Abstract

The strategy of the Kuwait Oil Company (KOC) is to implement key/emerging technologies at a country wide scale to meet future oil demand and production targets as planned in KPC 2040 strategy through overcome the field's challenges. KOC's Optimization strategy focuses on: • Increased and optimize oil production from production optimizations • Extension of field life Production interruption associated with pressure build up in reservoir, wellbore and flow lines have observed among many wells in West Kuwait fields perforated in Upper Burgan formation, which has a great impact on the company strategy. Tight emulsion phenomena is consider one the most challenging problems in West Kuwait wells due to the nature of asphaltenic crudes and high water cut production percentage. Traditional approaches to reduce high pressure and break the emulsion phase through injecting chemical near wellhead or in annuls is usually not successful in most cases and require large amount of chemical. Due to the c

Abstract

Crude oil production in Um-Ghdair field is consider one of the most complex operational activities in Kuwait Oil Company due to high water cut percentage, asphaletene flocculation, high viscosity and tight emulsion phenomena. As the fluid travels through the reservoir, wellbore, flowline, all the way to the gathering center, the state of initial equilibrium is disturbed leading to change in the chemical composition of the crude oil. As pressure and temperature continue to drop, and gas escapes, more asphaltenes and heavy components may continue to flocculate all the way throughout the system until the petroleum reaches its final destination. In this pilot project, asphaltene inhibitor and viscosity reducer agents were selected for reducing oil viscosity and breaking the tight emulsion phenomena in the selected piloting well in Um-Ghdair field. It was noticed that there is an asphaltene compounds flocculate in the interface between oil and water leading to increase crude oil viscosity.

Abstract

An acquisition square template of 12 km × 12 km was simulated using a configuration that resulted in maximum inline and crossline offsets of 6,000 m with 200 m source and receiver line intervals. The acquired data set allowed the evaluation, through decimation, of many different options in acquisition of 3D land seismic data for exploration and development. The assumption that long offsets with wide-azimuth geometries enable better multiple attenuation than narrow-azimuth geometries was one of the main reasons for acquiring this first world-class full-azimuth 3D land survey in Kuwait. Other reasons were to enable reservoir characterization, in stacked carbonate reservoirs environment, using prestack inversion and to detect fractures using anisotropic analysis. The data set also allowed the analysis of the effectiveness of the full-azimuth approach in terms of velocity determination and imaging quality. Two potential causes for loss of vertical resolution: NMO-stretch and anisotropy, we

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[No abstract available]

Abstract

Previously there were few RFT data available for the Wara formation of the Greater Burgan field. Therefore, during recent drilling, pressure measurements were made to investigate if vertical pressure equilibrium exists in the formation after a production history of more than fifty years. The erratic nature of measured pressure profiles indicates that vertical communication is poor in the reservoir. In each of the pressure measurements, a single probe was inserted into the mud filtrate zone, and then about 20 cc of liquid was collected. In addition to obtaining the pressure value, we also derived the permeability value by diagnosing the pressure derivative signatures. Multiple probes were also used to evaluate vertical permeability over an interval of 2.3 feet. This paper describes how we analyze the data and overcome the problems encountered. We demonstrate that 3D-reservoir simulation of the formation test can improve the quality of data interpretation. A summary of the analytical met

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Abstract

Reliability of equipment is indispensable for the uninterrupted operation of any oil & gas producing facility. Over a period of time, some oil wells producing sour crude were also added to the incoming feed of Gathering centres, which were originally designed for processing sweet crude. Most of the facilities were designed and installed prior to the publication of NACE MR 0175 and NACE TM 0284. As these facilities are still in operation under sour condition, it is prudent to take necessary measures in time for continuing safe operation of these facilities. In this paper, the authors share their experience in initial detection & online monitoring of service-induced damages to the equipments due to sour service using NDT techniques like Wet Fluorescent Magnetic Particle Inspection, manual ultrasonic testing and time of flight diffraction & Phased Array. The experience gathered during internal coating of the vessels has also been described. Several items of equipment continued in operatio

Abstract

This paper presents a case study of lithology prediction of the sand distribution in the Burgan Formation, North Kuwait, using prestack simultaneous inversion. The main objective of the study was to discriminate sand from shale and to identify thicker sand zones within Burgan Formation. Three lithologies (sand, shaly sand and shale) were identified on well logs using Vsh cutoffs. Seismic angle stacks were amplitude-balanced, and aligned properly before the inversion process began. After inversion quality check, seismic lithology classification was carried out using P-impedance versus Vp/Vs crossplots. Uncertainty in lithology prediction was quantified by using probability density functions. The sand thickness (time) was also estimated based on the lithology volume, and the sand thicknesses in wells were used to validate the results. © 2015 SEG.

Abstract

This paper presents a case study for lithology prediction of the Wara and Burgan Formations in Kuwait, using the prestack geostatistical inversion technique. The main objective of this study was to discriminate sand from shale, and to identify thin sand layers within Wara and Burgan Formations. Petrophysical editing was carried out to condition logs, as reliable logs are required for lithology classification and inversion. Two lithologies (sand and shale) were identified on well logs using Vsh (volume of shale) as cutoffs for Wara and Burgan Formations. Detailed well log statistics analysis (vertical size, statistical layer constrains, lithologies and their proportions) was carried out, and these statistical parameters were direct inputs for the geostatistical inversion. Seismic angle stacks were amplitude-balanced and aligned properly. Several inversion QC procedures were incorporated in the workflow to determine inversion parameters, and to optimize the quality of inversion results.

Abstract

Deterministic methods of predicting rock properties tend to be preferred by earth scientists over purely statistical approaches. This is probably due to a desire for the answer to “make sense”. This paper explores the benefits of a purely statistical approach and shows how a linear combination of attributes can closely approximate most deterministic approaches such as inversion and AVO analysis. © 2012 SEG.

Abstract

A 41 km. (25.5 mile) long, 508 mm (20″) Fuel Gas pipeline (FG048) was in service to supply Fuel Gas to oil gathering centers (GC) in the West Kuwait area since 1968. It was required to convert the pipeline for reverse flow of HP Gas from a new gas gathering center in West Kuwait. During MFL-ILI survey prior to conversion, several undefined anomalies were detected along with other internal and external corrosion. Repair work was initiated based on ASME B31G criteria. During repair work, sections having unidentified anomalies were cut out and inspected internally. Internal blistering and HIC damage were observed. Further investigation revealed severe HIC damage and internal blistering at different areas throughout the pipeline length. Since the pipeline was crucial in commissioning gas collection and compressor facility operation, and was required to be in service for transporting gas within a short time, a program of failure investigation, inspection, data analysis and repair work was i

Abstract

Locating the remaining oil (LTRO) in a matured reservoir can be complex and often requires a combination of techniques to achieve the best results. LTRO becomes an uphill task if the reservoir is structurally complex, highly channelized and at a mature stage. The studied reservoir has been on production since 1964 and is at the declining stage of the reservoir life. This paper describes the approach taken to identify additional oil from the areas of un-swept bypassed oil. A methodical approach has been followed to pinpoint those areas of the reservoir where the bypassed oil volumes are expected to be concentrated. The method consists of reviewing historical reservoir performance, fluid-flow dynamics including water movement based on cased and open-hole logs from the wells drilled from time to time, and understanding of the sweep of the reservoir by creating few appropriate sector models. The goal is to comprehend the connection between reservoir actual performance, current sweep and th

Abstract

Sand infiltration requires immediate action to avoid costly downhole and surface equipment erosion. Additionally, sand particles may reduce hydrocarbon production by blocking downhole fluid flow. This study demonstrates the advantage of integrating multiple reservoir monitoring logs to identify the sand contribution zones, quantify the sand production, and plan the well remediation work required, while minimizing operation downtime. A focused logging program and analysis method was developed to identify the sand infiltration location. Integration of passive acoustic and array-based production logs acquired the critical data to find the sand infiltration zones. The passive acoustic tool captured the count of inflowing sand strikes on the tool body generating a definitive acoustic signature. The array production logging tools mapped the fluid rates, flow delays, and fluid transport in the well. Post-processing of the passive acoustic data counted the unique sand strike events resulting i

Abstract

Data from horizontal wells have a lot of differences from data logged in vertically drilled wells. Instead of the tools measuring parallel to bedding, they measure perpendicular to bedding. The horizontal geometrical response to the layering is different from the vertical wells. Thus the interpretation of the data is also very different. Algorithms have to be adjusted from the horizontal perspective to fit the vertical perspective. The giant oil fields of North Kuwait, Raudhatain and Sabiriyah, have a log database with hundreds of vertical wells, many of them cored. The logs have been normalized to field wide benchmarks. The reservoirs characterized and models built; production history matched. Normalizing data in the horizontal sandstone wells is extremely difficult. Well bores drilled parallel to bedding are designed not to penetrate the shales; gamma ray benchmarks are not penetrated. Resistivities are measured across layering yielding extremely high resistivity responses. Shale con

Abstract

Mauddud reservoir in the Greater Burgan field is a thin, carbonate reservoir containing light oil in a 10-20 ft target zone with "good" porosity. Matrix permeability is low and natural fracture density can be variable in this reservoir. Thus, this reservoir must be exploited using horizontal wells. In the early 1990's, 16 horizontal wells were drilled in this reservoir. Five more horizontal wells have been drilled in the last 2 years in an effort to scope out the long-term potential of this reservoir. In conjunction with the drilling of recent horizontal wells, a comprehensive reservoir characterization program culminating into a full-field reservoir simulation model has been completed. The 24 million cell geological model was scaled up to a 9 million cell model at a 50 m x 50 m areal grid level to incorporate flow characteristics of horizontal wells properly in the simulation model. Matrix permeability of the scaled-up model was enhanced using a unique process based on analytical solu

Abstract

The Mauddud reservoir in the Greater Burgan field is a thin, carbonate reservoir containing light oil in a 10 to 20-feet (ft) target zone with "good" porosity. Matrix permeability is low, and natural fracture density can be variable in this reservoir. Thus, this reservoir must be exploited using horizontal wells. In the early 1990s, 16 horizontal wells were drilled in this reservoir. Five more horizontal wells have been drilled in 2005 and 2006 in an effort to scope out the long-term potential of this reservoir. However, only three of these five new wells had a production history of a few months that could be used in our history-matching effort. Thus, the history-matching effort concentrated on 19 wells (16 old plus 3 new wells). In conjunction with the drilling of recent horizontal wells, a comprehensive reservoir characterization program culminating into a full-field reservoir simulation model has been completed. The 24-million cell geological model was scaled up to a 9-million cell

Abstract

The objective is to increase the production/injection rate of the existing old sick vertical wells that are completed with 7" casing, by extending the reservoir exposure with converting those wells to horizontal producer/injector. In the initial Field Development stage, many wells were drilled and completed with 7" casing up to the surface. Several of those old wells are lying inactive in North Kuwait which has one of the largest oil reservoirs in the country. In addition, of the limited surface locations in the field combined with the growing anti-collision challenges, feasibility studies were carried out for reviving such sick wells which can't be delivered via limited hole sections; accordingly, an innovative idea introduced to complete those wells with 3 7/8" or 4 1/8" Open Hole Completion. To address the required challenges, 2-7/8" PAC HT DP had been used along with 3 1/8" Motor. Consequently, DP had to be spaced out every trip to maximize the WOB transfer and mitigate Buckling is

Abstract

This study investigates foam and water flooding (especially low salinity (LS) water flooding). Generally, injecting LS water alters sandstone wettability towards being more water-wet, is an effective EOR technique that improves oil recovery. Foams were also employed to enhance oil recovery due to its ability to increase residual oil mobility and sweep efficiency. Combining both LS water and foam into a novel attempt that takes advantage of the relative strengths of both EOR methods. This EOR combination was tested on Berea sandstone cores saturated with heavy oil. The ultimate outcome from this work is a "recipe" of EOR methods in combination, which utilizes LS water and foam to achieve recovery of over 72.65 percent of OOIP in core flooding tests. The core-flooding results showed that an increased heavy oil recovery was obtained by injecting foam and lowering water salinity. The contact angle and interfacial tension (IFT) measurements agreed with the core-flooding results. Copyright ©

Abstract

The Greater Burgan Field, first discovered in 1938, is the second largest oilfield in the world. Production from the Greater Burgan began in 1946 from the Wara reservoir via primary recovery. Recently, field-wide waterflood as a secondary recovery mechanism has been implemented. The current insight on the potential of hybrid low salinity water and polymer flooding in the Greater Burgan is presented. The goal of the Greater Burgan Study team in this enhanced oil recovery (EOR) evaluation program was to compare the benefits of using low salinity waterflood (LSW) and low salinity polymer (LSP) injection as tertiary oil recovery methods in the Wara sandstone reservoir of the Greater Burgan field. The efficacy of low salinity and low salinity polymer injection has been investigated in the laboratory and by conducting a series of single-well chemical tracer (SWCT) tests in one Wara producer. In the field trial carried out on Well A, three separate determinations of residual oil saturation (S

Abstract

Acid systems are widely recognized by the oil and gas industry as an attractive class of fluids for the efficient stimulation of carbonate reservoirs. One of the major challenges in carbonate acidizing treatments is adjusting the convective transport of acid deep into the reservoir while achieving a minimum rock face dissolution. Conventional emulsified acids are hindered by several limitations; low stability at high temperatures, a high viscosity that limits pumping rate due to frictional losses, the potential of formation damage, and the difficulty to achieve homogenous field-scale mixing. This paper highlights the successful application of an engineered low-viscosity retarded acid system without the need for gelation by a polymer or surfactant or emulsification by diesel. An acid stimulation job using a new innovative retarded acid system has been performed in a West Kuwait field well. The proposed acid system combines the use of a strong mineral acid (i.e. hydrochloric acid "HCl")

Abstract

While polymer flooding has widely been used as a successful technology to improve mobility control and sweep efficiency in many oil reservoirs, its applicability under harsh temperature/salinity conditions and in low-permeability reservoirs has prohibitively remained a challenge. This study was aimed at investigating the feasibility of low-salinity polymer flooding in a very challenging reservoir located in Kuwait with low permeability (< 10 mD), high temperature (113°C), high salinity (~239,000 ppm), high hardness (~20,000 ppm), and carbonate mineralogy. The evaluation was conducted through a series of systematic laboratory studies including polymer rheology, thermal stability, and transportability using coreflood tests. Our results highlight that the common constraints may be overcome by careful selection of polymer/ cosolvent/pre-shearing and appropriate design of low-salinity polymer flooding. Copyright 2019, Society of Petroleum Engineers.

Abstract

Introduction. One of the ultrasonic features of COVID-19 pneumonia is the presence of subpleural consolidation (SPC), and the number of SPCs varies among patients with COVID-19 pneumonia. Aim. To examine the relationship between disease severity and the number of SPCs on admission. Methodology. This observational, prospective, single-center study included patients with suspected COVID-19 infection who had been transferred to the ICU. A specialized intensivist in critical care ultrasound performed lung ultrasound (LUS) and echocardiography within 12 hours of a patient's admission to the ICU. The aeration score was calculated, and the total number of SPCs was quantified in 12 zones of the LUS. Results. Of 109 patients with suspected COVID-19 pneumonia, 77 (71%) were confirmed. The median patient age was 53 (82-36) years, and 81 of the patients (73.7%) were men. The aeration score and the counts of subpleural consolidation in each zone were significantly higher in patients with COVID-19 p

Abstract

In today's fast-paced technological world, Oil and Gas E&P industry must embrace innovative solutions for boosting efficiency and minimizing expenses. One promising direction involves investigating smart systems that can supervise, notify, and foresee the malfunction of electrical submersible pumps (ESPs). By leveraging artificial intelligence (AI) and machine learning (ML), we can transform how we handle the upkeep and administration of these vital elements. Adopting AI and ML-driven solutions offers significant advantages, such as preventing expensive failures and promoting eco-friendly resource management. By detecting and resolving potential issues early, we can extend equipment life and reduce our operations' environmental footprint. The widespread application of Electrical Submersible Pumps (ESPs) in Kuwait Oil Company (KOC) has recently experienced a surge in pump failures due to increased water production from maturing fields. This issue prompted the exploration for adopting in

Abstract

Cap rock integrity assessment is one of the corner stones for heavy oil field development where thermal, water flooding, or other Enhanced Oil Recovery (EOR) related fluid injection operation is involved. In this paper, we present our recent work related to cap rock in a heavy oil field in Northern Kuwait. The cap rock in our field is unique in many aspects compared to other heavy oil fields around the world, in that it is very shallow in burial depth, highly unconsolidated with high porosity and permeability and very ductile in terms of geomechanical properties. Furthermore, there are multiple pay reservoirs separated by different mudstone layers, so the term of cap rock becomes somewhat vague and complicated by itself. The unique properties of the cap rock in our field call for unique core analysis approaches and put up exciting challenges to petrophysical data acquisition and interpretation. A special core analysis approach has been adopted to provide mudstone porosity and permeabil

Abstract

Stimulating water injectors successfully is critical to any waterflood and to successfully stimulate wells it is important to understand what technology works and what does not. An effective method of evaluating stimulation efficency is by monitoring the long term performance of the water injectors and how injection pressure and temperature varies over time. The primary source of injection water for Greater Burgan is produced water, which is collected through an extensive gathering system. Because this gathering system is so large, the resulting fluids drop to atmospheric temperature before they are available for injection. Average daily temperatures in Kuwait vary by more than 60°F annually. All of the injection wells are injecting above fracturing pressures and these temperature swings impact the size of fractures leading to observed changes in rate of up to 40%. These effects must be understood to evaluate the impact of injection fluid temperature upon stimulation. Monitoring this s

Abstract

The goal of this procedure is to provide an understanding of the requirements for and techniques to successfully manage the Management of Change – Personnel (MOC-P) process. The emphasis will be on organizational change complexity. MOC-P is a system within the process safety management system. The management will explore how when changes occur in one element of the system, reciprocal changes may happen in other parts of the system. In order to accelerate skill development, this procedure features a problem-based learning approach that provides a collaborative job-focused experience. The management will get a better understanding of the planning and application of an MOC-P strategy, see the value for performing an MOC-P in maintaining PSM competencies, demonstrate MOC-P competency requirements to a novel organizational change event, identify novel solutions brought about by personnel changes, and collaboratively build a personal compilation of recommendations to apply on the job. Copyri

Abstract

Kuwait Petroleum Corporation (KPC) directed its Upstream subsidiaries to collaboratively work towards an integrated 2030 strategy. One of the key elements to achieving the 2030 strategic objectives was to collaborate and share expertise to resolve technical challenges currently facing the upstream entities. As a result, the Center of Excellence (CoE) was successfully implemented to leverage the diverse expertise of technical talent across the three upstream entities of Kuwait Oil Company (KOC), Kuwait Gulf Oil Company (KGOC) and Kuwait Foreign Petroleum Exploration Company (KUFPEC). CoE Discipline teams comprising of experts in strategically important technical disciplines created significant business value through sharing of knowledge, lessons learned, and experiences, around specific technical challenges. To embed the CoE as a way of working, change management was identified as a key enabler. Various interventions including organization-wide communications, focus on value creation, i

Abstract

This paper presents a critical review of planning systems for hydrocarbon exploration and production development (E&PD) companies. Traditional planning systems are no longer suitable to manage maturing reservoirs, capital-intensive projects, challenging reservoirs and growing development costs in low oil price regimes. The development of maturing oil fields and unconventional hydrocarbon resources requires dynamic development plans that are rigorously aligned with the targeted performance and adopted strategy. Traditional planning systems are no longer suitable because they lag in reacting to risks and opportunities. This paper describes a system that would reconcile development plans with business performance and constantly facilitate any required change in strategy. The triangular alignment of development plans with performance and strategy is quantitatively rigorous since it must encompass subsurface and surface operational risks including HSE risks and development cost. Planning sy

Abstract

It takes usually 3 to 4 years on an average to build a complex oil and gas facility from concept to commissioning. All critical features of the facility are decided during the early stages of the project. In fact the concept stage can be called as the stage when the DNA of the facility is cast. During rest of the project all that is being done is to develop and translate this DNA to reality. Very little can be done in later stages to correct safety problems buried in concept itself. Are we paying enough attention to process safety during this stage? Projects are implemented under several constraints and process safety sometimes takes a backseat. While there are several methods of Process Hazard Analysis by which process hazards are checked during design, how far are they effective? As the project accelerates towards completion all focus will be usually on the schedule. Are project teams able to see the compromises made on process safety during the fast track implementation? This paper

Abstract

Leadership in the oil and gas industry can only be achieved with a lean management system that promptly, identifies operational liabilities, generates optimal action plans and seamlessly manages performance to achieve the desired targets. Major accidents in the oil and gas installation pose a significant risk and most operators opt to underwrite their assets to mitigate their financial exposure. This paper presents the Insurance Surveyor playbook on asset risk rating. Insurance Surveyors evaluate asset risks based on six categorizes. The risk rating categorizes are hierarchal and also represent various phases in the asset life cycle, that include inherent features, asset management, alarms/leak detection systems and firefighting equipment. The Insurance surveyor inductively and deductively assess risk development and the operator's risk management, this involves running down the Management System to ensure a systematic assessment of risk is conducted and then evaluating the Operator's

Abstract

We designed, coded, and successfully installed wet/dry producing rules in an in-house multipurpose reservoir simulator. This paper discusses how we are using this feature to manage the development of the Greater Burgan Field. Wet/dry reservoir simulation played an important role in deciding the future production rate of Greater Burgan. We studied plateau rates ranging from 1.25 to 2.5 MMBOPD to see which production rates will or (more importantly) will not require facility upgrades for many years. For development scenarios that require upgrades, wet/dry was a key contributor for assisting with facility sizing and timing. The wet/dry producing rules demonstrated that substantial production increases were sustainable by segregating commingled flowlines. Wet/dry also indicated whether wet or dry production strategies were possible at planned development rates. Management selected a future rate of 1.7 MMBOPD as a result of this work. © Copyright 1998, Society of Petroleum Engineers, Inc.

Abstract

EOR is a key focus area for sustaining long term production and maximizing of recovery in Raudhatain and Sabriyah oil fields of North Kuwait (NK). NK oil fields consist of multiple stacked reservoirs containing both clastic and carbonate with challenging temperature and formation water salinity conditions for Chemical EOR. In addition to these harsh conditions, reservoirs have geological structural complexity, reservoir heterogeneity and aquifer strength settings. Kuwait Oil Company is putting large efforts into Chemical EOR (cEOR) maturation through two ongoing ASP pilots and polymer flooding maturation studies. Ongoing studies and preliminary piloting performance results revealed that different reservoir segments have different cEOR requirements for viable incremental oil opportunities on top of ongoing water flooding. An expansion strategy has been developed that provides a view on how to transition from pilot results to larger scale commercial implementation of cEOR for each reserv

Abstract

[No abstract available]

Abstract

The Infrastructure Master Plan (IMP) section of the Operations Support Group in Kuwait Oil Company (KOC) is responsible for developing a Master Plan to manage all the oil field’s surface footprint. Recently, KOC made an important decision that would impact the quality and accuracy of the data used for planning, operations and Health Safety & Environment (HSE) activities. In order to achieve the purpose of supporting automation, coordination and management of the company’s geographic information and resources, IMP completed its first ever, aerial acquisition of high resolution digital images of 10 cm and LiDAR (Light Detection and Ranging) of 4 ppm. Orthophotos and LiDAR bareearth Digital Elevation Model (DEM) will be produced at two different resolutions (10cm) and (20cm) using cutting-edge technologies. © 2021 American Society for Photogrammetry and Remote Sensing.

Abstract

The novel ultra-deep 3D bed boundary mapping technology was first ever implemented in case study well with the objective to map the various sand bodies in 3D while cutting down structure through the entire Wara section. The following paper discusses the key aspect of this technology and the results that followed. © 3rd EAGE/SPE Geosteering Workshop 2021.

Abstract

The Aptian Burgan reservoir, located in the Minagish Field of Kuwait, consists of a thick sequence of amalgamated channel sands providing good lateral connectivity; however, a fault network connecting the sands to the aquifer could potentially allow a premature water breakthrough. Moreover, several producers were drilled in the area, affecting the position of the OWC, because of a significant water rise in proximity of horizontal and vertical producers. The Burgan reservoir is, therefore, a challenging environment for the placing and completion of horizontal wells, requiring the accurate knowledge of the position of the OWC for optimal wellbore placement and completion planning. Kuwait Oil Company decided, therefore, to run a slim-hole BHA including a conventional azimuthal propagation resistivity tool in combination with an extra-deep azimuthal resistivity tool and multicomponent resistivity inversion modelling for the drilling of a new horizontal drain hole. This choice allowed both

Abstract

The Umm Gudair (UG) field is a carbonate reservoir of West Kuwait with more than 57 years of production history. The average water cut of the field reached to 60%. Due to long history of production and variable drawdown in the different part of the field, consequentially undulating current oil-water contact (COWC). In result, uncertainty of COWC in development wells drilling locations. UG field required a technology, which can give proactive approach while drilling to get ahead indication of approaching current oil water contact and geo-stop drilling to give optimum stand-off between the bit and the detected water contact (COWC). This innovative approach optimizes well performance through production's improvement and well cost optimization. In this paper, it will discuss the innovative approach for detecting current oil-water contact with EM Look Ahead while drilling. The pre-job well study, designing the tool configuration, real time execution and the result will be discussed. COWC wa

Abstract

Attenuating interference from internal multiples has challenged seismic data imaging in the Middle East basins. The challenge results from the strong short-period internal multiples that exhibit nearly indistinguishable characteristics from the primaries reflected from the underlying reservoirs due to predominantly horizontal strata and occasional low-relief structures, as indicated in the Jurassic formations in Kuwait. To address the internal-multiple issues, multiple prediction followed by adaptive subtraction is the most common approach in the industry. However, due to the similarities between primaries and multiples, applying adaptive subtraction poses a high risk of primary-amplitude damage, preventing quantitative seismic data interpretation. Therefore, we examine the Marchenko method that retrieves Green's functions from surface seismic data for target-oriented imaging without applying adaptive subtraction. Marchenko imaging has produced promising results on several offshore sei

Abstract

Objective: To detect the maternal and obstetrical factors associated with successful trial of vaginal birth among women with a previous cesar­ean delivery.; Material and Methods: A total of 122 women who were eligible for a trial of labor after cesarean section (TOLAC) according to departmental protocol were included in this comparative prospective study. After informed consent, the women included in this study were subjected to a thorough history to detect maternal and obstetric characteristics and a standard examination to estimate fetal weight, engagement of the fetal head, intra-partum features of fetal membranes, and cervical dilatation. After delivery, data on duration of labor, labor augmentation, mode of delivery, birth outcome, and neonatal intensive care (NICU) admission were recorded and analyzed.; Results: Trial of labor after cesarean section was successful in 72.13% and was unsuccessful in 27.87%. Body mass index (BMI) was significantly lower in the successful TOLAC group

Abstract

Raman spectroscopy is used to estimate thermal maturity of shale samples collected from seven wells in the Najmah Formation in Kuwait, encompassing a range of maturities between 0.80 and 1.40%VRE. The Najmah Formation contains kerogen Type II-S (S/C > 0.04) and therefore, maturity correlations for Type II are not applicable due to differences in organic material structure, kinetics and thermal transformation pathways. A new correlation is proposed for the purpose of thermal maturity estimation in Type II-S kerogens. The presented correlation is able to predict the thermal maturity, based on Raman spectra, with good accuracy when compared to the reflectance-derived thermal maturity values. © 2019 Elsevier B.V.

Abstract

Theunderstanding of the flowing behavior coming from Mauddud carbonate reservoir in Greater Burgan field has always been a matter of debate. This reservoir is composed of tight complex carbonates with net gross pay that ranges from 10 up to 25 feet. Its porosity response is generally low, aswell as its matrix permeability. The best strategy for reservoir exploitation it is for sure by mean of horizontal drilling but results did not match expectative, sincesome unsuccessful wells were drilled. For aforementioned reasons it is crucial to understand and characterize the presence of fractures in the Mauddud carbonate reservoir as well as the presence of vugs and leached features in order to establish if the observed production is related to matrix or to the fracture network contribution. The understanding of the relationship between matrix characteristics, fracture distribution, andwell production will allow planning a better developing strategy for the sweet spots. This paper describes in

Abstract

The paper outlines a comprehensive workflow for calibrating well models and optimizing well production. An automated well-model management system ensures data accuracy and timeliness by fetching information from the production database. Simultaneously, the well-production optimization process identifies opportunities for improving field development and production operations by analyzing real-time data and applying optimization techniques. The system empowers engineers with data-driven decision-making tools and provides recommendations for optimizing well parameters. The integration of multiple data sources, automated processes, and data quality control ensures the reliability of results. This automated approach enhances the identification of valid optimization opportunities and facilitates well performance management, leading to significant oil production gains and informed decision-making within the field. Copyright © 2024, International Petroleum Technology Conference.

Abstract

Although oilfield workflow automation processes have been implemented in the oil and gas industry during the last decade, the full impact and value of these technologies has yet to be realized. Tremendous potential still exists to implement new technology to maximize production, increase operational efficiency, and reduce down time/non-productive time. The Kuwait Integrated Digital Field project (KwIDF) is a novel intelligent digital oilfield operation for Kuwait Oil Company, the operator of the Sabriyah field in North Kuwait. The project has successfully implemented improvements in field's operational efficiency by reducing the down time in artificial lift completion, increasing well productivity, and preventing water production. This paper provides an overview of the project from the perspective of field data acquisition, data analysis, model analysis, diagnostics, and operational optimization conducted in "right time" in the operator's state-of-the-art collaboration center. The auto

Abstract

Kuwait Oil Company plans to drill deeper wells in the Greater Burgan field - a well-recognized field as one of the top world's giant producing fields - and the most prolific of Kuwait oil fields (Figure 1). While the whole Cretaceous section of Burgan field has been extensively explored and developed, the deeper part in lower and upper Jurassic sections remains a very challenging exploration and field development target, due to the seismic imaging and scarcity of good well data, therefore a high resolution 3D seismic data were conducted to delineate the upper Jurassic package; however, the seismic processing of these data was not finished at the time we conducted the study and we had to use the available seismic data to help delineating the lower Jurassic section as first priority. The challenge we have is the estimation of volumetrics from a carbonate reservoir. © 2019 SEG

Abstract

Kuwait Oil Company plans to drill deeper wells in the Greater Burgan field – a well-recognized field as one of the top world’s giant producing fields – and the most prolific of Kuwait oil fields (Figure 1). While the whole Cretaceous section of Burgan field has been extensively explored and developed, the deeper part in lower and upper Jurassic sections remains a very challenging exploration and field development target, due to the seismic imaging and scarcity of good well data, therefore a high resolution 3D seismic data were conducted to delineate the upper Jurassic package; however, the seismic processing of these data was not finished at the time we conducted the study and we had to use the available seismic data to help delineating the lower Jurassic section as first priority. The challenge we have is the estimation of volumetrics from a carbonate reservoir. © 2019 SEG

Abstract

Uncommitted acquisition system was every geophysicist's dream. The introduction of the Single-Sensor technology which allows measuring the true seismic wavefield makes it possible. KOC was pioneer to test and evaluate this technology during the last decade where wealth of information and experience has been gained from the application of this technology in exploration and development activities. Single-Sensor technology has given KOC the ability to resolve stratigraphic and structural uncertainties for the shallow heavy oil and the deep gas exploration as well as for the known Cretaceous reservoirs. More than 15 technical papers were published in most of the international conferences which comprised KOC successes with this technology. This paper will summarize KOC experience gained in maximizing the value of information extracted from the Single-Sensor measurements over the past years. © 2012 SEG.

Abstract

Kuwait is keen in developing the shallow Miocene Heavy Oil resources of Ratqa Lower Fars. EOR screening studies indicate thermal methods of Cyclic Steam Stimulation (CSS) and Steamflood as most promising technologies for developing this resource and meeting KOC goals. Thermal development was tried earlier in this field. In 1980's two CSS pilots were carried out that are considered successful. Steam Flood was also planned at that time but the project got stalled due to the Gulf War. Facilities got destroyed during that war. The present paper describes how thermal simulation techniques were used to design a new and improved thermal pilot, by matching the old CSS pilot performance, learning from history matching process and carrying out multiple prediction scenario analysis. The pilot plan is currently at the early phase of implementation in this field and is considered very important risk mitigation step, towards commercialization of the project. The paper summarized the objectives of th

Abstract

Quinolinic acid (QA) is an excitotoxic metabolite of the kynurenine pathway of tryptophan metabolism produced in response to inflammation and oxidative stress. Lead (Pb) causes oxidative stress and thus may produce neurotoxicity by increasing QA production. We investigated the in vitro cytotoxic effects of Pb and QA and the protective effects of the NMDA receptor antagonist memantine. Primary cultures of embryonic hippocampal cells from Wistar rats were treated with different concentrations of Pb, QA, and Pb + QA with and without memantine. Cell viability was determined by 3-(4,5-dimethylthiazol-2-yl)-2,5-diphenyltetrazolium bromide (MTT). Apoptosis was analyzed by flow cytometry after Annexin-V/propidium iodide staining. The numbers of immunostained neurons (with β3-Tubulin; Tuj1) and astrocytes (with glial fibrillary acidic protein) were counted. Pb at 20 μg/dL (0.97 μM) and QA at 500 nM concentrations showed significant cytotoxic effects, as evidenced by decreased cell viability, in

Abstract

Kuwait has proven oil reserves and production from supergiant and giant fields that include the Greater Burgan (Burgan, Ahmadi, and Maqwa), Raudhatain, Sabriya, and Minagish fields. These fields are associated with very gentle oval anticlines interpreted as drape structures over deep-seated fault scarps or as growth structures related to halokinesis. These structures are generally very simple, consisting of a series of roughly parallel, anticlinal uplifts trending NNW-SSE, with a few having a more N-S to NNE-SSW trend. Reservoir rocks are found in the Jurassic Marrat, Sargelu, and Najmah Formations (carbonates), the Lower Cretaceous Ratawi and Minagish Formations (sandstones and carbonates), and the Middle Cretaceous Burgan and Wara Formations (sandstones), as well as the Mauddud and Mishrif Formations (carbonates). Depth of reservoirs range from 3680 m (12,073 ft) in the Middle Jurassic to 2000–3650 m (6561–11,975 ft) in the Lower Cretaceous and 1000–2570 m (3281–8432 ft) in the Middl