bluuebunny/crossref_metadata_2025_split huggingface dataset:
Expandable Resin for Countering Severe Loss Circulation
Authors: Wagle Vikrant , Ramasamy Jothibasu , Alanqari Khawlah , AlYami Abdullah 
Published: March 2023

Abstract
One of the main reasons why loss circulation is difficult to remedy is the lack of knowledge about accurate fracture width and depth encountered while drilling, leading to an improper selection of suitable plugging materials that can adapt, in both volume and shape, to effectively plug a wide range of fractures with unknown dimensions. Traditional, non-reactive particulate/fiber based or settable fluid, types of loss circulation materials (LCM), when applied in insufficient quantities, cannot effectively seal a high permeability zone. The LCM described in this paper is however expandable in nature. This expandable nature of the resin can help the LCM adapt in volume to effectively seal a wide range of fractures with unknown dimensions. Volume adaptability is introduced in the LCM through in-situ generation of gas due to the decomposition of a gas generating compound.
The novel expandable LCM comprises of a resinous material, a gas producing agent, surfactant and an activator. The resinous material in presence of a gas producing agent, surfactant and an activator is designed to expand under downhole conditions and help to cure severe losses. Different LCM compositions comprising varying concentrations of resin material, a gas producing agent, surfactant and an activator have been described in the paper. Two different resins were used in the study. The resins were mixed in different ratios and the impact on gelling time was investigated. An aliphatic chemical activator was used in the study. The effect of this activator on the gelation properties of the resin was investigated. The effect of temperature on the expansion of the resin in the presence of gas producing agent was also investigated.
The expandable LCM starts to generate gas in-situ under wellbore conditions. Laboratory testing has been performed to quantify the % of expansion of the resin at different temperatures. It was observed that the rate of gas generation is faster at higher temperatures. The expandable LCM is designed so as to have a controllable gelation time under a variety of downhole conditions to allow accurate placement of the LCM inside the wellbore without premature setting of the fluid. It was shown that the gelation time of the treatment composition could be controlled by adjusting the concentration of the activator. The system is designed so as to give a predictable and controllable pumping time, ranging from a few minutes to several hours at over a wide range of temperatures.
A Workflow to Assess the Effect of Lateral Landing, Completion, and Fracturing on Production Potential in an Explorational Clastic Environment
Authors: Herrera Carlos , Khan Abdul Muqtadir , Almulhim Abdulrahman , Hamid Saad 
Published: March 2023

Abstract
Three horizontal wells were drilled and completed with hydraulic fracturing in an explorational environment based on reservoir characterization from openhole logs. Limited success in establishing gas production rates showed the need for an integrated technical workflow to be applied for the next well, well-A. After good production results were achieved in well-A, the next phase used three more wells to correlate the production performance based on precise well placement.
In well-A, openhole sampling was done during drilling of the pilot hole prior to sidetracking the lateral. This was followed by a novel fracturing approach with slickwater hybrid, low-polymer, and CO2 foamed treatments to study the effectiveness of treatments. Post-fracturing diagnostics including a production log and spectral noise log (SNL) were performed to assess production by stage. Three more wells were drilled in the same reservoir, and then a synthetic correlation model was built with resistivity logs to correlate precise lateral landing with the prolific sublayer. Finally, the production performance of all wells was studied based on well placement, fracturing, and the completion approach.
The first phase of the study of the three wells allowed characterizing well-A in terms of reservoir interval, wellbore orientation, and fracturing strategy. Layer 1 was used to sidetrack the lateral. The post-fracturing production log and SNL indicated the CO2 foamed treatment was the best approach for well-A. The next three wells in the development phase were drilled in layer 1 with good production but inconsistent results. Because the highest flow rate in well-A was seen from the heel part of the lateral, an ultradeep resistivity-correlation bed boundary model was generated from well-A to characterize structural dip, and precise lateral locations were analyzed for all the wells. The model was also used to describe the most prolific sublayer within the layer 1 reservoir. The results showed a strong production dependence on the lateral landing with respect to the defined prolific sublayer. The number of fractures placed also showed a direct relation with gas rates. Finally, a geosteering simulation model was built to be used to further develop the area and detailed recommendations were documented. The ultradeep azimuthal resistivity tool has the capacity to detect ultradeep resistivity up to 100 ft from the borehole. Simultaneously, it can map ultrathin layers, which is necessary for the laminated reservoirs.
The objectives of precise well placement and rendering productive gas wells in the exploration area through a comprehensive workflow was optimized and analyzed over 4 years. This paper presents systematic findings and a robust framework ready for implementation in future developments.
Utilization of Innovative Resin-Cement Blend to Enhance Wellbore Integrity
Authors: Ali Wajid , Al-Turki Faisal Abdullah , Abbas Athman , Al-Yami Abdullah Saleh , Wagle Vikrant , Al-Safran Ali 
Published: March 2023

Abstract
A major challenge that is being occasionally faced during the well's lifecycle is the pressure buildup between the cemented casing annuli, also known as sustained casing pressure (SCP). Compromise of cement sheath integrity is one of the primary reasons for such a pressure buildup. This challenge prompted to develop such an isolation material that should enhance the mechanical properties of cement. The resin-cement blend system can be regarded as a novel technology to assure long term zonal isolation.
This paper presents the lab testing and application of the resin-cement system, where potential high-pressure influx was expected across a water-bearing formation. The resin-cement system was designed to be placed as a tail slurry to provide enhanced mechanical properties in comparison to a conventional slurry. The combined mixture of resin and cement slurry provided all the necessary properties of the desired product. The slurry was batch-mixed to ensure the homogeneity of resin-cement slurry mixture. The cement treatment was performed as designed and met all zonal isolation objectives.
Engineered solutions ultimately deliver the optimal asset value of the reservoir. During the last few decades, several laboratory investigations and field studies have been conducted to find solutions to the problem of SCP, which appears after primary or remedial cement jobs. Almost all these studies unanimously conclude that the conventional cement does not always endure the mechanical stresses imposed by the wellbore conditions and it often falls short in providing long term isolation beyond the production life of the well. When the resin is introduced into a cement slurry, it forms a dense, highly cross-linked matrix. The extent of the cross-linking reaction is governed primarily by volume, temperature, and time. The distribution of resin throughout the slurry provides a shock-absorbing tendency to the particulates of the cement. This feature increases the ductility and the resilience to withstand stress from load-inducing events throughout the life of the well. Resin-cement's increased compressive strength, ductility, and enhanced shear bond strength help to provide a dependable barrier that would help prevent future sustained casing pressure (SCP).
Improved Reservoir Management with Multi Positioning Interval Control Valves in Multilateral Wells
Authors: Shahreyar Noman , Butler Ben , Shakeel Muzzammil 
Published: March 2023

Abstract
Multilateral technology continues to gain interest within the oil and gas industry. While multilateral wells are recognized as an advanced well construction and completion technique to optimize production performance and improve field recovery, further opportunities exist to increase production performance throughout the life of these wells through the use of variable inflow control for the main bore and/or the laterals. The inflow control on these wells is achieved by interval control valves (ICV). An ICV is generally classified as either on-off (i.e., full-open or closed) or multi-position (i.e. discrete choking type). This paper discusses a reservoir simulation case study with varying degrees of inflow control to demonstrate value added by ICVs to multilateral completions to improve oil recovery of a field.
A 3D black-oil reservoir model was utilized to simulate production and cumulative recovery evaluation with horizontal and multilateral intelligent completion oil producers supported by vertical non-intelligent water injectors. The modeling was carried out with varying degrees of control in the ICVs employed in the oil producers. Multiple scenarios were modeled as follows: 2-position ICV (open-closed)4-position ICV (choking)9-position ICV (choking)
This modeling will quantify the value provided by a customized multi-position ICV in a multilateral intelligent completion with regards to improved reservoir performance. Since the customized ICV solution requires a more detailed well completion design and evaluation, it is necessary to be able to quantify the value that this option can deliver when employed in multilaterals. This paper shall demonstrate the added value that can be achieved in multilateral wells by utilizing multi-position choking ICVs versus binary open-close ICVs to manage reservoir uncertainty and improve reservoir performance. This paper will also highlight the importance of flow discharge characteristics with respect to each choking position and the benefits of flow trim customization during well life.
Unlocking Fracture Characterization Ambiguity a Multi Disciplinary Integrated Approach
Authors: Abughneej Ali , Al Naqeeb Mohamed , Al-Ostath Moahmmed , Albanay Fatemah , Abd El Dayem Muhammad , Al-Hamad Nasser , Al-Jamaan Abdullah , Akbar Laila 
Published: March 2023

Abstract
Fracture systems play a significant role in production in the case of tight/low porosity complex reservoirs. Exploration well in North Kuwait that targets Middle Marrat formation is met with the challenge of lack of understanding of reservoir compartments in an under-explored field, with minimum offset wells to properly evaluate its potential. A multi-domain approach is proposed with various expertise to tackle the petrophysical and geomechanical aspects of the fracture system governing the carbonate layer, to assess its producibility and its qualification for stimulation through hydraulic fracturing.
To address the exploration challenge, a novel comprehensive approach for fracture evaluation was implemented for the first time, starting at the wellbore stage, followed by an extensive analysis far away from the wellbore to evaluate their extent and their possible contribution to the flow, later combined with a geomechanical evaluation of their stress state, to come up with a confident estimation of their producibility and subsequently, a proper completion optimization plan for maximum reservoir exploitation.
The robust approach started with deployment of the image logs photorealistic oil-based mud imager with the purpose of capturing the highest resolution prospect of fractures on the borehole wall. The image logs tool provides direct quantification of fracture properties with regard to their density and orientation, and visual qualification of their type, connectedness, and aperture.
The 3D Far-Field Sonic technology was then implemented to unveil the ambiguity typically associated with fracture analysis, and provide new insight into the fracture continuity, reaching up to 160ft away from the borehole circumference which is a unique answer product presented for the first time in oil field market. The 3D Far-Field Sonic delivered astonishing results by identifying highly fractured zones and fracture extensions including the true dip and azimuth for each fracture. Geomechanical evaluation was carried out to understand the stress regime, and the relationship between critically stressed fractures with production patterns, and ultimately provide a location and direction to guide enhanced production in future wells.
Integrating data from various advanced tools helped identify zones of producing fractures and provided a practical solution for stimulation optimization. The multi-domain expertise addressed the challenge of natural fractures consistency between different measurements and allowed for proper evaluation of critically stressed fractures to understand production mechanisms and depletion behavior, through understanding present-day stress state, fracture geometry, and fracture slip properties. The consistency of the study provided convenient results ensuring proper well planning and future completion strategies.
Improved AMD Nanosheet System to Increase Oil Production Under Harsh Reservoir Conditions
Authors: Cao Dongqing , Han Ming , Fahmi Mohanad M. , AlSofi Abdulkareem M. 
Published: March 2023

Abstract
Amphiphilic molybdenum disulfide (AMD) nanosheet is a novel flake type Nano material, which is different from the widely used particulate Nano material, for increasing oil production. Most of the current researches and applications of nanosheets were for low temperature and low permeability sandstone reservoirs. This work investigated an improved nanosheet system for permeable carbonates at harsh reservoir conditions.
AMD nanosheet sample was a concentrated black liquid with flake size about 80*60*1.2 nm. The features in a high salinity water (HSW) and high temperature were characterized by compatibility test, interfacial tension (IFT) test, emulsification test, and phase behavior test. The potential for increasing oil production was evaluated by micromodel displacement tests. The micromodel was treated to oil-wet to simulate the wettability of carbonates. The performances of initial sample and improved sample by a cationic surfactant were compared.
Initial AMD nanosheet sample was not compatible with HSW at 95 °C. A cationic surfactant significantly improve the compatibility. IFT of 50 mg/L nanosheet with a light oil was 0.46 mN/m at 25 °C. IFT of The improved system with the surfactant decreased to 0.21 mN/m at 90 °C. The increase of nanosheet and surfactant concentration resulted in an IFT increase. Although IFT was not ultra-low, nanosheet had strong interfacial activity on oil-water interface even at low concentration. Nanosheet-only produced much stable emulsion than surfactant-only. Mixing nanosheet and surfactant increased emulsion stability slightly. Phase behavior results demonstrated that surfactant improved the hydrophilic and lipophilic balance of nanosheet to produce Winsor III type microemulsion. In core flow testing, the nanosheet alone injection partially plugged the core plug with relatively high adsorption/retention. Adding the surfactant improved the migration and reduced adsorption of nanosheet in porous media. Micromodel displacement test showed that improved nanosheet system at low concentration of 50 mg/L increased oil production by more than 20% after water flooding at both ambient temperature and reservoir temperature at 95 °C.
This study investigated a more efficient material with same dimension as oil-water interface compared with surfactant or particulate Nano materials. An improved nanosheet system was developed for carbonate reservoirs under harsh conditions.
Intelligent Gas Production Avails Planning System
Authors: Al Saad Mohammed Sadiq , Al Qahtani Adel Ali 
Published: March 2023

Abstract
The health of wells, facilities, and reservoirs is a core responsibility of gas reservoir management. In addressing the challenges of gas demand dynamism, water and solids production mitigation, facilities and reservoirs integrity, an intelligent production avails target system is developed. The system is designed to generate systematic and sustainable well-by-well production avails for various production cycles/scenarios in seconds.
The system digests wells data fed into the system through an up-to-date wells database and in-field sensors linked to a supervisory control and data acquisition (SCADA) system. Feed data includes testing parameters, i.e., gas rate, condensate-gas ratio, water-gas ratio, and wellhead pressure, geochemical water analyses, solids production, reservoir pressure, and pressure-volume-temperature (PVT). Upon QC, a daily well potential is determined based on testing data, Productivity Index (PI), and cumulative production. Well potential is then automatically verified against in-field gas flow sensors data. Maximum allowable avails per well are then determined based on the aforementioned parameters and surface facilities design to meet dynamic gas demand while sustaining wells performance and facilities integrity.
The resulting system found an excellent parallel between determined well potential and producible gas rate from in-field sensors. In emulating an experienced decision-making process, linear regression modeling proved diverse variable integration for parameters. Variable importance figures based on residuals fit (in brackets) are as follows; test gas gate (7.5), test WHP (2.4), PI (0.6), WGR and geochemical water sampling parameters (5.6), and reservoir pressure (2.9). Solids production was incorporated as a cap for wells producing from unconsolidated formations. Condensate production and PVT allowed for dynamic facilities-oriented production scenarios to be developed on demand. This diverse variable importance illustrates the holistic approach of this system in integrating avails dynamics on a well-by-well basis and reservoir levels. Incorporation of surface facilities is a key feature considering non-associated gas, condensate, and hydrocarbons PVT from processing capacity and design parameters standpoints.
This intelligent system capitalizes on big data analytics of surveillance activities and in-field sensors to automate vital reservoir management business. It assumes a novel approach in production allocation across non-associated gas fields in a systematic and intelligent manner with production sustainability as the main objective. Further novelty is the linkage between subsurface and surface aspects of the field in the process to maintain both reservoir health and facilities integrity.
A Novel Approach for Improving Uptime of Water Supply Wells in Oil Fields by Applying Lean Six Sigma
Authors: Al Shukaili Aisha , Ram Nayakam , Al Ghadani Adnan , Al Malki Younis , Susatyo Yoseph 
Published: March 2023

Abstract
Objectives/Scope: In the oil and gas industry, there are different ways to support and maintain oil production by preserving the pressure in the oil reservoirs. Water injection is acknowledged as one of the most effective methods to keep the reservoir’s pressure and hence maximize the oil recovery. In X field, located in the South of Oman, oil recovery utilizing water injection started in 2005. Three water supply wells provide the water for injection. Since 2018 the uptime of these wells has been around +- 69% which is far from the target uptime of 95%. This affects the water injectivity to the reservoir and hence oil production. On average, around 370 bbl/d of oil production is deferred, with potential revenue of 6 million US$ lost annually.
Methods, Procedures, Process: To overcome the problem of low uptime of water supply, Lean Six Sigma was applied, using the DMAIC (Define, Measure, Analyze, Improve and Control) method. The DMAIC approach has successfully proven process improvements in different industries but has yet to be used in the oil and gas industry. The DMAIC method was applied to identify the main contributors to wells failures, and hence remove process defects and reduce the downtime of the water supply wells. Six Sigma is generally known as a data-driven methodology for improving quality and reducing variation in business activities using multiple statistical tools.
Results, Observations, Conclusions: The study was performed on various possible factors that can cause downtime to the water supply wells. Statistical analysis confirmed three leading causes: well surface leaks, overhead line failures and backpressure. Three dedicated teams were formed to develop and implement improvement plans. This improved uptime of the water supply wells from 69% to more than 98%, which translates to an increase of 1100m3/day (6900 bbl./day) of water injection. As a result, production increased by 1150 bbl./day of oil. The overall benefit for the 14 days pilot and sustain interval of this project was 640,000 USD (assuming 40 USD per barrel). The changes being sustained give an expected annual gain of 4.7 million USD per well. This approach will be replicated in another three fields with the same issue.
Novel/Additive Information: Applying the Lean Six Sigma methodology has effectively improved the uptime of water supply wells and hence water injectivity and oil production. This study proved that Lean Six Sigma could be used to help unlock many oil production opportunities.
Performance Evaluation of Iron Oxide and Graphite Nanoparticles in Water-Based Drilling Muds at HPHT Conditions
Authors: Murtaza Mobeen , Rana Azeem , Ahmad Hafiz Mudaser , Mahmoud Mohamed , Patil Shirish , Kamal Muhammad Shahzad , Al Sheri Dhafer 
Published: March 2023

Abstract
The compositions of drilling muds are tailored to fulfil the harsh requirements of a deep wellbore environment. The fluid loss into the formations causes borehole instability and hinders the drilling operation's performance. The decrease in rheological characteristics influences carrying capacity. Nanoparticles have the ability to block the nanopores present in clay and limit fluid loss in formations and maintain drilling mud stability. This study investigates the capacity of iron oxide and graphite nanoparticles to affect the fluid loss characteristics and rheological features of a water-based drilling mud under HPHT conditions.
To study rheological parameters, the Discovery Hybrid rheometer was used to determine the rheological properties of drilling muds containing nanoparticles in the concentration of 0.5 lb/bbl in a base drilling mud composed of 10 lb/bbl bentonite and 0.5 lb/bbl XC polymer. The experimental data were fitted to the Bingham Plastic model to study rheological parameters. API filtration test was performed to study the fluid loss volume of each drilling mud formulation. The linear swelling inhibition test showed that iron oxide and graphite particles reduced the swelling of bentonite.
A significant improvement in rheological properties was observed for nanoparticles specifically with the addition of iron oxide (Fe2O3). The yield point and viscosity were increased significantly with iron oxide compared to graphite. The addition of nanoparticles maintained the stability of drilling muds at HPHT conditions and resulted in a stable rheological profile. A significant reduction in the fluid loss was also observed with iron oxide resulting in the lowest fluid loss compared to base and graphite mixed drilling muds.
The use of nanoparticles along with high molecular weight polymer improved the fluid loss characteristics, rheological properties, and dispersion. This study reveals the potential use of nanoparticles as a water-based drilling mud additive with effective drilling operations and less formation damage in harsh conditions.