bluuebunny/crossref_metadata_2025_split huggingface dataset:
Urban Planning in North Kuwait: Collaborating Across All Assets to Optimize Developments and Exploit Synergies
Authors: Warrlich Georg M. , Al-Dohaiem Khalid , Al-Boloushi Ahmed , Abdelrahman Hesham , Kumar Vaidyula S. , Al-Rashdan Saad , Schrameyer Sandor , Cheers Mike , Hulshof Bart , Al-Haqqan Hamad , Reijnders Gert Jan , Al-Rabah Abdullah 
Published: December 2018

Abstract
The Northern part of Kuwait is a highly active development area for deeper gas, intermediate-depth conventional oil and shallow heavy oil. All these developments have overlapping footprints in an already congested area, requiring different development concepts for gas, water flood and steam respectively. Additionally, different Assets manage the respective reservoirs. Integrated Urban Planning across all Assets therefore becomes a vital requirement for realizing all concurrent future developments regarding land use, and enabling close collaboration to leverage synergies among the Assets, utilizing both organizational and new technology-based solutions, in order to maximize value for Kuwait Oil Company (KOC).
In North Kuwait Urban Planning is a joint effort between KOC and Shell, with initial focus on establishing an agreement for work methods, effective communications, and protocols with all stakeholders. Next all "as-built" infrastructure and current plans were combined and reviewed. This formed the basis to identify and resolve conflicts, recognize opportunities for reduced land requirements and optimize the development synergies. The approach is underpinned with new technologies, tools, best practices, and concepts like multi-well pad developments, area discounting, exclusion zones, and shared infrastructure and road access corridors, based on global analogue developments.
In this paper example field ‘A’ is discussed as it has stacked reservoirs of shallow heavy oil, intermediate conventional oil and deep, sour gas. It requires significant urban planning focus to avoid conflicts and enable synergies. In field A, the shallow heavy-oil development requires large number of wells in a dense well-spacing versus fewer wells targeting the intermediate-depth conventional oil and deeper gas reservoirs, which requires large "safety zones" around well sites. In both cases, common infrastructure like roads, power distribution, flow line and trunkline corridors also need to be considered jointly.
Urban Planning collaboration between assets with distinct development challenges can help in creating safe co-development opportunities, thus maximizing value for KOC.
Evaluation of the Scaling Resistance of Different Coating and Material for Thermal Operations
Authors: Fattahpour Vahidoddin , Mahmoudi Mahdi , Roostaei Morteza , Cheung Stephen , Gong Lu , Qiu Xiaoyong , Huang Jun , Velayati Arian , Kyanpour Mohammad , Alkouh Ahmad , Strom Raymond , Fermaniuk Brent , Zeng Hongbo , Luo Jing-Li 
Published: December 2018

Abstract
Several alloys and coating techniques have been used by industry for their anti-corrosion and anti-fouling properties in the industry. One of the major problems in thermal operation is related to silica and calcium carbonate scale. In this study, we intend to better understanding the relative scaling resistance performance of different coatings and alloys exposed to typical formation water in thermal operations. This paper provides a study on failed samples collected from various projects in Western Canada. Moreover, a review of research work on scaling properties of different materials in thermal applications will be presented.
Different failed screens were collected from various projects in Western Canada. Thin section analysis, X-ray diffraction (XRD), scanning electron microscopy (SEM) joined with energy dispersive X-ray spectroscopy (EDX) were performed on collected failed pipeline samples to determine the composition of the scale material. Obtained results revealed that the main scaling materials are silicates and carbonates. Chert, clays and carbonates act as cement to bind sand grains (mainly quartz).
Later, a review was performed on an ongoing investigation regarding the materials and coatings for improving the anti-scaling properties. Bulk scaling tests, Atomic Force Microscopy (AFM), and in-situ field trials were used to investigate the anti-scaling properties of two RGL proprietary grade materials, proRC05, and proRS06, as well as electroless nickel (EN) coating. Carbon steel L80, carbon steel 4140 and EN30B alloy steel were used for comparison. The microstructural change of the material surface was studied using complementary techniques (e.g., XRD, SEM, and EDX). The tests have been performed under a complex chemical environment that represents the chemistry of the near screen condition in thermal operation, to assess the relative performance of different coatings. Among proRC05, proRS06, 4140 carbon steel and EN30B alloy steel, the anti-scaling performance follows the order of proRC05 &gt; proRS06 &gt; 4140 carbon steel &gt; EN30B alloy steel. Comparison between EN-coated and uncoated samples shows that the EN-coated carbon steel L80 provides better anti-corrosion and fouling resistance performance with a small amount of iron oxides and silica foulants. Field trials of EN-coated technology have been also proven to be effective.
This work provides a detailed review on recent attempts on evaluating the anti-scaling properties of various materials and coatings to minimize the silica and calcium carbonate scale. Furthermore, field trials were reviewed for evaluating the scaling and corrosion properties in thermal production. The results of this study will help engineers select material for projects in which silica and calcium carbonate scaling could be a significant issue.
Designing of a Groundwater Production Scheme for the Northern Oil Fields, Kuwait
Authors: Al-Enezi Huda , AlMuhaimeed Imad , Al-Mutairi Meshaal , Al-Senafi Mohammed , AlKhalid Asem , AlFahad Khalid 
Published: December 2018

Abstract
The Kuwait Oil Company's (KOC's) future development plans propose an increase in the production and utilization of groundwater reserves in the northern oil fields, where new groundwater gathering centers are to be constructed for water handling processes. In order to preserve the natural resources of the country, and realizing the fragility of the fresh/brackish/saline coexistence in the groundwater resources of northern Kuwait, the Water Research Center (WRC) of the Kuwait Institute for Scientific Research (KISR) conducted this study on behalf of KOC. The main objective of the project was to design, locate and set a production schedule of groundwater wells to produce 10,000 m3/d with salinity less than 10,000 mg/l for a specific period of time. This study will enhance the potential of utilizing brackish water at the project area while maintaining minimum mixing between brackish and saline groundwaters. To fulfill its objectives, this study conducted data collection followed by designing and constructing several production and observation wells that were used for a program of pumping and recovery tests. During this field work, a campaign of groundwater sampling and water level measurements were conducted. The water samples were analyzed in the appropriate laboratories for physical, chemical, and biological parameters according to international standards. Then, another stage of numerical modelling took place to simulate the movement of saline and brackish waters putting all the newly drilled wells into operation. The results showed that it is possible to extract 10,000 m3/day from the project area with a salinity ranging between 3,500 and 10,000 mg/l indicating brackish water quality. The groundwater in the study area is of sodium chloride and sodium sulphate type, and no organic contamination of groundwater was detected in the study area. However, the study also shows that it is not possible to extract water from certain locations because the salinity will be elevated above the design limit of 10,000 mg/l.
Wellbore Trajectory Optimization Using Rate of Penetration and Wellbore Stability Analysis
Authors: Abbas Ahmed K. , Alameedy Usama , Alsaba Mortadha , Rushdi Salih 
Published: December 2018

Abstract
Drilling deviated wells is a frequently used approach in the oil and gas industry to increase the productivity of wells in reservoirs with a small thickness. Drilling these wells has been a challenge due to the low rate of penetration (ROP) and severe wellbore instability issues. The objective of this research is to reach a better drilling performance by reducing drilling time and increasing wellbore stability.
In this work, the first step was to develop a model that predicts the ROP for deviated wells by applying Artificial Neural Networks (ANNs). In the modeling, azimuth (AZI) and inclination (INC) of the wellbore trajectory, controllable drilling parameters, unconfined compressive strength (UCS), formation pore pressure, and in-situ stresses of the studied area were included as inputs. The second step was by optimizing the process using a genetic algorithm (GA), as a class of optimizing methods for complex functions, to obtain the maximum ROP along with the related wellbore trajectory (AZI and INC). Finally, the suggested azimuth (AZI) and inclination (INC) are premeditated by considering the results of wellbore stability analysis using wireline logging measurements, core and drilling data from the offset wells.
The results showed that the optimized wellbore trajectory based on wellbore stability analysis was compatible with the results of the genetic algorithm (GA) that used to reach higher ROP. The recommended orientation that leads to maximum ROP and maintains the stability of drilling deviated wells (i.e., inclination ranged between 40°—50°) is parallel to (140°—150°) direction. The present study emphasizes that the proposed methodology can be applied as a cost-effective tool to optimize the wellbore trajectory and to calculate approximately the drilling time for future highly deviated wells.
Cost Optimization Study of Soak Period and Production Cycles of Cyclic Steam Injection in Lower Fars Heavy Oil LFHO Reservoir
Authors: Alshammari Awadh T. , Alajmi Haifaa M. , Marquez Sharoh G. , Farhart James L. , Al-Otaibi Faisal S. 
Published: December 2018

Abstract
The cyclic steam stimulation (CSS) and injection process is a thermal recovery process consisting of three main stages: steam injection, steam soak and production of the heated oil. Before a stimulated well is put into production, a soak period is required to allow the injected steam to heat the oil around the wellbore and reduce its viscosity so that it will become more susceptible to flow. In actual operations, the soak period could vary from days to weeks, or even months. Prolonged soak period causes the well productivity to decline because of the continuous heat loss to the formation. On the other hand, insufficient soak period prevents effective transfer of the heat from the wet steam into the formation. For this reason, it is desirable to determine the optimal soak period that will maximize oil production and net profit during cyclic steam injection. The injection period at the beginning of the cycle, as well as its ensuing production period is also investigated to verify which stage in the CSS process is most influential in assuring higher recovery.
In this study, a thermal, numerical reservoir oil simulator is utilized to evaluate the effect of varying the injection volume, soak period and production period with a view to improving crude oil recovery in Ratqa-North Kuwait Lower Fars Heavy Oil (LFHO) reservoir. Further economic studies are then pursued to determine the effectiveness of cyclic steam injection operations whilst maintaining a safe operational environment ensuring cap-rock integrity and also avoiding localized pockets of higher pressure and temperature (heaving).
The key findings from this study was that the maximum injection period (60 days), minimum soak period (5 days) and minimum production period (90 days) are required for every cycle, in order to maximize recovery and optimize the cost.
The Function of Baffles within Heavy Oil Reservoir and their Impact on Field Development: A Case Study from Kuwait
Authors: Benham Philip , Freeman Mike , Zhang Ian , Choudhary Pradeep , Spring Laurent , Warrlich Georg , Ahmed Khalid , Shen Chonghui , Sanwoolu Ayodele , Jha Madan , Al-Haqqan Hamad , Al-Boloushi Ahmad , Al-Rabah Abdullah 
Published: December 2018

Abstract
A heavy oil field (Field X) in Northern Kuwait is in the early stages of development but it is clear from production pilots that tight units (baffles) of variable lithology, thickness and continuity, within the reservoir will play a key role in influencing steam conformance and recovery efficiency. The high well/core density of the field’s production startup area allows re-evaluation of baffles in light of cross-discipline integration of pilot production data, petrophysical data and detailed core review.
A process was followed to update and calibrate all core descriptions against logs, follow a consistently picked set of petrophysically defined markers, compare visually defined lithofacies with log defined ones, and then map out key surfaces. The key next step is to define appropriate reservoir properties by facies/rock types, apply these to understanding pilot behaviour and predict steam conformance for Well, Reservoir and Facilities Management (WRFM) and the next phases of the wider field development planning. The field’s baffles play a role far beyond just understanding steam conformance, they are a first barrier for cap rock integrity and their presence/absence will also influence the path and rate of the aquifer influx.
The petrophysical redefinition (Baffle Quality Index) of a "semi-stratigraphic" interval - which will stop or slow steam migration depending on its quality and lateral extent - has enabled efficient communication about the baffle, and allowed the wider team of petroleum engineers from a number of subsurface disciplines to focus on dynamic properties impacting recovery – steam conformance, aquifer influx, windows between isolated reservoir units – and then evolve the development strategy, effectively respond to WRFM issues, optimize observation and infill well placement and increase UR in a cost effective way.
Sand Production Assessment & Sand Control Selection for Steam Flood in South Oman
Authors: Al Shizawi Wafa , Al Zadjali Ruqaiya , Mahajan Sandeep , Bellmann Lars 
Published: December 2018

Abstract
A thermal steam project has been successfully implemented in a Petroleum Development Oman (PDO) field in the South of Oman. The thermal project developed the crest of the field which has mainly formation A. The thermal response has been favorable as witnessed by the incremental oil recovery. The steam flood is now planned to be expanded further to the South where it will encounter the same formation as currently developed at the crest & to the North where it will encounter two new formations (B & C). The new formations have limited field data on sand production; therefore a sand prediction evaluation for both cold & thermal production conditions is required for these new formations. In this paper we describe the analysis of the sand control potential and the selection process of the sand control technology.
The assessment of the potential for sand production and the requirement for sand control was based on a combination of a) actual field data such as sand production, well performance & completion data; and b) a sand prediction model for the hot and cold operating production conditions utilizing rock-mechanical data. In addition, core sieve analysis data were used to determine the Particle Size Distribution (PSD), which was used to select the sand control type and screen slot width.
The sand evaluation study demonstrated that for formation A has only the probability of transient sand failure under hot operation conditions. The wells will therefore be completed without sand control. On the other hand, formations B & C have a risk of catastrophic sand failure under both cold and hot operation conditions. A completion with thermally compliant sand control is a must for formation B. In case of formation C the selection of sand control is challenging as the sand distribution shows a high percentage of fines. In this case sand control is obtained through selective perforation, excluding the sand prone intervals. The impact of blanking the high GR intervals on inflow is expected to be low as the average the permeability for these intervals is low.
The implementation of the selected Stand Alone Screens for sand control in formation B will be the first thermal application of these screens in PDO.
Sand Control Strategy for Unconsolidated Sandstone Heavy Oil Reservoir in Kuwait
Authors: Reda Mahmoud , Erhama Abdulaziz , Henderson Kerry , Al-Mulla Yousef , AlMuhanna Tamadhor 
Published: December 2018

Abstract
Production deferment due to wellbore sanding issues is a major risk for heavy oil field development. The heavy oil reservoir in Kuwait is a multi-stacked unconsolidated formation, which is prone to sanding. Currently there are two steam flood pilots in inverted 5-spot pattern configuration with pattern areas of 5 and 10 acres. The wells were operated for two cycles of Cyclic Steam Stimulation (CSS), before their conversion to steam flood.
Different Sand Control equipment is field tested in some pilot wells to optimize production in this viscous oil-saturated unconsolidated sandstone reservoir. This paper will discuss the operational challenges and the difference in the performance of cold production and after thermal CSS cycles of the installed Stand-Alone Sand Screens (SAS), which were retrofitted in the pilot wells. The mesh size of the SAS was designed based on the particle size distribution and well operating condition.
A comprehensive reservoir and well surveillance program was conducted to monitor and gather necessary data to characterize the reservoir and well performance in the pilot wells equipped with sand control equipment. The primary objective was to determine the optimal sand control strategy, moving forward in to the commercial phase of field development.
This paper will discuss the learnings from the pilot wells. The various SAS used were partially successful in mitigating sand production. More piloting with advanced sand controlling technologies at both laboratory and field levels may be required to reach to the optimum design for the field-specific cases.
The well trials using SAS was mainly to assess the screens regain permeability (skin) versus crude oil production while minimizing sand movement within the wellbore. This helped to improve the artificial lift pump run life and minimize sand debris from entering the pump.
Reducing Operating Costs through Accurate Measurements
Authors: Marshall Craig 
Published: December 2018

Abstract
Heavy oils are characterised depending on their density rather than their viscosity [1]. Although there are various definitions for what constitutes heavy oil it is commonly agreed that the majority contain impurities such as asphaltenes, waxes and carbon residue. The API gravity definition, a common definition used in the oil and gas industry worldwide, states that heavy oil has an upper limit of 22°. Figure 1 shows the upper and lower limits of various categories of oil as stated in the API gravity definition.
Confirmed world oil reserves are split approximately into 70% high viscosity and 30% (low viscosity) conventional light oils. High viscosity oils are regarded as a vital energy resource for the foreseeable future, with significant yields forecast at 100 years or more.
A literature review conducted by NEL and Oxford University highlighted the issues facing application of conventional flow meters to high viscosity fluids [2]. Following on from the review, an initial experimental test programme [3] was instigated using a selection of conventional flow meters applied in viscous fluids. The overall conclusion from this work reinforced the notion that liquid flow meters cannot simply be relocated from low to high viscosity service without suitable characterisation or modification, nor can calibrations conducted in a low viscosity medium necessarily be applied to heavier crudes without appropriate compensation.
A Feasibility Study of Hybrid Thermal and Chemical EOR Methods in a Low-Permeability Carbonate Heavy Oil Reservoir with Strong Aquifer Drive
Authors: Al-Murayri Mohammed Taha , Fadli Eman Hadad , Al-Shati Fawziya Mohammad , Qubian Ali , Li Zhitao , Trine Eric , Alizadeh Amir H. , Delshad Mojdeh 
Published: December 2018

Abstract
KOC's Umm Gudair/Abduliyah Tayarat reservoir has large oil reserves but is a challenging target due to low formation permeability and high oil viscosity. This study is focused on feasibility assessment of hybrid thermal and chemical methods incorporating both laboratory and simulation results.
A recent updated static geological model for West Kuwait fields was used as the basis to generate a full-field dynamic reservoir model with representative reservoir geometry, heterogeneity, and complexity. Carter-Tracy aquifers were added to model lateral and bottom aquifers. Laboratory data were incorporated to model physiochemical properties. Gridblocks were globally refined to gain better resolution for heavy oil and EOR simulations. The full-field reservoir model was used to systematically study the potentials of hybrid thermal and chemical EOR methods in comparison with conventional waterflood and chemical EOR methods.
Our studies show that in order to produce oil at an economic rate, long horizontal wells on the order of kilometers or horizontal wells stimulated by acidizing, multistage fracturing, or multiple laterals should be deployed. Vertical wells yield low oil production rates due to limited contact areas and severe water coning. Aquifer water intrusion from the west side of reservoir overshadows the bottom aquifer and the edge east side aquifer due to the heterogeneity of reservoir permeability. A sector model was extracted from the full-field Eclipse model and further refined to avoid grid effects in simulation of EOR processes. Simulation results show that hybrid thermal and chemical methods (hot polymer/Surfactant-Polymer/Alkaline-Surfactant-Polymer flood) can effectively increase oil recovery from high-permeability, high-saturation sweet spots of the Tayarat reservoir. With the help of horizontal wells, hot polymer flood shows the best performance after 20 years of oil production and yields more than 30% of incremental oil recovery. Hot Surfactant-Polymer flood shows slightly lower cumulative oil recovery but sustained oil production rates and less production decline in the late stage of the flood. Phase 2 coreflood experiments confirmed that hot polymer flood can effectively enhance oil recovery.
In summary, this research study identified sweet spots for oil recovery and EOR applications in the challenging Tayarat reservoir and demonstrated the potential of producing significant amount of oil with appropriate IOR (e.g., extended reach horizontal wells, multistage fractures, stimulation, etc.) and EOR (e.g., hybrid thermal and chemical methods) techniques.