Abstract

Major oil producing countries are affected by the recent drop in oil price and lack of local gas production available for consumption in the local society. With oil prices more than halved over the last year, the oil industry is gradually slipping into the red. However, significant volume of local gas supply need is critical to catch-up day to day local consumption demands (i.e. power plant, house-hold consumption), hence Jurassic gas reservoirs have been explored to develop and produce huge amount of sour gas fluid which is associated with significant HSE risks due to very high toxicity and corrosion impact (in addition to lack of local expertise in sour gas facility design and production). Although many articles have been published on how to execute mega sour gas projects, the industry will need to make a step change in its delivery performance of mega sour gas projects with improved know-how and expertise, and will need to re-energise it's focus on how to avoid unnecessary process s

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[No abstract available]

Abstract

The complexity of the production from Heavy Oil Field increases many folds during the lifecycle of the field. The inclusion of Process Safety Management (PSM) from concepts of the project adds value; however, the uncertainty can be very canny as the parameters keep varying over each production cycle. A large field development and the operation during the lifecycle should be harmonious; it is supported by PSM and Barrier Management which plays a vital role in preparing and guiding towards a holistic Risk Management. Technical Safety Studies can be challenging as scenarios keep changing on every production cycles and each of the uncertainty has to be compounded with different iterative simulations. They shall as minimum include H2S, Thermal expansions and possible thermal releases, corrosion rates, flow parameters and monitoring. The challenges has been addressed based on KOC's understanding of the risk, the Pilot Project experience. The significant barriers and process safety challenges

Abstract

Based on the North Kuwait Heavy Oil fields' development plan, by the end of 2019 more than 1,000 wells will be connected to the producing facilities. An extensive amount of surface and subsurface data will be collected and transmitted to the central databases. This paper describes the Data Management processes and workflows currently in place not only to use the captured and analyzed data for production and facilities optimized and safe operation but also the strategic plan for future integrated wells and facilities management. Different approaches for both at wells and surface facilities data sets are being implemented not only to monitor and optimize the wells and field performance but also to provide other disciplines with the right data in the right format at the right time. The vision is to move away from the current approach to a new one to handle automated real-time data capture, data analysis, data visualization and Exception Based surveillance within the domain of CWE (Collabo

Abstract

The Large Scale Steam Flood Pilot with two patterns in South Ratqa Field (Heavy Oil - North Kuwait) is considered the first of its kind in KOC and a major milestone for North Kuwait (NK) Heavy Oil Development program. The pilot program is crucial for NK Heavy Oil development plans as it will allow the evaluation of the Lower Fars Heavy Oil reservoir at close spacing, and it will assess the implication of the selected recovery process for South Ratqa (SR) field operations and project economics. In addition, the project will enable NK to:, Optimised production of Heavy Oil reserve through Steam Flood, Assess well completion integrity and optimum A/L type, Identify Cost optimization opportunities for Heavy Oil phased development The two patterns test different schemes, one for the evaluation of 10-Acre spacing with the second for evaluation of 5-Acre spacing with inverted five spot configurations. The 10-Acre pattern consists of 13 wells (Producer/Injector) plus 7 observation wells; the 5

Abstract

North Kuwait Jurassic Gas (NKJG) fields are challenging HPHT wells with near-critical fluids in reservoir conditions. These wells are deep and sour with 2-8 % H2S and 1-3 % CO2 with average reservoir pressure ranging from 10, 000-4, 000 psi and average reservoir temperature of ~275oF. Best practices in terms of developing these fields by using the best technologies in drilling, completion, and production are essential to maximize the reserve recovery in order to deliver hydrocarbon to the market. Due to anhydrite presence and existing high variation of natural fracture distribution along the wellbore with different lithology and reservoir properties. There is differential pressure depletion happens within the entire reservoir, so these reservoirs have been divided into different flow units based on stratigraphy and pressure differential. These layers have different productivity index based on production logging records and calibrated well production models due to existence of dual-poro

Abstract

A comprehensive development strategy for BGSL1 reservoir of Burgan Formation, deposited in Lower Cretaceous, of Greter Burgan field, Kuwait was formulated to increase the production of the low productive heterogeneous reservoir. The BGSL1 reservoir was deposited in shore face dominated coastline with protected tidal bay. The heterogeneous nature and low Sand: Shale ratio makes development of this important reservoir difficult. After studying the production performance of BGSL1 reservoir, mainly four technical challenges are identified. These are 1) wet production, 2) low productivity index, 3) short self-flow life and frequent work over needed and 4) Complexity in terms of lower API crude, multiple oil-water contacts and heterogeneity. Initial study for BGSL1 reservoir was started by revisiting all the wells drilled to BGSL1 reservoir. Remaining Oil distribution maps of each sub-layer were prepared which had given clear understanding of potential of this reservoir. BGSL1 reservoir rema

Abstract

Kuwait Oil Company manages the production and export of oil and gas with the associated facilities from different oil fields in the state of Kuwait. Kuwait Oil Company has ambitious growth targets with challenges of expanding portfolio, high water cuts, lower reservoir pressures, new facilities, and complex production processes. In recognition of these challenges, KOC Leadership Committee created the Production Excellence and Planning Team (PE&P) in June 2015. KOC assets are committed to the company's vision to achieve a leading global position in the Oil & Gas industry. Operational Excellence is an element of organizational leadership that stresses the application of a variety of principles, systems, and tools toward the sustainable improvement of key performance metrics. This is only possible through the consistent and transparent view of companywide production, capacity (wells and facilities), constraints and loss numbers. Efficiently deriving actionable insights from the vast amoun

Abstract

In Umm Niqa field, Lower Fars (LF) is a shallow, unconsolidated, sour heavy oil and low-pressure sand reservoir. During the current appraisal and exploratory phases, oil production forecasts based on reservoir simulation models were observed to be significantly higher than actual production. Furthermore, unexpected early water breakthrough and the rapid increase in the water cut added more complexity to the reservoir production. This paper will focus on how these challenges were addressed with a unique workflow. If the reservoir is producing more than one phase, then relative permeability determination becomes essential for the production forecast as well as production optimization to delay the water breakthrough. Due to the unconsolidated nature of LF reservoir, it was challenging to perform coring operation in this environment. In the few cases where cores were obtained, it was almost impossible to perform the relative permeability analysis on the core plugs. Therefore, there was a n

Abstract

Digital Oilfields worldwide have accomplished many value added benefits. This paper discusses the benefits realized after implementing DOF technology in Greater Burgan Field of Kuwait. It describes how oil production is being optimized and sustained consistently. It highlights the cost savings achieved and reduction in production losses based on numerous improvements in work processes. Inevitably the ease in production management has led KOC towards further expansion. Burgan DOF technology comprises of digital instruments and infrastructure installed on wells and production facility. Well data such as pressures, temperature, water cut, flowing status and choke size is transmitted in real time to the field operations center for continuous monitoring along with key facility data. The intelligent operations system at the main collaboration center has automated workflows and smart alarm managers to instantly detect and calculate losses from wells or facility issues. Engineers can quickly a

Abstract

Greater Burgan Field has been producing from more than 60 years and brings many challenges. The majority of the production comes from Wara and Burgan reservoirs. The Cretaceous Burgan sands are divided into five main reservoirs; two reservoirs consist of stacked, massive fluvial channels, while remaining three mostly consist of delta distributary channels and bays in a tidal delta setting grading to shallow marine. BGSM reservoir is one of the five reservoirs of Burgan reservoirs, which is deposited mostly by braided fluvial systems and is one of the major producers of the Greater Burgan Field. Some of the areas where remaining oil column of BGSM reservoir has become less; the optimization of production has been a challenge. This is due to the fact that due to less oil column; the production shortly becomes water wet and well ceased to produce by vertical or deviated well. To produce from BGSM reservoir, one horizontal well was drilled in a low potential area for the first time where n

Abstract

Asphaltene precipitation is caused by numerous factors such as temperature, pressure and compositional vartiations. Drilling, completion, acid stimulation, and hydraulic fracturing activities can also result in settling in the near-wellbore region. Heavier crudes have a fewer precipitation issue becasue of dissolving more asphaltene. Thus, it is crucial to understand the significance of each uncertainty and control variables not only theoretically, but also with application to real-life examples, such as with this model that uses a 32-degree API South American oil to demonstrate the importance of each variable to shed light in order to efficiently manage such reservoirs. A commercial optimization and uncertainty tool is combined with a full-physics commercial simulator, which can create a model to investigate the significance of major factors influencing the performance of wells in temperature-dependent asphaltene precipitation and irreversible flocculation. Temperature-dependent aspha

Abstract

Voidage replacement is a key element in displacement processes, not only for keeping the reservoir pressure at its initial level but also in mitigating surface subsidence in certain fields. Despite its simple definition, it is a complicated process in reservoir management because of uncertainities involved and lack of all required measurements due to economical or technical restrictions. Thus, every single decision parameter and their relative significance in voidage replacement process is important for robust reservoir management. In general, voidage replacement is achieved where injection is based on production. This study investigates the case of triggers where the production rate at the bottom hole conditions is predicated on the bottom hole flowing conditions or reservoir gas injection rate. A full-physics commercial reservoir simulator is coupled with robust optimization software, where a miscible flood operation is modeled with a group bottom hole flowing target coupled with voi

Abstract

One of the major challenges facing Kuwait mature oil fields is to maintain their current production and maximize recoverable reserves; to achieve Kuwait 2030 target: 4 MMSTBO. The challenging production environment in the selected area from Kuwaiti fields is not an exception, where high pressure and H2S wells are existing. Connecting wells, to the same processing facility, with varying in reservoir pressure, high, medium and low, create bottlenecks in the surface network. To find bottlenecks in flowlines and have an optimum distribution of wells; the engineers have built and studied flowline network model in-house using a commercial steady-state multiphase flow simulator for the wells connecting to one of Kuwait companys' Gathering Centre (GC). GC-XY was considered as its eight headers are ranging between high and low pressure headers, and receiving production from several fields in Kuwait. The project started by data collection, followed by quality check the flowing conditions for eac

Abstract

Production well testing is of paramount significance for building reliable production history of oilfields. Kuwait Oil Company (KOC) requires periodic testing of oilfield wells for production, pressure, and fluid property monitoring. In some cases, accurate flow-rate measurements cannot be conducted with conventional well test separators because flow rates are out of the operating range of the individual singlephase metering devices, challenging flow conditions (geometries) exist, or wells are flowing under non-critical conditions in which backpressure from the test separators or production lines affects well productivity. Typically, production well testing operations have been executed with portable testing units instrumented with multiphase flowmeters (MPFMs) or conventional test separators. A recently introduced mobile dual-leg MPFM unit with 19- and 40-mm venturi sizes (installed side by side) in a single skid was used for the first time in several KOC wells together with other loc

Abstract

Over the years KOC has been working to enhance the Health, Safety, Quality and Project Management of their projects through initiatives in order the meet the company's strategic goals of 2030. The company has recognized that the Project Management Consultants (PMC's) are key players in the execution of KOC's strategic projects. Therefore an initiative was put in place to develop an incentive/disincentive program which included the PMC's. The PMC's performance is based on how well the contractor is being managed for KOC. The primary objectives of the PMC Performance Enhancement Program are: ▷ Achieve improved PMC Performance ▷ Effectively manage the performance of the EPC Contractors for assigned projects within the approve schedule and budgets ▷ Encourage and reward the PMC's to achieve the set goals for the projects. This has been successfully implemented on several projects where all aspects of the program were proven to be successful. This program has been embraced by all of the PMC

Abstract

Each year the Company plans capital and maintenance programs to enhance and safely maintain the production system while satisfying all statutory regulations including employees' welfare. In fulfilling its role as the corporate level planning body of the Company, the Planning Group considers a wealth of policy issues that may influence the selection of projects. The list of proposed projects invariably exceeds financial targets. Allocating Company's finite resources is crucial to its long-term success. An annual task therefore is to reduce the number of projects to be within the total budget, while recognizing the various strategic, tactical and HSE objectives represented by these projects. The most successful companies are those that have a formal project screening process in place: they allocate resources efficiently, and commit to stopping on-going (carry-over) projects that do not meet continuation criteria (e.g. the project objectives have undergone revision). The focus of review,

Abstract

The re-acidization of HP-HT horizontal oil well Umm Guddair XXX in Kuwait resulted in a productivity index four times what was seen after the initial acidization. This astounding improvement in the results can be attributed to better acidization through thorough cleaning of the horizontal section prior to the 2nd stimulation, as well as placing the acid in stages and introducing a suitable diverting agent. Copyright 2005, Society of Petroleum Engineers.

Abstract

The emergence of multiple Jurassic carbonate play has opened up a new vista of exploration in the state of Kuwait. A strong need is felt to focus the exploratory efforts on the deep reservoirs below the oil producing Tertiary - Cretaceous strata across Kuwait. In absence of good quality seismic data below the Late Jurassic salt - anhydrite sequence the methods derived from the analyses of subsurface information obtained from exploratory drilling are utilized to complement to seismic study. The present paper describes one such method used as an aid to exploration of deep Jurassic reservoirs in North Kuwait. Three exploratory wells have penetrated Jurassic Middle Marrat reservoir facies in the Raudhatain field. The wells are drilled 5 to 9 km apart in an area of about 160 sq. km. The initial test results show that this carbonate reservoir has a potential of producing light oil @ 3800 to 5300 BOPD and gas @ 8.5 to 15.5 MMscf / D. The production has been obtained from both limestone matrix

Abstract

The area under study is Raudhatain field discovered in 1955 is faulted anticlinal dome developed on the Northern part of Kuwait. The Mauddud Formation from the Mid Cretaceous age was well developed and has a long production history. Around 150 wells were drilled targeting Mauddud reservoir mainly concentrating on the structure of Raudhatain field. Despite the long production history of Mauddud reservoir, still it is a relatively small stage of development, due to the poor aquifers. Under these circumstances, a detailed study was prerequisite for building 3D geological model of this carbonate reservoir, input to reservoir simulation models, which can constitute a significant challenge. Hence, before carrying out simulation planned to carry out seismic reservoir characterization using the Geostatistical inversion (GI) technique with the newly acquired broadband full azimuth seismic data. The GI accomplishes with the three major components Statistical modeling, Bayesian inference techniqu

Abstract

The area under study is Raudhatain field discovered in 1955 is faulted anticlinal dome developed on the Northern part of Kuwait. The Mauddud Formation from the Mid Cretaceous age was well developed and has a long production history. Around 150 wells were drilled targeting Mauddud reservoir mainly concentrating on the structure of Raudhatain field. Despite the long production history of Mauddud reservoir, still it is a relatively small stage of development, due to the poor aquifers. Under these circumstances, a detailed study was prerequisite for building 3D geological model of this carbonate reservoir, input to reservoir simulation models, which can constitute a significant challenge. Hence, before carrying out simulation planned to carry out seismic reservoir characterization using the Geostatistical inversion (GI) technique with the newly acquired broadband full azimuth seismic data. The GI accomplishes with the three major components Statistical modeling, Bayesian inference techniqu

Abstract

An assessment has been done on the prospectivity of the Makhul formation (Tithonian To Berriasian ) for unconventional resources in Kuwait fields. It is observed that the Lower part of the Makhul Formation is only likely potential target for unconventional hydrocarbon exploration as evidenced from the geochemistry data. A wide variation in the organic content is noticed from layer to layer.The porosity within the organic matter (less than 1 to 2%) is observed at nano micron resolution from the Micro CT,2DSEM measurements. Considering the high heterogeneity of the organic content and mineralogy within this stratigraphic succession, it is recommended to identify the prospective layers within the basal Makhul Formation (within the 100-250 ft section), with close sampling and geochemical analysis followed by selected SEM and FIBSEM measurements and integrate the organic content and porosity/ permeability data with distinctive unconventional log derived /interpreted parameters and geomechni

Abstract

Objectives: Proteinuria is one of the diagnostic criteria of preeclampsia (PE). Measurement of 24-hour urine protein is the gold standard method for detection of proteinuria in PE. The 24-hour urine sampling is time-consuming, and inconvenient. To evaluate the accuracy of protein/creatinine (P/C) ratio in detection of significant proteinuria (> 1 g/24-hours urine) in PE. Material and methods: One hundred and ten (110) preeclamptic women were included in this study and admitted for blood pressure monitoring, 24-hour urine collection, fetal well-being assessment and spot urine sample for measuring of P/C ratio. After thorough history and clinical examination, routine antenatal investigations were done for the women included in the study according to the hospital's protocol, and to exclude pre-existing chronic renal disease. Twenty-four-hour urine collection started on the morning following hospital admission. Spot urine samples were obtained shortly before the 24-hour urine collection fo

Abstract

Monitoring the reservoir pressures throughout the production life of the field is considered as a cornerstone for reservoir management and optimization of the development plans. There are many challenges to have routine and proper pressure records. Multi-zone single completion wells are one of these challenges, where it is difficult to acquire the reservoir pressure for each zone through the conventional pressure gauges. In addition to that, deferring the production or injection of high rate wells for quite time to acquire downhole static pressure data is adding more to these challenges. Raudhatain Zubair Reservoir is a layered reservoir with difference in reservoir pressure from layer to the other. Spectral Noise Logging technique has been utilized to estimate the average reservoir pressure for each perforated layer in a Multi-zone single completion oil producer. The noise logging survey has been carried out under flowing conditions and on different rates. The process of estimation th

Abstract

The Greater Burgan field is the second largest field in the world. With more wells being drilled the need for surveillance has increased to monitor the massive reservoir, depletion manner, remaining potential and pressure support. Processes to manage and interpret acquired data need to be established. Modern techniques applied on acquired data to detect deviations from expectation and taking prompt corrective actions need to be quantified to assess the value of information. This paper describes the approach towards development of an integrated reservoir surveillance plan for the field. A comprehensive effort was undertaken to review the historic surveillance activities and the interpretation of the acquired data over the last three years. The consequent value-adding decisions from effective use of surveillance information are highlighted through incremental benefits obtained in terms of production gain or water curtailment. The results are used to highlight the importance of an organiz

Abstract

The objective of this study is to develop an optimized and fit-for-purpose design for future surveys; a dense point-receiver 3D acquisition pilot has been decimated to simulate alternative acquisition geometries where advanced noise attenuation techniques have been tested. Noise attenuation using the true receiver coordinates have addressed some of the limitations of earlier DGF methods and further improved the S/N. Additionally, surface wave analysis, inversion and modelling was effective on the attenuation of coherent noise even when aliased. These developments in processing technology, in the context of integrated acquisition and processing design, have allowed us to redesign our acquisition geometries to be more cost-effective. Therefore, the design of the current acquisition of Burgan field was driven by the results of this study by using single lines of the point-receivers at a denser receiver line spacing, with symmetrical source geometry. The reduction in source and receiver li

Abstract

This paper presents the use of Simultaneous Inversion for the delineation of sealing shale for the Zubair reservoir in the Kra Al Maru area, West Kuwait. The Zubair Formation is a thick layer of sandstone with inter-bedded shale and is a major producer of hydrocarbon in northern part of Kuwait. The Zubair Formation has very good potential as a reservoir rock, but due to the absence of any vertical or lateral seal, trapped hydrocarbons have not been found in our study area. To explore the hydrocarbon potential in the Zubair Formation, this study focused on searching for cap rock (shale) within this formation. Shale within the Zubair Formation may act as cap rock for hydrocarbon entrapment, so discrimination of sand and shale is essential for the study. To address the challenge of sand and shale discrimination, Simultaneous Inversion (SI) was used. The Vp/Vs property of SI was used to differentiate the sand and shale facies and to identify a potential prospect zone for the Zubair reservo

Abstract

This paper presents the use of Simultaneous Inversion for the delineation of sealing shale for the Zubair reservoir in the Kra Al Maru area, West Kuwait. The Zubair Formation is a thick layer of sandstone with inter-bedded shale and is a major producer of hydrocarbon in northern part of Kuwait. The Zubair Formation has very good potential as a reservoir rock, but due to the absence of any vertical or lateral seal, trapped hydrocarbons have not been found in our study area. To explore the hydrocarbon potential in the Zubair Formation, this study focused on searching for cap rock (shale) within this formation. Shale within the Zubair Formation may act as cap rock for hydrocarbon entrapment, so discrimination of sand and shale is essential for the study. To address the challenge of sand and shale discrimination, Simultaneous Inversion (SI) was used. The Vp/Vs property of SI was used to differentiate the sand and shale facies and to identify a potential prospect zone for the Zubair reservo

Abstract

This paper presents the use of prestack geostatistical inversion (PGI) technique, for the delineation of thin sand intervals in the Wara Formations in the Magwa and Ahmadi fields, Kuwait. In this area, Wara Formations is predominantly sand and shale sequences, with higher proportion of shaliness compared to the adjacent Burgan field. Wara sands are good producers of hydrocarbon in the study area. The low P-impedance contrast between the sand and shale makes P-Impedance ineffective to discriminate them. The Vp/Vs ratio from the PGI is found to effectively discriminate these sand units from shale. The main inputs for PGI study are well log data, well log statistics and seismic angle stack data. Petrophysical analysis was carried out, which is essential for identifying reservoir facies. Two lithologies in Wara Formation are defined using well log analysis with Vshale cut off. Detailed well log statistics analysis (vertical size, layer constraints and lithology proportions) was carried out

Abstract

This paper presents the use of prestack geostatistical inversion (PGI) technique, for the delineation of thin sand intervals in the Wara Formations in the Magwa and Ahmadi fields, Kuwait. In this area, Wara Formations is predominantly sand and shale sequences, with higher proportion of shaliness compared to the adjacent Burgan field. Wara sands are good producers of hydrocarbon in the study area. The low P-impedance contrast between the sand and shale makes P-Impedance ineffective to discriminate them. The Vp/Vs ratio from the PGI is found to effectively discriminate these sand units from shale. The main inputs for PGI study are well log data, well log statistics and seismic angle stack data. Petrophysical analysis was carried out, which is essential for identifying reservoir facies. Two lithologies in Wara Formation are defined using well log analysis with Vshale cut off. Detailed well log statistics analysis (vertical size, layer constraints and lithology proportions) was carried out

Abstract

The study area is in the Burgan field located onshore in the South-East of Kuwait. Hundreds of wells have been drilled in this field proving the presence of oil in the Wara and Burgan Formations in the Middle Cretaceous interval. It was expected that mapping of the reservoir sands in these formations could be improved by utilizing the spatial coverage of the 3D seismic data. Reservoir characterization using post stack deterministic inversion method to estimate acoustic impedance (P-impedance) alone was not able to differentiate the reservoir and non-reservoir lithologies in these formations. This was due to the low contrast in P-impedance between sands and shales. An attempt at reservoir characterization was made by using shear impedance (S-impedance) along with P-impedance to discriminate shale and sand properties. Consequently, the simultaneous inversion method was used to derive these rock properties from the 3D seismic data integrated with well log data. The results from simultaneo

Abstract

This paper presents the use of Pre stack Simultaneous Inversion for identifying the extension of the sealing shale for the Zubair reservoir in the North Kuwait area. The Zubair Formation is a thick layer of sandstone with interbedded shale. The Zubair Formation has very good potential as a reservoir rock, but due to the absence of any vertical or lateral seal, trapped hydrocarbons have not been found in the study area. Shale within the Zubair Formation may act as cap rock for hydrocarbon entrapment, so discrimination of sand and shale is essential for the study. To address the challenge of sand and shale discrimination, Simultaneous Inversion (SI) was used. The Vp/Vs ratio generated using simultaneous inversion was used to differentiate the sand and shale facies. The gamma ray volume generated from Vp/Vs ratio volume was used to identify a potential prospective zone for the Zubair reservoir with both vertical and lateral seals. © 2017 SEG.

Abstract

The Hith and Gotnia formations in Kuwait are characterized by wide spread deposition of salt and anhydrite. The carbonates are often intercalated with anhydrites, and these carbonate stringers may act as potential reservoir rock for hydrocarbon accumulation. In recent drilling the presence of hydrocarbon has been reported from these carbonate layers. An integrated study was initiated in southwestern part of Kuwait to explore the prospectivity of the carbonate stringers. The density log profile from nearby area within the Hith/Gotnia Formation shows that density for salt, carbonate and anhydrites are 2.1 gm/cc, 2.7gm/cc and 2.9gm/cc respectively. Since anhydrite is a very hard rock, the presence of relatively soft, (porous) carbonates affects the rock impedance of the layer. This criterion has been prudently utilized to locate the potential prospect zone in the area. A post stack seismic inversion study was conducted in the area. The study has brought out that in the southwestern part o

Abstract

Characterizing heavy oil viscosity by nuclear magnetic resonance (NMR) relaxation time (T1 and T2) measurements is much more challenging than characterizing light oil viscosities. Crude oils contain a wide range of hydrocarbons, resulting in broad T1 and T2 distributions that vary with the oil composition. Most often, a single geometric mean value T1,gm or T2,gm is correlated with the crude oil viscosity, which cannot accurately account for the inherent complexity of the oil constituent information. Furthermore, as the viscosity increases, some of the protons in the oil relax too quickly to be observable by logging or laboratory NMR instruments. This results in deficiencies of relaxation time and signal amplitude that give rise to apparent T1 and T2 distributions (T1,app and T2,app) and apparent hydrogen index (HIapp). Using T1,app and T2,app distributions in NMR viscosity models could produce erroneous heavy oil viscosity estimations. Several attempts have been made to overcome these

Abstract

Aims: Thermal injury to the oesophagus is an important cause of life-threatening complication after ablation for atrial fibrillation (AF). Thermal protection of the oesophageal lumen by infusing cold liquid reduces thermal injury to a limited extent. We tested the ability of a more powerful method of oesophageal temperature control to reduce the incidence of thermal injury. Methods and results: A single-centre, prospective, double-blinded randomized trial was used to investigate the ability of the ensoETM device to protect the oesophagus from thermal injury. This device was compared in a 1:1 randomization with a control group of standard practice utilizing a single-point temperature probe. In the protected group, the device maintained the luminal temperature at 4°C during radiofrequency (RF) ablation for AF under general anaesthesia. Endoscopic examination was performed at 7 days post-ablation and oesophageal injury was scored. The patient and the endoscopist were blinded to the random

Abstract

This study demonstrates the feasibility of using low-field nuclear magnetic resonance (LF-NMR) relaxometry for the identification and characterization of crude oils as an alternative and robust technique. In general, the NMR relaxometry is based on monitoring nuclear spin dynamics (molecular dynamics) and analyzing its dependencies on the physicochemical properties of samples. The approach reported in this study comprises the initial analysis of crude oils by several standard American Society for Testing and Materials (ASTM) methods followed by a series of routine LF-NMR measurements. The LF-NMR based method showed the following practical advantages: It is non-destructive, requires minimum sample preparation without hazardous solvents, which helps keeping analysis costs reasonably low. The NMR analysis itself is fast and takes a few seconds for a crude oil sample. The whole method workflow is simple and easy to perform in specially developed user-friendly software that was “trained” to

Abstract

This paper describes the mobilization of a snubbing unit and blowout preventer (BOP) stack in the Middle East and their use to enable the control of a well with an underground blowout and surface broaching within a short time. The mobilization timeline is provided, along with details about how the snubbing unit and BOPs were integrated with existing equipment to enable re-entry into the blowout well. The procedures and equipment used to enable a stable rig up and well entry are discussed. The paper also describes the situation within the well and the procedures used to enable control. Changes to the original plan, the reasons for the changes, and the results are also described. Mobilization, rig up, and testing were completed within 12 days of receiving instructions to proceed. The well was controlled and left in a safe condition within an additional 14 days. The original plan had to be continuously reviewed and modified as more information became available during the snubbing operatio

Abstract

Land seismic data are often plagued with substantial amounts of coherent surface-related noise that blurs the reflection signals needed for imaging of the deeper lying targets. Such waves typically consist of a combination of Rayleigh-waves, Love waves, and guided P and S waves. Here we present a method that uses the phase-velocity dispersion of un-scattered Rayleigh waves to first invert for the near-surface (shear-wave) velocity. Once a model is obtained that accurately fits the locally observed phase-velocity dispersion, the resulting modeled dispersion can be used to calculate the travel-times and amplitudes of Rayleigh-waves as a function of frequency and mode number. In this way the un-scattered Rayleigh waves can be modeled in a laterally and vertically varying medium. This then allows an adaptive subtraction procedure to remove the undesired Rayleigh wave signal. The benefit of this method is that it is not affected by aliasing of the signal and as such allows removal of aliase

Abstract

Land seismic data are often plagued with substantial amounts of coherent surface-related noise that blurs the reflection signals needed for imaging of the deeper lying targets. Such waves typically consist of a combination of Rayleigh-waves, Love waves, and guided P and S waves. Here we present a method that uses the phase-velocity dispersion of un-scattered Rayleigh waves to first invert for the near-surface (shear-wave) velocity. Once a model is obtained that accurately fits the locally observed phasevelocity dispersion, the resulting modeled dispersion can be used to calculate the travel-times and amplitudes of Rayleigh-waves as a function of frequency and mode number. In this way the un-scattered Rayleigh waves can be modeled in a laterally and vertically varying medium. This then allows an adaptive subtraction procedure to remove the undesired Rayleigh wave signal. The benefit of this method is that it is not affected by aliasing of the signal and as such allows removal of aliased

Abstract

KOC have been drilling deep HP/HT wells for over thirty years during which time the well prospects have become more challenging, aiming for new frontier areas with increased depth and formation difficulty. The rig designs employed have therefore been developed over the years with new technologies being incorporated to meet these challenges, and to improve safety and operational performance. In 2011 KOC looked into the enhancement of the equipment specifications for deep drilling rigs to integrate 'State-of-the-Art' technologies in the new contract terms. UPDC-776 was the first of the existing fleet rigs to be upgraded and this work was handled as an integrated project by the rig contractor working in close cooperation with the field operator. With regard to the rig design, major changes were made to enhance safety, capacity and automation of the drilling functions. These modifications included; re-design of sub-structure to incorporate full 15K BOP stack rig-up, upgrade of TDS, 2200HP

Abstract

[No abstract available]

Abstract

The asset optimization system deployed in Kuwait's Greater Burgan oil field involved development of an integrated model of the processing facility, flowlines and wells. The objective of the integrated asset model is to achieve production optimization from the network considering well performance and restrictions combined with the limitation imposed by the surface piping network and the processing facilities. The Burgan oil field's integrated digital field (KwIDF) automation system monitors well and plant instruments in real time from SCADA and DCS systems. It uses real time wellhead pressure and water water-cut measurements for virtual metering and calibration of the well and network models. To maintain the facility production target, various built-in production optimization scenarios are run daily and the results are visualized through smart dashboards in the state-of-the-art collaboration center. The results are shown as new optimized set points for choke or header changesto achieve

Abstract

Viscosity is driven by asphaltene content and is a key parameter in the development of heavy oil fields. Understanding fluid composition and temperature and pressure-induced changes in fluid viscosity is vital for an optimized production strategy and surface facility design. A recent field and laboratory study exemplifies the steps necessary to obtain the fit-for-purpose data from heavy oil samples. This paper presents the case study of a new downhole optical composition analysis sensor used during real-time downhole fluid analysis and sampling for the first time in a Kuwait heavy oil formation. The primary objectives of a sampling program are to confirm fluid indications on the openhole logs and collect crucial pressure/volume/temperature (PVT) samples. The downhole optical composition analysis sensor provides the information necessary to estimate a sample contamination level. It also indicates when the sample is sufficiently clean for PVT analysis. The samples should be acquired from

Abstract

Kuwait Oil Company (KOC) is running two pilot projects in South Ratqa Field to evaluate steam injection using cyclic steam stimulation (CSS) and steam flooding (SF) methods. These projects are the first of their kind in KOC history and one of the major milestones in the North Kuwait Heavy Oil Development. Two large-scale thermal pilot (LSTP) projects are located north and south of the South Ratqa Field, with the north running two different areas of 10 and 5 acres and well completion and the south running one area of 5 acres. KOC has been injecting steam in these pilots in an unconsolidated high viscous formation since 2015, beginning with a CSS process that migrating to SF during the second half of 2017. A fundamental goal to help ensure success with this type of project is carefully monitoring the injected steam per well and per formation layer by installing fiber optic distributed temperature sensing (DTS) and pressure gauges in a portion of the wells; this goal was defined at the be

Abstract

Many unforeseen circumstances can occur when coiled tubing (CT) is deployed into a well with differential pressure sticking being one such potential problem. Diagnosing wellbore data before operating on a well is important but does not eliminate the possibility of stuck CT. With the increase in use of CT on wells with extreme conditions, the requirement to find solutions that can help retrieve the CT and its bottom hole assembly (BHA) is crucial. When using conventional CT equipment, the operator will have access to several parameters, such as weight, circulating pressure, wellhead pressure (WHP), and depth. However, all these are surface parameters, meaning they are obtained based on the surface conditions. Having accurate downhole information to accompany the surface data can be much more helpful when encountering differential pressure sticking situations. This paper presents the application of real-time hybrid CT (RTHCT) technology to overcome stuck CT. The technology incorporates a

Abstract

The Burgan sandstone reservoir in the Minagish field of Kuwait is a complex depositional sequence that makes targeting Upper Burgan sands unpredictable due to channeling limiting the reservoir exposure. The area is complicated further by oil-water contact (OWC) uncertainty due to the long history of oil production. The objective of the well was real-time OWC mapping to provide reservoir insight, maximize pay zone exposure and extend the well life through optimizing the completion and production regime. Recent production pulsed-neutron capture (PNC) logging in an offset well showed watering in the Upper Burgan reservoir. This might indicate a change in the level of the OWC or water coning. Utilization of an ultra-deep azimuthal resistivity (UDAR) mapping service was planned to help locate the OWC below the well trajectory and simultaneously identify and track the desired target sandstone sequence. UDAR has proven its capability to map reservoir boundaries and the OWC in real time, durin

Abstract

As part of any successful development plan of any hydrocarbon field, drilling boreholes safely is a key factor to make the entire process safe, economic and environmentally friendly. One of the main factors that dictates whether a borehole is going to be drilled safely or not is to understand the geomichanical behavior of the different formation to be penetrated. A definition of geomechanics could be stated as the science that studies the relationship between each of; in-situ stresses, rock mechanics, and the drilling fluid properties. In Kuwait and during the course of efforts to develop Wara channel sands in Minagish Field to the west of the country, Kuwait Oil Company (KOC) realized that continuing to drill development wells using conventional drilling practices is not any more an easy task. Considerable non-productive time has been recorded due encountering events such as shale carvings and pack off leading to stuck pipe. In addition, partial to total lost circulation were faced wh

Abstract

One of the first sources for formation evaluation while drilling a well is the gas data provided by the mud logging services, that is used increasingly as preliminary real-time reservoir interpretation to identify gasoil or oil-water contacts, reservoir entry points, lithological changes and other applications. Gas ratio analysis and interpretation is a very valuable formation evaluation tool for geologists and petrophysicists to characterize the hydrocarbon fluid types and rock properties. Gas ratios when used in combination with wireline or logging while drilling tools can help resolve uncertainties that otherwise could only be resolved by testing a well. Jurassic deeper wells (>11000 ft) with a varying pressure regimes, very often the wireline logging or Logging while drilling (LWD) logs are cancelled due to several drilling related complications especially mud gain/loss situations. In these wells, Gas while drilling becomes a very unique and important tool that can provide signific

Abstract

This paper reviews recent developments in enhanced oil recovery (EOR) techniques published in SPE conference proceedings for 2007 to 2009. It also updates the EOR criteria developed by Taber et al. in 1996 based on field applications reported in Oil & Gas Journal and at various SPE conferences. It classifies EOR methods into five main categories: gas-based, water-based, thermal, others, and combination technologies. New developments in EOR techniques, chemicals, and mechanisms are summarized to clarify advances in EOR criteria beyond previous limitations. Reservoirs that had previously been ruled out based on specific reservoir conditions are now candidates under updated EOR screening criteria. To demonstrate this potential, this work has established guidelines for the selection and optimization of chemical EOR methods for a specific reservoir. Copyright 2010, Society of Petroleum Engineers.

Abstract

The objective of this paper is to illustrate the use of pulsed neutron capture log in reconstruction of water encroachment history in time and space in a brown field. Time-lapse pulsed neutron logs tracked the movement of oil-water contact in wells through time. This data from multiple wells was used to reconstruct the oil-water contact surfaces at different times for the area studied. The study resulted in a remaining oil column height map for the area and also predicted future water movement patterns. The remaining reserves at different times were calculated using a static model and these fluid contact surfaces. Estimated production between these time surfaces as computed from the static model matched well with the recorded actual production giving credence to the study. © 2014 EAGE www.firstbreak.org.