bluuebunny/crossref_metadata_2025 huggingface dataset:
Deep Learning Application for Inverting Petrophysical Properties Directly from Seismic
Authors: Lew C. L. , MacBeth C. , Elsheikh A.
Published: October 2023

In this study, we introduce a method to directly invert for porosity, Vclay and hydrocarbon saturation (Shc) simultaneously from pre-stack seismic data using deep learning approach. We implemented L1 norm in the loss function for Shc estimation, added noise into synthetic seismic dataset for training, and estimated uncertainties in the inversion results by training multiple network models. UNet architecture (ResNet-18 as encoder) is used due to its ability to preserve spatial resolution. The inputs for the network are the angle stacks whereas the outputs are the petrophysical properties. We implemented mean-squared error and L1 norm as the loss functions during the training process. The L1 norm is the mean absolute values of the predicted hydrocarbon saturation, which can help promotes sparsity. The network learns on synthetic dataset. We use facies-based geostatistical simulation to generate 1D synthetic petrophysical logs. Then linking the petrophysical properties to elastic properties through rock physics model (RPM), followed by computation of reflectivities using full Zoeppritz equations at five different groups of incidence angles (0°-55°). The traces in each group are convolved with the source wavelet prior to stacking the synthetic seismograms. To increase the variability of possible scenarios, we vary the spherical variogram ranges (8,10, and 12ms), use four different types of suitable RPM, apply oil and gas cases for the hydrocarbon fluid types, and convolve with nine different sets of angle dependent source wavelets. Two synthetic datasets are prepared: Dataset1 (ideal noiseless case) and Dataset 2 (noise added to the angle stacks), and a field data. The first (MLT1) and second (MLT2) machine learning are trained on a sub-dataset in Dataset 1 and 2 respectively. Based on the field dataset, the results from MLT2 show a better prediction performance than MLT1, with an average correlation coefficient of 0.68 (porosity), 0.74 (Vclay) and 0.67 (Shc) achieved. The better results from MLT2 can be related to the nature of measured seismic which contain noise that being learnt by MLT2. For uncertainty estimation, the network (ML3) is trained for 20 times on randomly selected sub-dataset in Dataset 2 using Monte Carlo dropout technique. The uncertainty is estimated by calculating the standard deviation of the solutions provided by ML3 when applying to the field data. Uncertainty estimation allows quantification on the stability of the solutions when varying training dataset.
Wireless Operation of Subsea Hardwares in Field X, Nigeria
Authors: Ngerebara J. , Ugbor I. M , Alawode O. , Brewer R. , Prandi R. , Lokka T. , Tarakanov A.
Published: October 2023

Tubing hanger (TH) installation in offshore subsea wells is a vital step in the construction and operation of oil and gas production systems. The TH is used in the completion of wells to suspend tubing from the Horizontal Xmas Tree (HXT), the wellhead (WH) or the Tubing hanger spool (THS), allow communication of hydraulic and electric down hole functions and seal-in the annulus. TH with tubing provide a conduit for the extraction of hydrocarbons from beneath the seabed.

Installation and retrieval of the Tubing Hanger is typically performed using a tubular riser inside the marine riser and Blow Out Preventer (BOP). Installation and recovery of the TH is via a Tubing Hanger Running Assembly (THRA). A THRA consist of a Simplified Landing String (SLS) or also called a BOP Spanner Joint and a Tubing Hanger Running/Retrieval Tool (THRT). The control of the THRT and associated downhole functions has historically been provided through a heavy-duty umbilical or Electro-Hydraulic (EH) umbilical, manually clamped to the drill pipe during deployment.

This set-up requires a large investment in associated equipment; EH Reel c/w umbilical, Work Over Control Unit (WCU), also known as Workover Control System (WOCS) and a substantial amount of rig real-estate with multiple resources to operate. Several activities and processes are required to be performed in parallel during the handling of the umbilical and clamping of the umbilical to the drill pipe during deployment. This presents specific challenges which must be carefully managed. In this context, it is essential to understand the function of an EH umbilical and the associated difficulties it brings.

This paper provides an overview of the specific challenges associated with the traditional deployment of the EH umbilical and an alternative new technology which removes the EH reel and WCU from the overall set-up. It is important to clarify that at the time of writing this paper, the new technology has not been deployed in field X, Nigeria.
Data Analytics from a Legacy Dataset Enabling Optimization of Coiled Tubing Drilling Laterals in a Geologically Complex Gas Storage Reservoir
Authors: Saradva H. , Jain S. , Shaikh M. , Barhate A. , Bihade K.
Published: October 2023

Sharjah National Oil Corporation (SNOC) operates the Sajaa gas field since the 1980s. From 2003-06, a highly successful Underbalanced Coiled Tubing Drilling (UBCTD) campaign was executed by drilling 163 multi-laterals for production enhancement. Two decades later, utilizing this huge data repository, SNOC performed a data science study to improve the understanding of the reservoir and drilling methodologies for an adjacent gas storage field for productivity enhancement in mature wells.

The team compiled an extensive dataset of production and pressure while drilling data in combination with biostratigraphy information from the drill cuttings. This unique collection of valuable UBCTD data was then structured and ready to use in a data science initiative. The various parameters were analyzed against each other to determine multiple relationships between productivity, drilling and geology. The outcomes from this study form the basis of the multilaterals’ placement for the UBCTD planned in three development wells. The project aims to increase the well capacity for injection and production by over 1.5x times.

The data repository and its derived analytics were crucial for the team to visualize all relationships between geology, reservoir properties, well productivity and drilling parameters. The study outcomes provided tangible evidence to the team in planning the UBCTD laterals in the gas storage reservoir. The pressure regime and drilling philosophy of the upcoming injection UBCTD laterals differ significantly from the legacy UBCTD campaign executed two decades ago, and the data was used cautiously to achieve the following objectives: Identifying and quantifying the most productive biozones within the Thamama reservoir associated with lateral placementDetermining the optimum lateral length, trajectory, inclination and drilling parameters for well stability and improved productivityIdentifying drilling issues encountered at reservoir and drilling parameters

The paper accentuates the importance of the typically untapped legacy data for well and field development planning. Using modern tools at our disposal with conventional workflows, we gain the unprecedented potential to improve the understanding of the reservoir and positively impact the project outcomes. This paper demonstrates the value of data science and analytics on legacy data, where technology reduces drilling and sub-surface uncertainty for a critical development project.
Geosteering in Swept and Stacked Channel Reservoir - Integrated Approach Using Mathematical Reservoir Modeling Towards Completion Optimization
Authors: Al-Kandari Talal S. , Sadeq Abdullah , Al-Shammari Omar H , Al-Dhafeeri Sultan , Santoso Gagok Imam , AlGhamdi Sarah Mohammed
Published: October 2023

Bedding characteristics and the vertical fluid distribution are factors that, when not addressed properly, can jeopardize the results of a horizontal drilling campaign. However, the risk and uncertainty can be mitigated by the integrated reservoir and geological modeling approach using recent LWD technological development. this paper will present an analytical roadmap from reservoir modeling toward well placement evaluation and completion optimization.

The reservoir context of this study is divided into upper and lower sand packages. The upper sand has two stacked channels separated by a silty layer, thus becoming the main producer reservoir target. The lower sand has one stacked channel, which is expected to be swept (water zone), as indicated by some offset wells having high water cuts. The first roadmap is to build a workflow to geosteer the upper stacked sand packages. The second one simulates the expected swept zone properties and correlates it with Ultra Deep Resistivity. The third roadmap is to evaluate the formation evaluation to enhance the completion optimization.

The well was drilled along a 1000ft MD interval at the upper sand package, which first half at the first lobe, then continues to the second lobe at the second half. High-definition Ultra-Deep Resistivity (UDAR) resistivity inversion helps to optimize well placement and maximize reservoir exposure. UDAR Inversion also maps the second layer reservoir properties. The observation at the lower sand lobe with the potential water-swept zone with more than 80 – 90 % saturation in some areas. The information was paired with the information about channel geometry and internal architecture, enabling the delineation of reservoir architecture and properties. Based on this finding, the formation evaluation analysis combined with the UDAR inversion to optimize the inflow control completion design. The success of this well has shown the benefits of utilizing a new deterministic parametric deep resistivity inversion. The information about the channel sands’ extent and geometry, as well as the identification of their internal architecture, has reduced uncertainties and increased reservoir understanding.
Optimizing Sulphur Granulation Process Scheme to Reduce System CAPEX
Authors: Kumar Pankaj
Published: October 2023

Sulphur is a vital and essential by-product of sour gas processing. Smooth operation of Sulphur production/ handling facilities is a key for business continuity in gas processing industry. Sulphur (Solid) is a challenging material to handle due to its brittle nature and prone to breakage due to abrasion during transport, storage, and handling. Excessive dust generation poses a serious safety risk due to explosive nature of Sulphur dust. Despite various measures to collect and suppress Sulphur dust, it remains a potential source of fire and explosion hazards, as well as maintenance issues

Apart from other forms of Sulphur compound (H2S/SO2/SO3), elemental Sulphur itself in the form of yellow dust is also an environmental pollutant. Sulphur is transported mainly in solid form as liquid Sulphur transportation is a big hazard.

This study is based on experience from a Sulphur granulation and handling facility in an organization which produces and handles the liquid /granulated Sulphur at a very large scale with around 22000 TPD. During transport / storage / handling, due to breakage of Sulphur granules, huge dust is generated. Being air-borne, this Sulphur dust has a great potential of fire/explosion and serious HSE concern for organization considering safety as its top priority.

Considering above, strength of granulated Sulphur product is of utmost importance. This strength depends on polymeric content in Sulphur. Various old research used to recommend different operating parameters to increase and maintain the polymeric Sulphur content. One of the conventional approaches is to maintain high liquid Sulphur temperature during transportation and storage and cooling in Sulphur coolers just before solidification in granulation process through Granulators. Sulphur coolers and associated system are CAPEX intensive. This paper explores the possibility of eliminating the Sulphur coolers requirement to optimize the CAPEX.
Development of a Repeatable and Objective Decision Model for the Human Error Probability Estimation According to the HEART Framework
Authors: Mascherona R. , Compare M. , Medici S. , Zio E. , Ronchi A. , Zausa F. , Caia A.
Published: October 2023

The proposed methodology aims at developing a model to provide a structured and repeatable approach to estimate the error probabilities of the human actions carried out during well construction and control operations according to the Human Error Assessment and Reduction Technique (HEART) approach. This relies on a combination of AI-based and traditional techniques that exploit all the available Knowledge, Information and Data (KID) in the field. The modeling framework consists of different steps. According to the decision science paradigm, identification of the criteria to assign a nominal Human Error Probability (HEP) to each human action considered in the analyzed risk scenario, according to the HEART framework. The development of a Bayesian Network to characterize the qualitative categorical variables for each HEP assignment criterion, based on the available KIDs, and describe the uncertainty on the factors that HEART considers to modify the nominal HEP into the actual HEP. Encoding of the estimated task actual HEP into the risk scenario probabilistic model. The developed methodology has been applied to a case-study related to a "blow-out prevention scenario" in the context of a drilling platform. All the human actions involved in the prevention ofblow-out and carried out on the rig site have been analyzed, collecting the available KID. This provides evidence to build a Bayesian Network model, which allows obtaining a probability distribution for each task over the possible generic tasks, thus preventing the limiting approach of relying on a single assignment, which inevitably neglects some aspects and, thus, results in an inaccurate HEP estimation. This allows overcoming the limitations of the HEART methodology, which is characterized by vague descriptions, as we focus on understandable criteria harmonizing HEART categories with the task features. The results show the complexity deriving from this attribution process, highlighting how the generic task which shows more compatibility with the analyzed task is generally not the most conservative and robust choice. The novelty of the approach is in the rationalizationof the application of the HEART methodology, by developing a HEP attribution methodology that exploits all the available KID without reducing to traditional qualitative categorization.
Driving Safe, Reliable and Sustainable Operations Using a Novel Asset Performance Management Framework
Authors: Alrabady Linda A.
Published: October 2023

The oil and gas industries are under a huge pressure to deliver the world’s energy needs in a secure and affordable manner whilst keeping up with ever-increasing emphasis on regulatory compliance and environmental sustainability. Price volatility calls for decarbonization, and aging infrastructure have added pressure on shrinking margins, despite resulting cost-cutting initiatives.

The Energy industry carries added risks due to the nature of its operations: handling and processing hydrocarbons, complexity of the asset mix and value chains, as well as the potential for severe personnel, process safety and environmental incidents. The license to operate is very much linked to the operators’ ability to manage all those risks effectively, throughout the asset life cycle by ensuring that integrity and reliability are designed into projects and delivered throughout the consecutive lifecycle stages. (Procurement, construction, commissioning, operations, and disposal). Establishing a best practice asset performance management program while balancing these business drivers and factors into the decision-making, results in optimized management of risks to the business.

This paper presents a novel asset performance management framework based on Risk-Based Reliability Centered Maintenance (RCM3), with emphasis on explainable, open box hybrid Man-Machine collaboration models that have proven effective in identifying and monetizing dynamic risks, recommending and prioritizing proactive risk management actions, and finally, monitoring the effectiveness of those interventions to form a profile for driving safe, reliable and sustainable operations of Oil and Gas Facilities. The proposed methodology relies on Contextualizing equipment data from operational technology (OT) systems combined with years of codified experts’ knowledge. By shedding the light on the data, the data will shine a spotlight on what matters and help prioritize actions thus balancing Risk, Cost, and business objectives.
The intelligent Carbon Leakage Surveillance (iCLS) System
Authors: Al-Qasim Abdulaziz S. , Alzayani Alia , Almuaibid Abdulrahman , Yousef Ali , Burba George , Fratini Gerardo , Griessbaum Frank , Facius Dirk
Published: October 2023

Pressure to improve sustainability, particularly with regard to CO2 emissions, is mounting for the oil and gas sector. Many companies have been working extensively on developing technologies programs to decarbonize. One of the technologies implemented to reduce carbon emissions is enhanced oil recovery (EOR) using CO2. To ensure that the sequestered CO2 is not leaking, the area needs to be monitored for the release of CO2 within the wells.

The iCLS deployment is based on eddy covariance technology which is a micrometeorological technique for direct measurements of gas transport between the surface and the atmosphere. It is utilized to monitor large areas where CO2 may escape from the subsurface, to detect and quantify CO2 leakage, and to improve CO2 storage efficiency. It includes a number of High Frequency CO2/H2O gas analyzer in combination with 3D high frequency Anemometer, which are used to determine fluxes and monitor any increase of CO2 emissions over time. The tower will also employ a combination of BioMet sensors to interpret the fluxes measured.

Several methods that monitor the CO2 concentrations on the surface have been evaluated, and EC method was considered most appropriate to monitor a large area of interest (AOI) continuously. Local conditions have been checked, and an EC system was designed. The location of the EC system was fixed to match requirements by landscape, wind direction, AOI and budget. In order to ensure continuous access to the remote EC system, communication and software tools were used for data monitoring and surveillance of instruments. Lastly but most importantly, this technology will be supported by renewable energy such as solar and wind power modules. Two 25 m towers were erected at the AOI, employing CO2/H2O analyzers along with anemometers, data management & communication systems and solar power systems each. The two EC systems were fully installed. Furthermore, the systems were checked successfully for data collection and for remote access from the company’s offices for review and analysis. For additional assurance, a simulated CO2 release experiment was conducted to measure the sensitivity of the technology. The experiment showed that iCLS did detect the release, which as a result showed a spike in CO2 concentration.

This paper will share the lessons learnt from the deployment of such innovative technology. This deployment of eddy covariance is one of the few for CCUS surface monitoring. Additionally, the simulated CO2 release experiment is the first in the world for such a deployment and AOI.
Nanospheres Application for Conformance Control in Low-Permeability Carbonate Formation in Oman Block 5
Authors: Andrianov A. , Wang Y. , Busaidi K. , Kindi Z. , Naabi A. M. , Hasani M. , Liu E.
Published: October 2023

Nanospheres is the conformance control technology improving the performance of water flooding in oil reservoir (Andrianov et al 2022). The pilot project has been executed in one of the light oil / tight carbonate oil fields in Block 5 in north of Oman operated by Daleel Petroleum (Daleel) by ZL EOR Chemicals (ZL).

The pilot was divided into main two stages: i) Nanospheres injection, from March 2020 to February 2021, ii) Additional monitoring period, following the injection period, from March 2021 to May 2022. The nanospheres solution has been injected in two injection wells. Special preparation and injection skid was used for injection. In total 86 tons of nanospheres were injected.

The project performance has been monitored through comprehensive surveillance program, including frequent well testing, close monitoring of water injection, pressure, emulsion, and viscosity. Technical results obtained by end of the monitoring period were positive and demonstrated the suitability of nanospheres for conformance control in carbonate fields. Cumulative oil gain achieved was around 40,000 barrels of oil at time of analysis.

The forecast was based on DCA (Decline Curve Analysis). Expected recovery in this period (combined oil rate of the three supported oil producers) without an intervention (NFA case) was 142,145 bbl. Thus, nanospheres injection added ~28% of oil gain. Overall, the project was executed successfully, safely and oil production target has been reached. This is the demonstration of technology potential in carbonate formations.

This paper is organized in the following way: Section 1 briefly introduces the reservoir and the technology; Section 2 describes experimental results, Section 3 shows injection wells selection and project design while Section 4 reviews project performance and evaluates technical results. Incremental oil gain per well was monitored closely via frequent well testing and wellhead sampling where all the three producing wells were under monitoring. Finally, Section 5 gives the project summary, lessons learnt and discusses the future expansion of the technology.
Revisiting Petroleum Engineering Curriculum: Adaptation to Energy Landscape
Authors: Al-Shalabi Emad W. , Srivastava Manish N. , Taleghani Arash D. , Ershaghi Iraj
Published: October 2023

With the flux of changes in major conventional oil and gas companies to become energy companies and the observed decline in student enrollment in petroleum engineering (PTE) programs around the world, there is a need to revisit PTE programs and their content. This manuscript discusses potential directions and steps that can be considered by current PTE programs to adapt to the new energy landscape. This study tries to highlight the pros and cons of expanding PTE programs to include other energy resources, the need to add new courses or adjust current course contents with new topics, repurposing or readjusting existing skills for renewables in meeting future energy requirements, and future of job market. We also discuss the role of artificial intelligence (AI) and machine learning (ML) in preparing students for a more competitive job market such as the challenges faced with applying AI/ML to a PTE program. In brief, the energy transition does not mean leaving oil and gas behind. Petroleum engineering discipline will last for decades to come as soon fossil fuels remain the most economical and reliable energy resource and even beyond that depending on other energy resources of the same nature. However, petroleum technical and non-technical skills may fit into future low-emissions technology through slight upskilling and reskilling. Despite the current shifts in the industry, we anticipate that petroleum engineering as a major remains relevant and important for the energy sector, because of the unique expertise and technologies developed over the years. This paper can be used as a guide for PTE programs for revisiting and rebranding their curricula during and beyond the energy transition area.
Optimizing Well Integrity with Accurate Forecasting of Casing and Tubing Resistance Reduction Trends Through Innovative Numerical Modelling Techniques
Authors: Aliko E. , Casciaro D. , Conte A. , Busollo C. , Baronio E. , Abdo E. A.
Published: October 2023

Well integrity is an essential aspect of well operations, and international standards are stringent on its application. Tubing and casing corrosion constitutes a major risk to well integrity and a challenge that must be analysed preventively. Corrosion logs are programmed to verify the status of the barriers, but there is currently no methodology for planning future logs. This paper proposes a numerical modelling method to forecast tubular resistance reduction trends and estimate the barrier's residual life.

Corrosion logs are expensive and require the well to be shut-in, which impacts the cost of the operation. Therefore, a numerical methodology for planning future logging is preferable to planning based on experience. A methodology was developed using data from historical corrosion logs and a time-linear corrosion model to predict the point at which the downhole barriers will no longer satisfy the Maximum Allowable Annular Surface Pressure (MAASP) criteria anymore. The methodology calculates collapse and burst resistance of corroded pipes, using operator's criteria for minimum allowable MAASP, while considering well completion design and vertic al depths resulting from the directional survey.

The result of the methodology is a chart that forecasts the progressive reduction of the MAASP and the time at which it will cross the minimum criteria of the operator. The corrosion logging schedule can, hence, be programmed before this time limit thus optimizing planning and costs for the operator. Models based on empirical data and statistical analysis often fail to consider the specific corrosion trends of each well. The proposed methodology provided a comprehensive assessment of the corrosion progress, making it a more reliable tool for forecasting future corrosion trends. The methodology uses the last two corrosion logs for optimal prediction, but it also works when a single corrosion log is available. Numerical modelling is than used to calculate pipe resistance at each depth step of the LAS file, drawing a picture of the resistance vs. depth and time. Furthermore, the methodology provides a certain variation window that takes into consideration the best- and worst-case scenarios. This adds a layer of safety on top of the procedure when the worst-case scenario is used to schedule logs.

This methodology presents a first application of numerical modelling to forecast tubular resistance reduction trends in well barriers, due to corrosion/erosion. This allows standard procedures to be improved by scheduling corrosion logs based on solid forecasts instead of using experience and observations, thus ensuring optimization of the corrosion logging program. This, in turn, leads to a reduction in costs without affecting the overall operability and risking barrier failures.
Novel Sustainable Nanofluids from Waste Plastics for Oil Recovery Displacement and Decarbonization
Authors: Wang Wei , Chang Sehoon , Gizzatov Ayrat , Thomas Gawain
Published: October 2023

This research presents a novel and sustainable method to produce Janus carbon nanofluids from waste plastics. These nanofluids show promise as highly effective agents for Enhanced Oil Recovery (EOR) under reservoir conditions. A cost-effective method, combining pyrolysis, chemical functionalization, and pulverization, was developed to synthesize Janus carbon nanoparticles (JC-NPs) from waste plastics on an industrial scale. The properties of these nanostructures were confirmed using techniques like scanning electron microscopy (SEM), Langmuir-Blodgett (LB) isotherm analysis, interfacial tension (IFT) measurements, and microfluidic flooding measurements. LB isotherm measurement revealed that JC-NPs exhibit both nanoparticulate and surfactant-like behavior. These particles can be directed and assembled at rock/fluid or water/oil interfaces when formulated as nanofluids in a brine suspension. The JC-NPs notably alter the wettability of the rock surface, and IFT measurements indicate their ability to decrease the interfacial tension between brine and crude oil under simulated reservoir conditions. In EOR performance tests with microfluidic chips, we observed that the Janus nanofluids at ultra-low concentrations (0.001 wt %) can enhance oil displacement in simulated carbonate reservoirs. This innovative method of repurposing waste plastics into useful nanomaterials has the potential to reduce the carbon footprint and contribute to a more resource-efficient chemical industry.
A Novel Method: Injection Dynamic - Transient Acoustic Pressure Thermal Logging to Increase the Effectiveness of Water Shutoff and Remediation Operation in Depleted Production Wells
Authors: Nayung Galih P. , Rudhy S. , Asep S. , Nur Cahya M. , Humam H. A.
Published: October 2023

The evaluation of flow profile in the wellbore system is an important part of oil & gas field development. Leaks that occur in or behind production casing not only potentially cause safety and environment issues, but also potentially lead to misjudgments of production analysis and the estimation of remaining reserve. The flow profile in the wellbore is mostly affected by the life cycle of well itself during drilling phase, completion phase, production or injection phase and restoration phase. One of many well-known technologies applied in oil & gas industries is the acoustic and pressure thermal log. The selection of surveillance methods to identify leaks and undesired water problems not only provides more effective results but also carries an acceptable risk in the term of project cost. The objective of this paper is to show how a novel approach of acoustic and pressure thermal surveillance can be used to increase the effectiveness of water shutoff job in depleted oil & gas wells.

An innovative approach of dynamic surveillance procedures called injection dynamic – transient method along artificial lift or depleted production wells must be conducted during acoustic, pressure and thermal data acquisition. Certain parameters must be adjusted properly during data acquisition, depending on completion and reservoir characteristics well by well such as area of interest, completion string, completion fluid, perforation type, injectivity test and reservoir properties. Several studies in depleted production wells show that the undesired flow in or behind production casing can be interpreted and identified precisely compared with conventional methods such as cement bond log.

As a result, the acoustic, pressure and thermal data interpretation contribute to both successful water shutoff operation and post-job production performance. Water problems can significantly be reduced from 1300 barrels water per day to 320 barrels water per day and on the other hand oil & gas significantly increased from 34 barrels oil equivalent per day to 532 barrels oil equivalent per day. Moreover, this paper should be beneficial to help all petroleum engineers currently working in mature oil & gas field not only to identify undesired flow problem precisely but also develop more comprehensive and effective remediation plans.
Technology Demonstration of Multi-Species (CO2, SO2, NO2, & PM) Capture
Authors: Wagstaff Christopher , AlGahtani Mohammad , Michaux Sylvain , Sreedharan Sai Shrinivas , Prabhudharwadkar Deoras , Roberts William
Published: October 2023

Post-combustion capture of carbon dioxide usually requires other upstream pollutant capture systems such as selective catalytic reduction for NOx, flue gas desulfurization, electrostatic precipitators, etc (Dziejarski et al. (2023)). Traditional carbon capture technologies cannot be deployed at point emission sources that do not have these systems and use fuels containing sulfur (e.g., heavy fuel oil, sour gas, etc.). A novel pollutant capture system is being developed at KAUST that eliminates this limitation.

A Cryogenic Carbon and Sulfur Capture (CCSC) technology is developed in partnership with Sustainable Energy Solutions (SES, part of Chart Industries). This technology focuses on post-combustion CO2 capture along with SO2, NO2, and other Particulate Matter (PM) pollutants. CCSC is modular in design and mounted on a 15-meter-long trailer. The multi-species co-capture system is mounted in the central section of the trailer and includes a separate control room and gas storage room on either end of the trailer. This trailer-mounted CCSC system has a nominal capacity of capturing 0.25 ton of CO2/day.

This CCSC process cools exhaust flue gases below the desublimating temperatures of CO2 (~−130°C) where CO2 solidifies out of the flue gas. This separation process is done by spraying isopentane as a contact liquid into an upward-moving flue gas. CO2 freezes into the contact liquid and ultimately flows out as a slurry. The contact liquid is regenerated via screwpress, and then the interstitial liquid is recovered via distillation. An additional column is necessary for the separation of a third species SO2.

The main objective of this trailer rig is to serve as a technology and IP development platform to cocapture multiple pollutants all using a single technology. The trailer rig is designed to be flue gas agnostic and finds applications in many facilities. Even though the system is currently optimized for the most probable site which is a heavy fuel oil (HFO) fired steam power plant, it can easily be adapted to shipboard carbon capture and co-capture of other pollutants more prominent from marine applications. A wetted-wire patented technology from KAUST (Wagstaff et al. (2022)) already shows promise for shipboard heat and mass transfer.
Don't Stop Drilling Operations but Use Customized Cross-Linked LCM Solution for Fractured Formations
Authors: Al-Zahrani Walid , Olivares Tulio , Bahamdan Abdulaziz , Burts Donnie
Published: October 2023

Curing drilling fluids losses in fractured and sandstone formations is the most challenging scenario to drilling team. Loss zones are unpredictable, due to large vugular zones, extended and connected fracture structures or in interbedded sandstone formations. However, based on proper evaluation of the offset wells data, loss events can be anticipated. Typically, conventional lost circulation material (LCM) pills containing various particle size distributions are part of the lost circulation armory in fractured sections. However, results show variation. This cross-linked LCM is distinguished for those situations with the most-severe lost circulation, as these cross-linking polymers will produce a rubber gel structure. This chemical blend has extremely effective sealing characteristics that are used as an innovative approach to the initial response to lost circulation. Depending on the bottom hole temperature, a retarder will be used to customize the mentioned LCM solution. This paper discusses a Customized Cross-Linked LCM Solution for Fractured and Sandstone Formations, based on a customized blend of high and low molecular weight anionic polymer, reinforcing material and cross-linking agent that has an extremely effective sealing characteristic. In addition, it can be pumped through the regular bottom hole assembly without losing rig time associated with tripping and mixing conventional LCM treatment.
A Next-Generation, Fully Controllable Alloy Wellbore Sealing Technology
Authors: Lucas Alex , McWilliam Gary , Eden Robert , Rege Gert , Osnes Kay Even , Worthington Sam , Gudmestad Kristian
Published: October 2023

Sealing wellbores via the use of alloy sealing technology presents a number of challenges. The typical approach involves the use of exothermic chemical reactions delivering high temperatures to ensure sufficient heat is generated to ensure the alloys remain molten for long enough to reach their intended radial extent.

One challenge of such an approach are the high temperatures generated and their potential effect on the external well barrier elements (casing, cement, formation). Furthermore, chemical methods are a ‘one shot’ approach that do not permit close control or repeat of the heating the process after initiation.

A next-generation alloy placement system has been developed using an electrical heater, cable and deployment system with sufficient capacity to deploy a fully controllable and verifiable heating solution, capable of operating at lower temperatures for extended durations. This allows close control of heating cycle to prevent damage and optimise the process, resulting in a superior barrier envelope. Furthermore, rigorous design and testing ensures the minimum amount of expensive alloy is used to achieve the desired seal.

This paper details the extensive design and testing programme that was undertaken to devise an optimal alloy plug and mature a complete barrier system that challenges both conventional approaches involving cement, and first-generation alloy plugging technologies. The project culminated in a full-scale pilot in a test well that replicated the challenging wellbore environment of the intended application as closely as possible. The testing demonstrated that the technology is capable of setting a competent alloy barrier to deliver at least a 3,000 psi / 207 bar differential pressure ‘big bore’ seal, even when set in drilling fluid and flowing gas.
Achieving the Impossible – Chasing Oil Column in Extremely Heterogeneous and Highly Flooded Area by Utilizing Extra Deep Azimuthal Resistivity
Authors: Seddik Ibrahim Abdelgaffar , Noordin Firdaus Bin Mohamed , Aziz Khalid Mohamed Abdul , Trisnadi Dicky , Zuraiqi Mohamed Ali , Potshangbam Sanathoi , Saravanakumar Krishnan , Yehia Mohammed , Bouny Ali
Published: October 2023

Well placement in flank and highly flooded areas is almost impossible with conventional logging while drilling (LWD) technology. Extremely heterogeneous reservoir properties coupled with an uneven flood front presented high project risk, with the potential to compromise the landing and not optimally place the well, which could impact the well objective. Extra deep azimuthal resistivity (EDAR) look ahead capability with a greater depth of detection is the only feasible technology to mitigate these challenges due to high uncertainty of waterfront.

The initial wellbore has been on production since 2010 and reached more than 90% water cut by 2021. To extend its life, the well must be sidetracked as a new drain hole. Since the well was located in a complex geological structure, which was highly flooded with a complicated flood front pattern, the reservoir target was very challenging. Conventional logging technology, which has minimal depth of investigation, does not have sufficient capability to provide data sufficiently far from wellbore to take proactive decisions on landing and placing the well within the oil zone. Look ahead capability of EDAR technology, which can detect much deeper resistivity contrast ahead of the bit, was selected to identify the optimum landing point. This EDAR technology was also adopted in the horizontal section to geosteeer within the main oil column and assisted in optimizing lower completion design.

EDAR inversion has shown tremendous value in mapping the resistivity changes while approaching to land the well in the target zone. It mapped a flooded zone 80 ft ahead of bit. This information helped in optimizing the trajectory to delay the landing while searching for an oil column in the target reservoir. EDAR inversion mapped the oil column 20 ft ahead of bit from the flooded zone and the trajectory was accordingly adjusted to land successfully in the oil pool bounded by water zones above and below.

Real-time inversion along the horizontal section was utilized successfully in navigating and mapping the gradual change in oil column towards toe of the well, mapping a thin column (~20ft) at heel to more than 100 ft thick towards well toe.
One Step Closer to Replacing Portland Cement with Geopolymers for Oil Well Applications
Authors: Kamali M. , Khalifeh M. , Kverneland J. , Benmesbah M. , Delabroy L. , Middleton R.
Published: October 2023

Inorganic geopolymers are typically composed of aluminosilicate-rich powders and alkali silicate solutions as hardeners. Once mixed, these geopolymers exhibit cement-like behavior. However, highly alkaline solutions raise HSE (Health, Safety, and Environment) concerns in field operations. This paper provides a comprehensive characterization of a "one-part" granite-based geopolymer for oilfield applications that eliminates the need for alkaline solutions. Exactly like to cement, only fresh water is required to mix the geopolymer. As the reference material, API neat Class G cement was used for comparison. The fluid properties in the liquid state, including viscosity, gel strength, static fluid-loss, and mechanical properties after solidification such as sonic strength development, uniaxial compressive strength, and tensile strength, were tested following API standards. The initial analysis indicated that the rock-based geopolymer may not require any dispersant if the ingredients are engineered properly. However, a limitation of the geopolymer is its short thickening time at elevated temperatures. The use of two candidate organic and inorganic retarders extended the pumping time, followed by solidification and strength development. The short-term mechanical properties of the one-part geopolymer were evaluated by curing samples under downhole condition up to 60 days, where the bottom-hole circulation temperature and the static temperatures were 50°C and 70°C, respectively. The mix design exhibits a rapid transition from gelation to hardening. The compressive strength of the solidified samples was 50% less than that of the neat Class G cement, but the material demonstrated 4 times more flexibility.
Improving Wastewater Treatment Through Application of Industry 4.0
Authors: Fonia Devendra Singh
Published: October 2023

Wastewater Treatment faces the challenges of constantly changing parameters of the influence. These fluctuations can be in terms of COD, TOC, Ammonia, Sulphides, Phenols, cyanides, oil& grease etc.

This paper focuses on two (2) refinery Waste-Water Treatment Plants (WWTP's) where providing stable and consistent treatment was difficult due to constantly fluctuating: COD with fluctuations from a low of 100 mg/ltr, to a high of 2000 mg/ltr.TOC with fluctuations from a low of 50 mg/ltr, to a high of 450 mg/ltr.Ammonia with fluctuations from a low of 5 mg/ltr, to a high of 70 mg/ltr.Sulphides with fluctuations from a low of 3 mg/ltr, to a high of 170 mg/ltr.
Use of Double Machine Learning for Microseismic Data Analysis: What Factors Influence Microseismic Events?
Authors: Conde Oliver Rojas , Misra Siddharth , Liu Rui
Published: October 2023

This study proposes a new workflow for analyzing microseismic data using causal inference techniques. This approach allows us to identify the causal relationships between a new microseismic event and its spatiotemporally proximal, prior microseismic events, while taking into account confounding variables that influence both the cause-and-effect variables. We applied this workflow to microseismic data acquired from hydraulic fracturing operations on 2 horizontal wells in the Marcellus Shale. Our results revealed several new insights into the microseismic source mechanisms, including: 1) The magnitude of a new microseismic event does not depend on the number or spatial and temporal concentrations of the spatiotemporally proximal, prior events; 2) When the maximum magnitude of prior event in a region increases, a new event occurs much earlier in that region; 3) A region with a large number of microseismic events will produce a new microseismic event much earlier in time than a region with fewer events. These causal relationships suggest that accurately selecting confounders is crucial for obtaining accurate causal estimates. Failure to properly select confounders can result in significant overestimation or underestimation of the causal estimates, as high as +/- 100%. Our results also confirm that causation and correlation are two distinct concepts. A causal analysis with true confounders reveals the true causal relationship that cannot be quantified using correlation/association methods. This is demonstrated using Double Machine Learning (DML) to compute the average treatment effect for both a true confounder variable and a random confounder variable.
Applications & Challenges of the Non-Metallic Material for Hydrocarbon Piping
Authors: Saeed W. S. , Al Mehairi A. S. , Alnaqbi A. M. , Al Blooshi S. O.
Published: October 2023

This paper will explore the various applications and challenges of non-metallic piping for hydrocarbon service and how it helps reduce corrosion costs. According to the NACE study, the total annual cost of corrosion in the oil and gas industry is estimated to be $1.372 billion. It is remarkable how much money can be saved by implementing non-metallic piping solutions. Not only does it reduce corrosion costs, but it also helps improve safety and efficiency in the oil and gas industry. By reducing the need for frequent maintenance, non-metallic piping provides a cost-effective and reliable solution for hydrocarbon service.

This paper highlights two successful case studies for High-Density Poly Ethylene (HDPE) in the oil and gas industry and further elaborates on the challenges. Additionally, the lesson learned from another case for the fire water network is highlighted along with a rout case analysis of the failures.
Flawless Startup – A Holistic Approach to Fasttrack Starting Up a Multimillion Project
Authors: Ioan Tiberiu , Malagon Cecilia , Ruzhnikov Alexey , Elmokashfi Haytham
Published: October 2023

Project management defines five phases, where the project initiation (or start-up) is the most critical. That is specifically applicable to the drilling industry in the case of multi-well, multi-rig projects. This paper covers the implementation of the start-up sub-process within the integration operating model during the planning phase, the optimization of resources, and the stakeholder strategy that allowed to spud the wells in a compressed schedule and exceeded the expectations.

Once the project manager was appointed, the handover process between sales and the project execution teams started. This activity marked the Project Initiation phase within the Project Management process. The Project Manager followed the Start-up sub-process to ensure all the tasks required to start a complex project were followed to spud on time and avoid HSE incidents and liquidated damages.

The Start-up sub-process follows the Project Management Institute (PMI) framework and includes all the project management areas but is applied to the specificities of the customer, commercial model, and project complexity.