bluuebunny/crossref_metadata_2025_split huggingface dataset:
Jack-Up Rig Installed Structure for Marginal Field Development
Authors: Raja Badrol Raja Sharifuddin , A. Rahman Ahmad Rizal , M. Daud M. Hafis , A. Razak Zahari , Rohani Muhammad Joehan , Saifuzzaman Syamsulzaidi , M. Sidek Ahmad Mahmud , Natarajan Shreenaath , Ismail Muhammad Yussof , Rosli Hilal 
Published: November 2020

Abstract
Fixed offshore structures has predominantly been installed via the conventional crane barge, no matter whether it is small or a big structure. Utilization of a crane barge has resulted in a significant installation costs as the mobilization cost and the Daily Charter Rates (DCR) for the vessel is very high. Supporting the innovation agenda in an effort to better control project costs, the rig-installed platform concept is one of the option chosen to install small lightweight structure due to the cheaper cost of Jack-up Rig (JUR) day rates compared to a conventional crane barge.
The savings in material, schedule and mobilization could be realized as the jack-up rig can proceed with the drilling of the wells (which are also the main piles of the structure) directly after the structure installation. As JUR is primarily used to drill oil/gas wells, some minor modification may be required to the JUR before it can be utilized to install small and lightweight offshore structures, both jacket and topsides, with some degree of limitations due to the drilling envelope and derrick lifting capacity.
This ‘know-how’ has been around for quite some time in the industry by niche service providers, but was not regularly exploited in this part of the world as it has been a norm for the field development team to manage an installation contractor whilst the wells team manage a drilling contractor. This paper shares the learnings of a wellhead platform for a marginal field that was successfully engineered, fabricated and offshore installed using a JUR and eventually achieved 1st Oil within 9 months of contract award at an installed cost below USD 29 Million. This paper will mainly discuss on the pre-requisites of JUR installed platforms, case for change, concept select and potential value creation to the overall project.
The project referenced above has exemplified to the industry that JUR installed platform is a feasible option in this part of the world, with significant cost savings, contributing to a better economics for a marginal field project.
Challenges on the Installation of Offshore Floating Units in Congested Subsea Fields and Exposed to Tropical Squall
Authors: Bamdad Mehrdad 
Published: November 2020

Abstract
Positioning and installation of a floating production unit requires mobilization of necessary marine spread associated with comprehensive engineering preparation. Risk based rules and regulation define certain criteria as general guideline but to be firmed and verified based on risk assessment. This paper reviews the criteria in a tropical area with congested subsea facilities where the squall wind brings some risks to the installation and with subsea facility as already installed or wet-stored which makes the normal criteria more difficult to be met. With reference to a successful recent installation, procedure for the installation in terms of engineering assessment and operational works proposed.
In this paper, risks and uncertainties with an offshore floating unit are presented based on marine spread with variation in their characteristics and reliability, mooring system characteristic and redundancy, engineering and installation team capabilities. Practical possibility considered to mitigate the given risks and based on that, positioning and installation criteria revisited against the general criteria as come from standard. Relevant engineering analyses are proposed with the type of results expected.
As results, a practical procedure for an installation with recommended sequences, type and characteristics of marine spread and mooring equipment are provided. Some recommendations are provided for field development and overall project schedule to be considered in an early stage of a project to ease the installation phase and reduce risks and costs. Some key engineering analyses for station keeping and line transfer are proposed to verify capacity of the proposed installation spread against the possible environmental and operation scenarios.
This paper provides some further clarity in terms of installation criteria and procedure for positioning and installation of offshore production units particulary for the spread moored system with reference to a successful installation campaign in tropical area subject to squall and congested subsea field.
De-Risking the Prospect Maturation by Hydrocarbon Saturation Assessment on Carbonate Reservoir Characterisation, Central Luconia, Sarawak, Malaysia
Authors: Ahmad Tarmizi Nor Aiman , Lim Pei Wen , Ou Kuan Ee , Tolioe William Amelio , Hanalim Linda 
Published: November 2020

AbstractSeveral discoveries of carbonate reservoirs are reported in Central Luconia, which initiated numerous carbonate characterization studies there. The outcomes are vital as analogues for prospects maturation, especially in estimating input parameters for hydrocarbon volume in-place assessment. However, hydrocarbon saturation is hardly discussed. This paper presents a comparison of some saturation-height functions commonly used in the oil and gas industry leveraged as the regional approach preference to optimize hydrocarbon saturation assessment in the volumetric estimation of carbonate reservoir in Central Luconia.This study focuses on hydrocarbon saturation, one of the key parameters in the volumetric assessment. A few saturation height function methods are tested on the studied field, integrated with the understanding of carbonate characteristics like rock quality and rock type on analogue field or block, to optimize the prospect assessment. Standard and advanced log data were used in this context, to effectively derive saturation height functions. In addition, capillary pressure (Pc) data was used to calibrate the derived saturation height function equation. The saturations from different methods are then plugged-in for volumetric estimations.One of the two outcomes from this study is a thorough comparison analysis of saturation values obtained via different methods; and a suitable analogue to be applied for future prospect evaluations as regional model, obtained through analyzing end results of volume in-place calculated by various saturations computed, coupled with in-depth geological understanding of the prospects to analogue field or block. The saturation height function was weighted by area-depth to account for the gross rock volume and compared against post-drill results. The analogue is to be utilized to derive saturation height equation when there is no data available for any prospect.To-date, there is a rising interest in carbonate reservoirs prospects evaluations, which usually come with very limited data. It is hard to ascertain the techno-commerciality, to risks with such minimal information, from volume in-place to economics. Hence, the findings of this study will assist in reducing the uncertainty in hydrocarbon saturation assessment. The analogue developed is handy to be replicated for similar carbonate reservoirs in Central Luconia, or other locations. By selecting the appropriate saturation assessment methodology and suitable analogue as a reference, the risk and uncertainty of prospect evaluation and maturation shall be further diminished.
Thermal and Rheological Investigations on N,N'-Methylenebis Acrylamide Cross-Linked Polyacrylamide Nanocomposite Hydrogels for Water Shutoff Applications
Authors: Keishnan Mohan Raj , Michael Feven Mattewe , Almohsin Ayman Mohammed , Alsharaeh Edreese H 
Published: November 2020

Abstract
Herein, we report thermal and rheological investigations on PAM nanocomposite hydrogels that are cross-linked with N,N’ methylenebis acrylamide (MBA) in presence of Zr(OH)4 and Zr(OH)4G fillers with a potential for water shutoff applications. The fillers such as Zr(OH)2 or their composites Zr(OH)4G were found to enhance the thermal and mechanical characteristics of the PAM hydrogels in addition to the organic cross-linker. The samples were prepared with different weight percentages of MBA with and without the presence of fillers. The samples were characterized by dynamic scanning calorimetry (DSC), thermogravimetric analyses (TGA) and dynamic mechanical analyses (DMA). Upon investigating the thermal properties of the hydrogels, the neat-PAM hydrogels have shown a maximum of the bound water content of 0.45 with 0.3 wt% of MBA while the PAM-Zr(OH)4 with 0.3 wt% of MBA cross-linker had higher bound water of 0.41. However, when Zr(OH)4G was used as a filler, the ones with 0.15 wt% of MBA showed a higher bound water content of 0.35. The TGA results revealed that there is a significant increase in the degradation temperature (Tg = 181°C) for the neat-PAM hydrogel with 0.3 wt% of MBA in comparison to that of neat-PAM with 0.15 wt% of MBA (175°C), indicating that the chain mobility of the polymer matrix at a lower temperature was decreased when the cross-linker concentration was increased. For the PAM-Zr(OH)4 and PAM-Zr(OH)4G nanocomposites, the Tg were found to be higher with 0.3 wt% of MBA in comparison to the ones with 0.15 and 0.6 wt%. The gel strength for neat-PAM is calculated to be 13.5 and that of PAM-Zr(OH)4 and PAM-Zr(OH)4G nanocomposite hydrogels are 4.2 and 12.8 respectively. In contrast to the gel strength, the PAM-Zr(OH)4 nanocomposite hydrogel displayed a high damping factor (tan δ = 0.23) in comparison to that of PAM-Zr(OH)4G (0.08) and neat-PAM (0.07).
Condensate Banking Characterization and Quantification of Improvement from Different Mitigations Using Pressure Transient Analysis: A Case Study in Hai Thach Field Offshore Vietnam
Authors: Pham Duy Hoang , Hoang Son Ky , Trinh Vinh Xuan , Tran Tung Vu 
Published: November 2020

Abstract
To successfully mitigate a near-wellbore condensate blockage, the status of the condensate blockage must be thoroughly understood. This case study proposes a new technique of pressure transient analysis (PTA) to investigate the formation and impact of condensate banking on well deliverability. This new PTA technique was successfully applied to the largest reservoir of the high-pressure high-temperature Hai Thach field, providing valuable information in designing mitigation programs. Finally, two mitigation methods (hydraulic fracturing and condensate bank removal) were investigated to evaluate their potential production enhancement.
The entire production history with many buildups was matched systematically and simultaneously by PTA to determine the skin factor evolution in addition to reservoir permeability. An increasing trend of skin factor confirmed the presence of condensate blockage in the near-wellbore area and provided information about the time required for the condensate bank to form. In addition, the size of the condensate blockage was obtained from the radius of the radial composite reservoir model. Finally, improvement on production rate by two mitigation methods was examined using typical skin factors achieved by these methods.
Two production wells from the main reservoir of Hai Thach field were selected for this study. From observed data, the gas rate of the first well reduced rapidly from 10 MMSCF/d to 4 MMSCF/d and the second well had a low stable rate of 3 MMSCF/d. The application of PTA revealed that skin factor of the first well dramatically increased from 0 to roughly 11 and similar behavior was also captured at the second well as this value increased from 0.5 to around 5. This upward trend of skin factor confirmed the presence of condensate blockage at near-wellbore regions of these wells and it took approximately 5 months to form the condensate bank. The radius of condensate bank was also determined at roughly 14 ft and the average permeability of these wells fall in the range of 0.2 to 0.5 mD. In addition, the mitigation analysis on two production wells showed that hydraulic fracturing and condensate bank removal methods could improve well production rate up to approximately 180% and 100%, respectively.
From conventional well testing techniques, it is challenging to obtain further information of condensate bank in a near-wellbore region. This case study proposes a novel application of PTA which successfully provided in-depth knowledge of condensate blockage, such as condensate bank size and formation time. This information is crucial in designing mitigation programs to improve recovery of affected wells. The potential enhancement on production rate from different condensate banking mitigation methods was also quantified, providing valuable information on the feasibility of such mitigation jobs.
Production of Biopolymer Schizophyllan Using Local Sources in Malaysia
Authors: Gunaji Radhika Gautam , Junin Radzuan , Bandyopadhyay Sulalit , Guttula Pavan 
Published: November 2020

Abstract
In recent years polymer flooding has been field tested extensively and has succeeded in many Enhanced Oil Recovery (EOR) projects. The use of synthetic polymers in EOR is undesirable from an environmental perspective. Further, due to limitations of the existing synthetic polymers in high temperature and high salinity conditions, thermal degradation among other drawbacks, biopolymers have attracted the attention of the petroleum Industry. Recently, the use of biopolymer schizophyllan for polymer flooding operations has been found to have advantages such as stability under high temperature and high salinity conditions. This biopolymer is commercially produced from the fungus schizophyllum commune using glucose as a carbon source via fermentation process and is currently available in small quantities as an expensive purified pharmaceutical and cosmetic grade material. Our study aims to utilize locally available sources in Malaysia to synthesize the above biopolymer making it cost effective. The fungus schizophyllum commune commonly known as "cendawan kukur" in Malaysia was used as a starting material. Different production media containing carbon and nitrogen sources, required for the growth of the fungus, were utilized for the biopolymer production. Initial viscosity studies carried out using rheometer showed that, the production media comprising sago starch as the carbon source and potato extract as the nitrogen source, showed the highest viscosity value of 0.12 Pa-s at 30°C. Therefore, this media was chosen as the most favorable media for the biopolymer production. Further, the biopolymer extracted from this media was identified by Fourier Transform Infrared (FTIR) spectroscopy which showed similarity in chemical structure with reference to commercial schizophyllan data from the literature. The results from Thermo Gravimetric (TG) analysis showed that the biopolymer was thermally stable at higher temperatures similar to that of the commercial schizophyllan. This study would develop the utilization of locally available sources to produce schizophyllan for polymer flooding operations by explaining various characteristics so as to meet the expected requirements for it to be applied in an oil field.
Deep and Thin Overpressure Reservoir Characterization of Paleogene Formation Wenchang in the Enping 17 Sag of the South China Sea
Authors: Liu Jun , Li Yingwei , Liang Donghai , Peng Guangrong , Bai Haijun , Ruan Xiaomin , Xu Jianhua , Zeng Rui 
Published: November 2020

Abstract
Only one wildcat well had been drilled for deep formation hydrocarbon exploration (4400 m to 4800 m) and partially penetrated into Lower Paleogene Formation Wenchang (FM WC) without commercial oil discovery in the Enping 17 Sag, northern of the Pearl River Mouth Basin in the South China Sea. Although large thicknesses of grey lacustrine mudstone with abundant organic material are proven to be the regional source rock, lack of a good reservoir for hydrocarbon accumulation in FM WC is the failure reason for this well. Encountering a 9-m-thick sand layer at a depth of 4650 m indicates that braided fluvial delta and lowstand turbidite sandstone may develop in the FM WC, and the zones below upper section 1 of FM WC are proved to be overpressure. It protects pores in the deep reservoir from compaction. Condensate gas was observed by drill stem test (DST) in overpressure sand layer while no gas was measured in sand layers above the overpressure zone. Aiming at delineating effective reservoir in FM WC, an integrated workflow for 3D seismic reservoir characterization of offshore deep and thin layers was developed for this area without sufficient well data. The workflow includes seismic data reprocessing, well log-based rock physics analysis, seismic structure interpretation, 3D simultaneous amplitude variation with offset (AVO) inversion, 3D lithology prediction, and geological integrated analysis. We present four key solutions to address four specific challenges in this case study: 1) application of adaptive deghosting (AD) techniques to remove the source and streamer depth-related ghost notches in the seismic data spectrum and the bandwidth extension (BWXT) technique to improve the seismic data resolution; 2) a practical rock physics modeling approach to consider the formation overpressure for pseudo-shear sonic log prediction; 3) interactive and synchronized workflow between prestack 3D AVO inversion and seismic processing to predict a 9-m-thick layer in FM WC after 60+ rounds of cyclic tests; 4) cross validation between seismic qualitative attributes and quantitative inversion results to verify the lithology prediction result with limited well data.
Selection of Right Inspection Tool for Challenging Pipeline
Authors: Abdullah Mohamed Ali , Koi Swee Ling , Rahmad Ahmad Najib 
Published: November 2020

Abstract
PETRONAS is operating more than 10,000km of offshore and onshore pipeline systems. Inspection and monitoring is one of the element in the Pipeline Integrity Management System (PIMS) where it covers critical activities to ensure high integrity and reliability of business operation for transportation of oil, gas and petrochemical products. This will further identify the risk and manage the pipeline through its operating design life. PETRONAS currently facing new challenges in managing onshore pipeline with girth weld anomaly and stress-strain issue due to geohazard threat.
This paper will describe the inspection options that have been evaluated in addressing stress-strain and girth weld anomaly threats. MFL technology with enhanced inspection capabilities coupled with Geopig are the most reliable technology to ascertain the weldment integrity threat as well as stress-strain of the pipeline.
The replication of inspection tool selection can be applied for offshore pipelines having issues/challenges with respect to geohazards i.e. faults, gas pockets that can induce movement, differential settlement of seabed etc.; and weldment quality verification. The enhanced MFL inspection technology is also collaboration between PETRONAS, local vendor and international inspection company.
A Comprehensive Surfactant Performance Assessment in Harsh Malaysian Reservoir Conditions
Authors: Belhaj Ahmed Fatih , Elraies Khaled Abdalla , Mahmood Syed Mohammad , Tewari Raj Deo , Elryes Ahmed Abdulla 
Published: November 2020

AbstractSurfactants have the ability to overcome the capillary forces restricting mobilization of oil in the porous media. Generally, the application of surfactants in harsh reservoir conditions has been avoided, due to the challenges accompanying their implementation in such conditions. In this paper, the performance of a mixture of Alkyl Ether Carboxylate (AEC) and Alkylpolyglucoside (APG) was experimentally investigated in harsh reservoir conditions. A Malaysian offshore field with challenging conditions has been studied in this present work, with a reservoir temperature of 106°C and injection water salinity of 32,000 ppm. The investigations were made using surface tension, interfacial tension and partitioning experiments. Surfactant concentration was measured throughout the partitioning test using High Performance Liquid Chromatography (HPLC). The results of the surface tension test showed that the CMC for AEC:APG mixture was approximately 0.13 wt% at 106 °C. IFT results showed that the presence of the surfactant mixture was capable of reducing the IFT between crude oil and brine, and achieve low IFT value (0.035 mN/m) in such harsh conditions. Partitioning test results explained the partitioning behaviour of the surfactant molecules into the oil-water interface. Additionally, surfactant concentration, brine/oil ratio and salinity have a significant impact on surfactant partitioning. The results corresponded to the interfacial tension behaviour, where the lowest IFT value was observed at the highest kp value for the AEC:APG mixture. This concluded that the partitioning coefficient can be directly related to interfacial tension. Furthermore, the increase of the brine/oil ratio as well as the salinity, portrayed an increasing trend of the kp values. The findings of this study showed promising outcomes for future implementation of surfactant flooding in such harsh conditions. By using the proposed surfactant mixture, potential success becomes likely for surfactant flooding application in this study under harsh reservoir conditions.
A Streamlined Multidiscipline Workflow for Pipeline Slugging Assessment
Authors: Zhang Jeff , Jha Saurav , Matuszyk Tim 
Published: November 2020

Abstract
Free spans exist in subsea multiphase pipelines laid over undulating seabed profiles or across continental scarps for offshore field developments. Slug flow induced fatigue damage on the free spans can potentially lead to pipeline re-sizing, more restrictive installation and welding requirements, and limits on life-of-field operational flexibility; these, in turn, have a significant impact on project economics. Slug flow assessments are typically associated with large uncertainties (e.g. flow conditions and span arrangement) and therefore require comprehensive sensitivity analysis to confirm robustness; this can prove time-consuming. This presents opportunities for significant optimisation in workflows to target governing operating scenarios.
This paper describes an integrated iterative approach between the Flow Assurance and Pipeline engineering disciplines to streamline the workflow based on the value or cost associated with changes in input parameters that impact pipeline fatigue assessment outcomes. Case studies on two multiphase pipelines (one with multiple long spans introduced by undulating seabed profile and another featuring a very long span across a continental scarp) are presented to illustrate this design approach.
The results show that early identification of the key pipeline profile features and dominating spans for pipeline slugging fatigue assessments facilitated the Flow Assurance slug flow modelling optimisation and reduced the computational time. Early engagement and alignment regarding pipeline assessment methods and desired slugging data requirements were very valuable for optimising the Flow Assurance slug flow modelling fidelity and also to minimise data processing requirements for both Flow Assurance and Pipeline disciplines. Timely feedback from the Pipeline discipline regarding fatigue accumulation based on screening work performed using an initial slugging data set with a wide flow rate range helped narrow down additional slug flow scenarios to be modelled by Flow Assurance.