Abstract

This paper proposes a novel approach that combines physics-based numerical simulation with deep-learning neural networks to create an AI-Physics hybrid model for reservoir simulation. Our primary objective is to reduce the time of history match and achieve the best match between model and observation data using our hybrid model. We trained our model using historical data and created a reliable forecasting model that predicts field behavior and proposes new scenarios to improve production in the upcoming years. To test our model, we combined AI physics history training with blind test prediction calculations of the remaining oil map, and the AI physics model created a forecast scenario definition based on this map. Our proposed simulation method can reduce the time of history matching and scenario evaluation by 90-95%. We created three improved forecast scenarios based on predefined scenarios that can produce millions of standard barrels more oil over three years than the original devel

Abstract

Introduction: A genetic variation at the level of aromatase enzyme and/or androgen receptors was suggested in polycystic ovary syndrome (PCOS). Aim of the study: To determine the androgens elevated and diagnostic for PCOS. Material and methods: A total of 120 PCOS women were compared to non-PCOS controls in this study. The studied women were evaluated thoroughly, including: day 2-3 hormonal profile and any hormonal change confirmed by two laboratory results eight weeks apart. Collected data were analysed to determine the androgens elevated and diagnostic for PCOS. Results: The luteinising hormone (LH) and LH/follicle stimulating hormone (FSH) ratio were significantly high in the studied PCOS group compared to controls (p = 0.02 and 0.01, respectively). In addition, total and free testosterone and androstenedione were significantly high in the studied PCOS group compared to controls (p = 0.001, 0.003, and 0.02, respectively). The studied PCOS group had higher relative risk (RR) and odds

Abstract

The Great Burgan reservoir is the largest sandstone oilfield in the world, it has been developed and produced since the 1930s. Historically developed through deviated wells, a new project of horizontal wells was initiated recently to produce from the UB3 reservoir unit. A pilot hole is usually required to identify the presence of productive sublayers and the depth of the oil-water contact (OWC), which must be avoided in the horizontal section. Elimination of the pilot hole would help to minimize the time and cost of development (Al Khalifa et al. 2020). The azimuthal ultra-deep resistivity mapping service (UDR) has proven its capability to eliminate the need for pilot holes by mapping reservoir boundaries and OWC on the fly, earlier than with traditional methods. This facilitates real-time geosteering to land the well in a single drilling run in the productive zone. Additionally, it helps to reduce non-productive time by making it easier to stop drilling and set casing above a target l

Abstract

Mauddud carbonates in the Bahrah Field of Kuwait, with their low permeability, are often considered as unconventional reservoirs, which require multi-stage hydraulic fracturing stimulation. Optimal stage distribution is one of the key elements in this type of completion design. This paper presents the forecasting methodology for estimating the production performance of each stage which can later help to optimize stage placement in long horizontal sections. High-resolution micro-resistivity imaging and an azimuthal sonic tool, in combination with conventional triple-combo logs and formation pressure testing, were run in a 6.125-in. section to help develop an effective and sustainable production plan, based on the petrophysical and geomechanical properties of the heterogeneous tight carbonate reservoir. The use of image data helped to evaluate the permeability distribution close to the borehole wall more accurately than conventional porosity-based permeability relationships, which showed

Abstract

A novel encapsulated deep eutectic solvent (DES) was introduced for biodiesel production via a two-step process. The DES was encapsulated in medical capsules and were used to reduce the free fatty acid (FFA) content of acidic crude palm oil (ACPO) to the minimum acceptable level (< 1%). The DES was synthesized from methyltriphenylphosphonium bromide (MTPB) and p-toluenesulfonic acid (PTSA). The effects pertaining to different operating conditions such as capsule dosage, reaction time, molar ratio, and reaction temperature were optimized. The FFA content of ACPO was reduced from existing 9.61% to less than 1% under optimum operating conditions. This indicated that encapsulated MTPB-DES performed high catalytic activity in FFA esterification reaction and showed considerable activity even after four consecutive recycling runs. The produced biodiesel after acid esterification and alkaline transesterification met the EN14214 international biodiesel standard specifications. To our best knowl

Abstract

Alkaline-Surfactant-Polymer Flooding (ASP) has the potential to unlock massive oil reserves in quest of production sustenance within the bounds of profitable economics. Field results from a successful ASP pilot targeting the massive Sabriyah Mauddud (SAMA) reservoir in Kuwait, using a regular five-spot with five acre-spacing are encouraging. Oil cut post softened water pre-flushing reached 0% and tracer data indicated pre-mature breakthrough at the central producer. This necessitated in-depth conformance gel treatment1-3 to induce flow under matrix conditions and softened water injection resumed thereafter for a period of ~3 months, during which oil cut ranged between 2 to 6%. Oil cut then decreased to 0% again, beyond which polymer pre-flushing was introduced for a period of ~2 months, during which oil cut was increased to up to ~4%. ASP flooding resulted in an unambiguous and sustainable increase in oil cut with an average of ~12% over a period of more than 6 months. Furthermore, dai

Abstract

We believe our prime responsibility is to protect the environment by utilizing the energy in a responsible way and also by reducing the wastage of energy. Energy conservation will play a vital role in climate change and leave our planet pristine for the next generations to come. In light of our Company’s ambitious vision of reducing energy consumption and losses and to conserve energy without disturbing the regular business of the Company, we have started to evaluate all the options to conserve the energy by incorporating the latest technologies, conducting awareness programs and optimizing the energy consumption. In line with our objectives, we conducted a study on one of the existing office building to check all the possibility of reducing energy consumption without disturbing the regular activity. At the end, we realised that the simple and easy way to conserve Energy is through conducting an Energy Audit and implementing Energy Audit recommendations. Copyright 2019, Society of Petr

Abstract

West Kuwait's 22-in. section comprises a vertical hole through 3,500 feet of interbedded carbonates varying significantly in compressive strength, and drilled commonly with minimal or no fluid returns. The section is typically drilled with roller-cone tungsten carbide insert (TCI) bits because large polycrystalline diamond compact (PDC) bits are extremely costly and require expensive performance motors to support their generated torque. PDC bits are also at risk of impact damage when drilling through the interbedded formations in this interval. Operators tend to apply higher drilling parameters while in the lower compressive strength intervals to achieve higher rates of penetration (ROP). Consequently, when the TCI bit enters the following harder formations with the same high operating parameters, it often suffers severe cutting structure damage. The result is reduced ROP. Greater weight on bit is then applied, causing further bit damage and possible sealed bearing failure. An engineer

Abstract

Optimised drilling performance requires matching the right drill bit technology to an application, which can be an engineering challenge. Hybrid bits provide versatility in drill bit selection that was previously not possible with conventional drill bit technology, allowing for a broader range of applications. This paper details the results of a case study where polycrystalline diamond compact (PDC), tungsten carbide insert (TCI) and hybrid bits were tested in the same application in an attempt to improve drilling performance. Each drill bit type has its strengths and weaknesses, and is therefore suitably matched for specific applications. Sometimes, a specific technology matches well to the application, and it is the ideal solution; however, there are many cases where the ideal drill bit type isn't so clear. Hybrid drill bit technologies produced a new generation of bits. These bits reduce the difference between specific bit technologies, enabling them to outperform either type in dem

Abstract

Producing hydrocarbons at appraisal and development targets from deep, sour, over-pressured and HPHT carbonates in North Kuwait has been a challenge driven by the complex reservoir heterogeneity as well as the damage induced by the use of barite-laden heavy oil-based mud (OBM) in drilling and during installation of production tubing as completion fluid. Due to the tight formation properties and the added damage induced by OBM, matrix acidizing does not always deliver hydrocarbons at economic rates. Such zones require hydraulic fracturing under challenging conditions imposed by the wellbore limitations, such as high degree of deviation, smaller tubing as the frac string, and length limitations of the seal-bore assembly, as well as the on-site presence of a deep drilling rig to complete the tests effectively and on-time. Tubing conveyed perforation (TCP) and wireline perforation techniques require wells to be subdued prior to the installation of final completion due to the over-pressured

Abstract

Excess fluid leak-off, a challenge in Kuwait's naturally fractured tight carbonate formations, can compromise post-fracture productivity. Past acid fracture treatments, both for moderate and high temperature formations failed to generate the long differently etched fracture due to excessive leak-off. Treating zones with multiple perforated intervals in a single stage, particularly in pay zones with long heterogeneous rock properties can result in non optimal stimulation. Therefore, a new approach was developed with proven success to enhance fracture conductivity and overall production by efficient control of fluid leak-off. This novel approach incorporates the use of far-field and near-wellbore diverting systems into the acid fracture design. These solid particulate diverters (SPD) include low and high temperature systems that provide enhanced near-wellbore diversion in both case and open-hole applications. The SPD are designed to bridge across perforations and fractures in the higher

Abstract

An improved workflow for handling an excess of Hydrogen Sulfide (H2S) in treatment facilities is presented. The objective is for the selection of wells to decrease H2S production by reduction of choke sizes with the lowest possible impact on oil production. During operational restrictions in a gas treatment plant, it is necessary to reduce the H2S quantity received at the facility. To perform this operation, an approach is to limit the production from wells with the biggest rate production of H2S (volume); another solution is to restrict the wells with the highest concentration of H2S (% molar - composition); However, both scenarios have an impact on oil production. KOC - KwIDF Jurassic, has developed a procedure that considers the derivative of the produced H2S curve as a function of produced Oil to find the optimal scenario. The proposed method was evaluated using the results from a sequence of monthly allocations that include characteristics such as: facility, number of wells, and f

Abstract

In this study a land surface CSEM dataset acquired over a heavy oil reservoir was inverted for resistivity structure through 3D CSEM constrained inversion. Unconstrained and constrained results proved good match with available well data. High/low saturated sands respond differently in terms of resistivity signature, therefore the recovered model from CSEM measurement can be used for prospect ranking/de-risking prior to drilling campaigns. 3D constrained inversion provides evident enhancement in model resolution, both laterally and vertically. This shows that surface CSEM, when complemented with the necessary apriori information and ancillary G&G data, is capable of recovering the variations of resistivity within the formation with a resolution comparable to the distribution of the well logs in the area. The technology can also be applied for monitoring applications, using surface CSEM surveys to complement the more localized measurements performed at reservoir depth, such as resistivit

Abstract

Promotion of horizontal well drilling started with inflow control device (ICD) completion to boost the hydrocarbon production as per the KOC 2030 strategy. Drilling these wells revealed many technical issues leading to stuck pipe due to improper hole cleaning. The rate of penetration (ROP) in the buildup and lateral sections was erratic. Drilling a pilot hole and performing pipe-conveyed logging runs were the main factors contributing to excess rig time. It was observed that drain hole cleaning methods and drilling time optimization needed to be improved. These factors increased rig time by about 40 while drilling many horizontal wells in the North Kuwait (NK) horizontal operation, adding significant costs to the well budget. While drilling these horizontal wells, well design was optimized and the drilling team applied the optimized design that increased hole-cleaning effectively, improved ROP and reduced the logging time. The 6%-in. and 8%-in. motorized rotary steer-able systems (RSS)

Abstract

Well ‘A’ is a horizontal well drilled in the primary and productive upper layer of the carbonate reservoir just below 7,750 ft TVD, with lateral length of 3,495 ft. This layer, due to inherent well placement, presented completion and production challenges attributed to low permeability and with limited scope for production enhancement. The asset team required an effective solution to drain reserves from this well and for evaluating future well placements. Near-wellbore (NWB) acid stimulation technique was preferred over conventional acid fracturing due to low vertical stress contrast and high tortuosity effects caused by lateral azimuth relative to maximum stress orientation. Based on the Bernoulli concept for fluid diversion and using a dual path pumping system, initiation and propagation of micro-fractures was achieved by pumping fluid through tubing and annulus with a controlled pump schedule. A specially designed high-pressure tool was used for creating formation cavity by pumping

Abstract

The Minagish field in West Kuwait is a high potential field which poses several challenges in terms of hydrocarbon flow assurance through highly depleted tight carbonate intervals with uneven reservoir quality and curtailed mobility. These conditions have shifted the field development from vertical to horizontal wellbore completions. Achieving complete wellbore coverage is a challenge for any Matrix Acid treatment performed in a long openhole lateral with disparities in reservoir characteristics. The fluid will flow into the path of least resistance leaving large portions of the formation untreated. As a result, economic Acid treatment options dwindle significantly, thus reservoir stimulation results are not always optimum. A multistage acid stimulation technique using Integrated Dynamic Diversion (IDD) has been performed in a West Kuwait field well. The process uses active fluid energy to divert flow into a specific sweet point (high pressure point) in the lateral, which can pinpoint

Abstract

In the current cost-constrained oil field environment, operators must complete their wells while minimizing capital expenditure. Operators respond to these challenges by utilizing customized diagnostic services and specialized tools in a single run to save on rig costs. Coiled Tubing (CT) deployed fiber-optics assist in taking Distributed Temperature Sensing (DTS) during acid stimulations to estimate fluid volume distribution in the horizontal openhole with a specialized jetting tool to create wormholes and complex microfractures. This paper discusses an acid stimulation process using dynamic fluid energy to divert flow into a specific sweet spot in the well to initiate and accurately pinpoint acid stimulation. The treatment efficiency was monitored and visualized in Real Time (RT) with CT-conveyed fiber-optic DTS. This acid stimulation process, named Integrated Dynamic Diversion (IDD), often uses two independent fluid streams: the acid phase down the treating string and other liquids

Abstract

The Najmah carbonate-shale formation, an unconventional Jurassic kerogen layer in the North Kuwait region, has undergone testing, revealing its significant potential as a gas, condensate, and light oil reservoir in various well locations and as a prolific source rock. Given its exceptionally low porosity, the flow-control mechanism is heavily reliant on the presence of a natural fracture network. This layer, previously referred to as Najmah shale, serves as the source reservoir, characterized by its abundant organic-rich clay with both argillaceous and calcareous components. This is evident in the notably high total gamma ray values, which are accompanied by elevated uranium levels on spectral gamma ray logs. Matrix porosity averages between 2% and 6%, permeability is low, ranging from 0.01 to 1.5 mD, and the total organic content (TOC) falls within the range of 2% to 30%. The precise identification and interpretation of fractures, bed boundaries, and borehole breakout through high-res

Abstract

The Lower Zubair sand reservoirs have produced or shown oil in several but not all of the wells drilled in western and southeastern Kuwait. Evidence from the available core and log data analysis suggests that the Lower Zubair sand distribution consists of NE-SW trending estuarine channel fill. Thin due to their strati-structural nature, these Zubair sands are present at some places and absent at others. The tectonic activity in the area has resulted in faults and fractures in the interval comprising not only the Lower Zubair sands but the Middle and Upper Zubair sands as well. In general, the impedance contrast between these thin Zubair sands and the underlying Ratawi shale is poor. Therefore, the challenge is to identify not only the spatial variability of these Lower Zubair sands but also crosscutting faults and fractures. We address these challenges by first enhancing the bandwidth of the available seismic data using spectral inversion to estimate thin bed reflectivity, followed by

Abstract

The Lower Zubair sand reservoirs have produced or shown oil in several but not all of the wells drilled in western and southeastern Kuwait. Evidence from the available core and log data analysis suggests that the Lower Zubair sand distribution consists of NE-SW trending estuarine channel fill. Thin due to their strati structural nature, these Zubair sands are present at some places and absent at others. The tectonic activity in the area has resulted in faults and fractures in the interval comprising not only the Lower Zubair sands but the Middle and Upper Zubair sands as well. In general, the impedance contrast between these thin Zubair sands and the underlying Ratawi shale is poor. Therefore, the challenge is to identify not only the spatial variability of these Lower Zubair sands but also crosscutting faults and fractures. We address these challenges by first enhancing the bandwidth of the available seismic data using spectral inversion to estimate thin bed reflectivity, followed by

Abstract

Electric Submersible Pump (ESP) is extensively used by Kuwait Oil Company (KOC) for the producer wells. In the Minagish field (West Kuwait) of KOC, Corrosion related issues in ESP producer wells have been observed due to increasing water cut (WC), H2S, and CO2. KOC embarked on a trial in the Minagish field to install Glass Reinforced Epoxy (GRE) lined tubing for ESP completion in a candidate well having increasing WC, CO2, and H2S. The installation was done in 1 well, and the well has been producing without any issues for more than 2 years, thereby increasing the Mean-Time-before-Failure (MTBF) and contributing to sustained production as compared to when the well was completed with Carbon steel tubing. Corrosion in the tubing can lead to loss of tubing metal wall or corrosive scale formation. In several cases, holes in tubing were formed, causing the produced fluid to recirculate within the wellbore, altering the ESP performance and loads. The GRE liner acts as a protective isolating l

Abstract

The 1st oil in Kuwait was discovered in Bahrah in 1936. However, it was found uneconomical to develop this field due to complicated geological structure, formation tightness, cost and lack of technology at that time. In 2016, KOC has accomplished subsurface evaluation study to re-develop Bahrah field utilizing advanced fracturing technique. In last 5 years, the outcome of this study was applied successfully and resulted in remarkable production incremental from from ~3 MBOPD to more than 40 MBOPD. Multi-stage fracturing helped to unlock potential in most tightness carbonate formation in North Kuwait fields. Nevertheless, more studies was conducted to optimize the fracturing and completion design to improve well productivity as well as uniform production profile through well bore. Multi stage fracturing in open hole was the common technique since new development plan started. Although this technique had positive impact on overall field production, but it was observed uneven flow through

Abstract

Achieving excellent HSE performance is one of the main objectives of any industry, especially by High Hazard or Major Accident Hazardous (MAH) industries. Considering various national and global market demands, Oil & Gas industry must be ready to embark on challenging scenarios. To ensure such challenges are successfully addressed, the role of business partners (Business Partners) is very much vital and important as many projects are to be executed to achieve the set objects/targets safely. In many organizations, HSE (Health, Safety and Environment) or HSSE (Health, Safety, Security and Environment) has been considered as one of the strategic objectives. In order to achieve such objectives, moving together with Business Partners (Contractors) bring lot of importance. In addition, this makes organizations to uphold a safe work environment at the work sites that demands and expects collaboration and support from the Business Partners who are on board as well as who will be on board with

Abstract

Maximizing oil production by implementing appropriate latest technology is of utmost importance to meet the KOCs strategic goals. The Burgan Formation in the Sabiriyah field is of Cretaceous age and consists of three reservoirs viz, Lower, Middle and Upper Burgan. The Upper Burgan is broadly divided into seven lithological units. Among them, Upper Burgan 2 (UB2) and Upper Burgan 4 (UB4) litho units demonstrates comparatively good reservoir quality with sufficient lateral extension. The Upper Burgan reservoir in Sabiriyah field is very heterogeneous and complex in nature. The reservoir was developed through vertical wells all these years. However, to enhance production contribution from this complex reservoir, a paradigm shift in development strategy was adopted. Accordingly, a first ever non-conventional well (NCW) was planned, successfully drilled and completed with ICD. The detailed geological studies and information from dynamic data were integrated in identifying the target. The tw

Abstract

The North Kuwait Jurassic Complex (NKJC) consists of six fields with four identified reservoirs in the naturally fractured Jurassic carbonate section. An integrated model incorporating seismic, geological, petrophysical, and engineering data is built to estimate the hydrocarbon volumes and provide multiscenario production forecasts for the NKJC. Water saturation is populated in the static (fine-grid) model using a saturation height function (SHF), which is a continuous function of porosity and height above free-water level (HAFWL). The SHF is equivalent to a capillary pressure (at reservoir conditions), which is a function of porosity and water saturation. Capillary pressure curves based on the SHF are used to initialize water saturation in the dynamic (upscaled) model. Given the fact that reservoir simulators cannot handle capillary pressure curves as continuous functions of porosity, discretization of the porosity-dependent capillary pressure function was performed. For this purpose,

Abstract

Kuwait Bay is an imperative characteristic of the State of Kuwait. It has a number of major activities existing around it, including, business, industrial and recreational ones. The phase of construction and development of projects, and their resulting pollution have led to major change in the features of the area. The purpose of this research is to serve as a managing tool for decision-making through the environmental assessment of Kuwait Bay. Due to the multiplicities and diversities of the man-made activities and the natural environmental setting of the bay, the impacts are out looked on a holistic approach rather than on a single approach. The methodology of assessment including, sampling and analysis of water and sediment, statistical analysis, as well as application of the Rapid Impact Assessment Matrix (RAIM) in order to analysis the impacts in an integrated approach. The southern areas of the bay are the main sources of pollution that distributed northward to cover the central

Abstract

This paper presents the results of reservoir simulations of both chemical and gas EOR processes for the Mauddud reservoir in the Sabiriyah field (SAMA) in Kuwait, which is a high-temperature and high- salinity carbonate reservoir. The subject reservoir has been under pattern waterflood. Many wells experienced water breakthrough with considerable increase in water-cut due to high reservoir heterogeneity and adverse mobility ratio. Sector-scale simulations of recovery techniques such as miscible CO2, water-alternating-gas (WAG), and chemical EOR processes were performed. The results indicate the potential for significant improvement in recovery efficiency over continued waterflooding. Subsequently, a pilot-scale simulation model was created as a guide to field pilot tests of the EOR processes. One of the challenges in developing the simulation model was to capture the reservoir dynamic characteristics. We present a method of incorporating dynamic data in model construction stage and mode

Abstract

[No abstract available]

Abstract

Kuwait Oil Company (KOC) has undertaken implementation of an Alkali-Surfactant-Polymer EOR pilot in probably the world's first carbonate reservoir in Sabiriyah Mauddud reservoir with billions of barrels in oil-in-place. This project in the North Kuwait area is being pursued with the help of industry experts in chemical EOR who are involved in conceptualization, pre-planning, pilot design and execution. A normal 5-spot, 5.5-acre pilot is presently operational since June 2017 with water injection in progress. Encouraged by the excellent results of a series of Single Well Chemical Tracer Tests and of course and of course not unmindful of the risks, the company looks at this pilot as a ‘game changer’ with huge potential to enhance and sustain the North Kuwait oil production and reserve growth. It follows a path where an early lead could not only give it a distinct advantage in terms of achieving its goals but also create favorable conditions for commercial potential of this new technology.

Abstract

Background: The coronavirus disease 2019 (COVID-19) pandemic has rapidly spread to most countries around the world. Disproportionate spread of COVID-19 among the Indian community in Kuwait prompted heightened surveillance in this community. Aims: To study the epidemiological characteristics of COVID-19 patients and their contacts among the Indian community in Kuwait. Methods: Data collection was done as a part of contact tracing efforts undertaken by the Kuwaiti Ministry of Health. Results: We analysed contact-tracing data for the initial 1348 laboratory-confirmed Indian patients and 6357 contacts (5681 close and 676 casual). The mean (standard deviation) age of the patients was 39.43 (10.5) years and 76.5% of the cases were asymptomatic or had only mild symptoms. Asymptomatic patients were significantly older [40.05 (10.42) years] than patients with severe symptoms [37.54 (10.54) years] (P = 0.024). About 70% of the patients were living in shared accommodation. Most of the close conta

Abstract

On page 19, equation (2), letter '' represents live oil density. It was incorrectly shown as letter 'r' on page 20. (equation presented) where is live oil density, st is dead oil density and g is gas density (all in g/cm3). This equation was rearranged so that live oil density could be predicted from the remaining parameters: On page 21, in the formula for live oil viscosity 'µ' the live oil density in the exponent should be squared (2 not 2): ∝ = 10 (-1.058 - 3.2109 + 6.3494 2). © 2001 GeoArabia. All rights reserved.

Abstract

Most of wells in the major oil fields of West Kuwait Asset are producing with Electrical Submersible Pump (ESP). During 2012-2013, the ESP premature failures reached high percentages of up to 30% of ESP population with high deferred oil. In order to enhance the ESP performance and reduce the number of premature failed ESP, FD (WK) has initiated ESP Equipment Reliability Project in 2014. The main objective was to define a proper workflow that will be capable to identify the root cause of ESP premature failures, find the way forward and mitigation actions to overcome the issue. All ESP business partners from KOC and service providers were involved in the project. Series of technical workshops following the API and KOC standards were conducted by the team members to analyze the ESP performance and premature failures where the team was able to define analytical workflow in the early review sessions to conduct the required work. The workflow takes in consideration the reservoir parameters a

Abstract

Identifying oil-saturated versus water-saturated sands in shallow, unconsolidated, viscous-oil-bearing terrigenous-clastic reservoirs of Kuwait field is challenging. Field appraisal was based upon seismic, core and wireline-log data from 19 wells. Static and dynamic models incorporating all subsurface data were built to estimate oil-in-place and forecast production. Estimating and modeling fluid saturations in reservoir zones was accomplished by integrating core, dielectric-resistivity, Nuclear Magnetic Resonance (NMR) and Wireline Formation Tester (WFT) data. Wells were drilled along a northwest/southeast-trend, thus geologic and reservoir-property variability in east and west parts of the field are uncertain. Stratigraphy and lithologic properties in these Miocene-age fluvial to shallow-marine strata impart a complex 3-D fluid distribution in the field. Repeated shoreline progradations and retrogradations deposited a stratigraphic succession defined by five facies-associations (i.e.,

Abstract

Oil and gas operations are risky and accidents involving uncontrolled release of oil & gas sometimes happen leading to blow out and oil spill or contamination of near surface formations. A workover operation in an old oil well of Greater Burgan field in Kuwait resulted in a partial blowout situation with huge amount of gas and oil escaping to the near surface formations through failed casing sections. The charging of near surface formations resulted in a high-risk situation preventing any operations and drilling in the area. Estimating the areal extent affected by the gas leakage for taking safety and mitigation measures became very challenging. The leakage of high-pressure oil & gas into near surface formation resulted in increased pore pressure and uplifting of the surface. In this study to understand the surface deformation, SAR images acquired as a part of InSAR monitoring project were processed and interferograms were generated using images acquired just before and after the event

Abstract

At Kuwait Oil Company (KOC) most of the ESP wells are running with downhole sensors to enhance the daily monitoring routine and for having a better knowledge of the pumps performances. However, one of the most important parameter of these ESP Wells is only known after a time period within 3-6 months: The Flow Rate. Production Tests are obtained using Multiphase Flow Testing Units which usually last between 4 and 6 hours that are also utilized to conduct some sensitivities such as choke size and motor speed changes. At Well Surveillance Group, a tailored fit model was developed from which the ESP flow rate can be estimated based on the downhole sensor data and basic fluid properties with an overall deviation below 2% (when they are compared to the results obtained from the Testing Unit). In this sense, flow rate monitoring can be performed at any time and flow testing time and associated cost can be reduced among other benefits. The method requires knowing the ESP model and total number

Abstract

Azimuthal anisotropy of reservoir or overburden rocks is an important factor in uencing all seismic signatures. Multiazimuthal walkaw ay vertical seismic profiling (VSP) has a great potential for improving the results of seismic imaging and enhancing lithology discrimination by obtaining relevan t anisotropic parameters. If anisotrop y is fracture-induced, then the estimated quantities may be con verted into valuable petrophysical parameters defining fracture intensity and uid con ten t. Application of this technology, how ever, was previously limited to geological settings with laterally homogeneous plane-layered o verburden. Here, we dev elop an approach whic hremoves the necessit y for this assumption and allows us to deal with laterally heterogeneous environments. To achiev e this,w e supplement VSP data with a seismic velocity model and perform ray tracing in order to propagate surface-measured horizontal slownesses do wn to the receiv er level. Combining horizon taland vertical s

Abstract

Reservoir relative permeability and capillary pressure, as a function of saturation, is important for assessing reservoir hydrocarbon recovery, selecting the well completion method, and determining the production strategy because they are fundamental inputs to reservoir simulation for predicting lifetime production of a well. Estimation of relative permeability and capillary pressure curves at reservoir conditions is also an important task for successful planning of waterflooding and enhanced oil recovery. The relative permeability and capillary pressure data estimated from core analysis might cause concern regarding representativeness, and adjustments are typically necessary for successful production forecasting. This paper proposes a new method to obtain relative permeability and capillary pressure curves with downhole pressure-transient analysis (PTA) of mini-drillstem tests (miniDSTs) and well log-derived saturations. The new approach was based on performing miniDSTs in the free wa

Abstract

Sand production is a major concern for the efficiency of conventional and heavy oil production operations and facility equipment. Sand production could cause problems during well workovers, well and facilities clean-up, and waste sand removal. Understanding the sand production phenomena is essential to control it and to prevent losses to oil production operations, especially when producing from unconsolidated formations. Sandmovement depends on many parameters such as particle size and carrying fluid viscosity. The objective of this work is to investigate, experimentally, the sand settling time of Lower Fars (LF) heavy oil formation during production. LF is located north of Kuwait. It is an unconsolidated formation. The effect sand particle size and oil viscosity on the settling time was investigated. The results showed that there was a trend of settling time as a function of particle size and oil viscosity. As particle size increased, its settling time decreased. Also, it was observed

Abstract

The distinctive nature of the unconventional resources in the Najmah formation in The State of Kuwait poses unique challenges that must be overcome to achieve economic development. The Najmah potential has been characterized with large detail in several asset areas of the country, however, a regional, countrywide Play Fairway Assessment was carried out to high-grade those areas that could constitute the sweet spot for focusing on Pilot Well Design and Resource Evaluation. 1D and 3D Mechanical Earth Models were also developed to fine-tune the proposed sweet spot area and aid in the pilot wellbore design evaluation. The objective of the Play Fairway Analysis study was to carry out a thorough integration of Geology, Geophysics, Petrophysics, Geomechanics and Drilling data to produce an evaluation throughout the state of Kuwait. In this study, we developed and implemented an Unconventional Evaluation Workflow with the objectives of assessing a recommended sweet spot area and planning a pil

Abstract

As reservoirs approach maturity, the understanding and implementation of Enhanced Oil Recovery (EOR) techniques become essential to meet the world growing oil demand. EOR processes involve the displacement of one fluid by another. The major EOR methods in the petroleum industry include thermal, miscible and chemical processes. Miscible displacement methods involve the injection of solvents that will inter-mix with the reservoir oil to increase its mobility and reduce the oil saturation to low values in the swept zone of an oil reservoir. This work is part of Kuwait strong focus on EOR applications in Kuwaiti reservoirs to maximize the hydrocarbon recovery factors for a sustainable growth in oil production. This study is an experimental study that evaluates and investigates the miscible flood performance in Kuwait. An oil formation was selected as a candidate reservoir for this study after conducting EOR screening criteria. Core and fluid samples were collected and their properties were

Abstract

Asphaltene deposition in oil wells is a challenging flow-assurance phenomenon that affects the well production, project economics, and operational safety. While asphaltene precipitation is governed by the hydrocarbon mixture thermodynamics, Asphaltene deposition is governed by the complexity of flow hydrodynamic behavior and characteristics. This study aims to evaluate and compare the performance of the existing asphaltene deposition models and improve the current theoretical understanding of the deposition phenomenon by developing better predictive asphaltene deposition model. A large experimental database is collected, including aerosol and asphaltene particles deposition in air and crude oil systems, respectively, to carry on the evaluation. The results of this study revealed that Kor and Kharrat (2017) model of transport coefficient, which accounts for both diffusional and inertial deposition mechanisms outperformed other models in matching the transport coefficient from aerosol/ai

Abstract

This work is concerned with the nature of produced fluids resulting from ASP injection in a carbonate reservoir in Kuwait. The main objective is to examine and identify the nature of produced emulsions at conditions and chemical concentrations that are predicted by numerical simulation studies of the ASP pilot. The laboratory element of the work provides emulsion handling insight before the pilot begins, to reduce potential downtime and production costs. Laboratory tests and numerical simulations were used to identify the nature of the produced fluids. The simulations used a pilot-scale model to determine realistic ranges of chemical concentrations. The laboratory study used these pre-determined concentration ranges to form, observe, and characterize the emulsions. Key variables that increase emulsion formation and stability are determined. Variables studied include total surfactant concentration, surfactant ratio, polymer, effects of crushed core, temperature, pH, salinity, and viscos

Abstract

Matured oil reservoirs may have to be reviewed for unproduced mobile oil that has been compartmentalized by stratigraphy or structure. This paper presents such a case study in which the reservoir is more than 55 years old with no current producing wells within the case study area. A new well recently penetrated this reservoir and the unexpectedly higher oil column triggered this review. The reservoir is characterized by thin sandstone reservoirs with a strong, active aquifer. The workflow included a geological overview of the reservoir architecture and production/completion history of past completions. The detailed geological model was constructed incorporating the cased-hole oil saturations. This led to the building of a non-scaled-up, concurrent, 2-phase, 3D reservoir model for simulation using Frontsim. The fluid flow trend and the drainage pattern were analyzed by simulating the performance of assumed completions and re-completions of all the existing wells that penetrated this res

Abstract

[No abstract available]

Abstract

The evaluation of carbonate cores is a complex task because of the inherent heterogeneities that occur at all length scales. Rock properties may be defined differently at different scales and this introduces a challenge in capturing the heterogeneity in a single rock volume. This research work studied whole core samples using multi-resolution imaging and advanced computations. The samples could not be directly measured by conventional techniques due to their fractured state and complex nature. The cores are Mid Cretaceous in age, derived from a giant oil field in the Middle East and are predominately composed of limestone with complex paragenetic history. The core samples were first imaged by X-ray dual-energy CT in 3D at a resolution of 0.5mm/voxel. The whole core CT images revealed extreme heterogeneity along the sample lengths and showed varying distribution patterns of high and low-density textures. The selected plugs from those density textures were acquired to accurately represen

Abstract

Accurate and timely welltest data is critical to evaluate well performance and for effective reservoir management. In Kuwait Oil Company's Burgan South and East areas, the standard method of welltesting in the past has been through test separators and test tank. Because of the flow rate stabilization time and minimum volume required in the test tank for accurate reading of fluid level, welltest duration can range from 10 to 24 hours, especially for low volume wells. This is an operational challenge from the standpoint of acquiring accurate data and meet welltest frequency targets. In an effort to meet these goals, KOC has installed a new system of well testing with Coriolis meter and AGA Gas flow meters in its gathering centers (GCs). The coriolis meter, an online mass and density flow meter, can measure well flow rates with reasonable accuracy within 1-2 hours. This study has compared "simultaneous" well tests results of different categories of wells - high and low flow rate, dry and

Abstract

To realize the potential of heavy oil assets in achieving the long term production targets of Kuwait Oil Company (KOC), various pilots are currently under operation. This paper provides an overview of a recent multi-pattern pilot under steam injection to evaluate reservoir potential and to reduce the uncertainties in future investments. The implementation of a comprehensive surveillance plan is described and the early results of the pilot are discussed. Analytical techniques, statistical methods and engineering tools have been implemented to understand the reservoir performance and to evaluate operational variables. These techniques include injectivity analysis, pressure transient analysis, and multivariate analysis of production data. The size of steam chest is estimated by indirect techniques such as pressure fall off test which have been qualitatively confirmed by analytical methods. The analysis includes integration with other techniques such as seismic data and Distributed Tempera

Abstract

This paper presents the results of a methodical screening and evaluation study on various enhanced oil recovery technologies for potential deployment at the Sabriya Lower Burgan (SALB) reservoir in Kuwait. The EOR technologies that were considered in this study included alkaline-surfactant-polymer, surfactant-polymer, polymer, CO2, N2 and Low Salinity flooding. Initial parametric screening of different EOR technologies was conducted based on reservoir characteristics, and this was followed by laboratory studies to determine the extent to which the initial screening conclusions were valid. Sector model simulations were also used to evaluate and confirm the suitability of the Sabriya Lower Burgan reservoir for the above-mentioned EOR technologies. Screening and sector model simulations of the Sabriyah Lower Burgan formation indicated that Section A has potential for enhanced oil recovery technologies while the B zone does not, primarily due to the strong water drive in Section B. Chemica

Abstract

Evaluation of infertility indicated for women failed to conceive after one year of unprotected intercourse and for women over 35 years failed to conceive after 6 mo of unprotected intercourse, because the fertility decline as women approach 40 years. Evaluation of infertile couple should begin with semen analysis of male partner. If the semen analysis is within normal range, evaluation then move on to female partner. Evaluation of the infertile woman should be carried in cost-effective manner to identify the causes of infertility using the least invasive methods. Methods of evaluation of infertile women include: 1) history and physical examination; 2) evaluation of the male partner; 3) documentation of ovulation; 4) evaluation of the ovarian reserve; 5) evaluation of cervical causes of infertility; 6) evaluation of uterine causes of infertility; 7) documentation of the tubal patency; and 8) exclusion of peritoneal causes of infertility. Evaluation of infertile couple should include eva

Abstract

Effluent, which is a mixture of produced and brackish water from the Greater Burgan Field operations, has historically been disposed of through the use of evaporation pits. While this has worked adequately in the past, some of the Gathering Centers (GC) are unable to handle the ever increasing volumes with evaporation pits. Between environmental concerns, the decreasing capacity of the pits and the increasing volume of water, alternative disposal methods needed to be considered. Kuwait Oil Company (KOC) embarked on a study to look at the various options of disposing of its increasing volume of effluent water. A multidisciplinary team composed of Reservoir Engineers, Geologists, Operations personnel and Facility Engineers was assembled with the task of developing recommendations. Their efforts encompassed a review of alternative disposal options, reservoir assessment, on-site coreflood tests, two pilot disposal projects, and a survey of water quality. © Copyright 1998, Society of Petrol