bluuebunny/crossref_metadata_2025_split huggingface dataset:
Hydraulic Modeling Helps Designing Ultralow ECD Nonaqueous Fluids to Meet Narrow ECD Windows
Authors: Hui Zhou , Chesnee Davis , Jay Deville , Bill Shumway , Ryan Schiro , Tim Bailey , Rob Valenziano , David Carbajal 
Published: November 2018

Abstract
Hydraulic modeling was used to simulate the effect of fluid rheology (both high- and low-shear-rate rheology) on the equivalent circulating density (ECD) at critical points in the well. The modeling results provided a guide for the design of nonaqueous fluid properties necessary to achieve the required ultralow ECD values. Using a combination of a rheology modifier and a new low-end fluid rheology enhancer, ultralow ECD nonaqueous fluids were successfully developed to meet the fluid rheology and barire sag requirement. The low-end fluid rheology enhancer provided a desired gel structure that helps minimize barite sag, which is often the concern for low-rheology nonaqueous fluids.
The hydraulic modeling results showed that, although both high- and low-shear-rate fluid rheology must be very low to achieve ultralow ECD values, the reduction of high-shear-rate rheology has a larger effect on the reduction of ECD values. For a given ECD value, a fluid with a lower high-shear-rate rheology and higher low-shear-rate rheology is preferred because the higher low-shear-rate rheology is due to a much-desired gel structure that helps reduce barite sag during static aging. Hole cleaning is also expected to improve with higher low-shear-rate rheology.
Based on this information, a 14.0-lbm/gal clay-free nonaqueous drilling fluid was successfully formulated to achieve the required ECD without the use of micronized barite. As described, the fluid uses the combination of two rheology modifiers, one of which functions as a gel strength enhancer that provides the much-needed gel structure to minimize barite sag.
Lost-Circulation Control Material Yields Successful Cementing Operation and Achieves Good Zonal Isolation in Middle East Region
Authors: HamidZada AhmedAgha , De Barros Adelson Jose , El Sayed Ashraf , Matar Wael , Bereikaa Hesham , Vaidyanathan Vignesh , Ruben Medina 
Published: November 2018

Abstract
While drilling an 8.5 in. open hole in the Umm Shaif field, an unexpected fault was encountered across formation ARAB-D2, increasing losses from 15.0 to 40.0 bbl/hr. Initial losses were managed using mud lost-circulation material (LCM) pills; however, losses were observed again while running the liner. It was decided to cement the liner to secure the shoe, with the expectation of being required to perform a remedial operation. The liner was cemented with all precautions to help prevent further loss.
By systematically introducing enhancements to the cementing and liner running practices and optimizing the fluid (cement/spacer) design using the latest technology fiber system in the spacer, it was possible to achieve the objective to control losses during the cementing operation. Additionally, securing the shoe and isolating the reservoir zone while preparing for a top-of-liner squeeze and liner perforation, if necessary, to squeeze cement in poorly isolated zones was achieved. Three-dimensional (3D) placement simulator software was used to model the flow rates and the equivalent circulating density (ECD) during the operation, and sensitivity runs were performed to observe worst-case scenarios at different loss rates to optimize volumes, rates, etc.
Once the spacer crossed the loss zone, lost-circulation additives (composed of a blend of various additives) began bridging across the zone, enabling the cement slurry to reach the top of liner, where it circulated excess cement. The tagged hard cement above the top-of-liner log exhibited good isolation to the reservoir formation, no remedial operations were necessary for the shoe and top of liner, and no perforations were necessary.
Spacer fluids are an environmentally acceptable blend of carefully selected materials, including coarse and tough LCM, fibers, and medium-sized, resilient angular materials. These fluid systems help mitigate losses when cementing across weak, unconsolidated, or fractured formations and carry materials with both high-pressure integrity and compressibility to help ensure tolerance to modifications in fracture size, caused by differential pressure fluctuations, without the materials being dislodged or allowing collapse. These materials are stable and insoluble in water. The spacer fluid system breaks the emulsion of oil-based drilling fluid, water wetting the casing pipe and the formation in preparation for cement bonding. Additionally, such materials resist intermingling of fluids at the interface in the fluid train.
Study on Flow Diversion Caused by Deformable Preformed Particle Gel
Authors: Zhou Kang , Hou Jian , Wu Dejun , Du Qingjun 
Published: November 2018

Abstract
Water channeling becomes severer after long time of water flooding especially in heterogeneous oil reservoirs. Field applications of deformable preformed particle gel (PPG) in China has proved that injection of PPG can lead to flow diversion, increase sweeping efficiency and thus increase oil recovery. However, it is unclear how PPG promotes flow diversion and its controlling influence factors. To address this problem, the paper carries out the microscopic simulation study.
The flow of deformable PPG is complex, involving particle deformation, migration, fluid flow and particle-fluid interaction. In the study, the discrete boundary idea of immersed boundary method is used to deal with particle deformation. The lattice boltzmann method (LBM) and immersed moving boundary method (IMB) are combined to simulate the fluid flow considering the existence of particles. The discrete element method (DEM) is used to simulate particle-particle and particle-wall contact. Combining these techniques, the paper studies how deformable PPG migrates in a two-channel model and promotes flow diversion. The effect of particle diameter and elastic modulus on flow diversion is also discussed.
The two-channel model simulation results show that the fractional flow increases and decreases alternately between the two channels. This is mainly because the flow resistance increases and forces more subsequent water turns to another channel due to the particle deformation and wall friction when the PPG migrates in one channel. The influencing factor discussions indicate that in a certain extent the flow diversion capacity of deformable PPG increases as the PPG diameter and elastic modulus increase. However, overlarge PPG diameter and elastic modulus may block the small channel. In this situation, the fractional flow of small channel decreases to 0 and the water channeling becomes much more severer. Therefore, the PPG diameter and elastic modulus should be properly selected in order to obtain flow diversion and reduce water channeling in field applications.
The paper focuses on how deformable PPG promotes flow diversion, which provides a microscopic interpretation on enhanced oil recovery mechanism of PPG in heterogeneous reservoirs. The influencing factor analyses also provide valuable references for future applications of deformable PPG in more oilfields.
Right Data, Right Place, Right Time: The Evolution of a Data Acquisition Strategy for a Tight Gas Development in the Sultanate of Oman
Authors: Dawson William , Spain David , Rashdi Khalil Al , Saadi Sawsan Al , Gangopadhyay Abhijit , McTeague Mike , Busafi Badar Al 
Published: November 2018

Abstract
BP is developing the Khazzan and Ghazeer fields of Block 61 in the Sultanate of Oman. The development includes three Cambro-Ordovician tight gas sand reservoirs which require hydraulic fracturing for commercial production rates. There are challenges with depth and high temperature for the open hole logging environment, with a restrictive inner diameter and residual proppant creating challenges for the cased hole logging environment. Additionally, there are cost challenges on all data acquisition including coring, downhole gauges, sampling, proppant tracers and many other forms of surveillance.
This paper outlines the evolution of the data acquisition strategy for the Khazzan and Ghazeer assets. The development plan at project sanction was 20 vertical and 272 horizontal wells. The data acquisition strategy led to the development of a data acquisition plan, and all stakeholders were engaged to ensure the right data was acquired in the right place at the right time. Cross functional behaviours and fiscal discipline were essential in this process. Inclusion of the service companies into the wider BP team was crucial to ensure appropriate technology was applied, learning from previous operations implemented and new technology options made available.
Through careful management of the data acquisition plan, all data in development wells prior to first gas were acquired within the allocated data acquisition budget despite drilling 20% more wells than originally planned for this period. Early improvement in subsurface understanding enabled an overall reduction in well count for the life of the project, extension of the original development into unpenetrated areas, adding significant value to the project.
Energy Harvesting for Downhole Applications in Open-hole Multilaterals
Authors: Arsalan Muhammad , J. Ahmad Talha , S. Saeed Abubaker 
Published: November 2018

Abstract
This paper addresses the need and challenges associated with the energy harvesting methods in the downhole multilateral openhole horizontal well environment. The need for downhole energy harvesting is discussed and the functional requirements are established. Different means of energy harvesting that are available in either or both flowing and shut-in conditions are presented and the possibility of using them in the downhole horizontal wells for long-term monitoring and control systems is evaluated.
A Success Story of an Integrated Excel Based Process Simulation Model
Authors: Muthukrishnan Murali , Al Matroushi Mohamed Salem 
Published: November 2018

Abstract
Process Simulation model has the capability to provide optimum solutions for achieving higher productivity and efficiency of the existing processing facilities. To achieve this, process simulation model is required to be updated with actual operating conditions and composition. This activity requires substantial time to obtain the operating conditions and updating the simulation model for every changes of plant operating conditions and composition. In order to enhance the process of updating the simulation model for analyzing and troubleshooting the current performance in a proactive manner, an Excel based tool is developed to integrate the simulation model with Historian data. This Excel based tool will automatically update the operating data and composition in the process simulation model for the selected date (Historicisn data) and transfer the results from process simulation model back to the excel for further analysis.
The name specified by ADNOC Gas Processing for this excel tool is "Plant Simulation Interface (PSI)" Model. Following key advantages can be realized by using the PSI model. Validation of the process simulation model (Aspen HYSYS) using current plant data to establish a base case.Carrying out Preliminary Adequacy check of the plant within short schedule for different processing capacities and composition.Increasing the efficiency of the plant by fine-tuning the operating conditions within the operating envelope.Perform case studies to study the impact before implementing in the processing unit.Faulty instruments can be easily identified.Extraction of the results - required parameters and properties are easier and faster.No process simulation experience / expert is required as this works in Excel based environment except for the development of base model.
PSI model is developed in one of the processing facility of ADNOC Gas processing. Similar model is being developed for all the processing facilities in ADNOC Gas Processing. It is possible to extend similar ideas and develop Integrated Excel based simulation models for any oil and gas processing unit to increase agility in decision making, improve reliability and reduce the operating cost.
This paper outlines the procedure to develop an integrated Excel tool by linking the high fidelity simulation models with the data historian tags (PI data), Laboratory Information management system (LIMS) and to automate the complex workflow and the advantages of using this model.
OCTG Corrosion Status Monitoring in Wells Completed with Challenging High Ni CRA Non-Magnetic OCTG in Gas Well Environment with Higher Temperature, Extreme Hydrogen Sulphide and Reservoir Conditions – A Case Study
Authors: Sparke Simon , Abu-Ramoun Husam , Singh Basant Kumar , Dawson Graeme 
Published: November 2018

Abstract
This paper identifies a field with challenging well operating conditions for OCTG Corrosion logging in gas well that include pressure, temperature, carbon dioxide (CO2), hydrogen sulphide (H2S) and well completed with high Ni corrosion resistant alloys (CRA).
This case study, describes how periodic well interventions to measure the wall thickness of various strings, required specialised technologies in gas well to the high chromium and nickel content in the tubing which reduces the magnetic properties of the string(s).
All well interventions require careful tool selection, planning and implementation, however when the conditions are extreme and present HSE related issues, the planning must reflect a greater level of detail and understanding.
Additionally, the logging and interpretation process required for high end CRA tubulars is more detailed and sophisticated and little public domain data is available to assist in the well programme implementation. The Operator required logging tools to be fitted with highly sensitive and fast responding sensors, housed in titanium casings and run in memory mode with a slickline conveyance.
In this case study two wells were logged with multibarrier corrosion logging tools combined with multi-finger calipers, to determine tubing and casing thickness status of three tubular barriers. The flow wetted areas were completed with high end chrome/nickel tubulars with potential challenges for data acquisition and subsequent analysis. However, pre-logging planning was supported and bench marked by yard testing where identical composition materials had been used.
On retrieval, the data package showed provided a composite set of data, throughout the well and log interpretation clearly identified the well status to be positive. This provides excellent support for the applied logging technology.
Pre-logging data searches within SPE and other locations for academic papers describing similar scenario could not be found and this paper is understood to be the one of first kind. These specialized principles and procedures likely to provide with much needed BASE CASE guideline for such future corrosion monitoring logging in similar field conditions.
GIS: The Global Risk Mapping Towards Digital
Authors: Gouviez Benoit , George Bina , Nizar Mouna 
Published: November 2018

Abstract
Abu Al Bukhoosh (ABK) is an oil and gas field located 180 kilometers away from the Abu Dhabi's coast and has been in operation since 1974. The complex was gradually developed over the past forty years, and has some aging platforms and facilities.
As a consequence the problems related to Asset Integrity is one of the most important with regards to Operations Risk Management. Repairs or intervention activities must have very specific and rigorous plans for addressing barriers to prevent uncontrollable loss of containment from the wellbore to the external environment. Hence continuous monitoring and integrity management of the field is mandatory for long-term profitability and HSE performance in an aging asset like ABK.
Asset Integrity is usually well covered during technical discussions and meetings, and is usually considered as a subject matter expert topic. However Asset Integrity and its associated technological risks are usually less discussed during general events involving the whole organization. This is more limited to operational safety KPI's, the protection of the environment and the prevention of accidents to people. These are easier topics to discuss and are more suited to the corporate communication materials.
Northern Sea Route as the Main Driver for the Arctic Development: Challenges with Infrastructure and Opportunities for International Cooperation
Authors: Akimova Irina 
Published: November 2018

Abstract
Arctic's huge reserves potential development was blocked for many years by the lack of accessible and all-year open for navigation transport routes. In spite of the fact that the Northern Sea Route is the shortest way from Europe to Asia, currently about 75% of the total cargo turnover delivers through the south corridor via the Suez Canal and the Mediterrenian sea, but the turnover via the Northern Sea Route is growing rapidly over the past years. Due to the strategic allocation of the Northern Sea Route it attracts enormous attention of the international companies now. This paper highlights challenges with the development of the Northern Sea Route nowadays along with the opportunities for international cooperation.
Reducing the Risks of Emissions and Potential Loss of Production Due to Uncontrolled Off Spec Gas into Pipeline by Modification of the Logic of Shutdown Valve
Authors: Kurniawan Fanda , Nugroho Aditya Bagoes , Walahendra I Putu 
Published: November 2018

Abstract
Potential loss of production and gas emissions to flare constitute major problems in gas processing plant when off-spec gas cannot be controlled and may cause the entire gas to pipeline being off-spec and endanger liquefied natural gas (LNG) plant as the buyers have to burn the entire gas in gas pipeline to flare and, thus, there is an increase in emissions to environment. Normally, the gas impurity parameters to be maintained in a plant consist of Hydrogen Sulfide (H2S), Carbon Dioxide (CO2) and water content (H2O), which are monitored by the online analyzer transmitter installed after the purification units, such as acid gas removal unit and dehydration unit. The transmitter normally does not send the interlock signal to command the plant shutdown due to several factors which may affect the values of the analyzer. However, the off-spec gas shall not be allowed to enter the pipeline; otherwise, emissions and loss of production cannot be controlled. Among the methods to control off-spec gas is to shut the export gas to the pipeline remotely whenever there is confirmed off-spec sales gas. Modification of control of sales gas shutdown during an off-spec event can be done by adding a logic from the remote push button to the shutdown valve at the export gas line which can be operated by human intervention to prevent the off-spec gas from being delivered to the pipeline and buyers which may lead to an increase in emissions to environment and a loss of production.
Multimillion Cell Dynamic Model for High Resolution Studies of a Carbonate Reservoir, Part-1
Authors: Al Jenaibi Faisal , Giddins Marie Ann , Valero Adelis , Ali Samad , Saeed Yawar , Amtereg Ahmed , Bajwa Ali 
Published: November 2018

Abstract
Simulating a high-resolution multimillion cell model brings many benefits, by enabling reservoir engineers to use the best grid size for accurate representation of water and gas movement in the reservoir, essential for advanced field management, Enhanced Oil Recovery or complex well design studies.
To improve the characterization of a giant heterogeneous carbonate reservoir and enhance the quality of field development plans, new high-resolution static and dynamic models have been used to study one of the largest oil fields in Abu Dhabi. A detailed static model of over 50 million grid cells was constructed, using a unique water saturation modeling approach, without upscaling to a dynamic simulation, using hysteresis for both relative permeability and capillary pressure.
The reservoir has over 50 years of history, with hundreds of vertical and horizontal wells. Large volumes of data from well logs, cores and other measurements were used to populate the static model, define dynamic rock types and match well log water saturation and water capillary pressure profiles. The concept of wettability change with depth was introduced, with an oil-wet system at the crest, graduating to a water-wet system near the thin transition zone. A geological resolution grid was used for reservoir simulation studies, after testing input data consistency and stable behavior.
A stability test was performed by running the simulation with no wells for 50 years after equilibration and showed no movable fluids. This verified the consistency of the reservoir static properties, rock types, water saturation, relative permeability and fluid model. A history matched case was developed with over 850 wells using the same fine grid, to meet the objective of completing each simulation run within one day. After history matching, a compositional simulation model was built, to investigate the impact of grid resolution on future production forecasts.
This is the largest dynamic model built by the company and demonstrates the benefits of rigorous attention to the quality of the static data, while using modern simulation workflows to avoid compromising the detailed model by upscaling. The methodologies presented in this paper will be adopted as best practices for future similar projects.
Modified Thermal Maturity Models for Kuwait Basin Through Mud Gas Isotope Logging While Drilling; Benefits of Analyzing d13C2 and d13C3 at Wellsite
Authors: Dashti Jalal , Al-Awadi Mashari , Mushnuri Sudhakar , Al-Meshilah Thuwaini , Shoeibi Ahmad , Cecconi Bianca , Estarabadi Javad 
Published: November 2018

Abstract
Carbon isotopic characterization of mud gas can add great value to the information collected at wellsite and nowadays the interest in this topic is increasing as documented by the study from Poirier et al. (IMOG 2017).
The presented study has the objective of illustrating the data logged through a cavity ring-down spectroscopic (CRDS) technique that allowed collection of robust and reliable carbon isotopic data at wellsite. The logged carbon isotopic data were then used for studying the behavior of two formations (Makhul and Najmah) across different fields. Makhul Formation represents the lower most Formation of Cretaceous in Kuwait, representing predominantly as carbonate rock. In lower Makhul, the high gamma radioactivity is due to enrichment of the shales by uranium. While, Najmah formation is an excellent source rock located in upper Jurassic, it consists of black calcareous limestone source rock with high organic content. Both formations are considered as major source rocks for petroleum systems in state of Kuwait. Many standard interpretation models from the literature were screened and adopted in inter-field correlation, resulting in a good matching with the geographical distribution of the fields.
The second part of the study will focus on the added value of recording carbon isotopic ratios up to C3. The analysis of δ13C3 is demanding from the instrumental point of view, thus, the benefits in terms of formation evaluation that comes from the logging of isotopes up to C3 will be illustrated in the study. With reference to other literatures, δ13C1 readings might be affected by mixing phenomena with biogenic gases, and thus they are not the best candidates to run maturity assessment through isotopes. Instead, carbon isotopic ratios of ethane and propane are not affected by mixing with biogenic gas, resulting in more robust and accurate interpretations. Few models from literature were applied on collected data, allowing choosing the one that matches best the behavior of the studied basin.
Independent measurements on the maturity of the source rock in the area confirmed that the trend highlighted through carbon isotopes logging at wellsite is correct, validating the usefulness of this technique at wellsite.