bluuebunny/crossref_metadata_2025_split huggingface dataset:
Processing Formation Test Data to Reduce the Risk Inherent in Capturing Representative Samples in Zones with Highly Varying Permeabilities
Authors: Deering James , Mohsin Mustafa Abdul , Proett Mark , Eyuboglu Sami , Fakhry Waleed 
Published: June 2015

Abstract
A new method of objectively quantifying formation tester data quality has recently been developed with the aim of optimizing the generation of fluid gradients and contacts. This paper demonstrates how this new method of processing formation test data and integration with the open hole log data can be applied to improve job planning for sampling. By using data that have been quality controlled, sampling operations can be improved by using the optimal sampling tool configuration which can result in higher operational efficiencies with reduced rig time for complex logging and sampling operations. In this case study, formation tester objectives included establishing gradients and fluid contact points, determination of formation fluids and capturing representative samples over multiple horizons in a single 6 ⅛" wellbore. An additional factor which increased the complexity of this operation was the length and deviation of the wellbore, raising concerns about differential sticking due to the lengthy stationary sampling times required. The formation tester evaluation process was divided into two runs: wireline deployed pressure testing and drill pipe conveyed sampling. This culminated in successfully completing 22 pumpouts with 4 samples captured over 6 days without any incidents. The straddle packer was used 17 times in varying permeability formations and is considered to be the most number of inflations in the Middle East region.
The real-time formation tester data acquired were compared to the quality controlled data used for post processing analysis. The results were then used to identify the optimum procedures to be followed and future best practices. The lessons learned from the case study presented are used to demonstrate a quality control process with recently developed realtime methods for evaluating test quality. This allowed the data to be analyzed quickly and with confidence, enabling improved pumpout and sampling operation planning.
Overcoming Formation Evaluation Challenges in Short Radius Re-entry Wells in Aging Reservoirs
Authors: Ageel Ibraheem M , Baikelov Chingiz , Sanchez Pablo , Hameed Aamir , Gupta Sunil , Ammar Karim , Al-Momen Osamah 
Published: June 2015

Abstract
Innovations in drilling and completion technology has opened a new era in the oil and gas sector revitalizing old fields either to tap bypassed pockets of hydrocarbons or enhance the recovery factor with re-entry wells. Now enhancing production from aging fields has become a major activity for oil and gas companies. However, this is not a straight-forward decision and often the oil companies are challenged with the casing integrity, inadequate or missing log data and being able to complete the well economically.
The history of re-entry wells goes back to 1950's but it is only recently that the industry is seeing more medium and short radius wells to improve operational efficiency and to make the projects more economical. Slim borehole, complex geometry and high dogleg severity are the common attributes of such re-entry wells. Unequivocally, these complex wellbore geometries will improve recovery of reserves and maximise the net present value (NPV); however the real challenge lies with the acquisition of formation evaluation data. In these challenging conditions conventional Wireline or LWD techniques cannot provide adequate solutions to obtain much needed formation evaluation data. It was one of the reasons why most of the challenging re-entry wells in the past were not logged. Saudi Aramco faced similar challenges in one of their re-entry aging wells. The well was drilled in 1968 as a vertical open-hole producer. A series of work-overs were performed over the life of the well and in 2002, the well was side-tracked and a short radius trajectory was chosen to drill a horizontal section. During drilling the operator encountered a total loss circulation zone and was forced to plug the zone blindly without being able to log and investigate the cause.
Memory logging and slim tools have been introduced in the last decade. The operator planned to carry out another work-over in 2014.
Innovative Coiled-Tubing Deployed Zonal Isolation of a Highly Permeable, Acid-Fractured Carbonate Reservoir in Saudi Arabia
Authors: Gill Harmohan , Morris Ronald , Karadkar Prasad , Danish Syed , Arenas Angel , Deonarine Keshan 
Published: June 2015

Abstract
This paper highlights the difficulties and limitations faced along with the respective solutions proposed and executed during the zonal isolation of a highly permeable, naturally fractured and acidized carbonate reservoir during its exploration phase after having performed an extended pressure buildup (PBU) test on a remote field in Saudi Arabia.
To accurately compute the hydrocarbon reserves of a particular region, operators must explore new reservoirs in remote areas, in both challenging offshore and onshore environments, to decide future field development. The services performed on these wells include drill-stem test (DST) completions, underbalance perforation, acid stimulation, placing downhole gauges/shut-in tools, extended flowback and PBU periods, and final zonal isolation.
In this candidate well, the operator wanted to test three zones, further performing high-rate acid fractures on the lower two zones to be able to determine commercial hydrocarbon gas rates. The first major challenge was for zonal isolation of the lowest zone, expected to be a highly fractured zone that might also be stimulated. A cement plug was designed to be deployed by means of coiled tubing (CT) for accurate placement and depth control. The added challenge in this exploratory well was to plug any wellbore channels and highly permeable fractured streaks in the lowest reservoir zone after acid stimulation and reservoir evaluation were completed while preventing excessive cement fluid loss into the zone from the cement volume that would challenge the plug effectiveness. This paper explains the innovative solution devised for this well, including the job execution and elaborating on the combination of CT intervention, carefully designed chemical blends, cement fluid handling systems, and implementation of best practices to deliver a successful zonal abandonment. The operation consisted of three runs: the first used a lead batch of an organically crosslinked polymer with loss circulation material (LCM) in the solution; the second was performed for cleanout, displacement, and permanent cement slurry placement; and, after waiting on cement (WOC), the third was used to tag the top of cement (TOC) and perform a pressure test. The organically crosslinked polymer with LCM solids served to bridge off the perforation tunnels and potential fractures in the rock so that a precise volume of cement plug slurry could be pumped safely and accurately.
Formation Pressure Estimation and Miocene Clay Minerals Assemblages Identification, Drilling Challenges and Mitigation, Integrated Case Study, Gulf of Suez, Egypt
Authors: Abdallah Khalid , El Sherbeny Wael , Darwish M. , El Kammar M. , Gouda Mohamad , Al Shaikh Nasser Sadiq A. , Al-Hakim Mohammad 
Published: June 2015

Abstract
The pressure regime modeling is an integral part of the well planning and formation evaluation process. An adequate prediction of the estimated pore pressure and better understanding for the pressure regime of any area are important prior drilling any well to optimize the proposed wells target location and enable the well planner to anticipate the location and the potential magnitude of the possible abnormal pressure problems for future drilling plans and consequently minimizing drilling cost.
Wellbore instability, particularly in shale formations, is a major challenge in drilling operations. Many factors such as rock properties, in-situ stresses, chemical interactions between shale and drilling fluids, and thermal effects must be taken into consideration in well trajectory designs and drilling fluid formulations to mitigate wellbore instability-related problems.
Energy dispersive X-ray analysis (EDAX) is a technique used for identifying the elemental composition of a specimen. The EDAX analysis system works as an integrated feature of a scanning electron microscope (SEM).
Identifying shales by X-ray diffraction (XRD) operates on the principle that all minerals and clays are poorly crystalline, exhibit less sharp peaks, because of weathering effects and the substitution of ions at the atomic level crystalline (to some degree)., In contrast Quartz is highly crystalline and with XRD, produces a narrow, sharp peak.,
The paper indicates the degree of integration utilizing both pore pressure data and clay mineralogy to minimizes the uncertainty to properly anticipate drilling challenges and drilling fluids design, in additions it will reveal all XRD and SEM results that define the clay mineralogy and chemistry for Miocene succession in addition to drilling challenges related to each type of clay (bit balling, fine migrates, caved shales and difficulties running the BHA string). The paper will also provide recommendations for drilling fluid design to mitigate drilling challenges and minimize reservoir damage.
Integrating both pore pressure estimation and clay mineralogy determination for specific troublesome formation can minimizes uncertainty for anticipated drilling challenge and proposed solutions.
Chemical Enhanced Oil Recovery Pilot Design for Heglig Main Field-Sudan
Authors: Ali Husham A. , Musa Tagwa Ahmed , Doroudi Abe 
Published: June 2015

Abstract
Chemical flooding is known as one of the Enhanced Oil Recovery (cEOR) methodology to increase recoverable oil from the aging reservoirs, so that: several successful chemical injection projects were done worldwide for the past decade.
Previous studies in screening of EOR methods for the Sudanese oil fields show that Heglig Main oil field is suitable candidate for cEOR operation; the Stock Tank Original Oil in Place (STOOIP) for this field is about 577.95 MMSTB where only 22.2 % was produced through naturally depletion.
The objective of this research is to select the optimum pilot area and to design the cEOR pilot in Heglig Main oil field through a dynamic simulation modeling study; this model was constructed and run in advanced Thermal/Chemical simulation software. The scope of work of the pilot study is; a) to ascertain the alteration in oil saturation, injectivity, chemical absorption, and chemical breakthrough time for cEOR in this field, and b) to obtain pilot results in order to further refine to the cEOR full-field model.
The advantage of pilot model study is; reducing the cost by utilizations of existing wells and also minimizing the operating constraints by selecting the poor/medium performing wells.
According to the current study, a sector model with the well spacing of 200-350 m which is main factor for choosing the "pilot well area" could be properly implemented to check the flooding behavior, continuity, predict the production performance and incremental oil recovery, as well as to predict cEOR response and breakthrough time.
In this paper, pilot area as a sector model extracted from Heglig main field and a dynamic simulation model was constructed. Accordingly, seven (7) scenarios of 5-spot pattern were prepared and run in advanced Thermal/Chemical simulation software. Sensitivity analysis and optimization were also done to achieve the best scenario of the chemical flooding.
The results show that a combination of 0.4wt% of Alkaline, 0.1wt% of Surfactant, and 0.1wt% of Polymer in an ASP flooding process can increase the recovery factor of Heglig main up to 43.54%.
A Market Survey of Offshore Underwater Robotic Inspection Technologies for the Oil and Gas Industry
Authors: Ledezma F. Diaz , Amer A. , Abdellatif F. , Outa A. , Trigui H. , Patel S. , Binyahib R. 
Published: June 2015

Abstract
This paper is aimed at providing an insight in some of the most up-to-date technologies for offshore pipeline inspection. The first part reviews the basics of the main underwater pipeline inspection technologies that are commonly used to detect signs of corrosion, fractures and other flaws. The second part surveys the existing robotic technologies for deep and shallow waters that are dedicated to underwater monitoring and inspection of pipeline integrity.
Magnetic Flux Leakage (MFL) Technology Provides The Industry's Most Precise Pipe Integrity And Corrosion Evaluation, Accurately Characterizing Casing And Tubing Strength. Technology Overview And Case History
Authors: El Sherbeny Wael , Nuic Ivo , Hasan Gasser , Abdesslam Abba , Hassane Tharwat 
Published: June 2015

Abstract
The Magnetic Flux Leakage (MFL) Technique is the most commonly used technique to inspect large diameter transmission pipelines. A typical MFL inspection system uses permanent magnets to apply an axially oriented magnetic field to the ferromagnetic pipe material. The magnetic field is perturbed by a metal-loss region (usually caused by corrosion) to produce flux leakage outside the pipe, which can be measured by field sensors.
The magnetization system in an MFL inspection system should ideally produce a magnetic field that is strong enough to cause a measurable amount of magnetic flux to leak from the pipe material at metal-loss regions, uniform from inside to the outside surface of the wall thickness so that the measured signal is more linearly related to metal-loss depth, and consistent in magnitude along the length of a pipe so that flux leakage measurements can be compared at different locations during an inspection run.
In general, the field strength most strongly affects detection of metal loss defects while characterization of defect geometry requires a field that is strong, uniform, and consistent.
Improvements in the downhole hardware also provide more flexible and efficient data acquisition, reducing operating time while improving data accuracy and operational safety. In conventional magnetic flux leakage (MFL) tools, the flux leakage sensors are coils; in the "high-resolution" tool, the coil is replaced by multiple "Hall Effect" sensors.
The HR Vertilog service uses MFL measurements to identify and quantify internal and external corrosion defects. The overlapping arrays of flux-leakage sensors and discriminator sensors offer full circumferential inspection of the tubing or casing string. This process differentiates between metal-loss (corrosion) and metal-gain (hardware) Features, and distinguishes between general corrosion and isolated pitting. Paper represents technology overview and field cases history
First Autonomous ICD Installation in Saudi Arabia-Modeling a Field Case
Authors: Al-Kadem Mohammad , AlMuhaish AbduRazzaq , Lee Byung O , Least Brandon 
Published: June 2015

Abstract
Maximizing oil production in horizontal wells is the most critical factor to enhance oil recovery for reservoir management purposes. Technologies in oil industry have been improved dramatically starting the horizontal wells to Extreme reservoir contact wells. However, this drastic improvement has been challenged when water or gas invades the reservoir. Conventional passive Inflow Control Device (ICD) is very excellent technology which primarily aims to balance oil influx over the entire reservoir and hence increase the oil recovery. However, there are several types of ICD in which they work based on viscosity factor. For instance, conventional nozzle type can operate with the reservoir fluids at different viscosities however in contrast, the other type i.e. Helical or channel ICD is dependent on viscosity. Both mentioned types can be functioned properly at early stage of the well production life however problems are encountered when there is water or gas breakthrough. A new generation of ICD is the Autonomous Inflow Control Device. This new type of ICD has the ability to proactively provide additional restriction on undesirable fluids based on viscosity and mobility. It can be operated at different viscosity ranges which confirmed its applicability in any type of reservoirs.
It is good to mention this AICD is going to be tested and evaluated for the first time on three wells in Saudi Aramco. One of the wells is going to be discussed in this paper with the following aspects:
The selection factors for installing AICD on the subject well based on reservoir and field data. Historical production of the well along with major events in terms of water coning issues. Pre-modeling of the AICD completion using NETool™ simulation software. Comparison between Standalone Screens (SAS) and AICD using the NETool™. Verification of field results with NETool™ modeling.
This paper describes the added values of installing AICD technology over the conventional type in heavy oil reservoir in which it maximizes oil production, enhances oil recovery and more importantly delay the water or gas breakthrough with more restriction. This will be thoroughly discussed with the use of the simulation results.
Innovational Techniques in Utilizing Real-Time Downhole Pressure and Distributed Temperature Surveying for Skin Quantification During Matrix Stimulation in Complex Multilateral Well in Saudi Arabia
Authors: Bokhari Noordeen , Ghamdi Talal , Ahmed Ramy , Al-Dosary Abdulrahman 
Published: June 2015

Abstract
This paper describes an innovative workflow for well intervention in a complex multilateral well, not only for accessing each lateral, but also to quantitatively evaluate matrix treatment in real-time for each lateral independently. The quantitative evaluation is based on two simultaneous criterions. The first is derived from the downhole pressure diagnostic plot (pressure transient analysis) in real time using the data acquired by the downhole real time gauge. The second is an estimate of the zonal coverage from the temperature profile plot before, while, and after pumping a treatment. Pressure transient analysis gives the skin as a direct output, and the cooling down/warming up distributed temperature sensing profiles identify where the treatment fluids went into the formation.
This approach of combining well testing analysis techniques throughout the treatment in combination with zone coverage evaluation is strongly recommended for horizontal and complex wells, either clastic or non-clastic rocks. Basically, deriving the skin from the injectivity test (pre-treatment) and the skin from the post flush (post-treatment) will give an accurate as well as confident result when evaluating matrix treatments.
In a field case, a comparison of the formation damage skin before and after the treatment was performed on the spot, and an improvement of eight times in injectivity was achieved with nearly uniform distribution of treatment fluids across five well laterals.
Following the state-of-the-art procedures proposed and executed in this well, we were able to combine different technologies and techniques, which provided measurable cost reduction. The application of the technique will lead to eliminating confusion in accessing well laterals, quantifying the formation damage improvement in real time, eliminating the non-uniform distribution of treatment, optimizing diversion design/placement, and the ability to make treatment changes on the spot.
Use of Wellhead Data for Pressure Transient Analysis for HPHT Gas Wells
Authors: Kabir Akim , Saavedra Sebastian L. , Utaibi Abdullah , Basri Mustafa 
Published: June 2015

Abstract
The idea of using wellhead data for pressure transient analysis is very attractive, as if it is successful it spares us from the need to deploy any type of downhole tools, which are costly and wireline conveyed tools pose various mechanical risks including planting fish in the wellbore. The economics is overwhelmingly in favour for deep and hot wells where wireline intervention costs are high and workovers are expensive. Wellbore storage, presence of a second phase, cooling of the fluid column are some of the major obstacles in making use of wellhead data for pressure transient analysis.
In this paper we describe our experience of Pressure Transient Analysis using wellhead data for some dry gas fields in Saudi Arabia. For most of the cases wellbore storage is not an issue, as we can design the test for a period long enough to get out of that region. We have conducted some pressure build-up tests with gauges at both downhole and wellhead. Then we have converted wellhead pressure (WHP) data to bottomhole pressures (BHP) using the popular Cullender-Smith method and its various modifications. Two phase region and wellbore storage effect have been overcome. However, temperature transient has been found to be the biggest challenge which affects not only the absolute BHP, but also the bottomhole pressure trend which forms the very basis of transient pressure analysis. A thermal decay function was used to model the temperature transient using the initial and final temperature profiles. The resulting calculated BHP trend gets closer to the actual measured data, however differences still remain. Then we spell out a detailed plan to mitigate the remaining uncertainties to make the best use of these wellhead pressure data and obviate the need for running wireline gauges.
Harnessing the Power of Type-2 Fuzzy Logic System in the Prediction of Reservoir Properties
Authors: Olatunji S. O. , Selamat Ali , Abdul Azeez Abdur Raheem 
Published: June 2015

Abstract
The unique power of type-2 fuzzy logic system is harnessed in this work by way of using it to improve the prediction accuracy of permeability and PVT properties in a hybrid intelligent model setting. In this proposed setup, hybridization of type-2 FLS (T2) and sensitivity based linear learning method (SBLLM) is presented and have been shown to considerably achieved improved performance over the constituent models, particularly the SBLLM. SBLLM, as a learning tool, have gained popularity due to its unique characteristics and performance. However, the generalization capability of SBLLM and other neural network based solutions often depend, to a large extent on the characteristics of the dataset, particularly on whether uncertainty is present in the dataset or not. The celebrated unique ability of type-2 fuzzy logic system in modeling uncertainties cannot be overemphasized. In this work, a hybrid system through the combination of type-2 fuzzy logic systems (type-2 FLS) and SBLLM is established, and then use to predict both permeability and PVT properties, which are very germane to the field of reservoir engineering and management; type-2 FLS has been chosen to be a precursor to SBLLM in order to harness the power of type-2 FLS thereby facilitating a means to better handle uncertainties existing in datasets. The dataset first pass through the type-2 FLS for possible uncertainty handling and prediction and then the output from the type-2 FLS is then passed to the SBLLM for its training and testing and then final prediction is done using the unseen testing dataset. Simulations have been carried out, using the built hybrid model, on different industrial datasets, for permeability and PVT properties separately. Results from empirical studies show that the proposed enhanced hybrid system performed better than each of the constituent parts, though the improvement made over that of SBLLM performance is higher compared to that of type-2 FLS, possibly because type-2 FLS is originally adept at modeling uncertainties. Thus it has been established here the huge benefit that could accrue from properly harnessing the power of type-2 fuzzy logic system.