bluuebunny/crossref_metadata_2025_split huggingface dataset:
Mathematical Model for Predicting the Reservoir Performance of Gas Condensate in Multiphase Flow Systems
Authors: Bapat Sarthak , Akhter Nadeem 
Published: November 2020

Abstract
It is today an undoubted fact that the role of gas condensate systems has increased multifold in the global energy chain. However, the development and production of gas condensate systems remains a challenge to the petroleum industry due to its technical complexity. The production data analysis methodologies that has been followed throughout the industry to estimate gas condensate reservoir performance are conventional technologies which have proved ineffective in forecasting and estimating the gas condensate reservoir performance. The complexities involved in the gas condensate system like liquid dropout, condensate blockage and successive multiphase flow of gas and condensate along with the extensive early-transient infinite acting behavior are the root cause for the failure of the gas condensate system.The similarity method transforms the governing PDE for fluid flow into ODE written in terms of single independent variable that combines time and space. The similarity method provides a unique advantage of solving the obtained ODE without the need for linearization. In this paper, the Boltzmann transformation technique is applied to governing equations for multiphase flow for two inner boundary conditions (constant gas flow rate and constant bottomhole pressure) in linear and radial flow regimes.
The proposed model is validated by using the line-source solution for single phase gas flow above the dewpoint. The proposed analytical solution for flow above the dewpoint pressure reasonably coincided with the line-source solution for flow above the dewpoint, thus, the proposed methodology can be used as an alternative and less time-consuming approach to predict reservoir performance in early transient multiphase linear and radial flow gas condensate systems. The capillary pressure effects considered in the paper were reasonably negligible considering the fact that a negligible capillary difference was used in fluid PVT properties. But was significant when incorporated as an additional pressure gradient term. This however, demonstrated that capillary pressure effects play a vital role in the production data analysis in gas condensate reservoirs. There is no analytical production analysis method developed to date has considered pressure-saturation as a function of a non-dependent dimensionless coordinate in multiphase (oil, gas and water) linear and radial flow systems. This paper aims to fill this knowledge gap by extending a modification of the similarity method to fully incorporate capillary pressure effect in multiphase linear and radial flow systems in which pressure and saturation are simultaneously considered as functions of a dimensionless coordinate.
Stretching Well Engineering Design Standard Limit for Fit for Purpose High Pressure Well Architecture and Delivery
Authors: Abu Bakar Nurul Nadia , Raja Ismail Raja Muhammad , Rameli M. Faisal , Khazali-Rosli Khairul Amir 
Published: November 2020

Abstract
Stretching the engineering limit in order to deliver a high pressure, wildcat well, ZT-1, driven by design optimization and allocated resources which resulted in well cost optimization. For a successful delivery of ZT-1 well, three (3) engineering limit focus area has been identified and tackled with proper risk mitigations for well design optimization. ZT-1 well was designed based on prognosed mid case PPFG, with sensitivity to high case PPFG. As per standard practises, exploration well design need to consider a drill kick tolerance scenario of 25bbls in 8-1/2" hole section. However, ZT-1 opted for a reduced drill kick tolerance of 10 bbls in order to drill the wildcat reservoir in one-hole section, by considering well operational point of view. Second focus area with regards to collapse and triaxial safety factor for 7" production liner. According to company casing design standard, full evacuation to atmospheric load case need to be considered for production casing, which failed in ZT-1 well design. Since the probability of the said load case to occur in ZT-1 well is very low due to its clastic nature, team applied risk based design approach by using actual data from manufacturer to enable the usage of said 7" casing. Third focus area linked to the lower hard cement pressure test value. According to company Pressure Containment and Control standard, casing should be tested after the cement is hard, to the lesser of 70% of maximum internal maximum internal yield pressure (MIYP), or FIT or LOT plus 500 psi, or 200bbls influx from max PP for exploration well. Since ZT-1 well is using the standard G-Cement, the limitation is on cement integrity that does not allow hard cement pressure test to meet the three criteria's, hence derogation was raised. The three-focus area was challenged with calculated risks and proper mitigations in place. For first focus area, real time pore pressure prediction, assisted by FPWD were utilized to assess the operational limits. A robust Total Depth (TD) decision tree criteria were developed, based on PPFG uncertainty and drilling was limited up to drill kick tolerance to safeguard the operations. Second focus area enable us to utilize current OCTG resources hence resulted in cost avoidance. The third focus area is to allow fast decision-making during operation in case of the plug does not bump thus will cause hard cement pressure test. These effective decision frameworks were developed without compromising the well and the cement integrity. The three derogations were raised to stretch the design and operational envelope set by company in order to deliver fit for purpose well design without process safety incident. ZT-1 was drilled safely to deliver the well objectives.
Relative Permeability of Heterogeneous Mixed-Wet Porous Media as Determined by Pore-Scale JBN Based Model
Authors: Mahmud Walid Mohamed , Abdussalam Omran Elhamali , Bennour Ziad , Ermila Mansur 
Published: November 2020

Abstract
Relative permeability data are essential for almost all calculations of fluid flow in porous media. In addition, water and oil relative permeability curves play important roles in characterizing the simultaneous two-phase flow in porous media and predicting the performance of displacement processes. In this work, a pore-scale study of two-phase relative permeability in mixed-wet heterogeneous porous media at different capillary pressure and flow rate is presented.
Multicomponent Johnson, Bossler and Naumann (JBN) method was employed to determine relative permeability using recovery, saturation and pressure results obtained from 3D Eclipse simulation model of a core sample. Mixed-wet states were created by altering the wettability of solid surfaces in contact with the non-wetting phase at the end of the unsteady-state simulation of initially water-wet porous media. JBN relative permeability results were compared to input relative permeability. The JBN results were found to match input data relative permeability especially at lower capillary pressure. The relative permeability of water in the mixed-wet porous media was found to decrease at lower to medium flow rates as water is pinned in smaller pore spaces leading to lower saturation and connectivity in wetting layers. Meanwhile, oil relative permeability increased due to higher connectivity and therefrom greater mobility. On the hand, oil relative permeability of in the mixed-wet porous media decreased at higher flow rates where water connectivity increased the relative permeability of water with increasing water saturation. A new JBN based model was developed to determine relative permeability and good matches were observed between the JBN calculated results and the input relative permeability. Therefore, the model can be utilized for various porous media applications at different wetting conditions.
Connectivity Analysis of Wireless FracBots Network in Hydraulic Fractures Environment
Authors: Alshehri Abdallah A , Shewoil Abdulelah H 
Published: November 2020

Abstract
Fractures Robots (FracBots) are underground IoT (internet of things) wireless sensor nodes designed to be deployed in oil/gas reservoirs to map hydraulic fractures (HF) and monitor in real-time main reservoir parameters including pressure and temperature in real-time. A significant amount of FracBots will be injected inside hydraulic fractures immediately after conducting the fracturing job to gain the required data. They will launch the network connectivity in a fashion of FracBot-to-FracBot to collect, exchange data and transmit it to the base station installed in the wellbore. FracBots technology employs the same concept of the wireless underground sensor network (WUSN), a very capable technology for the applications in hydraulic fractures network. However, developing such technology is exceptionally challenging due to many environmental complications. The main challenges are severe environment, size, and energy limitations which contribute heavily to destroying the quality of the underground wireless communication link. FracBots technology comprises a gateway, a base station (BS), and FracBots. The main role of the BS is to transfer power to FracBots for charging purpose, gather data from FracBots, and finally transmit data to a gateway that send them to a centralized computer for further processing. The function of FracBot nodes is to sense the required data, send it wirelessly among them in multi-hop fashion and then communicate data to BS.
This paper discusses the available wireless communication techniques including electromagnetic waves (EM) and magnetic induction (MI) wireless communication that might be suitable candidates for hydraulic fractures environment. They are compared in terms of the path loss model, path loss parameters, and the advantages and disadvantages of each technique. Moreover, we provide several simulations showing the importance of omnidirectional antenna and the effect of an alignment angle (between the axes of transmitter and receiver) on the path loss of the MI network. Also, we analyze the environmental effects on the path loss inside hydraulic fractures. After studying both EM and MI techniques in fractures environment. We found that the heterogenous environment stiffly influences the EM and MI communications inside hydraulic fractures in oil reservoirs. A hybrid solution that combines both EM and MI communication technologies will be very suitable for such an environment.
Improving Operational Performance Through Digitalization of Standing Instruction to Driller SID
Authors: Hamid Mohd Ridzuan , Meor Hashim Meor M , Norazman Nor Ashraf , Norhashimi Lokman bin , Hamzah M Hadi , Arriffin Muhammad Faris , Mohamad Azlan bin 
Published: November 2020

Abstract
With the current format of SIDs being completely different each project and manually typed in every rigs, improving operational performance based on lessons learned can be quite complicated. The digitalization of Standing Instruction to Driller (SID) can help to overcome this pain point by standardizing and synchronizing SIDs throughout company's operations globally. The paper approaches the subject by introducing a much leaner and seamless method in registering an SID. This can be achieved by having relevant drilling personnel to pick and choose from a common database of SIDs which is frequently updated and verified via web-based platform. The dropdown will be automatically filtered by the application according to the BHA and/or other relevant filter categories chosen. Digital SID drafting process will begin after Notice of Operations (NOOP) has been completed. Information from the NOOP will be populated in the Digital SID platform with all the required associated details including but not limited to BHA designs, hole sections, depths, procedures and lessons learned. These SIDs will have to be agreed and approved by assigned personnel prior to the execution of the operation. Since the solution is capable to create a high quality SID which is readable by both human and machine, it can be integrated with real-time sensors to provide automatic detection for every operation in the SIDs. Therefore, implementation of this Digital SID solution can sustain SIDs consistency across different projects and capable to embed insights in context for future reference. Direct business value created from Digital SID improves process cycle efficiency in a project well life cycle.
Minimum Facility Platform Bring Sub–Commercial Back to Life
Authors: Lophongphanit Chaowarit , Sookkij Kanlaya , Thippayawarn Anucha , Oonkhanond Pariyachat , Medheethunyapong Napa , Theinkaew Sornnarong , Kulavong Passakorn , Hongtong Pongpat , Viriyasomboon Napas , Chotmongkol Prasitsan , Juengsiripitak Jirat 
Published: November 2020

Abstract
Zawtika Project is an offshore gas field located in the Gulf of Moattama, Myanmar with water depth ranges from 120 meters to 160 meters. PTTEPI has operated Zawtika field and brought it to production since 2014 with conventional wellhead platforms (CWP) development. The future prospects are expected to be smaller gas reservoirs which are not commercially developed with CWP. Thus, a minimum facilty platform concept study had been initiated after CWP cannot be economically justified to develop and maintain gas production plateau.
The basic engineering study was conducted on the selected wellhead platform options namely Zawtika optimized conventional wellhead platform (ZOCP) and Zawtika minimum facility platform (ZMFP). These platform types will be chosen for EPCI based on the size of the candidate prospects after the post-appraisal well result is confirmed.
ZOCP is merely a conventional wellhead platform with partial design optimization. On the other hand, ZMFP is a true minimum facility platform. This paper will focus on this type of platform.
ZMFP capacity is reduced to match with the target prospects at 90 MMSCFD gas production. The facilities equipment and intra-field sealine are also reviewed and optimized. ZMFP is expected to reduce the CAPEX approximate up to 20% from (1) minimized well slots (2) commingled the flowlines (3) sweet gas material compatible selection. The unique design of ZMFP is the power supply comes from 100% solar power which is a new implementing concept.
Estimated of the base weight of ZMFP is 17% lower than CWP leading to estimated CAPEX reduction almost 20% compared with CWP. However, due to the stability of platform under the water depth of Zawtika field condition makes the wellhead platform design to be a 4-legged jacket. Small improvement can be done at the jacket which is about 65% of the total CAPEX.
Then an economic evaluation is carried out to compare the NPV of the existing platform design with the improved ZMFP, it found that NPV improve significantly almost 15 %. With the lowering down of the CAPEX, at this stage ZMFP design currently enables 3 sub-commercial prospects to be economically developed. ZMFP design is already selected to implement with the coming Zawtika phase 1D development for 3 wellhead platforms and now it is under EPCI preparation.
Zawtika minimum facility platform demonstrates PTTEPI aims to maximize the resource recovery of the field by developing and monetizing sub-commercial reservoirs. With the above-mentioned objective, a new platform is engineered and designed to sacrifices some options down to its fit-for-purpose facility yet maintain the integrity and environmental friendly designs.
SEAR JIP: A Success Story of Collaboration and How to Improve Equipment Reliability on Subsea Production Systems
Authors: Botto Adriana , Tomar Manish , Ferrier Stuart , Berzins Chris , Casey Mark , Marstrand Jesper , Smith Harvey 
Published: November 2020

Abstract
The award-winning Subsea Equipment Australia Reliability (SEAR) Joint Industry Project (JIP); is a partnership led by Wood with participation from a group of operators namely Chevron Australia, ConocoPhillips, Inpex, Santos, Shell Australia and Woodside. Now delivering Phase 6, the JIP is focused on collaboration and knowledge sharing in order to improve the competitiveness of Australia's oil & gas industry by addressing critical challenges associated with subsea equipment failing prematurely.
This paper will provide an overview of the SEAR JIP and outline lessons learned, and value created. Results from the reliability database will be presented as well as findings from ongoing field trials on the four living laboratories deployed in different geographic locations and water depths in Northern Australia. This paper will also discuss challenges associated with subsea controls umbilicals that are prone to emit hydrogen gas and fluids at the surface facility through the electrical junction boxes.
The end goal of SEAR JIP is to develop an industry wide recommended practice, with regional guidance notes for equipment and field design. The recommended practice is intended to reduce operating cost for existing and future projects, while identifying technologies that are specific to Australian waters.
Identification of Fracture Properties in Shale Oil Reservoirs by a Well Testing Model: A Case Study
Authors: Jun Pu , Qin Xuejie , Chen Zhiming , Shi Luming , Wei Yi , Chen Haoshu , Meng Meiling , Gou Feifei 
Published: November 2020

Abstract
In the shale oil reservoirs, the horizontal wells with large-scale fracturing treatments have been the most effective tools to enhance oil productivity. After large-scale fracturing treatments, many micro-seismic data showed that the fracture networks are generated in the reservoir along the wellbore. Understanding the complex fracture properties is the primary step for fracturing evaluation and productivity estimation. Thus, an efficient approach is needed to estimate the fracture properties. To improve this situation, a well-testing approach was proposed in this work to identify the fracture properties. This work was organized as follows: (1) developing a well-testing model of multiple fracture horizontal well (MFHW) including reservoir flow equations, fracture flow equations, and mass balance equations, (2) solving and verifying the proposed model using boundary element method, superposition principle, and numerical approach, (3) applying the well-testing model to investigate the pressure transient behaviors, and (4) estimating the fracture properties of shale oil wells from the Junggar Basin.
Compensating the Effect of Shallow Gas Cloud for Seismic Time-to-Depth Conversion
Authors: Azmi Afifah , Mad Zahir M Hafizal , Ishak M Anwar , Mohd Adnan Amar Ghaziah , Megat Ismail Megat Iskandar , Che Lah Che Zurida 
Published: November 2020

Abstract
Shallow overburden, specifically gas cloud, will create velocity anomaly. The anomaly will make the events underneath to be disrupted, thus affecting the seismic reflectors. Velocity model build from the seismic with the existence of anomalies will give us an inaccurate velocity estimation. Velocity model is crucial for various processes and one of it is for time-to-depth conversion. Therefore, it is very critical to have an accurate velocity model in order to provide us actual subsurface structures and lead us to the true reservoir location. In this paper, we will explain on our proposed approach to condition the velocity model with gas cloud problem. The robustness of the method was tested by using different velocity models for time-to-depth conversion and the results were analyzed. The criteria of the best depth map are conformance with geological structures, accurate well tie with the existing well and minimal residual errors within acceptable range. From the study conducted, we have proved that the seismic velocity with gas cloud correction provides the best depth map with minimal residuals.
Road Map Towards the Integrity Assurance of Composite Repairs in Offshore Facilities
Authors: Choo Wei Lee , Arifin Rosman , Mohd Ramli Siti Haslina , Syed A. Hamid Syed Muhsin 
Published: November 2020

Abstract
Composite repairs on pressurized equipment, piping and pipeline in offshore facilities have become increasingly common due to its benefits in terms of cheaper cost and faster repair time, which generally leads to avoidance of potential production downtime. PETRONAS has developed a roadmap which is in alignment with currently available international code and standard references on integrity assurance program for composite repairs, such as ISO 24817. This roadmap seeks to manage the risks involved during all phases of a composite repair program (i.e. pre-installation, during installation, post installation and periodic monitoring). It focuses on five primary elements namely: 1. inspection tools evaluation including desktop evaluation, technology demonstration, pilot program implementation, and summary of inspection methodologies, 2. Governance establishment covering development of company guideline, 3. Competency management enhancement via personnel training, certification schemes, and roles and responsibilities establishment, 4. Procedure, planning, implementation & monitoring, and 5. Continuous improvement via assurance programs and management review. This paper summarizes some of the efforts undertaken, and future plans to support each of the abovementioned phases as part of a comprehensive solution for the integrity assurance of composite repairs in offshore facilities.
Pipeline Integrity Management and the Invent of Analytics
Authors: Mohd Ali Napiah Mohd Nazmi , Abu Bakar Mohd Hisham , Mat Tuselim Ahmad Sirwan 
Published: November 2020

Abstract
Managing pipeline integrity revolves around abundance of data and information from monitoring of safe operating limits, inspections and maintenance. Those data and information may come from real-time/on-line systems, manually input ad-hoc, manually input from inspections and maintenance carried out on a particular pipeline. The oil and gas pipeline industry have sort of mature with respect to having a software/tool in aiding and assisting personnel in performing risk, fitness-for-service, repair assessments, and executing management of change for a pipeline system; and many more assessments/analyses.
Nevertheless with the invent of analytics, there is strong need to explore the new ways of working with those abundance data and information OR maximising the utilisation of the data and information for the benefit of assessing or evaluating pipeline's risk and integrity to predict 'accurately' risk and integrity so that specific and cost-effective actions and mitigations can be deployed within a stipulated period of time.
In those regard, PETRONAS is actively working with industry to establish predictive analytics for critical offshore and onshore pipelines' threats/anomalies i.e. internal corrosion and free span for offshore; and external corrosion and geotechnical hazard for onshore. This paper will dwell on the principles, concepts and methodology of predictive analytics tools for the development. It is envisaged that eventually those threats/anomalies will be analytics-managed to eliminate unwanted incidents to PETRONAS's offshore and onshore pipelines. In addition, analytics-pipeline integrity management will also likely to provide 'accurate' prediction of 'future' pipeline integrity.