bluuebunny/crossref_metadata_2025 huggingface dataset:
3D Seismic Processing Involving UDD and SCDC Application in the Transition-Zone in Abu Dhabi, UAE
Authors: Hu Junhui , Ye Zaibing , Chen Yingpeng , Gao Junqi , Cambois Guillaume , Mahgoub Mohamed
Published: November 2024

Transition-zone (TZ) seismic surveying is difficult as it involves operating in land, marine and intertidal areas, which are often environmentally sensitive, and have a multitude of source and receiver technologies, each adapted to a particular terrain. This diversity in acquisition is also challenging for processing, for which the goal is to provide a seamless image of the subsurface regardless of the terrain and the technology used to record the data.

Our strategic approach unfolds in two pivotal phases: initially, it focused on comprehensive noise removal across land, intertidal, and marine. Meanwhile, meticulously addressing variations in amplitude RMS and wavelet characteristics associated with diverse terrains, sources (dynamite, vibrator, different Airgun with distinct signatures, and corresponding surface ghosts), and receivers (GPR nodes which used for recording marine data, GSR nodes which for land data).

Secondly, an Up/Down Deconvolution (UDD) was adapted to work within ultra-shallow water offshore environments. Where UDD was not applicable in onshore and intertidal areas, surface-consistent spiking deconvolution (SCDC) was applied instead, and with additional light matching process, the final connection between UDD and SCDC was seamless.

Denoise and multi-mode seismic data preconditioning work were challenging, it was also observed that offshore records were dominated by mud-roll and guided wave, while ground-roll and ambient noise prevailed onshore. The intertidal area suffered badly from weak signal and high sea waves noise. In processing, over ten iterations of denoise were employed to tackle different types of noise, such as spike, monochromatic, swell, air-blast, linear and random noise.

Prior to implementing Up/Down Deconvolution (UDD) or surface-consistent spiking deconvolution (SCDC), it is necessary to harmonize wavelet characteristics and amplitude RMS originating from diverse terrains, sources, and receivers. This harmonization process ensures the optimal performance of UDD/SCDC in mitigating multiples and enhancing signal uniformity.

Moreover, intertidal data presented unique challenges, in addition to standard processing, we have applied supplementary processing techniques tailored to elevate data quality and facilitate seamless transition from offshore to onshore environments.

With the application of optimum processing workflow, a seamless final image far superior to legacy data was obtained. Multiple content was much reduced due to the longer offsets seismic data and the UDD seismic processing route. Event continuity and fault definition were also improved thanks to the surface-consistent processes (especially SCDC) applied throughout the sequence. Furthermore, most notably, this TZ survey covered areas that had previously never been acquired which are highly prospective.
Digital SCAL for Improved Determination of Water Saturation in a Low Resistivity Pay Ooidic Middle East Formation
Authors: Eyvazzadeh R. , Grader A. , Hafez A. , Gonzalez D.
Published: November 2024

Digital rock analysis was used to develop a transform of deep resistivity to water saturation in a Low Resistivity Pay (LRP) Ooidic formation. These reservoirs often exhibit low resistivity which lead to pessimistic hydrocarbon volumes using traditional Archie's relationships. The paper presents the causes of LRP condition. The scope of this analysis was to obtain digital drainage capillary pressure and resistivity index (PCRI) data in rock types with significant volume fraction of micro porosity where physical experiments are difficult to perform. The digital PCRI data yielded variable Archie saturation exponents leading to new resistivity-water saturation transforms.

The Ooidic formation had three main rock types characterized by the volume of calcite cement in the macro pore system. The representative digital rocks were used to generate drainage PCRI data. Physical lab measurements included helium poro-perm tests, mercury injection, thin sections, and mineralogy. The outer porous layers of the ooids were partially saturated with high salinity water that created the LRP. The nano-environments translate to low rock quality that requires long experimental times, especially using porous plate drainage capillary pressure experiments. Representative three-dimensional digital rocks were generated using a combination of X-ray computed tomography (CT) and focused ion beam – scanning electron microscopy (FIB-SEM) methods. Digital rocks were used to simulate drainage PCRI experiments followed by a new resistivity-water saturation transform.

The digital rocks representing the outer layers of the ooids were used to generate PCRI data that matched well the MICP responses. The PCRI data for the micro porosity were integrated with the macro porosity data to create unique upscaled RI responses. The resulting Archie's saturation factor, "n", was variable with water saturation and unique for each rock type. Texture analysis of whole core CT data provided the location of the rock types in the logs. The new correlations between deep resistivity and water saturation were applied to generate an updated water saturation log that showed a significant decrease in water saturation in the LRP zone.

The novel aspect of this project is the generation of digital PCRI data for the porous outer layer of the ooids that explains the presence of a low resistivity pay zone. Obtaining such data with physical laboratory experiments is difficult and time consuming. Digital upscaling of the micro and macro PCRI data provided the means to map Archie's "n", construct a new transform equation, and generate an updated water saturation log for the well. The digital/physical integrative workflow was used for the first time in an Ooidic formation. A streamlined workflow may rapidly produce updated logs to increase the certainty in quantifying the original hydrocarbon in place in an exploration campaign or field development.
Applications of Advanced Acoustic Measurements for Reservoir Characterization and Geomechanics: Case Study from South Iraq
Authors: Shabeeb Ameen , Alward Wassem , Al-Jubouri Mohammed , Abdi Hadi , Patro Radhika , Mukherjee Nistha , Saha Saurajit , Chatterjee Chandreyi , Bhowmik Sneha , Bin Nie Xiang , Wang An , Zhong Yin , Zhang Yue
Published: November 2024

The oil and gas field in Iraq, referred to as Field A, has demonstrated consistent hydrocarbon production from its cretaceous reservoirs since its inception. A comprehensive reservoir characterization workflow, integrating petrophysical, geological, and geomechanical modeling enabled extraction of important reservoir insights, faster and safer drilling, and optimum completion design maximizing production from this field. Acquisition of advanced acoustic data, along with high-resolution image data has been instrumental in reservoir characterization. High-resolution multi-shot processing of monopole & dipole data provided insights into the formation properties and their variation radially and laterally. Dipole shear anisotropy analysis helped recognize the presence of stress-induced and intrinsic anisotropy in the formations. Geological features could be modeled using a combination of dipole shear anisotropy and image interpretation results. The complex pore system in carbonates poses challenges for using empirical porosity-based permeability estimation methods, an innovative workflow for permeability estimation was developed, utilizing Stoneley attenuation to derive continuous permeability. This workflow was carried out for multiple wells of Field A drilling across the Cretaceous successions. Acoustic anisotropy was observed in some intervals in deeper cretaceous reservoirs. The direction of anisotropy was found to be NE-SW which is aligned with the regional maximum stress direction. Stoneley mobility was analyzed and calibrated with NMR and other reservoir measurements to identify high mobility zones. These results integrated with petrophysics, geology, and geomechanics led to the evaluation of the potential reservoir zones thus aiding in future production planning. Multi-well pore pressure and horizontal stress modeling workflows were utilized Heavily depleted areas of the field were then recognized as differential stuck intervals and development drilling plans were modified accordingly. Horizontal stress modeling was carried out to identify stress barriers in the tight reservoir to assess the feasibility of successful fracking operations. The minimum required bottom hole pressures (BHP) have been also calculated for the initiation and propagation of the hydraulic fractures. This paper demonstrates the value of multi-well study and integration of petrophysical, geological, acoustics, and geomechanical analysis to get critical insights on reservoir and completion quality for sweet spot identification and drilling new wells for better productivity. Recommendations generated from these workflows served as a catalyst for achieving ambitious production goals in the field.
Revolutionizing Oil Production Field Operations in the UAE: Leveraging on the Cutting-Edge Drone Technology
Authors: Alshehhi Khulood , Aslam Muhammad , Al Naqbi Mohamed , Al Shamsi Hessa , Al Ketbi Abdulla , Al Dhaheri Bader
Published: November 2024

ADNOC Onshore's largest asset embarked on a cutting-edge drone technology deployment for the integrity evaluation of it and improvement of productivity while enhancing safety and sustainability. This paper presents the utilization of unmanned aerial vehicle (UAV) deployment in Oil Field for inspection of inaccessible locations like flare tips, overhead lines, swift emergency response, patrolling, and instant material delivery.

Deployment of avant-garde technology like drones was highly effective in various applications, including material delivery in difficult terrain, emergency response, inspection of inaccessible locations like flare tips and overhead lines, and field patrolling. State of the art drones with high-performance motors paired with wide propellers that ensure stable flight in strong winds in deserted environments were selected. A system that automatically heats the batteries while flying at subzero temperatures, an enclosed design with omnidirectional collision avoidance, and infrared laser to detect were selected as applications with the possibility of live-streaming and playback provision.
Application of Vortex Bladeless Turbines at the offshore Platform for Sustainable Energy
Authors: Dol Sharul Sham , Hamdan Hasan
Published: November 2024

The global demand for sustainable energy is growing rapidly, even in the oil and gas industry. The project largely centered on the extensive conception of vortex technology, energy endurance and the vortex bladeless turbine (VBT) design. In the case of the offshore platform, vortices are generated from both ocean currents and wind flows. These oscillations can be utilized to generate power due to the fluctuations produced by the vortices. Vortex-induced vibration works on the principle of Kármán vortices where a cylindrical or bluff-body shaped object oscillates due to the alternate vortex formation on the boundary layers by adverse fluid pressure. The oscillation depends on the unsteady lift and drag forces generated. This mechanical oscillation is later converted to electrical energy. This work focusses on the capability of VBT energy available around the offshore platform in order to determine the possibility of such utilization to meet the demand needed for these platform activities. These oscillations, it could be harnessed properly, would be able to turn into useful energy to supplement basic platform operations (i.e. lighting, pumps, compressors, heating and ventilations). The computational fluid dynamics simulation CFD ANSYS model was conducted using viscous shear-stress transport SST k-ω turbulence model to simulate the flow path and its oscillations and how the mast design can be optimized (i.e. by adding vortex generators) in order to produce the best possible VBT aerodynamics and hydrodynamics performance hence energy generation. The VBT model was then fabricated and experimentally tested in order to finalize the overall performance.

The utilization of carefully designed springs enables the VBT system to oscillate in resonance with the structural natural frequency to generate sufficient power measured by piezoelectric transducers. The performance depends on the followings; frequency and speed of ocean currents and wind flows, depth of water and size of offshore platform, air temperatures and pressures and size and materials of VBT. The main advantage of vortex bladeless turbine is it has both wind and ocean flow vibrations. There are no moving components, such as gears, bearings, or the requirement for maintenance, in a VBT making it suitable for a remote offshore application. VBT design has a number of attractive features; self-running and independent, made of lightweight minimal raw materials, environmentally friendly, in addition to its low cost and harmless to the oil and gas offshore operations. The platform also offers existing structural and power facilities for VBT installations. By completing this project, new and important knowledge regarding the ground-breaking advancement in novel vortex power generation would be gained that inspires new innovative ideas sustainable operation. Energy resource diversity is the key for energy sustainability and moving toward the UAE 2050 vision.
Autonomous Directional Drilling Delivers Faster and Less Tortuous Wells
Authors: Oliveira V. , Dossary A. , Osman A. M. , Ibrahim M.
Published: November 2024

Wellbore trajectory control in directional well drilling activity is done via directional drilling methods. Directional drilling is a technique that traditionally involved considerable human skill and intervention to steer the well, measure responses, project wellbore position, and react to results. Achieving a required well directional profile required experienced personnel to continuously respond to well requirements. Improved efficiencies were needed to be introduced to this field to benefit from the digital capabilities available for the industry.

Industry has strived to introduce a means of automating the directional drilling cycle where minimum human intervention would be needed. A system has been deployed in Middle East fields to automate the directional drilling workflow. The system uses advanced cloud-based software and connected intelligent systems to create a continuous feedback loop between the surface and downhole. The system reads the well trajectory data sent from downhole equipment and processes the trajectory compared to required target objectives, evaluates multiple projection options before selecting an optimized projection and sends surface communications to downhole equipment to follow the needed path with no human intervention.

A major operator focused on evaluating this system on multiple wells. Three candidate wells were selected to evaluate their directional responses compared to similar ones in the same basin. Detailed comparison for the three wells focused on achieving the required trajectories, rate of penetration (ROP) gains, reduction in the number of surface downlink commands compared to offsets to demonstrate better directional control and reduction in tortuosity levels compared to offsets. On these three wells, a total footage of 6,473-ft was drilled fully autonomously with no human intervention on directional drilling requirements. All profiles were successfully executed where computations, projections and commands were done through the automation system. Average ROP showed improvement reaching 24% compared to offsets. The number of surface downlink commands showed reduction up to 39% compared to offsets. Well tortuosity showed reduction up to 22% compared to offsets allowing for easier bottom-hole assembly tripping and tubular running.

The implemented autonomous directional drilling system has proven to deliver multiple directional profiles with no human intervention. The system demonstrated that digital capabilities can be utilized to improve directional drilling efficiency and to deliver further performance gains and smoother wells.
Accelerating Reservoir Modeling Workflows With Neural Operators and GPU-Based Full-Physics Simulations on the Cloud
Authors: Mukundakrishnan K. , Wiegand K. , Natoli V. , Etienam C. , Sethi H. , Tishechkin D. , Kahn D. , Ananthan V.
Published: November 2024

Large-scale applications in reservoir engineering, such as history matching, uncertainty quantification, well placement optimization, and reserve estimation, require numerous simulations of high-fidelity models. Despite rapid advances in high-performance computing, these simulations are computationally intensive and challenging. Integration of scientific machine learning (ML) techniques with high-fidelity full-physics computational models for developing high quality proxy/surrogate models offers a promising solution to overcome traditional challenges.

This work presents a workflow for generating full-field proxy models for predicting the time-evolving state variables (pressure and saturations). This is achieved by integrating a state-of-the-art ML framework with a GPU-accelerated full-physics simulator, the latter to help generate large amounts of training data in the fastest possible time. For the ML part, we specifically utilize Fourier Neural Operators (FNOs) for better generalization.

We demonstrate the effectiveness of our framework using two synthetic models and varying the positions of the wells, mimicking well placement optimization scenarios. Both the models considered are 2-phase oil-water systems with one injector well and four producer wells. The size of the grid is 64×64×64. For the first model, the permeability and porosity fields are assumed homogeneous while the second model has large variations in porosity and permeability inside the reservoir.

Our results show that FNO-based ML approach holds promise for addressing full-field proxy generations for challenging models with complex variations in saturation front topologies. The total water injection rates and oil production rates were accurately captured by the current model. The study showed based on the complexity of the model, selecting the right number of Fourier modes is critical for ensuring accuracy. While using a lower number of modes may resulted in smoothing of the saturation front that may not always be desirable, a higher number of modes resulted in small and non-physical bounded (stable) variations along the saturation fronts.
An All-Electric Intelligent Completion System For Zonal Water Injection Well With Snubbing Operation
Authors: Wang Quanbin , Zhang Weiping , Feng Fan , Liu Yazhen , Jia Deli
Published: November 2024

During the construction of water injection wells in low permeability oilfield, the wellhead usually has a pressure of over 1450 PSI. The conventional intelligent completion system, due to the hydraulic pipelines or the cable being placed outside the tubing, should release the pressure to drop below 72.5 PSI before the operation, which exists such problems as long-time occupation of wells, destroying the balance between injection and production, and discharging a large amount of sewage.

This paper proposes an all-electric intelligent completion system for zonal water injection with snubbing service. The system is designed with a non-contact docking device, with the female connector running along with the completion string, and the male connector running down to the female connector center from the inside of the tubing using a cable after the packers are set. Based on the principle of electromagnetic induction, the power and signals can be wirelessly transmitted between the male and female connectors. In this way, the system could achieve control and monitoring of water distributors, and meet the snubbing operations.

The core tools of this technology include ground control host, non-contact docking device, integrated intelligent water distributor and other devices. The ground control host can collect underground monitoring data from water distributors and control them to adjust the water injection volume in separate layers. The non-contact docking device consists of a male connector and a female connector, which are connected to the top water distributor and located at the upper end of the distributor. The docking device has an average power transmission efficiency of over 85%, a maximum power of 36W and a data communication efficiency of 4800bps. The integrated intelligent water distributor integrates a dual channel water distributor and a packer. A set of water distributor can monitor the pressure and flow rate of two zonal layers, infinitely regulate water injection volume of each layer and implement interlayer isolation. The flow rate of a single layer can be measured in the range of 31.45~629 bbl/day with the accuracy of ±3% Full Scale. The system has applied four wells in Jilin Oilfield of China National Petroleum Corporation, which can achieve 435 PSI snubbing operation, and can monitor and control zonal water injection parameters in real time.

The all-electric controlled intelligent completion system for zonal water injection has advantages of being suitable for snubbing operation and real-time monitoring of water injection parameters in layers. It provides engineering and technical means to alleviate interlayer conflicts in injection wells that require snubbing operation, improve reservoir awareness, and ensure safe and green production in oil fields, with broad application prospects.
Enhancing Well Intervention with a 360° Multi-Side View Camera Visual Analytics Service: Case Study in Saudi Arabia
Authors: Coello P. Vandeweerd , Pratama A. , Ermakov K. , Raza M.
Published: November 2024

The 360° Multi-Side View Camera (360 MSVC) visual analytics service is a revolutionary tool that provides real-time video feed and detailed wellbore data analysis that can be run simultaneously with most other coiled tubing (CT) downhole tools. Its unique capabilities were recently demonstrated during an operation in Saudi Arabia, where it successfully addressed a challenge with a trilateral producer well with stuck interval control valves (ICVs).

The well, drilled in 2006, had ICVs that have been immobile since 2019, suspected to be impaired by scale deposits or mechanical damage. The 360 MSVC was deployed to inspect the condition of the ICVs and successfully identified scale deposits and damage.

After the diagnostic phase, a course of action was determined, and an acid wash with CT was performed to clean the ICVs and dissolve the scale deposits. Shifting tools and an impact hammer were used alongside the 360 MSVC to manipulate the ICVs, and real-time visual feedback confirmed the two ICVs were successfully cleaned and shifted. A third ICV, however, could not be shifted because of mechanical damage; but this issue was identified quickly, which prevented any additional time spent on ineffective solutions.

This successful intervention, guided by the 360 MSVC, has paved the way for its application in more wells in the near future. This case study highlights the value of the advanced analytics of the 360 MSVC and its pump-through capability, which enables it to be run with additional tools simultaneously. This combination allowed accurate diagnostics, intervention, and verification in a single trip to enhance operational efficiency and cost-effectiveness.
Enhancing Offshore Pipeline Safety: Application of Vibroacoustic Technology for Impact & Leak Detection
Authors: Gomes A. P. , Marino M. , Romagnoli I. , del Giudice S. , Chiappa F.
Published: November 2024

Vibroacoustic Technology is an effective tool for detecting leakages and third-party interferences in pipelines. It operates on the principle of identifying pressure, sound, and vibration patterns generated by leaks or various activities near the pipeline, both above and below ground. These activities can include excavator digging, landslides, construction work, impact or anchor drags on offshore pipelines, and other potentially harmful actions.

Beyond detecting third-party activities and leaks, Vibroacoustic Technology provides precise and timely localization of these events, enabling rapid intervention and repair. This capability is particularly valuable in remote areas where accessing the site for repairs may be challenging. Furthermore, precise localization of detected events minimizes the time and resources needed for repairs.

The technology's deployment is non-invasive. Vibroacoustic sensors are equipped with static pressure sensors, hydrophones, and accelerometers, can be installed both onshore and on offshore pipelines, can be placed on existing derivations, spaced tens of kilometers apart. The data collected by these sensors are transmitted to a central processing server where core processors analyze it, performing noise removal, detection, and localization algorithms. Upon detecting an impact, the software modules search for vessels sailing in the impact area using an automatic identification system (AIS). This information is then added to the alarm database.

In summary, Vibroacoustic Technology is versatile, capable of detecting various potentially harmful activities, and serving as an effective leak detection system. Its precise and timely event localization helps minimize repair time and resources, ensuring the safety and integrity of gas pipelines while reducing maintenance and repair costs.
Revolutionizing the Perforation Process Via an End-To-End Automated Perforation Toolbox in the Gulf of Thailand (PerfSight)
Authors: Tonburinthip T. , Norasaed W.
Published: November 2024

This paper presents an innovative solution to generate the composite log using the in-house auto depth-shifting program and addresses the challenge of determining the optimal perforation depth for reservoir engineers to achieve optimal hydrocarbon recovery and reservoir performance. The traditional manual process of depth shifting is not only time-consuming but also prone to human errors, requiring collaborative efforts from multiple stakeholders.

To address these challenges, Perfsight was developed, an in-house programming tool. It incorporates three key modules: auto depth matching, perforating depth optimization, and cement verification. The first module utilizes grid search to align depths between open-hole and cased-hole logs, accounting for variations in weight tension. The second module employs linear programming to optimize perforation interval selection, considering practical constraints. By assessing key factors such as resistivity, gamma rays, density, and neutron, our automated method ensures optimal perforation intervals. Lastly, the cement verification module utilizes a cement score equation to automatically identify the "good cement zone," mitigating the risk of flow behind the casing.

Our study demonstrates a perforation enhancement process, transitioning from depth matching to cement verification in the perforating process. Our depth matching module achieves a commendable similarity score of 0.93, facilitating automatic correlation between open-hole and cased-hole logs. Following this, our tool utilizes linear programming to suggest perforating depths for each sand, considering operational constraints such as interval length and patching area to prevent water-coning. The model selects optimum intervals by prioritizing prolific, porous, clean, and top sections of the sands, resulting in a 20% increase in prolific score compared to manual selection. Subsequently, the model evaluates cement quality using a developed equation, identifying intervals with a cement score exceeding 80 as "good cement zones" to prevent water-flowing behind the casing. Our tool significantly streamlines the perforating process, reducing processing time from 4 hours to just 20 minutes, while also automating error-prone tasks such as cement quality verification. When integrated, these components produce a comprehensive one-stop service, generating a composite log.
How, Why, and Where Thermal Diffusion Properties Work in Oil and Gas
Authors: MacMoy Ian , Motovilin Adrei
Published: November 2024

This paper focuses on testing done by oil companies and results from a protective intermetallic system (PIS) for production pipe in sour gas regions. The testing focuses on exposing the materials to stresses such as wear, tensile, chemical environments and compares the results against legacy materials in those regions. The testing parameters were taken from direct instruction from oil companies needing these tests for individual regions specifically associated with West Texas and Oman, in depths more than 7000 feet. In those locations, sour gas, brine conditions, thermal stress, and mechanical stresses combine to play a complex role in corroding production pipe. Oil companies are looking for ways to reduce equipment turnover to improve productivity. Coatings historically create a barrier to the corrosive environment; however, the coating may not be robust enough to withstand the stresses or can inadvertently create more stresses. The Intermetallic layer of the (PIS), the thermally diffused alloy has very different properties. The thermally diffused alloy works with the substrate to create a new alloy or intermetallic layer to block out the stresses from reaching the substrate at the microscopic level.
E-Navigate Aids for Smart and Adaptive Planning, Scheduling, and Excursions
Authors: Yahia A. O , Qahtani M. A , Alsalim A. T
Published: November 2024

Navigation aid is a crucial component in offshore oil and gas operations which directly affect not only the cost of the operation but also and more importantly the health and safety of agents. Annually the number of vessels offshore increase due to the high demand in the industry. With that being said, navigation and maintaining the offshore equipment, such as buoys, becomes inherently more difficult.

In any operation, maintaining the different equipment and artifacts that contribute to the end goal is critical. However, it does come with a challenge. On one hand there are cases where the equipment in question is due for a planned maintenance. On the other hand, equipment fails suddenly or require and immediate response, which is the less desirable scenario.
Certified LNG Bunker Metering System for Maximum Transparency
Authors: Author Stephan Natter , Author Sam Miller
Published: November 2024

The demand for Liquefied Natural Gas (LNG) as a marine fuel is surging as ship owners strive to comply with emission reductions set by the IMO. Transparency during bunkering operation is key to ensure acceptance by the different stake holders involved. The measurement equipment which is used today often misses on measurement traceability and custody transfer certification for the quantity measurement. Short deliveries and disputes between buyer and seller are the result.

Complex and maintenance intensive gas analysis equipment is used to measure the LNG composition and requires frequent maintenance.

This paper outlines the benefits of utilizing a custody transfer approved bunker metering system based on MFM (Mass Flow Meter) in combination with Raman spectroscopy.

The transferred quantity of LNG is measured with custody transfer approved Coriolis mass flow meter of type Promass Q. This mass flow meter type has a mechanically optimized design for cryogenic liquids which leads to high temperature stability and accuracy. The quantity measurement includes LNG, boil off gas (BOG) and fuel gas consumption. Raman spectroscopy is used to measure the LNG composition in real-time without the need for vaporization and sampling. Custody transfer approved flow computers calculate the amount of energy transferred and provide the reporting for commercial transaction. In addition, the methane number is calculated following different mathematical models.

The quantity measurement shows significantly better accuracy than required by OIML R117. The operation time is reduced due to real-time LNG composition measurement. This LNG bunkering system allows compact installation on board the bunker tanker because no vaporization and sampling equipment is needed. The Raman analyzer does not need any calibration gases for frequent verification. This reduces the effort and costs for maintenance. The real time quantity and quality measurement provides a high degree of transparency during the bunker operation. The combination of accuracy, transparency, custody transfer approval and real time information gives all stakeholder a high degree of confidence into the received measuring results.

New is the combination of custody transfer approved MFMs with a Raman analyzer for metering LNG bunker transfers. The custody transfer certification for metering the LNG bunker quantities sets the corner stone for transparency and measuring accuracy. It lifts LNG bunkering on the same level of system integrity as we know it from the oil bunker industry using MFMs already today.Body text 1 paragraph.
Machine Learning Assisted Framework to Improve Well Rate Estimation Processes for Enhanced Production Surveillance
Authors: Gireesh Greeshma , El-Bakry Amr , Garrison Brett , Smith Richard , Singh Vikash , Avlani Jainam , Khera Kashika
Published: November 2024

Robust well rate estimation, one of the most important requirements for production surveillance, is essential to understand the performance of a hydrocarbon field and plan optimization activities that can assist in additional production uplift. This paper is concerned with developing a novel framework to combine multiple data sources in order to produce highly reliable well rate estimates. The focus is on improving meter water-cuts (water to total liquid ratio) during measurements using manual spin cuts. Accuracy of in-line automated water-cut meter readings, which measures water-cut during well testing, gets reduced with presence of gas. Water-cuts calculated from spin cut samples, which are manually collected from well test set-up, are more reliable as they do not depend on gas content. Different machine learning modeling approaches were evaluated to estimate a new corrected meter water-cut reading for every well test, using historical spin cut data and closest meter water-cut and temperature readings recorded during collection of these spin cut samples. To account for fluctuations in meter readings resulting from manual calibration of meter, a weighted correction factor ("bias correction") was also added to the improve the predictions. While comparing raw meter reading and model estimates to water cut from spin cut samples, from one year of unseen data, a significant reduction (from 5.6% to 0.5%) in mean error was observed. From evaluations, Tree Bagger models, which are Random Forest models without random selection of features, were found to have the best performance. Moreover, the model was able to capture and respond to sudden shifts in meter readings, possibly originating from manual calibration of the meter. While considering individual wells (or well groups which are tested together through the same meter), poor model performance was observed for few wells where spin cuts consistently recorded values lower than the corresponding meter readings. Model performance was also impacted on well groups where (a) spin cuts taken in close time proximity showed higher variation in water-cuts and (b) spin cut data was sparse. The corrected water-cuts and corresponding phase rates received positive feedback from the operators, underscoring their significance in well rates estimation. This approach uses multiple data sources, real time and historical meter data and, latest and historical manual spin cut data for a surveillance system that runs every few minutes, thus correcting water-cut measurements and coupling it with real time well rate estimations. Additionally, an innovative bias correction method was implemented to improve accuracy of measurements. This framework generates substantial value for upstream businesses with higher well counts (1000+ wells) where data driven approaches are proven to enhance surveillance.
An Integrated Approach of Thin Carbonate Reservoir Prediction and its Application
Authors: Jianfang Yang , Shanbo Sheng , Jiawen Song , Bao Li , Mengze Li , Tiejun Sun , Jiangong Chen , Xueyin Ding , Zichang Tang , Qiang Li , Ailing Wang , Guibin Dong , Yong Liu
Published: November 2024

Controlled by sedimentary diagenesis, the carbonate reservoir in the N Block of the eastern margin of Pre-Caspian Basin are mainly 3-5 meters thick. The accuracy of reservoir prediction is low, posing significant challenges to exploration. To address the problem, a new integrated thin carbonate reservoir prediction technique was summarized based on geological genetic analysis and Seismic Meme Inversion.

The integrated thin carbonate reservoir prediction workflow mainly includes 3 steps. 1) Integrated sedimentary microfacies classification based on core, well logging, seismic and palaeogeomorphology to identify favorable facies (Inner shoal) for the development of thin carbonate reservoirs; 2) In the favorable facies, generated the characteristic physical parameters which can reflect the thin carbonate reservoir sensitively by curve reconstruction technique; 3) Utilized the method of Seismic Meme Inversion with high resolution to complete the thin carbonate reservoir prediction quantitatively based on reconstructed well logging and high quality seismic data.

According to the certification of new drilling wells, this technique has been applied successfully in carbonate reservoir in Block N on the eastern margin of Pre-Caspian Basin. The 3-5 meters carbonate reservoir can be effectively identified, with a drilling coincidence rate of over 90% in thin reservoir of 5 meters or more, as verified by new drilling well, greatly improving the drilling success rate.

The integrated thin carbonate reservoir prediction workflow integrated geological analysis and high resolution Seismic Meme Inversion improved the accuracy and reliability of thin reservoir prediction. Under the guidance of geological analysis, the geophysical exploration technology takes full account of the genetic mechanism of geological body, which can greatly reduce the multiplicity of reservoir prediction by using seismic data.
Advancing Portfolio Project Delivery and Operation Handover Assurance Through Digitalization in the Oil and Gas
Authors: Chime Kingsley Chidiebere
Published: November 2024

Consistently delivering success in the dynamic Oil and Gas industry is dependent of the effective identification and development of hydrocarbon opportunities. Research from Senseye Predictive Maintenance shows that the average oil and gas producer loses up to $128 million per year (3). Unplanned downtime and production deferment from missed Asset handover transition continues to add up, and in today’s energy environment, that magnitude of loss just isn’t sustainable.

The recent energy crisis and the resulting focus on energy supply and security have led to a recovery in oil and gas demand. Capitalizing on that demand, however, isn’t so easy. Industry Operators are filling the gap and getting more performance out of existing assets through expansion and modification projects. While the timely execution and delivery of cost effective engineering projects is critical, the actual transition from Project completion to Asset Handover acceptance is considered the cornerstone of this success. This paper explores the role of Digitalization in advancing First-Time-Right Project-to-Asset Handover Assurance in Oil and Gas sector, to enable the efficiency, accuracy, and transparency of this Transition Phase. The harmonization and automation of multiple Project Management business processes, and integration with Digital Tools, have enabled real-time data exchange, collection, and analysis, and ensure that all project deliverables meet the required specifications before handover. This approach provides auditable trail of activities, enhance compliance with related Technical Standards, and provide basis for proper stakeholder oversight of project status. Digitalization have shown to represents a paradigm shift, and an imperative for companies aiming to enhance operational efficiency, reduce risks, and achieve sustainable growth in a highly competitive industry where the Unit Cost of Production needs to be kept at the minimum. This paper would reflect on the enhanced Project to Asset Handover Framework, as implemented in Petroleum Development Oman (PDO), and how it transformed Flawless Project Delivery.
Utilizing AI to Maximize Equipment Availability at Minimum Operational Cost & Reduce Emission Impacts
Authors: Mohamed K. A. , Aboutaleb A. , Ghosh R. , Mahasseb M. , Altayer A.
Published: November 2024

Organizations striving for operational excellence must constantly evolve their ability to deliver customer value while increasing the cost-efficiency of their operations. The essence of this endeavor is to boost equipment ROI (Return On Investment) by prolonging its useful life and lengthening intervals between major maintenance overhauls, thereby reducing equipment renewal and operational costs while ensuring availability and integrity.

AON's maintenance & reliability department has devised an optimal procedure called RBMO (Risk-Based Maintenance Optimization) to meet these goals. The process starts with a pre-selected list of equipment scheduled for next year's major overhaul according to OEM (Original Equipment Manufacturer) guidelines. Each piece of equipment undergoes four different assessments: AI-predicted performance using the CPAD (Computerized Predictive and Diagnostic) system, condition monitoring techniques (like vibration, oil analysis, thermography, etc…), historical reliability data, and a comparison of energy versus maintenance costs. Should all evaluations yield favorable results, extending the equipment's service life can be done safely.

The development of the process began in 2023. The application of the new process commenced in the fourth quarter of 2023, resulting in an assessment of 11 pieces of equipment and deferring the maintenance overhaul (MOH) for 9 items to the following year. This decision was based on risk assessments that led to a savings of $1.9 million per year in maintenance costs and generated an additional $900K annually in production availability. In the first quarter of 2024, further assessments were conducted on 26 pieces of equipment, with 23 equipment MOHs being postponed to the subsequent year, saving another $875K in annual maintenance costs and enhancing production availability by $2.6 million. In total, these actions have saved $2.775 million per year in maintenance expenses.
Enhancing Offshore Personnel Transportation Efficiency Through Digital Logistics Management
Authors: Larsen F. , Wickholm R.
Published: November 2024

Executive Summary

The offshore industry is characterized by its inherent complexity, with numerous interconnected components requiring precise coordination to ensure smooth and efficient operations. One of the most critical aspects of these operations is the transportation of personnel, which is often plagued by challenges such as lack of collaboration among multiple stakeholders, reliance on manual processes, disconnected systems, and communication barriers.

This whitepaper examines the various challenges and inefficiencies associated with current offshore personnel transportation processes. It highlights the transformative potential of adopting a digital logistics management system, particularly through a Software-as-a-Service (SaaS) solution. By integrating advanced digital tools into the planning and execution phases of personnel and cargo transport, organizations can achieve substantial improvements in several key areas.

Firstly, operational efficiency can be significantly enhanced through better coordination and real-time visibility of logistics activities. Secondly, cost savings can be realized by optimizing resource utilization and reducing unnecessary expenditures. Thirdly, workforce allocation can be improved, ensuring that personnel are deployed where they are needed most, thereby minimizing delays and enhancing productivity.

In summary, this whitepaper underscores the importance of digital transformation in the offshore industry. By embracing SaaS solutions, organizations can overcome the limitations of traditional methods, leading to more streamlined, cost-effective, and efficient operations. The insights provided herein aim to guide industry stakeholders towards adopting innovative digital strategies that will drive future success and sustainability.

Key Benefits Highlighted: Operational Flexibility: Enhanced ability to adapt to unforeseen disruptions.Seamless Communication: Improved collaboration and information flow among stakeholders.Accommodation Optimization: Better planning and utilization of offshore accommodation resources.Equipment-Staff Alignment: Synchronized arrival of personnel and equipment at offshore sites.
Regional Globigerina Limestone Characterization by Fluid Replacement Model and Pre Stack Inversion for Predicting Future Exploration and Development in Northeast Java Basin Indonesia
Authors: Sumantri Indra
Published: November 2024

Since 1980, Globigerina limestone reservoirs have been explored and successfully discovered biogenic gas. At least, 15 wells were drilled with 13 of them are contributing to energy sustainability in Madura and East Java communities of Indonesia. Gas accumulation of this unique reservoir is very well pronounced in seismic data, either found as seismic flat spot, seismic dim spot, and seismic bright spot. Each of this seismic response correlated to its reservoir characteristic, where porosity ranges up to 55% with permeability up to 500mD. The facies of Globigerina limestone foraminifera are varied from grain-stone to pack-wackestone. Even though the success ratio of this play is high, due to its marginal resource, a thorough reservoir characterization has to be established, or the field may end un-economic when the properties are far worse than expected. Regional AI - Vp/Vs cross plot is the initial tool to define the filled gas reservoir qualitatively among existing wells, roughly describe the reservoir quality through rock density and p-wave velocity. By using the Zoeppritz equations, the reflection coefficients are calculated and generated P-impedance, S-impedance, and density as outputs. Others elastic moduli such as bulk modulus and LMR were derived from these individual parameters for further discriminations among lithology, porosity, and fluid effect. The aim of this regional study is to deliver the workflow in dealing with such unique reservoir, with very limited deposition over the world. This workflow can be used as exploration or appraisal and development tools where size of the field is quite challenging yet still tempting to look and economically valuable for investment in Indonesia.