The Kuwait Oil Company (KOC; Arabic: شركة نفط الكويت) is an oil company headquartered in Ahmadi, Kuwait. It is a subsidiary of the Kuwait Petroleum Corporation, a government-owned holding company. Kuwait was the world's 10th largest petroleum and other liquids producer in 2013, and fifth-largest exporter in terms of volume of crude oil and condensates. The managing director of the company is Emad Sultan.
Super duplex stainless steels (SDSSs) are widely used for critical applications due to their good mechanical properties and excellent corrosion resistance. These properties are achieved through the controlled addition of alloying elements and the proper balance of their microstructure, constituting approximately equal fractions of ferrite and austenite. Improper heat treatment or cooling conditions can alter phase balance and adversely affect the beneficial properties of the alloy. This study assesses the effect of microstructures generated under different cooling conditions on the mechanical properties and corrosion susceptibility of cast SDSS UNS J93404. The alloy samples subjected to different cooling conditions were characterized for their microstructure and phase constituents using an optical microscope, scanning electron microscope (SEM), and x-ray diffraction (XRD). The mechanical properties of the samples with different microstructures were evaluated using hardness, impact toughness, and tensile testing. Electrochemical potentiokinetic reactivation (EPR) and potentiodynamic polarization techniques were used to assess the corrosion behavior. Additionally, slow strain rate testing (SSRT) was conducted in 15
In this case study, we present the operational and well delivery experiences from the Jurassic HPHT deep gas drilling campaign, demonstrating geomechanics-aided improvements in the Abdali field, Kuwait. The target sections were drilled through heterogeneous carbonates with varying pressure regimes and mechanical properties. The section hosts limestones susceptible to mechanical instability and dolomitic reservoirs prone to differential sticking. The integrated workflow combines predrill risk assessment, drilling event analysis, geomechanical modeling, mud weight design, real-time monitoring, and operations geomechanics intervention. It resulted in safer, more efficient well delivery, wellbore integrity, and successful logging data acquisition under extreme conditions, delivered substantial time and cost savings, and can be adapted to analogous challenging subsurface environments.
The objective of the project is to drill a horizontal 6 in hole section through Najmah Formation in North Kuwait by utilizing Managed Pressure Drilling to define Pore Pressure uncertainty, reduce extra overbalance to mitigate hazards of losses, maintaining pipe rotation during well control events and differential stuck and utilizing Early kick/loss detection system. The well is located in a naturally fractured zone. Overall, Najmah's stratigraphy is divided into four lithological units, two of which are clean carbonate-platform limestones, and the other two are organic-rich. Its reservoir properties are dominated by fractured porosity and extremely low classified as a tight reservoir in terms of permeability In collaboration with Kuwait Oil Company (KOC) and Weatherford, a high-level strategy was developed by following the recommendations shared in a Pre-section Geomechanics Data Package (PSGDP). The package included estimated pore pressure values, based on a 5-point system analyzed by a precise study of the drilling hazards from offset wells highlighting the risks associated with and lessons learnt. Majority of the offset wells drilled were complex sections encountering challenging drilling hazards, specifically severe losses from the start up of the section to the target depth leading to None-Productive Time in the conventional approach to resolve the encountered issues, cement plugs, bull-heading in case of well flowing. With the given data the MPD drilling program planned an Equivalent Circulating Density of not higher than 12.4 ppg as target while utilizing MPD-CBHP Application to manage the bottom hole pressure in case encountering the high pressure of 13.99 ppg and to avoid bull heading by precise monitoring and quick response of adjusting ECD in case of experiencing gain and manage to circulate out the influx within MPD's given capabilities. The application of MPD technique allowed efficient and safe drilling through a highly uncertain pressure window by performing a number of MPD-Dynamic Pore Pressure Tests providing real-time pressure assessments. MPD techniques in the section included staged mud weight reductions from 14.5 to 11.2 ppg, tandem pill applications, backpressure management during connections, and continuous monitoring of background gas and flow stability. The final section was drilled with BHECD ranging from 12.36 to 12.18 ppg, with no total loss events compared to offsets, controllable returns losses (≤15 BPH). The section also encountered high gas and well-flowing and was safely circulated the gas to the flaring line, highlighting the efficient use of MPD for effective well control and kick-loss situation management The liner was successfully run and set at 18,860 ft MD with static conditions and efficient hole cleaning, reinforcing the value of MPD not only in drilling but also in casing and completion operations. The flawless execution showcases the value of collaboration in the latest geomechanics workflow, supporting KOC's journey by optimum mud weights to overcome challenges to use the proper completions in similar wells.
The success of polymer flooding in harsh reservoir environments hinges on a range of critical parameters: in-situ oil viscosity, mobile oil saturation, reservoir temperature, conformance, injectivity, shear rate, and complex brine chemistry (e.g., salinity, iron, and divalent ions). This paper explores the game-changing potential of polymer flooding through a series of cutting-edge advanced lab-to-field case studies utilizing high-TDS produced water. By combining rigorous polymer screening, smart surveillance and adaptive field strategies, the study reveals how technical and geological challenges were turned into opportunities which unlock substantial value in Kuwait's geologically complex, heterogeneous carbonate and sandstone reservoirs through innovative, field-proven approaches. A data-driven workflow was created to support the selection, evaluation and deployment of polymers for flooding in challenging reservoir environments (high salinity, hardness, and temperature). Stable synthetic polymers were meticulously screened through laboratory and core flooding tests using high-TDS produced water to ensure stability under harsh environment. High-resolution, history-matched simulations used to develop pre-pilot strategies. Single-well Long-Term-Polymer-Injectivity-Tests (LTPITs) were executed across multiple reservoirs to assess injectivity, in-situ behavior, and techno-commercial feasibility (rates/throughput) under matrix conditions. Lessons learned enabled proactive challenge mitigation. Simulations were performed using calibrated/history matched model with LTPIT to design commercial polymer flooding and economic assessments. Innovative polymer screening and laboratory testing identified synthetic polymers containing 20–50% ATBS and molecular weights between 5–18 million Daltons as thermal, chemical and mechanical stability under extreme reservoir conditions (upto 270,000 ppm of TDS, 40,000 ppm of hardness and 210°F temperature). Core flood tests using high-TDS injection water demonstrated these polymers’ potential to increase oil recovery and accelerate oil production in 2-100cp oil viscosity reservoirs. Field trials through LTPITs established polymer long-term injectivity under matrix conditions, techno-commercial viability (injection rates / throughput), in-situ polymeric rheological parameters (viscosity / concentration / shear rate), resistance factor (RF), and residual resistance factor (RRF). Lessons from each LTPIT successfully addressed to convert challenges into opportunities in subsequent pilots. The results of phase commercial simulation demonstrated enhanced oil recovery, faster production rates and reduced water cuts compared to conventional waterflooding. Additionally, economic evaluations revealed attractive unit technical costs and a significantly improved net present value (NPV), reinforcing the feasibility and commercial potential of deploying polymer flooding to unlock substantial value in Kuwait's harsh reservoir environments.
This paper presents the successful application of advanced tubular patch technology as a rigless, cost-effective solution to restore production and mitigate tubing integrity leaks in Sabriyah field, North Kuwait. The scope includes addressing ESP-related failures caused by downhole circulation issues, reducing costly rig workover operations, and demonstrating how this approach restored well productivity, minimized downtime, and provided long-term reliability while maintaining full-bore access for future interventions. To tackle persistent tubing integrity leaks above the ESP discharge, a multidisciplinary asset team conducted detailed well screening based on ESP performance, tubing condition, and commercial oil potential. Instead of traditional rig workover and tubing replacement, an advanced tubular patch system was selected. The system consists of a blank pipe with hydraulically activated metal-to-metal sealing elements at both ends to isolate leaking intervals. The rigless intervention was designed to restore zonal isolation while preserving tubing bore. Pre-job planning, candidate well selection, and execution strategies ensured successful deployment across multiple wells. The tubular patch system was successfully deployed in nine wells, isolating tubing leaks and restoring well integrity without requiring costly rig-based workovers. The intervention delivered a combined production restoration of approximately 3,800 BOPD, while preventing more than 200,000 bbl of deferred oil that would have been lost during extended downtime awaiting rig scheduling. In total, about 300 ft of tubular patches were installed, leading to cost savings exceeding USD 16 million compared to conventional tubing replacement operations. Furthermore, the technology ensured large-bore access for future ESP interventions and well surveillance. The case demonstrated that tubular patch applications can provide a sustainable and repeatable solution for mitigating tubing-related ESP failures, significantly improving asset uptime and reducing operational costs. Based on this success, KOC has expanded the deployment of tubular patches across Sabriyah and other fields to address similar challenges. This paper presents the first large-scale field application of tubular patch technology in Kuwait, demonstrating its effectiveness as a rigless solution for ESP-related tubing leaks and eliminating costly rig workovers. The results include significant production restoration, deferred oil savings, and multi-million-dollar cost reductions. By integrating innovative technology with systematic candidate selection, this case sets a new benchmark for extending ESP run life, enhancing artificial lift performance, and optimizing well integrity management in mature fields.
