Abstract

Umm Gudair/Abduliyah Tayarat reservoir is a challenging EOR target because of its high oil viscosity, low permeability, and carbonate mineralogy. A previous feasibility study indicated that a hybrid EOR thermal and chemical method combined with IOR techniques could produce significant amount of oil from this reservoir. The objective of this study was to identify the most viable reservoir-specific EOR/IOR approach taking into account techno-economic considerations. With the latest well logging data, production history, and petrophysical measurements, the Tayarat reservoir simulation model was revisited. Consequently, this simulation model was updated and calibrated to reflect field and lab observations. In addition, lab tests that demonstrated good transport and oil recovery performances of a selected polymer in low permeability reservoir cores were modeled to provide parameters for field-scale scoping simulations. Sensitivity studies were conducted to evaluate the effects of injection

Abstract

Greater Burgan is the second largest oil field and the largest clastic reservoir in the world. There are over 1000 wells on production in this field. There is a robust plan to drill more wells in the coming years to cater for world demand in production. It is therefore necessary to track and report the production and field performance from this giant field in a timely and effective manner. This paper describes the approach taken towards the development of an integrated tracking and reporting metrics tool which displays operational data to key decision makers to monitor field performance and make practical decisions. The metrics report provides a comprehensive view of the performance of an asset using key performance indicators (KPIs) in the form of a dashboard. Information is captured from corporate databases, in house tools and data sources tracking daily operations. The report is displayed graphically for quick overview of categories such as daily production, subsurface and shut-in w

Abstract

The Greater Burgan field in Kuwait was discovered in 1938 and contains more than 1,000 wells. It is extremely important to identify and perform focused surveillance work to have a better understanding of the reservoir drainage mechanism, remaining potential, and pressure decline. Considerable data accumulate every year, leading to questions about whether acquiring so much data is justified. This paper describes the approach to develop an integrated reservoir-surveillance plan for monitoring the field.

Abstract

[No abstract available]

Abstract

Carbonate rock is a predominant Middle Eastern Region geologic feature. Penetration of 16" hole sections through carbonates in the Kuwait Northern Field has in the past required the use of more than one bit. This paper describes an engineering methodology that has produced bit designs that are consistently able to complete the entire 16" Kuwait Northern Field Section with a single bit as demonstrated by production drilling over the course of many bits. Case information is included. The new design results from a symptom / cause / remedy approach that identifies root causes of unsatisfactory bit life and suggests productive, remedial solutions. Critical drilling information for prior bits was collected and analyzed to identify roller cone bit problems (symptoms). Remedies responsive to each symptom were developed. Remedy engineering was not constrained by traditional design guidelines and certain preferred solutions are considered to be unconventional. Specific, implemented remedies desc

Abstract

The South Umm Gudair (SUG) oil field located in the Neutral zone between Kuwait and Saudi Arabia has produced since 1968 from an active water drive carbonate reservoir of Lower Cretaceous age. The lower zones are homogenous intervals of higher permeability which appear to be sufficiently swept by natural water drive over a period of time. The upper zones of the reservoir are more heterogeneous and have lower permeability in the range of 50-150 millidarcies. These upper zones are relatively thin and are bound by tighter intervals that act as effective barriers to the natural water drive system. Due to the presence of barriers and low permeability intervals, these zones have been poorly swept resulting in significant volumes of by-passed oil remaining in these parts of the reservoir. The new approach of exploiting these reserves by drilling and completing 4 horizontal and 2 horizontal side track (HST) wells targeting the lower permeability portions of the reservoir in the SUG field since

Abstract

Aim: To describe the status of diabetes control and complications, and the quality of diabetes management in Saudi Arabia, Kuwait, and the United Arab Emirates, and to obtain an insight into the relationship between these factors.Methods: Patients with diabetes for>12 months were enrolled from specialist clinics and general hospitals. All available data from the patients' medical files including patient demographics; glycemic, lipid, and blood pressure status; diabetes-related complications; and diabetes management were recorded in data collection forms and analyzed.Results: Overall, 1290 patients with diabetes were enrolled with a mean (±standard deviation) age of 49.4 ± 12.3 years and duration of diabetes of 8.7 ± 5.9 years. Glycemic control was poor: Mean glycated hemoglobin A1cof 8.3 ± 2.0%, fasting and postprandial plasma glucose levels of 155.9 ± 57.1 mg/dL (8.7 ± 3.2 mmol/L), and 218.2 ± 87.4 mg/dL (12.1 ± 4.9 mmol/L), respectively. Diabetes-related complications such as neuropa

Abstract

Using examples from the Permian Basin of Texas, the North Slope of Alaska, and the Bergan Field of Kuwait, this paper describes how oil geochemical fingerprinting can be applied to diagnose quickly and easily three production problems that may affect highly deviated wells. High-Resolution Gas Chromatography can be used to quantify ∼1,000 different compounds in an oil, and the relative abundances of those compounds form a geochemical fingerprint. Geochemical differences between fluids in adjacent reservoirs can serve as natural tracers for fluid origin, allowing changes in production in highly deviated wells to be understood. Application 1: In wells that are fracture stimulated, oil fingerprinting can be used to assess whether induced fractures have propagated out of the target interval and into overlying or underlying formations. Oil fingerprinting can be used to quantify what percentage of the produced oil and gas is coming from each interval and how the effective stimulated rock volu

Abstract

Background and aims: Chest radiography (CXR) and computerized tomography (CT) scan are the preferred methods for lung imaging in diagnosing pneumonia in the intensive care unit, in spite of their limitations. The aim of this study was to assess the performance of bedside lung ultrasound examination by a critical care physician, compared with CXR and chest CT, in the diagnosis of acute pneumonia in the ICU. Materials and Methods: This was an observational, prospective, single-center study conducted in the intensive care unit of Ahmadi General Hospital. Lung ultrasound examinations (LUSs) were performed by trained critical care physicians, and a chest radiograph was interpreted by another critical care physician blinded to the LUS results. CT scans were obtained when clinically indicated by the senior physician. Results: Out of 92 patients with suspected pneumonia, 73 (79.3%) were confirmed to have a diagnosis of pneumonia based on radiological reports, clinical progress, inflammatory ma

Abstract

Objectives: Failure to identify women at risk of preterm labor (PTL) leads to failure to implement standard measures. This study designed to evaluate the accuracy of PremaQuick test in detection of PTL in women presented with threatened preterm labor (TPTL). Material and methods: One hundred and twenty-two (122) pregnant women, singleton pregnancy, < 37 weeks, admitted with TPTL included in this study, and were compared to 122 controls. After thorough evaluation, participants were examined using sterile vaginal speculum for cervico-vaginal fluid (CVF) sampling, and PremaQuick test. The CVF sampling was followed by trans-vaginal sonographic (TVS) assessment of cervical length (CL). Participants were managed according to hospitals policy thorough their admission, and after discharge in the ante-natal clinics till delivery. After delivery, the delivery data were compared by the recorded participants data on admission. Results: The PremaQuick test had 95.1% sensitivity, 97.5% specificity,

Abstract

Pulsed-neutron capture (PNC) logs are commonly used to determine formation water saturation in cased-hole environments, often for time-lapse monitoring purposes. This paper describes a new diffusion-corrected sigma algorithm developed for a pulse neutron logging tool. In southeast Kuwait, diffusion-corrected sigma log data was recorded in three wells using an array of four optimally spaced gamma ray detectors above a neutron generator. To calculate a diffusion-corrected sigma, an algorithm based on a dual exponential fit was applied to the time-decay spectrum of the near and far detectors. This calculation separates the formation and borehole decays. This approach provides an apparent formation sigma for the near and far detectors. The algorithm uses the near detector for final sigma, and a diffusion correction to the near sigma is determined by a function of a near-far sigma difference. The diffusion- corrected sigma matched the expected results and provided a good statistical

Abstract

A study was designed to confirm the formation properties obtained from available conventional RCA data and inferred from corrected wireline log data using digital rock analysis (digital RCA and SCAL analysis) on cores from the Greater Burgan field. This study was performed for Kuwait Oil Company, Fields Development Group (S&EK) by FEI Digital Rock Services in 2014. As part of this study, 27 feet of whole core, from the Lower Ahmadi (AHL2) to Upper Wara (WU1) formations, were imaged by X-ray computed tomography (CT) imaging, including 1 foot of partially preserved core. 14 plugs were extracted from these cores and imaged in 3D by a high resolution helical micro-CT. Analysis revealed stark differences in mineralogy, grain size and sorting and the presence of severe fracturing in some plugs due to the fragility and friability of the rock. Sub-plugs were extracted from 10 of the 14 plugs (including one sub-plug from the partially preserved section) and imaged in 3D by helical micro-CT. 7 o

Abstract

KOC-SEK asset has the main goal of maintaining, increasing, and optimizing the production of the Greater Burgan, the largest clastic reservoir in the World. Discovered in 1938, Greater Burgan is a multilayer formation with large hydrocarbon volumes of different oil type (from heavy to light) for which a detailed characterization and exploitation strategy was required to develop a sustained asset production. With the asset facing multiple challenges to maximize recovery and sustain target production field rate, one of these challenges has been to optimize the segregation of a large number of wells into 15 gathering centres. This is to ensure de-bottlenecking and to address back-pressure issues of the production networks while flowing wells in their optimal operational envelope to avoid the rapid depletion of the reservoir and the increasing water production. Due to the vast number of wells, the intricate network, the limitations in the gathering system and the dynamic operations, mainta

Abstract

Kuwait Integrated Digital Field Gathering Center 1 (KwIDF-GC1) pilot project was launched in Burgan field in 2009 as an investigation into how a cross-functional and cross-domain infrastructure could be established to aid in the achievement of corporate goals set for the following two decades. The company's vision for 2030 includes a philosophical shift in the way that the country's workforce accomplishes its tasks, employing latest technologies and work processes. The project solution integrates field instrumentation with workflows automated in software and focused collaboration. All well sites were instrumented with pressure and temperature gauges, multiphase water cut meters, remotely automated chokes and electronic H2S detectors. Automation of field was the first step in providing the advanced technology required of this project, realizing tangible advantages in minimizing the health, safety and environmental (HSE) exposure of field personnel. Well site data can be read, and choke

Abstract

Two common challenges to sustain production in North Kuwait (NK) include (1) management of artificial lift equipment run life and (2) reduction of production decline through pressure maintenance by water injection. Standard electric submersible pump (ESP) management guidelines promote practices to protect ESP run life while sacrificing well production rates. However, using operating rates that are not always safe can permit optimum reservoir recovery. Better management of well production targets is required to maintain safe ESP operation ranges while pushing the limits to increase production. A methodology has been developed to continuously optimize the well production potential without surpassing its safe operating envelope, keeping pump intake pressure (PIP) above the bubble point, ensuring optimum delivery at the surface, and minimizing pump downtime. This workflow was developed to assist the engineers in expediting data analysis and interpretation. This paper describes the develope

Abstract

The Najmah and Upper Sargelu formations in Kuwait are tight and unconventional fractured carbonate reservoirs that contain varying amounts of clay minerals and organic matter. Experimental MICP analysis revealed that almost all throats are smaller than 1μm in diameter and most are smaller than 100nm. The pores are poorly connected and this presents challenges for laboratory SCAL experiments. In view of this limitation, the exploitation of the reservoir had been severely constrained for want of parameters critical to reservoir simulation. The contribution of the tight matrix in controlling effective system conductivity needs to be understood to properly simulate production performance (Acharya et al., 2012). An integrated digital imaging and rock physics workflow was applied leading to data relating to fluid-to-fluid and matrixto- fluid interactions for the matrix of this challenging reservoir. Through multi-scale digital rock analysis, petrophysical and multiphase flow properties were

Abstract

We present the results of a comprehensive multiscale imaging and simulation projecton core plugs from the Minagish formation in South East Kuwait. The objective of the study was to calculate petrophysical and two-phase flow properties of core plugs representative of well BG-0836. The well contains multiple rock types ranging from packstone to coarse grainstone and includes an oil-water transition zone. Nine plugs were selected to represent the different rock types and wettability conditions encountered in the well. A digital rock analysis (DRA) program was established to characterize the plugs by combining experiments, imaging, modeling, and simulations. The plugs were imaged at multiple scales by X-ray micro Computed Tomography (microCT), Scanning Electron Microscopy (SEM) and SEM-Energy Dispersive X-ray Spectroscopy (SEM-EDS) to allow a detailed characterization of the pore space and the construction of representative rock models. The rock models were used to calculate the petrophysi

Abstract

A case study is presented in this paper that introduces a novel approach to Performance Management (PM) in an Exploration and Production Development Company (E&PDC). Typically, performance is measured at a functional level without sufficient attention to the validity of the Strategy, and the efficiency of the organization, or its leadership. Business analytics, and risk-based planning is used to improve the application of the business Strategy in an E&PDC. The case study described in this paper examines the Strategic performance, and the organization’s efficiency as part of the Performance Management system. Data Analytics was conducted on consolidated 12 years historical performance metrics to identify, the Health of the Strategy, correlations of different Performance Management metrics, and, leadership efficiency. Strategic outlook was developed using multi variable regression to slice, and dice business performance profiles, assess risk, as well as opportunity. Risk based planning i

Abstract

The Ministry of Oil (MOO) is going with new task to realize the New Kuwait Vision, and so, MOO is on track to shift to a complete digital work environment. Preliminary steps toward the transformation arose with a high concern of connecting with one of the main stakeholders, the Kuwait Oil Company. All in optimism to modernize the data digitally between the Kuwait Oil Company and the Ministry of Oil when it comes to the Technical papers proposal. Based on such, many more motives appeared to modify the work process from manual to digital. Therefore, crucial plans were established based on calculated plans set by managerial personnel to group delegated tasks. As an outcome, the staff with recognizable capabilities dispersed these tasks and executed most using current applications. In the ancient systems, papers that used to take around 21 working days to be reviewed from start to finish, now in a days with the digital system, take around 3 days only, saving a lot of time and resources for

Abstract

The North Kuwait Carbonate (NKJG) reservoirs are currently under development by KOC (Kuwait Oil Company). The appraisal and development of the NKJG offer challenges such as lateral variations in reservoir quality, tight to very tight reservoirs and natural fracturing to a varying degree spatially. The presence of open, connected fractures is one of the key elements to achieve a successful development. Also, the presence of fracture corridors increase the risk associated with drilling. Numerous fracture modelling studies have been supporting both appraisal and development strategies of the fields. This paper illustrates how small scale detailed DFN (Discrete Fracture Network) can support the planning and drilling activities of future appraisal wells. A series of detailed DFN models has been built around existing wells. The DFN models are based on a thorough structural understanding, detailed fracture characterization using bore-hole image (BHI) and core data around the wells of interest

Abstract

Several major incidents that involved newly commissioned projects with a range of inherent weaknesses bear testimony to the need for building process safety systematically into future engineering projects. The proper integration of hazard and risk studies into a project is key to achieving full potential for safety. One of the main objectives of successfully integrating process safety into a project is to reduce this residual safety risk. This paper describes the best practice developed by Kuwait Oil Company for integrating process safety activities, especially performing PHA studies through out the life cycle of process related facility projects. This paper outlines types of projects at KOC, phases of projects, brief on project requirement at each phase, details on PHA, PHSER and PSSR reviews at each stage of process to adequately assess & manage the risk. The failure to integrate all of these means that processes and project may not achieve their full safe and efficient performance.

Abstract

This project began when a 9-5/8" in 43.5 ppf production casing became inaccessible due to the existing cemented pipe inside, preventing further reservoir section exposure and necessitating a mechanical sidetrack meanwhile introducing the challenge of loosing one section and imposimg slim hole challenges. The size and weight of the double-casing made for challenging drilling, as did the eight very different formations, which were drilled. The side-track was accomplished in two steps, an 8½ in hole followed by a single long 61/8 in section, rather than the three steps (16 in, 12¼ in, 8½ in) that are typically required. The optimal kick off point carfully located across the dual casing by running electromagnetic diagnostics, the casing collar locator, and the cement bond log. The double casing mill was carefully tailored to successfully accomplish the exit in one run. Moreover, an extra 26 ft. MD rathole was drilled, which helped to eliminate the mud motor elongation run. A rotary steerab

Abstract

Downhole sampling and laboratory analysis are key complementary techniques offering a step change in fluid characterization. It is generally accepted that fluids in the reservoir are in chemical equilibrium. However this assertion, although convenient, is often invalid, for several reasons from source variations, due to in-reservoir reaction, degradation or precipitation. In a large majority of cases many of these phenomena are difficult to appreciate, because the techniques used for fluid sampling often lack the pin-point acquisition accuracy (geographical, depth and time) required to provide the information at a level of accuracy sufficient to detect subtle variations. Instead only a mixture of different oil is captured providing "averaged" oil composition and characteristics, whereas the reality in the reservoir may be markedly different. The vertical compositional gradient in oil column has been documented in many large oil column reservoirs. The geographical variation has been muc

Abstract

A downhole fluid analysis prototype module (MRPV) has been developed which measures both asphaltene onset pressure (AOP) and bubblepoint pressure (Pb). This manuscript describes one of many recent downhole jobs which were part of a study to characterize live crude oil in real time while sampling mobile oil in a permeable tar mat. These jobs support an enhanced oil recovery (EOR) study to understand the best way to extract bypassed oil (Fatma 2019). In this manuscript, downhole bubblepoint and AOP measurements made with the MRPV in well RA-0Y37 agree with those obtained in a laboratory with bottomhole samples. The effect of oil-based mud contamination on the AOP and Pb is examined during clean up while sampling. Water was present for all jobs, but the hydrophobic membrane blocked water from entering the MRPV, facilitating ease of interpretation of optical data. This manuscript comprises the first part of a two-part series (Tiwari 2020). © 2020 Society of Petroleum Engineers.

Abstract

Reservoir relative permeability as a function of saturation is critical for assessing reservoir hydrocarbon recovery, selecting the well-completion method, and determining the production strategy. It is a key input to reservoir simulation for predicting lifetime production of a well. Estimation of relative permeability curves at reservoir conditions is also a crucial task for successful reservoir modeling and history matching of production data. The relative permeability data estimated from core analysis may cause concern regarding representativeness, and adjustments are typically necessary for successful production forecasting. This paper proposes a new method to obtain relative permeability curves with downhole pressure-transient analysis of mini-drillstem tests (mini-DSTs) and well-log-derived saturations. The new approach was based on performing mini-DSTs in the free water, oil, and oil-water transition zones. Analyses of the mini-DST buildup tests provided absolute formation perme

Abstract

With the desired objective of increasing Oil production, the Operator initiated a high inclination well drilling campaign utilizing open hole completions with Inflow Control Device (ICD) screens in Burgan (sandstone) reservoirs. The approach dramatically reduces the effect of water and gas breakthrough, while optimizing production rates throughout the completion interval. Challenges encountered while drilling these high inclination wells included increased non-productive time resulting from interbedded formations with varying formation pressures, wellbore instability in the reactive, stressed shale sections and hole cleaning challenges. A non-aqueous reservoir drilling fluid (RDIF) system was customized with extensive laboratory testing to overcome the challenges and protect the reservoir from drilling fluid damage. The formation damage phenomena investigated included foreign particle invasion, formation clay swelling, chemical incompatibility, oil wetting of the reservoir rock, emulsi

Abstract

The advancements in drilling technology have led to rapid and sustained improvements in drilling operations. This gradual development of tools and techniques has resulted in time savings and safety improvements. The number of directional and horizontal wells is growing every year and many of these are being drilled in more challenging oilfield environments such as deep gas fields, carbonate reservoirs and high pressure-high temperature zones. There is also an increasing demand for precision directional and horizontal drilling in mature oil fields. Such advancement of technology and tools require an appropriate approach of developing the available technical manpower with related drilling competencies. Therefore, a competency based model becomes essential for National Oil Companies (NOCs) to develop their technical manpower to keep pace with the technology development. Effective competency development is a combination of awareness, knowledge, skills and attitude that must be demonstrated

Abstract

In the Asset of North Kuwait, a very productive, narrow and moderately continuous sandstone layer has been heavily exploited since 1990. Over and underlain by extensive shale barriers, this channel sand with weak lateral drive, has been developed using predominantly vertical and deviated wells. The sand body was deposited in an estuarine environment as a minor switching channel with limited lateral connectivity. With reservoir pressure currently at 3ppg MWE, horizontal completions were planned to further accelerate production in anticipation of much needed pressure support. The major challenges to overcome were i) the trajectory planning and high-angle drilling through about 300 feet of highly loss prone Dolomite, close above the target reservoir, ii) casing-off the high-pressured overlying shale, iii) restrict formation damage while drilling lateral section and iv) avoiding differential sticking using conventional over-balanced mud systems. An excellently engineered 7.6 ppg OBM (least

Abstract

It is a regular practice to close the nearby Injector wells prior to drilling any reservoir section to avoid encountering any abnormal pressure due to injection, which may create complications like well-control. However, shutting down injection for long period certainly creates negative impact on productivity & reservoir pressure management. This paper reveals innovative approach in drilling such wells without closing any injectors while ensuring safe and trouble-free operations in a matured field in North Kuwait. This paper elaborates on the methodology to safely drill into a charged-up reservoir from planning till execution stage. A formation-wise pressure mapping was developed with collaboration from Reservoir Engineering team with zone-wise color coding based on severity of reservoir pressure. In the planning phase, any upcoming well could be plotted in this map which will instantly give an idea about likely pressure regime to be encountered. In execution phase, real-time BHP is ac

Abstract

Kuwait has been drilling and producing from the deep, sour Jurassic reservoirs during the past 30 years. Drilling high angle wells / horizontal wells can provide a means to intersect possible oil bearing fractures besides extending the drain hole length for increasing productivity. The wells drilled to these prospects are challenging because of HPHT conditions, narrow mud weight window and sour gas. The Jurassic reservoirs itself exists below a deep high pressure formation G bearing multi Salt-Anhydrite sequences. The Jurassic wells are typically based on big bore well design with the final hole size ending in 6 ½"/6" hole size. The well constructions typically comprise of seven casing policy and requires 15 K well control equipment. It is imperative that surface/intermediate casing strings are run to the maximum depths possible in order to reach well TD in the planned workable hole size. The isolation of formation G with the planned 10 ¾″ casing is essential to drill and complete the

Abstract

As a field development strategy, KOC is developing highly depleted reservoir. The field has been experiencing wellbore instability issues. Some recent wells have encountered stuck pipe and mud losses in clastic and carbonate sections. To reduce geomechanical related Non-Productive Time and rig days, it is important that combined effect of in-situ stress state and well trajectory on wellbore stability should be thoroughly investigated. Rock mechanical behaviours also need to be evaluated to optimize drilling practice. The growing appreciation of the effects of regional tectonics is making it crucial to move away from simplified characterisation of rock behaviour and to turn into advanced geomechanical modelling techniques to engineer better wells and fields. The advanced 3D coupled Geomechanical-Fluid-Flow modelling method combines input data of different origin, such as seismic data, petrophysical data, fluid-flow data and well logs. With such an integrated model, spatial variations of

Abstract

Greater than 65% of South & East Kuwait, oil production is from more than 1000 Artificial Lifted (AL) wells, mainly Electric Submersible pumps (ESPs). This is managed in three different Areas through a total of fifteen different facilities, with downhole Artificial Lift equipment from greater than five (5) different vendors and numerous subcontracts for the top side equipment to match the downhole requirement. S&EK is also on an active transition to 100% Artificial Lift. The magnitude of production, the large number of wells, variation in equipment, relatively widespread facility and company future plans can give a sense of the operations, engagement and networking required to streamline various aspects to deliver strategic business value systematically and repetitively. The journey, processes and results of Artificial Lift technical excellence embedded in the organization will be shared in this paper. The importance of continuous integration, alignment across different directorates an

Abstract

In Kuwait, the traditional approach to Field Development has been to drill wells, whether Vertical or Horizontal, Single or Dual, with completions dedicated to either Production or Injection. However, as increasingly more wells are being drilled to develop the stacked reservoirs, surface infrastructure is growing in complexity with regard to Production Flowline routing, Gathering Facility location, Satellite Manifold placement, Water Injection distribution lines routing, and access road construction. Also, since the reservoir stack is a combination of areally extensive Carbonates overlying shale & channel sand sequences, optimum surface locations of Injectors for one reservoir is now increasingly conflicting with the optimum surface locations for the Producer of another reservoir. The North Kuwait team presented options that could reduce the requirement for excessive wellbores for both new Producers and Injectors. One of which is the utilization of a single wellbore to both Produce Oil

Abstract

In Kuwait, the traditional approach to Field Development has been to drill wells, whether Vertical or Horizontal, Single or Dual, with completions dedicated to either Production or Injection. However, as increasingly more wells are being drilled to develop the stacked reservoirs, surface infrastructure is growing in complexity with regard to Production Flowline routing, Gathering Facility location, Satellite Manifold placement, Water Injection distribution lines routing, and access road construction. Also, since the reservoir stack is a combination of areally extensive Carbonates overlying shale & channel sand sequences, optimum surface locations of Injectors for one reservoir is now increasingly conflicting with the optimum surface locations for the Producer of another reservoir. The North Kuwait team presented options that could reduce the requirement for excessive wellbores for both new Producers and Injectors. One of which is the utilization of a single wellbore to both Produce Oil

Abstract

Objectives/Scope: The objective of this abstract is to present The ECO Development Procedure, which is a quick and easy to adopt development tool that enables young engineers to attend their daily challenges through safe and robust procedure via securing a rewardable system that benefits both their seniors/specialists along with the young engineers in order to secure an efficient competency replacement policy in the team. Methods, Procedures, Process: The ECO Development Procedure offers a unique competency development tool that can be utilized as a foundation for all Operational Teams competency replacement policy. The program methodology is based on operational procedures and utilizes the latest methods in training and development fields. Starting with utilizing the Power of Positivity in creating a non-judging or gradable procedure to equally award participants. Consultants and consultees shall practice Deep Listening, Power Questions, Smart Action-Items and effective feedback. Resu

Abstract

Due to the substantial amounts of money involved and the complex interactions of a num-ber of different factors, managers of oil and gas companies are faced with significant challenges when making investment decisions that will increase business efficiency and achieve competitive advantages, especially through cost control. Due to the various uncertainties of the current period, optimal investment strategies are difficult to determine. Thus, through an economic analysis that includes data analysis, quantitative risk analysis scenarios, modelling and simulations, a work framework, in the form of a generic algorithm, is proposed with the aim of generating a complex procedure for optimizing investment decisions in oil field development. A complex set of elements is considered in the analysis: costs (operational expenditures (OPEX) and capital expenditures (CAPEX), daily drilling rig costs), prices (oil, gas, separation and water injection preparation), production profiles, different types

Abstract

The cost per barrel is higher for Heavy Oil developments, and particularly thermal developments than for Conventional. Specific attention needs to be paid to the cost of Heavy Oil developments to ensure economic viability. The current cost basis for the heavy oil project shows that energy costs constitute some 45% of Unit Technical Cost and more than 65% of the OPEX per barrel. An OPEX cost improvement plan has been conceptualized to reduce the cost per barrel. Hence, the improvement plan focusses on Alternative Energy sources for steam generation. In addition to the cost optimization, those initiatives will contribute heavily in achieving HH the Emir of Kuwait vision to cover 15% of Kuwait's peak load with renewable energy by 2030″. Based on current field development plans a feasibility study was carried out to determine the maximum practical and economic fraction of energy that can be contributed by renewables in heavy oil development. The bulk of the work was executed developing a m

Abstract

In Oil Wells the design for each feasible artificial lift method is determined before running the economic analysis to better determine the efficiency of a particular installation. Consideration of the applicable artificial lift method helps to generate the necessary information for the net present value (NPV) analysis. In this paper, a study is carried for economic comparison of the wells with same design production rate considering two artificial lift methods i.e., ESP (Electrical Submersible Pump) and rod pump. In order to increase the operational window in general, units with expected higher run life and robust construction are preferred. Therefore, in this paper firstly, it is discussed for rate comparison between conventional beam pump and unconventional extra-long stroke rod pumping units. Secondly, simulation result of ESP for the same production rate as is achievable by unconventional rod pumping unit is discussed and thirdly an economic comparison is carried between them. It

Abstract

In this current study, the transient numerical calculations using CFD code are carried out under different outlet impeller diameters for the flow field within a centrifugal pump under single-phase and cavitation conditions. Both qualitative and quantitative analyses are carried out on all of these results in order to better understand the flow structure within a centrifugal pump. Also, the investigations using different outlet impeller diameters configurations relating to the static pressure, velocity magnitude, vapour volume fraction variations, as well as pressure fluctuations in both time and frequency domain at the impeller and volute of the pump are analysed. Velocity and static pressure variations of the pump under different outlet impeller diameters range (200, 210 and 220 mm) are investigated. Reliable model is developed and validated, at various pump operating conditions, to analyse the characteristics of pressure fluctuations in both time and frequency domain. Cavitation occu

Abstract

Solution to the anisotropic stress equation evolved from extended Eaton requires knowledge of horizontal and vertical elastic properties (Equation 1). Its application to derive a general well log based acoustic model is facilitated using laboratory acoustic measurements at horizontal, vertical, and 45 degree orientation. However, obtaining 45 degree samples are very difficult due to the fragile nature of laminated, textured, and unconventional shales. Instead of using such samples, an acoustic transducer has been developed to measure velocity at 45 degrees; thus only needing simpler to cut vertical and horizontal samples. For the unconventional shales considered, the resulting model is robust and appears to fit a wide range of well data from different formations, fields and basins. The presentation also includes anisotropic Geomechanical characterization examples including some from Middle Eastern shale play evaluation. Copyright © (2014) by the European Association of Geoscientists &

Abstract

As oil and gas fields are depleted, artificial lift (AL) systems are often required to maintain delivery volumes and to maximize recovery. To handle adverse conditions, such as high viscosity oil, high water cut, sand, low reservoir pressures, high temperatures, low productivity wells, and high angle wells, special AL systems may be required. In highly productive Burgan reservoirs, high water production is a major issue in both vertical and horizontal wells thus requiring AL systems to maximize the oil recovery. Unfortunately, there are pump failures or getting stuck due to changes in the well condition or uncertainties. Replacing the failed pump needs more cost and availability of rigs. Conventional PCPs are installed by running the stator assembly on the bottom of the tubing and the rotor on the bottom of the rod. In case of malfunction in the system due to change in the well condition may lead to pump failure and its replacement. Besides production losses during the pump failure, th

Abstract

A large number of wells drilled targeting Cretaceous reservoirs. Due to unavailability of suitable surface locations, highly deviated and horizontal wells are drilled. Kuwait Oil Company has determined that output from the Burgan oilfield of South & East Kuwait required to be maintained as per the plan. To achive this plan, highly deviated and horizontal wells drilled with new process to sustain production. An inflow control device is a component technology, which is installed as part of a well completion to help optimize production by equalizing reservoir inflow along the length of the wellbore. This device supplying a specific setting to partially choke flow. The resulting installation can be used to delay water breakthrough by reducing annular velocity across a selected interval such as the heel of a horizontal well. Inflow control devices are usually used with sand screens in open hole completions. Channel sand geometry are discontinuous patches of sand lenses at differing stratigr

Abstract

Oil wells performance can be determined from completed zone productivity, completion type and size, and surface facilities. A significant surface tool, wellhead choke, can profoundly impact on the well performance. Determining the optimum choke size can result in improving the production of the well by altering the wellhead pressure, therefore the pressure drop. Increasing the bean size above optimum might result in decreasing wellhead pressure below flowline pressure and prevent the oil from flowing. To determine the optimum choke size for oil well; live trial and error could be helpful, though it is not practical and need to be combined with a well simulation analysis and history matching. A multiphase flow simulator is applied on a set of selected wells, having bottlenecks and backpressure issues in Kuwaiti oilfields. The simulation has been developed by choosing a precise flow correlation that presents a reliable flow behavior and pressure drop results. A comparison of different fl

Abstract

Training and development is recognized as critical support function of the organization. It has greater impact on assets which are diverse depending on the delivery mechanism. Identifying the most effective training solution to enhance the human resource and eventually organizational capability is only one aspect of delivery mechanism. The main and very critical aspect of delivery mechanism which has two way impacts on the organization is the adequate tools and techniques adopted to implement the learning solutions. Kuwait Oil Company has introduced a comprehensive integrated delivery mechanism ensuring the quality control at all stages; planning, implementation and evaluation. As a case study, this paper will present the mechanism of two learning solutions/learning tools (Instructor led training course and on job training). A multidimensional assessment tool kit to determine the effectiveness of the Instructor led courses and on-job training has been established which is a systematic

Abstract

In the current and future scenario of increasing demand for hydrocarbons, Multi-Disciplinary Integrated Reservoir Management team is the key to achieve maximum production rates and ultimate recovery. In Raudhatain Upper Burgan reservoir production started in 1959 with initial reservoir pressure of 3850 psi. Decline in reservoir pressure with sustained rate of production indicated weak aquifer support and initiated water injection during the year 2001 with three flank injectors. Production rate was sustained at 30 to 35 MBOPD for long time and it was decided that to go the next level of production and to meet KOC's strategic production target. Various alternative pressures - production plans were scrutinized by the multi-disciplinary team consists of Geologists, Reservoir Engineers, Petrophysicists and Petroleum Engineers and identified bottlenecks, constraints and action plan to address the problems and to accelerate the production. Some of the bottlenecks to accelerate the production

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The digital rock physics laboratories following the CT and micro CT scan techniques are in forefront and claim to carry out an accurate pore to core scale characterization of carbonate rocks with minimum possible time lapse. They measure the rock properties (porosity, permeability, electrical resistivity and elastic properties), this technique is relatively costly compared to the measurements of physical laboratories but results are obtained faster. It is known that the prediction of petro physical properties of the carbonates and assessment of multiphase flow properties in carbonates are very challenging due to complexity in the depositional processes and various digenetic changes altering the primary and even the secondary fabric of the rocks .A wide ranges of the pore and particle sizes are seen thus making the carbonate rocks heterogeneous and complex and even in a core piece of 4x6 inches a wide variation of various rock properties are noticed. A synthesis of the data obtained fro

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Background: The effectiveness, safety, and cost of vancomycin and linezolid for managing gram-positive bacterial infections in Kuwait are unknown. This study assessed the effectiveness, safety, and cost of vancomycin, teicoplanin and linezolid for managing gram-positive bacterial infections in Kuwait. Research design and methods: This retrospective study included adult patients who were prescribed antibiotics (vancomycin, teicoplanin, and linezolid) for the treatment of gram-positive infections at five hospitals in Kuwait. Descriptive statistics were used to assess the effectiveness and safety outcomes. A cost analysis was performed on the patients hospitalised for gram-positive infections. Results: Among 116 patients, 42.2 % (n = 49) received glycopeptides (vancomycin [n = 45] and teicoplanin [n = 4]) or linezolid (n = 67). Clinical cure was achieved in 100 patients without significant intergroup differences (p = 0.34). Thrombocytopenia and acute kidney injury occurred in 19 and 20 pa

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Enhanced oil recovery methods are appealing to increase oil recovery from reservoirs due to market pressures in times of lower oil price. Chemical enhanced oil recovery (cEOR) methods such as ASP involve the use of alkali, surfactant, and polymer, to create an ultralow interfacial tension (IFT) between microemulsion and oil phases. These chemicals have the potential to interact with asphaltenes in crude oil and may cause either a decrease or an increase in asphaltene deposition. This paper presents an investigation into the effects of ASP chemicals on asphaltene precipitation. Crude oil, from a cEOR-nominated Kuwaiti reservoir, was analyzed with an ASP formulation that was determined through microemulsion phase behavior experiments. Crude oil, chemical components, and incompatible solvent were added together, and light transmission was measured over a 15-minute period to determine asphaltene precipitation over time. A blank graph of the crude in incompatible solvent showed a light tran

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Introduction: To evaluate the efficacy of ferric carboxy maltose (FCM) in the treatment of iron deficiency/iron deficiency anaemia (ID/IDA) during pregnancy. Material and methods: Pregnant women ≥ 20 years old diagnosed with ID (serum ferritin < 15 μg/l) and moderate IDA were included in this study for correction of their ID/IDA. The participants received an FCM infusion for correction of their ID/IDA. The pre-treatment ferritin, haemoglobin (Hb), and red blood cell (RBC) indices were compared with the 6- and 12-week post-treatment values to evaluate the efficacy of FCM in the treatment of ID/IDA during pregnancy. Results: The pre-treatment ferritin and Hb significantly increased from 10.3 ±2.3 μg/l and 7.99 ±0.6 g/dl, respectively, to 139.5 ±1.9 and 14.04 ±0.45, respectively, 6-weeks after FCM infusion (p = 0.02 and 0.001, respectively), and to 128.9 ±1.7 and 13.02 ±0.5, respectively, 12-weeks after FCM infusion (p = 0.0008 and 0.02, respectively). In addition, the pre-treatment RBCs