Abstract

"A challenge only becomes an obstacle when you bow to it - Ray A. Davis". The development of heavy oil resources at North Kuwait Fields is an important strategic project for Kuwait Oil Company (KOC). With the target of reaching 4 million barrels per day (MBPD) production capacity by the year 2020, KOC is expected to produce 900,000 BPD of heavy oil by the year 2020. However, while cruising towards this ambitious target, KOC is also facing some unique HSE challenges - risk of exposure to high concentration of Hydrogen Sulphide (H 2 S) especially in the Heavy Oil Fields. The objective of this paper is to present KOC's strategies in the management of H 2 S in heavy oil drilling and processing activities. Various controls including access control, mandatory H 2 S Awareness and Escape training cou

Abstract

[No abstract available]

Abstract

[No abstract available]

Abstract

This paper describes the architectural and texture/facies evolution of a complex carbonate system through the construction of a regional scale 3D stratigraphic forward model (252 × 152 km2, 4 km × 4 km grid size) encompassing onshore and offshore Kuwait. The model mimics the development of a Jurassic carbonate ramp system at a 2nd to 3rd sequence stratigraphic order (1–80 Myr duration; Schlager, 2010) by simulating sedimentary processes and ecological parameters such as carbonate production versus depth, time, wave energy, as well as erosional and gravitational transport. Multi-scale 1D, 2D, and 3D geological and geophysical constraints have been used to calibrate the Lower Jurassic Marrat stratigraphic model, which resulted in the identification of (1) a dominantly transgressive lower unit composed of onlapping packages of mudstone to wackestone textures, with anhydritic intercalations; (2) a dominantly regressive middle unit composed of prograding inner ramp shoal and lagoonal facies

Abstract

Dedicated exploration efforts targeted on the Jurassic reservoirs in North Kuwait culminated in the discovery of six separate fields, encompassing an area of approximately 1,772 km2. These reservoirs are known to hold commercial accumulation of gas, gas condensate and volatile oil and are currently in an early phase of development. The producing Jurassic reservoirs belong to the Marrat, Sargelu and Najmah Formations of Toarcian to Tithonian ages. These reservoirs consist of tight carbonates with several other complex lithologies and are naturally fractured with fractures acting as a driver to production in the Najmah and Sargelu formations and fractures acting as production assist in the Marrat Formation. A 3D geological model was developed for these reservoirs. The static geological model consists of a matrix model capturing the facies, and other matrix reservoir properties like porosity, permeability and water saturation; and the fracture model captures the fracture properties like f

Abstract

In this paper, 3D mapping technology for hydrocarbon contaminated soil a powerful tool for characterizing the soil properties, soil condition, and the extent of Hydrocarbon contamination in the site that been investigated. Furthermore, this innovative 3D soil mapping technology will assist remediation projects managers in developing their remediation strategies, and support their decision in investigating and screening the required technology for specific contaminated sites. It is observed throughout this research paper that this 3D Soil mapping technology will dramatically reduce the numbers of samples required by the current typical soil site sampling process, which will reduce the sampling costs for any Hydrocarbon contaminated sites. In addition, this sampling method and technology will provide better quality results with reduction in time required for sampling any contaminated site. Moreover, throughout the literature review, we have identified that there are two interpolation met

Abstract

An existing exploration lead in the study area is considered to be high risk due to its lack of four-way closure, whereas nearby existing producing fields all have excellent four-way closures. However, stratigraphic traps could potentially exist in this area, which would make this lead attractive for exploration. We attempt to utilize seismic attributes, not only to delineate faults and fractures as the structural fabric, but also to delineate major stratigraphic features, including mapping of porosity distribution for the zone of interest. Post-stack inversion was conducted to get layer properties and to enhance the seismic resolution. The inverted acoustic impedance was combined with conventional migrated stack for neural network analysis to predict 3D porosity volume calibrated with well data. We observed that seismic attributes are useful for fault/fracture mapping in this area. Semblance, structure cube, and dip corrected structure cube are useful for regional fault mapping; where

Abstract

The recent exploration focus in Kuwait has expanded from finding conventional, structural traps to unconventional reservoirs. One of our target reservoirs in the study area of North Kuwait is the Najmah Formation. The Najmah reservoir is mainly unconventional, organic-rich shale, a highly fractureenhanced reservoir. Historically, our exploration focus has been on the 4-way closures with indication of fracture zones. To explore for hydrocarbon potential in low structural areas with less natural fractures, there is a need to map the fracability of the unconventional reservoir. This abstract describes the workflow for a prestack simultaneous inversion, to estimate seismic fracability volumes using mainly the LambdaRho vs. MuRho crossplot method. Detailed well tie analysis was carried out for wells with petrophysics and rock physics editing applied. Stable wavelets were obtained for the simultaneous inversion. The inversion results (P-Impedance, S-Impedance) were quality checked by compari

Abstract

This 2018 work comes in the context of the exploration of the Lower Jurassic Marrat Formation over Kuwait, focused mainly on the less explored offshore sector. The aim of this study is to further reduce exploration risks and to focus views on the potential of stratigraphic trapping mechanisms along the central Kuwait sector, known as the Kuwait Bay. Following a multi-disciplinary and multi-scale assessment, the present work involved a wide data collection, quality control of core and well logs, in conjunction with 2D and 3D seismic data that allowed the definition and interpretation the main stratigraphic surfaces in the Marrat formation. Well to seismic calibration was conducted in order to interpret five main horizons along the Kuwait Bay study area (survey of 2358 Km2). Well core results have been described in the neighboring sectors and were used to geologically constrain the depositional environments of the Marrat Formation expected to develop in an inner to mid ramp system. Downl

Abstract

This 2018 work comes in the context of the exploration of the Lower Jurassic Marrat Formation over Kuwait, focused mainly on the less explored offshore sector. The aim of this study is to further reduce exploration risks and to focus views on the potential of stratigraphic trapping mechanisms along the central Kuwait sector, known as the Kuwait Bay. Following a multi-disciplinary and multi-scale assessment, the present work involved a wide data collection, quality control of core and well logs, in conjunction with 2D and 3D seismic data that allowed the definition and interpretation the main stratigraphic surfaces in the Marrat formation. Well to seismic calibration was conducted in order to interpret five main horizons along the Kuwait Bay study area (survey of 2358 Km2). Well core results have been described in the neighboring sectors and were used to geologically constrain the depositional environments of the Marrat Formation expected to develop in an inner to mid ramp system. Downl

Abstract

Seismic data in Raudhatain field in Kuwait is strongly contaminated with multiples that impair the image of reservoir reflectors and challenge the structural as well as the quantitative interpretation. A reliable reservoir interpretation depends on an optimal attenuation of multiples (free surface and interbed). In this project, we demonstrated that a significant amount of multiple energy was attenuated by implementing 3D SRME together with data and model driven interbed de-multiple using two strong shallow reflectors as the dominant multiple generators. The project was run with a primary objective of a successful multiple attenuation at the Jurassic level. Initially, 3D Fourier interpolation was applied to regularize and infill shots and receiver independently, to prepare the data for 3D multiple attenuation. However, the survey in some areas was undershot due to agricultural activities, resulting in massive data gaps which presented challenges for data regularization/ interpolation.

Abstract

Seismic data in Raudhatain field in Kuwait is strongly contaminated with multiple energy that impairs the image of reservoir reflectors, and challenges the structural as well as the quantitative interpretation of the reservoir. A reliable reservoir intepretation depends on an optimal attenuation of multiple energy (free surface and interbed). In this project we demonstrated that a sigificant amount of multiple energy was attenuated by implementing 3D SRME along with data and model driven interbed de-multiple that uses two strong shallow reflectors as the dominant multiple generators. © 2017 SEG.

Abstract

Some key challenges in thermal heavy oil recovery include how to monitor steam flood effectiveness and cap-rock integrity. Kuwait Oil Company acquired baseline 3D VSP surveys in January 2016 as geophysical surveillance projects for a steam flood pilot. This paper presents a technical approach of 3D VSP acquisition design, data processing, seismic inversion, quantitative interpretation and its application for the monitoring of steam movement. Applying pressured steam to a reservoir can lead to damage of overlying cap-rock and could cause energy leakage through fractures. The technique of baseline 3D VSP and future time-lapsed 4D VSP are designed to image steam flood movement within the reservoirs. The possible applications of 3D/4D VSP technology include imaging the steam chamber size of a 30-day steam cycle, reservoir characterization and investigating integrity of the sealing cap shale. Extensive planning and immaculate execution of the 3D VSP operations resulted in timely completion

Abstract

Drilling new wells in the deep Jurassic formations of the North Kuwait fields has gained increased importance given its high gas production potential, which represents a strategic target for Kuwait's domestic gas independency. However, reaching these formations bears severe drilling risks and challenges caused by differentially depleted reservoir sections that lead to arbitrary stress distributions and high pore pressure zones. This study presents an integrated 4D geomechanical model that includes a machine learning model for the development of a drilling expert system. This allows to predict drilling events along any arbitrary well trajectory in the 3D field model by analysing the stress field based on the construction of a mechanical earth model. The model further assesses completion quality to hydraulically fracture the rock mass. The simulation covers a 34 million grid cell model and is based on high-resolution geological information, seismic inversion data, rock core laboratory da

Abstract

After 40 years of depletion drive, a mature, giant and multi-layer carbonate reservoir is developed through waterflooding. Oil production, sustained through infill drilling and new development patterns, is often associated with increasingly higher water production compared to earlier development phases. A field redevelopment plan has been established to alleviate the impact of reservoir heterogeneities on oil recovery, driven by the analysis of the historical performance of production and injection of a range of well types. The field is developed through historical opportunistic development concepts utilizing evolving technology trends. Therefore, the field has initially wide spacing vertical waterflooding patterns followed by horizontal wells, subjected to seawater or produced water injection, applying a range of wells placement or completion technologies and different water injection operating strategies. Systematic categorization, grouping and analyzing of a rich data set of wells p

Abstract

A grain flow unit was encountered within the Oxfordian Najmah Formation in one of the recently drilled deep wells in the southern Burgan area, Kuwait. The unit is about 55ft thick occurring at a depth of 11000ft within the kerogen rich source rock. It is dominated by packstone to grainstone facies with good hydrocarbon potential. It is delineated by spectral decomposition and model based seismic inversion. The resulted configuration has the characteristics of channel geomorphology - about 12km long and less than 1km wide. The traverse comprises a few crevasse splays and a fan-like feature at the tail end. The sedimentary process is inferred to be a cohesionless laminar flow through a fault controlled passage from west to east. It could have originated at the foot of the Rimthan Arch in the southwest which was separating the Gotnia intrashelf basin from the Arabian basin in the south. © 2013 SEG SEG Houston 2013 Annual Meeting.

Abstract

Drilling new wells in the deep Jurassic formations of the North Kuwait fields has gained increased importance given its high gas production potential, which represents a strategic target for Kuwait's domestic gas independency. However, reaching these formations bears severe drilling risks and challenges caused by differentially depleted reservoir sections that lead to arbitrary stress distributions and high pore pressure zones. This study presents an integrated 4D geomechanical model that includes a machine learning model for the development of a drilling expert system. This allows to predict drilling events along any arbitrary well trajectory in the 3D field model by analysing the stress field based on the construction of a mechanical earth model. The model further assesses completion quality to hydraulically fracture the rock mass. The simulation covers a 34 million grid cell model and is based on high-resolution geological information, seismic inversion data, rock core laboratory da

Abstract

With the objective of increasing its production to 4.0 million BOPD, the Kuwait Oil Company (KOC) is developing its fields with optimum technology solutions. One of these promising technologies is that of advanced completions-specifically, inflow-control devices (ICDs) and interval-control valves (ICVs). Application of this technology led to multifold increases in sustained production in horizontal wells in all reservoirs and a simultaneous reduction in water cut.

Abstract

Kuwait Oil Company (KOC) is undertaking an EOR project on a heavy oil field. This 3DVSP project was designed to monitor a 30-day steam injection into two reservoir sands which are separated by thin shale and top sealed by a thicker shale. The goals of this project include creating a repeatable baseline survey for future 4DVSP purposes, acquiring high resolution data so individual thin reservoirs can be imaged, reservoir characterization analysis, and estimation of the steam chamber size after a 30-day CSS injection. Obtaining the highest possible frequencies was identified as a critical success factor for achieving these goals. Extensive modelling and innovative customization of the acquisition design resulted in high resolution 3D seismic which provided surveillance and steam monitoring of thin vertically stacked reservoirs. The results demonstrated the steam flow direction was complex rather than a simple radial pattern. Reservoir characterization helped explain some of the complexit

Abstract

In this paper we discuss a case study of inversion of full-azimuth data for fracture characterization of the limestone member of one of the deep carbonate reservoirs of Kuwait. The inversion methodology assumes an orthotropic system of symmetry that is appropriate for analysis of VTI (vertical transverse isotropy) anisotropic rock layers containing swarms of aligned vertical fractures. Measured seismic amplitudes show good agreement with synthetic models created at different well locations, indicating reliable representation of fractures in amplitude data. Rock physics modeling shows a relationship between elastic properties and seismic anisotropy, and reservoir properties like porosity and fracture density. © 2014 SEG

Abstract

In this paper we discuss a case study of inversion of fullazimuth data for fracture characterization of the limestone member of one of the deep carbonate reservoirs of Kuwait. The inversion methodology assumes an orthotropic system of symmetry that is appropriate for analysis of VTI (vertical transverse isotropy) anisotropic rock layers containing swarms of aligned vertical fractures. Measured seismic amplitudes show good agreement with synthetic models created at different well locations, indicating reliable representation of fractures in amplitude data. Rock physics modeling shows a relationship between elastic properties and seismic anisotropy, and reservoir properties like porosity and fracture density. © 2014 SEG.

Abstract

The Cenomanian Wara Formation in Minagish Field is composed mainly of coastal plain deposits, observed at field scale along with shallow marine shales and carbonate bioclastic sandy beds. They are locally disrupted by embedded channelized sandy bodies from fluvio-tidal origin. The reservoir units are represented by different channel geometries with limited areal extension. The placement and completion of horizontal and highly deviated wells in such reservoir is a challenge necessitating a collaborative approach to avoid major well bore instability issues. These issues have a significant impact on the well cost and time line. In addition, having the right placement and completion is important for optimizing the drainage contact. To address such challenges during the different stages of the drilling operation, different technologies were used. For example, while the well was drilling through the unstable Wara and Ahmadi shaley formations, a Logging While Drilling (LWD) sonic and gamma ra

Abstract

Raudhatain-Mauddud, a super-giant depletion oil reservoir in North Kuwait, consists primarily of two areas: The crest of the reservoir with good rock/fluid quality and the flank area with poor rock/fluid quality. In some areas of the reservoir, however, especially in the flanks, the rock attributes are not fully mapped. The typical perforation that is being followed while completing the wells in the flank area of the reservoir uses either wireline-conveyed perforation or the underbalance firing TCP shoot and pull technique. The wells are then often acid stimulated to improve the injectivity/productivity profile of the injector/producer wells, respectively. A new approach involving the propellant-assisted perforation technique was applied in five wells in the flank area of the Raudhatain-Mauddud reservoir. The results show a significant improvement of injectivity/ productivity. Because this technique was being used for the first time in this reservoir, and probably for the first time in

Abstract

In the past years, machine learning (ML) and deep learning (DL) have led to the advancement of several applications, including computer vision, natural language processing, and audio processing. These complex tasks require large models, which is a challenge to deploy in devices with limited resources. These resource-constrained devices have limited computation power and memory. Hence, the neural networks must be optimized through network acceleration and compression techniques. This paper proposes a novel method to compress and accelerate neural networks from a small set of spatial convolution kernels. Firstly, a novel pruning algorithm is proposed based on the density-based clustering method that identifies and removes redundancy in CNNs while maintaining the accuracy and throughput tradeoff. Secondly, a novel pruning algorithm based on the grid-based clustering method is proposed to identify and remove redundancy in CNNs. The performance of the three pruning algorithms (density-based

Abstract

Work is in progress to de-risk and mature liquid solvent injection for extra-heavy oil extraction from the Lower Burgan Abdali (ADBG) reservoir in North Kuwait. This is a deep reservoir (i.e. 9, 000 ft) that is not believed to be amenable to steam-based EOR methods. This paper presents a workflow to create a holistic equation of state (EOS) describing the thermophysical properties of the selected solvents, extra-heavy oil, and their blend at different conditions. Such a model is essential to capture subsurface-to-surface variations in the mixture properties, thus allowing proper assessment of solvent-assisted oil production to design a fit-for-purpose pilot for further validation. Two multi-component liquid solvents and representative extra-heavy downhole oil samples were investigated using high-pressure laboratory testing. Different conditions were considered to measure fluid and density. Thereafter, a cubic EOS model was built to reproduce the extra-heavy oil lab-based PVT data. On a

Abstract

This study focuses on a multi-well pilot test for a chemical enhanced oil recovery (CEOR) project in Sabriyah Lower Burgan reservoir that is located in the north of Kuwait. The objective of this research is to evaluate the economic applicability of a proposed Alkaline Surfactant Polymer (ASP) formulation based on laboratory core flooding in a multi-well pattern of the candidate reservoir. Simulation and economic modelling was used for this evaluation. Sabriyah Lower Burgan is a large sandstone reservoir with excellent rock properties (Darcy permeabilities). The field is currently developed through primary depletion with an active edge water drive. All forms of EOR were evaluated and CEOR was the only practical technology that passed all screening criteria. Understanding the reservoir behavior is critical and evaluating multiple implementation strategies is important to insure economic success. The objective of the pilot test is to demonstrate that the recommended ASP formulation can ec

Abstract

The first phase of development of the viscous oil resources of Kuwait is planned to be delivered through cyclic steam and steam flood technology. A pilot plan to ensure optimum utilization of the injected heat and maximizing recovery from this resource is under implementation. The reservoir is layered and the level of communication between the zones is not fully understood. Careful planning in completion is needed in this complex reservoir, to obtain meaningful information for interpretation of the pilot results. The present study summarizes the methodology used to address this challenge. The complex layered nature of the reservoir along with possible free gas pockets poses serious challenge for the completion strategy. In this study, simulation history matching of the dynamic test data from the ongoing thermal and non-Thermal pilots was used to interrogate the preliminary static description. The process resulted in an improved and reliable dynamic model, which was then used in the pre

Abstract

The development of the vast viscous oil resources of Kuwait is considered a very important strategic goal of the country. The first phase of development plans is under implementation to meet a target production of 60 M bopd by a combination of cold flow and cyclic steam stimulation (CSS) followed by steamflood to have optimum recovery from this resource. The thermal development plan for the viscous oil resources, targeting high recovery factor from this resource, is considered to be the first EOR project in Kuwait. The thermal project starts with Cyclic Steam Stimulation followed by steamflood. To optimize the process and maximizing recovery, three pilots have been planned for evaluation of these technologies in this field. A detailed plan was developed to ensure quality surveillance information is obtained to support this pilot performance interpretation. This present paper summarizes the salient features of that surveillance plan and how the planned data can be interpreted, to obtain

Abstract

The Mishrif formation in west Kuwait is a tight carbonate reservoir having low oil mobility. It is fractured and heterogeneous with wide variation in porosity ranging from 10 to 25%, matrix permeability of about 0.1 to 10 md, and 20°API oil. Production tests and geomechanical study results have revealed that productivity is mostly from the high-permeability matrix and critically stressed fracture networks. Recently, the Mishrif development has been dominated by horizontal wells to maximize reservoir contact and enhance productivity. However, a challenge in such openhole completion is the stimulation strategy requiring effective diversion technology due to the uneven acid distribution along the lateral section. To address those challenges, a novel engineered workflow has been implemented relying on distributed temperature sensing (DTS) to assess the fluid coverage across the openhole section. Results enable identifying high- and low-intake zones, segmenting the uncased section into inte

Abstract

A cost-effective water management strategy for the thermal development should ensure the availability of right quality and quantity of water during the lifetime of the field. This paper presents an actual case for field water management, which includes availability, use, re-use and safe disposal of both source and effluent water. Thermal projects are notorious for their large volume of produced water through the life of the field. While treatment of produced water is a major issue; in a country like Kuwait where water is scarce, part of the produced water need to be recycled and re-used for steam generation. The methods and procedure followed are based on the practices used in the current Large Scale Thermal Pilots (LSTPs). The process involves field observations and performance, facility set-up and limitations, technical analysis and mitigation plan; so as to reach to an efficient water management plan and deliver better quality water. Heavy oil field development in Northern Kuwait is

Abstract

Preventing and curing fluid losses in limestone formations is one of the most challenging loss situations to prevent and control. Loss zones are unpredictable, due to large vugular zones and extended and connected fracture structures. Often these limestone intervals are depleted reservoirs. Typically, calcium carbonate pills containing various size distributions are part of the lost circulation armory in reservoir sections. However, results are highly variable and not suitable for large-scale losses. This is distinguished for those situations with the most-severe lost circulation, where chemical sealants may be more applicable than treatments by plugging particles. The paper discusses about use of a cross-linking polymer fluid treatment that enables operators to cure lost circulation zones in many different applications, providing distinct operational and economic advantages over conventional reactive and temperature activated methods. The paper discusses the customization of the polym

Abstract

Preventing and curing fluid losses in limestone formations is one of the most challenging loss situations to prevent and control. Loss zones are unpredictable, due to large vugular zones and extended and connected fracture structures. Often these limestone intervals are depleted reservoirs. Typically, calcium carbonate pills containing various size distributions are part of the lost circulation armory in reservoir sections. However, results are highly variable and not suitable for large-scale losses. This is distinguished for those situations with the most-severe lost circulation, where chemical sealants may be more applicable than treatments by plugging particles. The paper discusses about use of a cross-linking polymer fluid treatment that enables operators to cure lost circulation zones in many different applications, providing distinct operational and economic advantages over conventional reactive and temperature activated methods. The paper discusses the customization of the polym

Abstract

Following the rig-based well testing stage, completion programs of high-pressure wells in North Kuwait call for well killing with heavy oil-based mud (OBM). The workover rig is then demobilized, and production flowlines are installed. Well activation plans are carried out riglessly, and coiled tubing (CT) is instrumental to bringing the wells back to sustainable production. One of the major drawbacks from this practice is the formation damage generated by the OBM, which often requires additional interventions for remediation. To address this limitation, a new approach leveraging instrumented CT for temporary well suspension was recently implemented. Real-time downhole telemetry is enabled by an optical line installed in the CT pipe and used to accurately set a through-tubing inflatable packer (TTIP). Once the latter is anchored at the planned depth, above the interval open to the formation, CT is disconnected from the packer assembly, and the fishing neck is protected with a sand plug.

Abstract

Water coning is one of the most serious problems encountered in active bottom-water drive reservoir. It increases the cost of production operations, reduces the efficiency of the depletion mechanism, and decreases the overall oil recovery. Therefore, preventive measures to curtail water coning damaging effects should be well delineated at the early stages of reservoir depletion. Production rate, mobility ratio, well completion design, and reservoir anisotropy are few of the major parameters influencing and promoting water coning. The objective of this paper is to develop a depletion strategy for an active bottom-water drive reservoir that would improve oil recovery, reduce water production due to coning, delay water breakthrough time, and pre-identify wells that are candidates to excessive water production. The proposed depletion strategy does not only take into consideration the reservoir conditions, but also the currently available surface production facilities and future development

Abstract

[No abstract available]

Abstract

The accuracy of the phase envelope calculated for a black oil sample strongly depends upon the quality and type of information used to optimize the equation of state (EOS). Possible inputs for EOS tuning include (but is not limited to) composition from a chromatogram or optical absorbance, density, saturation pressure (bubble or dew point pressure), and the relative volumes of liquid and gas. In this manuscript, we describe a workflow using a system of microsensors that our group has previously published that accurately measures fluid properties from which the phase envelopes of several black oil samples are calculated and refined. © 2019, Society of Petroleum Engineers

Abstract

One of the most complex reservoir structures in Kuwait is the Mishrif reservoir in the Minagish field of western Kuwait. This depleted reservoir is composed of multiple heavily faulted compartments, each trending in different directions and with varying depth extensions. Earlier production was heavily dependent on these faults. Of late, a dynamic change in approach is under study to maximize the sustained oil production. Recent findings from multiple openhole horizontal laterals crossing Mishrif using production logging tools and dynamic temperature survey enabled identification of some major faults as thief zones and not contributing to production. In extreme cases, mechanical isolation is necessary to overcome the losses and allow the well to produce. An openhole multistage completion (MSC) with extensive packer placement was deployed in a well in the central geographic area of the Mishrif crossing multiple faults and natural fractures. This was to study and to maximize the productio

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 h

Abstract

Optimization of permanent liner completions in the North Kuwait Jurassic Gas (NKJG) reservoirs has been an ongoing challenge progressed on a steep learning curve within the last decade. Various completion options are field-tested in determining the optimal completion hardware and activation methodology. The asset's objectives have been multi-dimensional: Preserve natural fractures, minimize formation damage, segregate, stimulate and activate optimally, while installing permanent completions hardware efficiently, which can withstand 15,000-psi differential pressure at high temperature and sour gas environment and sustain production for the well life of over 20 years. NKJG faces the enormous task of increasing the hydrocarbon production potential by over 200% within a short time period. The reservoirs are high-pressured and high-temperature (HTHP) gas condensate assets with tight matrix properties (i.e. <0.1 mD permeability), in variation with naturally fractured sections within flow-zon

Abstract

Selecting the completion design and stimulation technique in North Kuwait Jurassic Gas (NKJG) were critical to overcome reservoir challenges by stimulating these unconventional formations efficiently and effectively. Therefore, the completion design must be high-pressure rated upto 15,000 psi, high temperature of 275°F and sour service specified because of high H2S & CO2 content. These reservoirs are heterogeneous carbonate type with various productivity index due to existence of natural fracture which needs proper completion type that treat each reservoir layer separately. The most challenging factor in these unconventional reservoirs is the high permeability contrast among the different flow units because of the dual porosity effect which needs convenient diversion mechanism during the stimulation. The reservoir was segmented into different intervals to enhance the productivity index of each flow unit. For that reason, "High Rate Matrix Acidizing (HRMA)" method was obtained with reta

Abstract

Asphaltene deposition in the reservoir, wellbore and facilities has long been recognized as a problem in the Marrat reservoir in the Magwa field, Kuwait. One option of avoiding asphaltene problems in the reservoir, including the near wellbore region, is to maintain reservoir pressure and flowing BHPs above the asphaltene onset pressure (AOP). Given that there is a large pressure difference between AOP and the bubble point pressure and that natural flow is possible at pressure well below AOP, there may be economic benefits in operating the reservoir at pressures below AOP. Benefits relate the reduced and delayed costs of water injection facilities. There may also be some additional recovery related to fluid expansion. Potential problems relate to possible adverse changes to relative permeability due to asphaltene related wettability changes, productivity impairment due to near well-bore asphaltene deposition and increased asphaltene problems in the wellbore. The second and third of thes

Abstract

Unconventional resources in the State of Kuwait are vast and have the potential to constitute a new industry for exploration and development in the region. However, these resources pose some unique challenges that must be overcome with innovation and technology to make them viable. A systematic approach was followed by Kuwait Oil Company (KOC) to review Kuwait’s entire resource portfolio in great detail. These evaluations comprised country-wide, detailed reservoir characterization evaluations, geomechanical studies, worldwide analogs review and available technology in the industry. Based on this review, the unconventional resources are categorized in three classes, namely, Class-I for self-sourced organic rich intervals, Class-II for Tight reservoirs, and Class-III for immobile heavy oil. The results obtained in the aforementioned studies are quite encouraging and indicate that these resources have the potential of becoming world-class producers. The objective of this paper is to prese

Abstract

Liquid solvent injection is envisaged for extra-heavy oil extraction from the Lower Burgan Abdali (ADBG) reservoir in North Kuwait. This is a deep reservoir (9000 ft) where steam-assisted EOR methods are associated with a wide array of tehno-ecnomic challenges. This paper presents a methodology for creating a holistic Equation of State (EOS) describing the thermophysical properties of the selected solvents, extra-heavy oil, and their blend at different conditions. Such a model is essential for studying subsurface-to-surface variations in the mixture properties to assess the viability of solvent-assisted production. Representative extra-heavy downhole oil samples and two multi-component liquid solvents were investigated by performing high-pressure laboratory testing. Fluid density and viscosity were measured under varying conditions. A cubic EOS model was built to reproduce the extra-heavy oil lab-based PVT data. Simultaneously, another EOS model was developed for the two solvents. Thes

Abstract

Electrical submersible pumps (ESPs) are among the most common artificial lift techniques in highly productive oil wells. The ESP failures are extremely costly to the producers and must be minimized. This study proposes a hybrid approach utilizing multi-class classification machine learning (ML) models to identify various specific failure modes (SFMs) of an ESP. A comprehensive dataset and various ML algorithms are utilized, considering the physics of fluid flow through the ESP. The ML models are based on field data gathered from the surface and downhole ESP monitoring equipment over five years of production of 10 wells. The dataset includes the failure cause, duration of downtime, the corresponding high-frequency (per minute) pump data, and well-production data. The prediction periods of 3 hours to 7 days before the failure are evaluated to minimize false alarms and predict the true events. Four modeling designs are used to handle the data and predict ESP failure. These designs differ

Abstract

[No abstract available]

Abstract

[No abstract available]

Abstract

The Greater Burgan Field is located in southeastern Kuwait, covers a surface area of about 800 square kilometers and is ranked as the largest clastic oil field in the world. The field comprises six main reservoir units, namely Wara Sand, Mauddud Limestone, Burgan Sand Upper, Burgan Sand Middle, Burgan Sand Lower and Burgan Fourth Sand, stacking on top of each other. The Wara Shale acts as a barrier separating Wara from the massive sands of the underlaying Burgan formation. However, extensive faulting does allow communication between the Wara and the Burgan Sands. Production was initiated from the Greater Burgan Field in early 1946. As the field has matured over time, the reservoir pressure has declined in certain areas, with associated reduced productivity. The reduction of wells' productivity, combined with the increasing water production, has necessitated improved oil recovery (IOR) initiative in order to support the Kuwait Oil Company (KOC) 2030 strategy, sustaining a corporate targ

Abstract

High permeable layers are one of the key factors of heterogeneity in the Mauddud carbonate reservoir. The objective of this study is to use a field scale definitive approach to characterize high permeable layers with limited data control and derisk their presence at pilot scale using multi-disciplinary data sets acquired from EOR pilot wells An appropriate definition is assigned to characterize high permeable layers based on core and log data. High permeability layers thus defined were indexed as facies logs at well locations. The indexed facies logs were correlated with different data sets in connection with from NMR, FMI, mud logs and tracers. Before incorporating surveillance data, a base case facies model was generated out of multiple distribution runs using facies index logs from pilot wells. The geological uncertainty associated with high permeable facies identified at pilot wells was decreased by incorporating previously acquired PNL logs, C/O logs, tracer, ILTs, PLTs and SNL-HP

Abstract

Horizontal well drilling is a well-established technology to enhance well productivity by increasing reservoir contact compared to that of vertical wells under the same conditions. In gas condensate reservoirs, in addition to the three-dimensional (3D) nature of the flow geometry around the horizontal well, the flow behaviour is further complicated by the phase change and the variation of relative permeability (kr) due to the coupling (increase in kr by an increase in velocity or decrease in IFT) and inertia (a decrease in kr by an increase in velocity) effects. There are no practically attractive simple methods for well productivity calculations that account for these effects. Therefore, as an alternative, numerical simulation of such a complex 3D flow using commercial numerical simulators is usually adopted. This approach requires a 3D fine grid compositional approach which is very demanding, cumbersome and often associated with convergence problems due to numerical instability. Cons

Abstract

Because core porosity versus permeability relationships are often limited for predicting production performance, it is desirable to investigate alternative methodologies to improve permeability estimates. This paper presents a workflow using logging-while-drilling (LWD) sensor measurements, namely laterolog resistivities for permeability derivation and high-resolution microresistivity images for porosity partitioning. High-resolution microresistivity images were used for traditional picks of symmetric features, such as bedding planes and fractures, as well as for identification of asymmetric features, such as vugs or secondary porosity. The estimation of secondary porosity was based on several assumptions. In water water-based mud (WBM) systems, the encountered vugs during drilling will be filled with conductive fluid and hence display dark pixels on the high-resolution image. The determination of these features was based on a histogram of pixels created corresponding to a full azimuth