bluuebunny/crossref_metadata_2025 huggingface dataset:
Scaling E-Fuels - A Solution for Deep Decarbonizing the Mobility Sector
Authors: Schwappach D. , Hannan S. Yasir
Published: November 2024

As we navigate the adverse effects of climate change and looming pressure on industries globally to adhere to their pledged to climate goals, the urgency to accelerate decarbonization across various sectors becomes ever more apparent. The decarbonization of the transport industry via electrification has been greatly developed for road mobility. However, for "Hard-to-abate" transport sectors such as shipping and aviation, synthetic fuels, or e-fuels, offer a promising solution with their energy-dense nature, ease of storage, and compatibility with existing global infrastructure. However, despite their potential, the path to wide-scale production is not without challenges. This paper aims to outline the barriers that must be overcome to facilitate a broader adoption of e-fuels.
Alternative Method for Estimating Liquefaction-Induced Settlement of Shallow Foundation PLEM Using Finite Element Analysis
Authors: Nattapoom K. , Chao T. , Sompop S. , Patraporn W , Apisit T
Published: November 2024

Settlement of subsea structures, such as Pipeline End Manifolds (PLEMs), is typically calculated using conventional software or analytical methods for non-liquefied soil conditions. However, these methods do not effectively address realistic structural settlement behaviors under liquefied soil conditions induced by seismic activities. Recent publications have introduced simplified procedures for estimating liquefaction-induced settlement, but these are tailored primarily for onshore structures and do not extend to subsea applications. Additionally, specialized software in geotechnical engineering has limited capability to model the penetration of shallow foundation structures through liquefied soil layers during seismic conditions.

This study proposes an alternative method using Finite-Element-Analysis (FEA) to model and analyze the settlement of subsea structures, specifically PLEMs, in liquefied soil conditions caused by earthquake ground motions. The shallow foundation part of PLEMs, called mudmat, and soil layers were modeled. The soil model was defined based the density, the shear modulus, and pressure as a function of volumetric strain. The Smooth Particle Hydrodynamics (SPH) technique was employed to capture large deformations under dynamic conditions like earthquakes. Simultaneously, settlement of mudmat under the same conditions was reproduced using geotechnical engineering software to validate the proposed approach. The result from the studied FEA revealed greater settlement than traditional geotechnical engineering software in liquefied soil during seismic conditions. This comparison demonstrates the advantages and limitations of each approach, highlighting the enhanced capability of FEA when utilizing the SPH technique to capture the complex behavior of subsea structure in liquefied soils. Consequently, it provides more realistic results for design proposes.
Introducing New Dissolvable Perforating Particles to Optimize Abrasive Perforation
Authors: Kharrat Wassim , Hamdi Abdullah , Rajab Mohammed , Samuel Mathew
Published: November 2024

Coiled tubing (CT) abrasive perforation offers a valuable alternative for explosive based perforation methodology. This technique employs fluids containing abrasive material, which are jetted at high pressure through specially designed downhole tools' nozzles, creating clean tunnels connecting the wellbore to the reservoir without causing perforation damage like traditional perforating guns. Sand is the preferred abrasive material in the traditional methods as it is the cheapest besides the fact that it causes significantly less damage to CT pipe and abrasive perforating tools compared to all other artificial solids like bauxite or ceramics. The conventional abrasive perforation requires a cleanout operation using gelled fluids with adequate annular velocity and viscosity at bottom hole temperature.

In this paper, the abrasive perforating performance of a novel dissolvable perforating particles (DPP) is compared in a yard test with that of conventional 100 mesh and 20/40 mesh silica sand. The effectiveness factors are the punches' outer diameters in a 4.5 inches casing and a cement block, and the penetration depth through the cement block.

The DPP delivers entry hole size and tunnel penetration length comparable to the ones obtained using sand while eliminating the need to be cleaned out of the wellbore. Therefore, the optimized abrasive perforation reduces (1) the operational time and carbon emission, (2) the risk of CT pipe stuck due to highly deviated wells, high bottomhole temperature and low cleanout annular velocity, (3) water and gel consumptions, and (4) CT pipe fatigue caused by cleanout reciprocations. The DPP is applicable in both carbonate and sandstone formations as it is soluble in a dissolver, which is dissolving carbonates and not causing any clays' destabilization.

Contrary to the traditional explosive perforation, the dynamic underbalance eliminates the crushed zone and the residual rock and charge debris, which makes it a clean perforating technique same as the abrasive perforating method. However, after stopping the need for any cleanout, the optimized abrasive perforation supersedes not only with zero logistical challenges but mainly with the reduction of wellbore tortuosity thanks to its larger diameter holes and surface contact with the reservoir, which enable both: better hydrocarbons production and hydraulic fracturing treatments in very tight formations after significantly decreasing its breakdown pressures.
Field X's Journey to the Best-In-Class Performance, Using the Gap-To-Potential Approach
Authors: Shukaili Ghosin AL , Kindi Said Al , Riyami Said Al , Hatmi Fahad Al , Ajmi Ajmed Al , RIYAMI Yaqoob Al , Lawati Mehdi Al , Ghadani Adnan Al , Ismail Ahmed Al , Almatroushi Saif
Published: November 2024

Field X is the largest oil field in Petroleum Development Oman (PDO), with the most wells and the highest production. It is also a very mature field, with many old wells and aging facilities. This means that it is important to manage the field carefully to maintain production and prevent decline. In 2020, Field X's performance was below industry standards. The subsurface unscheduled deferment was on the rise (reaching 3.7% of total field potential in 2020), the artificial lift failure index was high (28%), the number of closed-in wells (CIW) with potential was high (9.1%), and the oil gain from optimization activities was low (3.1%). To improve performance, the team embarked on a journey towards WRFM Excellence. They used a Gap to Potential (GtP) benchmarking approach to identify and address performance gaps.

The team successfully executed their strategy, and Field X's WRM performance is now best-in-class. This was achieved through effective collaboration between different departments, agile work processes, the use of technology, automation, and visual management.

Between 2020 and 2023, there has been a dramatic improvement in Field X's performance. For example, the subsurface unscheduled deferment rate has decreased from 3.7% to 2.1%, and some fields have achieved ZERO unscheduled subsurface deferment. The artificial lift failure index has also dropped from 28% to 18%, and the CIW stock has dropped from 9.1% to 4.6%. The oil gain from Optimization has even doubled, from 3.1% to 7.2%. In addition to these performance improvements, the successful deployment of the GPT approach also had a positive impact on Health, Safety, and Environment (HSE), as all projects were executed safely with zero lost time injuries. Furthermore, the conversion of 40 wells from beam pump to Long Stork Unites LSU resulted in a 40% reduction in energy consumption and CO2 emissions.

Overall, the results of the GPT approach in Field X are very impressive. The team was able to achieve significant improvements in performance, HSE, and sustainability. This is a great example of how the GPT approach can be used to improve the performance of oil and gas fields. This paper reports on the successful implementation of the Field X Gap-to-Potential (GPT) approach, resulting in best-in-class performance.
A Novel Technology for Low-Carbon Hydrogen from H2S: A Large-Scale Techno-Economic and Environmental Assessment
Authors: Ali Sawsan. M. , Al Khatib Ismail. I. , Vega Lourdes. F.
Published: November 2024

H2S, a waste gas in oil & gas industry is usually incinerated in the Claus process. H2S-methane reforming (H2SMR) is a new technology developed at KU-RICH for producing low-cost and low-carbon hydrogen, key for the hydrogen economy. This work provides a comparative techno-economic and environmental assessment for alternative hydrogen-production via H2S methane reforming where H2S substitutes water in the conventional Steam methane reforming process (SMR). A large-scale H2SMR process is developed and benchmarked against SMR with CO2 capture (SMR+CC) in addition to methane thermal decomposition (CH4Pyrol). The study reveals the comparable energy intensity of H2SMR and SMR+CC at 148-149 MJ.kgH2-1 while CH4Pyrol has the least energy intensity of 75 MJ.kgH2-1. The added-value of process by-products of H2SMR and CH4Pyrol improved their levelized cost of hydrogen (LCOH) to $-1.00 and $1.93 per Kg, respectively compared to SMR+CC with $4.13 per kg and $2.41 per kg excluding and including CO2 selling credits. The carbon footprint of the three pathways is demonstrated via a gate-to-gate lifecycle assessment obtained in the order of H2SMR < CH4Pyrol< SMR+CC.
Artificial Lift Optimization with Clamp-On Multiphase Flowmeter
Authors: Black M. , Heinks C. , Cramer R.
Published: November 2024

This paper examines how clamp-on multiphase flowmeters can be used to optimize the performance of oilfield assets, such as artificial lift systems on unconventional wells. A clamp-on Electromagnetic Acoustic Transducer (EMAT) multiphase metering system has been developed that can be rapidly installed on all, or some of the production flow lines of new wells or retrofitted to existing wells with zero intervention. The EMAT measurement approach is clamp-on and non-radioactive. Examples of EMAT real time field measurements shall be presented and how the resulting data can be used to improve asset performance/integrity.

The workflow used to configure the meter prior to installation to the line shall be described. This includes empirical and physics-based flow analysis of reported well conditions based on pipe geometry, production data and PVT information plus in this case analysis of the dynamics of artificial lift systems for given wells. EMAT flowmeters were brought to multiple well sites and installed on producing flowlines downstream of the well heads where measurements were taken, and the configuration of the artificial lift system was noted. Results obtained were analyzed to assess the performance of the artificial lift systems.

The EMAT flowmeter was installed on several wells with an installation time less than one hour and with zero intervention. In preparation for each well, simulations were performed using the Taitel and Dukler model [1,2] to predict the flow regime. Traditionally such simulations use average flow values as measured by the test separator, but in this case the real time, multiphase dynamics of the artificial lift system as measured by the EMAT meter can be taken into consideration, because in many cases the flow is fluctuating around this average value. EMAT real-time high frequency multiphase flow measurements were used to provide a more realistic simulation capability which cannot be delivered by conventional test separators. The EMAT flowmeter embellished simulations were used to deliver improved data for each well, thus providing a detailed understanding of the flow regime within the flow line. These data were then used to better understand the dynamics, flow regime and performance of the artificial lift system e.g. rapid identification of damaging conditions that can reduce the productivity and lifetime of downhole pumps.

The EMAT measurement technique is a novel approach for multiphase clamp-on well monitoring. Using multiphase flow data, including high frequency measurement and assessment of flow regimes within the pipe, to assess artificial lift performance is unique and qualitatively different to typical applications such as well testing. Improving the performance of artificial lift can lead to larger scale objectives such as optimization across the reservoir.
Advanced Well Test Advisory System and Virtual Flow Metering to Improve Production Allocation and Well Surveillance. A Success Case in a Major Middle East Oil Company
Authors: Davila Rayner , Al Braiki Warda Awadh , Molina Adriana , Alyaqoubi Afra , Aladsani Amna Salem , Bahumaish Fatima , Ofodile Azubuike , Halvorson Steven , Bakhti Sara , Braunschweig Lukas , Lu Dennis , Khare Kautuk , Aydin Murat
Published: November 2024

This paper demonstrates a successful example of a technology pilot that solved technical challenges related to well testing and production allocation. Two tools, called i-WellTest and WellAware, were developed in nearly 3 month that supports well testing process from start to finish, including prioritization by exception based on real time well head parameters, smart guidance, scheduling, live monitoring, automated validation, as well as provide six alternates well rate estimation methods including one AI.

Accurate well allocation ensures efficient production performance. Engineers struggle to accurately estimate daily well rates, well statuses, and effectively identify underperforming wells due to limited access to well sensor data and absence of integrated production systems. This results in undetected production issues, and high uncertainty on well allocation factors, especially for gas lifted wells.

Working collaboratively with Palantir, 10 oil producers were selected, equipped with sensors able to get well head parameters, choke size, gas lift rates, valve status and MPFM readings. Pilot was conducted in two phases: first month discovering the value, and second month validating it.

i-WellTest is a real time application designed to assist engineers prior, during and after a test is conducted. It includes prioritization, scheduling, online validation, and report automation to optimize the entire well test process. Wells are to be tested by exception when their performance changes significantly, and while being on test, i-WellTest provides advice to engineers on the issues of optimal stabilization time, test duration, quality of the results, and the final validation. All of these issues are tackled by using a combination of online, data driven models and pattern recognition being fed by real time data from well and testing facilities.

i-WellTest makes the Well Testing process more transparent for the teams involved by allowing engineers to operate from a common view of the world which provides a granular understanding of well tests. This has led to the opportunity of reducing testing durations which, if taken, could translate into a significant reduction of Field deferred production.

Well test advisory system and virtual flow metering provides an unprecedented solution for long lasting technical challenges and limitations, in roughly three months it was accomplished what normally would have taken a year or more. Our engineers can now see things, do things, and work collaboratively in ways they could not have before. It demonstrated success case on how real technical issues can be addressed quickly by embracing cutting edge technologies.
The Algorithm for Monitoring and Managing Wells with Sanding Issues
Authors: Kovacevic Strahinja , Mihailovic Slobodan
Published: November 2024

The goal of this study is to create an algorithm for identifying problematic wells with sanding issues in mature oil fields, producing with Cased Hole Gravel Pack as the predominant sand control technology. In most cases, problematic wells selection is actually the choice of underperforming wells. However, this simplified interpretation (clarification) may result in the selection of wrong candidates and the implementation of inadequate solutions and technologies aimed at solving certain problems that cause production performance to decrease.

The first step in this process was to identify all parameters that are related to well production from unconsolidated reservoirs. Then this data was matched with the implemented sand control technology and its design. With deep-dive analysis of workover and production history in this field and depending on specific issues that had been occurring regularly, we were able to develop a series of questions and answers that led to a specific solution. In this way, an algorithm for identifying problematic wells and choosing the right solutions was created.

This algorithm offers a new, systematic and detailed approach to managing the oil wells with sanding issues, giving the guidelines for establishing the problematic wells and measures for restoring the production level. In this way, it provides a cost-effective analysis tool because it reduces expenditures for poor decisions when dealing with sanding problems. Similar algorithms could be created for wells with other issues, such as gas interference, poor inflow, paraffin depositions, etc.
An Integrated Analytical Technique to Screen Depleted Reservoirs for Underground Gas Storage Suitability
Authors: Telang V. N. , Mohamed Y. , Eldin S. S. , Chughtai M. , Singh H. , Pandya S. , Mascagnini C. , Perumalla S.
Published: November 2024

Underground gas storage (UGS) technique is gaining impetus and is widely implemented due to the global gas demand and consequent variation of gas prices. Due to the upfront investment involved in UGS projects, thorough screening of potential candidate reservoirs followed by economic feasibility analysis is essential to ensure the functionality of the project.

A range of technical factors like reservoir containment, gas recovery, pressure regimes throughout the operation, well integrity, available surface equipment, presence of contaminants in the fluid and project safety are considered as a part of the reservoir screening and UGS design workflow. Cushion gas requirement, working gas capacity, and maximum gas injection/ withdrawal requirements are the key operating elements that drive the feasibility and design of a UGS project. Finally, risk evaluation, economic feasibility and policy factors are reviewed to assess the feasibility of the candidate reservoir for a UGS project.

The study encompassed evaluation of three depleted fields for UGS candidacy. The two smaller fields offer very limited storage volumes and were deemed as unsuitable due to target extraction and storage rates. The bigger structure was delineated as a potential candidate. Geological investigation affirmed the caprock seal integrity. Formation pressure data confirmed hydraulic connectivity of the reservoir that was continuous to an adjacent structure. However, this connectivity was constrained by a gas-water contact (GWC) that acted as the bottom boundary for the containment. After calibrating the model with a fit-for-purpose objective, the reservoir modelling identified opportunities for maximizing working gas capacity through sensitivity analysis. Well engineering and completion assessments qualified existing wells for conversion to injectors, identify potential workover requirements and propose upgrades to existing equipment. Overall, the reservoir was qualified as good candidate for UGS requiring an additional investment circa $200Mn towards UGS specific surface facility with 30% uncertainty.

Based on the meticulous review and integration of outcomes from multiple disciplines, a quick analytical technique based on material balance and production performance prediction was developed. This workflow was carefully implemented to assess the UGS candidacy of a similar reservoir in a nearby field. Further development of the workflow has the potential to serve as quick-look tool and precursor to the detail oriented integrated approach described earlier.
Successful Trial of Innovative Sand Fallback Eliminator System for ESP Wells in KOC Fields
Authors: Al-Abdullah Hashem , Saud Ammar , Al-Rasheedi Khaled , Jalan Shiv , Tirkey Naween , Al-Rughaib Sara , ElKhalil Samer
Published: November 2024

Electrical Submersible Pumps are widely used in Kuwait Oil Company (KOC) fields in order to enhance or sustain production from matured oil fields. These high-power electro-mechanical systems are susceptible to failure due to various reasons, leading to high work-over rig intervention costs and time, in addition to substantial production deferment.

The objective of this pilot trial was to apprise applicability and feasibility of an economic innovative solution in order to address sand and debris fallback during ESP trips and shutdowns periods.

The available conventional systems within KOC to tackle the sand fallback challenge in ESP wells are not efficient or durable. It fails in a short time, leading to a significant impact on the well's deliverability and operating costs.

In 2021, KOC started applying a unique solution on wells where the ESP run life was short due to solid and sand fallback accumulating on top of the pump during ESP trips and shutdown periods. This patent-protected technology diverts falling back sand, solids, and debris into the outer chamber of the tool and quarantines them away from the pump. Upon ESP restart, internal dynamic flow ports agitate sand, and solids caught in the tool's chamber carries them to surface along with the produced fluids.

This pilot trial has gone through different stages including challenge identification, technology survey, candidate well selection process, business cases build-up, success criteria, execution and evaluation phases.

Well's performance were evaluated rigorously before and after this unique system installation for a duration of six (6) months. Several KPIs were set to conclude and judge the technology such as: ESP sensor data, ESP run life and well productivity, it was concluded that this innovative technology was able to significantly improve well's productivity and achieve prolonged ESP run life compared to the currently adopted conventional techniques.

This paper highlights in further details the operational challenges and failures due to sand fallback, technical features of this field proven technology, sharing the success case studies and shed light on the captured lessons learned for continuous improvement & optimization.

The novelty of this technology is the ability to provide a cost-effective durable solution for sand fallback issue in ESP wells to extend ESP run life, achieve production improvement and avoid costly workovers and production deferment.
Development Design of Midland Basin Edge Using Measurements and Modeling
Authors: Malpani Raj , Lyons Shelby L. , Kumar D. Satish , Bhatnagar Ankit , Bhatt Divyanshu , Tahir Hussain , Heij Gerhard , Every Sean , Lopez Cucha , Felts Libby , Meier Holger A.
Published: November 2024

The Midland basin is one of the most actively developed basins in the world. The primary unconventional reservoirs, Wolfcamp and Spraberry, are targeted basin-wide by various operators. While many of the development decisions across the broader Midland basin are well studied and published, including target benches/sub-benches, well spacing, completion intensity, and frac order, there is often limited applicability of prior data and learnings to structurally isolated mini-basins within Midland basin.

To better understand fracture growth, vertical communication, and development choices specific to the mini-basin, a data acquisition program was designed and executed. The data acquisition program consisted of a vertical well with open hole logging suite, geochemistry sampling, and external pressure gauges. In addition, six horizontal wells were monitored during the stimulation and production phases.

Interpretation of the acquired data, coupled with integrated fracture and reservoir models, enabled rigorous testing/validation of development choices. Fracture sequence and completion intensity has been observed to refine well spacing and target benches. This paper covers the integrated workflow that coupled interpretation of data acquired through a unique data acquisition program, modeling, and sensitivity analysis to inform future development and targeted appraisal choices in the mini-basin.
Integrated Workflow with Mechanical and Chemical Solutions for Offshore UAE Coiled Tubing Strontium Sulfate Scale Removal
Authors: Khalil Ur Rehman. H. , Arali V. B. , Franco Delgado , E. ElAttar A. , Ryan A. , Mahmoud W. , Alam S. S. , Abolmaali M.
Published: November 2024

Sulfate scale formation, caused by the mixing of sulfate-rich seawater with barium or strontium-rich formation water, hinders oil and gas production by reducing flow rates and damaging equipment. Removing sulfate scales from wells is challenging because of their hardness, chemical resistance, strong adherence, and the operational and environmental complexities involved. Additionally, handling them poses safety concerns as they are classified as technologically enhanced naturally occurring radioactive materials (TENORM), requiring strict safety protocols.

The primary objective of this project was to remove challenging hard scale for an operator in the UAE offshore oilfields, which impaired production and accessibility for well intervention using coiled tubing (CT) milling solutions and innovative chemistry. The operator faced serious issues with strontium sulfate (SrSO4) accumulation on offshore locations that obstructed production flow, necessitating frequent and costly hydraulic workover unit (HWU) operations for full completion replacement.

A scale removal workflow was developed using a 2.75-in. and 2.50-in. outside diameter (OD) diamond mill bit in conjunction with chelating sulfate solvents to address the hard SrSO4 scale. Diamond mill bits, chosen for their superior cutting efficiency and wear resistance, were used alongside a chelating agent (CA) identified through laboratory tests as the most effective dissolver, achieving 100% scale dissolution within a period of 24 hours. Periodic soaking with the CA softened the scale, enhancing the rate of penetration (ROP) from 2 to 5 ft/hr to an average of 20 ft/hr. This approach enabled the removal of SrSO4 scale in two wells, successfully restoring the original well production by and establishing a new precedent for offshore rigless interventions.
Leveraging Reservoir Knowledge, Multi-Scenario Modelling and Artificial Intelligence to Robustly Screen Development Options on a Click of a Button
Authors: Munira Hadhrami , Robert Bos , Vedant Kumar , Louis Dcosta , Abdulla Hamdi
Published: November 2024

During the past decade, Petroleum Development Oman's Hydrocarbon Maturation Centre (HMC) has established thematic catalogues with reservoir knowledge for various formations in PDO's acreage. The objective of this multidisciplinary collection of data, experience and insights is to reduce FDP cycle times by providing users web-based access to standardized datasets, workflows and past development decisions and thereby leveraging the use of analogues for development decision making. However, despite the vast amount of analogue information specific development decisions such as optimal pattern type, well spacing, water throughput, etc. and corresponding recovery factors and production profiles are still evaluated using conventional forecasting tools, which are seemingly time and resources consuming.

In this project, PDO has developed an innovative web-based tool that leverages the extensive analogue knowledge, multi-scenario modelling, and Artificial Intelligence (AI) to eliminate or significantly reduce the requirement for such reservoir simulation studies. For several reservoirs formations, 10,000's of sector simulation models were built, covering all possible combination of static and dynamic parameters with the uncertainty ranges quantified in the thematic catalogues and representing the most common development concepts. The entire dataset is then used to train AI models and build the model library.

The generated sector model library is searchable and can be used to identify reservoir analogues. The AI webtool then can predict recovery factors, forecast profile ranges etc. for any analogue or new sector model for the available development concepts at a click of a button. This allows a fast & robust evaluation of subsurface development options with clarity on trade off's, eliminates repetitive modelling & simulation requirements, and significantly accelerates simulation-based forecasting by 50% or more.

Unlike most traditional forecast prediction tools, available in the company, the FDIC-AI dashboard is based on extensive multi-scenario modelling and simulation results and use artificial intelligence to create predictions for any reservoir models with parameter combination within the defined ranges. This means that the tool can 1) generate valuable insights on production behaviour based on geological characteristics and development concept, II) be used for predictive analysis and benchmarking of reservoir expected performance, III) improve the efficiency in making early decisions on development concept decisions by quantifying trade-offs, VI) support the aspiration of the company towards leveraging analogue-based developments and agility in delivering projects.
Novel Amine-Free, Ultra-Low-Carbon Hydrogen Technology: Production Process for an Affordable, Decarbonized, and Secure Energy Transition
Authors: Cormier I. J. , Shelat M. R. , Eisinger B. J. , Kichak I. P. , Park S.
Published: November 2024

Blue hydrogen production technologies, derived from fossil fuels and offering high rates of carbon capture, occupy an important position in the climate initiatives ecosystem. By providing a clean, high-energy-density product from abundant, affordable fuels—all while relying on existing infrastructure and knowledge—these solutions fit readily into energy transition narratives. In this paper, a novel oxy-fuel combustion, amine-free, blue hydrogen generation process is introduced and compared against conventional, state-of-the-art performance and cost benchmarks using inputs keyed to the United Arab Emirates (UAE).

Adopting analysis methodologies from a reference study, this ultra-low-carbon (ULC) technology demonstrates a clear advantage over the reference autothermal reforming (ATR) with amine-based CO2 capture plant: namely, a 9.8% increase in effective thermal efficiency, a 6.6% increase in cold gas efficiency, a 26.8% decrease in baseline carbon intensity (CI) score, and a 21.2% decrease in the levelized cost of hydrogen. Oxy-fuel combustion, and the equipment associated with it, enables higher uses of waste heat from the hydrogen purification system. Furthermore, it reduces inefficiencies associated with nitrogen intrusion into the system and air's less ideal thermophysical properties as a thermal medium compared to CO2, thereby intensifying the blue hydrogen production process. The product streams—hydrogen and carbon dioxide—are kept separate throughout the process.

Compared to the amine-based post-combustion capture (PCC) systems conventionally paired with hydrogen production technologies, oxy-fuel combustion offers improved performance parameters and costs for CO2 compression, purification, and storage equipment. This is made possible by the comparatively simple exhaust stream separation process. Composed principally of water and carbon dioxide (avoiding contamination by nitrogen as occurs in processes relying on air-fired heating), the exhaust stream readily separates into process condensate and pipeline-ready CO2. Not only does this simplified CO2 clean-up and export configuration reduce both project capital (CapEx) and operating expenditures (OpEx) versus amine systems, but it also avoids generation of the toxic byproducts (e.g., nitramines and nitrosamines) associated with such systems. The authors expect that as the transition to Net Zero builds momentum, hazardous chemical byproducts like these will become scrutinized in much the same manner as greenhouse gas (GHG) emissions. With their local knowledge and significant capital resources, companies based in energy-abundant regions (e.g., the Middle East) are best positioned to anticipate and respond to such trends by adopting innovative solutions such as the technology discussed herein.
Soil Washing Case Studies within the Remediation Sector
Authors: Wilson Andrew. , Conway Amy.
Published: November 2024

Soil washing is increasingly popular in the remediation sector due to its effectiveness and versatility in treating contaminated soil. It is effective for a variety of contaminants, including organics, heavy metals, hydrocarbons, and pesticides, and allows for the treated soil to be recycled or reused. The growing adoption of soil washing is driven by stricter environmental regulations and advancements in technology, which enhance its efficiency and cost-effectiveness. The process involves assessing the site, excavating the soil, and then using a series of washing and separation techniques to remove contaminants. After treatment, the contaminants are properly managed, and the cleaned soil can be returned to the site or used for other purposes. Soil washing compares favorably to other remediation techniques due to speed of processing, relatively small footprint and ESG credentials. Recent case studies from Long Island, Saudi Arabia, and Kuwait highlight the successful application of soil washing in various settings, showing its effectiveness in managing diverse contamination issues and supporting sustainability goals.
Predicting the Elastic Properties of Anisotropic Reservoirs from Dipole Logging While Drilling Using Machine Learning
Authors: Maalouf E. , Chebli H. K.
Published: November 2024

The presence of a drill collar in logging-while-drilling acoustic instruments complicates the calculation of subsurface formation properties from acoustic logs. The collar's acoustic modes interfere with the formation's acoustic modes, which are essential for determining rock properties, particularly the flexural mode obtained from a dipole source. This interference is more pronounced in slower formations. Furthermore, most formations exhibit anisotropy, yet conventional log interpretation typically captures elastic properties in only one direction. To address these challenges, a method is proposed that overcomes tool effects and accurately calculates the complete set of elastic properties of rocks from the dipole flexural mode. The approach utilizes the modified matrix pencil algorithm to extract the flexural mode with minimal noise and interference, followed by a neural network to calculate the anisotropic velocities of rocks. The results demonstrate that the predicted elastic properties are accurate, and that the method is robust and fast, enabling real-time prediction of formation properties during drilling. This application optimizes the drilling and geosteering of wells for hydrocarbon and geothermal production, as well as carbon sequestration applications. Real-time inference of reservoir properties reduces non-productive time, minimizes drilling risks, and enhances the ability to precisely reach target reservoirs. Overall, this approach improves the efficiency and effectiveness of subsurface characterization, contributing to more sustainable energy exploration and carbon management strategies.
Agile Approach for Proactive Talent Mobility
Authors: Shokry K. , AlGhaithi S. , Al Mekhaini E.
Published: November 2024

The oil and gas industry is at a critical stage, facing rapid technological advancements, fluctuating market dynamics, and a global shift towards sustainable energy solutions. These challenges demand a workforce that is not only highly skilled but also adaptable and agile. Traditional approaches to talent management and mobility often fall short of providing the necessary flexibility and responsiveness. As such, there is an urgent need for innovative frameworks that can enhance workforce agility, operational effectiveness, and overall organizational resilience.

This manuscript presents a comprehensive framework for proactive talent mobility, specifically tailored for the oil and gas sector. The proposed AGILE (Assess, Grow, Implement, Leverage, Evaluate) framework aims to foster a skills-based organization where talent mobility is seamlessly integrated with strategic business objectives and continuous skills development. This approach addresses current workforce challenges and anticipates future demands, ensuring the organization remains competitive and resilient.

The AGILE framework can leverage advanced technologies, including AI-enabled platforms, to optimize the matching of employees to projects and assignments based on their skills, performance, and development needs. This integration enhances talent utilization, improves employee engagement, and promotes a culture of continuous learning and adaptability. This paper will explore the details of the AGILE framework, outlining its components, processes, anticipated outcomes, and the novel contributions it offers to strategic human resource management in the oil and gas industry.
Operational Excellence: Re-Think Beyond Reuse, Reduce, Recycle in the Circular Economy
Authors: Palhares T.
Published: November 2024

The increased demand for remanufactured parts marks a paradigm shift for oil and gas operators. As companies seek to achieve their individual sustainability goals, returning core equipment parts and choosing remanufactured parts are both key tactics to help reduce waste and make sustainability gains. Returned parts and assemblies are disassembled to their piece parts, cleaned and inspected before undergoing processes such as laser cladding, machining, metal deposition and other advanced salvage procedures. The remanufactured parts are then assembled into like-new components with like-new quality and warranty. This enables oil and gas companies to benefit from using high-quality and economical parts while supporting the circular economy.

This paper will share data and examples from the field that illustrate how the responsible use of remanufactured parts impacts the circular economy in the EMEA region.
Research on the Approach and Challenges of Green Ammonia as Hydrogen Carrier
Authors: Yue WANG , Haijun ZHONG , Xiwen SONG , Boyan CHEN , Xuerui ZHANG
Published: November 2024

The difficulties in hydrogen storage and transportation have become the main bottleneck that restricts the large-scale development of the hydrogen energy industry. As a solution for hydrogen storage, ammonia has a high hydrogen storage density, provides mild storage conditions, possesses mature and complete conditions for production, storage and transportation, providing a means to address the problem of hydrogen storage and transportation. However, the question such as whether the process is economical is still lack of enough research. This study is aimed to summarize the current development of synthetic ammonia industry and discuss the development path of ammonia in hydrogen energy industry. Based on the upon analysis, we propose thoughts on the development of the world synthetic ammonia industry, and points out four development paths. We analyzes economy of synthetic ammonia made from electrolytic hydrogen as an alternative to coal, cost of ammonia as a carrier for transportation of hydrogen. When the electricity price is RMB 0.2/kWh, the cost of green ammonia production is RMB 2,095/t, which is comparable to the cost of gray ammonia production when the coal price is RMB 900/t; when the electricity price is RMB 0.1/kWh, the cost of green ammonia production is RMB 1,115/t, which is comparable to the cost of gray ammonia production when the coal price is RMB 277/t. Four feasible development paths of China's ammonia industry are proposed. Firstly, integrating green hydrogen into ammonia synthesis plants to expand green ammonia production capacity and reduce carbon emissions. Secondly, consuming renewable energy electricity to produce ammonia. Thirdly, efficiently integrating byproduct hydrogen resources into ammonia production to enhance economic benefits. Last but not least, using offshore wind power to develop distributed and miniaturized ammonia synthesis projects.
Driving High Performance and Decarbonizing Well Construction Carbon Dioxide CO2 Footprint: A Petroleum Development Oman PDO Case Study
Authors: Wahshi Khalifa , Rashdi Ahmed , Pranava Ananda , Abri Mohammed , Harthy Khalid , Khattak Mohammad , Haji Younis , Sulaimani Mustafa , Rashdi Ishaq , Salmi Sulaiman , Elturki Noman
Published: November 2024

Petroleum Development Oman PDO has set an ambitious target of achieving net-zero emissions by 2050. In alignment with this goal, this paper showcases how high performance can be achieved while reducing the carbon footprint of well construction.

Petroleum Development Oman PDO achieves high performance through a series of continuous improvement initiatives, known as the "Well Staircase." These initiatives encompass well design optimization, the adoption of new technologies, operational efficiency enhancements, and cementing design optimization. A comprehensive value creation workshop, involving all stakeholders, was conducted to consolidate these initiatives. Furthermore, this workshop quantified the planned cost savings and time reductions. To operationalize Petroleum Development Oman PDO's net-zero emissions aspiration, a new dimension was introduced to these key initiatives - a reduction in Carbon Dioxide CO2 emissions.

Illustrative examples of these initiatives include slimming the well design in the A-field, resulting in an 11% reduction in costs per well, a saving of 9.8 days, and a decrease in CO2 emissions by 245 tonnes. Replacing Motorized Reamers MSRs yielded a 1% reduction in well costs and a 0.4-tonne reduction in CO2 emissions due to transportation. The optimized slurry formulation led to a 15-tonne reduction in CO2 emissions per well. The elimination of round trips by employing a risk-assessed hole condition approach resulted in a cost saving of 1.6% per well, a time saving of 2.5 days, and a reduction in CO2 emissions by 62 tonnes.

This innovative approach demonstrates how high performance can be achieved while simultaneously decarbonizing well construction, providing valuable insights and practical strategies for the industry's journey toward a sustainable future.
Talent Accelerator Program for ADNOC Employees: A Journey for Accelerated Development
Authors: Al Hemeiri Ashwaq
Published: November 2024

The Talent Accelerator Program (TAP) is a comprehensive and innovative initiative that aims to develop the financial, commercial, technical, and leadership skills of ADNOC high potential employees from downstream and upstream sectors. The program prepares the participants for the CFA certification and equips them with the future skills requirement for the oil and gas industry. The program adopts a multidisciplinary approach that integrates theory and practice, and involves various learning methods and assessments. The program also involves the participants with top leaders from ADNOC and exposes them to real-life problems and opportunities in their respective sectors.
High-Resolution Carbon Isotopic Records from the Ediacaran Sequence in Saudi Arabia: Implications to Shuram Anomaly and Petroleum Prospectivity
Authors: Malik Muhammad Hammad , Koeshidayatullah Ardiansyah , Herlambang Adhipa , Bello Abdulwahab M. , Amao Abduljameo , Al-Ramadan Khalid
Published: November 2024

The southern regions of the Arabian plate in Oman feature remarkable exposures of Ediacaran strata, which hold significance not only for their association with subsurface hydrocarbon reserves but also for hosting evidence of the world's largest negative marine Carbon excursion "The Shuram-Wanoka Anomaly". In contrast, analogous Ediacaran sequences present in the northern sections of the plate within the Kingdom of Saudi Arabia, have yet to reveal their hydrocarbon potential or indication of the Shuram anomaly and this disparity has fueled geological inquires. Our study focused on two well-exposed Ediacaran successions, the "Dhaiqa Basin" being the most northern Ediacaran basin in the Kingdom, and the "Antaq Basin" being the southernmost basin. We have conducted a comprehensive multiproxy characterization including sedimentological, micropaleontological, mineralogical and isotopic measurements. The findings unveiled some distinct depositional characteristics and diagenetic histories in these sediments despite their similar age. In the kingdom of Saudi Arabia, the northern most Ediacaran basin, the Dhaiqa basin exhibit carbonate facies with some microfossils suggesting a shallow-water environment, whereas the southernmost basin in the Kingdom, the Antaq basin is predominantly siliciclastic indicating a terrestrial origin. Stable isotopic results of Carbon and Oxygen further advocate on the isolated nature of these deposits with values diverging significantly from the global sea values as well as values recovered from Oman. The dissimilarity is attributed to the presence of the Najd Fault system in northern portions of the Arabian plate. Although the deposition in Oman is identified as a shallow open marine environment, the sediments in Saudi Arabia indicate deposition mainly in isolated basins influenced by the movements associated with the Najd Fault system. Although certain carbonate lithofacies in northern Dhaiqa Basin contain carbonaceous organic matter, resulting in a fetid odor in freshly broken rock samples, the Total Organic Carbon (TOC) results indicate an overall organic content ranging below 0.2%, classified as type IV. However, akin to their Omani counterparts, the proximity of these sediments to subsurface evaporites in the southern parts of the kingdom suggest a potential prospect for future hydrocarbon exploration.
Detailed Regional Seismic Sequence Stratigraphy and Clinoforms Characterization of the Early Cretaceous Lower Habshan Prograding System in Onshore UAE
Authors: Xie A. , Fadipe O. , Hassan H. , Ujetz B. , Vantala A. , Al-Salmi H. , Alhosani S.
Published: November 2024

Significant advancements in seismic imaging of carbonate strata over the past decades have transformed our scientific comprehension of carbonate sediment accumulation and alteration. These breakthroughs have far-reaching implications, extending from hydrocarbon exploration to the fields of geomorphology and the study of paleoclimate changes (Hendry et al., 2021). Through the analysis of 3D seismic data gathered for hydrocarbon exploration, we have gained a deeper understanding of how strata at the carbonate platform margin accumulate, forming patterns that are progradational, aggradational, and retrogradational. These patterns chronicle a long-term history of variations in accommodation space, sediment production, and sediment transport (Dujoncquaoy et al., 2018).

This study was initially conducted to explore the distribution of lower Habshan Formation and its reservoirs, aiming to uncover potential opportunities within the UAE. It offers a comprehensive regional well and seismic based synthesis of the lower Habshan Formation, encompassing nearly all eastern onshore areas of Abu Dhabi. It leverages new interpretations from the latest mega 3D seismic data, various seismic attribute maps, and well data to provide a detailed understanding of the lower Habshan Formation. The regional facies and maps developed for the lower Habshan during this study offer a novel and more precise method for predicting strike-parallel continuity and lateral facies variability in prospective reservoir targets, as well as identifying new play concepts.