bluuebunny/crossref_metadata_2025_split huggingface dataset:
Best Practices for Assessing Chemical EOR Project Risks for a Major Malaysian Offshore Oilfield
Authors: Khanifar Ahmad , Deo Tewari Raj , Mousavimirkalaei Seyed Mousa , Bin Abd Raub Mohd Razib 
Published: October 2019

Abstract
A major Malaysian matured offshore oilfield which is currently under waterflooding has been seen declining in production in recent years. Among various enhanced oil recovery (EOR) techniques evaluated, this field appears to be amenable to chemical EOR implementation. Chemical EOR project requires high capital and operating expenditure (CAPEX and OPEX) and often involve complex logistical and operational challenges in an offshore environment. A comprehensive study and technical road map plan from laboratory to pilot and then to full field reservoir simulation model has been established to reduce the project risks prior to field-scale chemical EOR implementation.
For this study, detailed EOR screening and ranking evolution is conducted and confirmed that chemical EOR is ranked high among other EOR techniques and stands for better chance of success techno-economically. Subsequently, all the relevant field examinations to verify the incremental oil recovery from chemical EOR including extensive laboratory experiments such as fluid-fluid and fluid-rock evaluations and pilot tests by single well chemical tracer method were designed and implemented.
This paper mainly presents the challenges and the strategies to build a realistic full field chemical EOR numerical simulation model (using CMG's STARS), which include history matching and waterflooding optimization process stages. The work has been carried out to address the best practice workflow for chemical EOR simulation, lessons learned from how to properly prepare and incorporate the chemical input data, identify uncertainties relate to project risks and minimize or mitigate the impact of risks to the project economics.
Numerical simulation was utilized along with assisted optimization methods that combine experimental design and artificial intelligence (AI) techniques (using CMG's CMOST) to determine injection chemical concentration and chemical slug size for optimal oil recovery factor and project net present value (NPV). Sensitivity studies were also performed with the reservoir simulation models to determine the impact of effects such as residual oil saturation (Sor) reduction, chemical loss through adsorption, dilution effects on capillary number, salinity and viscosity effects, cooling effects, chemical reactions, among others. The study results show that chemical EOR injection is a technically feasible and economically viable option for this oilfield from subsurface, incremental oil recovery, and facilities stand points. Furthermore, the results of this risk assessment will facilitate and expedite the full field project execution and investment plan in future.
A New Artificial Intelligence Recognition Method of Dominant Channel Based on Principal Component Analysis
Authors: Chen Cunliang , Han Xiaodong , Yang Ming , Zhang Wei , Wang Xiang , Dong Peng 
Published: October 2019

Abstract
Long term waterflooding leads to the formation of dominant channels in sandstone oil reservoirs, which aggravates the heterogeneity of the reservoir and decreases the displacement performance of the injected water. The ineffective water circulation through the dominant channel would significantly increase the cost of water injection and reduce the oilfield exploitation effciency. Therefore, valid identification and controlling of the dominate channel are essential for enhancing the oil production efficiency of waterflooding reservoirs. Although many methods have been proposed to identify the dominant channel, the accuracy of these methods is always unsatisfactory caused. The results obtained by using various methods are not consistent with the others.
A new method that can comprehensively utilize multiple data is proposed here for improving the identification accuracy of dominate channels. The formation of the dominant channel is affected by both geological factors and development factors. And all these parameters change during the waterflooding process and could reflect the formation of dominant channels. In our method, the evaluation index system consisted of both geological factors and development factors that are firstly formed and analyzed. Consequently, the principal component analysis (PCA) method is applied to aggregate the multiple independent indexes into a comprehensive index. The calculated relative value of the comprehensive index is then considered as the assessment criterion to identify the dominant channel. As an artificial intelligence method, PCA is widely used for reducing dimension statistics. This method has good advantages in the identification of the dominant channel since it can take various data into consideration and reduce subjectivity during the identification process.
The proposed method has been applied in several oilfields for dominant channel identification, and the results are entirely satisfactory. Accurate identification of dominant channels is helpful for the design of an effective adjustment plan, which could provide technical support for achieving higher production efficiency and better economic benefits.
Confirmed Effectiveness of Tracers’ Production Logging in Comparison with Conventional Production Logging
Authors: Basov Artem , Bukov Oleg , Shevchuk Taras , Lazutkin Dmitry , Saprykina Kseniya , Kiselev Vasily , Novikov Igor , Drobot Albina 
Published: October 2019

Abstract
Due to traditional oil and gas reserve depletion, the share of unconventional, hard-to-recover oil and gas reserves is constantly expanding. The cost of horizontal well stimulation used to increase oil recovery rate using multi-stage hydraulic fracturing is significantly higher. Addressing this requires the implementation of new technologies and services to facilitate optimal drilling, completion and stimulation returns, thus shifting the focus to analyzing well productivity increases. The use of developed production logging technology allows oil and gas producing companies to efficiently determine well productive intervals, thereby indicating high production rates and maintaining the profitability of operating wells by eliminating non-productive intervals. This data allows for planning field development with higher profitability by increasing the oil recovery rate.
An Integrated Geological Approach for a Successful Waterflood Implementations and EOR Planning: Lesson Learned from T Field Development, Barito Basin, Indonesia
Authors: Setya Wardhana Brianto Adhie , Titaley Grace Stephani , Purwatiningsih Ninik 
Published: October 2019

Abstract
The brain of a waterflood project is a geological framework that defines reservoir continuity relative to its transmit fluids as well as restrict fluid movement. The lack of geological knowledge results in the misleading interpretation and understanding of the reservoir behavior. This paper presents an integrated geological aspect, concept and approach to design an effective well pattern and well spacing in waterflooding. This method is proven to improve sweep efficiency and lead us to make an EOR planning in our field. T Field is one of the mature fields where a successful waterflood project has been implemented in Indonesia
Detailed core description with sedimentary structure analysis, paleocurrent analysis in FMI data and various property maps were conducted to identify the relationship between injection and production well. It also gives the information about movement of injected water. The sediment transport suggests some directional anisotropy in permeability. The distribution of geological heterogeneities and their influence on fluid flow characteristics were determined by generating maps and cross sections based on integration of log, core & petrographic data and qualitative information from production data. Parameters mapped included the distribution of porosity, log derived geometric mean permeability, clay content, and Dykstra-Parsons coefficients of permeability variations.
The results of this study showed a good correlation of facies distribution and sedimentation direction with flow of water movement behavior. The direction indicated relatively west to east sediment transport being perpendicular to the structure. It was also matched with tracer survey analysis and simulation model. In our success story, we applied the staggered line of full scale waterflood pattern to maximize the areal sweep efficiency and improve 5-7% recovery factor of total OOIP. This information also strongly supports the building of reliable static and dynamic model.
We proved that an integrated geological approach, including a good understanding of facies and sedimentation characteristics of reservoir will lead us to build successful waterflood and EOR project in the future.
A New Generation of Independent Temperature and Pressure Drilling Fluids System with Flat Rheological Properties, Low Invasion, Higher Shale Stability and Lubricity to Replace Oil Based Mud
Authors: Taraghikhah Shervin , Mohammadi Mojtaba Kalhor , Nowtarki Koroush Tahmasbi 
Published: October 2019

Abstract
The knowledge about rheological models is critical for a drilling fluid study. Typical drilling fluids have lower rheological properties in higher temperature or increase in gel properties which is the main reason for frictional losses when circulating. Keeping the rheological properties with constant value is one of the challenges to manage ECD and its effects. Our main goal is to introduce a flat rheology water based mud in order to improve fluid stability and prevent loss circulations and robustness while drilling operation.
The newly developed flat rheology water based drilling fluid system is formulated in different mud weights 1.12 S. G – 2.15 S. G to keep the shale inhibition, temperature stability and rheological properties in the highest possible performance.
This fluid system was subjected to hot rolling for 8 hours at 250 °F and 300 °F. Rheological properties were measured before and after hot rolling in several temperatures in order to confirm the flat and stable rheology. As well, other properties like shale recovery, fluid loss and lubricity were measured. After hot rolling (250 °F and 300 °F) rheology measurements were performed with Fann Viscometer for each mud in different temperature and pressures (60 °F to 180 °F) and the results were collected to be compared with before hot rolling data in the same conditions. All rheological data (PV, YP, Gels and etc.) remained the same comparing the properties before hot rolling.
This water based mud possesses the highest shale inhibition (shale recovery ranges from 95-100%). The API-fluid loss and HPHT-Fluid Loss were sufficiently controlled. Lubricity effect provided us with a really acceptable Kf (coefficient friction factor), under 0.2, which enables applying the system in high deviated zones or directional drilling. Stability tests show that this system has no incompatibility with high salinities and is adequately resistant in presence of contaminations. Also this system is applicable in the presence of weighting agents. Finally cost comparisons and environmental evaluations introduce this system as a cost benefit and environmental friendly system.
The most striking feature of this research is to design and introduce a flat rheology water based drilling fluid replacing conventional drilling fluid systems with temperature and pressure independent rheology along with other qualified characteristics. Significantly, this system is sufficiently environmental friendly and cost effective.
Non-Intrusive Technologies for Prudent Brown Field Redevelopment – An Operator's Experience
Authors: Yeap Wei Jian , Sidek Sulaiman , Naharindra Adhi , Riyanto Latief , Idris Khairul Nizam , Bakon Freddy Layang , Ambrose Jonathan Luke , Mackie Alexander , Rajan Santa , Sridhar Siddesh , Wong Kion Ming , Alias Azrul 
Published: October 2019

Abstract
In the oil and gas industry, operators strive to minimize loss time and production while keeping its facilities and operations safe. Over the past few decades, technological innovation has equipped the industry with the equipment and practices necessary to make the exploration and production more efficient, safe and environmental friendly. This paper discusses successful implementation of several non-intrusive technologies by the operator for redevelopment of maturing oilfield in offshore East Malaysia.
The field was discovered in 1967 and oil has been produced since 1972 from the major hydrocarbon accumulation in 8 producing reservoirs, sandwiched between shallow gas-bearing reservoirs and deeper gas/condensate-bearing reservoirs. Enhanced Oil Recovery (EOR) redevelopment project in the field began in 2018, targeting the major oil reservoirs and Non-Associated Gas (NAG) reservoirs. Crestal gas injection and flank water injection will be implemented to further develop the oil rims of A and B reservoir while Immiscible Water-Alternate-Gas (IWAG) injection will be implemented in the C reservoir. The EOR scheme will include infill drilling of new wells and workover of existing wells to deliver targeted incremental oil recovery.
The journey towards EOR redevelopment project consistently requires integrated contributions from multiple disciplines such as Petroleum Engineering, Production, Well Services, Facilities and Process Engineering, which has been facilitated effectively through Reservoir, Well and Facility Management (RWFM). This holistic work process involves creating critical strategy for EOR redevelopment activities, optimization decisions and asset management, ensuring the delivery of remaining reserves and long-term production maximization. By implementing RWFM collaboration and support, several non-intrusive technologies have been evaluated & implemented to solve long overdue problems such as online acoustic sand monitoring system, non-intrusive acoustic valve inspection device and active sonar meter.
Overall, this paper highlights the working principles, actual field results and lessons learnt from the application of non-intrusive technologies through RWFM collaboration that deliver significant cost and efficiency benefits as well as safety for prudent brown field EOR redevelopment.
Well Opportunity Register, Define and Selection: Changing the Game in Production Optimisation Using Automation and Analytics
Authors: Mario Cio Cio , Saputra Rini , Saefuddin Sera , Triyono Triyono , Metra Sabrina , Gaskari Razi , Martinez Henry , Songchitruksa Praput , Kartika Djaya Belly Agustinus , Sinha Rajeev Ranjan , Vadivel Karthick 
Published: October 2019

Abstract
The oil & gas industry is catching up to automation of traditional workflows practiced in the industry and implementation of artificial intelligence to fasten repetitive tasks. This is driven by the need to automate low-cognitive tasks enabling engineers to spend more time on high-cognitive components of the existing workflows, thus leading up to smarter decisions. This has been made possible by the recent developments and adoption of various analytics and machine learning tools.
Well intervention and workover are a routine and important exercise undertaken in the oil and gas industry where the objective is to identify the sick wells and diagnose the right intervention and workover to improve the production. A typical well intervention and workover candidates study includes: Identifying the underperforming wells,Diagnosing these wells and identifying the right workover/ intervention opportunitiesCreating a ranking of the opportunities using a standard approach.Forecasting the gain after workover/interventionRunning economic analysis to identify the candidate based on opportunity's profitability
Ujung Pangkah Oil and Gas Field is an offshore field located in Indonesia. The reservoir is a multi-layered carbonate oil and gas reservoir, being produced mostly through horizontal wells. An intelligent solution termed as SWORDS was developed for the Ujung Pangkah field that enables the engineers to be permanently aware of the intervention and workover opportunities. The SWORDS solution is driven by 'Automation & Analytics', where the ranking of the opportunities has been driven by a multi-criteria decision making process leveraging the Petroleum Engineering techniques practiced over decades.
Developing FDP Capabilities with PetroCup Petroleum Asset Simulator
Authors: Aslanyan Arthur 
Published: October 2019

Abstract
The paper shares practical cases on PetroCup – a new generation of on-line petroleum asset training and testing facility which helps developing the practical asset management skills and improve practical skill in associated disciplines, such as geology, petrophysics, flow simulations, production technology, well testing, production logging, surface facilities and petroleum economics.
Going through web-tournament is like a quest and represents a challenge for multi-disciplinary asset team during one or few days. The after-tournament debriefing helps asset teams understand their mistakes and learn from them.
Paper explains the specifics of public and corporate sessions and brings few case studies on both.
The training facility is based on PolyPlan simulator which has a very simplistic user-friendly webinterface which allows petroleum engineers perform typical routine activities (drilling, complex workers, varying pump and choke settings, well testing, logging etc.) with an intuitive button-click.
The PolyPlan simulator is modelling surface infrastructure, geological model, dynamic flow model, wellbore flow model, flow metering system for production gathering and water supply systems, popular OH and CH sensors and associated data acquisition procedures and reproducing a very realistic response to the typical field activities.
The paper also provides an overview of synthetic assets library and their complications and future plans on creating the new petroleum assets. The PetroCup facility provides a fast and cheap way of accumulating practical experience in petroleum asset management. It gives opportunity for people to learn new methods and tricks from sessions moderators and from each other.
Participants get opportunity not only to apply their engineering knowledge but also develop the presentation skill while convincing the team in their findings and ideas.
It also makes a great team building and helps people get closer and know each other while working on a project. The same facility can be used as automated unbiased assessment of accumulated experience in field development and associated petroleum disciplines.
The PetroCup allows people to join from different locations which substantially extends scalability of the knowledge sharing.
A Breakthrough Effort in Bringing the Learning Experience Closer to Employee by Using Online Blended Learning
Authors: Hidayatullah Aulia Syarifah , Larasati Ditta 
Published: October 2019

Abstract
Traditionally, people ought to come to a face-to-face or in-class training, whether arranged by company through in-house training or set up by a public provider. This conservative mechanism has its drawbacks for employees as in-class training require them to be in one location at a certain time. It becomes a challenge specifically for an employee in Oil & Gas company with its various working hour and working schedule (rotational or residential). This paper describes the breakthrough effort in PT Pertamina Hulu Mahakam (PHM) where training is delivered using online blended learning methods in which employees can participate actively in a learning program conducted from any region of the world without leaving the workstation or residence. Online blended learning does not require any fancy equipment or tools, as a participant only needs a laptop or desktop with speakerphone and of course, good internet connection. Besides, online blended learning may also worth to consider in terms of cost that might be lesser than conducting in-class training or sending people to conventional public training.
Localization of the Remaining Reserves of R Oilfield With Pulse Code Pressure Testing
Authors: Aslanyan Artur , Ganiev Bulat , Lutfullin Azat , Sagidullin Lenar , Karimov Ildar , Mukhliev Ilnur , Farakhova Rushana , Gainutdinova Landysh , Zinurov Linar 
Published: October 2019

Abstract
The paper is sharing experience on using the cross-well pressure pulse-code testing (PCT) to locate the remaining reserves for the waterflood infill drilling.
R Field is a very mature giant field in Volgo-Ural region of Russia and has been under production for more than 70 years.
One of the key challenges at this stage is to locate the remaining reserves which have been migrating over the field following the waterflood patterns with a lot of areal and vertical flow profile complications.
Successful Application of Novel Modified HF Acid System for Sandstone Matrix Acidizing in B Field
Authors: Ting Chang Siong , Kamarudzaman Zayful , Aris M Ikhwan , Hasbi Nurul Ezween , M Jeffry Suzanna Juyanty , M Shafian Siti Rohaida , Chandrakant Ashvin , Hassan M Hafiidz , Kamaruddin Izam Ikhwan , Mohamad Khairul Idzwan 
Published: October 2019

Abstract
Fines migration is the common formation damage mechanism in the sandstone reservoir of field B which has less established information on mineralogy distribution. There were many attempts to remediate the formation damage using conventional mud acid fluid system but resulted in mixed success rates. This situation warrant for the need for a modified acid recipe to avoid aggravation of fines migration problems in this field post acid treatment.
This paper presents the pilot application of a modified HF acid recipe incorporating chelate. The paper also depict the evaluation process that includes candidate selection, laboratory workflow and results, treatment design, execution strategy and the post job analysis on well B-1S. In order to increase the acid stimulation success rate, the team analyzed numerous post job reports of the nearby wells that were previously treated with conventional mud acid system. The root causes of the previous job failures were identified, such as prolonged soaking of acid in the formation due to unplanned platform shutdown and limited platform deck space. Taking these factors into account, the modified HF acid system (with 1.0% HF) was selected for execution in B Field. The pilot execution resulted in double the production compared to the pre-treatment rate. The modified HF acid system has also improved the economics of the project due to its lower cost since it is a one-step system and has lower additives requirement.