bluuebunny/crossref_metadata_2025 huggingface dataset:
Analytical Approach to Predict Water Breakthrough Time Using Time-Lapse Pressure Transient Analysis: Application to Single Gas Well Reservoirs
Authors: Bhat S. , Choudhary A. , Kumar A. , Fife D.
Published: November 2024

Water breakthrough time (WBT) prediction is crucial for effective reservoir management with significant impact on field life and recovery. Time-Lapse Pressure Transient Analysis (PTA) can be used as one of the tools to predict WBT based on aquifer boundary movement over time. This paper aims to propose a simple yet effective approach for predicting WBT and cumulative gas production at WBT for gas reservoirs with single producer based on boundary movements observed in consecutive pressure build-ups (BUs).

BUs conducted over the span of three years were analyzed using appropriate analytical boundary models for each well. For consecutive BUs, upward shift in derivative during late time region indicated aquifer boundary movement towards the well. For each BU, equivalent radius corresponding to aquifer boundary was calculated based on PTA boundary distances. Correlation between equivalent radii and cumulative gas production was then established. WBT equivalent radius was calculated from the intersection of reservoir top and horizontal plane through the well bottom. Corresponding to WBT equivalent radius, cumulative gas production at WBT was found from the correlation. WBT can then be back calculated from cumulative gas based on gas production targets.

WBT was predicted for multiple wells for multi-reservoir gas field with single producers. Actual WBT closely matches with the predicted WBT validating the proposed methodology for future applications. This methodology provides vital inputs for optimizing production strategy and surveillance plan to extend the field life and improve recovery. This methodology is found particularly useful in dealing with the field with multiple reservoirs with single producer where managing life of each well is critical. Since this methodology is based on analytical approach, it does not account for reservoir heterogeneities, interference with other wells, coning, fingering etc. Regardless of the limitations, this method can effectively predict water-breakthrough time in single well reservoirs.

This novel water-breakthrough prediction method uses analytical model instead of numerical models proposed earlier. Hence, this approach requires limited inputs and simplified workflow. Considering reasonably accurate prediction of WBT, it can be used as primary input for optimizing production strategy. Further integration with the reservoir simulation model will be advantageous.
Emulsion System with Nanoparticles for Selective Control of Water Flows in Mature Sandstone Formations Offshore
Authors: Sergeev V. , Abe M.
Published: November 2024

This paper presents results of laboratory research conducted in the framework of a nano-emulsion technology piloting project for reduction of water production in mature sandstone oilfields offshore. Efforts of a technology developer, an oil and gas exploration and production (E&P) company and a petroleum research institute were put together to develop a fit-for-purpose piloting program. The offshore oilfields selected for the pilot are in the South of Vietnam. A laboratory part of program included list of experiments for testing physical and technological properties of the new product, a nano-emulsion called ESN which stands for Emulsion System with Nanoparticles. This new system is an inverse emulsion, whose nanoparticle augmented physical properties can be easily adapted for control of fluids flow in a wide range of reservoir conditions. A synergy from natural and artificial surfactants chemically intertwined with supercharged silicon dioxide nanoparticles brings to life a whole new scientific concept of the flow-control technologies for petroleum and geosystems industry. The ESN is an environmentally friendly technology used for advanced control of fluids flow subsurface. In this study, an application of ESN is aimed to selectively shut-off water zones within a profile of oil-gas well. The ESN consists of three liquid components: process or sea water, crude oil or diesel and nanoparticle-based surfactant. Implementation of the laboratory part of the piloting program resulted in a ready-for-pilot solution at reasonable cost and time. One of the main tasks of this research was to quantitatively demonstrate effectiveness of the unique features of ESN for selectively blocking water-bearing zones of sandstone reservoirs in Lower Miocene (2950 psi and 91°C) and Late Oligocene (3900 psi and 107°C) hydrocarbon formations. As a basic requirement from the E&P company, ESN had to be stable at said reservoir conditions and compatible with reservoir and process fluids. Besides that, the operator wanted to confirm that ESN is an easy-to-handle flow-control agent in the offshore environment, meaning that it can be prepared with ordinary equipment available at the vessel, all components must be liquids that can be easily mixed at ambient conditions, and properties of the ready-to-use composition do not change during operation. Thus, the laboratory program was executed in three successive stages: 1) ambient condition; 2) high pressure and temperature conditions; and 3) the reservoir conditions. As a result, a stable and reservoir-compatible ESN formulation that met all requirements set by the E&P company was quickly selected. In the series of core floods, it was confirmed that ESN selectively blocks predominantly water-saturated cores, while oil-saturated cores permeability drops slightly with clear tendency to full recovery under crude oil flow.
Diagnosing Well Integrity in Oilfield with Corrosive Aquifer with Pulse Electromagnetic and Chorus Acoustic Technologies
Authors: Evdokimov S. , Kadura M. , Ben Boudiaf M. , Sikander S. , Ezwai J. , Zitouni M. , Ezarrug N. , Abosart A. , Elyaseer M. , Hander M.
Published: November 2024

This paper discusses the approach of through-barrier diagnostics to direct Plug and Abandonment (PnA) and sidetracking operations in one of the fields in Libya. PnA before sidetracking is a critical procedure in the lifecycle of a well, involving the secure sealing of mother wellbore to prevent hydrocarbon leaks and ensure environmental and safety compliance. Proper PnA confirms the integrity of the new sidetrack wellbore.

The initial plan to revive the well involved abandoning the main borehole by isolating the perforated interval below and then drilling a sidetrack. Traditional evaluation methods revealed moderate corrosion in the 9 5/8″ production casing. To gain a comprehensive understanding of the well's condition, Pulse electromagnetic and Chorus acoustics technologies were employed, uncovering more extensive issues: approximately 200 feet of severe external metal loss in the 9 5/8″ casing and around 1200 feet in the 13 3/8″ casing, primarily due to a shallow aquifer and H2S / CO2 presence.

Understanding and mitigating the effects of corrosive aquifers are essential for maintaining the integrity, safety, and productivity of wells. Therefore, Pulse electromagnetic survey was performed on a nearby well to evaluate the impact of the aquifer. This assessment revealed similar metal loss in the external casing, attributed to the active aquifer. However, the extent of the metal loss was less severe due to the younger age of the well.

To address and manage these risks effectively, a time-lapse monitoring approach was proposed. This approach involves continuous or periodic monitoring over time to track the progression of corrosion and implement timely interventions. Such proactive measures are crucial for ensuring the long-term sustainability and operational efficiency of the wells, as well as for preventing potential environmental and safety hazards associated with corrosive aquifer interactions.
Beyond Boundaries: Achieving Safe and Efficient Delivery of Deep Play Exploration Wells
Authors: Mahmood Humaimi. , Fadhil Kindi. , Abdul Aziz Burashdi. , Aiman Mughaizwi. , Faisal Busaidi. , Nasser Abbadi. , Ibrahim Al-Suleimani. , Isehaq Sabhi. , Salmeen Marjibi.
Published: November 2024

This paper provides a comprehensive analysis of frontier exploration in deep HTHP play wells, specifically those exceeding 6 km depth in Northern Sultanate of Oman and targeting deep and sour formations. The study focuses on advancements in well design optimization, drilling dynamics, and operational efficiencies to achieve critical well objectives safely while reducing costs and minimizing health, safety, and environmental (HSE) impacts, despite the challenges posed by high subsurface uncertainties such as a wide range of pore pressure- fracture gradients (PPFG), highly sour environments with H2S, and hard rock formations.

To address these challenges, a multifaceted approach was employed, integrating advanced well design, hybrid completion techniques, and optimized material selection. This includes comprehensive drilling dynamics, geomechanical strategies, and rigorous planning and execution efforts. Innovative material usage, such as hybrid completions for increased fracturing pressure, played a pivotal role in overcoming the unique conditions of Northern Sultanate of Oman's deep geological formations.

The application of these methodologies resulted in significant achievements: cost savings exceeding $2.6 million, operational efficiencies with less than 0.4% non-productive time, and substantial mitigation of HSE impacts. Notably, well-1 utilized an optimized hybrid casing string, saving over $600,000 and reducing equipment runs. Wells 2 and 3 demonstrated the effectiveness of new hybrid completion approaches, enhancing fracturing capabilities under high-pressure conditions. The project has proven its expectations in terms of hydrocarbons, illustrating the potential of deep play wells to yield substantial returns and valuable geological data for ongoing exploration efforts. These results underscore the success of the optimized approaches in handling harsh reservoir conditions and exceptionally hard rock formations, setting new benchmarks for safe and efficient deep play exploration.

Additionally, the paper introduces groundbreaking techniques like hybrid completions and surface-applied pressure in B-Annulus optimization, offering robust solutions for deep play exploration challenges. The successful replication of these techniques across critical sour wells in Petroleum Development Oman (PDO) showcases their potential to revolutionize deep and deeper play gas exploration, promising substantial advancements in exploration capabilities and industry standards.
Achieving Energy Savings Through Monitoring and Data Analysis
Authors: Al Ahmed Manal , Sajjad Saqib
Published: November 2024

This paper explores the pivotal role of continuous monitoring and data analysis in establishing an effective energy management system within the oil and gas industry. As global energy demands continue to surge, the imperative for fuel efficiency and carbon footprint has become a critical concern for utility providers. Organizations across the sector are persistently seeking innovative ways to optimize plant operations, control life cycle costs, and mitigate fuel consumption and carbon footprint.

ADNOC Gas, a leading energy company in the United Arab Emirates, has adopted a proactive approach to enhance operational efficiency and accordingly revenue generation from its existing assets, including gas turbine generators, steam turbine generators, and boilers. By leveraging its in-house resources and expertise, one of the operating sites has successfully identified and implemented two distinct energy improvement initiatives through the application of continuous monitoring and data analysis.

These initiatives underscore the value of a comprehensive energy management strategy that seamlessly integrates real-time monitoring, data-driven decision-making, and a steadfast commitment to operational excellence. By optimizing the performance of their critical assets, ADNOC Gas has achieved significant reductions in fuel consumption and carbon emissions, ultimately enhancing the company's overall sustainability and profitability.

The paper's in-depth examination of the referred success story serves as a valuable case study for other utility providers and energy companies seeking to implement similar strategies to improve their own operational efficiency and environmental performance. The insights presented in this paper offers a roadmap for organizations looking to leverage the power of continuous monitoring and data-driven decision-making to drive sustainable energy management practices in the oil and gas industry.
Chemical Tracer for Soil CCS Monitoring Application: Monitoring CO2 Storage in Saline Aquifers Using Advanced Chemical Tracer and Detection Technology
Authors: Al Muntheri Hiyam , XU Siqing , Al Hammadi Amer , Al Shehhi Zayed , Abazeed Osama , Hartvig Sven Kristian , Ghosh Abbay
Published: November 2024

ADNOC has embarked on a major Carbon Capture and Storage (CCS) project where large quantities of CO2 are injected into deep saline aquifers for permanent storage instead of releasing into the atmosphere.

An advanced chemical tracer technology was deployed in the first CCS project in the UAE for continuous CO2 monitoring to ensure permanent and safe CO2 storage. In case of containment breach, the chemical tracer technology can confirm the leakage and identify its source.

After CO2 injection for permanent storage, any containment breaching would be detected in the shallow soil monitoring borehole. Few soil monitoring boreholes were excavated across the field in which Capillary Adsorption Tubes (CAT) were inserted for some time and replaced by another according to the sampling frequency plan. The tube is sent to the lab for CO2 leak detection and reporting. The high detection resolution is in the order of 0.1 parts per trillion (ppt). This has a positive impact on the system economics because smaller quantities of chemical tracer material are required.

The tracer injection monitoring system is ongoing in the first CO2 storage area of Abu Dhabi. The monitoring includes soil monitoring which are shallow boreholes. The soil monitoring boreholes were excavated close to the CO2 injection well to ensure that there are no well integrity issues developed due to thermal effects by CO2 injection. The soil monitoring boreholes to be verified by surface gas CO2 monitors. Soil monitors were located around the radial storage area, to detect CO2 leakage and to understand CO2 migration to the soil through the cap rock (in case of leakage). The monitoring system for caprock and well integrity will provide: Surface soil monitoring for cap rock integrity, integrity confirmation for legacy wells, integrity confirmation of injection well in the post-injection monitoring period, leakage quantification, leakage origin if multiple injectors. The monitoring system can continue for up to 30 years of the operational period as well as the full post-injection monitoring, measurement and verification horizon.

This paper presents a description of a sophisticated CO2 monitoring technology that is being deployed in UAE's first CCS project. CO2 tracer technology is considered as one of the most accurate methods to detect CO2 leakage at surface. Its high-detection resolution allows early leakage identification and early mitigation action. In addition, it proves to be relatively low cost, operationally easy to execute, and requires a small operational footprint.
Field Test of Lithium Extraction in Oilfield Associated Water: A Case Study of YQ Treatment Station
Authors: Miao Xinyue , Wen Zhang , Ren Yongcang , Wang Min , Wang Kelin , Zhao Zhiyong , Liu Zhiming , Han Guoqiang , Ma Rui , Chen Xin , Zhang Lei , Deng Qianxing
Published: November 2024

The oilfield associated water is complex in composition and poses significant hazards, necessitating treatment to prevent environmental pollution. Taking the Yingqian Treatment Station as an example, it processes approximately 2,400m³ of water daily. Sampling and testing revealed that the total hardness of the water exceeds 20,000mg/L, with a Mg2+ concentration of about 1,200mg/L. Most importantly, the Li+ concentration reached 150mg/L, meeting the requirements for economic development (≥50mg/L). Consequently, related research and experiments were promptly initiated.

Owing to the associated water's high total hardness and low lithium content, which significantly differ from saturated brine, traditional lithium extraction techniques cannot be directly applied. In response, research has identified that manganese-based adsorbents offer the advantage of high adsorption capacity, but require concentrated acid for desorption. Conversely, bipolar membrane electrodialysis has the merit of producing lithium products with high purity; however, the byproduct concentrated acid is a hazardous chemical that necessitates proper disposal. Consequently, a combined technological approach has been proposed to leverage the strengths of both methods.

The lithium extraction experiment from oil-gas field associated water at the YQ Treatment Station in China was conducted from May to June 2023, successfully producing 2.05kg of monohydrate lithium hydroxide from 116m3 of associated water. However, the experiment encountered numerous issues. For instance, the LiCl solution after a single desorption with HCl failed to meet the feed concentration requirements for subsequent processes. After extensive argumentation, the solution was adjusted by using a mixture of LiCl and HCl from the first desorption to replace HCl as the desorbent, and adjusting the desorption process from one stage to two, thereby increasing the LiCl concentration.

The daily production of associated water in blocks such as Yingqian (YQ), Keshen 8 (KS8), and Dabei (DB) in the Western China Oil-gas Field exceeds 7,000 m3, indicating potential for lithium resource development. In the near future, as these lithium resources are gradually harnessed, they will yield substantial economic benefits and reduce the overall cost of water treatment.
Simultaneous Industrial Decarbonization and High-Value Materials Production via Microwave Plasma-Based Methane Cracking: Demonstration in an Industrial Setting
Authors: Elcoate C. D. , Cruz A. J. , Urade A. , Al Maqtari A. , Dhebar S. , Khan I. M. , Zaffaroni F.
Published: November 2024

Robust, scalable, and cost-effective decarbonization technologies are key to the energy transition roadmaps of the energy sector and the industrial segments at large. In particular, to reach ADNOC's target of net-zero emissions by 2045, the reduction of methane emissions, a potent greenhouse gas, is critical. To accelerate the deployment of decarbonization technologies, these innovative solutions must be proven in real and scaled environments in a safe, efficient, and reliable way. This paper aims to showcase a pilot study led by Levidian, Abu Dhabi National Oil Company (ADNOC), ADNOC Gas, and Baker Hughes, deploying the LOOP technology. This technology platform converts hydrocarbons into a high-value revenue stream through hydrogen-rich output gas and graphene. This work presents collaborative effort on field deployment studies and preliminary outcomes, lessons learned, next steps and future potential.

The energy sector faces the multifaceted challenge of industrial decarbonization while concurrently ensuring security, affordability, and sustainability. In industrial facilities such as oil refineries and upstream oil and gas sites, there are currently limited solutions that can provide the following: Proving flare gas sites can be decarbonized at scale and cost-effectively.Enabling hydrogen production from methane-rich gas sources.Demonstrating carbon capture in the form of high-value material, e.g., graphene.

The LOOP technology – a demonstration of circular economy in action – is a platform that decarbonizes gas, produces a hydrogen-rich gas stream and locks carbon in high-value graphene. Graphene is being incorporated into materials to make them last longer and perform better. It has unique characteristics, such as high mechanical strength and excellent thermal and electrical conductivities, which make it possible to enhance a wide range of materials, improving product performance, increasing lifespan, and reducing carbon footprint. Levidian, ADNOC, and Baker Hughes collaborated to accelerate the technology readiness level of the LOOP through a pilot study, enabling the deployment of the system at the Habshan Gas Processing Plant in the UAE.
Development of Simplified CO2 Liquefaction & Loading Process at Elevated Pressure
Authors: Shazawa Yu , Suzuki Asato , Shimizu Miho , Nakano Yoshitaka , Inoue Tomoki , Lothe Per
Published: November 2024

The increasing urgency to mitigate climate change has driven significant interest in Carbon Capture and Storage (CCS) technologies. These technologies are essential for reducing the concentration of greenhouse gases in the atmosphere, thereby limiting global temperature rise. Among these technologies, the liquefaction, marine transportation, and storage of liquefied carbon dioxide (LCO2) play a crucial role.

CO2 liquefaction and marine transportation typically involve medium pressure (MP) or low pressure (LP) modes which require extensive refrigeration cycles. The MP mode of liquefaction and marine transportation is a traditional method, whereas the LP mode is relatively recent. However, these cycles lead to high energy consumption and capital expenditures (CAPEX), which can make the processes less efficient and more costly.

This paper explores an innovative approach to simplify the CO2 liquefaction process at elevated pressures (EP) using LCO2-EP cargo tank technology optimized for CO2. The proposed approach involves a liquefaction cycle using isenthalpic expansion leveraging the Joule-Thomson (J-T) effect instead of external refrigeration cycles. The primary goals are to reduce energy consumption, to lower CAPEX, and to minimize CO2 emissions within the CCS value chain.
Rapid Forecasting of Trapped and Movable Carbon Dioxide in Saline Aquifers using LSTM-based Sequence-to-Sequence Learning
Authors: Ren G. , Talabi O. , Kumar V. , Misra S. , Odi U. , Silver A. , Gupta A. , Temizel C.
Published: November 2024

Geological carbon storage (GCS) will play a crucial role in reducing greenhouse gas emissions. Deep saline aquifers are considered suitable sites for geological carbon storage due to their accessibility, storage capacity, and containment efficiency. The paper develops a deep-learning-based rapid forecasting workflow to visualize the temporal evolution of the trapped and movable CO2 in the subsurface aquifer during a geological carbon storage operation. Rapid forecasting enables agile decision-making by providing timely insights into rapidly changing environments. This study presents the application of an LSTM-based Seq2Seq model for predicting the temporal variations in proportions of residually trapped, solubility trapped (dissolved), and movable CO2. A dataset comprising 1600 simulations of CO2 evolution in saline aquifer under various geological and engineering parameters was utilized as training and testing dataset. The LSTM-based Seq2Seq model was trained and tested to forecast the dynamic temporal variations in residually trapped and solubility trapped CO2 mass and the movable CO2 mass fractions over a period of 80 years, involving injection phase followed by monitoring phase. The prediction outcomes demonstrate that the LSTM-based Seq2Seq model not only attains a Coefficient of Determination (R2) of up to 0.99 but also requires merely 0.35 milliseconds to forecast the movable and trapped CO2 mass, which is six orders of magnitude computational speed-up as compared to conventional simulator.
A Comprehensive Life Cycle Assessment of an LNG Carrier from Cradle to Grave
Authors: Bansal Ambrish , Pranav Kumar , Bhopale Manasi
Published: November 2024

This research paper presents a comprehensive Lifecycle Assessment (LCA) of a 174,000 m3 LNG Carrier, covering the entire lifecycle from material extraction to ship breaking and material recycling and disposal (cradle to grave). Adhering to ISO 14040 and 14044 standards, the study employed SimaPro software for modelling and utilized CML - IA methodology for impact assessment, including categories such as global warming and human toxicity. Monte Carlo simulations were conducted for uncertainty analysis, enhancing the study's reliability.

The assessment comprised three phases: Cradle-to-Gate (ship building), Gate-to-End of Operations (ship operations), and End of Operations to Grave (ship decommissioning and recycling). Data from shipyards and operators ensured industry- specific relevance. The Cradle-to-Gate stage evaluated the environmental impacts of shipyard processes, raw materials, and equipment, establishing a baseline for scope 3 emissions estimation. The LCA establishes a comprehensive scope 3 assessments offering insights beyond direct operational activities, fostering collaboration with suppliers for shared environmental goals. By assessing the Global Warming Potential (GWP) of materials, the study highlighted the ecological benefits of adopting sustainable options like 'green steel.' It also examined the impact of renewable energy use in the yard.

The Gate-to-End of Operations stage analyzed operational impacts, considering different ship modes, maintenance, and emissions associated with fuel use. The study emphasized the importance of considering both Well-to-Tank and Tank-to- Wake emissions in LCA for informed decisions on fuel selection based on sustainability goals.

Quantifying environmental impacts throughout the LNG Carrier's lifecycle provides valuable information for decisionmakers, shipbuilders, and regulators. The research offers strategic guidance for stakeholders to align with sustainability goals, enabling continuous monitoring and evaluation. This approach empowers decision-makers to implement targeted improvements, steering the maritime industry towards a more environmentally responsible and sustainable future.

The total Global Warming Potential for the LNG carrier was found to be 2370 million kg CO2 eq. The assessment identified the Gate to End of Operations phase, particularly Ship Operations, as the primary contributor to the LNG carrier's Global Warming Potential (GWP), primarily due to fuel use. The End of Operations to Grave phase, focusing on ship recycling, highlighted steel melting as a significant contributor to GWP, underscoring the need for sustainable ship-breaking practices.
Innovation in Battery Energy Storage Systems via Redox Flow Batteries Technology
Authors: Atatreh S. , Seddik B. Ahmed , Qurashi A. , Ozsoy O.
Published: November 2024

Utility scale energy storage which is cost effective and scalable is required to meet the global energy demand while maintaining global climate goals, including UAE's goal of net zero by 2050. Increasing renewable energy resources results in volatility presented by supply fluctuations and grid-stability challenges which can be addressed through innovative modular Battery Energy Storage Systems (BESS) that has long discharge hours, more than six hours, fast ramp-up rate and has relatively low maintenance cost. Vanadium Redox Flow Batteries (VRFB) provide substantial advantages which support a scalable, efficient utility scale energy storage system that can be commercialized at a competitive Levelized Cost of Storage (LCOS).

Our global Innovation centers are collaborating to develop innovative solution to upgrade existing Battery Energy Storage Systems in power plants and other applications via Vanadium Redox Flow Batteries (VRFB) technologies along with wide synergy opportunities for clean technology implementation. Our research focuses on the system integration of large scale VRFB system, power rating of 10-100 MW, to the grids and investigates economics of scale and demand forecasts. Moreover, it aims to study the effect of high temperature in the GCC region on the performance of the cell, stack, and system levels. VRFB provides substantial advantages which support the commercialization regions that are rich with Renewable Energy (RE) resources, like solar and wind, where the surplus production can be stored and used at a feasible cost. Other applications include black start and backup power, also upgrading the existing BESS in large power plants. VRFB systems have the unique advantage to decouple power from capacity and can be designed independently, which supports to adapt to changing market conditions and increase your plants flexibility. Moreover, the lifetime can match the powerplant and offer further aspects such as recycling capacity. It's important to note that studies reveal positive trends on the availability of the element Vanadium through reliable supply chain and stable supply/demand, which can further increase the competitiveness of VRFB.

Ongoing and future work includes collaborating with a utility/large energy supplier to study and develop a large-scale MW pilot VRFB system in harsh environment such, high temperature climates, to further co-create breakthrough industrial and commercial solutions in VRFB. Redox Flow Battery (RFB) systems are promising solution for utility scale energy storage solutions with zero emissions and have promising business case to replace diesel generators for backup power black start applications. The results include a complete system analysis and a feasible roadmap for VRFB technology adoption.
Revolutionizing Liquid Unloading in Gas Wells: Maximizing Production with Self-Agitating Chemical Sticks
Authors: Wazir N. Ahmad , Rodzali M , Riyanto L. , Zainal S. , Hendraningrat L.
Published: November 2024

During a well's initial operation, high gas pressure and velocity lift water naturally. As the well ages, reduced pressure, and velocity cause water to accumulate, creating hydrostatic pressure that eventually blocks gas production. To resume gas flow, removing the accumulated water is essential. Many removal methods are costly and energy intensive. This paper presents a detailed analysis and evaluation of the technical performance of self-agitating chemical sticks, specifically designed for liquid unloading in gas wells. The operation of self-agitating chemical sticks is based on a reaction between a foam stick and an acid stick. This stoichiometric reaction generates N2 gas, leading to foam formation that lowers the hydrostatic pressure within the gas wellbore. Laboratory evaluations of these chemical sticks, including their unloading efficiency, solubility and the impact of condensate presence were conducted under various simulated conditions at different temperatures and salinity levels. Laboratory evaluation confirmed the superior performance of the self-agitating sticks. The unloading efficiency under various temperatures and salinity levels indicated that the chemical sticks were more efficient at high temperatures above 85°C, where the reaction between the foam stick and acid stick became more vigorous, unloading more than 50% of water under simulated conditions. However, salinity did not significantly affect the performance of the chemical sticks, indicating that they can be applied at any salinity level in the well. The presence of condensate was also tested at various levels, and the results indicated that the performance of the sticks is not significantly affected if the condensate level does not exceed 50% of the well. Solubility tests showed that the chemical sticks can dissolve completely without debris, even at low temperatures. This broadens the potential application of the sticks under any conditions in a gas well. The Self-agitating chemical stick presents a unique character as the gas produced from the reaction between foam sticks and acid sticks is N2 gas compared to typical gas produced by other foam sticks and gas sticks, which is CO2 gas. CO2 gas can alter the pH of the liquid in the wellbore to acidic, increasing the risk of corrosion in the casing and production tubing. Hence, the liquid unloading through the foam formation from the self-N2 gas-generating stick will reduce the risk due to the inert nature of the N2 gas.
Responsible & Sustainable Approach Towards Minimizing Incidental Flaring Events
Authors: Rajpurohit Surendra Singh , Osama Abdalla , Katheeri Mohamed Al , Anilkumar Ravishankar , Almarzooqi Iman , Rashedi Mohamed Al
Published: November 2024

As part of Company's continuous efforts to foster Sustainability, Decarbonizations and GHG emissions reductions, we have introduced a new systematic approach to reduce the frequency and the magnitude of unplanned flaring events across Company fields. This paper examines these cycled phases starting with data collection & initial assessment stage, followed by identification of the bad actors, then classifying them based on their severity and impact. This is further proceeded with utilizing root cause analysis mechanisms where recommended action is implemented accordingly. To ensure the effectiveness of executing the solutions, action and implementation plans will be developed in the final stage. Additionally, this paper explores opportunities and the value added in terms of flaring avoidance, Equipment Availability and Reliability without jeopardizing HSE and Asset Integrity. To ensure a cohesive and efficient response to the flaring event, a centralized task force team has been formed to address the issue comprehensively and implement necessary solutions.
Breaking the Mold with an Innovative, High Performance Retrievable Bridge Plug for Wellbore Isolation Applications
Authors: Fry Oliver , Friesen Jeremy , Aboelnaga Sharif , McGowan Robin , Khokhar Sajid Hussain , Sorensen Alla , Al-Kashgari Ahmed
Published: November 2024

This paper describes a method of overcoming fundamental limitations in conventional retrievable bridge plug (RBP) design to significantly improve oil and gas wellbore isolation operations. By eliminating both elastomer deformation to reach the seal bore and the reliance on elastomer memory to recover to gauge, we can address the industry's need for retrievability combined with the increased performance requirements of higher pressure, higher temperatures, and gas-tight barriers. This approach eliminates significant risks in NPT, well loss and well control and also enables the placement of high-performance retrievable plugs in previously inaccessible completions.

To fundamentally change the trade-off between access, retrievability and performance in elastomer design a novel method of slicing a volume into constituent segments was developed. These segments can be re-arranged, without mechanical deformation, to fit into a smaller annular volume. This allows the construction of sealing elements and extrusion barriers that do not need to be deformed to reach the sealing bore, and do not rely on elastomer relaxation or memory to return to gauge diameter. This makes the retrievability of the plug independent of the material degradation issues that typically occur to the elastomer element downhole, particularly in high performance applications.

This Segmented-Ring Technology forms the basis of a novel sealing system that has been developed offering higher performance (> 10,000 psi) at higher expansion ratios (20%) than any available wireline retrievable bridge plug on the market, thereby allowing High-Pressure, High Temperature (HPHT) gas-tight performance in restricted access completions. The elimination of elastomer memory as a recovery method greatly reduces recovery risks due to compression set, material degradation and Rapid Gas Decompression (RGD). The unique method of reconstructing the seal at the sealing diameter, paired with a modular plug architecture, also allows for new sizes of seal to be rapidly designed and deployed for specific applications.

The new Segmented Ring sealing system has been successfully implemented on multiple plug sizes ranging from 3-1/2"to 7" sizes, and successfully deployed worldwide to address recovery issues and high performance through tight restriction requirements.
Cultivating a Pervasive Data Culture - Establishing the Upstream Data Culture Program in PETRONAS
Authors: Saroji H. N. , Idris N. Md
Published: November 2024

PETRONAS Upstream is on the journey towards becoming a data enabled and driven organization. To ensure that Upstream is data-driven, it must first be data-enabled where data must be available, accessible, actionable and most importantly trusted for it to be consumed to make accurate decisions. However, simply having data that is democratized (available and accessible) and trusted simply does not guarantee success unless it is accompanied by the right attitudes and behaviors. Another significant challenge observed was the lack of data literacy and inconsistent data governance practices among both data creators and consumers. Additionally, the absence of standardized data management processes has been a major obstacle to establishing a trusted data source, which is essential for making accurate and informed decisions. Therefore, the Upstream Data Culture Program was established to address these challenges and most importantly to cultivate a pervasive data culture within PETRONAS Upstream.

The Upstream Data Culture Program was established to shift Upstreams’ mindset from the status quo to a data-driven approach, drawing on the renowned 8-step Change Model by John P. Kotter, a leading expert in business, leadership, and change management. The primary objective of this program is to foster a pervasive data culture by focusing on four key components commonly associated with data-driven organizations: Data Practices, Data Literacy, Data-Driven Leadership, and Data-Driven Decision Making.
Repurposing the Pipeline for CO2 Transportation in the Carbon Capture and Sequestration (CCS) Project
Authors: Amirrudin F. , Hashim W. Wan , Ali Z. , Sam M. Rahmat
Published: November 2024

Field D has been in production for over 40 years, and its output is now decreasing to the point of nearing abandonment conditions. This makes the field an appealing candidate for CO2 sequestration, aiding in the achievement of net zero carbon emission target while generating revenue through CO2 storage services. The processing, transportation, and sequestration of CO2 should be implemented at the minimum life cycle cost to ensure that the tariff imposed on emitters is more attractive than paying carbon tax. The tariff rate can be significantly reduced by converting the existing 205km-long natural gas pipeline from Field D facility to shore as the CO2 injection pipeline for sequestration.

This work highlights several key studies conducted during the feasibility stage to evaluate the viability of repurposing existing hydrocarbon pipelines for CO2 transportation. The feasibility study covered the flow assurance aspects elaborated in this paper, focusing on selecting dense or supercritical fluid versus gas-phase transport and flow assurance issues encountered in pipelines and injection wells. Effects on pipeline design and operating philosophies were also evaluated. Worst-case operating scenarios were thoroughly examined to establish the range of acceptable moisture content, impurity composition, and corrosion concerns, taking account of the use of corrosion inhibitors. A risk assessment was also conducted to identify mitigation plans, which included, among other things, material testing to be included in the action plan.

Evaluating an existing pipeline for suitability to convert to CO2 transportation service is challenging due to the need to access historical operating data and mechanical integrity data. According to the pipeline fitness for service (FFS) study, the flow assurance analysis determines the optimal design and safe operating envelope for the pipeline with CO2 service. Corrosion assessment was performed in enhanced-Multicorp software using inputs from flow assurance analysis to identify potential corrosion rates (CR) for CO2 service with presence of moisture and free water in the pipeline. The study also identified suitable corrosion inhibitors with expected dosages to suppress high corrosion rates in CO2 service when free water is present. Despite the data limitations, the feasibility of conversion was successfully demonstrated. To fully mitigate the risk, material testing on the existing pipeline will need to be conducted as a further precaution. This study offers valuable insights into the challenges and methodologies for converting existing natural gas pipeline to CO2 service in the early stage of CCS development.
Amalgamating Biosteering and Productivity Index Trend Analysis on the First Underbalanced Coiled Tubing Drilling (UBCTD) Injector Well in the Middle East to Improve Well Performance in Real-Time
Authors: Saradva H. , Mortimer E. , Robert M. , Jain S. , Rennox J. , Rivadeneira E.
Published: November 2024

Sharjah National Oil Corporation (SNOC) undertook an Underbalanced Coiled Tubing Drilling (UBCTD) drilling project to improve three wells’ performance in its gas-storage reservoir. The project's success was crucial towards ensuring energy security in Sharjah and increasing the operational capacity of the gas-storage reservoir. A unique combination of biostratigraphy, production data and bottomhole drilling parameters was applied to maximize lateral length in the high productivity reservoir zones to support this vision.

The three-well UBCTD pilot campaign involved setting a whipstock in a 7″ liner, milling a casing exit for sidetracking, and drilling 3-5/8″ lateral wells. The laterals utilized UBCTD technology and methods to eliminate formation damage, enhance production, and improve drilling performance.

An integrated real-time biosteering, productivity index (PI), trend analysis and sub-surface geological monitoring methodology was adopted to achieve the project objectives. Biosteering was performed by preparing thin sections from cuttings samples and petrographic analysis conducted to identify indicative microfacies and microfossils. The analysis was integrated with gamma ray (GR), logs to identify the reservoir layer and stratigraphic position of the drill-bit relative to the target reservoirs.

The integration of biosteering, PI trend analysis, and sub-surface geological monitoring aimed to optimize drilling and production efficiency. The well's measured productivity was transient during drilling, leading to a "pseudo-PI" calculation. While this was not a reliable predictor under steady-state conditions, it effectively indicated productivity when the drill bit intersected the reservoir. Flow rate changes signaled the impact of drilling zones, with increased rates indicating enhanced productivity. Concurrently, the formation's biostratigraphy was assessed, recording trends across multiple laterals to identify productive biozones. Geosteering then optimized lateral trajectories within these zones to maximize productivity. This holistic approach allowed for real-time adjustment, ensuring drilling and production activities were aligned with reservoir characteristics, ultimately enhancing overall efficiency and output.

This paper underscores the benefits of integrating data from diverse sources to enhance reservoir and well performance analysis. It also highlights the pitfalls of information silos hindering data sharing among teams striving for a common goal. As a comprehensive guide, this paper provides an in-depth discussion of a workflow that integrates drilling, formation, and reservoir data to optimize productivity enhancement strategies.
Using Data-Driven Tubing Head Pressure Proxy for Integrated Production Network Coupled with Subsurface Models: A Way to Improve Computational Speed While Keeping Real Field Limits and Prediction Accuracy
Authors: Limsukhon P. , Sarbas Z. , Kabdenov S. , Abubakirov Y. , Iskakov E.
Published: November 2024

The coupling of surface and sub-surface modeling approach has been deployed in managing short- and long-term forecasts in the industry over the decades. Computation time for the fully coupling model poses a real challenge for long term forecast. The compromise solution was proposed for long term reservoir management studies, where surface networks are removed from the fully coupling model. The key challenge to this approach is the assignment of the wellhead pressure constraints, which are retrieved from surface network in fully coupled model.

Multiple assumptions of constant wellhead pressures were tested with random success of replication to fully coupled model results. The field level forecasts were reasonably reproduced; however, the reproduction was not achieved at gathering stations which are several kilometers away from each other. This poses a potential divergence of regional depletion rate of reservoirs from fully coupled model forecasts, which could impact reservoir management studies. The advancement of native functionality of reservoir simulator allows parameters to be calculated dynamically. Thus, "Tubing Head Pressure (THP) Proxy" was proposed to dynamically calculate values of wellhead pressure constraints over forecasting periods, where the pressure values calculated from subsurface models are close to solutions derived from fully coupled model.

The production forecasts with coupled subsurface models and THP proxy show excellent representation of fully coupled model at a significantly shorter turnaround time. The usage of THP proxy resulted in 4.5-fold decrease in computational run time compared to fully coupled model with the 0.3% error in cumulative oil produced at the end of concession production forecast date. For end of field life forecasts, the run time optimization achieved nearly 3.3 times reduction compared to surface and subsurface coupled model with the reasonable match for total volumes produced for the given period. The robustness of the solution over the wide ranges of reservoir management options and subsurface model ranges (P10, P50, P90) was observed. The possibility of evaluating surface system debottlenecking options using THP proxy was also explored and tested.

This paper describes the workflow which is aided by data science/analytics that generates THP proxy functions and integrate them into coupled subsurface modeling. This method helps enterprises to greatly improve the speed of long-term forecast deliverables from business planning & reserves booking processes, and governmental regulation documents that support the field development plan while maintaining the actual field constraints and prediction accuracy.