bluuebunny/crossref_metadata_2025_split huggingface dataset:
Limitation of EOR Applications in Tight Oil Formation
Authors: Mansour Ahmed , Gamadi Talal , Emadibaladehi Hossein , Watson Marshall 
Published: October 2017

Abstract
Tight oil reservoirs have become one of the main forces of oil production growth in the USA. Only 3% to 7% of the oil can be recovered under primary depletion. Further improvement in oil recovery in tight oil reservoirs can be achieved by applying gas flooding or huff ‘n’ puff. However, these methods have limitations, especially when dealing with ultra-low permeable formations. Hence, the objective of this study was to discover the limitations of EOR methods in tight formation.
A 2D compositional simulation model was used to investigate the limitations of applying gas flooding and huff ‘n’ puff in a tight formation. The results were compared under distinct scenarios and conditions. Distinct values of well spacing were used to identify the optimal well spacing. Different average permeability values were used to study the effect of permeability value on the EOR performance in tight formation.
The Simulation Model results showed a potential of applying EOR in tight formation under specific conditions. Well spacing optimization has a significant effect on the gas flooding performance in tight formations. Hence, it is recommended to identify the well spacing before commencing gas flooding or huff ‘n’ puff. This simulation study showed any formation with a permeability less than 0.01 md should not be considered for gas flooding due to gas injectivity issues, long injection time, and long depletion time. Huff ‘n’ puff showed better results and more oil recovery at a permeability less than 0.01 md. Simulation results showed that any formation with a permeability greater than 0.1 md may be considered for gas flooding because of the following reasons: gas flooding showed a better recovery factor compared to the huff ‘n’ puff method; short depletion time was needed to start gas injection; and gas flooding required less injection time and provided long well spacing.
This study increases understanding of the EOR factor in a tight formation. The results of the study showed the limitations of the EOR using simulation approaches. Knowing the disadvantages and limitations of EOR in tight formations will lead to improving the efficiency of EOR in tight formations.
De-Risking Chemical EOR Pilot in a Giant Carbonate Reservoir of Kuwait During Pre-Pilot Phase
Authors: Tiwari Sanhita , AlAbdullah Mohammad , Al-Dhuwaihi Abdulaziz , Al-Ajmi Moudi 
Published: October 2017

Abstract
Encouraging results from Lab, simulation studies and single well pilot tests (SWCT tests) using ASP flooding provided confidence to conduct multi well pilot test. A confined, normal 5-spot pattern CEOR pilot is planned. SAMA performance over its waterflood life of 17 years has highlighted reservoir heterogeneity in terms of rock and fluids. The paper describes activities performed during pre-pilot phase of drilling 7 pilot wells to de-risk the complexities expected in this carbonate reservoir.
Drilling of 7 close spacing vertical well within 5 acre required proper planning and drilling sequence. Out of the seven wells, four corner wells are drilled as injectors and center well as producer. Two observation wells within the pilot area include a sampling well and the other completed with fiberglass casing as a logging well. Data acquisition from coring, formation pressure measurement, sampling, H2S measurement and logging is meticulously planned and quality checked.
The main objective of this CEOR pilot is to field test the efficacy of the ASP formulation prepared in the lab. This pilot scale testing would help a better risk assessment and estimate of incremental oil gain due to this technology application. Field-wide implementation of this technology in Sabiriyah Mauddud and other reservoirs in NK will depend on the success of this CEOR Pilot. All 7 EOR pilot wells were successfully drilled despite many challenges using industry’s best practices. Enormous good quality data was generated during drilling of these wells which will aid in understanding the complexity of reservoir within small pilot area and help in implementation of Chemical EOR in Sabiriyah Mauddud reservoir. All the information generated during pre-pilot will be utilized for starting up this CEOR pilot.
EOR in carbonate reservoir has been a challenge for the oil industry. These challenges and related risks are mostly attributed to the complexity of reservoir description. Good quality wells and exhaustive information generated during pre-pilot phase did provide valuable insights to de-risk and ensure proper implementation of the Chemical EOR pilot project in a carbonate reservoir which will be a harbinger for North Kuwait’s efforts to exploit EOR reserves.
Reaping The Benefits of the Mega Water Flood Project in North Kuwait - Production Enhancement Opportunities Tracking & Implementing
Authors: Saleh Nada , Chetri Hom , Al-Twaitan Tasneem , Al-qenae Amna 
Published: October 2017

Abstract
Sabiriyah Mauddud and Upper Burgan are two of the giant reservoirs in North Kuwait(NK) under active water flood since 2000. About 400 MBWPD of water is currently being injected to maintain the reservoir pressure & improve the production/recovery. A comprehensive workflow process was developed and implemented to understand the waterflood performance, pressure-production response trends and map the opportunities to encash the benefits in terms of quick oil gains. The paper discusses the best practices adopted to increase production from two of the water flooded reservoirs in NK.
Sound workflow process was created by integrating the technical inputs under collaborative environment from subsurface & surface teams. Series of segment reviews are conducted to understand the connectivity between producers & injectors, duly integrating all surveillance data. Analytical diagnostic tools have been used to distinguish between the good water and bad water and improve the VRR & sweep. Live ESP data is monitored and tracked at intelligent field collaboration centre to decide about the actions for the wells requiring ESP upsizing, downsizing and VSD/choke optimization. Wells with running ESPs were identified for VSD & choke optimization, using rationalized technical criteria. Wells with failed ESPs are reviewed for smart replacements with water shut off/water flood conformance & ESP re-design. Simultaneous actions for the well model creation; running sensitivity and scheduling in the workover rig are taken up.
ESP upsize, along with VSD installation/choke optimization, was implemented in number of wells with significant oil gain (about 11% enhancement within a short time frame). As a part of the process established, this activity has become a regular practice in NK. Such wells are under constant monitoring so that water injection actions in nearby injectors, if needed, could be taken up such as allowable management, arresting the declining trend etc. The benefit of mega water flood activities have been reaped in terms of production enhancement adhering to the best reservoir management practices.
Quick understanding of the Water flood response and relignment of actions on the associated wells via rigless and rig workovers is the key to the success for significant ramp of the NK production within a short time window of 6-7 months. Several work flow processes established during the campaign are now deeply imbeded within NK asset.
Decision-Based Modeling: Linking Subsurface Modeling Strategies to Business Decisions in KOC's Viscous Oil Field Developments
Authors: Al-Dohaiem Khalid , Warrlich Georg , Cheers Mike , Reijnders Gert-Jan , Jha Madan , Bagheri Mohammad Ali , Saikia Pabitra , Zhang Ian 
Published: October 2017

Abstract
When developing and operating oil and gas fields, a large number of engineering decisions need to be taken. These decisions range from the very high-level such as recovery mechanism, facility sizing or well count to more detailed decisions such as individual well placements, well design and completion strategies. Typically, subsurface models play a role in informing these decisions by testing their effect on forecasted production and it is generally held best practice to test them against a wide range of subsurface conditions, a range that expresses the envelope of subsurface uncertainty. Whilst these commonly held objectives are more or less universal, selecting an appropriate subsurface modelling strategy (i.e. what to model & how to model it) to achieve these objectives usually generates more divergent views. Whilst there are always various valid modelling approaches available which are both geologically and numerically valid, a good modelling strategy pays close attention to the type of the specific decisions being taken for the project and the accuracy required to take those decisions.
To align these views, in decision-based modelling, business decisions and their timing were mapped to the models needed to make the estimates that inform them. Dialogue between the disciplines established the accuracy required for these estimates, and these discussions often revealed surprising opportunities to simplify processes and accelerate delivery. The outcome is a common view on a decision-driven modeling strategy that enables business decisions to be taken efficiently. This strategy, and the subsequent delivery plan that is developed from it is seen as a key to success.
This paper describes the decision-based approach taken in the subsurface modelling required to support quality development decisions for the development of two of KOC's Heavy oil fields through the Enhanced Technical Service Agreement (ETSA) between Shell and KOC. In this particular application of the process, the suite of models to be built has been mutually agreed at the start by the integrated development team through a structured collaborative workshop, or Model Framing Event. A fullfield and a sector model for 2 different fields are discussed to exemplify the link between required decision and supporting modelling approach.
Formation Evaluation of Thin Bedded Unconventional Reservoir and Its Impact on Reserves Estimation of Bahariya Oil Bearing Reservoir in Alfadl & Alqadr Field, Abu Gharadig Basin, Western Desert, Egypt
Authors: El-Bendary Ahmed A. , El-Sayed Moustafa M. , Mabrouk Ibrahim M. , Bakr Ahmed 
Published: October 2017

Abstract
Thin-bedded reservoirs of sand and shale, which contains hydrocarbons was determined in Abu Gharadig Basin, however the hydrocarbon-in-place is not properly quantified which is reflected on the volumetric calculations. The net pay and hydrocarbon saturation assessment is challenging in Shaly sand reservoir, with low resistivity and low contrast log response.
The scope of this study is to overcome the petrophysical challenges in reservoir evaluation and reach more accurate volumetric calculations using advanced unconventional evaluation modules.
Integrating the available data lead to a more accurate petrophysical evaluation. At first, the core data was used to divide the reservoir into different rock types by calculating the (FZI). The next step was integrating the core petrographic analysis with the available electric logging data to identify the clay types and shale distribution in the reservoir and their properties by following Thomas-Stieber diagrams.
The results of the previously stated methodology showed that, two types of Shaly distribution are present in the reservoir; the first one is a laminated Shaly sand reservoir for which the low resistivity pay evaluation module was used for the saturation calculations. The second type of clays was dispersed clays within the sand which had a major effect on the reservoir porosity and hence a different evaluation module was used. Waxman-Smitts method was used to calculate the saturation for the reservoir affected by this shale distribution.
The third step was using both the capillary pressure measurements form the SCAL core data and the FWL derived from the pressure data analysis to construct a saturation height function model which was used to calibrate the saturation calculations from the Shaly sand analysis modules.
In order to effectively address uncertainties within the reservoir as well as model the heterogeneities variations across the field, Electrofacies model was used to identify rock facies distribution which helped create conceptual model scenarios to be used in the Static model realizations. This model integrated sedimentary, structure and texture information interpreted from standard logs and core data. This integration provides a powerful tool for the distribution of reservoir characterizations.
Defining the Sulphur Logistic Requirements for Jurassic Gas Facilities-I
Authors: Blas Wilfredo L. , Al-Dousari Fahad Obaid , Al-Otaibi Mohammed , Amott Nicholas P. 
Published: October 2017

Abstract
The Jurassic Gas Facilities I (JGF-I) project marks Kuwait Oil Company’s (KOC) first major sour gas development project in North Kuwait (NK). The facilities are designed to handle a peak production of one thousand and two hundred metric tons per day (1200 MTPD) of molten sulphur. The sulphur will be loaded onto dedicated trucks and hauled to Kuwait National Petroleum Corporation’s (KNPC’s) Mina Al-Ahmadi (MAA) Refinery. The sulphur is then pelletized and sent out for export. The refinery is located approximately 145 kilometres south by road from the JGF-I facilities. A total equivalent of 63.5 million kilometres would have been travelled by sulphur trucks over a 20-year period.
Trucks are usually the most appropriate way of transporting goods and people overland. However, road transport is the biggest cause of fatalities within upstream companies and contractors. Kuwait is one of the countries with the highest number of fatalities resulting from car accidents [3], with 18.7 fatalities per 100,000 of the population [1].
It is essential that roads and other associated infrastructure, including traffic and road behaviour, is assessed intensively using route surveys. Consideration must always be given to using alternatives and evaluated for cost benefits, efficiency and risk exposure. Such an evaluation must also include handling and storage of goods where appropriate [9].
This paper describes how the project developed a tour-based transport model to define the required number of trucks and loading bays. The model also aided in the identification and quantification of potential bottlenecks. The results were used to engage with the appropriate external stakeholder(s) who have the biggest influence on the sulphur transport operations. Minimising the required size of the truck fleet will reduce the road transportation risks.
Evaluation Method and Application of Different Development Stages in Waterflooding Reservoirs
Authors: Libing Fu , Jun Ni , Zifei Fan , Xuanran Li 
Published: October 2017

Abstract
Oilfield development generally goes through multiple stages of development. Different stages have different development effects and features. Waterflooding characteristic curve is one of the main methods of development evaluation and oil recovery forecast in waterflooding oilfields. The chart of relationship between water content and recovery degree is directly applied to predict recovery factor. However, the production data could not be in accordance with the curve in the chart in the course of practical application. In order to improve the precision and applicability of water drive characteristic curve charts, based on seepage mechanics and material conservation principle, waterflooding characteristic formula between accumulative oil production and accumulative liquid production was deduced. Using mathematical equation method, a new relation between water-cut and recovery degree considering different time-phased actual development data was presented and the corresponding formula of water cut increasing rate was derived. Fitting parameters by regression fitting method from the actual production data was employed as the reference value for the revised mathematical model and the corresponding water drive curve cluster was drawn based on the fitting-curve. At the same time, the method of time-phased water drive effect evaluation was presented. Results showed that recovery factor of waterflooding reservoirs predicted by improved chart is more exact and the fitting degree of water cut between calculated and actual data is better than by existing charts, demonstrating that the improved chart has strong practicability in waterflooding development effect evaluation and index forecast. Those conclusions improve the waterflooding theory and provide useful guidance for effect evaluation of water displacing, water cut calculation and oil recovery ratio prediction for different stages. The presented research content furthers the theory of waterflooding, and builds theoretical foundation for the technologies of development evaluation in waterflooding reservoirs.
Installing Sucker Rod Pumping System on a Dual String Well Using Rig-less Intervention - Burgan Field - South East Kuwait
Authors: Al-Dousari A. A. , Al-Ramly S. A. , Imbrea R.. , Sierra T.. , Ibrahim A. M. , Khan F.. 
Published: October 2017

Abstract
The vision of each company in the current oil and gas industry scenario is to utilize the existing field investment to increase oil production at minimum cost. Installing sucker rod pumping unit on a dual string well was a big challenge to achieve, especially when the other string was producing naturally. The manuscript focuses on the challenges accompanied with the identification of well needs, designing phase, planning phase and execution phase.
Meetings have been held with both field development and well surveillance engineers to discuss the challenges to be faced to install a sucker rod pumping unit. The challenges were to occupy a turn in the rig schedule that have been set for the rest of the quarter, to install the surface unit in presence of a well head set on a high level to meet dual string surface set up and in downhole pump installation to be set through a 3.5-in. tubing with no rig accessThe solution was to use a unique way of installation by utilizing the available equipment without having the need of using a rig.
Running downhole insert pump using a insert pump anchor was the solution to set the pump at any desired depth inside the 3.5" tubing. That will only require a flush-by unit access with no need to remove the current surface set up for the dual strings. The well head for the desired well was set to 11.5 ft above ground level creating a big challenge that has been solved by using 6 portable gravel pans that can be re-located later to lift the surface unit with 6 ft to be installed above the desired string.
Successfully installing the sucker rod pumping unit in such way resulted the following benefits: Achieve required oil recovery from the string without affecting the other naturally flowing one.Eliminated work over Operation and stand by time costs.Reduced No-Production period.Installed downhole pump with the capability of retrieving the pump and/or converting the artificial lift method if required with no rig intervention.
Successful installation of a sucker rod system on a dual string well for the first time in Kuwait in Burgan field, is now considered a solution for dual string wells to optimize oil recovery with minimum cost, and is being considered as a reference for rig-less interventions with the capability of changing the type of lift in future.
A Novel and Efficient Method for Quantitative Cement Logging using a Logging-While-Drilling Acoustic Tool
Authors: Qi Zhang Bin , Feng Liu , Xin Zhou , Han Shim Yen , Li Lin 
Published: October 2017

Abstract
Logging-While-Drilling (LWD) acoustic tools encounter interference from collar arrivals when attempting quantitative cement evaluation. In low-bonding condition, the interference is not significant, an amplitude-based bond index determination is reliable with the limitation in higher bonding conditions under most scenarios (Kinoshita, T. et al. 2013). However, using the sensitivity of the measured acoustic attenuation to cement bond quality, then LWD based quantitative cement evaluation can be expanded to cover the full range of bonding (Pistre, V. et al. 2014). The combination of the two methodologies into a hybrid method has allowed quantitative cement evaluation to be delivered on LWD acoustic tools and so offer significant time saving advantages over conventional methods (Feng, Y.W. et al. 2016). In this reference example, a LWD acoustic tool was run in a deviated well combined with a casing scraper in the casing cleaning run. The LWD cement quality data were converted to a synthetic Cement Bond Log (CBL) curve expressed in millivolt (mV) units and compared with traditional CBL data. The final processed result is later interpreted as being good bonding, medium bonding and poor bonding as per the operators’ standard.
Overall, the LWD cement evaluation results showed good agreement with the traditional CBL data in almost all intervals where cement quality ranged from good to poor. However, the acoustic data were affected by noise in part of the section as indicated by the noisy variable density log (VDL) in the example well. The LWD cement evaluation delivered very positive results but it is also noticed that the mechanical casing scraper could potentially present a significant source of acoustic noise. The severity of this noise varied with logging speed. Although the downhole noise generation cannot be eliminated, through detailed prejob planning, its effects were mitigated and the results obtained met the logging expectations despite the challenging environment.
As a counterpart measurement of conventional CBL logging, utilizing the novel LWD cement evaluation methodology brings a new method to the industry for quantitatively logging the cement quality of complex wells, while at the same time, running the cement logging tool together with a casing scraper provides a more efficient and economical method to acquire the data.