bluuebunny/crossref_metadata_2025_split huggingface dataset:
Delivering an Innovative Active MPD Wellbore Sealing System for Field Operations
Authors: Johnson Austin , Sundaramoorthy Saravanan , Ameen Kareem , Nichols Jess , MacGregor Alex , Fraczek Justin 
Published: November 2020

Abstract

Objectives/Scope
This paper shares results from the first field deployment of an active sealing device in a narrow margin deepwater well in the Black Sea. The active sealing device represents a clean-sheet design approach purpose built for deepwater MPD operations. This paper shares highlights from the detailed design through the prototype testing to the first-use stages of the program.

Methods, Procedures, Process
This paper discusses three distinct program phases covering the overall process from concept development to field operation. First, the detailed design phase is discussed, introducing the reader to system components and functionalities. The second phase of full-scale testing is discussed from the design verification, system optimization, and systems integration testing perspectives. Finally, field results are shared detailing findings from the first deployment on a dynamically positioned deepwater rig drilling a narrow margin MPD well in the Black Sea.

Results/Observations/Conclusions
The paper shares findings, insights, and results from each of the phases of the active sealing device development program.Upscaling passive RCD technology for deepwater has negative effects on system performance.A non-rotating, externally functioned seal sleeve element eliminates multiple high wear components.Elimination of bearing assemblies and rotary seals removes common failure modes seen in deepwater.Redundant, actively controlled seal elements ensure wellbore seal quality throughout the seal life.A lubrication system injects mud between seal elements, enabling seal condition monitoring.Active seal condition monitoring alerts the rig crew when to replace the elements prior to failure.Full-scale testing has been completed demonstrating the system under simulated drilling conditions.Seal life demonstrated to outlast most deepwater MPD hole sections.Operational testing and integration testing reduce commissioning and testing time consumed on the rig.Active sealing device successfully integrated into the drilling riser and MPD specialty joint.Multi-modal system provides rig crew with distinct operational strategies to meet current parameters.Consistent seal life enables rig crew to drill MPD sections with confidence in the wellbore seal.Deepwater well with multiple MPD sections successfully drilled using new active sealing device.

Novel/Additive Information
The project includes secondary novel aspects such as drilling contractor ownership of the subsea and topside MPD equipment. The MPD system is integrated into the drilling control system allowing communication between the rig, subsea, MPD topsides, and all third-party systems, while also sharing commonality with other rigs in the fleet. An objective of the MPD system design is to enable new models of fleet management to meet drilling contractor operations.
Multi-Functional Production Unit for Marginal Fields
Authors: Thiruthonder Haravinth , See Kiat Chin 
Published: November 2020

Abstract
With soaring global demand, depleting supplies of crude oil coupled with the collapse in the oil prices, maximizing oil production in mature fields has become a priority. Such fields account for over 70% of the world's oil and gas production, with a worldwide average recovery factor of 35% for oil. Main challenge encountered by mature oil fields is the well pressure depletion over time, sand production and increased water-cut. Since pressure depletion is inevitable, it is particularly challenging to continue to produce as there is insufficient reservoir pressure to push the well fluids to the main processing facilities. As the reservoirs starts to deplete, other issues such as sand production and high water cut also becomes more prominent.
The system discussed in this paper is an effective engineering solution designed for topside receiving facilities. The Multi Production Unit (MPU) is a low pressure production unit with integral desanding and dewatering. MPU is a system tailored to boost the pressure of production fluids from low pressure wells, while handling common challenges in mature fields such as high water cut and high sand production. The system is ideally suited for remote wellhead platforms where wells have insufficient pressure to deliver well fluids to production header in addition to flow assurance issues related to high sand and water production.
Conceptual design of this system is based on the very low, almost atmospheric, operating pressure of the system, wherein the elements. The system is designed in such a way that it can receive continuous full flow from the well, and still manages–through intricate isolation methodology-to operate in batches. This batch operation arrangement allows for liquid accumulation which is then discharged to the production header after being pressurized. The integral desander enables sand removal from the production fluid before discharging the liquids to the production header. The accumulated sand can be discharged in batches whilst the system continues to produce. The dewatering feature of the system allows for removal of water prior to discharging the oilflow from the well to topside becomes easier without the need to inject the well itself with any foreign, resulting in reduced induced backpressure due to reduction in flow to the downstream system.
Features of the system include:Compact design;Light weight;Self-contained system – no external utilities required except for HP gas source for motive gas and instrument gas/air supply;No pumps and power generation;Low system complexity and controls;Fully automated systemNo manning requirement;Sand handling; andBulk water handling.
4D Seismic for Integrated Reservoir Characterisation
Authors: Tan Aaron Qun , Chia Jessica , Thiam Flora , Ting Angelina Jia 
Published: November 2020

Abstract
A case study on the integration of 4D seismic with various multi-scale and multidimensional field data to understand dynamic behaviour of the reservoirs is presented.
4D seismic is a key dataset amongst others e.g.geochemical fingerprinting, well inflow tracers, injection logging tools/production logging tools, and multi-well pressure deconvolution) together withconventional field data, which is acquired since starting up the field in late-2016. 4D data proved to be an essential piece that complemented field observations and is integral for constraining the subsurface models in support of a rapid second pahse of development and WRFM decisions. The paper describes the approaches taken to integrate these distinct datasets in the dynamic model as well as the various challenges faced in assimilating them in a coherent manner.
One key subsurface challenge is to understand the degree of compartmentalisation risk to make sound WRFM decisions and to plan for a robust phase 2 development. As a starting point, conventional field performance analysis (production & injection performance) indicated connectivity across the reservoirs, though more limited in certain areas. This was supplemented with other subsurface data to further validate and improve the dynamic models. The 4D signals provided an indication of pressure and fluid connectivity as well as an indication of water sweep direction. Updates to the dynamic fault seal were performed in line with observations from 4D seismic and various field data.
Understanding the dynamic behavior of the M field is key in view of the various challenges faced in reservoir management, e.g. increasing GOR trends and lower WI performance, in parallel with developing plans for the Phase 2 development. The incorporation of data of different scales and dimensions (4D seismic, fluid chemistry, PLT, multi-well pressure deconvolution) added value to the process of updating the dynamic models.
Revolutionising Formation Evaluation in Low Mobility Reservoirs of India
Authors: Ali Ahmed Moge , Ghosal Debdeep , Singh Shreya , Haldia Bhopal Singh , Chaturvedi Praveen 
Published: November 2020

Abstract
Formation testing has been widely prevalent in the industry for critical information, such as reservoir pressure, gradient analysis, and fluid identification, that aids formation evaluation. This paper focuses on the successful evaluation of low-mobility reservoirs using the 3D radial probe as compared to the conventional probe in a comprehensive study of 60 wells (most of them offshore) across India. One of the major challenges in formation evaluation, fluid flow from any interval is not certain. Prospective zones are encountered that lie in unconsolidated sands where critical drawdown pressure cannot be exceeded because of formation integrity issues or there are zones that have low mobility and thus cannot be tested. Reliable pressure results cannot be obtained from these formations, nor can the fluids in these zones be identified because of poor flow potential. To overcome this major challenge, different probe (tool inlet) configurations are used that increase the flow area and help test tight formations (e.g., the 3D radial probe). In this study, 1754 stations were analyzed across several heterogeneous formation types and multiple operators to verify the diverse applicability of the 3D radial probe. The analysis was conducted in two phases. Formation testing results from the first phase showed that 47% and 68% of the points of interest in 2018 and Q1, Q2 of 2019, respectively, across all wells remained unevaluated with the conventional probe. Even among the points that gave valid results, there were low-mobility points where downhole fluid analysis (DFA) was not possible because of poor flow potential. Upon introducing the 3D radial probe in six wells, the shortfall of the conventional probe was overcome, which ultimately contributed to 35% additional evaluation success in 2018. In a comparison of the performance on the same wells and same formations, 3D radial probe fluid identification success in 2019 was 93% compared to 2% success in conventional probe evaluation in these tight reservoirs. Through this study, the uncertainty of fluid typing in the tight reservoir was resolved. Accurate interval permeability values were determined and were input to well deliverability estimates. The 3D radial probe results also help the drillstem test (DST) design, saving significant well cost because wet intervals are avoided using downhole fluid characterization, which revolutionizes formation testing in tight reservoirs.
Value Creation Transformation from a Reactive Workflow to a Proactive and Predictive Monitoring in Real Time Centre
Authors: Arriffin Muhammad Faris , Norhashimi Lokman Bin , Richard Bobbywadi Bin , Mohamad Azlan Bin , Meor Hashim Meor M. 
Published: November 2020

Abstract
Drilling operation real-time centre is envisaged to move forward from having a reactive workflow to being a proactive and predictive monitoring centre. Future state of a fully capable wells real-time centre will systematically integrate previously isolated and underutilized well engineering systems and applications and implement big data analytics by manipulating machine learning algorithm to automate recognition of potential non-productive time incidents. Current setup of real-time centre is presented and compared with future framework corresponding to service delivery process map, real-time system architecture, drilling data flow, and applications which include interventions protocol. Service delivery process map will progress from a directly linear to a close-loop integrated workflow. Applications and databases integration in a single platform on cloud will constitute a two-way connectivity of real time actual measured versus simulated and historical data for an enriched predictive monitoring of drilling operations via established machine learning algorithm. The machine learning algorithm will perform symptom analysis and automation of flag tagging to recognize potential events with inputs from existing combination of static and dynamic monitoring. This data driven approach is capable of leveraging on unprecedented amount of data to provide unbiased algorithm with rigorous trainings. Dynamic monitoring drilling system allows dynamic drilling parameters to be observed continuously and generates cutting simulations to forecast hole conditions and dynamic equivalent circulating density. Running along these systems is the technical limit and benchmarking tool which creates numerous key performance indicators for improvement in drilling operations and pushing well engineering design to its technical limit. The implementation of these systems indicates that intelligent wells systems are achievable in the future by virtues of having enhanced and relevant information available at the opportune moment to help deliver time, cost and effort savings.
Experimental Study on Novel Composite Aicd
Authors: Pan Hao , Cao Yan Feng , Huang Hui , Xu Hao Dong 
Published: November 2020

Abstract
In order to delay the water breakthrough and reduce water production once breakthrough occurs in the bottom water reservoirs, the water control mechanism of novel C-AICD is studied.
The paper describes the laboratory testing of C-AICD, AICD and ICD performed to evaluate the performance of C-AICD and the differences between C-AICD, AICD and ICD. Results from single phase experimental flow testing are presented and discussed.
The testing was conducted in a dedicated flow facility with water, oil and mixed phase fluild. It is under the same experimental conditions to test the water control effect of ICD, AICD, and C-AICD and be analyzed based on the recorded pressure and flow rate data.
The testing results showed that C-AICD could take advantage of AICD and ICD. It could function as a passive ICD to achieve uniform inflow at the beginning of production, and then function as AICD to autonomously restrict water production in the middle and late stages.
Based on a water control design and simulation of one horizontal well, it is found that the comprehensive water-cut of C-AICD well in the production life is about 13% lower than that of the common screen well, which provides a new technical method for economic and effective water-control in oil fields.
Feasibility Study of Dual-Function Chemical in Reducing Surfactant Adsorption and Interfacial Tension for Chemical Enhanced Oil Recovery Application
Authors: Md Akhir Nur Asyraf , Abd Hamid Afif Izwan , Mohd Saaid Ismail , Idris Ahmad Kamal , Nik Norizam Nik Nor , Yusof Nik Kamarulzaman 
Published: November 2020

Abstract
The performance of a low-cost and biodegradable dual-function chemical was evaluated based on its attainment in reducing the interfacial tension and surfactant adsorption in the synthetic seawater at the temperature of more than 90°C. The phase behaviour, interfacial tension, and static adsorption tests have been conducted for the feasibility study of dual-function chemical for the chemical enhanced oil recovery application. The experimental matrices were constructed using Design Expert. Anionic and amphoteric surfactants have been identified for the study to be tested with the dual-function chemical at the temperature more than 90°C in the synthetic seawater. In the phase behaviour study, the volume ratio of the aqueous phase to the Malaysian crude oil was kept 1:1. The interfacial tension between the surfactant and dual-function chemical system against the crude oil was performed by using a spinning drop method. Meanwhile, the static adsorption was conducted by using the crushed core at room temperature up to 30 days, the analysis was conducted by using High-Performance Liquid Chromatography (HPLC) method. In comparison with two types of surfactants; the dual function chemical works best with the anionic surfactant in order to reach the ultralow interfacial tension (less than 10-3 mN/m) within 60 minutes. The ultralow interfacial tension for amphoteric surfactant can only be obtained at an earlier time. In contrast, the phase behaviour study for anionic and amphoteric surfactants and dual-function chemical obtained was a Type II(-) microemulsion. In the static adsorption study, the dual-function chemical (&gt;0.5 wt.%) significantly helps in reducing the adsorption of anionic and amphoteric surfactants up to 73%. Based on the obtained results, dual-function chemical works efficiently when compounded with anionic surfactant than amphoteric surfactant at the same surfactant concentration and reservoir conditions.
Optimisation Design for Pipeline Free Span Mitigation
Authors: Dai Xuexin , Patonico Francesco , Patil Kiran , Goh Kia Hock 
Published: November 2020

Abstract
Pipeline free span mitigation is an integral part of field developments and their design for shallow water conditions poses a number of challenges which require special considerations. This paper discusses the main aspects of pipeline free span mitigation in shallow water conditions as is the case for the Arabian Gulf Region in which the water depths could be close to the limits of applicability of the conventional design codes based on experiences for other regions.
Free span mitigation design according to conventional codes will induce tremendous quantities of intervention works. An optimization design procedure is developed to minimize the number of IWs without compromising pipeline's integrity. Part of the procedure is the implementation of a finite element model which can capture the main features of on-bottom roughness analysis, e.g. pipe-soil interaction and residual lay tension etc. The whole process from pipeline laying on the seabed to operating are simulated. Post-process tools are developed for prompt visualization of the span profiles at different stages to provide efficient judgement for design of mitigation scheme.
The predicted spans from the FE model are compared with as-laid survey spans and good agreement is found, w.r.t locations and span lengths. Sensitivity studies have been performed to investigate the effect of various parameters on pipeline span length. The optimization design procedure constitute mainly three aspects. Firstly, allowable span length (ASL) can be increased by eliminating over-conservatism. The second aspect is reducing span lengths by various approaches, e.g. increasing concrete coating thickness, optimizing the residual lay tension and micro re-routing etc. Lastly, new optimization philosophy is also proposed, which is based on fatigue analysis for the entire design life of pipeline instead of screening by ASL for as-laid condition. Total fatigue damage during as-laid and operating conditions are calculated and compared with allowable value. For locations with total fatigue damage less than allowable value, IWs are not required. The material and installation costs are thus saved without compromising pipeline integrity.
To date, few studies have fully addressed the free span mitigation in shallow water regions. The optimization design procedure and extensive results in this paper will be a good reference for free span mitigation in shallow water regions. This will have direct cost and schedule impact on the execution of brown field developments where crossings and free span mitigation constitute a major element of the project.
Transient Pressure Analysis in Multi-Stage Fractured Horizontal Wells from Tight Gas Reservoirs with Weak Fluid Supply
Authors: Chen Zhiming , Zhang Jiali , Shi Luming , Zhao Juan , Yuan Lijia , Yi Xinbin , Wang Tianyi 
Published: November 2020

Abstract
This paper develops a novel WFS model for transient pressure analysis in multi-stage fractured horizontal wells. In the WFS model, two concepts called WFS pressure and WFS index are introduced and an additional skin factor in the interface of inner and outer regions is applied based on a radial composite reservoir. Then, a novel multi-stage fractured horizontal well model is developed by considering the WFS, stress-sensitivity effects, and finite-conductivity fractures. The reservoir model is solved by the perturbation transformation, Laplace transform, and numerical inversion. While the fracture model is solved by fracture discretization and superposition principle. Finally, the bottom hole pressure is obtained. Following that, model verification and sensitivity study are performed. It is found that the flow regimes of the WFS model includes bilinear flow, linear flow, first radial flow, bi-radial flow, pseudo radial flow, and WFS flow. An interesting feature of "hump" caused by WFS flow exhibits in the pressure derivative curve. The results of sensitivity study show that the height of that "hump" increases as the WFS pressure increases, but is independent of WFS index. What’s more, WFS flow exhibits a closed boundary flow when the WFS index is equal to zero, while it appears as a constant pressure boundary flow when WFS pressure is very tiny. Through the WFS model, the fluid supply characteristics of tight gas reservoirs are fully understood.
Innovative Down-Hole Chemicals Conveyance System with Built in Dual Steering Wheels, First in Onshore Kuwait
Authors: Abdalla Mustafa Al-Hussaini , Al-Kandari Hamad , Al-Meshwet Saad , Telang Milan Kumar , Gowelly Mostafa , Hassan Rabea 
Published: November 2020

Abstract
Produced fluids, from a tight deep carbonate reservoir extended laterally from West to South East Kuwait experienced severe asphaltene deposition along production tubing. This flow assurance challenge significantly increases well operating cost, risk and production deferment periods due to frequent Coiled Tubing (CT) cleaning jobs using considerable amount of expensive organic solvents.
This flow assurance challenge is caused mainly due to the absence of any of strong reservoir aquifer support, continuous decline in reservoir pressure and high draw down across this tight reservoir in order to meet production targets.
The objective of this pilot trial was to provide a long term solution with redundancy feature to convey chemicals safely from surface to down-hole through capillary tubes and pressure regulated chemical injection valves. Different techniques have been introduced since 1980 including batch chemical squeeze treatment, coated tubulars and Radio Frequency Vibration tools. Results of these trials have shown either short term production gain or no improvement on asphaltene build-up rate and well productivity.
In order to dynamically mitigate this challenge, a dual in-situ chemical injection system was installed to convey chemicals deep inside the well on a continuous basis. The system was successfully installed and has provided a safe & reliable field qualifying tool to verify chemical performance at different injection parameters.
The novelty of this technology is the ability to provide a continuous asphaltene management system to achieve production sustainability using dual injection conduits and down-hole pressure regulated valves utilizing relatively small amount of chemicals.
This paper highlights the adopted approach of continuous asphaltene management system from hardware design & installation prospective to chemical qualifying process in the field and also shed light on the pilot trial lessons learned.