bluuebunny/crossref_metadata_2025_split huggingface dataset:
An Era to Remember: Managing Offshore Drilling Campaign During World Pandemic Covid-19 Crisis
Authors: Ismail Ahmad Luttphi , Ishak M. Faizatulizuddin , Idris M. Idzarul , Abdul Hakim Hazlan , Othman M. Fikree , Chandran Kayathiri , Alias A. Hakim , Rozlan M. Rizwan , M. Ghazali M. Haziq 
Published: March 2022

Abstract
When the pandemic COVID-19 erupted and spreaded throughout the world, numerous rules and regulations were implemented to ensure the safety of everyone. The outcome of Covid-19 resulted in a global shutdown, where cases continued to grow rapidly that directly affected the normal processes in all business sectors. While the future is still uncertain, business plan must keep on progressing by managing all the obstacles to ensure the business goal is delivered efficaciously while keeping the impact as low as possible. In the early stage of the outbreak, there was limited knowledge and experience to manage a drilling campaign virtually, to ensure all plans are smooth despite all the restrictions to avoid additional cost and schedule impact to the company.
Since the outbreak was quite abrupt, the main challenge faced by the team was to ensure a continuous operation like any other year before but with additional enforcement of stringent COVID-19 SOP and to come up with new modus operandi with stringent SOP at every location. During this pandemic, the operation is exposed to the risk of being on standby mode due to equipment unavailability, unreadiness of manpower or delay in vessel movement. Knowing that drilling operation is so dynamic, that a slight change to the drilling sequence could lead to operation shutdown if the required services are not readily onboard. This uncomplimentary impact is due to the new rules or regulations implemented on the manpower and equipment movement to reduce risk of Covid-19 infection. Therefore, a thorough planning is crucial to ensure the success of operation, in fact a few fallback plans must be in placed to minimize the cost and schedule exposure.
This paper will address the challenges in managing equipment and manpower throughout the operation for BX-Project together with the solutions to ensure the governance, rules and regulations of Covid-19 are being followed. The approaches taken during this campaign is used as a baseline to run a drilling operation during Covid-19 pandemic in the upcoming year. Lessons learnt captured from this campaign can be replicated by other projects and finding the more efficient ways to implement the best practices. This pandemic has challenged our perseverance to deliver the project objectives while maintaining the dedication, health, focus as well as creativity to overcome unfamiliar circumstances.
Numerical Simulation of Whole Process Flow of Cementing Slurry
Authors: Liu Shan Shan , Li Rui Long , Yuan Wei Wei 
Published: March 2022

Abstract
Cementing is an important link in the process of oil and gas well construction. The quality of cementing directly affects the safety of next drilling, recovery capacity and life of later production. It is very important to accurately reflect and describe the dynamic changes of various underground parameters in the process of cementing for reasonable control of construction measures and guarantee the quality of cementing replacement. Based on the study of the dynamic process of cementing, the field equation is simplified to ID model by using the principle of momentum conservation and mass conservation, and the calculation model of cementing dynamic parameters at any time considering the effect of U-shaped pipe is established, including bottom hole pressure, friction, height and volume of vacuum section, static pressure in pipe and annulus, ECD and other dynamic parameters. The initial value problem is solved numerically by iterative method. The software of cement slurry flow simulator is developed, which is used to visually simulate the cement slurry flow process. The numerical model development software can be used to visually simulate the dynamic flow process of cement injection, which is suitable for complex wellbore structure and multi fluid injection. It can simulate the whole flow process of cement injection well, including the generation of U-tube effect, and analyze the variation law of dynamic parameters. The software can be used to simulate the dynamic flow process of cement injection, which is suitable for complex wellbore structure and multi fluid injection including the generation of U-tube effect, and analyze the variation law of dynamic parameters. Field data of a well was verified, and the results show that the proposed method can accurately calculate the flow parameters in the whole process of cementing, and can be used to guide the design of cementing operation. The innovation of this paper is to develop the simulation software of cementing slurry dynamic process. The function modules of the software use numerical model instead of empirical formula to improve the calculation accuracy of each parameter. The software has comprehensive functions, and gives the dynamic parameter change law of each stage in the fixed construction process. It has strong practicability and can well meet the requirements of on-site construction.
First Field Deployment of Erosion Control Technology for High Sand Production Wells in Offshore Malaysia
Authors: Myo Thant Maung Maung , Che Daud M. Faizal , Tuan Mahmud Tuan M. Yusoff , Kayat Zainab , Xian Lung Ivan Chee , Ngo Tran Nguyet , McNaught Rob , Wood Terry , Kiat See Chin 
Published: March 2022

Abstract
Sand production in oil and gas fields severely affects multiphase flow pipelines, piping and production facilities result in erosion damages and operational difficulties including valves, bends and other geometric fittings leading to loss of primary containment (LOPC). Presently, there is no technology available which can control sand erosion in real-time and help optimize production. This paper aims to present the first field deployment of a uniquely engineered flow modification device in debottlenecking a high sand producing well and maximizing production while reduction in erosion.
The sand erosion challenge can be overcome by using a patented Erosion Control Technology (ECT), to deflect and redistribute sand in the product flow stream. ECT has been successfully developed and validated through three test programs between 2016-2019. Following these, ECT technology maturity has been qualified for field application and selected to be deployed by PETRONAS, in one of the offshore fields located in Sabah, Malaysia, which is currently experiencing high erosion due to high sand production. The ECT pipe spool consists of a 3D printed Inconel 718 alloy insert integrated into carbon steel pipe to protect an elbow from sand erosion within the topsides wellhead piping system upstream of the wellhead choke. A control elbow upstream of the ECT device has also been installed to act as a mean of comparison throughout the pilot.
The protected elbow and control elbow will be monitored using manual UT at marked locations to measure localized wall thickness variation over the pilot testing period. The pilot is part way through its test program having been installed and commissioned at the end of 2021. Photos of the arrangement are shared in this paper along with the baseline wall thickness measurement.
The pilot trial success criteria are to show that the protected elbow will have minimal wall loss compared to the control elbow showing the effectiveness of ECT. The pilot expects ECT to reduce erosion due to sand and safeguard the facilities as well as maximize well production in preventing shortfall in total field production.
Novel Reservoir Sand Grain Size Map Based on Open Hole Gamma Ray Log as Im-Proved ThruTubing Sand Screen Size Selection Guideline on Tunu Multi-Layer Un-Consolidated Gas Reservoir
Authors: Setiadi Rahman , Jong Yulianto , Mahfudhin Nur , Muwaffaqih Mutawif Ilmi , Dading Albert Richal 
Published: March 2022

AbstractTunu is one of Mahakam fields with majority gas production. The depositional nature of fluvial with minimum tidal influence results in the signature of delta sedimentation by hundred layers of gas-bearing sand lenses as pay zone. They are constructed of unconsolidated clean and shaly sand reservoirs at the shallower burial and higher consolidation at deeper burial due to compaction and diagenesis. The unconsolidated section requires sand control as mandatory means to unlock it safely.The combined challenge of numerous sand layers and marginal reserves makes it economically impossible to perform regular detailed physical sand grain assessment by individual conventional coring completed with Laser Particle Sieve Analysis (LPSA). An economic approach is through performing sand bailing. However, the bailed sand dry-sieve results were confusing with wide particle size distribution (PSD) curve variation from several well samples. Referring to this PSD uncertainty, installing straddled thru-tubing screen in front of the reservoir as sand control resulted in good production and plugged indication at the beginning of the initiative by utilizing a similar screen opening size. Thus, a new fit-for-purpose methodology was required.A study to predict sand grain size on each reservoir target was initiated by analyzing three available shallow reservoir cores in Mahakam, which could cover most of Tunu's shallow sedimentation type. The result was that most of the sand grain size distribution on each sample core correlated with their calculated shale volume content (v-shale). Lower v-shale is respected to larger sand grain size. Unconsolidated Tunu Shallow reservoir doesn't contain any specific radioactive minerals. Thus, v-shale could be easily calculated from gamma-ray logs, which are always available on each reservoir target at any drilled wells. The relationship between sand grain size and v-shale was gathered on a single map.The map was then validated by historical screen installation. Positive results were seen when screen size selection respects specific patterns on the generated sand map at the v-shale value of perforation intervals. Thru-tubing screen installation campaign was continued following the new sand map reference. It could deliver more than 80% successful installation with no plugging or sand at a new perforated reservoir when no screen integrity issue due to erosion was encountered.This novel approach allowed better prediction of thru-tubing screen opening size requirements and perforation interval selection in Tunu unconsolidated reservoir and was successfully expanded in offshore Mahakam field at similar facies.
State of the Art Subsea Electric Control Systems
Authors: Champavere Claudine , Lacher Esteban , Moe Sigurd , Settiyannan Gunasekaran , Skrivervik Egil Mulstad 
Published: March 2022

Abstract
This paper explains the technology development to date of subsea electric valve actuation solutions for subsea production systems and discusses the roadmap for the future. Key experiences, and how these solutions are gradually becoming standard choice for many operators is discussed, from the subsea industry first applications 20 years ago.
Revised Methodology for Assessing Fixed Offshore Structures With Wave in Deck Loading
Authors: Lihin Zul Hilmi , Khan Riaz , Ishak M Izzat Muhaimin , A Rahman Azam , Kar Suman , Abdul Rahman Ahmad Rizal 
Published: March 2022

Abstract
Wave-in-deck (WID) loading has been an issue of concern for engineers dealing with the performance of fixed offshore structures. The issue is particularly relevant for reassessment of existing structures due to subsidence or structures designed to older codes and standards, where WID was not considered. WID issues often in costly subsea remediation, impact platform occupancy levels or premature decommissioning critical structures due to safety concerns.
The current in-house procedure is a simplified approach and revised to reflect the silhouette method and new industry requirements for the reliability of fixed offshore structures. The revised reassessment process shall enhance the methodology, based on widely accepted industry best practices.
The platform model is calibrated based on the measured in-field platform natural frequencies using a structural health monitoring (SHM) system, so that the reliability assessment can be performed on a structural model to validate the effects of the revised wave in deck approach. The revised methodology demonstrates the potential of unlocking structural capacity of offshore structures by removing conservatism normally associated with traditional reliability assessment methods, thus significantly improving the ability to achieve target structural reliability levels in a cost-effective manner.
A case study was embarked upon to demonstrate the benefit of the revised methodology for fixed offshore with insufficient air gap due to subsidence. The pilot study revealed significant improvement in ultimate strength of the structure using the revised methodology by more than 10% improvement in reserve capacity. This provides added benefits for increasing inspection intervals and optimizing the maintenance strategy due to risk reduction and avoidance of costly strengthening modification and repair (SMR).
The objective of the present paper is to establish an updated methodology to determine wave-in-deck loading for ultimate strength analysis. The scope of work of the study are as follow:
Perform a literature review of wave-in-deck assessment best practices, codes and standards. Develop assessment procedure based on international standards and research papers. Perform ultimate strength assessment based on revised methodology on a selected platform. Preparation of assessment methodology and case study report.
Alternate Foundation Concepts for Offshore Jackets in Calcareous Soils
Authors: Kumar Chaithanya , Pambudi Sandhria Ferriawan Agung , Salunke Milind Manohar , Rayappa John William 
Published: March 2022

Abstract
Calcareous soil type is found at many locations, requiring careful selection of foundation type. Calcareous soil is mostly or partly composed of calcium carbonate in the form of lime or chalk derived from the underlying chalk or limestone rock. North-West Shelf of Australia is an example of site which consists of carbonate soil types wherein the majority of existing offshore facilities and platforms being installed using Drilled and Grouted (D&G) piled foundations and in some instances using Gravity based foundations.
This paper discusses alternate foundation concepts on such soils, namely; (i) Micro-piles, and (ii) Inclined pile cluster, along with the common concepts of (iii) D&G piles and (iv) Gravity based foundations. The foundation concepts are discussed with focus on key aspects of the foundation structural configuration, vertical foundation capacity feasibility, and some serviceability related aspects. In addition, offshore operation and installation duration perspective are also discussed to provide some insight on how each foundation concept could suit the project preference which often influence the final selection of foundation concept. Risk/challenges and advantages of each concept are then summarized for overall comparison.
An Experimental and Numerical Approach for the Best Enhanced Oil Recovery Strategy in Capillary-Dominant Reservoirs
Authors: Alabdulghani Ahmad , Hoteit Hussein 
Published: March 2022

AbstractWorking with naturally fractured reservoirs (NFRs) can be challenging. Inadequate understanding of the enhanced oil recovery (EOR) driving forces in these reservoirs may result in serious conformance issues due to excessive water production. As a result, this work investigates and numerically validates some fundamental flow mechanisms in heterogeneous reservoirs, particularly capillary-dominant ones, to highlight the best EOR strategy for this specific case.Consequently, a two-dimensional lab-scale reservoir model with injection and production ports was designed, fabricated, and tested in single-phase and two-phase flow scenarios, simulating a water-wet fractured system. First, a single-phase flow waterflood baseline was studied, compared to the literature, verified by commercial reservoir simulation software, and eventually considered to calibrate the porosity and permeability model in the simulation model where the controlling variables are limited. Based on this work, the same procedures were experimentally repeated and verified by simulation, where waterflooding and polymer injection were used to displace oil with more governing variables.The single-phase scenarios aided in distinguishing between the waterflood and polymer flood cases. Water prefers to channel through high permeable streaks when injected into a fractured water-wet reservoir, resulting in poor volumetric sweep and significant bypassed zones. Whereas the controlling variables in two-phase flow were increased, capillarity and mobility ratio were dominant in the simulation. During waterflooding, flow divergence was observed faster toward the matrix medium, overriding the high permeability front in the fracture due to the strong capillarity contrast between the matrix and fracture media. Even when capillarity is strongly present, polymer flooding demonstrated a better volumetric sweep in all scenarios.The unique demonstration of fluid flow inside the two-dimensional lab-scale reservoir model, as well as numerical simulation, shed light on the efficacy of these EOR strategies in fractured reservoirs. Furthermore, for the first time, the behavior of capillary-dominant reservoirs with an advancing flow path within smaller pores compared to larger ones within the reservoir media has been experimentally captured. Understanding reservoir characteristics and having the know-how to implement the best recovery scenario can, in fact, maximize the field's life cycle and increase the Recovery Factor (RF).
Magnetometer Survey: Multi-Discipline Collaboration Impacting Bottom Line
Authors: Kamaruzaman Muhd Akram , Din Mohd Saifullah , Endot Ernyza , Sim Peter , Lojikim Chrissie , Chang Chung Yan , Mohd Ramli Mohd Faiz 
Published: March 2022

Abstract
Central Luconia has been explored with hundreds of well since the 1950s. During that time, all offshore wells were drilled using hyperbolic positioning system which has lower accuracy compare to current satellite positioning system, which was only introduced in early 1990s. With this knowledge, the old exploration well's locations (which was drilled in 1970s) pose potential hazards in terms of seabed obstruction and potential well collision during the future development wells drilling. Without a reliable seismic to well tie, interpreter has difficulty in identifying the top of carbonate event for depth conversion, thus impacting the well delivery, static model building and subsurface reserves estimation.
Onsite verification was carried out using a multibeam echosounder (MBES), a Side Scan Sonar (SSS), and a Sub Bottom Profiler (SBP) in accordance with standard site survey procedures, but the existing wellhead location was unable to be detected because the wells had been abandoned and cut off at the seabed level. Magnetometer was deployed to further investigate the existing wellhead location; the sensor was towed approximately about three (3) times water depth from the stern of the vessel and altitude 10m from the seabed. To navigate the towed sensor, Ultra Short Baseline (USBL) transponder was attached close to the sensor to get real time underwater positioning. Five (5) survey lines were designed centered at the suspected existing wellhead location with the coverage of 60m radius. During data acquisition, the magnetic anomalies were recorded in the system via receiver and total magnetic data was used for further analysis to derive the as-found wellhead location. During the interpretation, the area of ambient magnetic field distortion was identified and marked as anomaly which represents "area of suspected wellhead". The magnitude and pattern of such distortion was used for interpretation and combined with the coordinates from the positioning system (surface and underwater) onboard the survey vessel.
The general total magnetic field reading is ranging between 40920nT and 41130nT with the magnetic anomaly/wellhead had magnetic value from 100nT to 115nT. The total magnetic field analytical signal value is ranging from 0 to 3.5. The target magnetic anomaly refers to the area with greatest analytical signal value where it is also the area with most drastic change of the total magnetic field. From the survey results, the as-found wellhead position varies from 48m - 53m compared to existing wellhead position. With the confirmation on the old wellhead location, this helps to derisk the well collisions study for future development well and also improves the seismic to well tie analysis to provide higher confidence in the Top Carbonate pick and a better inverted seismic match in the reservoir interval for properties distribution.
Lookback Analysis and Benchmarking to Improve Success Rate of Thru Tubing Perforations for Accessing Behind Casing Opportunities in Brown Fields
Authors: Anand Saurabh , Hamzah M. Amir Shah B. , Madon Bahrom B. , Chun Kok Kin , Othman Anis Izzuddin , Ismail M. Shah B Mat , Rahim M. Ikhlas 
Published: March 2022

Abstract
Accessing behind casing opportunities plays a key role in ensuring that production targets are achieved in the PETRONAS operated fields in Malaysian basin. This is however getting more challenging as these fields comprising mostly of stacked clastic reservoirs get matured. This paper provides a comprehensive review of all thru tubing perforation jobs done over last two years in PETRONAS operated fields in the region with focus on failure reasons and future mitigation measures to ensure higher rate of success.
As a part of this study, all the historical thru tubing perforation jobs done to access behind casing opportunities over last 2 years across more than 22 producing fields in the region with PETRONAS as the operator were analyzed in detail. These jobs were then studied with respect to the main factors which impacts overall job success or failure. These included but was not limited to fluid contacts, gun, and charge type, nearby well performance, zone saturation data availability, completion type, contractor performance etc. In addition, post job details like sand production, artificial lift performance which contributed to well behavior post perforation were also evaluated. Exhaustive gun perforation and well model simulations were conducted to model post perforation well performance. Actual data with distribution and impact of the above-mentioned parameters will be discussed at length in the paper. Key findings which contribute to the overall successful thru tubing perforation jobs and lessons learnt for future perforation jobs will be presented in the paper.
Based on the comprehensive review and in-depth analysis, the operator has gained great visibility on key focus areas for thru tubing perforation jobs to increase success rate for completing the behind casing opportunities. Results specially re-iterate the importance of saturation data, gun selection and sand control among other parameters for successful thru tubing perforation jobs in matured stacked reservoirs. The study also indicate why these parameters are even more important for multiple tubular perforations such as cement packers, complex dual string completions, multiple tubular perforation etc. Based on the findings from the study, the paper will recommend key points to consider while completing behind casing opportunities in challenging environment.
While a lot of literature and study is available on perforations in general, the author could not find any noticeable work which is based on large amount of actual field data on how to improve thru tubing perforation jobs in matured stacked reservoirs in complex completions. This paper aims to help operators improve on the existing practices to ensure better and more successful results while completing behind casing opportunities using thru tubing perforations.