bluuebunny/crossref_metadata_2025_split huggingface dataset:
Alternative Approach to Acid Stimulation in Extended Reach Multilateral Water Injector Well
Authors: Al Balushi I. A. , Charushin A. , Makawi S. 
Published: February 2024

Abstract
A dual-lateral water injector well was drilled in December 2022 to sustain reservoir pressure and support nearby wells production. A low injectivity of 1,500 bpd was observed from the start of the injection, which was analyzed to be due to tight dolomite formation whereas nearby wells production did not achieve the desired production rates. The objective of the paper is to describe the process of enhancing the injectivity in this extended reach dual-lateral water injector by combining several techniques.
Due to the low permeability of the well formation, a work cycle was developed to ensure the successful intervention is executed in a controlled manner. Therefore, acid stimulation treatment was conducted in two runs. Firstly, the long open hole horizontal mother-bore was accessed by means of coil tubing supported with an extend reach vibration tool and a friction reducer, where 185 stages were pumped utilizing special jetting tool. Secondly, an open-hole inflatable packer was run to isolate the stimulated mother-bore. Thirdly, the lateral was treated from the window depth via the coiled tubing/tubing annulus. Finally, inflatable packer was retrieved providing access to both laterals. The main stimulation fluid was chosen to be emulsified acid which provides retardation effect and deeper wormhole penetration.
Acid stimulation of the dual-lateral well was a complex intervention using extended reach tool along with friction reducer while selectively stimulating the second lateral using open hole inflatable packer. In the first run, CT reached 15,070 ft till lockup, while original lock-up depth without extended reach methods was expected at 13,691 ft. Total injectivity was improved in both holes whereas post-treatment pressure reduced to 2,100 psi compared to the initial injectivity test of 3,500 psi at 5 bpm. The operator concluded that the anticipated objective was exceeded by increasing the injection rate from 1,500 bpm to 2,500 bpm after bringing the well back on injection.
The paper highlights the successful acid stimulation associated with complex intervention executed through coiled tubing and proves the concept of stimulation dual-lateral well without using re-entry downhole tools to access a lateral. This case helps to present the value, challenges, lessons learned and opportunities existing in well stimulation for multilateral that would have previously been deployed through a costlier means of workover operation.
Coning Control Completion First Successful Implementation in North Kuwait
Authors: Al-Subaiei Dalal , Al-Mousawi Abdullah , Kumar Priya , Ron Angel Gonzalez , Zakrya Shamseldin , Al-Husaini Mohammad 
Published: February 2024

Abstract
The presence of formation water under strong water drive will support the oil production in the early life of the well then will become an issue, which is difficult to control with time. With the need of sustain and increase oil production in North Kuwait year after year, it become impassable to keep producing oil wells with low rate and rate below critical coning rate. Using Chaperone method calculation, the critical coning rate require for lower Burgan is ± 300 BLPD, to avoid coning LB well should be produce with rate less than 300 BOPD. With the high target oil rate required from NK, it is impossible to produce wells with rate below 300 BLPD.
Coning control completion (CCC) is a new technology that have been used in NK to control the coning issue in Lower Burgan, the completion contain a reverse ESP located below the oil water contact (OWC). Reverse ESP will create a counteractive pressure drawdown below the OWC to control the progression of the water cone within the oil zone. The reverse ESP will take the water below the OWC of the target zone, dump water into under-lying reservoir to minimize produced water at surface. CCC have helped NK to reduce WC from 90% to 30%.
Coning has always been an uncontrolled issue in lower Burgan, with the high pressure in LB all wells produce naturally with low WC with time coning rise-causing WC to reach 80-90%. With the increase of WC the well can't produce naturally, and it need an ESP to lift the fluid, with ESP the conning increases causing WC to increase more than 90%. CCC have helped to in reduce excessive produced water on the gathering centers and improve the Recovery Factor in partial and strong water drive Reservoirs by reducing the coning effect.
This paper will discuss the mechanism, application and the successful result of using CCC in NK and how implementing this new type of completion helped NK to improve lower Burgan reservoir.
Study on In-Situ Stress Evolution and Its Impact on Infill Well Fractures Propagation- A Case Study from China
Authors: Wang Xiaoguang. , Wu Qingxiang. , Jiang Zhibin. , Xie Dan. , Zhou Wei. , Qian Chuanchuan. , Lian Liming. , Wang Jie. , Li Zheng. , Qu Liming. , Huang Xingning. 
Published: February 2024

Abstract
Hydraulic fracturing of horizontal wells is an effective development mode for low-permeability reservoirs, while new drilling can enhance reservoir recovery. The drilling, fracturing, and production processes all induce changes in reservoir stress, affecting the infill wells’ fracture design. Adoption of finite element-based discontinuous discrete fracture numerical method. The extension of wellbore and fracture is described by dynamic mesh technology during drilling and fracturing, and the discontinuous discrete fracture model can be computed by using a conventional finite element mesh, which can be perfectly matched with the discrete fracture model, so as to realize the integrated numerical simulation of drilling-fracturing-production. Use the construction of infill wells in low-permeability reservoirs in Area 8 as an example, the integrated simulation of drilling-fracturing-production is carried out for the wells to be constructed in the encrypted well area, and the maximization of the exploitation economy of the well area guides the optimization of the infill wells’ fracturing. The simulation results show that the long-term production process of the old well reduces the formation pressure and ground stress in the encrypted well area, and the direction of the maximum horizontal principal stress is deflected. Considering the influence of the old well production, the drilling fluid density during the drilling of the encrypted well can no longer be designed using the original formation pressure profile. With the drilling fluid column pressure not greater than the minimum horizontal principal stress at this stage, the direction of maximum horizontal principal stress around the encrypted well is further deflected after the wellbore is drilled open, causing the initial expansion direction of the fracture to be deflected along the wellbore; injecting water to boost the pressure of the old well prior to the fracturing of the encrypted well can improve the fracturing effect of the encrypted well. The established numerical method can realize the simulation of reservoir stress evolution in the whole process of drilling-fracturing-production and the integrated numerical simulation of fracturing-production, which can optimize the design of fracturing in infill wells and improve the single-well production.
Integrated Logging While Drilling and Wireline Borehole Seismic for Safe Exploration Drilling in the Andaman Sea, Deepwater Indonesia
Authors: Sakina M. , Kelsall N. , Singh S. , Juliansyah M. N. , Jessup D. , Octaviani T , Arif F. , Permanasari D. , Halim H 
Published: February 2024

Abstract
A vertical exploration well, Timpan-1, was drilled in the offshore Andaman Field, deepwater Indonesia, using a unique integration of logging while drilling (LWD) and wireline borehole seismic/vertical seismic profiling (VSP) to reduce risk and increase safety while exploring the carbonate reservoir. The seismic while drilling (SWD) technology was used on the 12 ¼-in. hole section for geostopping decisions to set the 9 5/8-in. casing at the correct depth immediately above the carbonate reservoir. Once the casing reached the bottom and the drilling operation continued to well total depth (TD) on the 8 ½-in. hole section, wireline VSP was acquired to obtain the velocity profile and VSP image. The depth prediction was determined using the lookahead method, where the closer the seismic sensor, the more accurate the depth prediction. The final integrated data of both 1D images of the corridor stack from SWD and wireline VSP was displayed side by side, with overlapping levels. This aim is to have the data for the whole section and fully utilize both acquisition data. In conclusion, SWD technology is used for geostopping purposes, and wireline VSP provided the best conveyance option to help manage the depth uncertainty for the final hole section and other advanced applications of ZVSP, such as attenuation (Q) estimation. Integrating the borehole seismic acquisitions technology is the correct strategy to mitigate significant depth and velocity uncertainty risks. Thus, SWD and wireline VSP can provide a better understanding of the velocity profile and seismic interpretation of nearby Timpan-1 well.
Determination of the Connected and Isolated Porosities by a Poroelastodynamics Model
Authors: Liu Chao , Phan Dung T. 
Published: February 2024

Abstract
It is essential to know the connected and isolated porosities that play a crucial role in the estimation of in-situ hydrocarbon reserves of a reservoir and the determination of favorable target production regions. Yet, no effective methods are found in the literature to determine the connected and isolated porosities. In this work, we present a method to determine simultaneously both the connected and isolated porosities, using the theory of dual-porosity single-permeability poroelastodynamics. This theory is derived based on the dual-porosity dual-permeability poroelastodynamics. The dual-porosity single-permeability poroelastodynamics is associated with elastic waves propagation in fluid saturated rocks with connected and isolated porosities. Phenomena including wave dispersion and attenuation occur simultaneously due to the coupled motions of the rock matrix and fluids in pore spaces. An example is presented to demonstrate the application of the dual-porosity single-permeability poroelastodynamics in the determination of the connected and isolated porosities.
Utilization of Compact Unitized Wellhead System for Unconventional Wells
Authors: Alsaeed M. , Mukhlifi M. E. , Amer M. Al 
Published: February 2024

Abstract
This paper covers the introduction of a new fit for purpose design consisting of a unitized wellhead (Unihead) that has been introduced to satisfy both drilling and well stimulation requirements while optimizing the capital cost, reducing the flat time, and enhancing both rig and rig-less operations. Cost management is paramount to ensure the success for all project specifically for unconventional wells. Optimizations in casing design, drilling fluids and completion have been implemented heavily and around the globe. However, wellhead design optimization remains to be an area of improvement.
Prior to presented optimization, the existing wellhead system used in subject wells was originally designed for conventional wells. That system had two major drawbacks. First, it increased the rig flat time since it required waiting for cement to set before removing the Blow Out Preventer (BOP) to install the casing hanger. After that, the next wellhead spool is installed followed by installing the BOP. Second, the system used metal seals to isolate the annuli and also used a production tree to suspend the well after the drilling phase, which was costly.
The new system consists of utilizing a Unihead body and mandrel hangers to suspend both the production and long string casings. The annuli between the Unihead and the casing hangers are sealed by a seal assembly (Packoff) utilizing elastomer seals. After completing the drilling phase, the system will also facilitate rig-less well stimulation operations. Furthermore, the system will enable the installation of downhole completion and a velocity string after well stimulation. Finally, the well will be produced through the velocity production tree.
The new system was successfully installed with outstanding results and offered several advantages. This includes the time optimization, capital cost reduction and significantly reduced flat time. The system achieved these benefits through the proper system design that is fit for purpose for both rig and rig-less operations and eliminated the challenges usually encountered with conventional system design.
Achieving Ultimate Production Recovery by Building on the Successful Development Through Infill Project Utilizing Fit for Purpose Integrated Static and Dynamic Modelling
Authors: Shoaibi S. S. Al , Omairi S. , Riyami H. Al , Suleimani A. Al , Barwani A. , Hajri Y. , Khaduri S. Al 
Published: February 2024

Abstract

Objective/Scope
This paper discusses the approach utilized to model the static and dynamic data of a field in order to come up with a development plan for infill wells. These models are required to estimate the remaining in place hydrocarbons in analytical approach that is fit-for-purpose to cater for the project value drivers as well as the decisions required to be taken.

Methods/Procedures/Process
The field went through development plan by drilling oil producers as well as water injection wells. All FDP wells have been drilled already. Next development phase for the field is to drill infill wells and change the concept from 200m PPI spacing wells to a finer infill spacing well.
A study was conducted aiming to mature the volumes associated from appraising stage to commercially developed phase through Full infill development for the field.

Results/Observations/Conclusions
Due to presence of multi analogue fields which are producing in similar manners, it was proposed to use these analogues to come with the study plan for the field which resulted in putting fit for purpose plan to mature the volumes by not compromising the value drivers. In addition, the key decisions for the project are answered through this integrated plan. Furthermore, early development wells are planned to be executed at earlier stage to calibrate model result.

Novel/Additive info
This paper summarizes the approach utilized in the study which include developing static maps from Equivalent Oil Column data (EOC) using petrophysical properties from log data gathered in existing wells and use these maps to initiate dynamic box models that are used to history match existing producers and subsequently forecast the production in the proposed well location for infill purposes.
Uncertainty Quantification and Management in Model Calibration and History Matching with Ensemble Kalman Methods
Authors: Al-Turki A. A. , Hammad K. J. , Sudirman S. B. , Sawlan Z. N. 
Published: February 2024

Abstract
History matching field performance is a time-consuming, complex and ill-posed inverse problem that yields multiple plausible solutions. This is due to the inherent uncertainty associated with geological and flow modeling. The history matching must be performed diligently with the ultimate objective of availing reliable prediction tools for managing the oil and gas assets. Our work capitalizes on the latest development in ensemble Kalman techniques, namely, the Ensemble Kalman Filter (EnKF) and Ensemble Smoother (ES) to properly quantify and manage reservoir models’ uncertainty throughout the process of calibration and history matching.
Iterative ensemble algorithms have been developed to overcome the shortcomings of the existing methods such as the lack of data assimilation capabilities and abilities to quantify and manage uncertainties, in addition to the huge number of simulations runs required to complete a study. In this work, NORNE benchmark model was used to generate an initial ensemble of 40 to 50 equally probable reservoir models was generated with variable areal, vertical permeability and porosity. The initial ensemble captured the most influencing reservoir properties, which will be propagated and honored by the subsequent ensemble iterations. Data misfits between the field historical data and simulation data are calculated for each of the realizations of reservoir models to quantify the impact of reservoir uncertainty, and to perform the necessary changes on horizontal, vertical permeability and porosity values for the next iteration. Each generation of the optimization process reduces the data misfit compared to the previous iteration. The process continues until a satisfactory field level and well level history match is reached or when there is no more improvement.
The application of the Iterative ensemble algorithms is demonstrated by history matching NORNE benchmark model. Multiple iterative ensemble smoothers with adaptive inflation and localization techniques were implemented and compared. The ES algorithms preserved key geological features of the reservoir model throughout the history matching process. During this study, ES served as a bridge between classical control theory solutions and Bayesian probabilistic solutions of sequential inverse problems. The methods demonstrated good tracking qualities while giving some estimate of uncertainty as well.
The updated reservoir properties (horizontal, vertical permeability and porosity values) are conditioned throughout the ES iterations (cycles), maintaining consistency with the initial geological understanding. The workflow resulted in enhanced history match quality in shorter turnaround time with much fewer simulation runs than the traditional genetic or evolutionary algorithms. The geological realism of the model is retained for robust prediction and development planning.
Assessment of Thermal Maturity Trends in a Lower Paleozoic Source Rock Formation
Authors: Alraddadi Abdullah , Karg Harald , Salem Ahmed , Alfraih Ibrahim 
Published: February 2024

The Arabian plate has been known by its west-east asymmetric lithospheric structure, expressing itself in distinct topography and geological patterns. The western portion of the plate, consists of the Arabian Shield, exhibiting buoyant and exposed basement, while the eastern portion belongs to the wider Western Gulf Basin (Fig. 1), hosting a variety of Phanerozoic basins, which were subjected to continuous subsidence and deep burial since the Late Proterozoic terrane amalgamation. This pronounced asymmetric surface geologic pattern has deep-seated thermal and physical drivers (Stern and Johnson, 2010), governing basal heat flow and heat distribution within the sedimentary column, which ultimately drives the thermal maturity pattern of the Lower Paleozoic Source Rock across the region.
The main goal of this study is to highlight observed trends of the thermal maturity of Lower Paleozoic Source Rocks, and to discuss the primary causes for these trends within a smaller section of the Western Gulf Basin (Fig. 1). Burial history and heat flow modeling were utilized in this study based on temperature and pyrolysis data collected from around 37 wells across the study area of approximately 23,000 km2.
Sustainable Redevelopment of the Volve Field Amidst Recent Energy Security Challenges Faced by Northwestern Europe; A Case Study from Central North Sea
Authors: Ahmad M. Nauroz , Yaser M. , Abdel-Basset M. , Abdelrahim R. , Siddique E. , Abdelbagi M. E. , Firmansyah B. , Aktar M. 
Published: February 2024

Abstract
This study outlines the brownfield development plan that was employed for the Volve oil field in the central North Sea. The Volve field had been abandoned in 2016 due to economic reasons. Data from the Equinor Volve field repository was analyzed with a focus on the Hugin sandstone reservoir of Mid-Jurassic age. The goal was to identify the most suitable techno-economic approach to extend the life of the asset while also being environmentally sustainable.
The study was framed around a comprehensive geological, petrophysical, reservoir and production engineering evaluation that served as a basis for a detailed economic evaluation for the asset. The resulting dynamic reservoir model included a thorough history matching of the wells’ and field's production behavior to identify the remaining sweet spots. Two field development options were evaluated driven by critical economic variants such as Net Present Value, Internal Rate of Return, and Payout Period, using the UK Royalty/Tax fiscal regime as the framework for calculating cash flow. Methods to achieve a low carbon footprint were also incorporated.
The first option, a double peripheral layout spot pattern with six producers and two injectors, achieved the highest incremental production growth. However, due to its significant environmental impact, it was deemed unsuitable. Based on the economic evaluation, the optimal scenario for the redevelopment of Volve field was six producers, two water injectors and one water source well. The base development plan included latest development in drilling technologies such as Managed Pressure Drilling (MPD), advanced Inflow Control Device (ICD) completions for producers as well as regulating water injection through WFR's and digital end-to-end solutions. All considered scenarios were evaluated for their carbon footprint, and sustainable technologies were considered in the final plan for seeking approval from governing regulatory authorities.
The Volve field re-development plan has been achieved through deployment of novel techniques to smartly drill and complete wells to achieve sustainable incremental reserves. The redevelopment of Volve field is considered critical in the current energy demand and security challenges faced by Northwestern Europe and aims to open several other assets which have been considered non-viable during the last downturn.