Abstract

Increased water cut represents one of the biggest challenges to the oil industry, with more than 75% of the produced fluid being water that brings an increased cost per barrel of oil through water handling, scale deposition, corrosion, and mainly the bypassed oil reserve. Water shut off solutions range from mechanical solutions like bridge plugs to chemical treatments that include cement, resins and polymer gels. Cement applied as a plug or a squeeze treatment is often the preferred option to the operating company for isolating unwanted production intervals near the wellbore, and crosslinked polymer systems are also commonly used when deeper penetration is required. However, the success of these treatments often suffers from mixed fluid quality, zonal isolation (cementing quality), proper placement, numerous downhole conditions and more importantly backflow of unset cement slurry or immature gels while cleaning up leftover slurries in the wellbore or pulling out the work string after t

Abstract

This paper presents a method for facies classification derived from cross plots of basic gamma ray and bulk density wireline log data. It has been specifically developed in-house for two North Kuwait heavy-oil fields, and has been calibrated against both field analogues and core sample measurements. This new facies classification scheme has proven to be quick and cost effective, with multiple practical applications for future field development and operation optimization. For two heavy oil fields in North Kuwait basic Gamma Ray and Bulk Density (GR-DENS) curve data from over 1300 wells were cross-plotted. The resulting relationship characteristics were used to delineate eight separate facies, which plot along a continuum from clean porous sands with little cement and clay, to less porous sands with increasing clay and cementation content, to carbonate and shale. The properties for these facies were calibrated against data from core analyses and with outcrop analogues in North Kuwait. Th

Abstract

Successful operation of a waterflood requires the ability to make informed decisions based on pattern voidage replacement ratio (VRR), watercut, and water production rate. These performance measures are calculated from actual performance data using predefined allocation factors. In a pattern, there are several producers, each contributing to the total pattern production. The percentage of total volume produced from each producer is called the allocation factor. Waterflood performance is commonly monitored and studied using static allocation factors. The monitoring workflow uses the injection and production data from a database, and pattern allocation factors are assigned to production wells as static values based on geometry of waterflood patterns. In fact, the pattern allocation factors are set as a fraction of the area of a circle exposed to that pattern; hence they are constant. The allocation factors will not represent the real physics involved if they are determined based merely o

Abstract

Increasing the life of PDC bits without compromising on bit performance is crucial in drilling operations. It allows the operator to reduce non-productive time and the bit manufacturer to increase the reliability and the repairability of its products. This paper introduces a new PDC bit selection method designed to maximize the durability of the selected bit based on simulations of 3D realistic cutter damage. During PDC bit drilling operations, any damage caused to one cutter tends to overload others and compromise the balancing and the durability of the whole cutting structure. The impact of various kinds of bit failure and cutter damage on the performance of different cutting structures is estimated. The analysis is performed with the help of a 3D bit-rock interaction model which simulates the drilling process considering both the drill bit and the hole being drilled as 3D meshed surfaces. The simulator is based on a generic computational geometry algorithm which estimates the exact

Abstract

Maintaining and sustaining reservoir performance and health is a priority that requires ongoing assurance activities that will maximize recovery up to industry best practices. An automated and integrated reservoir performance tool has been developed to provide high-level assurances at both the reservoir and asset level. The Reservoir Management Performance Index (RMPI) is a set of indices that can identify key performance issues involving several aspects of the reservoir'sdevelopment and operational plans. This tool identifies mitigating measures that require action, assures production sustainability, promotes a reservoir-focused organization, and standardizes the reservoir performance evaluation in an organization. RMPIprovides a high-level overview and a platform for all management and operation levels, where observing the same set of results can initiate collective decisions that improve reservoir management. Such a system was developed for a company to monitor and measure the perfo

Abstract

Steam injection by Cyclic Steam Stimulation (CSS) and Steamflood (SF) are the selected enhanced oil recovery methods in a Kuwait shallow formation. Initial single wells and recent 5-spot pilots for CSS has production affected by sanding issues from the unconsolidated formation. A robust reservoir geomechanical model and cap rock integrity characterization on a field scale is a prerequisite for successful design and implementation of the two target steam-based EOR techniques for commercial exploitation. Conventional geomechanical modeling approaches normally depend on history matching of the in-situ rock failure. However, lack of quality data measurements for minimum and maximum horizontal stress was major challenge for soft sediment rock. Unconsolidated formation have their own inherent issues. Rock being weak and soft, it has low strength, as exhibited by the unconfined compressive strength (UCS). It also has comparatively lower values for the elastic moduli. Most of the time, the Lea

Abstract

This article attempts to summarize measures that are required to be adopted in order to have safe drilling practices mainly in unstable shale formation and have a smooth landing section in target reservoir below the shale. For the last three years in North Kuwait, the number of geo-steering jobs increased significantly and some encountered problems while drilling Wara shale that may end up in losing tools and eventually the hole itself. This paper focuses on information regarding problems encountered in geo-steering jobs and the best practices followed to achieve goals. Stratigraphically, Wara shale lies underlying Tuba and overlying Mauddud carbonates. It has thickness variation in between 80 to 110 feet TVD. Wara shale in North Kuwait is generally unstable and very sensitive to mud properties and creates instability of the wellbore. A wide range of drilling data from well placement jobs were documented and analyzed in order to get an idea of the behavior of shale section, how to dril

Abstract

The Wara reservoir is one of the main producing formations of the giant Greater Burgan field. It has been on production under natural depletion for many years. A massive water-flood of this formation has recently commenced. This was preceded by a large-scale pilot water flood the aims of which included enhancing reservoir understanding. This paper describes how historical data, including data from the large-scale pilot, were used to construct representative part filed models. The area of the pilot water flood has significant volumes of data, including core and log data and dynamic data such as pressure transient data, interference tests, tracer tests and cased-hole logs. These provide valuable information for reservoir characterization. The Wara formation was deposited in a tidally influenced fluvio-deltaic environment where sand continuity is complex. There was a desire to develop realistic geological and simulation models that accounted for our understanding of Wara geology and were

Abstract

Reservoir Performance is tracked and monitored with the help of various surveillance measurements. The surveys may include static and flowing bottom hole pressure measurements, pressure transient studies, production logging, pulsed neutron capture logging and flow rate measurements. The measured or interpreted values include reservoir pressure, productivity index, reservoir permeability, well efficiency, flow capacity, water saturation, fluid contacts and flow rates of oil, gas and water. These values, when appropriately grouped and mapped, indicate the reservoir performance and fluid flow movement. However, the asset needs to be managed with limited surveillance every year. This brings into focus the need to optimally select the candidate wells or completions. Surveillance is planned with an objective to minimize the uncertainty in the measured values. This results in maximizing understanding of the reservoir performance leading to sound reservoir monitoring and better business decisi

Abstract

Reservoir simulation is widely applied to model and manage subsurface flow operations. However, due to the nonlinear nature of the governing equations and the multiscale character of the geological description, executing numerical simulations can be expensive and increasingly slow. In this study, we propose an innovative high-speed simulation method to build a model that is capable to predict the field's behavior. In this study, a novel AI-Physics hybrid model was proposed for reservoir simulation. Classical numerical simulation and deep learning neural networks are coupled together to create an AI-Physics hybrid reservoir simulation. As a result, a model was obtained with predictive capabilities to forecast the field's behavior. Then, we combined AI-Physics history training with blind test prediction calculation of remaining oil maps. Finally, forecast scenario definitions based on the remaining oil map were created by the AI-Physic model. The proposed high-speed simulation model can

Abstract

The North Kuwait Jurassic Gas (NKJG) asset is highly complex. The main target zone is the dolomitic Marrat reservoirs that have been under differential depletion and production for several years. The Marrat are deep carbonates, naturally fractured with low matrix permeability and high conductivity contrasts. Reservoir fluid composition is sour gas condensate and volatile oil mix supported by a weak water primary drive mechanism. The Marrat reservoir is divided into flow units/flow zones with variations in reservoir properties. The variations in properties, conductivity contrasts, and the propensity to flow preferentially from the naturally fractured network cause effective stimulation of individual flow zones critical for productivity enhancement. Ideally, each flow zone must be stimulated separately to optimize the productivity of the well and to prevent unintended bypassing of the Jurassic hydrocarbons. A customized deployment method that is neither fracturing nor matrix stimulation

Abstract

Seismic multiples create false events on seismic sections, which degrade the accuracy of structural and stratigraphic mapping of the Jurassic and deeper Pre-Jurassic reservoirs in onshore Kuwait. Most of the multiple attenuation techniques use prestack data, and it is often concluded that once the data is stacked, we cannot do any further multiple attenuation. Most of the multiples in the seismic data are generated from some particular layers occurring above the target reservoir intervals. Once these multiple generating layers are identified, then it is easy to model these multiples. This paper presents a case study of attenuating multiples on stacked seismic dataset, North Kuwait, using the impulse response of the primaries and the interbed multiples at well-to-seismic calibration stage and further at the inversion stage. © 2017 SEG.

Abstract

The objective of this study is to accurately measure the wettability contact angle of a cretaceous carbonate reservoir in a vertical well set-up known for as an unconventional tight carbonate oil reservoir. Also, to investigate the relative heterogeneity of these samples using digitally captured images; these images accurately capture natural pore-system in this carbonate rock samples and their wettability performance attributed towards building a vertical depth wettability/heterogeneity model. To capture, measure and model natural tight matrix static contact angle wettability in order to understand their new physics that will advance unconventional tight oil reservoir characterization. Entire vertical well depth reservoir core rock samples, in the form of rock fragments, are selected, then imaged, and then characterized for porosity, permeability, tortuosity/heterogeneity, and pore/grain-wettability contact angle in 2D format utilizing SEM-BSE imaging techniques. The generated big dat

Abstract

The appropriate inflow control valve (ICV) design plays an important role for achieving adequate proactive reservoir management, production management and improving oil recovery. The smart completion consisting of custom designed inflow control valves along with downhole gauges are proven to be the great tool for maximizing sweep efficiency in Minagish Field, West Kuwait. The demonstrated benefits include reduction of unwanted water production, equalization of inflow profile, elimination of cross flow across laterals in multilateral wells and optimization of water injection allocation resulted in increasing sustained well productivity and maximizing oil recovery. Further the downhole gauges provides required reservoir surveillance data on real time for effective reservoir and production monitoring. Moreover the real time surveillance and production control capabilities over entire well life enabled ability to take necessary actions at right time for facilitate defensive as well as proa

Abstract

This paper focusses on rapidly growing gas demand in the state, its key drivers and solutions. Emphasis is provided on Kuwait's outlook and ventures into liquefied natural gas (LNG), controls and measures developed for handling constraints in logistical infrastructure. Requirement for tight interaction between the suppliers and consumers was pivotal to segregate different qualities of natural gas to certain consumers. A robust Gas Network system was conceived in the state and it was concluded that under normal operating conditions, it will be possible to supply gas to all essential consumers by combining the available gas from upstream units, refineries and LNG import facility. In this work, a full-blown gas network was simulated to determine transportation capacities, potential restrictions of suppliers and flexibility to use different types of gases available in the system. The study outlined decisive propositions such as the natural gas produced in the state will not be adequate to

Abstract

In 2007, Kuwait Oil Company (KOC) conducted a pilot full-azimuth survey over the North West Raudhatain Area, located in North Kuwait. A single-sensor acquisition and processing method was employed to record a full azimuth dataset with 6000 m inline and crossline spacing, focused at the Jurassic reservoirs. One of the primary objectives of the survey was to test the feasibility of characterizing the fractured Jurassic reservoirs using azimuthal anisotropy. The data were well populated in offset and azimuth, and since the vel scans showed no azimuthal variations, the same velocity field was used for the four azimuth-sectored P-P volumes pre-stack time migrations. The high fold sectored data were instrumental in successfully extracting and analyzing attributes for anisotropy analysis. This paper focuses on the acquisition and processing aspects of the data for azimuthal anisotropy studies. © 1996-2018 Society of Exploration Geophysicists All Rights Reserved.

Abstract

Even though technology development has leveraged a consistent grow in the number of rigless interventions, many remedial programs still require the support of workover rigs. In South-East Kuwait, mechanical constraints at the production tree tubing hanger prevented the operator to install the blowout preventer (BOP) of the workover rig following the conventional practices and called for a custom-fit approach to enable the required number of pressure barriers to intervene this well. The intervention approach relied on instrumented CT for well killing and temporary well suspension. CT real-time downhole telemetry enabled accurate placement and setting of a through-tubing inflatable and retrievable packer (TTIRP) inside the production tubing. Once the packer integrity is pressure tested in both directions, CT is disconnected, and then a sand plug followed by an acid soluble cement plug are spot on top of the TTIRP. Upon confirmation of cement plug integrity, the workover rigs come into pl

Abstract

A comprehensive chemical enhanced oil recovery (CEOR) laboratory evaluation program was carried out to compare surfactants for alkali-surfactant-polymer (ASP) and surfactant-polymer (SP) implementation in a giant Middle East sandstone oil reservoir. The efficacies of ASP and SP floods were investigated in laboratory corefloods and simulations with emphasis on surfactant retention to improve techno-economic feasibility. ASP and SP flooding processes were designed with low operational cost in mind and tested in laboratory corefloods. Different injection water salinities were considered for practical field application. The handling and availability of injection water with a suitable composition has significant implications in CEOR projects. SP design using produced brine with minimum water treatment is an attractive option for commercial deployment. We considered different injection water salinities, surfactant molecules, and brine treatment requirements for several ASP and SP designs. AS

Abstract

One grand challenge of surfactant technologies in high salinity sandstone reservoirs is the surfactant retention and its utilization for commercial projects. A proven mitigation strategy to reduce surfactant retention is to soften the seawater or produced brine and add alkali with the surfactant and polymer. However, softening produced brine can be costly and the addition of alkali can impose other issues such as scale and produced fluid separation. A comprehensive chemical enhanced oil recovery (CEOR) laboratory program was carried out to compare different surfactant formulations for both alkali-surfactant-polymer (ASP) and surfactant-polymer (SP) implementation in a giant Middle East sandstone oil reservoir with high salinity on the order of 160,000 ppm. The efficacies of ASP and SP floods were investigated in laboratory corefloods and simulations with emphasis on surfactant retention to improve techno-economic feasibility. Both ASP and SP floods were designed with low operational co

Abstract

According to the modified World Health Organization (WHO) classification, mechanical valves pose a high maternal risk and complications for pregnant women with heart disease. Left atrial appendage aneurysm (LAAA) is a rare condition that can manifest clinically in several ways or remain silent for a long time and can be either congenital or acquired. We present the case of a pregnant woman who had a LAAA discovered several years after her last mitral valve replacement. © 2023 SMC Media Srl. All rights reserved.

Abstract

The Jurassic Marrat formation in West Kuwait is a tight and heterogeneous carbonate reservoir in which petrophysical characteristics lead to a limitation in the predictability of reservoir properties. Landing a later well exposes operational risks, therefore LWD triple combo is excluded to avoid environmental issues and cost effects. Instead, LWD-NMR combined with Deep Azimuthal Resistivity tools emerges as the optimum solution to evaluate the formation and optimize well placement in the best reservoir quality. NMR is utilized for accurate porosity because it is independent of lithology. The T2 distribution is a direct indicator of porosity and permeability. DAR is an azimuthal propagation resistivity tool that can greatly reduce the risk of misplacing the wellbore while drillingextended reach and complex 3D horizontal wells. Marrat reservoir tends to have high resistivity, but theporosity isn't always ideal. It makes geosteering operation more challenging if only gamma & resistivity l

Abstract

Monitoring system for reservoir pressures in Kuwait Oil Company (KOC) consists of several components in the workflow. These include such processes as well bore surveillance plan, data acquisition from well bore surveys, data conversion into well-designed formats, data validation checks, flow of the formatted data into database, processing and analysis of total data for appropriate reporting. The reports on reservoir behavior may then be used for making informed decisions. A review of the existing pressure monitoring system in the organization revealed some opportunities for improving the information system. This was found to be especially the case, since it was recognized that the corporate database that serves as a common platform for storing many different classes of data, could now be utilized efficiently to support an improved information system. Potential areas of improvement were found to lie in areas such as, increasing the speed of process flows, improving the value of the info

Abstract

Background: The development of heart failure is a turning point in the natural course of aortic stenosis (AS). Pulmonary oedema and elevated left ventricular pressure (LVP) are cardinal features of heart failure. Evaluating pulmonary oedema by lung ultrasound involves taking the upper hand with a bedside noninvasive tool that may reflect LVP. Aim: We sought to assess the correlation between sonographic pulmonary congestion, invasive LV pre-A pressure, and echocardiographic LV end-diastolic pressure (LVEDP) in symptomatic AS patients receiving transcatheter aortic valve replacement. Methods: Forty-eight consecutive patients with severe AS and planned transcatheter aortic valve implantation (TAVI) were enrolled. LVEDP was estimated to be normal or elevated using the ASE/EACVI algorithm and transmitral Doppler indices, the E/A ratio, the E/e′, and the left atrial volume index. Invasive LV pre-A pressure was used as a reference, with > 12 mm Hg defined as elevated. Results: Forty-eight pat

Abstract

The Mauddud Formation, a late Albian-aged carbonate oil reservoir, is one of the main oil producers in Kuwait, however, it exhibits unreliable oil production from the Bahrah Field. The Mauddud Formation in the Bahrah field is divided into two sub-structures by a series of E-W faults and shows a slight degradation in oil quality (∼5API) within the up-dip structure. Intersections of the E-W faults with NW-SE faults are associated with deep-seated seismic pipes, which culminate in pull-up features, creating the overlying sag-like features. Additionally, the Mauddud Formation shows evidence of baroque (saddle) dolomite in fracture cements and replacing clasts. The baroque dolomite have 3He/4He ratios ∼0.3 times higher than atmospheric values. Taken together, this seismic and petrographic evidence suggests that the Mauddud Formation experienced an ingress of radiogenic, crustal fluids, potentially sourced from the basement. Seismic pipes, therefore, are interpreted to be the product of the

Abstract

An innovative, integrated characterization workflow is applied to complex siliciclastic reservoirs of the Lower Cretaceous Zubair Formation in the Bahrah Field of Northern Kuwait. A detailed sedimentological and petrophysical assessment, integrated with 3D seismic interpretation, constrained and delineated vertical and lateral facies changes within the field, which is also affected by complex fault and fracture patterns. Siliciclastic geo-bodies have been documented and mapped in 1D, 2D and 3D using seismic stratigraphy, seismic attributes and high-resolution seismic inversion reservoir characterization workflows. The spatial distribution of these geo-bodies appears to show the development of fluvio-deltaic systems in the southern and central sectors of the field, which evolved into marine dominated/tidally influenced deltaic systems towards the northern and eastern sectors. Two major fluvial channels trends have been identified: SW-NE and W-E, with a dominantly NE trending deltaic pro

Abstract

One of the most promising Enhanced Oil Recovery (EOR) methods is CO2 injection. However, if the oil contains asphaltenes, CO2 injection may cause asphaltene precipitation and introduce production related challenges. Conventional three-phase (gas/oil/water) compositional simulators are unable to predict precipitation of asphaltenes and multiphase compositional simulators are required. The use of detailed multiphase equilibrium calculations is very CPU intensive and commercial simulation packages often employ a hybrid model that may not capture the true physics at play. Conflicting findings have been reported from experimental and theoretical studies: Some studies show that Asphaltene deposition, due to CO2 injection, takes place near the injection well, while others have reported that asphaltene deposition occurs near the production well. True multiphase equilibrium calculations can be used to demonstrate that both findings are possible and that many factors will affect the deposition b

Abstract

The natural state of asphaltene in petroleum fluids is described as a colloidal system stabilized to some extent by the resins that act as peptizing agents. Destabilization of colloidal asphaltene appears to happen as a result of changes in temperature, pressure, and composition. This can significantly affect the production efficiency of the reservoir during oil recovery. The phenomena of asphaltene flocculation and deposition in oil well tubing appear to be influenced by two mechanisms, the fluid phase (gas/liquid/solid) separation and well flow regime respectively. The predictions of the onset of asphaltene flocculation determined by fluid phase laboratory studies do not necessarily imply that asphaltene deposition will occur during flow conditions. We believe that the deposition is due to the change in well flow regimes under the effect of reservoir drawdown pressure. This paper presents a method capable of predicting the onset of asphaltene deposition under well flow conditions. Th

Abstract

The natural state of asphaltenes in petroleum fluids is described as a colloidal system stabilized, to some extent, by the resins that act as peptizing agents. Destabilization of colloidal asphaltenes appears to happen as a result of changes in temperature, pressure, and composition. This can significantly affect the production efficiency of a reservoir during oil recovery. The phenomenon of asphaltene flocculation and deposition in well tubing appears to be influenced by two mechanisms: the fluid-phase (gas/liquid/ solid) separation and the well-flow regime. Predictions of the onset of asphaltene flocculation determined by fluid-phase laboratory studies do not necessarily imply that asphaltene deposition will occur during flow conditions. This paper presents a method for predicting the onset of asphaltene deposition under well-flow conditions. This method will allow us to take preventive actions before asphaltenes problems occur by keeping the asphaltenes dispersed in the oil phase. A

Abstract

Well control situation in high angle wells put challenging environment for the acquisition and interpretation of formation evaluation data on wireline. This case study puts a highlight on a new technology, which allows mitigating the well deviation and trajectory-related complications in addition to wellbore stability to acquire accurate wireline quality data, resulting in an improved completion design and an increase in production. The discussed well was drilled and completed as a horizontal open hole producer in 1994. It showed unstable production and was put on schedule for re-completion to increase production. The planned fishbone well completion design implied high-resolution caliper data acquisition to ascertain the borehole geometry in detail. Moreover, a time-lapse water saturation analysis was mandatory. On the other hand, a considerable operational risk was associated with conventional wireline tools deployment, pushing the toolstring downhole. However, this risk was

Abstract

Continuous improvement initiatives prompted the deployment of a new way to drill smart wells combining the most recent technologies. The solution consists of a complete closed loop workflow utilizing an intelligent rotary steerable system (RSS) with high-frequency downhole measurements and processing capacity, an in-bit parameter sensing device, and a novel high-speed telemetry system guided by an autonomous drilling platform. Primarily focused on reducing human intervention and improving performance, the leading Key Performance Indicators (KPI) selected to benchmark the performance were drilling time, represented by Rate of Penetration (ROP), and flat time represented by casing running time. All while providing operational consistency and reducing Health Safety and Environment (HSE) risks. The autonomous drilling platform orchestrates the rhythm in which the RSS executes commands to stay on the planned well path. Another workflow links between well placement software and the autonomou

Abstract

The development of young geoscientists and engineers to be independent contributors is paramount for Kuwait Oil Company's long-term success in optimizing their production and improving field development efficiency. In our fields, main challenges are characterized by the deep and tight naturally fractured carbonate reservoirs, volatile fluids, high pressure high temperature conditions and the presence of CO2 and sour gas. Production enhancement activities play a significant role in maintaining production capacity. Therefore, rapid and integrated decisions from multidisciplinary teams are necessary to select potential solutions and to accelerate the required remedial work. Yet the largely junior population of the asset teams creates an immense challenge in getting the work completed. Overcoming this challenge begins by developing individual staff learning programs that are aligned with competency gaps, business needs and personal development plans. The program lists the competencies requ

Abstract

Objectives/Scope: Well integrity monitoring is one of the critical processes in oil and gas wells to prevent unintended fluid movement or loss of containment to the environment. In this case study, there was continuous gas leakage to surface at high pressure through annulus "B" of an oil well in East Kuwait area. The detection and securing of the gas leak in this well was essential not only for securing the well and restoring production, but also for environmental considerations due to the sensitive geographical location. This paper presents an innovative logging combination for total well integrity assessment, including spectral noise, high-resolution temperature, multi-barrier corrosion evaluation, and fluid type identification for downhole gas leak detection. The paper also presents remedial actions taken to secure well integrity after assessing and evaluating diagnostic logs at each stage with a workover rig. Methods, Procedures, Process: Innovative combination of different measure

Abstract

The Burgan Marrat Reservoir is a challenging high-pressure, high-temperature carbonate oil reservoir dating back to the Jurassic age. This specific reservoir within the Burgan Field yields light oil, but it has a significant issue with Asphaltene deposition in the wellbore. Additionally, its well productivity is hampered by low matrix permeability. Addressing these challenges is crucial, and a successful acid fracturing process can not only enhance well productivity but also address Asphaltene-related problems. This study delves into a comprehensive methodology that was employed. The focus of well selection was on ensuring good well integrity and maintaining a considerable distance from the oil-water contact (OWC). The approach involved conducting a Multi-Rate test followed by pressure build-up to establish a baseline for understanding the reservoir's behavior, including darcy and non-darcy skin. The treatment design aimed at better fluid loss control and initiating highly conductive f

Abstract

[No abstract available]

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

This paper investigates asphaltene deposition in an oil well produces from a deep Jurassic reservoir located in Kuwait by developing a three-phase asphaltene deposition integrated model. The objective of this study is to develop and validate an integrated well model that incorporates asphaltene thermodynamic, aggregation, deposition, and transportation models coupled with a three-phase thermal-hydrodynamic mechanistic model. The proposed model is numerically solved to predict temporal and spatial asphaltene deposition and concurrently tracks oil composition changes due to asphaltene deposition. The elemental models of the integrated model are tuned against field data, and the deposition result is validated with a caliper log data. The field validation study revealed a very good match between the measured deposition behavior and model predictions. In addition, sensitivity analysis showed that although asphaltene precipitation increases as water cut increases due to higher pressure drop,

Abstract

This paper describes a unique approach for estimating reservoir performance of the Burgan formation of Greater Burgan field in Kuwait, by integrating results of complex simulation modeling with simple analogies and classical analyses. The method involved first running short-term predictions with a full-field multi-reservoir simulation model, with each case focused on an individual reservoir. Simulation results were then extracted and analyzed; average well oil decline rates were developed from the extracted simulation results for each reservoir and for each area of the field. These simulator declines were used as initial declines in long-term profiling, with additional subsequent decline periods considered for long-term performance. Water production was estimated based on extrapolation of predicted oil/water ratios from the simulator, and by incorporating adjustments based on analogies. Ultimate recoveries were estimated based on analogies. Performance profiles were then generated by i

Abstract

Objectives/Scope: This paper presents a unique successful application and implementation of testing procedures in an exploratory cretaceous well in Bahrah field (North Kuwait). Used to evaluate productivity and characteristics of a reservoir and clearly understand the reservoir's potential, which helps in reducing the risks related to developing the field for a long-term with sustainable production, and selecting the optimum completion and artificial lift method. Methods, Procedures, Process: The exploratory vertical well BH-X drilled to explore the hydrocarbon potential within the Northern Area of the Bahrah field targeting cretaceous Sandstone formation, with a total drilling depth 10,780 ft. Open-hole logs and collected WL open-hole fluid sample post drilling proved the oil bearing in the sandstone formation. The cement bond evaluation behind slim casing liner showed some doubt in quality in particularly cement image of ultrasonic tool. Decision was taken to proceed with testing wit

Abstract

Summary: Mutriba structure is a seismically defined structure in the Dibdibba basin. The anticline is located over the gravity low. Gravity and magnetic data has been used for its qualitative analysis. For quantitative analysis, an integrated model based study has helped in understanding the cause of development of Mutriba structure which is obscured in the deeper part of seismic data. The model indicates the presence of Salt Pillow near the basement which has resulted in development of Mutriba structure. The presence of low density Salt Pillow owed to gravity low. The possible reasons of aborted halokinesis (failed to grow as diaper) are also discussed.

Abstract

Cholesterol embolization syndrome (CES) is an atherosclerotic complication affecting different systems with various clinical manifestations, usually triggered iatrogenically by interventional and surgical procedures or thrombolytic therapy, although spontaneous cases have been reported. The hepatobiliary system can also be affected when the showered cholesterol crystals obliterate small vessels within this system causing both ischaemic and inflammatory responses. We describe a case of a male patient who initially developed multiple lacunar cerebral infarcts 10 days post-thrombolytic therapy and percutaneous coronary intervention (PCI) due to acute myocardial infarction. Several weeks later he developed acalculous cholecystitis complicated by liver abscess and kidney injury. The consequences and latency of manifestations within different organs and the temporal relationship with well-known trigger factors raised the suspicion of CES. LEARNING POINTS • Cholesterol embolization syndrome (

Abstract

The Minagish reservoir in the Burgan Field has been produced intermittently at relatively low rates since the 1960's. Full development has been delayed because of the relatively high H2S content of the reservoir fluid. A sour service production facility is now being planned. Reservoir pressure has declined over time and it has been recognized that a component of this decline is due to offset production from several other reservoirs in the area sharing an extensive common aquifer. Reservoir simulation has been used in two phases for the reservoir to assess development options as follows: The first phase of this work, the "fast loop", involved building models of the regional aquifer and producing reservoirs, developing multiple history matched models and using these models to assess the required volume of injection needed to prevent further reservoir decline. The field level history match was highly non-unique. This work identified the need to have water injection available prior to a ne

Abstract

Burgan Minagish (BGMN) reservoir in the Greater Burgan field, is one of the reservoirs among others that has been producing from Minagish formation. It has been in production intermittently since 1960's though full development was delayed due to high H2S content and the need to construct sour processing surface facilities. The analysis of reservoir pressure over time indicated that the main reason of reservoir pressure decline in BGMN was production from three neighboring reservoirs producing from the same formation. This was clear as pressure decline continued for the period of 2005-2009 while Burgan-Minagish was not in production. Reservoir pressure dropped below bubble point in 2011 and made it necessary to design and implement a pressure maintenance program. This included a water injection scheme which has been implemented since 2018. In 2012, using a novel approach (Al-Faresi et al, 2012), two Fast and Slow Loop simulation models were built to model a regional aquifer and quantify

Abstract

Background: Endometrial carcinoma is the most common gynecological cancer and its treatment is still controversial, especially in its early stages. There are conflicting data about the efficacy of retroperitoneal lymphadenectomy during abdominal hysterectomy and bilateral salpingoophrectomy treatment. Lymphadenectomy carries a risk of severe complications, especially in women with co-morbidities. Selective lymphadenectomy has been widely employed for staging evaluation of endometrial carcinoma because it is simple and seems to provide reliable data regarding nodal metastasis. This study was designed to evaluate accuracy of sentinel node sampling in detecting lymph node metastasis in primary endometrial carcinoma during staging laparotomy. Materials and Methods: Ninety-three women with endometrial carcinoma at high-risk for nodal metastasis were studied. During laparotomy, methylene blue dye was injected into sub-serosal myometrium, then retroperitoneal spaces were opened and blue lymph

Abstract

Asphaltene precipitation is considered a precursor of the plugging of oil wells and subsurface equipment and is a topic of continuous interest among companies and academic institutions. Numerous models to predict asphaltene precipitation at reservoir conditions have emerged over the years, and some have been dropped for several reasons. One particular case is the utilization of cubic equations of state such as Peng-Robinson (PR) and Soave-Redlich-Kwong (SRK), which although are relatively simple to code and utilize, have not been as effective in predicting asphaltene precipitation as compared to other models such as the perturbed chain version of the statistical associating fluid theory equation of state (PC-SAFT EOS). However, we have found that after improving the crude oil characterization procedure to obtain a proper set of simulation parameters from the available experimental data, the cubic equation of state can show excellent predictive capabilities in modeling asphaltene onset

Abstract

The five detector pulsed neutron (FDPN) tool is one of the most advanced tools in cased-hole reservoir evaluation. The evolution of multi-detector pulsed neutron tools (MDPN) created a turning point in the methodology to properly handle the different challenges within petrophysical cased-hole evaluation either in conventional or unconventional formations. This study demonstrates the applications of the FDPN tool and the methodology to handle the challenges in the multi-barrier well bore systems. The FDPN tool was used in two double-barrier well bore field cases in addition to one case with a triple casing system. Each case was unique in terms of objectives and challenges: Case 1 (13.375 inch, 9.625 inch and 7 inch casings) aimed to estimate the presence of gas in the annulus between the two casings and the formation gas behind the double-barrier wellbore system, while Case 2 (7 inch liner and 4.5 inch ICD) required to perform a three-phase calculation. In Case 3 (13.5 inch, 10.75 inch

Abstract

Horizontal wells drilled in Kuwait Oil Company (KOC) targeting tight carbonate Mishref reservoir in West Kuwait Minagish development fields provided increased reservoir contact area leading to higher production rate and wider access to available hydrocarbon reserves. Large wellbore radius in these open hole horizontal laterals have resulted in increased friction losses during production phase. Later, with flow equalizing completion techniques, ultimate recovery from the reservoir increased and stable production was achieved during the early phase of the reservoir. However, accessing these long horizontal laterals was a challenge and coiled tubing acidizing treatments helped achieve permeability improvements only upto a certain extent. Majority of the reservoir sections with lower permeability were unaccessed and left untreated. Limited pumping rates through coil tubing could achieve few inches of radial penetration into the formation due to limited amount of acid dosage in the stimulat

Abstract

Coming up with reliable water cut analysis and estimation has been challenging. An increase in water cut reduces oil production to no oil or is no longer economical. Water cut from the Portable Gas Oil Ratio (PGOR) test, while considered the most accurate is not sufficient to provide continuous water cut monitoring. Wells with Electrical Submersible Pump (ESP) have sensor reading acquired in real-time which can be utilized with supporting data to estimate water cut, fill the gap between PGOR tests and come up with continuous readings. This is conceptualized on spreadsheets and manually gathered the data from multiple sources. It may take hours to work on a single well and days for multiple wells with a complete cycle may take around 3-4 months. During the project, the prototype was built based on the solution design to provide seamless, advanced, and efficient water cut estimation through scalable data science-driven approach, data quality assessment, and improvement to ensure the data

Abstract

Well log data and reports volume generated by oilfield operations in Kuwait Oil Company (KOC) have increased tremendously over the last decade. Currently, KOC receives around 100 to 200 well log packages every week. Each package may contain hundreds of well log files. Mostly, the processes to receive, manage and load this amount of data into the Corporate Database were manual, involving 7 to 9 resources. Logging companies may have to wait a minimum of a week to receive the decision if their data delivery is approved or rejected. The Exploration and Production Information Management (E&P IM) team started an initiative to accelerate and automate these processes by developing and implementing a solution using Artificial Intelligence and Machine Learning techniques to increase productivity and operational efficiency and achieve high-quality data. The main results are high-quality data that meet E&P IM Well Log Standard and Specification, the processing time is reduced by 80%, and the opera

Abstract

Carbonate stimulations typically require formation-dissolving chemicals to eliminate near-wellbore damage by dissolving rock matrix or generating conductive channels such as wormholes to improve connectivity between the wellbore and the reservoir. Hydrochloric acid (HCl) has been a common choice for this purpose. However, commercially available emulsified acids, which contain acid droplets within a hydrocarbon phase, are preferred for acidifying carbonate at high temperatures. Nevertheless, these emulsified acids are usually highly viscous, leading to high friction pressure that cannot be mitigated by conventional friction reducers. In contrast, a more efficient single-phase retarded inorganic acid system (SPRIAS) was introduced to overcome these limitations. This paper presents a successful case study of SPRIAS's application in the oil and gas industry, particularly in high-temperature carbonate reservoirs. Advanced simulation software was used to model longer, intricate wormholes in

Abstract

The execution of pinpointed multi-stage acid fracturing inside 4-1/8-in. slim horizontal open hole sections is discussed. For the first time in Kuwait, pinpoint stimulation of 16 frac stages across a total 4,666 ft open hole while commingling three reservoir sections in very low reservoir quality carbonate rock was performed. Pumping rates were optimized while managing differential sticking hazards in the implementation of this frac procedure. Electric submersible pump completion deployment and well testing enhanced production by more than 100% over the anticipated rate. Stimulation parameters were optimized with 2-7/8-in. tubing as the frac string for greater reservoir penetration and productivity enhancement. Differential sticking was addressed by removing drilling filter cake prior to the frac job. Possible risks were evaluated, and mitigation plans were implemented which resulted in the successful application of multi-stage acid fracturing across the open hole. © Copyright 2018, So