bluuebunny/crossref_metadata_2025_split huggingface dataset:
HSEQ View and Review V&R; An Initiative to Improve Health Safety Environment & Quality HSEQ Performance in WCI Division
Authors: Widodo Bayu Dwi , Therademaker Ricky 
Published: October 2019

Abstract
Improving safety culture is a never ending challenge in Well Construction & Intervention (WCI). WCI launched several HSEQ initiatives in 2018 with expectation to reduce numbers of incident or similar incident recurrence in WCI operation. Those initiatives are Broadcast Safety Message, I-Care Leader, HSEQ Perfect Days, Safety Stand Down, Well Sentinel, Back to Basic and View and Review (V&R). Each HSEQ initiatives were introduced to achive Company ultimate goal, ZERO LTI.
By definition, view is the act of seeing or looking at something (John Milton, 1608-1674) and review is to think or talk about something again, in order to make changes to it or to make a decision about it (https://dictionary.cambridge.org/dictionary/english/review).
View and Review from WCI perspective meaning a technique to observe a daily activities or daily situation at work-place then to discuss the act/ situation with respective personnel in order to capture the positive point as well as point of improvement from the act/ situation being captured.
Key points of this initiative are no blame culture; open mind and sharing knowledge are the utmost spirit when delivering this program. Therefore the new worker will take a lot of benefit when participating in the program and to merge their behavior in the existing safety culture of the organization.
V&R initiative is a simple initiative and effective to boost up crew safety awareness and to facilitate sharing knowledge between teammates. This initiative can be implemented by all personnel; either experienced personnel, new personnel or even a visitor. The success of a program is how easy/ simple and fun the program to be implemented because it needs to be effective to achieve the objective itself.
Delivering the program to all crew on board for sure is a challenge. Consistency of its implementation is also another challenge. Hazard and risk do exist, the way on how we prevent and mitigate is the key of excellence HSE Performance, and one of the way to achieve it is View and Review.
Advanced Data-Driven Model for Drilling Bit Position and Direction Determination during Well Deepening
Authors: Koryabkin Vitaly , Semenikhin Artyom , Baybolov Timur , Gruzdev Arseniy , Simonov Yuriy , Chebuniaev Igor , Karpenko Maxim , Vasilyev Vasily 
Published: October 2019

Summary
In this paper we present a new data-driven methodology for a drilling bit position and direction determination. The model is based on machine learning approach and trained on a data collected in a real-time or near real-time: mechanical parameters of drilling, tool-face data, MWD/LWD data, etc.
The proposed methodology might be an interest for directional drilling service companies, operator companies that develop low-thickness productive strata. One of the main advantages of the proposed approach is economic efficiency which it provides due to absence of additional costs associated with payments for additional man hours for precise trajectory and direction monitoring. Methodology allows to predict trajectory at any time of drilling.
The methodology is illustrated on the historical data of drilling of one oilfield. At the current stage, the results of the testing show good quality. Blind test on 154 independent sliding episodes shows that median absolute error (MedAE) of depth, inclination and azimuth are 0.26 m, 0.25° and 0.42°. These errors will decrease after adding more wells and steps, which are described in future plans.
AGIR : One-Stop Application for Asset Integrity Risk Management
Authors: Susanti Feri , Hasanah Uswatun , Jaya Suwanto , Muttaqin Firdaus , Munir Bahrain 
Published: October 2019

Abstract
Major accident is one of the risks that oil and gas industries are exposed to. Although its probability of occurrence is low, the impact of this unfortunate event could result in significant losses in terms of personal safety, environment preservation, company asset, production and reputation. Therefore, risk management has to be in place, consisting of identification, assessment and prioritization of risks, followed by coordinated and economical application of resources to minimize, monitor and control the probability and/or impact of the unfortunate event.
In anticipation of potential major accident, there was an initiative to develop a system to manage risks in operations. In order to do that, a Technological Risk Assessment (TRA) study has been done for the existing facilities. As a result, technological risks, which deal with events that may have catastrophic and disastrous consequences, could be identified. However, due to operational changes, the level of risks could differ from the one defined by the TRA study. These risks are what we call "technical integrity risks".
In contrary to technological risks which are updated at every 5 years within the facility life cycle, technical integrity risks dynamically change over time in operational phase of the facility. Therefore, it was necessary to have one centralized database to register all the technical integrity risks. The database was named AGIR (Asset Global Integrity Risk) Register.
Apart from its function as a database, AGIR was developed as a one-stop application for risk management processes. All cases identified as potential integrity threats are registered in the application. A risk assessment tool is also embedded in order to guide users to perform risk assessment based on company's risk matrix in more systematic and efficient way. A TRA database is also included as reference of risk level by design, providing also the major risk register of the facilities. For cases that are confirmed as integrity threats, follow-up of actions defined is also monitored in this application. Furthermore, the application also provides dashboard function to generate reports. This application provides transparency and traceability in the implementation of risk management system. Its features could still be enriched to cope with the company's future needs with regard to risk management.
Dual Function Hydrate Inhibitor for Prevention of Hydrate in Methane and Carbon Dioxide System
Authors: Kassim Zamzila , Rahman Fadhli Hadana , Lal Bhajan 
Published: October 2019

Abstract
Dual function hydrate inhibitor (DFI) is envisaged to provide superior inhibition performances for controlling hydrate formation in comparison to conventional thermodynamic (THI) and kinetic hydrate (KHI) inhibitors. In this work, the performance of DFI was evaluated in high pressure Sapphire cell for methane (CH4) and carbon dioxide (CO2) system. The effects of DFI to the hydrate phase equilibrium conditions at various concentrations for both CH4 and CO2 system were measured in a pressure range of 3.90 – 8.30 MPa and 1.9 – 4.5 MPa respectively. The DFI is then being evaluated for KHI for CH4 and CO2 at 80 bar and 3.5 bar respectively at 274 K experimental temperature. Furthermore, the analysis of induction time and relative inhibition performance are presented for CH4 and CO2 in the absence and presence of DFI. The DFI inhibition performance is strongly evidence as it is observed able to shift hydrate equilibrium conditions, while at the same time prolong the hydrate induction time. In addition, hydrate dissociation enthalpies are also calculated for both considered systems and it was found the enthalpies are within the range of conventional hydrate formation, therefore it is evidence that DFI is not involved during the hydrate cages formation. DFI ability to simultaneously act as THI and KHI shows that DFI performance is more superior as compared to the conventional THI.
Simple and Effective Steps to Generate Opportunities in a Mature Field: Challenging Historical Data and Defying the Established Understanding
Authors: Abdulhadi Muhammad , Mansor Najmi , Tran Toan Van , Chin Hon Voon , Jacobs Stephen , Suggust Alister Albert , Usop Mohammad Zulfiqar , Huong Chii Seen , Zamzuri Dzulfahmi , Abdussalam Khomeini , Khalid Aizuddin , Munandai Hasim , Yusop Zainuddin 
Published: October 2019

Abstract
While it is true that reservoir simulation and new technology applications are crucial to unlocking reserves in a field, the first and most fundamental step in rejuvenating a mature field is to verify the existing data and evaluate the basis of the current understanding. This process, while seemingly "routine", can uncover ambiguous data and questionable interpretations, which can mislead the reservoir simulation results unless corrected. The older and more mature the oilfield, the more ambiguities that can be uncovered. The new understanding can be subsequently converted to "quick-gain" opportunities that can be quickly monetized, while maturing higher investment and more complicated opportunities with reservoir simulation.
The approach applied in a sample field named Field B comprised challenging the established interpretation and understanding by taking a more thorough look and applying a different approach with the basic data. There are examples of reinterpreting the seismic data, cross-checking pressure and production reports with geological understanding, cross-checking well intervention reports, production and open-hole log data, and challenging the conventional approach and understanding. On top of the detective work, it is also necessary to judge whether the data "make sense" or seem unreasonable. Although simple, this approach was effective and successful in generating multiple opportunities in Field B.
This paper provides valuable insight and examples in data verification and challenging established understanding to generate potential opportunities. Having a good grasp of the fundamentals is a valuable skill in a mature field environment. It pays to thoroughly understand the fundamentals, because otherwise, the "fancy techniques" will not work.
Performance Improvement of Thickened Liquid CO2 by Introducing a Philic-CO2 Silicone Polymer
Authors: Li Qiang , Wang Yanling , Li Qingchao , Wang Fuling , Bernardo Jennifer , Zhang Ye , Bai Baojun , Liu Fei 
Published: October 2019

Abstract
As an excellent stimulation treatment for the shale reservoir, CO2 fracturing liquid is injected into the reservoir to increase crude oil production due to the high mobility and high backflow. Nevertheless, many disadvantages in fracturing process, including high fluid loss volume, short fracture length and low viscosity of pure CO2, hinders its application and development. In this investigation, a novel silicone thickener consisted of CO2-Phobic Phenyl and CO2-Philic Ester group is prepared. The thickening performance of a thickener in liquid CO2 is measured by capillary viscosity measurement system at different conditions. Molecular simulation presents that a mesh structure can be formed among CO2, solvent and silicone, and the density of mesh structure affects the viscosity of thickened liquid CO2 Meanwhile, the filtration property and fracturing simulation are compared between pure CO2 and thickened CO2. With the capillary viscometer, the viscosity of thickened liquid CO2 can be increased to 2 mPa·s at 3 wt% thickener at 303 K and pressure of 12 MPa. An increasing CO2 viscosity was displayed as the thickener content and pressure increased, but a decrease of viscosity is shown as temperature and flow velocity rise. The elevated viscosity leads to a significantly reduced filtration volume. Fracturing simulation displays that the increased viscosity results in a longer fracturing time and length. By analyzing the fracturing simulation data, the thickener CO2 can involve a farther reservoir which the pure CO2 cannot reach. Compared to pure CO2, a 55m fracture is revealed during the fracturing simulation while it is only 6m for pure CO2. For the fracturing and filtration performance, the thickened CO2 is obviously better than the pure CO2. The addition of thickener can not only obviously improve the CO2 viscosity to some degree, but also the excellent fracturing and filtration performance according to the extended finite element simulation and the thickened CO2 is considered as an applicable fracturing fluid to develop the shale reservoir.
Assuring Groundwater Safety with Stable Isotope Monitoring Method for Waste Slurry Injection Project, Duri Field, Sumatra, Indonesia
Authors: Yuniar Yuniar , Sugiarto Ari , Syahputra Ahmad , Dwi Hadian M. Sapari , Barkah M. Nursiyam , Satrio Satrio 
Published: October 2019

Abstract
Shallow groundwater is the primary drinking water source for local communities surrounding Duri Field operations area. To ensure the local community has access to safe drinking water and to comply with Government of Indonesia (GOI) environmental safety regulations, PT. Chevron Pacific Indonesia (PT CPI) established a groundwater monitoring system to ensure that slurry waste injection into deep non-potable water aquifers does not contaminate nearby shallower drinking water aquifers. The prevention system also includes well integrity surveillance and monitoring as a leading indicator and water sampling and analysis as a lagging indicator.
Duri Field is in the Rokan block, Riau Province of Indonesia. Oily sand and viscous fluids are byproducts from oil production and treatment processes. The Sand Management Facility (SMF) was developed to manage these solid and liquid wastes by injecting mixed waste slurry under high pressure into deep subsurface formations. The scope of this study included 12 injector wells with two groundwater monitoring wells surrounding each injection well.
Stable isotope monitoring technology is used to ensure that deep waste injection slurry is not mixing with and contaminating shallow drinking water resources. Stable isotope (δ2H, δ18O) analysis was used to define the Local Meteoric Water Line (LMWL) of Rokan Watershed defined by equation δ2H = 7.6 δ18O + 10.5 (r2 = 0.921), which is applied as a reference point for isotope studies in SMF area. The stable isotope δ2H samples for groundwater in SMF ranged from −70.5 ‰ to −25.1 ‰ followed by formation and surface waters that respectively ranged from −64.8 ‰ to −48.9 ‰ and from −61.9 ‰ to −20.8 ‰, while δ18O samples ranged from −11.18 ‰ to −2.12 ‰.
After four years of monitoring, δ2H and δ18O results indicate that the shallow groundwater samples are coincident with the reference meteoric water line, which implies these samples originate from rainwater. Surface water samples are consistent with water influenced by evaporation processes. Conversely, samples of produced waters exhibit a distinctly different isotope character compared to the shallow water samples. This suggests that there is no connection and mixing between surface and shallow aquifer with the deeper slurry injection zones.
Stable isotope analysis has proven to be a successful groundwater monitoring technique and is an enabler for continued safe injection of slurry wastes into the deep subsurface. These efforts have been acknowledged by Kementrian Lingkungan Hidup dan Kehutanan (KLHK) of GOI experts as one of the most advance groundwater monitoring technologies currently in use in the Indonesian oil and gas industry.
Water Injection Performance Benchmarking & Replication of Best Practices Reduces Operating Cost Improves Recovery
Authors: Faiz M. Faridyl , Mandal Dipak , Masoudi Rahim , Mustapha Syarizan , Wahab M. Afiq , Nasron Budi Mawardi , Hadi Sriyanta 
Published: October 2019

Abstract
Water injection (WI) to improve oil production and increase reserves had been practiced in Malaysia since 1990s. Currently, around 27 fields are producing with water injection. To better manage these WI fields and gauge the relative performance of these fields, certain Key Performance Area (KPA) and Key Performance Indicators (KPI) were identified. Measurement of these KPA and KPIs serves as a yardstick to compare performance of WI fields and thus provide measures to improve collective performance by promoting replication of best practices and sharing lessons learnt.
In the era of digital technology, the periodic measurement of KPA and KPI has been automated using the existing online platform which can remain accessible to all related parties. It provides a platform for data visualization with simple look forward analysis. The WI data is stored in company databank and the performance dashboard can be viewed from existing software. The team managed to overcome the challenges in completing the historical data gap and data hygiene which previously were managed manually and were not integrated. This resulted in historical evaluation of KPAs and KPIs of certain fields.
This automation initiative will enable practicing engineers to identify the value leakages and proposed mitigation efforts. Some of the best practices identified such as pipeline pigging optimization, correct biocide dosage, periodic calibration of flow meter and chemical optimization already helped to reduce operating cost in certain WI fields.
With these efforts, the company could reduce the operating cost significantly in year 2018. Other than data visualization, the tool provides diagnostic plots such as Hall Plot, Chan's Plot etc. for quick analysis of signs of well/ reservoir health deviations and thus solutions could be provided proactively. On seeing the initial positive results, this tool is being tried for the rest of the WI fields.
This paper details how this tool tries to diagnose all sub-optimal areas within various WI project simultaneously, which leads to operational excellence and improvement in oil recovery, by identifying value leakages, providing proactive solutions with replication of thus identified best practices. Additionally, usage of this tool to rank WI performance of different projects can potentially help to initiate competition between different operators for improvement.
A Case Study of Miscible CO2 Flooding in a Giant Middle East Carbonate Reservoir
Authors: Wu Shuhong , Fan Tianyi , Zhao Lisha , Peng Hui , Tong Min , Wang Ke , Wang Cong 
Published: October 2019

Abstract
Miscible CO2 flooding is a proven field development technology, which has been widely applied to many fields to enhance the oil recovery. It can efficiently expand oil volume, reduce oil viscosity and eliminate oil-gas interfacial tension. In this paper, a case study is detailed on CO2 flooding in a giant low-permeability (2-5md) and low-viscosity (0.3mpa.s) carbonate oil reservoir in Middle East, which has been extensively developed since 1990's with natural depletion, water flooding, and hydrocarbon gas (HC) flooding as well as HCWAG. The demand for further enhancing oil recovery and reducing greenhouse gas emission requires to assess the potential of CO2-EOR flooding.
In this paper, production history is firstly reviewed as well as the CO2 pilot test, including production performance, gas/water injection profile and remaining oil distribution in a five-point high-angle horizontal well pattern. MMP of hydrocarbon gas and CO2 is compared in the carbonate reservoir with the miscibility with oil, miscible area, residue oil and also, the gas intake profile as well as gas breakthrough. The density difference between gas/CO2 and oil results in a gravity override, gas/CO2 channeling, and early breakthrough and poor vertical conformance problems. Therefore, CO2-alter-Water injection with optimized WAG cycle as well as tapered WAG are detailed to improve production performance and increase the oil recovery, which is considered as a potential way with high swept efficiency of water flooding (70-80%) in a low-viscosity and high displacement efficiency of CO2 miscible flooding (85-90%).
The discussions of simulation schemes in this study can be applied to determine the optimal strategy for the future development of this large carbonate reservoir in the Middle East.
Novel Method for Estimating SHmax in Naturally Fractured Formations Using DFIT Data: Case Study on Unconventional Shale Gas
Authors: Leem Junghun , M Ali Siti Syareena , Tan Chee Phuat , Kantaatmadja Budi Priyatna , Che Yusoff M. Fakharuddin , Md Zain Zahidah 
Published: October 2019

Abstract
Maximum horizontal stress (SHmax or SH) and associated horizontal stress anisotropy are some of the essential inputs for drilling and completion optimization such as 3D geomodel and geomechanical model building, drilling mud design and well trajectory analysis, solid production prediction, sweet spot identification in tight/shale plays (i.e. low stress anisotropy as well as high brittleness), and multi-stage hydraulic fracturing design optimization with stress shadowing analysis (e.g. well spacing, fracturing stage spacing, injection rate, fracturing fluid, proppant, etc.).
Minifrac/Diagnostic Fluid Injection Test (DFIT) prior to hydraulic fracturing can provide essential reservoir information, such as closure pressure (e.g. minimum horizontal stress, Shmin or Sh), formation pressure, and effective permeability from the G-function analysis. Nolte and Smith (1981) identified Pressure Dependent Leak-off (PDL) behavior in the G-function analysis, and defined PDL net pressure to estimate SHmax associated with small fissure opening along the main hydraulic fracture during the Minifrac/ DFIT. The definition might be suitable for estimating SHmax for non-fractured formations such as conventional ductile sandstones, which could create small fissure openings (e.g. cm size) along the main hydraulic fracture. However, in conventional and unconventional fractured formations such as fractured carbonates, tight sandstones, and shales, the methodology was not applicable because of limitation in the assumptions, which excluded interaction with existing natural fractures (i.e. natural fracture opening during the Minifrac/DFIT).
A novel methodology has been developed to estimate SHmax in conventional and unconventional fractured formations from Minifrac/DFIT field measurements. The SHmax Estimation from DFIT method (SHED) is considered more direct compared to the existing methods, since the common industry-accepted methods, such as the image log method from breakouts and the poroelastic horizontal strain method, require Shmin inputs from Minifrac/DFIT tests, additional logs such as image logs and sonic logs, and additional image and geomechanical analyses to define SHmax. Whereas, SHED only requires Minifrac/DFIT test data, typical G-function analysis, and natural fracture patterns from existing geological maps and other inputs, such as seismic surveys and Discrete Fracture Network (DFN) analysis. SHED has been validated and applied in several unconventional shale gas fields utilizing available Minifrac/DFIT field measurements.