bluuebunny/crossref_metadata_2025_split huggingface dataset:
Tail-End Oil Assets Revitalization Using Novel Artificial Lift Optimization Strategy
Authors: Elichev V. , Khabibullin R. , Litvinenko K. , Michailov V. 
Published: April 2016

Abstract
High oil price indeed creates conditions for successful life extension of mature assets. Even old suspended wells could be successfully revived as the watercut threshold for economic production is being changed due to new price situation. Normally, it is uneconomical to build new surface facilities for mature assets, therefore the most critical point for oil production level maximization of such fields is existing infrastructure constrains. The most common constraints are total liquid production and power capacities. These constraints are especially important in case of high watercut wells with medium to high well productivity. The Electrical Submersible Pump is the most widely used artificial lift method for the wells in late development stage. High liquid volume with high watercut leads to considerable power consumption and it turns out pumping equipment as the most significant power consumer. Obviously artificial lift optimization and appropriate management of available power are key enablers for life extension of mature assets. All power consumers in an asset are interconnected; therefore one cannot significantly optimize a field production doing artificial lift system performance optimization for a single well. Valuable optimization only could be achieved using an integrated performance optimization strategy on the whole asset production system and the strategy development is considered in this paper.
The paper presents the value maximization methodology for ESPs driven assets, which consists of optimal well production targets identification and equipment selection & sizing strategy. The key idea of the methodology is to break-down field production system into "capacity" consuming components, understand components behavior and efficiency of power consumption by each component redistribute available capacity between components, targeting maximization of oil production under existing constraints. The paper describes in detail the methodology and provides an example of application.
Acquisition of an Elevated Pressure Core in a Gas Flooded Carbonate Oil Reservoir: Design and Operational Challenges
Authors: Al Saman Al Neaimi Mai , Tee Aaron Sin , Boyd Douglas , Al Shehhi Rashed , Abdel Aziz Mohamed Emad , Namboodiri K.M.N , Al Junaibi Hamad , Al Zaabi Mohamad , Al Braik Haitham , Ftes Suleiman , Medjiah Abdul Kader , Farouz Ameer , Gao Bo , Gay Mike , Tariq Syed M. , Fudge Blake , Collett Paul , Gill Tim , Anis Abdul-Hamid , Schipper Bas , MacDonell Sheldon 
Published: April 2016

Abstract
Pressure core is the gold standard of reservoir saturation determination retaining gas and oil in an enclosed container preventing hydrocarbon loss to the mud system during retrieval of the core to surface. The technique is underutilized in the oil industry due to safety concerns, short coring lengths (3 to 7 feet) per trip and small core diameters (1.6 to 2.6 inches). A new elevated pressure coring system addresses these concerns. The system does not maintain true formation pressure but reduces the core barrel pressure to less than 1,000 psia for safer working conditions on surface. Upon arrival at surface, the core barrel and accompanying gas/liquid collection canisters are blown down and gas/liquid volumes measured and analysed. Free oil is gathered and stored for later analyses. Core diameter is 4 inches and core length is 10 feet.
Zakum Development Company (ZADCO) operates a gas injection pilot in a large carbonate oil reservoir. There was a need to determine field remaining oil saturation after gas flood (ROSg) in a gas injection pilot. Pressure coring was selected as the best technology to obtain this data. This paper covers the planning and implementation of a successful elevated pressure coring operation in the U.A.E., the operational aspects, special core handling techniques, issues encountered and solved. Recommendations are made for future pressure coring operations. A follow up paper will cover the core and fluid analyses aspects.
First Successful Installation of Expandable Liner Hanger Technology in United Arab Emirates (UAE) for ADCO: Engagement and Innovation
Authors: Cardozo L. G. , Bin Shamlan A. M. , El Barbay A. Y. , Ramadan T. M. , Mohamed Z. , Abu-Aita I. 
Published: April 2016

Abstract
This paper discusses the application of an expandable liner hanger system in ADCO, which is the first expandable liner hanger set in the UAE. For ADCO, the majority of the liners run in its area can be classified as drilling liners that allow the well to be "cased off" at key points in the drilling sequence so that drilling can progress safely to its target depth. Due to the well’s configuration, mandatory requirements were established to deploy the liner at the desired position as well as to obtain proper isolation of both the formations and the liner lap to avoid compromising the well integrity.
During the comparison with conventional systems used by the operator, the expandable liner hangers (ELH) demonstrated to be a technology that simplifies the tool assembly as it incorporates the liner hanger body with an integral packer, tieback polished bore receptacle, and setting sleeve to connect the assembly to the packer. In other words, this tool does not have external components such as slips, hydraulic cylinders, or pistons. Instead, moving parts of the setting mechanism are contained in the setting tool assembly; thus, minimizing the risk for premature setting when compared to a conventional liner hanger. However, manufacturers have developed their own designs, with important differences between them. For this reason, deep study on the features of the selected model was conducted in order to understand not only the advantages but reliability, hazards, and mitigations.
One of the most relevant aspects was the fact that the selected ELH system stays in the unset (unexpanded) position during all cementing operation, so full cross-sectional bypass area is preserved throughout the process, which helped to minimize the increases on the equivalent circulating density (ECD). On the other hand, conventional liner hangers are typically set just prior to cementing operations, so the chance to improve the cement placement is reduced as the string remains static during cement displacement. Moreover, due to the nature of the job, integration with the Cementing Engineering Team was crucial to ensure all factors were properly evaluated ahead of execution.
Meticulous planning, as well as clear criteria for acceptance of the proposed ELH system that meets the company’s quality standards, were established by a multidisciplinary team that succeeded the challenge of deploying the first ELH of this type in UAE, proving its feasibility even in difficult well conditions, with minimum risk for the personnel and the operations, and, as added value, it delivered a new approach for well design for ADCO.
Use of Nano-Emulsion Surfactants During Hydraulic Fracturing Treatments
Authors: Al-Anazi M. S. , Al-Khaldi M. H. , Fuseni A. , Al-Marshad K. M. 
Published: April 2016

Abstract
Hydraulic fracturing has been extensively used as an efficient method to enhance the hydrocarbon production, especially in tight formations. However, this technique has been associated with long-lasting formation damage challenge due to fracturing fluid filtrate leakoff. According to Laplace equation, this fluid leakoff results in a phenomenon called water blockage due to capillary forces. Recent studies have shown that surfactants can be used as an additive to fracturing fluids and they will reduce the required pressure to displace the injected fracturing fluids. In this study, the performance of two new nano-emulsion surfactants has been investigated.
Nano-emulsion surfactant mixtures were prepared at different concentrations ranging from 0.5 to 5 gpt using field mixing water. Mixing water and representative field condensate samples were used to conduct both the surface tension and contact angle measurements at temperature range of 77-325°F. Laplace equation was used to calculate capillary pressure values based on surface tension and contact angle values.
The results based on this study have illustrated the effectiveness of nano-emulsion surfactants to recover the fracturing fluid filtrate during flowback. The performance of these surfactants was investigated as a function of several parameters such as surfactant concentration, soaking time, and temperature. In addition, this paper explored the adsorption behavior of these surfactants on formation rock and the effect of nano-emulsion surfactants on the rock wettability. Optimal design parameters of these nano-emulsion surfactants to achieve significant enhancement in injected fracturing fluid recovery are also discussed.
Successful Implementation of CO2 Energized Acid Fracturing Treatment in Deep, Tight and Sour Carbonate Gas Reservoir in Saudi Arabia that Reduced Fresh Water Consumption and Enhanced Well Performance
Authors: Malik Ataur R. , Dashash Alaa A. , Driweesh Saad M. , Noaman Yousef M. , Soriano Eduardo , Lopez Alfredo 
Published: April 2016

Abstract
Up to three thousand barrels of stimulation fluids are pumped during a single vertical fracture treatment in carbonate reservoir of Saudi Arabia with the objective of creating sufficient conductive reservoir contact for commercial production. The post-stimulation production performance in deep, tight, and sour carbonate gas reservoirs often does not meet expectations due to complex reservoir characterization and poor transmissibility. The post-stimulation cleanup period often takes much longer due to resistance in unloading the pumped fluids.
Carbon dioxide (CO2) with 30% foam quality (FQ) has been introduced for the first time during acid fracturing treatment in the tight, sour and high pressure, high temperature (HPHT) carbonate gas reservoir of Saudi Arabia to reduce consumption of fresh water, minimize reservoir damage, reduce the flowback period and eliminate the need for nitrogen lifting with coiled tubing (CT). The water and acid volume were reduced by one third through energizing the fluids system with CO2 during acid fracturing treatment in the candidate well. The Pad fluid was a zirconate crosslinked gel that was optimized for low pH to maintain stability in the presence of CO2. To minimize fluid leak-off and improve diversion effects, a chemical diverting system was included in the CO2 energized acid fracture treatment. A non-emulsifier foaming agent was used in the Pad and acid blends to create the desired emulsion with CO2. The post-fracture flowback period was reduced significantly and a 2.5 fold increase in the gas rate was realized.
The addition of liquid CO2 to HCl in quantities sufficient to produce emulsion allows live acid to retard and penetrate much deeper than HCl itself. The CO2 strips hydrocarbon from the rock and allows acid to effectively react to the rock surface. CO2 remains in the liquid or supercritical phase during injection mode and flows back in the gas phase over a wide range of temperature and pressure allowing pumped fluids to recover in fast and safe manner.
This paper is focused on laboratory tests of fluid systems, and the design, execution and evaluation of CO2 energized acid fracturing treatment, and a safe flowback strategy used for sour wells with high a concentration of CO2.
Tests in Ultra High Pressure of H2S
Authors: Gabetta G. , Pontarollo A. , Sgorlon S. , Zonta P. 
Published: April 2016

Abstract
The exploitation of fields with high H2S and/or CO2 content is nowadays of growing importance for oil companies. The presence of H2S and/or sulphur in production fluids can be responsible for both general and localized corrosion. However, the knowledge of materials behavior in plants handling those fluids is limited due to the difficulty in performing tests in such aggressive and dangerous environments. The so-called Nace Solution, used to assess Sulfide Stress Cracking susceptibility of steels, is a water-based solution simulating production fluids in equilibrium with one bar bubbling H2S gas. This solution does not simulate situations where High Pressure (HP) and Ultra High Pressure (UHP) of acid gas is present.
This paper describes tests performed in a laboratory with an autoclave designed to test up to a total pressure of 1000 bar of H2S and/or other gas mixtures, with and without the presence of water, to fully simulate the service environment.
Autoclave tests were performed on four point bend specimens of Carbon Steels, Stainless Steel and Corrosion Resistant Alloys at pressure up to 730 bar, with the aim at better understanding the effect of a small content of water in the corrosive properties of re-injected gas mixture. Results show that a small amount of water (1%) is enough to trigger damage – in the form of cracking - in Type 316 Stainless Steel. For Carbon and Low Alloy steel, there is competition between general and localized corrosion. The main finding however is that more work is needed to obtain a better understanding of the behaviour of high pressure H2S and CO2 mixtures; compliance of laboratory tests with field conditions is important towards materials selection.
Successful Application of Innovative Reversible Invert Emulsion Reservoir Drilling Fluid and Improved Filter-Cake Cleanup Agent Increased Sustained Well Productivity in Smart Multilateral Wells with Inflow Control Device and Smart Completion in High Mobility Reservoir, West Kuwait
Authors: Das Om Prakash , Al-Enezi Khalaf 
Published: April 2016

Abstract
Maximizing sustained well productivity from smart multilateral wells in heterogeneous reservoir completed with Inflow Control Device completion (ICD) and smart completion requires effective filter-cake cleanup to ensure uniform inflow contribution from entire horizontal section. The specially designed reversible invert emulsion Reservoir Drilling Fluid (RDF) along with filter-cake cleanup agent were utilized in drilling and completion of Kuwait's first Level-4 smart multilateral well in Burgan reservoir of west Kuwait. Further the reservoir is having vertically stacked thin channel sands associated with complex fault network makes drilling and completion of multilateral wells challenging and necessitated an innovative Reservoir Drilling Fluid and effective filter-cake cleanup to maximize the completion efficiency. Moreover the combination of high water mobility due to hydrocarbon viscosity ranging from 40 to 60 cP at reservoir conditions and fault network connected to aquifer causes severe premature water breakthrough. The smart multilateral wells have addressed premature water breakthrough problem and enhanced well productivity by facilitating the adequate reservoir management. The horizontal sections of smart multilateral wells were drilled with invert emulsion reservoir drilling fluid and achieved gauged hole which facilitated trouble free ICD completion installation along with large quantity swell packers. Novel filter cake cleanup agent was pumped immediately after running the ICD completion to change filter cake wettability from oil-wet to water-wet for uniform cleanup and thereby regained original reservoir permeability. This has eliminated the risk of formation impairment, ICD screen and nozzle plugging and established excellent well productivity. The well has achieved significantly increased sustained well productivity by having low wellbore skin. The paper covers the selection and design of reversible invert emulsion drilling fluid along with filter-cake cleanup system, well completion operations and long term well performance results.
To Boldly Go Where No Crane Has Gone Before
Authors: McGrath Keir , Fisher Stewart , Blench Peter 
Published: April 2016

Abstract
TOTAL Abu Al Bukhoosh (TOTAL ABK) is an Oil and Gas super complex located 180 km away from Abu Dhab. coastlines in the United Arab Emirates. Offshore platforms are well known to be challenging in regards to confined and cramped spaces with limited access for repairs, maintenance or interventions. The installation of a specific 220 meters- 14′ gas line required multiple connections and new fittings. However, these were outside the operational radius of the platform pedestal crane. In order to tackle this issue, an innovative and clever solution was identified with the use of multi functional crane able to combine compact size and heavy lifting power.
As a first time on an Middle East platform, a URW-376 UNIC mini crane was used and allowed this challenging lifting operation to be safely performed. The 12 barg 14′ gas line was swiftly installed over the side of the Work Over platform upper deck where no steel beams are available to place runway beams.
This paper presents in details the lessons learned and the overall benefit of this peculiar lifting operation that allowed all the gas line components to be installed in a timely and efficient manner although located in a critical zone 2 rated area. High level of mobility, 360 degrees radius and highly versatile operating range are all discussed and illustrates why, at TABK : "we like better our spider crane than spider man".
Geo-processing for Surface Development Optimization
Authors: Hewitt Anthony , Vidal Arnaud 
Published: April 2016

Abstract
Installation and development of surface infrastructures is more and more challenging and often occurs in complex and/or sensitive contexts.
In such situations manual flow-line routing assessment has to be replaced by computed solutions which are capable of taking into account lots of external constrains at the same time they honor internal parameters.
For new developing fields and more specifically onshore it is important to optimize as much as possible locations of surface installations to respect safety, environmental, societal and economic backdrops. Rationalization of infrastructure plans from scratch is also a way to prepare sustainable development for the future.
Within TOTAL, Geomatics discipline including use of Geographical Information Systems in combination with geo-processing tools offers appropriate integrated solutions. These tools require gathering multiple data such as Digital Elevation Models, slope models, satellite imageries and take into account spatial, operational and safety conditions, allowing data analysis, processing and comparison between scenarios.
Each object must be identified using a data structure type, either Raster or Vector allowing the use of two types of optimization algorithms: classical based on raster or vector data and heuristic based on raster and/or graph and interactive constrains. In addition to these Spatial and 3D analyst tools, more specific processing algorithms must be implemented.
On a case study this method allowed connecting all well-heads to a Central Processing facility (CPF) in a very severe environmental context; the proposed ‘Minimum Spanning Tree’ solution considerably reduced the environmental footprint and connecting costs. Generalizing more geo-processing tools and including more operational constraints proved to be even more useful for new developing fields and their early surface installations development. Main improvements are on production side, reducing flow-lines length and optimizing flow assurance.
Applications are wide open; this approach can take into account more constrains like existing installations, societal environment, geo-morphological features and relief. Therefore its consideration for onshore mature fields is an obvious way forward.
In the Digital Era, with the hike in data acquisition and Google Earth and GPS in any smart-phone, considering computed GIS techniques to drive and optimize our surface installation positioning is an innovation guarantying environment respectful and sustainable development for petroleum infrastructures.
Utilization of Metallic Sulfur/Nanocarbon Hybrids as a Transparent Conductive Film
Authors: Fujimori Toshihiko 
Published: April 2016

Abstract
One of the major issues in the petroleum industries is to find out a new way to utilize excessive amounts of elemental sulfur, which has been produced during the refinery process of petroleum. Despite the importance, its use is limited to being an inexpensive reagent (e.g., sulfuric acid, fertilizers, and vulcanization of rubbers). Here we introduce a way to utilize elemental surfur as a metal wire. With an aid of ongoing nanotechnology based on carbon nanotubes (CNTs), we successfully synthesize this new metallic phase of sulfur using one-dimensional channels of CNTs as a template (Fujimori et al., Nature Commun. 2013). The key phenomenon is the formation of monatomic sulfur chains, which are essential for carrying electric current along the chains. Since the presence of metallic sulfur improve electric conductivity of pristine CNTs, the ability of the sulfur/CNT hybrid material involves a wide range of practical applications including next-generation electric devices for solar cells, touch panels of smartphones, or superlight-weight electric cables. Here we will demonstrate the potential application of the sulfur/CNT nanomaterials as a transparent conductive film (TCF) used in solar cells or touch panels. Although Indium-Tin-Oxide (ITO) has been commonly used as a TCF, it is inevitable that depletion of indium, which is one of the rare metals required for sustaining contemporary society, will emerge as a world-wide issue in the near future. We believe that the metallic sulfur/carbon nanomaterial has a rich potential to overcome this issue, contributing to the sustainable society that does not rely on rare metals. Most importantly, the CNT-template method is easy to handle, thus promoting the future utilization of excess sulfur.
Not Under My Watch !
Authors: Al Blooshi Muna , Duguay Alexandra , Hewitt Anthony , Delattre Eric , Brieussel Celine , Al Saabri Hassan 
Published: April 2016

Abstract
TOTAL ABK has initiated many actions in order to improve preparedness for emergency situations related to oil pollution. Task forces, more stringent audits, stronger management system requirements and procedures, tightened reporting exigencies and overall top of the notch oil spill surveillance tools were successfully integrated.
Using creative thinking to tackle this paramount environmental topic, "Not under my Watch" is a project resulting in significant optimization of our strategy and Preparedness to response to accidental oil spill.
As a direct result from this project, we are in a better position to anticipate and have significantly strengthened our preparedness level to respond to any oil spill.