bluuebunny/crossref_metadata_2025_split huggingface dataset:
From Outcrop to Producing Reservoirs: Applying Jal Az Zor Outcrop Studies to A Multi-Disciplinary Development Approach In Kuwait Heavy Oil Fields
Authors: Benham Philip , Cheers Michael J. , Freeman Michael , Choudhary Pradeep , Tanoli Saifullah , Warrlich Georg , Capello Maria , Al-Rabah Abdullah A. 
Published: December 2018

Abstract
The previous generation of integrated reservoir models for KOC's heavy oil fields in North Kuwait brought insight which enable implementation of development decisions. With field maturation, additional well data and emerging production trends drive a need to update models to ensure relevance for serving the evolving business objectives of sustaining and maximizing incremental production.
This subsurface analysis has been augmented through study of the Jal-Az-Zor escarpment (north of Kuwait City) where stratigraphic equivalents of the reservoir crop out. Field analogues permit direct observations of the reservoir characteristics and heterogeneities that influence production behavior and ultimately project economics. They can resolve questions on spatial continuity of the key reservoir flow units by bridging the scale gap between seismic and well data which directly link to OPEX & CAPEX expenditure through optimal well spacing & design, injection steam/water conformance and BSW management.
It is relatively rare to have available such closely linked field-outcrop analogue data which is so readily accessible. The Jal-Az-Zor Escarpment represents an important cost-effective resource which is only just beginning to be leveraged in an integrated way to benefit field development and operations.
Applications for the field observation data set include but are not restricted to: Lateral and vertical continuity/variability of the reservoir, baffle and barrier lithologies.Role of diagenesis and its control on reservoir quality.Recognition of thin but critical units that need to be retained in the model e.g. high (or low) perm streaks.Appreciation of Microscopic to Field scale heterogeneities compared with well spacing.Field to Core/Log calibration to improve interpretationMultidisciplinary engagement
Drilling Through Data: Automated Kick Detection Using Data Mining
Authors: Alouhali Raed , Aljubran Mohammad , Gharbi Salem , Al-yami Abdullah 
Published: December 2018

Abstract
This paper details using advancement in data analytics and the huge amount of data generated while drilling to develop an automated system to detect kicks while drilling. Detecting kicks in early stages gives the crew additional time to control it resulting in a safer and more efficient drilling operation. Five models were developed and evaluated to optimize kick detection they are: Decision Tree, K-Nearest Neighbor (KNN), Sequential Minimal Optimization (SMO) Algorithm, Artificial Neural Network (ANN), and Bayesian Network. The models were trained to detect kicks based on actual kick cases. The models are predicting kicks using only surface parameters such as: pressure gauges, flow meters, hook load, rate of penetration, torque, pump rate, and weight on bit. The performance of the five models is then evaluated and compared. Best two models were Decision Tree and K-Nearest Neighbor.
Implementing WRFM Well, Reservoir, Facility Management and Smart Field Best Practices for EOR Optimization
Authors: Zeidan A. A , Redha Reeham Ali , Williams Darryl D. , Montero Jacobo Enrique 
Published: December 2018

Abstract
Kuwait Oil Company (KOC) is operating two Heavy Oil fields. Field A aims at production by Cyclic Steam Stimulation (CSS), followed by steam flood. Field B envisages primary recovery through cold production, followed by non-thermal Enhanced Oil Recovery (EOR). This requires drilling and completion of large number of wells. Implementing Well, Reservoir and Facilities Management (WRFM) and Smart Field approach will be a key requirement for operation excellence in these fields.
Currently both fields have some wells in production, mostly as single isolated wells or wells in 5-acre/ 10-acre spacing. These pilot projects aimed at de-risking the commercial phase, which is to follow in the coming years. These wells are the training ground for young KOC staff to learn how to work in integrated teams using WRFM processes.
WRFM processes are tailor-made for KOC's operating environment. These processes include Digital Oil Field based on Exception Based Surveillance (to flag out only those wells and facilities outside of their operating envelope and/or optimization window) and Production System Optimization. This would help to eliminate operational bottlenecks, leading to optimization in manpower to deal with large number of wells. It is expected to be achieved by combining existing best practices of International Oil Companies (IOC) with existing KOC applications, leveraging successful global practices.
The paper shall highlight the timeline, activities and organizational changes underway to effect the transformation from existing operation to a larger and more complex development that includes continuous drilling, completion and well intervention (CWI) and facilities installation occurring simultaneously.
The implementation of WRFM Processes along with Digital field will achieve the production and operation goals by reducing well, artificial lift, and facility downtime. This innovative production optimization system by enabling efficient decision-making process shall lower the cost per bbl. and reduce down time by implementing automated surveillance workflow.
An Integrated Approach to Characterize Heavy Oil in Complex Clastics-A Case Study From Southern Part of India
Authors: Chakraborty Srimanta , Panchakarla Anjana , Deshpande Chandrashekhar , Malik Sonia , Singh Majithia Pritpal , Chaudhary Sunil , Murthy AVR 
Published: December 2018

Abstract
Conventional volumetric analysis has its own limitations & challenges to characterize fluid types in complex clastic reservoirs. Presence of shale and radioactive minerals in sandstones makes the evaluation more complicated compared to clean reservoirs as uncertainty become higher to ascertain grain density & total porosity. Delineation of pay zones (heavy oil bearing) & estimation of saturation become more uncertain due to reservoir complexities.
Elemental spectroscopy log can provide real time grain density, TOC (Total Organic Carbon) and mineralogy for complex reservoirs (radioactive sand). However, to determine the fluid type and porosity in this type of reservoir, Nuclear Magnetic Resonance (NMR) would be the best choice due to its capability of recording simultaneous T1 (Spin-lattice relaxation time) and T2 (Spin-Spin relaxation time) including diffusivity measurement sequences. Compare to the traditional 1D T2 spectrum based interpretation methodology; A new approach of using constrained 2D NMR inversion, enhances the capability to discern different fluid phases by mapping proton density as a function of T2 relaxation time (T2int) in the first parameter dimension and diffusion coefficient "D" (or T1 relaxation time or T1/T2app ratio) in the second parameter dimension. An integrated approach is used by combining NMR and Elemental spectroscopy results to reduce formation evaluation uncertainties in heavy oil reservoirs.
Successful integration of NMR, Elemental Spectroscopy Log with Image and Acoustic results helps to understand reservoir properties in study area. The advantage of using constrained 2D NMR over conventional 2D NMR reduces the uncertainty of responses between Clay Bound Water (CBW) and heavy oil, which has similar T2 relaxation mechanism. Integration of Clay volume from Elemental Spectroscopy measurements in constrained 2D NMR helps to differentiate the heavy oil and clay bound water responses. Furthermore, the combination of NMR & Elemental Spectroscopy results helps to segregate the existence of heavier oil & lighter oil components in the reservoir. Based on these results, potential hydrocarbon zones was identified and successful testing attempts were made.
This paper shows an approach of using constrained 2D NMR results over conventional 2D NMR to overcome reservoir uncertainties & to identify potential pay zones.
Risk Assessment in Sand Control Selection: Introducing a Traffic Light System in Stand-Alone Screen Selection
Authors: Mahmoudi Mahdi , Fattahpour Vahidoddin , Velayati Arian , Roostaei Morteza , Kyanpour Mohammad , Alkouh Ahmad , Sutton Colby , Fermaniuk Brent , Nouri Alireza 
Published: December 2018

Abstract
Sand control and sand management require a rigorous assessment of several contributing factors including the sand facies variation, fluid composition, near-wellbore velocities, interaction of the sand control with other completion tools and operational practices. A multivariate approach or risk analysis is required to consider the relative role of each parameter in the overall design for reliable and robust sand control. This paper introduces a qualitative risk factor model for this purpose.
In this research, a series of Sand Retention Tests (SRT) was conducted, and results were used to formulate a set of design criteria for slotted liners. The proposed criteria specify both the slot width and density for different operational conditions and different classes of Particle Size Distribution (PSD) for the McMurray oil sands. The goal is to provide a qualitative rationale for choosing the best liner design that keeps the produced sand and skin within an acceptable level. The test is performed at several flow rates to account for different operational conditions for Steam Assisted Gravity Drainage (SAGD) and Cyclic Steam Stimulation (CSS) wells. A Traffic Light System (TLS) is adopted for presenting the design criteria in which the red and green colors are used to indicate, respectively, unacceptable and acceptable design concerning sanding and plugging. Yellow color in the TLS is also used to indicate marginal design.
Testing results indicate the liner performance is affected by the near-wellbore flow velocities, geochemical composition of the produced water, PSD of the formation sand and fines content, and composition of formation clays. For low near-wellbore velocities and typical produced water composition, conservatively designed narrow slots show a similar performance compared to somewhat wider slots. However, high fluid flow velocities or unfavorable water composition results in excessive plugging of the pore space near the screen leading to significant pressure drops for narrow slots. The new design criteria suggest at low flow rates, slot widths up to three and half times of the mean grain size will result in minimal sand production. At elevated flow rates, however, this range shrinks to somewhere between one and a half to three times the mean grain size.
This paper presents novel design criteria for slotted liners using the results of multi-slot coupons in SRT testing, which is deemed to be more realistic compared to the single-slot coupon experiments in the previous tests. The new design criteria consider not only certain points on the PSD curve (e.g., D50 or D70) but also the shape of the PSD curve, water cut, and gas oil ratio and other parameters.
Satellite INSAR Technology for Cap Rock Integrity Monitoring of CSS and SF Heavy Oil Production Kuwait
Authors: Ren Zu Biao , Al-Rabah Abdullah Akarim , Bansal Prashant , Freudenreich Yann , Rawnsley Keith , Zhang Ian 
Published: December 2018

Abstract
Kuwait Oil Company (KOC) is developing its shallow heavy oil field using thermal method. Top risk of this project is the cap rock failure. If failure occur, it may lead to the steam leakage, overlying aquifer contamination, ground heave or subsidence and surface collapse. For the monitoring ground deformation caused by cyclic steam stimulation (CSS) and steam flooding (SF) thermal operation in Kuwait, InSAR technology is being considered. Interferometric Synthetic Aperture Radar (InSAR) is a remote sensing technique to measure surface heave and subsidence.
First stage of heavy oil thermal development in North Kuwait comprises production from shallow Miocene reservoirs covering an area of roughly 30 square kilometers, by two or three cyclic steam stimulation (CSS) process followed by steam flooding (SF) process. Main reservoirs are the shallow Tertiary un-consolidated sandstone within the measured depth of 650 to 750 feet, sealed off by Up Shale layer that is about 30 FT thick. High pressure and temperature steam will be injected to reservoirs zones, which could result in cap rock breach causing surface heave or subsidence. High-precision and frequent measurements of surface deformation is very important for the study of cap rock integrity.
With the advancement of InSAR technology, millimetric precision of ground deformation measurement is possible. The important factors affecting measurement accuracy of ground deformation is Radar microwave length. The most common of microwave is the L band with 24 cm wavelength, the C band with 4-8 cm wavelength and the X band with 2.5-4 cm wavelength. The choice of wavelength influences the precision. However, there are some other factors which have impact on measurement quality such as spatial density of the measurement points, climatic condition, distance between the measurement points and reference points, number and temporal distribution of acquisitions.
InSAR technology is expected to provide regular surface deformation maps during heavy oil production to monitor the cap rock integrity and to optimize wells and reservoir management. This technology has many benefits, such as reliability, simplicity, low cost, weather independent, minimal field intervention and ability to acquire at night. The absence of vegetation growth in our field area makes this technology very effective. To increase the frequency of data collection and to improve the accuracy of the deformation maps, satellite ascending and descending images are also used. Use of ascending and decending images helps in calculating the vertical and horizontal deformations from the Line of Sight (LOS) measurmemnts.
Hot Dry Air Diffusion HDAD Technology for Lower Fars Heavy Oil
Authors: Al-Bazzaz Waleed Hussien , Abdullah Laila Adnan , Qurban Anfal Naser , Al-Shatti Sharifa Abdul-Samad 
Published: December 2018

Abstract
Lower Fars heavy oil &lt;16 °API is considered a type of conventional heavy oil, which will be considered as priority petroleum production system for future heavy oil recovery in Kuwait. These types of oils are abundant in great amounts in Ratga field North Kuwait, yet expensive to produce due to its high viscosity hence low mobility underground. Kuwait strategy is shifting focus to these types of oils since conventional medium oil and other less-quantitative-light-oil reservoirs are continuously depleting. The study's interest is directed towards a specific type of EOR oil, which is hot dry air sequestration into Lower Fars heavy oil. This study presents novel heavy oil recovery method for 14 °API crude oil using hot dry air as well as their potential recoveries. All recoveries considered for this study are bench-scale laboratory physical experiments with horizontal (0 °), vertical (90 °), and directional (45 °) continuous air diffusion augmented with applied different thermal heat treatments.
The main objective for this research is to model recovery efficiency from this hot dry heat diffusion technique (HDAD). This technique will produce air diffusion design. This design will consider direction of blow diffusion for three possible well orientations: horizontal 0 degrees, vertical 90 degrees, and directional 45 degrees. Also, the design will consider six temperatures: 27 °C 30 °C 60 °C 70 °C 85 °C and 100 °C dry hot air diffusions. Moreover, the design will consider two diffusion velocities 74.08 km/hr and 111.12 km/hr. These velocities will determine designing the time of recovery, which is one hour, according to lab-time limitations and permissions. The main technology motivation for hot dry air diffusion (HDAD) research is finding the optimized economical EOR recovery efficiency factor that will extract most of 14 °API Lower Fars oil. The model determines the recovery potential factor in a classic, optimum and conventional economic scenario considering the energy usage to generate the hot dry air delivered to the reservoir. Also, HDAD technology usages will avoid the use of water technologies recoveries. Avoiding water technology recovery will minimize environmental impact, crude oil/ emulsions subsurface-mobility issues and costly water production management used at current steam economic challenges.
Engineered Hybrid Drill Bit Technology Doubles Drilling Performance in Impact-Prone Carbonates Heavy Oil Application
Authors: Agawani Waleed , Al-Enezi Dakhil R. , Pandya Mehul , Gupta Pravind , Abdelhamid Atef , Al-Habib Hamad , El-Touny Shrief , Ahmed Tausif , Mohammed Jassem A. 
Published: December 2018

Abstract
Optimised drilling performance requires matching the right drill bit technology to an application, which can be an engineering challenge. Hybrid bits provide versatility in drill bit selection that was previously not possible with conventional drill bit technology, allowing for a broader range of applications. This paper details the results of a case study where polycrystalline diamond compact (PDC), tungsten carbide insert (TCI) and hybrid bits were tested in the same application in an attempt to improve drilling performance.
Each drill bit type has its strengths and weaknesses, and is therefore suitably matched for specific applications. Sometimes, a specific technology matches well to the application, and it is the ideal solution; however, there are many cases where the ideal drill bit type isn't so clear. Hybrid drill bit technologies produced a new generation of bits. These bits reduce the difference between specific bit technologies, enabling them to outperform either type in demanding applications that require strengths from each technology to drill successfully.
A non-homogeneous carbonate formation that was prone to causing impact damage challenged conventional drill bit technologies. The 12.25–in. hole section was drilled vertically on a rotary bottom hole assembly (BHA). Initial trials with PDC bits showed that the bits suffered significant impact damage, preventing them from completing the section or reducing their drilling capacity so the rate of penetration (ROP) dropped below TCI performance. The TCI bits drilled relatively slowly, and although they were more durable, they also suffered impact damage.
Hybrid bits were tested on this project to leverage the benefits of each technology and improve drilling performance in this section. This hybrid technology achieved outstanding results in the South Ratqa field. In multiple deployments the hybrid drill bit doubled the ROP compared to conventional technologies. The benchmark performance reached by the hybrid drill bit was triple the ROP of conventional technology. The trial saved the operator up to 3.5 drilling days and more than 70% of the drilling cost for this section.
Investigation Wettability Contact Angle Measurement in Kuwaiti Heavy Oil Reservoir and Modeling Using 2D Imaging Technologies
Authors: Al-Bazzaz Waleed , AlMuddhhi Salah , AlOstath Mohammed 
Published: December 2018

Abstract
Wettability contact angle characterization will be investigated by 2D technologies and a deterministic model is developed. Deterministic approach is a robust technique using 2D image capturing and image analyses that are applied on a Kuwaiti silty sandstone reservoir to accurately quantify, mathematically as well as physically, wetting contact angle trends in the rock sample. And, then, generate all possible pore contact angles. Wettability contact angle quantification utilizes imaging method and recovery model with deterministic systems is a novel approach. Prediction of recovery schemes is crucial for reservoir development and management. Since contact angle initial state is captured and well described, measurement will no longer be random or follow stochastic solution. In this study, heavy oil recovery prediction model is also developed by constructing mathematical model based on statistical grouping and averaging for all measured pore-walls available in the rock sample. Pore parameters such as pore-area, pore-count, and pore-wall and pore shape distribution are all captured and measured experimentally and data can be accurately generated. Previously, contact angle is always based on linear assumptions and its direct quantification is vaguely established. In this study, quantifying wetting contact angle follows morphological approach that has greater confidence.
Polymer Field Development with a Strong Bottom-Up Aquifer in a Field in the South of the Sultanate of Oman
Authors: Alkindi Abdullah , Jabri Reham , Mjeni Rifaat , Gharbi Mohammed 
Published: December 2018

Abstract
Full field polymer flood has been identified as a potential EOR process for a heavy oil field with a strong bottom aquifer in the South of the Sultanate of Oman. A number of surface and subsurface risks have been identified prior to field implementation, including matrix injectivity, polymer sweep and impact of back produced polymer on surface facility & the field wet lands (reed beds). The development of the field will take a place in a phased manner in order to reduce the capex exposure, maximize the utilization of existing facility and managing project risks while contributing to the overall production. In order to support the standardization and steer the future phases the modular facility concept was selected as basis for polymer preparation and injection facilities, this design was made flexible enough to cater for a wide range of possible trial outcomes.
A very comprehensive polymer pilot was performed in this dome-shaped heavy oil reservoir to assess polymer sweep performance as well as losses to the strong water aquifer. An inclusive real-time surveillance programme was executed to monitor key parameters including pressure, injection/production rates, viscosity and water quality, which concluded incremental oil gain from the process. Other tests were conducted to assess the impact of back produced polymer on growth of plants, heater fouling and surface facility separation tanks. In general, all results were positive which paved the way for field-wide development of polymer flooding with less Capex requirement.
A sustained incremental oil gain was clearly observed from polymer injection, which was supported by saturation logs acquired from the observation wells. Injectivity could not be maintained as planned, due to a combination of polymer, biological and water quality issues. Later tests including biocide injection and QA/QC of polymer batches as well as some well stimulation did show improved injectivity profiles. Demulsifier tests mitigated the risk of creating stable emulsions. Lab tests indicated no heater fouling observed below 150°Cdeg. Short and long term investigation into the impact of water-contaminated polymer on plants in the wet lands was positive with the plants showing no necrosis with back produced polymer concentrations up to 500 ppm which is achievable given the excessive amount of water received at the facility level that dilute the back produced polymer. This helped in making the project more economically attractive as it results of a saving of around 30% from the overall project Capex.
The different surface and subsurface tests paved the way for a full field implementation of polymer injection in structures with strong bottom water aquifer. The paper discusses the phasing that was purused to mitigate risks, learn on the go and improve the project economics