bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Challenges of Reviving Iraq's Only LPG Storage and Marine Terminals
Authors: Nabet Medhat , Noori Sabah , Salman Muhammad , Abidi Syed , Orrock Steve , Bonner Chris , Kloeck Gert , Everdingen Huib Van 
Published: November 2018

Abstract
Umm Qasr storage and marine terminals are strategic assets for the gas investments in Iraq. Together they are the only Natural Gas Liquids Export Hub in Iraq and a key enabler to increase the capture of Iraq's flared gas.
Basrah Gas Company (BGC) started operating and developing Umm Qasr storage and marine terminals since its commencement of operations in May 2013 with a development plan to increase capture of flared gas and turn Iraq into net exporter of LPG. The development of Umm Qasr and the LPG export journey was phased into work streams that maximize the near-term and long-term value.
Work Stream 1: Early Pressurized LPG Export
Work Stream 2: High Pressure LPG Export
Work Stream 3: Refrigerated Export
The transition from pressurized LPG export to Refrigerated Export and the rehabilitation of Umm Qasr Marine Terminal jetties to comply with international safety and maritime standards is one of the most impactful projects in Southern Iraq. The project will provide the enabling infrastructure to increase export of Iraqi refrigerated propane and Butane positioning Iraq as one of the major players in the international LPG export market and diversifying its export revenues, besides providing impetus for further development of upstream gas capture and developments, and mid stream gas processing and utilization projects not just in south, but also in Norther Iraq using the already existing LPG grid network.
The refrigerated export scope comprises the rehabilitation of refrigeration trains that chills propane (C3) and Butane (C4) to −43 deg and −5 deg. C respectively turning them into liquids at atmospheric pressure, along with associated propane and butane cryogenic Tanks, cryogenic product pipelines between storage and marine terminals, rehabilitation and modernization of marine jetties 1 and 2 including dredging of more than 1 million cbm of soil, automation, safety and integrity upgrades with aim to cater for Very Large LPG Gas Carriers (VLGC) and Medium Range class Product (Naphta) tankers of ~50,000 Tons DWT
This paper pronounces the challenges, approach and impact of reviving Umm Qasr Storage and Marine Terminals infrastructure that was built in 80s, only partially commissioned, suffered dis-repair in successive wars and was extensively modified to suit the country's emergency import needs.
Innovative Epoxy Resin Formulation for Downhole Casing Repair Applications
Authors: Al-Yami Abdullah , Al-Jubran Mohammed , Aswad Hassan , Looni Qadir 
Published: November 2018

Abstract
Downhole casing repair is a major workover operation worldwide, especially in wells which were drilled and put on production decades ago. The presence of corrosive formations is considered a common downhole source that slowly corrodes steel strings over time. Several remedial options are available on the commercial shelf including cement slurry, resin chemicals, and mechanical casing patch technologies. Yet, these suffer from several disadvantages including limited isolation and integrity, cost, internal diameter restriction, etc. These drawbacks could lead to casing leaks reoccurring across the same depth shortly after applying the commercial treatments. In other scenarios, they result in internal diameter reduction and inability to pass tools, such as plugs, packers, whipstocks, etc. The proposed epoxy resin formulation retains improved mechanical and chemical properties over the commercial products to repair challenging downhole casing leaks, especially those with low injectivity.
This formulation is composed of a combination of two different resins and one curing agent. Compared to other commercial epoxy and polyester products, this formulation showed lower rheology of less 50% at room temperature, deeper crack penetration, improved compressive strength and elasticity, and enhanced corrosion resistance.
The product was deployed in the field to cure downhole 7 in. casing leaks with 73 pcf CaCl2 brine in place. The subject leak showed low injectivity of 0.4 bpm at 1,000 psi, requiring solid-free solutions. The innovative formulation was introduced as a result, and 20 bbl were spotted as a balanced plug and squeezed in hesitation to achieve the required pressure integrity of 600 psi after resin plug cleanout. Manganese Tetroxide was used as the weighing agent to mix up 80 pcf epoxy resin as per design. The low-rheology allowed for maximum injected volume at the required lock-up pressure of 1,000 psi. Meanwhile, the elastic nature enabled more resistance during the following re-entry operations and relatively higher rates of penetration during resin plug cleanout.
This paper will discuss the nature of the resin formulation and experimental work to compare this innovative product to the commercial products. The pilot testing, job simulation, and field deployment will be highlighted to emphasize the added value and potential of this product.
Swift Solutions to Avert Major Structural Failures
Authors: Nuthanapati Sreekanth , Adel Khalid , Al Maskari Juma 
Published: November 2018

Abstract
In today's challenging work and business environment, swift response to structural integrity concerns is the need of the hour to minimize the damages that will reduce down time, specifically in oil & gas sector. The solution devised to address structural concerns shall prevent further failure of structural members and avert major catastrophic accidents, as they support process equipment and piping. This paper outlines case studies of such structural failures, potential reasons of incidents and approaches followed in restoring structural integrity in a safe and economical way that ensures uninterrupted plant operation.
Key parameters to be studied / considered while arriving solutions to structural damage / incidents include reliability of data, primary cause of incident, inventory of readily available material, execution feasibility under plant operating conditions thereby avoiding plant or unit shutdowns and manpower skillsets. Due to various constraints, the solution arrived may be temporary that averts multiple structural failures or a major accident. Further studies would be required to identify the root cause and to confirm or enhance the implemented solution that will reaffirm long term integrity of structure.
In almost all of the incidents, some of the common steps followed for swift restoration of structural integrity include conducting a site survey to identify and judge the probable cause, reviewing available data, structural assessment and details of material in stock.
After analyzing numerous factors, diverse approaches unique to each incident were considered in arriving a solution that is fit-for-purpose.
Structural integrity issues, if not attended swiftly, can worsen the situation leading to safety concerns and major accidents. Solutions adopted for various incidents ensured restoration of structural integrity with minimal consequences. Suggested improvements and recommendations were implemented and no further issues were reported until this time.
Integration of Geochemical and Petrophysical Analyses for the Shilaif Formation Characterization
Authors: Makarychev Gennady , Leyrer Karl , Baig Muhammad Zeeshan , Van Laer Pierre 
Published: November 2018

Abstract
Development of unconventional oil plays worldwide demonstrated that conventional characterization of such rocks in terms of a total porosity and total water saturation does not always provide enough information for completion and drilling decisions. The characterization and quantification of different fluids in different pore space together with a coupled geomechanical model is key for "sweet spots" detection for wells placement, stimulation and production.
Based on our experience we present in this paper how an integration between geochemical analyses and advanced logging technologies can improve formation characterization in unconventional rocks; help to identify target intervals for wells stimulation and testing at an early exploration stage.
The workflow was developed for the Shilaif formation evaluation in Abu Dhabi and allows fluids typing and their quantification in different pore systems from advanced logs data interpretation calibrated to full size and pressurized sidewall core special analyses. Detailed description of the workflow and results of its application showing reservoir and hydrocarbons quality variation within the Shilaif formation in wells from synclines and anticlines are presented in this paper.
Impact of Low Cost Proppant and Fluid Systems in Hydraulic Fracturing of Unconventional Wells
Authors: Cheung Bettina , Hilling Scott , Brierley Sean Paul 
Published: November 2018

Abstract
As the industry advances on horizontal drilling and slim hole design, well completion and specifically hydraulic fracture stimulation remains the most expensive part of the well construction process in Unconventionals.
Proppant and fluid make up a significant portion of the stimulation cost of a well, it is therefore a key lever in cost reduction. This submission will examine the transition from Conventional to Unconventional stimulation designs with respect to technical and economic factors that drive fluid and proppant optimization.
The authors will then focus on the industry journey in multiple step change transitions from high viscosity fluid system with high strength premium proppants towards low viscosity fluid system and lower strength natural proppant. In each case, technical justifications based on theory, laboratory testing, or field trial data from Shell unconventional basins will be discussed. The authors will also briefly review several strategic approaches in proppant and fluid sourcing from the logistics perspective. Relevant cost data will also be used to reflect the overall impact of the evolution.
This paper reveals that significant cost reduction can be achieved by right sizing fracture conductivity through reduction on premium high strength proppants and shifting towards a low viscosity system, as well as leveraging appropriate supply chain strategy.
Successful Field Applications of Installing and Activating High Pressure/Temperature Multi-Stage Completion for Improving Well Performance in Deep North Kuwait Jurassic Formation
Authors: Al-Saeed A. , Ahmed Z. M. , Fidan E. , Salem A. M , Liu Pei Wu 
Published: November 2018

Abstract
In the last decades, defining optimum completion options in North Kuwait Jurassic Gas (NKJG) were essential to overcome reservoir challenges, connect to natural fractures, minimize formation damage, and stimulate formations efficiently in this sour gas environment. Moreover, the completion should withstand high-pressure differential (~15,000 psi) and high temperature (~275oF) during installing and producing over entire well life (over 20 years). The efficient completion type that suits NKJG environment will ensure enhancing the future well interventions and increase production potential within a short time period.
NKJG’s reservoirs are classified as high-pressure, high-temperature, sour, deep, with high contrast in permeability values (2 to 3 order of magnitude), and high variation of natural fracture distribution among well locations. In addition, the major flow zone of interest is divided into several segments with different reservoir properties and lithology which affect the production zonal contribution. The cased and perforated liner completion were used in this challenging area where low permeable zones were not contributing to flow even after stimulation due to high permeability contrast across reservoir flow units.
As a result, Multi-stage completion is one of completion designs that initiated to overcome reservoir complexity where it comprises of hydro-mechanical liner hanger packer, open-hole packers, hydraulic anchor and multiple frac ports set and activated as a drop-ball system. This type of completion avoid perforation or cementing process that reduce formation damage; so, it allows wellbore to access to full formation natural fractures and reservoir potential. Moreover, Multi-stage completion permits to select different stimulation technique across zone of interest and reduce well intervention costs.
The 4 ½" Multi-stage ball activated sleeve completion (HPHT) which is an alternative strategy to produce from different zone of interest successfully installed, sequentially stimulated and commingle- tested on flow back for two different case studies. Reservoirs are divided into three distinct intervals and acid treated with different stimulation techniques (Acid fracturing & High Rate Matrix Acidizing). The flow tests showed very good results that provide a good evidence for deploying this technology in tight gas and unconventional reservoirs.
This paper focuses on designing, installing, and execution phases of MSC of two successful case studies. In addition, spotting the key learnings and critical factors that should follow in the future to guarantee the well performance enhancement and overcome reservoir challenges.
Complex Fluid Characterization of Tight Gas Field in Sultanate of Oman; The Success Story of Subsurface Data Integration
Authors: Wulandari Ratih , Elie Marcel , Rajhi Mohammed , Morad Kamaladin 
Published: November 2018

Abstract
Field K1 as part of AA Tight Gas Cluster features significant variability in the fluid properties, concluded through PVT, well test as well as geochemical measurements. Following an extensive data acquisition program that was conducted at the beginning of the project, a multi-disciplinary review and integration of data was carried out in order to adequately characterize the fluid distribution across the field.
Several analyses were employed to understand the characterization of the fluid distribution through geochemistry analysis, compositional gradient analysis and lateral fluid investigation.
Gas samples and mud gases were collected during drilling and analyzed for gross composition and stable carbon isotope for geochemical analysis purposes. Condensates were collected and analyzed for gross composition, sulfur content and isotopic analyses. Analyses of both fluid types aimed at gathering reliable information in terms of source type and thermal maturity of gases. The large number of data points from high resolution sampling of mud gases allowed for a more confident examination of charge history and communication of the Upper Amin Formation across the cluster of fields.
The gas and condensate samples were taken after well completion for further PVT analysis. Gas composition, temperature, fraction of liquid drop-out and measured Dew Points suggested complex reservoir fluid and genetically different behavior with a contrasted fluid signature across Field K1. Plotting the fluid composition, phase envelopes, as well as Dew Point gradient supported application of a complex-fluid modeling together with segmentation.
The understanding of the fluid behavior is important for the reservoir description as well as the overall development plan of Field K1. The impact on the development plan includes: missing condensate recovery opportunity, on-plot and off-plot facility design, overall gas and condensate recovery factor per well, and the sequence of development.
This new analysis resulted in an upward update in resource volume estimation of Field K1. Well placement and drilling sequence optimization were derived as the positive outcome of this exercise.
Strategy Towards Unlocking and Accelerated Development of Low Permeability, Microporous Reservoirs
Authors: Kumar Kamlesh , Azzazi Mohamed , Hamdi Abdullah , Awang Zaidi , Nicholls Christopher , Lawati Yousuf , Huseini Hamood , Abri Said , Sharji Hamed 
Published: November 2018

Abstract
The Upper Shuaiba reservoirs in Lekhwair consist of carbonate formations extending over a very large area (40 km × 40 km). Earlier development projects identified thicker, well-appraised formations, resulting in successful waterfloods. In contrast, challenges have been encountered in some of the waterflood pilots attempting to unlock future development areas. An integrated evaluation of these poor performing areas led to the development of a rock type catalogue that mapped out different rock types and their properties. Initial developments were mostly in high permeability rock types (Rudist Rich and Grainstone) whilst the underperforming pilots are associated with microporous rock characterized by low permeability (~1 mD) and thin formations (2-5m). These microporous rocks are associated with a large hydrocarbon volume in place. Resolving this development challenge is critical in maintaining the company's long-term production targets.
Waterflood is the preferred development concept as it is in line with the existing facilities and infrastructure. The existing pilots demonstrate that low water injectivity/throughput is the key challenge to waterflood feasibility. Conventional acid stimulation does not work in these formations. Four different initiatives, in addition to injection water quality monitoring and improvements, are being tried to ensure successful maturation of microporous resources: Abrasive Jetting: used to create small tunnels up to 3m into the reservoir.Controlled Directional Acid Jetting: using acid to create multiple small laterals (up to 12 m in length) into the reservoir.Designer Acid: acid tailored to improve conventional acid stimulation.Fracture Aligned Sweep Technology (FAST) as implemented in Halfdan field; which creates longitudinal fractures along the length of the well.
The outcome of this study includes identification and mapping of the different rocktypes across the entire Upper Shuaiba; waterflood performance assessment of microporous rocks and new technology trials to accelerate the development of microporous resources. Whilst abrasive jetting has achieved limited success in improving injectivity, result from designer acid stimulation was disappointing. The other two trials are still under evaluation. In case all the initiatives fail to establish the feasibility of waterflood, alternate developments mechanisms are proposed as Phase 2 in the strategy.
This paper highlights how integration between different disciplines can help in maturation of a large resource volume, whilst accelerating its development by standardization of designs.
Enhancing NGL Recovery Through Utilized Design Margins
Authors: Al Ali Mariam , Al Matroushi Mohamed 
Published: November 2018

Abstract
In line with our quest to improve performance, optimize efficiency, and increase profitability, ADNOC Gas Processing is committed to ensure process design optimization by following best practices that add significant value to its gas business and industry. This report will outline how we were able to increase our C3+ recovery and thus the NGL production of BuHasa Train 2 by safely utilizing the existing design envelope and available design margins.
Although, operating a plant beyond its design capacity is not a new concept, process and HSE assessments are a must before proceeding. These efficiency enhancements can be implemented without any capital investment and also strengthen a plant's readiness to deal with any future challenges in plant performance. In gas processing plant such as NGL extraction, process fluid pressure is an important factor which can affect the plant characteristics. The influence of different values of pressure drop in various equipment needs to be realized as it can affect the quality and quantity of the process outputs.
An in-house feasibility study has been conducted to evaluate the possibility of increasing the HP compressor discharge pressure by 1 bar over its current operating pressure. The study indicated that it was possible to enhance the train's efficiency by increasing C3+ recovery, leading to an increase in NGL production and therefore a profitability increase.
The study was completed after the plant facilities were comprehensively evaluated for process safety and operability, as well as analyzed improvements in terms of C3+ recovery and NGL production.
A successful "Field Test Run" for 10 days were conducted to validate the predictions of the study to operate the HP compressors at 1 bar higher.
The product specification, quantity and plant operating costs are important parameters and balancing them will determine the optimum pressure distribution in the process and consequently realize our benefits. Hence, during the test run, the revised operating conditions were implemented and achieved safely without any major modification or upset to the facilities. As a result, the following cost benefits were realized: C3 + Recovery increased by around ≈ 0.2 wt.%NGL production increased by around ≈ 35 Ton/dayRevenues increased by around ≈ 2.8 MM US$/YearOperating cost increased by around≈ 220000 US$/Year
Novel Technology of Concentric Coiled Tubing Enhances Ultra-Low Pressure Reservoir Wellbore Cleanouts in Kuwait
Authors: AlMatar Mohammed Ahmad , Alshammari Faisal Shayea , Alhouti Naser Bader 
Published: November 2018

Abstract
Wells in the South Ratqa field often fill with sand. Ultra low bottom-hole pressure did not allow efficient sand cleanouts in several wells. Despite using massive amounts of nitrogen during clean out, and largest available CT size (2.375") to ensure enough annular velocity; severe fluid losses occurred into the formation, which resulted in decreased well production post clean outs, moreover handling energized returns has always been a logistic and safety hazard
Recently, concentric coiled tubing (CCT) technology was employed for the first time in Kuwait and five wells were identified as viable fill cleanout candidates for which traditional cleanout methods had proved inefficient at best and many times unsuccessful. The system uses concentric coiled tubing and a special vacuum tool designed to apply a localized drawdown, which would deliver the sand particles through the Coiled Tubing / Coiled tubing annulus to surface. Returns were handled using H2S resistant lines into a desander.
A carefully engineered cleanout program enabled removal of more than 12 MT of sand from four vertical wells, and also identified the formation damage in a horizontal wellbore. The identification of wellbore damage revealed the best intervention to cure the damage and eliminated speculative remedies that sometimes increased the damage done to reservoir. Additionally, the layout of well plots was designed in a very congested way to maximize output but made it impractical to have return pits, requiring mobile tanks to handle returns, while the energized nature of returns in conventional nitrogen jobs are dangerous to handle in a closed tank environment. CCT eliminated that hazard as the returns are not energized.
The campaign has pushed the boundaries of the coiled tubing interventions in Kuwait and has unlocked several wellbore cleanout opportunities using the CCT technology