bluuebunny/crossref_metadata_2025_split huggingface dataset:
Cementing the First Australian Offshore Carbon Capture and Storage Appraisal Well
Authors: Lyons Ariel , Sheikh Veisi Mahdi , Salehpour Amir , Azwar Cinto , Ashraf Shameed , Duthie Lynden , Marshall Steven 
Published: March 2022

Abstract
Analysis has consistently shown that carbon capture and storage (CCS) has an important role in meeting emission-reduction targets (IPCC, 2018). CCS wells require special design considerations to ensure long-term zonal isolation when exposed to carbon dioxide (CO2) because a complex set of chemical reactions leads to carbonation and dissolution of conventional cement sheaths.
Several studies conducted into the long-term stability of different cement systems when exposed to wet supercritical CO2 and CO2-saturated water showed that the novel CO2- resistant cement system provides enduring zonal isolation. Properties investigated included permeability, porosity, mass evolution, CO2 degradation front, and compressive strength. Given its superior mechanical properties, the novel CO2-resistant cement system was selected for use in the first Australian offshore CCS Gular-1 appraisal well.
To ensure that the blend characteristics of the novel CO2-resistant cement system remained optimal, a stringent quality-control procedure was developed. The blend management process, supported by rigorous laboratory testing, covered the complete lifecycle of the blend. This lifecycle extended from sourcing chemical components, to blending the components in a bulk plant, to transporting the blend across land and sea, and ultimately, preparing the slurry mixing.
By adhering to the project management process, all primary cement jobs were successfully performed without incident using conventional cementing equipment and practices. The novel approach of blending the product locally at a fit-for-purpose facility reduced costs compared with previous methods of importing a preblended product prepared at a special centralized facility. Blend homogeneity was maintained during transfer from a sea vessel to the jackup rig, with minimal change in density between samples received from the bulk plant and samples received from the rig. This blending, which verified the initial blend flow capability and the robustness tests performed at a regional laboratory using specialized equipment, concluded the blend is suitable for offshore operations.
Selection of a suitable cement system to ensure long-term zonal isolation will prove essential to the continuing expansion of the CO2 injection market. Through this offshore CCS appraisal project, valuable best practices and lessons learned in design and execution have been captured. This paper presents the decision process used for selecting a suitable CO2-resistant cement system for Australia's first offshore CCS appraisal well, drilled by AGR as part of the CarbonNet Project in late 2019, as well as the project management processes implemented to ensure successful job execution. The experiences detailed in this paper will benefit other operators confronted by challenges associated with wells subjected to CO2 injection.
World'S First Successful Dual String Installation of A Digital Intelligent Artificial Lift DIAL – Interventionless Gas Lift Production Optimization System, Offshore Malaysia
Authors: Rozlan M Rizwan , M Ghazali M Haziq , Bakar M Farris , Ishak M Faizatulizuddin , Samuel Orient Balbir , Misron Mohd Al Perdaus , Ismall Mohamad Sazwan , Salleh Nurfarah Izwana , Rizwan Badroel , Amara Abdel Ben , Faux Stephen , Ahmad Azhari Ahmad Hafiz , Anak Muara Azis 
Published: March 2022

Abstract
PETRONAS completed well H-X on B field in Malaysia with a Digital Intelligent Artificial Lift (DIAL) gas lift production optimization system. This DIAL installation represents the first ever successful installation of the technology in an Offshore well for Dual String production. This paper provides complete details of the installation planning and operational process undertaken to achieve this milestone.
DIAL is a unique technology that enhances the efficiency of gas lift production via downhole monitoring of production parameters informs remote surface-controlled adjustment of gas lift valves. This enables automation of production optimization removing the need for well intervention.
This paper focusses on a well completed in November 2020, the fourth well to be installed with the DIAL technology across PETRONAS Assets. The authors will provide details of the well and the installation phases: system design, pre-job preparations, improvements implementation, run in hole and surface hook-up. For each phase, challenges encountered, and lessons learned will be listed together with observed benefits.
The DIAL system introduces a paradigm shift in design, installation and operation of gas lifted wells. This paper will briefly highlight the justifications of this digital technology in comparison with conventional gas lift techniques. It will consider the value added from the design stage, through installation operations, to production optimization.
This successful installation confirms the ability to implement the DIAL technology in a challenging dual string completion design to enable deeper injection while avoiding interventions on a well with a greater than 60-degree deviation. With remotely operated, non-pressure dependent multi-valve in-well gas lift units, the technology removes the challenges normally associated with gas-injected production operation in a dual completion well – gas robbing and multi-pointing.
Despite the additional operational & planning complications due to COVID-19 restrictions, the well was completed with zero NPT and LTI. Once brought online, this DIAL-assisted production well will be remotely monitored and controlled ensuring continuous production optimization, part of PETRONAS' upstream digitization strategic vision.
The Future of Zero Continuous Flare Operation at Greater Bongkot North Field
Authors: Nunthaworrarat Rattachai , Srivaranon Suchart 
Published: March 2022

Abstract
The Greater Bongkot North (GBN)'s condensate stabilization system initially utilizes multi-stage flashing concept through the multi-stage separators. Most of the flashing gas at the last stage separator could not be recovered as being operated at very low pressure (0.05 barg) resulting in the continuous flaring through Low Pressure (LP) Flare Header at the Production Platform of the GBN since 1st operation day. Recovery of the unrecoverable low-pressure gas has been unsolved since then.
Regarding lower gas nomination forecasted and exported condensate rate in low condensate production mode, LP flare rate is being simulated at 1-3 MMSCFD whilst the existing condensate and gas recovery system shows the available capacity left over even the field potential is maintained. This information energized the opportunity of Recovery Scheme by boosting the pressure of LP Flare Gas and feeding the recovered gas to the existing FGRU compressor within the minimal modification scope. Entire feasible recovery options had been technically examined including essential requirements of modification to evaluate the Pros and Cons on each development scenarios.
Key engineering challenge on recovery of the low-pressure heavy flare gas is the closed recirculation of recovered hydrocarbon which wastefully occupies the system capacity. Selection on the returning point of the recovered gas is crucial to minimize the recirculation while increasing production yield. The selected option provides less modification works whereas the entire recovered gas feeding back to the existing FGRU compressor is feasible while the existing facilities at its maximum capacity are utilized and new equipment installation requires only one (Wet Screw) compressor and one liquid recovery (Vertical in-line centrifugal) pump. Each equipment was technically selected through evaluated technical specifications and limitation of installation spaces. Furthermore, the installation scenarios on the aging production platform are key challenge as deck extension, which new equipment are installed, is heavy-lifted, and installed on the existing lower deck of Production Platform using the available margin of platform load on the existing piles. Cost estimation is conducted together with economic evaluation for investment decision. The project is budgetary approved providing an attractive positive NPV. The economic evaluation results in positive NPV mainly due to the condensate gain from the flare gas recovery insisting that greenhouse gas reduction project could be performed in the techno-economical way.
The implementation of GBN New LP Flare Recovery scheme will soonest be getting started by FEED and Construction phases accordingly to shape up essential details of required engineering aspects to make the start-up of this project meets the timeline supporting Sustainable Development framework (Green-house gas reduction) as PTTEP strategic directions.
Perforating Docking System for Efficient High-Volume Operation
Authors: Jumaat Mohd Shafie , Wattanapornmongkol Sawit , Wattanachai Sorawit , Konglumthan Kontron 
Published: March 2022

Abstract
The Gulf of Thailand is developed with a high volume of slim monobore wells, producing from multiple thin reservoirs. The high volume of wells enables sufficient production output, but their costs must be well managed for overall field economics. An important cost component comes from the perforating operation that involves several runs of guns on electric wireline, and on each run consists of several guns that are activated sequentially using switches. This process of perforating multiple zones in a well, if not managed, will lead to extended operational time or worse, leading to serious problems like off-depth perforation. Additionally, the temperature of the wells averaging at 370 degF poses an additional challenge to the operations.
The efficiency of operation is paramount in achieving better well economics. Hence, several operational and technology optimizations were performed over the years to achieve several incremental in efficiency. Incremental improvement is always valuable in such a high-volume operation involving thousands of perforating runs annually. However, the gain is even more pronounced when a step change in efficiency is achieved, and this has been observed in the new gun docking system engineered for the high-volume market in Thailand. It enables quicker connection of multiple guns on the surface with better safety and reliability.
This paper discusses the background of the high-volume perforating in Thailand and the need for efficiency, which led to the development of this new gun docking system tailored for this market. This docking system technology is presented together with the statistics of its deployment in over 300 perforating runs to date and compared to the statistics of the previous system. The efficiency achieved comes from its quicker connection and arming system, combined with its better safety and reliability that lead to a lower misfire rate.
The success of its deployment and more importantly, its step change in efficiency may pave ways for more marginal fields to be developed globally. Additionally, as thousands of perforating runs are performed globally, its efficiency will also play a vital role in shortening operational times and contribute to lower global carbon emission.
Decommissioning of Splitter Wellhead Wells
Authors: Ishak Siti Nadiah , M Garib Nurul Iffah , Damasena Edwin , Dahasry Daeng Dhamiry 
Published: March 2022

Abstract
Drilling keeper wells with an open-sea concept by suspending a 36″ conductor to a jackup drilling rig as a temporary structure induced several criticalities in plugging and abandoning the wells. The severity amplified with the two (2) wells are cemented inside the conductor and completed with a splitter wellhead. As per the Malaysia local regulatory, any abandoned wells are to be free from any structure protruding from seabed. This is paramount in confirming the drilled location is free from potential hazards. This splitter design confirmed that conventional cut-and-pull approach is not feasible and multistring cutter is the only solution available. This paper covers the approach and result in performing eccentric cut of fully cemented 2 × 9-5/8″, 2 × 13-3/8″ and a 1.0″ wall thickness 36″ conductor including decommission of a splitter wellhead. In achieving the objective to P&A the keeper wells, an Abrasive Water Jet Cutter (AWJC) is deployed to perform an internal eccentric cut that able to penetrate five (5) cemented casing simultaneously. The cutter is paired up with Drilling Wire Saw (DWS) and Dual Drilling Machine (DDM) as a surface cutter and a "hole-borer" in cutting the retrieved multistring into shorter sections that eliminated the needs to dismantle the splitter wellhead into individual component. Meanwhile, for surface lifting and suspending, an engineered pad eyes, H-beam and lifting frame with pins were required to guarantee a successful operation. AWJC is designed to penetrate structures with extreme pressure, coupled with optimized pre-planned nozzle rotation speed to establish a complete 360° clean cut downhole. The jetting mechanism using the right mixture of water and garnet is crucial in providing sufficient capability to penetrate the conductor size in an eccentric condition considering the worst-case position of the cutter downhole. The significant finding from this P&A operation is understanding the type of garnet and fluid less environment around nozzle cutter head as main contributors for an efficient cutting process. Actual pick-up weight to pull free the pipe was 37% higher than the calculated weight for a complete cut. Hence, the surface capability shall be designed with some marginal tolerance to provide additional lifting capability in case an unsmoothed cut is experienced. Overall, the operation managed to overcome the challenges and uncertainties experienced and mark as a great milestone for the first ever decommission splitter well design in Malaysia.
Integrated Approach in Implementing Hydrate Management Strategies in Deepwater Gas Developments
Authors: Anuar Astriyana , M Norpiah Rohaizad 
Published: March 2022

Abstract
Hydrates have been a constant threat to subsea deepwater operations. Partial or total hydrate blockages usually occur after shutdown of a host facility, which invariably affects the resumption of production. The complexities of subsea production systems and extensiveness of deepwater fields present challenges in implementing hydrate management strategies. In the past, erroneous and ad-hoc strategies were implemented due to a lack of flow assurance (FA) awareness and understanding, resulting in production deferment caused by frequent hydrate formation/ blockages. Hydrate inhibition based on Mono-Ethylene Glycol (MEG) and Methanol (MeOH), if not properly understood and managed may lead to significant increases in a field's annual operating expenditure (OPEX). PETRONAS has gained a fair amount of experience in dealing with hydrates. The approaches taken in mitigating hydrate related issues in subsea developments have been exemplary and it is beneficial to be shared across the fraternities. These approaches will be discussed in detail throughout the article based on case studies from two subsea field developments: Field D Deepwater Gas Development and BG Gas Flowline at Field C
The Deployment of Deep Learning Models for Performance Optimization and Failure Prevention of Electric Submersible Pumps
Authors: Dachanuwattana Silpakorn , Ratanatanyong Suwitcha , Wasanapradit Tawan , Vimolsubsin Pojana , Kulchanyavivat Sawin 
Published: March 2022

Abstract
Real-time sensors are crucial for monitoring electrical submersible pump (ESP) operation. However, manually analyzing the whole data from these sensors is virtually impossible due to its overwhelming volume. Artificial intelligence (AI) is a game-changing tool that can leverage the big data from ESP sensors more efficiently. Coupled with ESP knowledge, AI could reveal insights into ESP behaviors, well performances, and reservoirs dynamics, leading to ESP life extension and better production optimization.
In this paper, we present the development and deployment of an AI workflow to enhance ESP surveillance. The workflow is developed in-house using the Python programming language and consists of the following four main modules:
Data ingestion – to ingest all ESP-relevant databases Data preprocess – to transform the databases in the format ready for AI modelling AI modelling – to experiment several AI models, e.g., to detect ESP critical events, and predict ESP run life. Deployment – To automatically notify ESP critical events and visualize insight from the AI models
The application of a hierarchical clustering algorithm reveals that the ESP run life in our fields are most influenced by gas production. Then, after more than 1000 runs of experiments, we achieve a deep learning model to predict whether an ESP will fail within the next 90 days. We also develop a module to automate nodal analysis as part of the AI workflow. Combining this physics-based model with a data-driven approach, the resulting AI models can accurately detect ESP critical events, such as ESP degradation, imminent gas lock, and sand production.
To deploy the AI workflow, we build a dashboard to effectively visualize actionable insights from the AI models on our local server. The workflow sends notifications of ESP critical events to users for prompt troubleshooting actions and collects user feedbacks for improvement of the AI models in the next model development cycle.
This paper demonstrates a holistic approach to develop a closed-loop ESP surveillance workflow that integrates the powers of AI, automation, and ESP knowledge including nodal analysis. The AI workflow potentially creates value of several million dollars or higher per year by extending ESP run lives and optimizing production. The lessons learnt from this AI workflow development are shared to assist the development and deploying of similar AI methods throughout the oil and gas industry.
Electromagnetic Measurement While Drilling System Enabled the Operator to Reach Beyond the Limits in a Multiphase Foam Drilling Medium
Authors: Ashraf Qasim , Khalid Ali , Hussain Syed Ahrar 
Published: March 2022

Abstract
In this era of low oil price, it is vital for the operators to deliver low cost wells with enhanced production. A continuous technological advancement in the oil and gas industry has played a pivotal role in establishing high returns on investments. Many techniques have been developed so far in this aspiration to improve the quality of the reservoirs, enhanced production mechanisms and efficient drilling operations.
Situated in Sulaiman fold belt of Pakistan a large Gas field was discovered by one of the NOCs in 2011. It was a carbonate reservoir, laterally extended on a large portion resulting in a big volumetric reservoir. When discovered it was observed that being naturally fractured and having low reservoir pressure it was plagued with massive loss of circulation and associated drilling challenges. Conventional drilling technique has also resulted in immense reservoir damage. To overcome the challenges of overbalanced drilling the operator started drilling with underbalanced drilling methodology in this formation, which resulted in efficient drilling, saving time and cost.
In order to improve the field economics, the operator decided to drill horizontally into this formation to maximize the production potential of each well. As a pilot project a well was designed to drill a horizontal leg of almost 504 m into this carbonate reservoir. It was obvious that this formation could not be drilled with conventional overbalanced mud system so it would be drilled with underbalanced multiphase foam drilling system. The biggest challenge in this gaseous foam drilling medium is to control the trajectory of the well as the measurement while drilling (MWD) system works through mud pulse telemetry that could only be done in an incompressible drilling fluid.
To address this major glitch an electromagnetic (EM) MWD system was suggested that can transmit the signals via electromagnetic waves and is independent of the drilling medium being used. Based on the resistivity analysis of the formations laying above this reservoir, modeling was performed to design the most suitable measuring system. As the lateral was long and deep so the requirement of extended range antenna system was also incorporated so that signal transmission remain uninterrupted throughout the drilling operation.
Through the application of this unconventional MWD technique the operator was able to drill the longest horizontal well in this block. The well was completed without any NPT in an excellent fashion and tested to evaluate the maximum flow potential of this reservoir. This application has shown the operators how to reach beyond the limits in such troublesome formations.
Analytical Modelling of Gas Hydrates in Porous Media
Authors: Rabbani Harris Sajjad , Khan Muhammad Saad , Qureshi M. Fahed Aziz , Rahman Mohammad Azizur , Seers Thomas , Lal Bhajan 
Published: March 2022

Abstract
A mathematical model is presented to predict the formation of gas hydrates in porous media under various boundary conditions. The new mathematical modeling framework is based on coupling the analytical pore network approach (APNA) and equation proposed by De La Fuente et al. [1]. Further, we also integrate thermodynamic models to capture the phase boundary at which the formation of gas hydrates takes place. The proposed analytical framework is a set of equations that are computationally inexpensive to solve, allowing us to predict the formation of gas hydrates in complex porous media. Complete governing equations are provided, and the method is described in detail to permit readers to replicate all results. To demonstrate the formation of hydrates in porous media, we analyzed the saturation of hydrates in porous media with different properties. Our model shows that the hydrate formation rate is positively related to the porous media's pore size. The hydrates were found to be preferably formed in the porous media composed of relatively larger pores, which could be attributed to the weak capillary forces resisting the formation of hydrates in porous media. The novelty of the new analytical model is the ability to predict the gas hydrates formation in porous media in a reasonable time using standard engineering computers. Furthermore, the model can aid in the estimation of natural gas hydrate reservoirs, which offer the avenue for effective methane recovery from the vast natural gas hydrate reserves in continental margins.
Challenges in Planning and Designing for the Sea Transportation of Heavy Modules of a Modularized Plant, an EPC Contractor's Perspective
Authors: Ahmad Nazari Zunaidi , Mashari Madada , Kumar Mukesh , Paul Eldho 
Published: March 2022

Abstract
The ocean transportation of heavy modules on heavy transportation vessels (HTV) has a large influence on the design and construction of modularized plants. In some instances, it governs structural design loads and influences the layout and commissioning plan of modules. Proper selection of transportation routes, seasons, and vessels will reduce the impact of transportation loads and constraints on the overall module design. Details presented in this paper are based on an EPC Modularization project involving the sea transportation of 5 mega modules weighing between 5000MT to 9000MT, totaling 34000MT, which took place between November 2020 and February 2021. A summary of planning and execution strategy together with key solutions to deal with challenges faced during this project can serve as a guide for future projects.