bluuebunny/crossref_metadata_2025_split huggingface dataset:
Striving For Production-Injection Balance in a Giant Carbonate Reservoir in North Kuwait: Lessons Learnt, Smart Mitigations & Way Forward
Authors: Al-Shuaib Mariam , Chetri HB , Al-Sirri Dalal , Chong Mizan , Al-Zaabi Hamad 
Published: October 2017

Abstract
North Kuwait is an active asset with Sabiriyah Mauddud as the largest reservoir undergoing development using water flood. Initially with inverted 5 spot; followed by inverted 9 spot and ultimately with Produce High-Inject Low (PHIL) concept, Mauddud had witnessed a continuous testing of as to what is the best strategy to maximize sweep & recovery. The current focus is on striking a balance between production and injection so as to beat the impact of delays in water injection projects.
Several techniques for evaluation of rock, pressure-production; fluid/ PVT; injection water quality; segment reviews; network modelling for producer as well injection network have been either matured to top class stature or initiated with the help of IOC consultants. Out of box solutions to have more injection in needy segments; deferment of drilling of new producers in pressure sink areas; ESP upsizes in segments with excellent pressure support or inversely ESP downsizing in low pressure areas had been the tested options without significantly impacting the trajectory of production build up. Due diligence was conducted to have comprehensive integration & optimization of resources and setting up associated priorities based on the depletion indices, injection efficiency and Voidage replacement trend. Exercise was done to assess the volume of water being re-circulated without sweep benefits so as to mitigate via conformance actions. MOCs have been initiated to fast track injection into the reservoir, even before the major project for water injection facility comes up. Opportunities for aggressive dump flood have been investigated and action plan under implementation. Change in scope from producers to injectors in the drilling plan for 2017/18 & 2018/19 have been proposed for the health of the reservoir.
Sabiriyah Mauddud is the single largest producer of oil in North Kuwait since last 2 years as a result of effective water flood management. Grey areas and gaps, as evident from the present performance and upcoming challenging production targets are quickly being bridged so as to encash the subsurface booty of STOOIP in Sabiriyah Mauddud - SAMA.
Smart Entry into Multilateral Wells with Coiled Tubing Fiber Optic Telemetry
Authors: Coss Gabriel , Cruickshank Doran , Danish Syed , Ambrosi Giuseppe , Garcia Alexis 
Published: October 2017

Abstract
Verifying that conventional coiled tubing (CT) has entered the correct lateral of a multilateral well can be a time-consuming and tedious challenge. While passing the kickoff point (KOP), surface pressure sensors may not clearly identify that a hydraulic knuckle joint has entered the lateral. To verify which lateral has been entered, the CT must be run-in-hole (RIH) to tag the unique total depth (TD) of the lateral. It can be difficult to prove that the correct lateral has been entered if the TDs for two laterals do not differ significantly. If the CT tags before or after the expected TD is reached, then the operator must pull out of hole (POOH) and repeat this process.
This paper presents an improved method for detecting which lateral has been entered shortly after passing the KOP by using a real-time, fiber optic cable (RTFO) bottomhole assembly (BHA). The RTFO BHA is equipped with sensors for gamma radiation (GR), tool inclination, tool face, casing collar locator (CCL), internal and external pressure, and temperature. These readings enable the operator to use the CCL and gamma detector to correlate to the desired lateral’s pipe joints using an existing CCL/GR log. The tool face reading theoretically predicts which angle the knuckle joint should be indexed. The internal pressure sensor provides clear indication of pressure changes when a hydraulic knuckle joint has entered the lateral and the inclination sensor verifies that the inclination of the BHA matches the inclination of the desired lateral.
This paper discusses two dual-lateral water injection wells; the TDs of the laterals in the first well were equal, with no trait that conventional CT would be able to distinguish. In addition, the inclination of each lateral was very close to the other, making the difference of pipe weight, read from the surface, not significantly different enough to verify which lateral had been entered. However, with the RTFO BHA, the correct lateral was easily entered and verified, significantly reducing time, risk, fluids, and CT pipe fatigue, while providing assurance that the stimulation fluid was accurately placed.
This paper describes the first time that a flow-through gamma, inclination, tool face sensor module was deployed to accurately enter, identify, and stimulate a casedhole multilateral well without cycling the CT at the KOP, and without relying on tagging TD to confirm that the BHA is inside the desired lateral. The new process proved to be a better, more cost effective, and efficient way to stimulate multilateral wells. This solution can be used by operators to extend the life of their mature fields.
How to Use Drill String Vibration Data to Reveal Geology Phenomena in Geosteering Jobs: An Application Sensor at the Bit
Authors: Sitinjak Eri Sarmantua , Kurniawan Baladika , Besol Yusuf 
Published: October 2017

Abstract
Drillstring vibration information can be used to define the geology of the well. Some geological phenomena in horizontal wells can be revealed from drill string vibration data. Examples include faults, exiting and entering the reservoir, different lithology and rock strength. This paper aims to gather vibration data from drilled horizontal wells and classify them based on the geological and lithological environment in which they were observed. Uncontrolled vibrations can limit the optimization of drilling performance, for instance increasing the possibility of stuck pipe, affecting wellbore stability, reducing drilling tool life, and causing tool failure. Three major kinds of vibrations result from horizontal drilling; axial vibration, lateral vibration, and torsional vibration. We collect all vibration data and group them to relate the vibration behavior to the geology of the horizontal well. This information can then be helpful in geo-steering. We compare the vibration behavior in different geological situations; for example in clastic and carbonate environments, drilling through changing lithology, exiting the reservoir, and passing through a series of faults.
The objective of this paper is to enable engineers to characterize the vibration data according to potential risk factors that may be encountered during real-time geo-steering, and to take actions that optimize the drilling operation. Observations have revealed a strong correlation between vibration behavior and geological phenomena in the Kuwait oil fields. These observations enable confirmation of a variety of geological features from geo-steering modelling. Furthermore, adjusting drilling parameters and implementing good drilling practice this minimizes the tool exposure to excessive vibrations in order to avoid tool failure, and optimizes drilling operation. An understanding of the vibration data also can be used to help to geo-steer and support the justification for any adjustment in the lateral section. This will not be a proactive adjustment but more of a reactive adjustment. An additional objective is to find the best tool configuration in certain horizontal well environments, thereby improving the drilling optimization and enabling optimum procedures when encountering excessive vibrations. These findings will help drilling to control the well and contribute to the wellbore stability. This will be the first paper to characterize vibration behavior in relation to the geology phenomena in horizontal wells in Kuwait.
Water-Oil Emulsions with Fines in Smart Water Enhanced Oil Recovery
Authors: Arshad Muhammad Waseem , Loldrup Fosbøl Philip , Shapiro Alexander , Thomsen Kaj 
Published: October 2017

Abstract
Smart water flooding is an advanced method for enhanced oil recovery (EOR) in which the composition of injected brine is altered by varying the concentration of selected ions that can increase the oil recovery from various carbonate reservoirs. Besides wettability alteration mechanism, the formation of water-soluble oil emulsions has been reported as a possible reason to explain the observed increase in oil recovery using smart water. The formation of water-soluble oil emulsions takes place on the interaction of insoluble salts (fines) with oils. However, the interaction of these fines with the crude oil is not very well studied for carbonate reservoirs. This work presents emulsion formation in water-oil systems in the presence of water-insoluble fines. The effect of amount of fines on emulsion formation is also examined.
Synthetic seawater (SSW) and deionized water (DIW) were used as water phase, two model oils (decane (D) and 1:1 vol. ratio of hexane-hexadecane (HH) mixture) and North Sea crude oil (NSCO) were used as oil phase, and fines of CaCO3 (≤ 30 µm) and CaSO4 (≈ 44 µm) were used as solid phase. Branson Sonifier® SFX250 was used for emulsion formation (based on the principle of ultrasonic processing). All the experiments were performed for the same conditions of 5 minutes of ultrasonic processing at an output power of 30 W by using 6.5 mm tapered microtip (sonication probe). Emulsion characterization was done by using an optical microscope (Axio Scaope.A1).
Several combinations of water-oil-fines were tested. The tests consisted of control experiments (in which only water-oil without any fines were tested) and water-oil-fines experiments. In the control experiments (without fines), SSW did not show any tendency to emulsify neither with the model oils nor with NSCO. However, DIW showed clear tendency to emulsify with model oils and NSCO. Amongst model oils, DIW emulsified with HH better compared to decane. Similar results were observed in the water-oil-fines experiments. SSW did not form any emulsion with the model oils in the presence of fines of CaCO3 and CaSO4. However, significant amounts of emulsion formation were observed when DIW was sonicated with model oils and fines. HH formed more emulsions compared to decane. For NSCO case, both SSW and DIW formed a significant amount of emulsions with both types of fines (CaCO3 and CaSO4). An increase in amount of fines showed an increase in emulsion formation and a better emulsion stabilization. Sonication is a quick and reliable technique to screen out emulsion formation in different combinations of water-oil-fines.
This work will further develop our understanding of emulsion formation in the water-oil-fines systems.
Chemo-Thermo-Poromechanical Wellbore Stability Modelling Using Multi-Component Drilling Fluids
Authors: Ibrahim Adamu , Akanji Lateef , Hamidi Hossein , Akisanya Alfred 
Published: October 2017

Abstract
This project intends to develop an improved wellbore stability model based on poromechanics and non-equilibrium thermodynamics which describes the physico-chemical interactions between a multi-component drilling fluid and a reactive shale formation. Through finite element modelling, this model can be employed in wellbore stability studies in order to optimise drilling fluid formulation and mud weight selection. Specifically, we present the results of finite-element-finite colume based analysis of thermal and solute diffusion associated with wellbore heating and cooling effect on the reservoir system by drilling fluid over a period of time. Then, we solve the heat driven solute diffusion equation with thermal osmosis and solute diffusion coefficients.
This preliminary investigation indicates a gradual but steady increase in temperature in the near wellbore region during during heat energy disspation from the far-field region. A reverse process was observed during the cooling process with both indicating a constant solute mass fraction over the time limit
Evaluation of a Chemical Enhanced Oil Recovery EOR Application in A Heterogeneous and Low Permeable Oil Reservoir: Advanced Screening by Reservoir Simulation
Authors: Elhajjaji R. R. , Swedan A.. , Behr Aron , Awofodu D. D. , Hincapie R.. 
Published: October 2017

Abstract
The potential of CEOR application in mature oil fields can be investigated using sector models of an appropriate boundary conditions. In this paper, we present an evaluation of feasibility study of surfactant and estimation of the incremental recoverable oil in a mature Libyan oil field assuming the availability of surfactant formulation with optimal performance at reservoir conditions. Overall permeability of reservoir rock is rather low which limits the applicable areas of CEOR applications.
Reservoir properties were characterized using an established optimization approach to define pilot areas that exhibit favorable conditions for chemical EOR flooding. An intensive study was accomplished to generate a sector model of an optimum boundary conditions that provide pronounced results to the Full Field Model (FFM). Typical laboratory data were used to design surfactant model at an ultra-low interfacial tension (IFT) of 10−3 mN/m. Furthermore, main parameters that could influence the results of surfactant model were optimized: flow rates, residual oil saturation (Sorc), correlated Capillary De-Saturation Curve (CDC), adsorption, and grid size effect.
Interstitial velocity of displacing fluid and capillary number were correlated to describe the effect of permeability variation on the ultimate residual oil saturation. Additional recovery by surfactant at current reservoir conditions appeared to be strongly affected by changing the correlated CDC. The estimated macroscopic efficiency of surfactant by the coarse and fine grid models indicates that the surfactant is being smeared in the coarse model, and consequently different pressure distribution in both models was observed after certain time of injection. Moreover, the predicted results illustrate the influence of any heterogeneity feature in reservoir properties on both microscopic (ED) and macroscopic (EV) sweep efficiencies of CEOR flooding.
In Addition to the lessons learned of proper simulation at field scale, a developed approach to evaluate the potential of CEOR at challenging reservoir conditions is introduced in this paper.
Application of Value Engineering and Life Cycle Costing Techniques for Offshore Topside Facility Projects: Towards Sustainability
Authors: Al-Yafei Ezeldine , Ogunlana Stephen , Oyegoke Adekunle 
Published: October 2017

Abstract
Most existing studies and literature show that both value engineering and life cycle costing concepts are not used in the upstream sectors of oil and gas, in particular in offshore brownfield projects. This paper will highlight the importance of applying these concepts at the conceptual stage of offshore topside facility projects in order to achieve quality at the lowest possible cost over the product design life, as well as considering the aspect of sustainability. The value engineering methodology and life cycle costing analysis stages are presented.
The paper presents four alternatives for structural materials to demonstrate the optimal solution from value engineering and life cycle costing concepts. The case application focused on steel grating as the traditional material used in offshore platforms, versus glass reinforced plastic (GRP) and aluminium gratings as new alternative materials. This method will provide the end users with an effective tool to select among competing alternatives.
This paper attempts to fill the gap in the existing knowledge in the upstream sector of the oil and gas industry, focusing on topside facility projects for offshore platforms by contributing to the following areas: applying value engineering and life cycle costing concepts to offshore topside projects at the conceptual and/or design stage.
Application of Noise and High Precision Temperature Logging Technology to Detect Tubing Leak in an Oil Well - A Case Study
Authors: Jalan Shiv Narayan , Al-Haddad Saud , Ali Shareefa Mulla , Al-Hamli Dalal , Prosvirkin Sergey , Aristov Sergey 
Published: October 2017

Abstract
Leak in well bore tubulars & packers leads to communication between tubing/casing or Short/Long strings thus causing enormous production losses in Oil & Gas industry. Moreover, it can cause cross flow between different reservoirs. Sometimes leak may lead to charging of shallow formations thus posing a big threat to well integrity. The detection of the source of communication presents a big challenge to the industry. Knowing the precise location of a leak helps in designing an effective remedial action thus reducing downtime and repair costs.
When a fluid leaks, it moves from the high-pressure side through the leak point to the low-pressure side, where it expands rapidly and produces a turbulent flow creating noise and temperature changes. Conventional noise and temperature tools are not capable of detecting the leak point with high confidence. However, the new generation Noise and Temperature logging tools have been able to locate such leaks precisely.
This paper presents successful use of Spectral Noise Logging in combination with High Precision Temperature logging (HPT-SNL) in a dual-completion oil well in Kuwait Oil Company for identifying communication between the long and the short tubing strings. The acoustic tool contains a new-generation, high-sensitivity hydrophone – a piezo crystal element that records noise in a wide frequency range (0.1 – 60 kHz). Temperature tool utilizes a super-sensitive platinum sensor with a response time of less than one second. Leak was detected at the bottom blast joint of the long string that was causing water entry into the short string thus killing the well. The technology can be used in critical oil and gas wells to identify tubing and casing leaks and address well integrity issues. It can also be used in water injection wells to identify the zones of water intake.
Application of Memory Concept on Petroleum Reservoir Characterization: A Critical Review
Authors: Miah Mohammad Islam , Deb Pulok Kanti , Rahman Md. Shad , Hossain M. Enamul 
Published: October 2017

AbstractPetroleum reservoir rock and fluid properties vary during any pressure disturbances or thermal actions in the reservoir formation. It is important to consider the rock properties such as permeability, porosity, etc. and fluid properties such as viscosity, PVT properties etc. as a function of time for applications including geothermal actions, chemical reactions, and other geological activities in the sub-surface of the reservoir complex structure. Memory is the effect of past events on the present and future course of developments. The continuous alteration of rock/fluid properties can be characterized using memory concept. It is also significant to consider the rock, and fluid properties as a function of time, and the inclusion of recently introduced memory concept in petroleum engineering study. In this paper, a detailed review of the existing techniques and models of reservoir characterization is presented. This study will provide an inclusive information on the present status of memory-based fluid flow modeling, rock and fluid properties models development under spurious assumptions during reservoir characterization. The variations of porosity and permeability over the distance are presented which are from the wellbore towards the outer boundary of the reservoir with time in actual reservoir conditions. Reservoir porosity and permeability are directly related to the reservoir formation depth and pressure. Reservoir porosity and pressure are decreasing over time. Permeability is changed over distance because it is directly related to the pressure of the complex reservoir system. In addition, the viscosity is a function of temperature of crude oil. Since memory-based diffusivity equation through porous media is more rigorous, as it incorporates continuous alteration of rock and fluid, and viscosity of oil predicts results from memory models should be preferred and reliable during the convergence process in reservoir simulators. This paper also aids as an insight of the future research opportunity toward developing models for reservoir properties, and models for fluid flow through porous media in the complex reservoir by the application of memory concept.
Winter Wheat Yield Prediction Using Normalized Difference Vegetative Index and Agro‐Climatic Parameters in Oklahoma
Authors: Zhang Ning , Zhao Chen , Quiring Steven M. , Li Jinlin 
Published: October 2017

Core Ideas
Normalized difference vegetative index has a stronger correlation with yield than moisture and temperature indices.
Optimal winter wheat model includes normalized difference vegetative index, moisture and temperature variables.
All three variables have different periods during which they are important.
Model can accurately predict winter wheat yield one month before harvest.
Gridded data outperform station‐based data for county‐level yield prediction.
This article develops a model for predicting winter wheat (Triticum aestivum L.) yield variations in Oklahoma, based on vegetation, moisture, and temperature conditions. A common model structure is identified using stepwise regression with one vegetation indicator (normalized difference vegetative index, NDVI) during wheat jointing and anthesis stages (March and April), one moisture indicator at emergence period (October and November), and one temperature indicator (temperature index, TI) at emergence, jointing and anthesis stages (October, March, and April). The final model accounts for ∼70% of the variation in winter wheat yield and can be used to forecast yields 1 mo before harvest. Spatially, it performs best in the northern and central portions of the Oklahoma winter wheat belt. Model performance is similar regardless of which moisture index is used. The correctly predicted yield variations in at least 9 of the 14 counties every year, and in the best case it correctly predicted yield variation in all counties. Our results also demonstrate that the gridded meteorological data generally outperforms the station‐based data for yield prediction at county level. The methods used in this study can be applied to identify the most significant variables and growth stages for winter wheat yield prediction in other regions.