bluuebunny/crossref_metadata_2025 huggingface dataset:
Addressing Reservoir Management, Operational Challenges and Strategic Planning Utilizing the Dynamic Model of the Worlds’ Largest Clastic Reservoir - The Wara-Burgan
Authors: Al-Samhan Amina , Al-Shamali Adnan , Al-Nemran Shahad , Al-Fadhli Wuroud , Yaser Muhammad , Jilani Syed Zeeshan , Maldonado Jorge E , Yunusov Manuchehr , Ibrahim Muhammad
Published: February 2024

To sustain oil production, the Wara-Burgan reservoirs have undergone massive drilling and water-injection over the past decade, leading to 1000s of new wells. These introduced several reservoir management and operational challenges, including localized pressure depletion, formation of secondary gas-cap, non-uniform water encroachment, by-passed oil formation, and fluid property changes. This paper focuses on identifying, analyzing, and evaluating the impact of these factors on reservoir management decisions using calibrated dynamic model across the Greater Burgan field.

To analyze and assess the reservoir management challenges with eight stacked reservoirs having 2400+ wells coupled under 14 gathering-centers, an integrated and up-to-date dynamic model was deemed indispensable, to provide a holistic picture of the reservoir performance. The dynamic model history matching was performed successfully by including all the available drilling, workover, production, injection, pressure, and surveillance data for newly drilled and existing wells. The update of history match exercise was conducted on the existing dynamic model for Wara and Burgan reservoirs to achieve field, gathering center and reservoir level matches.

The history matched dynamic model was subsequently used in simulating field development strategies, asset-action plans, and conducting high-resolution sector modeling of the Greater Burgan reservoirs. A comprehensive list of multiple forecasting and development options was mutually agreed with the Kuwait Oil Company (KOC) asset team. These were simulated whilst honoring all available data and information pertaining to wells and facilities, including their respective constraints.

Further variations to the simulation cases, including focused work on the Ahmadi ridge and Northern Burgan area were all simultaneously performed. Simulation cases related to testing the system capacity limit for the entire field as well as implementation of horizontal wells to target the sweet spots in the Middle and Lower sands were completed in addition.

This work was in part, used for proof-of-concept modelling pertaining to simultaneous injection and production, within the Wara-Burgan reservoir. This invariably led to a decision for facility re-assignment with respect to availing injection slots, for utilization in the field for water injection.

This work further formulates the asset strategy to develop all operational reservoirs of the Greater Burgan field with given and foreseeable constraints in view of the strategic objectives of KOC.
Optimized PDC Point-Loading Cutter Placement Drives Higher Performance in Anhydrite
Authors: Alsaif H. F. , Almarhoon Q. , Alraheb M.
Published: February 2024

Shaped cutters have been popular in the PDC cutter development realm. However, the optimum placement of those shaped cutters in a drill bit remains wide field to be explored. This paper illustrates how placement of the point-loading cutters drove higher performance in Anhydrites minimizing the need for multiple bits to complete the 8.5" section in the Unconventional Gas unit in The Middle East.

Formations rich in anhydrites and carbonates present a challenge to successfully drill given the hardness of the anhydrite and interbedding with carbonates. To assure consistent success with this application, a detailed application study was carried out to determine cutter failure modes. After that, multiple bit designs have been evaluated using Tetrahedron, a drilling simulator software, having variable position of the shaped cutter. Once the shaped cutter position has been optimized, the bit was tested in a lab environment. It was then deployed in the field after successful lab results.

Lab testing showed promising results for field deployment. Once the bit is run in the field, ROP improvement of 33% was achieved. Then, more field deployment followed with higher performance compared to other PDC bits. This bit consistently drills the entire section in one run replacing 2 bits. The field deployments resulted in significant cost savings for the operator as well as reductions in well delivery time. This repeatable performance proved that optimizing the position of point-loading shaped cutters leads to a higher performance drilling anhydrite. This higher performance results in enormous savings to the operator in terms of time and economics.
New Bit Design with Rotary Steerable System Unlocks Next Drilling Chapter: Improving DLS Capability and Drilling Performance
Authors: Al-Meer Ali , Nesaif Jawad , Osman Ahmed , Fakhrylgayanov Ayrat , Radhakrishnan Venkat , Alibrahim Eman , Varela Rodrigo , Silva Paul , Alabdullah Mansour , Gassas Reema
Published: February 2024

One of the biggest challenges in drilling operations is achieving the required dogleg severity (DLS) while drilling the landing curve section in 3D complex wells, especially the wells targeting shallower reservoirs that demand high DLS. This manuscript describes the first use implementations of a new bit design in the Middle East with a Rotary Steerable System (RSS) that achieves demanding DLS with avoiding usage of Positive Displacement Motor (PDM) in the directional bottom hole assembly (BHA), which could have compromised the drilling performance.

Dynamic modeling was performed to simulate the interaction of RSS and motorized RSS with the new bit design to model the DLS capability, shock and vibration, stick and slip, and BHA stability. The formation properties and response to different steering ratios were also included to have a comprehensive study of the fields. Furthermore, optimized drilling parameters regarding the flow rate, weight on the bit (WOB), and rotation per minute (RPM) were modeled to reach the best performance with increasing efficiency to mitigate shocks and vibrations and, at the same time, reduce stick and slip. The complex 3D design was drilled with shallow true vertical depth (TVD), successfully meeting the client’s requirement.

The challenge of the high DLS and having low performance is now a thing of the past, as a new chapter has been opened with the new bit design with rotary steerable BHA. The first trials with the new bit were successful. The required shallow TVD was achieved with up to 6 deg/100 ft of DLS. Moreover, there was no need to set the maximum steering ratio for the RSS tool, as the required DLS was achieved by using only 50% of its capability. On the other hand, operating the RSS tool with half its energy has increased its reliability, almost doubling its life span, which means longer sections can be drilled with one run in the future. However, with these new technologies, there is no need to run the motors with a high bend angle to get the DLS; this can be done by using the new bit design and the RSS tool. Furthermore, controlling the rate of penetration (ROP) to get a higher DLS was not necessary, as it resulted in increased performance with a smooth well trajectory.
The Influence of Red Mud Additive on Drilling Fluid Performance: Comparison Between Calcite in Conventional Drilling Mud and Red Mud Additive
Authors: AlBoraikan R. , Bageri B. , Solling T.
Published: February 2024

The main objective of this paper is to utilize red mud waste in drilling fluid design. Around the globe, there is a significant demand for energy and the global demands for technology keenness in providing an ecological solution. In recent years, there has been attentiveness toward finding sustainable solutions for waste prevention for upstream companies. This paper proposes a waste management solution as the red mud characteristics and composition show a potential drilling fluid application. Different techniques and evaluation procedures have been followed to characterize and evaluate the red mud additive. The differences in performance between red mud and a conventional calcite mud system were the core of the performance evaluation in this paper. The study was conducted to utilize red mud waste in the drilling fluid design and provided some information and guidance for the possibilities and challenges associated with using red mud additive in drilling mud systems. Red mud consists of coarse and fine particles, and to determine whether red mud can be considered an inert material in the drilling fluid design. The material undergoes a preparation process. Then, the particle size distribution analysis was performed to ensure the quality of the starting material. Finally, the material dissolution in acids was tested in 15 % HCl. Then, the investigation covers the solid characteristics and the elemental composition.

Moreover, the study highlights the effect of red mud dry additive in a drilling fluid system. Both rheological characteristics and filtration properties at 150 °F were highlighted in the paper. The filtration performance was tested based on the American Petroleum Institute (API) standard at LPLT and HPHT conditions. The practical applicational angle for this study exhibits similar rheological and filtration performance compared with calcite mud under HPHT conditions. By utilizing the red mud additive in the water-based drilling mud fluids system under HPHT conditions, the product gives relatively lower rheological characteristics, good solid suspension behaviour, and excellent filtration control. Red mud presents a possible example of a material where waste by-products can be seen as a potential product. The possibility does exist for the red mud to be used as an inert additive to optimize various drilling fluid properties.
Alkaline/Surfactant/Polymer (ASP) Flooding: Laboratory Evaluations, Simulation Studies and Pilot Planning for a Matured Carbonate Reservoir in Bahrain
Authors: Konwar L. , Anaisi I. AL. , Alwawainati E. , Matar O.
Published: February 2024

The Mauddud reservoir discovered in 1932 in Bahrain is now in a mature stage of development. A detailed feasibility study is carried out for identifying the most appropriate enhanced oil recovery (EOR) process for Mauddud reservoir and defining a strategy for further evaluation and implementation of the most promising EOR options. Detailed laboratory studies have identified alkaline-surfactant-polymer (ASP) process as the most technically attractive EOR process to increase the ultimate recovery from Mauddud reservoir by significantly improving the volumetric sweep and displacement efficiency. This paper aims to present detailed design of laboratory experiments and results en route to sector modeling studies in three (3) selected large areas. A 3.6 acres area is selected in Mauddud waterflooded reservoir for piloting. Detailed cost estimate is carried out using laboratory design data and simulation results.

Extensive laboratory design and testing such as polymer rheology, thermal stability tests, polymer injectivity, viscosity, adsorption, ASP phase behavior and coreflood tests are performed. 1-D coreflood simulation model was conducted using University of Texas Chemical Compositional Simulator (UTCHEM). Polymer rheology and surfactant phase behavior laboratory test data were matched to generate input parameters for the ASP injection simulation forecast. Representative sector and pattern simulation models were developed to estimate the EOR production potential from the Mauddud reservoir. The sector model developed was calibrated to the historical production, injection, and pressure data. The history matched sector model was used to select and develop pattern simulation models that were used to estimated EOR production potential.

Based on the evaluation of laboratory results, polymers are identified to give adequate viscosifying power and thermal stability. ASP formulations are identified for designing coreflood. Coreflood tests provided the process recovery data on residual oil saturation, chemical retention facilitating optimum slug design resulting in maximum oil recovery with minimum amount of chemical mass. The chemical formulation selected showed good phase behavior at different oil/water ratios, equilibrated quickly, good aqueous solubility, and generated ultra-low interfacial tension (IFT). The surfactant formulation showed great promise in the coreflood tests. The ASP coreflood tests recovered 63 to 70% of the waterflood residual oil and left a residual oil saturation after chemical flood (Sorc) of 9%. ASP pattern simulations showed incremental oil recovery factors between 26.7 and 31.9 percent of the original oil-in-place (OOIP).

The laboratory and sector simulation results are crucial to explore the feasibility of EOR project and will serve as inputs to detailed economic evaluation as well as pilot design and facilities planning.
Unpacking the Technical and Financial Challenges of Carbon Capture and Storage in Depleted Gas Fields for a Sustainable and Economically Viable Energy Future: Insights from the Egyptian Nile Delta
Authors: Abdelrahman Mohamed Mahmoud , Hoolahan Shaun
Published: February 2024

Carbon capture and storage (CCS) technologies are increasingly seen as a promising solution to the challenge of meeting rising energy demand while reducing greenhouse gas emissions. However, CCS projects face significant initial costs, and their viability depends on their ability to offer a return on investment. In addition, the unique characteristics of CCS projects, such as containment, capacity, phase behavior, sustained injectivity, and regulatory permissions, pose distinct challenges that require fresh analytical methods.

To address these challenges, this paper provides a comprehensive assessment of the technical and financial aspects of applying CCS in depleted gas fields operated by Dana Gas in the Egyptian Nile delta. The assessment covers a range of technical and financial aspects, including the evaluation of subsurface resources and wells, assessment of surface facilities and infrastructure, analysis of market demand, and financial and commercial viability. Using extensive data obtained from the gas fields and industry best practices, our analysis explores infrastructure repurposing opportunities, including pipeline CO2 capacity, CO2 compression scenarios, and CO2 processing requirements, with insights into the CCS value chain and market analysis.

Our findings demonstrate that the implementation of CCS in Dana Gas's depleted gas fields can be viable from both technical and financial perspectives. The estimated CO2 capture and transportation costs range from USD$16-17.5 per tonne of CO2 storage, depending on the emitter, making the project economically feasible for a reasonable range of estimated tariffs. The paper also highlights the importance of considering regulatory permissions, long-term verifiable containment, capacity, phase behavior, and sustained injectivity in the implementation of CCS projects. By providing a clear and detailed assessment of the technical and financial aspects of implementing CCS in depleted gas fields, our paper contributes to the literature on CCS technologies and informs future decision-making. Our findings also highlight the potential benefits and impact of implementing CCS in depleted gas fields, and the importance of advanced analytical methods in assessing such projects.

Our detailed analysis, which is based on extensive data obtained from the gas fields and industry best practices, provides valuable insights that can help to de-risk actual CCS project applications and facilitate informed decision-making. Our findings also contribute to the literature on CCS technologies, highlighting the potential benefits and impact of implementing CCS in depleted gas fields, and the importance of advanced analytical methods in the assessment of such projects.
Successful Implementation of Foam Batch Jobs for Gas Well Deliquification
Authors: Al Hadhrami Taher , Ghaempanah Babak , Al Aamri Ghusun , Kusela Ardia , Al Rashidi Ahmed
Published: February 2024

Liquid loading is a general threat to gas wells, hindering performance and recovery factor. Foam batching is a common deliquification technique that under right conditions offers significant results. Depending on the well performance foam batching can be applied as both a secondary and a primary means of deliquification. However, the key to success lies in proper selections of well candidate and foamer plus proper execution. Hence, a comprehensive understanding of foam batching suitability and monitoring for improvements are crucial for its successful implementation. Following trial phases on different foam assisted lift designs, PDO has currently landed on foam batch job as an optimum low-cost option and started its large-scale implementation to enhance its gas well deliquification capacity as well as to secure a secondary means of deliquification. This paper shares PDO’s experience from this implementation phase of foam batch jobs and contributes to practical and theoretical aspects of foam batch application for gas well deliquification.
Improving Well Productivity Through Better Perforation Design
Authors: Fituri M. A. , Munoz J. , Al Harbi A. , Abouganem A.
Published: February 2024

Formation damage in the near wellbore region, causes impairment to fluid flow, perforations are designed to bypass the near-wellbore drilling damage by generating deep perforation tunnels and bypassing the damaged zone, however, perforation tunnels are affected by additional damage surrounding the tunnel (crushed zone) and by the debris filling the tunnel that are generated during the creation of the tunnel.

Several perforation techniques developed and used to overcome the perforation damage; some techniques consider living with the perforation damage and create small fractures in this damage to improve permeability, such as Extreme Over Balance (EOB), other techniques consider removing all crushed zone and debris out from the perforation tunnels, such as Under Balance (UB), and Dynamic Under Balance (DUB), these different techniques are suitable for different environment as will be stated in this paper. By tailoring the perforations to the specific environment, a significant productivity improvement can be achieved. All the techniques are briefly explained in the paper with more details on the DUB which was successfully utilized for the case study.

A tailored perforation design was implemented for KOC, that utilized the deep penetration charges combined with dynamic underbalance method, which further improved the perforation tunnel cleanout. This improved design resulted in achieving more than 30% increase in production in comparison to conventional Over Balance (OB) perforation design that was implemented in nearby wells.
Distributed Temperature Survey (DTS) Technology Application in Optimization of Injector Well Coiled Tubing (CT) Acid Stimulation, A Case Study Review
Authors: Shokry A. , Bigno Y. , Agrawal P. , AlAli S. A. , AlHammadi I. A. , Sulaiman A. Y. , AlGhafeli S. K. , ElSheikh H. , Prossaird S. , Baioumy B. , Rivas J.
Published: February 2024

For a significant operator in the offshore Middle East, performing a production logging operation before an acid stimulation, either on an oil producer or a water injector well, is a common practice. Access to this data just before the intervention is critical to optimize the treatment and even to define the need for acid stimulation. The production logging tool (PLT) can be run with wireline (WL) or coiled tubing (CT) units; in both cases, the footprint gets increased due to the need for the WL unit and the increased time and cost due to the additional PLT runs.

Knowing all these factors makes the use of Distributed Temperature Sensing (DTS) for water injector wells cost-efficient since the operation can be done with only one CT reel without the need for WL unit and PLT tools. In fact, the injectivity profile can be done with just an Inconel-encapsulated fiber optic installed inside the CT string; this configuration allows to pump acid treatments with a single CT string reducing the footprint and rig-up/rig-down times of WL unit and swap between conventional and e-coil reels. However, the technology and methodology have yet to be proven in-house to be included as a common practice and replace the PLT operation pre & post-acid stimulation until this case study was conducted. This paper will review a first-in-the-region case study for an offshore water injector CT acid stimulation operation performed using DTS Technology to replace PLT logging, which introduced noticeable optimization to the acid stimulation operations. The paper will also quantitatively evaluate the performance optimizations that emanated from this new technology application.
Digital Integration Scope in Fracturing: Leveraging Domain Knowledge for Intelligent Advisors—Part I
Authors: Khan Abdul Muqtadir
Published: February 2024

Fracturing treatments in reservoirs with high tectonic effects or soft rock can lead to multiple challenges during fracturing treatment placement. Challenges like low injectivity and increasing pressure require expertise at each step. The decision-making process can be time consuming, which impacts operational efficiency. On the other hand, making a suboptimal decision affects the well performance. This study investigates how digital frameworks and infrastructure can enable imbibition of domain knowledge for efficient decision making.

The scenario management can enhance operational efficiency by enabling faster and efficient decision making. Precision and consistency in flush volume can also be achieved, and the amount of proppant placed can be optimized, thereby avoiding premature termination and screenouts. A near-wellbore screenout contingency utilizing the surface well testing manifolds can help avoid CT cleanout in certain cases. Stimulation efficiency can be significantly increased by lowering the number of stages skipped due to low injectivity. Seven scenarios were considered in a wide spectrum of treatments and completion types. Detailed contingency workflows were developed in different rock types for (1) design considerations for flush volume, (2) increasing pressure during the fracturing treatment, (3) overflush criteria in case of premature treatment termination, (4) screenout, (5) low injectivity, (6) reperforating, and (7) tubing-annulus communication. During the workflow development, the reservoir quality index, degree of rock consolidation, rock strength, and completion rathole were important factors considered.

A state machine automaton approach was utilized here to treat each action and condition in the flowchart as a state which advances based on rules and conditions. The solution was realized in two modes, interrogator, and simulator. The interrogator mode can be used by the user in a static case in pre-treatment or post-treatment scenarios. The simulator mode is built to integrate with the time series data stream and provide recommendations based on the data received, hence acting as an intelligent advisor on the wellsite. Comprehensive validations of the solution package have been conducted with synthetic and real data sets to show the experience of using the advisor. The solution has potential to enhance operational efficiency and reduce cost in multiple ways.
Unlocking New Solution in Brown Field Production: Innovative & Advanced THM (Tubing Heavy Wall Mechanical) Pump Improvement Method with Cost-Effective Approach
Authors: Dewanata Dionisius , Suryantoro Rahma Wisnu , Oktoviyanto Yusuf , Kurniawan Iwan , Andri Sailin , Akbar Despredi
Published: February 2024

Mature oil fields have various obstacles in producing oil efficiently. In Rantau Field, the reservoir pressure has already been depleted and nowadays the development using waterflood technology initiated to deploy for Zone Z-AAA. Evaluation of various strategies conducted to maximize production in waterflood Zone development (Z-AAA), minimizing cost and extending the field's economic life. Sucker rod pump (SRP) is the most artificial lift used in Rantau Field because SRP is one of the low -cost artificial lift, about 68.61% in total. The cost-efficient solution is done by repairing the downhole pump for SRP (tubing pump / THM Pump) after well service and re - installed it.

The challenge from using repaired tubing pump is the leakage of the pump. The authors conducted FMEA analysis to solve that p roblem. The tubing pump has a hold-down mechanism on its standing valve assembly and does not have backup seal when the hold-down ring is damaged, and yield strength of the hold-down ring is less than the seating nipple. A finite element simulation with mess skewness 0.2 was carried out to support the analysis to determine the improved design of standing valve assembly.

From the simulation, the hold-down ring with fit interference could not hold the force from the operational load, especially for bump- down jobs when the pump gets stuck. The stress that impacts the hold-down ring could reach 392 MPa (156% of its yield strength). The author modified the hold-down ring design into a threaded design complete with O-ring sealing, then called TSV. The stress impacted to TSV could reach 144 MPa (57% of its yield strength) in the simulation. To validate the finite element result, the author conducted a pressure test with a vacuum tester. The pressure test was applied at 500 Psi and could be held for 5 minutes. The next step i s the installation of TSV in three wells.

As the result of improving the design of standing valve assembly, the repaired tubing pump could be reinstalled in another we ll without changing the standing valve components and it has decreased the pump failure during the operation of the pump. Since the repaired tubing pump could be used repeatedly, new purchases of tubing pumps could be minimized, and it can suppress the production cost of mature oil fields in general.
A New Ensemble Machine-Learning Framework for Analyzing EUR of Future Deployed Wells in Tight Gas Reservoir
Authors: Jia Ying , Huang Lei , Zhao Chunlan , Ren Guanglei
Published: February 2024

Tight sandstone gas reservoir is the main type of unconventional natural gas reservoir, and is also the largest unconventional natural gas reservoir in the world. Its significance and role in natural gas resource are becoming more and more obvious[1]. Tight gas reservoirs are generally defined as having less than 0.1 millidarcy (mD) matrix permeability and less than 10% matrix porosity. [2]

China's tight gas reservoirs are widely distributed in more than 10 basins such as Ordos, Sichuan, Songliao, Bohai Bay, Qaidam, Tarim and Junggar etc. In recent years, with the advancement and large-scale application of hydraulic fracturing technology, the exploration and development of tight gas reservoir have made significant progress. Two gigantic gas zones in the Sulige Basin in the Ordos Basin and the Xujiahe Formation in the Sichuan Basin was discovered and developed. The prospective resources of low permeability sandstone gas reservoirs exceed 17-24 trillion square meters, accounting for 1/3 of the total natural gas resources in China[3–5]. Nowadays, the main tight gas field of Sinopec has entered a declining stage, facing the challenge of tapping the potential of remaining gas and improving oil recovery. How to analyze the production capacity of future deployed wells and optimize EUR based on clarifying the remaining gas in the gas reservoir is a key issue for efficient development.

At present, the evaluation of production capacity and EUR is divided into three categories: theoretical methods (evaluating production capacity based on test data and analyzing EUR based on production data analysis methods, such as RTA)[6–9], empirical methods (such as various experience decline models)[10], and data-driven methods (based on machine learning, neural network algorithms, and other modeling)[11–13]. Although theoretical methods have clear physical meaning, they are difficult to handle the contradiction between the full factor assumptions of physical models and the efficiency of model simulation; Empirical methods establish empirical production decline models based on the analysis of a large amount of production data, but they lack of strict seepage theory support and have poor applicability; Data driven methods mostly reflect the mapping relationship between data and data, and prediction accuracy directly depends on the quality of training data and the suitability of algorithms. The above methods were applicable to gas wells that have been in production for a period of time and show significant production decline characteristic. However, EUR predictions for newly deployed wells in a block are not applicable.
A Comprehensive Overview on Inefficient Events and Key Technologies of Multi-Branched Well Drilling and Completion: Cases in the Middle East
Authors: Zeng D. , Wang Z. , Tian Z. , Fan K.
Published: February 2024

Multi-lateral wells are widely utilized by exhibiting enhanced productivity and reduced drilling costs in comparison to traditional vertical well technology, due to the shared upper casing section and production process equipment. Nevertheless, a systematical evaluation of the key technologies of the multi-lateral wells is currently absent, resulting in frequent inefficiencies occurring during the drilling and completion process and having a negative influence on drilling efficiency.

Based on the statistical data sourced from an oilfield in the Middle East, this paper undertaken a comprehensive assessment of the inefficiencies from three perspectives of geological factor, design factor and drilling optimization. The key technologies for enhancing the efficiency of drilling and completion are identified.

Results indicate that inefficient events related to geological factors are primarily formation losses, while design-related inefficiencies include intricate trajectory for which control is difficult, as well as a long horizontal section with difficulties in cut carrying and a propensity for the formation of rock beds. From a viewpoint of drilling optimization, inefficiencies involve stuck pipes during drilling, particularly in water-sensitive formations, causing issues such as hole shrinkage, key seat sticking, and long operation time. In addition, an ease of swabbing during retrieve Whipstock in 7″ liner results in a heightened risk of well control, and shear pin may snap if the driller slacks off extra weight during run in hole (RIH), leading to the Whipstock to plummet into the hole.

In order to address the three types of factors, the strategy of abandoning total loss hole and using high-performance drilling fluids is adopted to save costs and time. Collision avoidance is considered to prevent unintended intersection or interference and distance among window to window is optimized around 200 ft. In addition, the multi-window one-time scraping method is used to enhance operational efficiency by minimizing the number of trips. During the drilling process in the 6-1/8″ wellbore, employing the fast drilling method reduces the time required by half compared to traditional controlled-speed drilling.

This research provides both practical and theoretical guidance for contributing to multi-lateral well construction efficiency, modulating non productive time (NPT) and ensuring safety during operation.
Beyond Surface Imaging: Acoustic Deep Shear Wave Imaging Bridges the Gap for Accurate Fracture Detection and Mapping
Authors: Hermawan Manuaba Ida Bagus Gede , Ghanim Rayan A , Haji Abdullah , Abouzaid Ahmed
Published: February 2024

Accurate fracture detection and mapping is essential for optimizing hydrocarbon production and avoiding early water breakthrough through fractures. However, conventional surface seismic methods and borehole shallow resistivity imaging have limitations in detecting deep fractures, which can lead to inaccurate reservoir characterization. This paper presents the application of Acoustic Deep Shear Wave Imaging (DSWI) for bridging the gap between the surface seismic and borehole shallow resistivity imaging data for accurate fracture detection and mapping, to avoid early water breakthrough through these fractures.

DSWI is a new imaging technology that uses shear waves to image the subsurface. Shear waves are sensitive to fractures and can provide detailed information on their orientation, size, and distribution. By combining the DSWI data with the surface seismic and borehole shallow resistivity imaging data, a more accurate image of the subsurface can be obtained, allowing for more accurate fracture detection and mapping. The accurate detection and mapping of fractures can help avoid early water breakthrough through the fractures. By identifying the high permeability pathways, these fractures can be avoided and isolated, allowing for more effective reservoir management and optimization of hydrocarbon production. The application of DSWI has several advantages over traditional imaging methods. DSWI can provide a more accurate image of the subsurface, allowing for more accurate fracture detection and mapping. In addition, DSWI can image deeper fractures that are not visible with conventional imaging methods.

In conclusion, the application of DSWI is a powerful tool for accurate fracture detection and mapping in the subsurface. By bridging the gap between the surface seismic and borehole shallow resistivity imaging data, a more accurate image of the subsurface can be obtained, allowing for more effective reservoir management and optimization of hydrocarbon production. The accurate detection and mapping of fractures can help avoid early water breakthrough through the fractures, and improve the overall productivity of the reservoir.
Re-Use and Utilize Kuwait National Petroleum Company KNPC Treated Effluent Waste Water in Kuwait Oil Company KOC for Industrial Applications Successful Case Study
Authors: Al-Maheimid Imad , Al-Mass Saja
Published: February 2024

Extended Abstract

Low salinity water and brackish groundwater is valuable and very precious source of water especially in arid land such as of Kuwait.

Considering that the Kuwait Oil Company KOC future low salinity water demand will increase significantly due to the expansion on the company activities, low salinity water are utilized for industrial applications, such as firefighting systems, desalter wash water and other industrial applications, taking in account that Abdaliyha brackish water (producing low salinity water from Dammam formation) is the main productive field of low salinity water that KOC relied on since 1945 to supply South & East Kuwait asset, West Kuwait asset as well as Ahmadi residence area for industrial and other non-potable applications, this precious source of low salinity water must be utilized and consumed carefully to avoid any deterioration may occur on the water specifications or / and on the aquifer water level.

In view of the above, low salinity water management has become of the great attention in the company to secure this sources of water future applications and demands, hence, KOC been prepared to handle and overcome this issue in economical, efficient and scientific acceptable manners.

Low salinity water and brackish groundwater is valuable and very precious source of water especially in arid land such as of Kuwait.

Considering that the Kuwait Oil Company KOC future low salinity water demand will increase significantly due to the expansion on the company activities, low salinity water are utilized for industrial applications, such as firefighting systems, desalter wash water and other industrial applications, taking in account that Abdaliyha brackish water (producing low salinity water from Dammam formation) is the main productive field of low salinity water that KOC relied on since 1945 to supply South & East Kuwait asset, West Kuwait asset as well as Ahmadi residence area for industrial and other non-potable applications, this precious source of low salinity water must be utilized and consumed carefully to avoid any deterioration may occur on the water specifications or / and on the aquifer water level.

In view of the above, low salinity water management has become of the great attention in the company to secure this sources of water future applications and demands, hence, KOC been prepared to handle and overcome this issue in economical, efficient and scientific acceptable manners.
Utilizing Lessons Learned from Overcoming Challenges to Achieve Continuous Improvement in Rig less Plug and Abandonment in Southern Region of Pakistan: Case Studies
Authors: Ahmad Syed Hamza , Ahmed Syed Sharjeel , Anwar Rameez , Yousaf Arif , Elmoneim Hossam A. , Khokhar Saad Yousuf
Published: February 2024

Due to the escalating number of ageing and depleted wells, the decommissioning of oil and gas wells has emerged as a critical aspect of the oil and gas industry. Nonetheless, decommissioning operations are known to be both time-consuming and expensive, requiring extensive workover operations that involve transporting heavy equipment, posing safety risks and environmental concerns. However, with the recent increase in the frequency of Plug and Abandonment (P&A), rig-less executions have become increasingly popular. They offer a cost-effective and time-efficient approach to decommissioning wells. However, it comes with unique challenges that vary from well to well and require sophisticated planning and utilization of specialized tools and procedures to ensure proper decommissioning of wells meets all regulatory requirements. The objective of this study is to analyze the challenges encountered during the execution of rig-less P&A and implement the lessons learnt to improve the overall efficiency of the operation.

The paper encompasses the detailed study of unique challenges encountered during the P&A of more than 50 wells, both vertical and deviated wells and with different types of completion. The challenges encountered during execution include the inability to properly kill the well having tight formation (typically sandstone) with a very narrow pore /loss gradient resulting in a simultaneous loss and gain situation. This requires specialized formulation of loss circulation material that is pumpable through restricted IDs of coiled tubing while creating an ultra-low invasion layer across the perforations to withstand the differential pressure of kill fluid.

There are certain challenges associated with establishing tubing-casing communication in deviated well, immensely scaled tubing restricting any intervention, old wells completed with mud as completion fluid and heavy-grade tubing. This paper provides insight for the selection tools and procedures considering well conditions to establish effective tubing-casing communication for cement plug placement. Moreover, this technical paper focusses on various remediation techniques and specialized chemical solutions that are at hand to address issues pertaining to sustained casing pressure (SCP) in a rig-less manner.

This technical paper presents an incisive analysis of the unique challenges and optimal strategies of rig-less P&A operations that can be adopted in multi-array wells. The insights and recommendations outlined in this paper can be extrapolated to other comparable operations, yielding a significant contribution to make P&A cost-effective and time efficient.
An Effective Metal Organic Framework (MOF) for Selective Barium Removal from Oil Field Waters
Authors: Hou J. , AlGhunaimi F. , Huang T. P. , Aljuryyed N.
Published: February 2024

Highly efficient capture of barium from oil field produced water is a meaningful task in water treatment, such as for water disposal, irrigation or barium recycling. Here, we propose a barium trap with metal-organic framework (MOF) modified by strong barium combining group (sulfate and sulfonic acid group). This MOF material can remove > 90% barium selectively in high salinity produced water, regardless of the ion interferences.

The Zr-BDC-NH2-SO4 material was prepared by 2-aminoterephthalic acid and Zr(SO4)2·4H2O assembly at 98 ºC under stirring for 16h. After washing with water and ethanol, the material was dried at 60 ºC overnight, and then characterized by XRD and SEM. In the adsorption experiment at room temperature, 0.2 g Zr-BDC-NH2-SO4 MOF material was immersed in series of concentrations of barium in deionized water or high salinity water (TDS > 60,000 ppm) for 2 hour’s incubation. The barium concentration was from 20 to 5,000 ppm. Barium concentration after Zr-BDC-NH2-SO4 removed was measured by ICP-MS.

In the theoretical structure of the MOF material, the sulfate anions located around the Zr6-cluster in Zr-BDC-NH2-SO4, and the sulfate anions are coordinated to the Zr6 inorganic node by a monodentate O atom. The sulfate anions in Zr-BDC-NH2-SO4 is fully exposed, indicating that Zr-BDC-NH2-SO4 will be easier to bind with Ba2+ ions. The adsorption results in deionized water shown that the adsorption amount of barium increase with initial barium concentration. At 5,000 ppm, the amount can be as large as 200 mg/g. And the adsorption curve was linear and did not reach the highest value yet. More importantly, the adsorption amount in produced water is almost the same comparing to deionized water, indicating that the adsorption of barium is not affected by salts in produced water because of the high selectivity of the sulfate functioned material.

This work provides a remarkable, sulfate group functionalized MOF with very high barium uptake capacity which surpasses most of reported adsorbents. It can selectively capture barium from high salinity oil field waters.
Driving Operational Excellence: Cost Savings and Performance Optimization Through Tripping and Connection Time Optimization
Authors: Gamal Hany , Albahri Said , Essa Hassan , Srivastava Mayank , Alghamdi Noor , Shaikh Wahid
Published: February 2024

Achieving operational excellence in the drilling industry is crucial for cost savings and improved efficiency. This abstract highlights the significance of tripping and connection time optimization through a real-time data analytics approach and proactive strategy to drive operational excellence, resulting in substantial cost savings and increased efficiency.

Tripping and connection time, which involve the processes of pulling out and running in the hole with drill strings during drilling operations, contribute significantly to the overall drilling time and operational costs. By optimizing these critical activities, drilling teams can achieve remarkable improvements in operational efficiency and financial performance. The current study explores various strategies and technologies employed to minimize tripping and connection time, such as real-time visualization dashboards, advanced data analytics, and intelligent drilling control systems. These approaches aim to detect the invisible lost time (ILT) toward streamlining and expediting the tripping and connection processes while ensuring safety and reliability.

The benefits of tripping and connection time optimization are crucial. Firstly, it leads to substantial cost savings by reducing non-productive time and optimizing drilling sequences. Secondly, it enhances operational efficiency by increasing the overall drilling rate, improving rig utilization, and enabling faster drilling cycle times. Case studies and industry examples through the research demonstrated a cost saving of 14 k$ from only one well through optimizing the tripping and connection time, demonstrating successful implementation of tripping and connection time proactive optimization strategies. Real-time data analytics plays a proactive role in detecting inefficient tripping and connection performance by providing timely insights and alerts. This capability enables prompt corrective actions to be taken, ensuring optimal tripping and connection operations. These real-world scenarios showcase the significant cost savings achieved and the positive impact on operational performance. Based on the results and observations, it can be concluded that tripping and connection time optimization is a vital strategy for achieving operational excellence, cost savings, and improved efficiency in drilling operations.

By leveraging real-time data analytics, automation, and advanced technologies, drilling companies can drive performance improvements, enhance financial outcomes, and maintain a competitive edge in the industry. Future research and industry efforts should focus on further refining and expanding these strategies to maximize the benefits and drive continuous improvement in the pursuit of operational excellence.
Integrated Solution for Development Carbonate Reservoir: Challenges and Mitigation in a Workover Operation
Authors: Alghareeb Abdulaziz Ahmad , Al-Raqwah Abdullah , Santoso Gagok , AlDossary Mubarak , Alghamdi Sarah
Published: February 2024

The work discusses a unique challenge in designing a horizontal well in the matured field that always comes with a multiple contingencies plan, from drilling, geology, reservoir management, and completion. Therefore, the topic presented in this paper is based on a holistic approach to tackle all potential uncertainties related to drilling operations toward production management. Limited data for wells previously drilled in the same area is gathered with associated uncertainties, and trajectory deepened in some wells to appraise and collect additional data. The well was completed lately to evaluate the reservoir potential, performance sustainability, reservoir drive, production around the area, etc. The workflow is set with some potential mitigation in place that includes using the latest rotary steerable system BHA during drilling of both- inclined sections including landing and horizontal trajectory into one section. The well was completed using complex LWD triple combo and sonic measurements aiming to overcome the uncertainty in formation evaluation. The process used proactive geosteering technology to enhance geosteering in the lateral section.

The well was drilled in 3 runs, starting with the kickoff/ whipstock assembly, continuing with the curve section with high dogleg severity (10.4 deg dogleg), then completing with the horizontal section. The geosteering strategy has been applied successfully by implementing the landing strategy with model compare update technique and correlation. The well successfully landed 5ft TVD below the top reservoir. The reservoir was expected to be 1-2 deg dipping down; however, the reality was down to 5-6 deg dipping. The well was geosteered proactively to avoid the risk of exiting the top of the reservoir and completed with good net to gross in the reservoir. The sonic measurement was used to evaluate the formation strength for geomechanical study and contingency fracturing plan if the reservoir porosity was tighter than expected.

This project implemented new technology and a novel approach to mitigate project uncertainty. The case studies are reviewed in which the application of innovative LWD services has played a fundamental role in providing new insight into the reservoir character and led to successful well placement.