bluuebunny/crossref_metadata_2025_split huggingface dataset:
In-situ Proppant: Beads, Microproppant, and Channelized-Proppant
Authors: Huang Jiangshui , Gong Wei , Lin Lijun , Yin Congbin , Liu Fuchen , Zhou Han , Bai Litao , Song Lulu , Yang Zhengzhou 
Published: November 2019

Abstract
Tight oil reservoirs need stimulation in order to produce the trapped oil. The most common form of stimulation used by the oil and gas industry is hydraulic fracturing. Fracturing operations tend to create fractures including primary fractures and microfractures. The objective of this study is to develop a fracturing fluid which can be converted into microproppant, beads, and channelized-proppant as desired in-situ during a fracturing operation to enhance the hydraulic conductivity of the microfractures and the primary fractures, and simplify the hydraulic fracturing operation, where the channelized-proppant is defined as the pillars surrounded by channels.
Resin, curing agents, surfactants, and aqueous phase were mixed together to form O/W emulsion to serve as fracturing fluid. After curing process, resin and curing agent would react and form proppant in-situ. The parameters affect the proppant formation such as the curing temperatures, pressure, mixing strength, surfactant concentration, and size control additives were all studied and thus through controlling the parameters, microproppant, beads, and channelized-proppant can form in-situ as desired. The particle size distribution, sphericity, roundness, conductivity, acid solubility, and crush strength were tested.
Through controlling the experimental parameters and adding size control additives, fracturing fluid can be converted into microproppant, beads, and channelized-proppant as desired at a temperature from 30° C to 90° C. Almost 100% of the resin and the curing agents were converted into proppant with a specific density of 1.09g/ml. For the beads, both the sphericity and roundness are over 0.9, less than 2% fines were generated after being loaded to 15 kpsi, the acid solubility is 2.37%, and the conductivity of the beads of 20/40 mesh tested with proppant loading of 1 lb/ft2 at 4000 psi at room temperature was 227 mD-ft. For the microproppant, both the sphericity and roundness are close to 1 with d50 about 80 µm. Furthermore, channelized-proppant was formed in an artificial fracture with walls made of glass sheets. Thus, with the fracturing fluid developed, the conductivity of the well can be maximally optimized through the in-situ formation of channelized proppant and microproppant to keep the primary fractures and microfractures open respectively.
Designing the Maximum Allowable Cost of Surface Facilities Using the Control Chart Analysis: A Case Study in Indonesia
Authors: Abdul Azizurrofi Ahmad , Erwanto Edward , Asnidar Asnidar , Rahmat Firdaus Rikky 
Published: November 2019

ABSTRACT
During the period from 2005 to 2018, the oil prices had reached the highest level in 2008 (99.67 US$/bbl) and the lowest level in 2016 (43 US$/bbl). The fluctuation in oil prices will affects the cost of investment (drilling and surface facilities) worlwide. Based on this condition, the standardization of the Investment Cost is needed to help the government and contractor in estimating the cost of investment in an oil and gas project.
As per December 2018, there were 471 projects approved by the government of Indonesia and the 266 of them are projects that producing oil (oil projects) and gas (gas projects). In these projects, there are details of investment costs that are included in the economic evaluation. This paper will calculate and produce the Maximum Allowable Cost ("MAC") of surface facilities per boe (US$/boe) based on statistical analysis of 266 projects. Hopefully, this method can be used as a reference (guidance) in giving approval for the cost of surface facilities and providing an overview to contractors regarding the estimated MAC of surface facilities in an oil and gas project.
For the purpose of this paper is, to divide the areas of Indonesia into 2 areas (Onshore and Offshore) which in each of these areas has 2 different types of projects (oil project and gas project). Then, to collect the data that related to cost of surface facilities and reserves and then the MAC of surface facilities per boe are calculated and produced using the Control Chart Analysis method. Lastly, the result will be distributed to those aforementioned areas.
Based on the analysis of 266 Projects in Indonesia, the MAC of surface facilities per boe in Onshore area are 20.80 US$/boe (oil project) and 18.59 US$/boe (gas project), while the MAC of surface facilities per boe in Offshore area are 14.32 US$/boe (oil project) and 27.62 US$/boe (gas projects). In general, the MAC of surface facilities per boe still far bellow the oil price.
Finally, this paper will show how to produce MAC of surface facilities per boe by using control chart analysis. This paper also expected to provide references for the government of Indonesia in giving approval to the cost of surface facilities proposed by contractors and provide contractors a quick look at oil and gas industry in Indonesia especially to those who plan to invest in Indonesia, and also help them create their petroleum exploration and exploitation strategy in Indonesia by considering on this information that will provide benefits for both government and contractor.
Cost Effective Structural Extension of Shallow Water Wellhead-Cum-Production Platforms with Concept of Partial Jacket
Authors: Shah Jinesh , Chatterjee Prabir 
Published: November 2019

Abstract
Due to requirements of process and other facilities upgrade, offshore platforms frequently need structural extension to create additional deck space. The present work deals with a wellhead-cum-production platform installed in 2011 at offshore Turkmenistan of Caspian Sea. The offshore platform consists of two 4-legged fixed jackets in 33.0 m water depth with 12-conductor slots. The platform requires additional space to install artificial lift systems and other process facility upgrades along with increased power generation capacity. Installation of another 4-legged jacket requires several months of engineering, construction and installation activities with sizeable marine spread and significant additional cost. Hence, to optimize the cost and schedule, extension of the platform is designed considering two partial jackets connected to the platform by means of clamped (underwater) and welded (above water) connections which can be carried out by smaller capacity cranes ensuring easy integration to the existing structure.
This paper proposes a method of installing horizontal structural extension by partial jackets and new piles. The structural extension of the platform will provide about 30% additional deck space with two or three levels. A partial-jacket is adequately connected to the existing structure to ensure intended distribution of vertical and horizontal loads. A partial-jacket frame thus address the requirements of guiding the piles as well as strengthening of the platform in compliance with code-check requirements (API RP 2A or ISO 19902).
Most of the steel structure can be fabricated and assembled at onshore and transported to designated location based on lifting capacity of the installation barge/vessel crane. The partial jackets, pile segments, deck framing and other loose items can be lifted (to/from the transportation barge) and installed by a barge crane of about 100 MT capacity for the present case. The same crane can also be utilized to drive the new piles.
The few advantages of the proposed method are: An optimum solution to create additional space for extra process facilities on production platformThe light structural weight helps in utilizing available small crane vessel for installation of partial jackets, deck framing and also driving the piles.The installation can be done in phases to address the immediate upgrade requirements.The entire installation work can be completed within a few weeks with minimum errors/ misalignment.This approach of platform extension has the flexibility for easy integration to the existing structure.The engineering, fabrication and installation actitivities can be performed by in-house resources (if available).
Selecting Friction Reducers Based on Variability in the Completion Water Mineralogy: Case Study, Permian Basin
Authors: Zamar Federico , Mendoza Cinthia Duran , Adil Faraaz 
Published: November 2019

Abstract
Performance comparisons of different tier friction reducers (FRs) using field water samples from the Delaware and Midland basins within the Permian Basin are discussed. The objective is to correlate them with their respective water mineralogy to identify the primary components affecting FR effectiveness, allowing a proper FR selection based on individual elements and not just by total dissolved solids (TDS). Identifying critical minerals that affect the proper FR selection enables making an educated FR selection not based on TDS count alone, which could potentially reduce the amount of testing and unsuccessful field trials.
To zero in on the primary elements within the water that affect friction reduction behavior, extensive testing was performed. Traditional and inductive couple plasma (ICP) water analyses were performed to determine mineralogy, and flow loop testing was performed to determine FR performance. Additionally, specific parameters (i.e., hydration time, maximum FR percentage, and stability) were measured and compared to the multiple tests to determine trends between FR performance and water mineralogy.
Understanding how a flow loop apparatus works is discussed, which helps when interpreting friction reduction performance. This is a fundamental component for understanding the behavior of the FR during testing and how it affects performance in the field. Additionally, this paper can be used as a basic guide for flow loop interpretation, and it attempts to identify possible causes of varying FR behavior in the field versus laboratory testing.
Towards Real-Time Edge Analytics - A Survey Literature Review of Real-Time Data Acquisition Evolution in the Upstream Oil and Gas Industry
Authors: Djamaluddin Basirudin , Jovin Tony , Nugraha Budhi 
Published: November 2019

Abstract
Edge analytics in the oil and gas industry has become an important topic, especially with the development of Industry 4.0. This paper reviews the existing literature regarding the movement away from traditional data acquisition and towards edge analytics. A meticulous, systematic literature review was conducted in order to understand how the industry would benefit from the implementation of edge analytics. It also aims to discover any advanced technologies belonging to other industries that could be of benefit to oil and gas.
The result shows that edge analytics implementation in oil and gas industry has started to build evidence for its successful implementation at the wellsite. Various innovations from other industries may be useful for further enhancement of existing edge analytics or transforming existing data aggregation of data acquisition at the wellsite.
Advanced Production Plant Optimization with AI
Authors: Kalagnanam Jayant , Piotrowski Dariusz , Murali Pavankumar , Subrahmanian Dharmashankar , Zhou Joe , Ma Claire , Silva Giovane , Williams Jacqueline , Liu Crystal , Haider Adnan , Rahman Pavel 
Published: November 2019

Abstract
Managing the dynamic behavioral changes of a production plant process to keep to a production plan is a challenge and requires the ability to predict the dynamic behavior of processes and alter any controls, as needed, to adhere as closely as possible to the plan. This paper presents a novel solution (called Cognitive Plant Advisor) based on the use of advanced machine learning to learn complex dynamics from sensor data coupled with mathematical programming to optimize the operations of a production plant. The Cognitive Plant Advisor provides set point recommedations for a 12-72 hour horizon to (i) improve throughput, or (ii) provide optimal recovery plan for a disruption. This advisory system has the potential to improve throughput by upto 1% of total production.
Novel Approach to Matrix Corrections in Complex Khuff Deep Gas Reservoirs, offshore Abu Dhabi
Authors: Menon Pradeep , Steiner Stefan , Mills Carey , Basioni Mahmoud , Mosse Laurent , Dasgupta Suvodip 
Published: November 2019

Abstract
The Permo-Triassic Formation of Khuff in offshore Abu Dhabi has shown a considerable potential as a tight gas reservoir, but the complex mineralogy and the heterogeneity has made formation evaluation challenging for this reservoir, particularly in respect to saturation. Complexities with log interpretation in these tight formations have called for the use the advanced measurements to help interpret more basic logs in a simple but accurate and consistent manner.
Deriving porosity from density requires the knowledge of matrix density. In complex Khuff reservoir, with a varying mix of dolomite and anhydrite with some calcite, it is impossible to put a constant matrix density. Photoelectric factor is not enough to resolve the mineralogy and advanced spectroscopy measurement is mandatory to provide matrix properties such as grain density, neutron (thermal and epithermal) and sigma (capture cross-section). These properties are used to compensate the formation density, neutron and sigma for the matrix effect, focusing any residual separation between the corrected porosities onto fluid effects.
Matrix-corrected density, neutron and sigma porosity curves can be used effectively to qualitatively interpret presence of gas, which is a big challenge in these tight gas reservoirs and this approach is demonstrated on multiple datasets. Since this is being applied on wireline logs with a depth of investigation shallower than 10-in, uncertainties remain concerning the deep, uninvaded zone water saturation. The deep resistivity measurement is still the only access to deep saturation. To quantify the water saturation from resistivity, besides the knowledge of formation water salinity, the other key information is the Archie parameter m (cementation exponent), which is directly dependent on the texture of the rock. Complex diagenesis on the varying mineralogy of the Khuff has created complex water-phase tortuosity, which needs to be considered. Multi-frequency dielectric measurement in addition to giving a shallow zone water saturation, also provides a water-phase tortuosity parameter, which is then used to improve deep water saturation computation.
When facing a complex reservoir, the temptation is high to jump to complex evaluation workflows, neglecting simple, quick-look-type approaches. However, advanced measurements, such as spectroscopy and dielectric dispersion empower this type of simple approach, enabling efficient controls and insights on the evaluation, as will be shown through the examples in this paper. Final evaluation still requires a fully integrated analysis, but it will benefit from the lesson learnt and insights from the quick-look.
Unlocking Challenges in Water Injection Development Schemes Utilizing a Novel IRM Automation Workflow for Opportunities Generation
Authors: Shbair Alaa , Saputelli Luigi , Noordin Firdaus , Bogoslavets Victor , Alblooshi Younes , Soufi Abdulrahman Al , Hijjawi Mohammed 
Published: November 2019

Abstract
Water injection is by far the most popular method used in the secondary recovery phase of field development for oil displacement and pressure maintenance. Proactive reservoir management is important to validate the efficiency of the existing water injection schemes and to assess field development strategies to prolong oil production plateau and improve the recovery factor (RF). The main challenges arise in stretching the reservoir target whilst ensuring stabilized or reduced water cut (WCT), minimizing by-passed oil volumes and preventing wells from becoming inactive due to high WCT.
In order to mitigate premature water flooding issues, mainly two options are available: (1) artificial lift techniques to activate producers suffering early and rapid water breakthrough; and (2) optimized completion designs via preventive or corrective controls. Preventive (i.e. proactive) approach involves segmenting the wellbore using sliding sleeves, influx control equipment, limited-perforated liners, while corrective (i.e. reactive) methods attempt to divert/remedy unwanted water influx via water-shut off (WSO) interventions. None of these alternatives can be fully pursued as full-field development strategies without realizing the technical limitations as well as their economic benefits.
The objective of this paper is to determine the value of applying subsurface water control strategies in the context of enhancing reservoir management and develop a novel framework to assess potential remediation opportunities. The technical evaluation was supported by a robust Integrated Reservoir Management (IRM) process. This process identified the rig/rigless jobs opportunities to intervene inactive wells due to high WCT and rank all possible mitigation methods in an automated economic manner.
The findings have also proved the value of installing autonomous inflow control devices (AICDs) to control water production along horizontal sections. In effect, it controlled water slumping without jeopardizing oil production of wells awaiting gas lifting. A case scenario of combined Gas-lift and ICD deployments suggested a net incremental value of $66 million (or 106%). Field test results of the horizontal well's production and WCT were found to be within 10% of the expected planned rates, and the oil gain is expected to further improve by 50% when gas-lift is commenced.
Production Assurance of Oil Field by using Integrated Modeling
Authors: Gouhar Hatem , Zhao Wenyang , Youssef Lina 
Published: November 2019

Abstract
The Production Assurance Tool is developed to calculate the potential oil production from any field for different operational scenarios considering well potential and pipeline network limitations. This Tool represents integration between the pipeline hydraulic model and the performance of the production wells.
The developed tool utilized PIPESIM software to model the pipeline network and Microsoft Excel as database for well performance in the format of lift curve, applying reservoir constraints and best reservoir management practices and as a general user interface for inputs and results. The programming script is performed by visual basic code to link PIPESIM with Microsoft excel to run number of iterations until the net system capacity is concluded. The challenges in each field determine the objective and configuration of the tool.
The tool is being utilized extensively by COMPANY as an efficient, accurate and swift method to support strategic decisions related to net capacity of the field considering reservoir potential and pipeline network limitations. Examples of applications include optimizing plans of new wells, identification of production loss and possible areas for compensation for specific operational scenario.
The tool is totally controlled by the designed general user interface with no physical interaction with the PIPESIM software and it can be easily updated with latest well lift curves and guidelines via COMPANY database, which is regularly updated by subsurface team.
As being an In House Tool, it can be always updated and tweaked as required for different objectives.
The tool provided an efficient methodology to fill the gap between reservoir performance and pipeline hydraulics by using available tools in the COMPANY with no extra investments and reduced the time required to conclude the feasibility and production optimization of different flow assurance scenarios.
A Broadband Full Azimuth Land Seismic Case Study Onshore Abu Dhabi
Authors: Glushchenko Anna , Roig Carlos , Smith Cara , Vasilyev Pavel 
Published: November 2019

Abstract
A state-of-the-art, high-density full azimuth seismic dataset was acquired over a producing field south-west Abu Dhabi to determine optimum high-resolution acquisition and processing parameters. The existing 3D seismic data was acquired in 1994-95 with low fold coverage. The central part of the new seismic volume has good well control to develop, optimize, and QC processing workflows. The new dataset utilised the system with single-sensor geophone accelerometers, point source DX80 vibrators using the Maximum Displacement sweep design with an enhancement of low frequencies as such a broadened amplitude spectrum. The key specifications for seismic acquisition include full azimuth high-density single-source / single-sensor data, long offsets and a broadband vibroseis sweep that retains low frequencies down to 3Hz. The single-sensor single-source technology and the full azimuth dense geometry (5x5m grid) was designed for an optimum subsurface imaging for this survey. The volume was processed through anisotropic prestack time and depth migration followed by poststack wavelet processing and spectral balancing.
How CFD Can Help to Understand Corrosion in Heat Exchanger
Authors: Christian Chauvet , Christophe Meynet , Fariz Maktar 
Published: November 2019

Abstract
Despite the long service life of heat exchanger with minimum maintenance, more and more tube rupture due to corrosion in heat exchangers are observed and become one of the most common cause of failure in any type of production facilities. In the recent cases studied by the Wood CFD team, it appeared that the main reason of the failure came to a bad distribution of the flow either on the shell side or within the tubes entraining an increase of the tube wall temperature.
Computational Fluid Dynamics (CFD) have been used in several occasion in order to determine the detailed flow pattern of the shell fluid especially around the inlet of the heat exchanger in order to identify areas of poor flow distribution. The increase of computing power and the reliability of the modelling approach have allowed to develop more accurate models which can help the engineers to understand the detailed phenomena happening in the heat exchangers.
The regions with recirculation or low velocity identified by the CFD are often matching the region where tube wall thinning due to corrosion are observed. The CFD modelling is not only limited to the shell fluid but can be also coupled with simulation of the tube fluid and conjugate heat transfer within the tube walls. The CFD simulation of the complete vessel allows the corrosion engineer to fully understand the mechanism at the origin of the failure. Through several examples, the author will demonstrate how CFD simulations have been used to understand the root causes of the failure and help the corrosion engineer and the heat exchanger designer to improve the performance and prevent failures.
The approach used has proven to be very effective to identify root cause of heat exchanger failure and is now proposed at a standard practice when such incident happens