lower Completion as a Sustainable Technology in Brownfield Asset.
Authors: Martinez Santiago Maryvi , Ortiz Jhon , Bethapudi Bhanu , Mirza Gulraiz , Noordin Firdaus , Trisnadi Dicky , Mohammed Tawheed , Al Obeidi Mazna , Soufi Abdulrahman , Leal Cesar 
Published: October 2022

Abstract
Horizontal wells has been used across fractured reservoirs for field development, in presence of ununiformed water/gas saturation, introducing challenges for reservoir management. Premature water/gas production cause a higher bypassed oil, impacting its recovery and the business profitability.
Wells performance can be enhanced through advanced and sustainable technologies, conveying in the use of integrated lower completion (i.e. ICV, ICD/AICD, DHPG, PPL).
This paper discusses well/reservoir criteria, completion design and impact of incorporating these technologies in the Reservoir 1 development plan.
Early water/gas breakthrough, zonal isolation, cost, well productivity, complexity of deployment, and material availability have been part of the essentials to be considered in the process workflow from planning, execution and deployment phase. Dedicated Steady-state numerical solutions inflow parameters such as permeability and water-cut profiles modeling were carried out to provide the most suitable lower completion design. The simulation was performed for separate scenarios where Flow control devices (FCD) and Intelligent Completion IC were incrementally implemented. The outcomes were compared in terms of well cumulative oil and water/gas production thru the scenarios and their value quantified.
This opportunity screening and lower completion design (LCD) workflow have recently been applied at Reservoir 1 development plan. Based on the simulation cases outcomes, Six (6) new wells drilled in 2020-2022 are provided with FCD, IC, PPL expecting an incremental oil production and oil recovery with less gas and less water production consequently prolonging the well life. In Addition with the environmental benefits associated with less emissions that are achieved by reducing un-wanted fluids production.
There is a planned to be drilled three (3) more wells with LCD in the next five years as part of the new field development strategies that will improve the sweeping efficiency and oil recovery tackling the production of undesired fluids in a proactive manner.
Less associated emissions – The environmental benefits are achieved by reducing gas and water production, which supports company's commitments to emissions reduction target within their total production operations.
Deep-Set Velocity String for Liner Deliquification
Authors: Hajri Amira Salim , Ghaempanah Babak , Rashidi Ahmed , Veeken Cornelis , Awan Kamran 
Published: October 2022

Abstract
The installation of a smaller size tubing or velocity string inside an existing tubing completion is a well-known deliquification technique. The velocity string comes in various designs providing different functionalities for deliquification. Typically, velocity strings are installed to the top of the producing reservoir interval. In case multiple reservoirs produce across significant liner length (the liner here is the length/area between the two reservoirs), this "shallow" velocity string does not provide deliquification across the reservoir liner section. Depending on the size and length of the reservoir liner and the inflow performance of the producing reservoirs, the liquid loading across the liner can have significant adverse impact on production in which case deliquification by means of a "deep" velocity string installed across the reservoir liner becomes essential. This paper shares different designs, a modeling methodology and real-life assessment cases of such deep-set velocity strings, to achieve deliquification across the tubing completion above the reservoir and the liner completion straddling the reservoir. The proposed designs provide different flow options by changing the setting of sliding side doors (SSD's) embedded in the design or isolating the two zones by packers. The proposed modeling methodology helps to compare the performance of different flow options for shallow and deep velocity string designs. This paper continues by sharing three field cases of deep-set VS for the assessment of its real-life application.
Application of Autonomous Inflow Control Valve (AICV) in Reducing the Gas Production in Ultra-Light Oil Reservoir: Case Study
Authors: Kherroubi Djamal , Cristea Zaharia , Berrahmoun Hocine , Punnapala Sameer , Berdiyev Yunnus , Tveritnev Alexey , Saeed Alshehhi Shamma , Abd El-Fattah Mahmoud , Hooper Nicholas , Brough Brent 
Published: October 2022

AbstractThis paper describes the deployment of Autonomous Inflow Control Valve (AICV) technology in an oil producing well affected by gas breakthrough, to reduce gas production and increase conformance. Based on the fluid properties, AICV differentiates the fluid flowing through it and can autonomously choke / shut off gas inflow from the high gas saturated zones, while allowing oil production from healthy oil-saturated zones.The subject oil producing well has open hole section of over 3200ft. A multidisciplinary data integration of well logs, production history, and subsurface geological description is considered for modelling and designing optimum AICV completion. The main objective is to restrict the gas breakthrough to a smaller compartment, allowing other compartments to produce at higher oil production.The AICV completion was run with a remote actuated shoe to enable fluid circulation from the end of downhole completion string while run-in-hole. AICV technology allows pro-active reservoir management. It shuts-off the gas at subsurface level autonomously, without any intervention. Due to the chocking effect, AICV allows sustain the well production within the reservoir management guidelines, with improved well availability and reducing the operating expenditures. This has an additional positive impact on the environment due to reduction of gas flaring as AICV is expected to reduce the gas production/GOR by 81%This paper discuss in detail how the AICV completion offered a technically attractive and cost-effective gas management and production optimization opportunity. Futures implementation of this solution will improve Miscible Water Alternating Gas (MWAG) injection efficiency and gas recycling in addition to reducing the carbon footprint per barrel of produced while sustaining production.
Data-Driven Characterization of Saturation Distribution for a Heterogeneous Carbonate Reservoir in Middle East
Authors: Wei Chenji , Huang Ruijie , Yang Jian , Gao Yan , Xiong Lihui 
Published: October 2022

Abstract
The middle east carbonate reservoirs are of tremendous potential, but due to the complex types of carbonate reservoirs and strong heterogeneity, the distribution characteristics of reservoir saturation are uneven, which makes reservoir development very difficult. The distribution characteristics of remaining oil are of great significance for evaluating development performance and preparing optimization plan. Deep learning offers a novel approach to solving this problem as a method of intelligent forecasting and analysis. In this paper, the dynamic reservoir production data were collected to establish the data foundation for data driven model training and forecasting. Then the Bi-GRU algorithm was utilized to forecast the performance of single well, which achieved high accuracy predictions with R2 of 0.91, RMSE of 198.93, and MAE of 85.22. After that, single-well temporal three-phase saturation inferring method was proposed based on dynamic performance data, relative permeability curves, and reservoir engineering methods. Finally, kriging interpolation algorithm was used to generate reservoir spatial three-phase saturation distribution. Compared with conventional numerical simulation methods, this method exhibits advantages in computational efficiency and prediction accuracy, and also provides a novel direction for saturation prediction research.