bluuebunny/crossref_metadata_2025_split huggingface dataset:
Well Depth Monitor Software Design Based On Laser Distance Measuring Device
Authors: Han Haochen , Hu Yongjian , Zhang Yong , Sun Qi , Sun Chengqin , Fang Zhimeng , Chen Haoweu 
Published: November 2020

Abstract
Well depth is one of the most valuable parameters in drilling engineering. Commonly well depth is calculated by the absolute difference in height based on the revolution of drawwork sensor, which is a pulse encoder or incremental optical encoder. Both encoders have complicated calibration process, and the measurement is easily disturbed.
Different from the traditional indirect measurement from the drawwork sensor, the direct measurement provided by laser distance device can simplify the process and decrease the systemic error. The principle of the measurement is to calculate the distance by the product of the atmospheric refraction coefficient and the speed of light. In our design, we fixed the laser distance device on the hook and placed the reflector under the crown to measure the height variant. Modern industrial laser distance device with high accuracy can finish multiple measurements per unit time and calculate the average to reduce the measurement error effectively.
The well depth measurement system software based on laser distance measuring device can shorten and simplify the calibration process or even realize automatic calibration. The laser distance measuring device can be used effectively in the severe weather, such as strong winds, and minimize the error caused by manual operation. We completed the optimization of laser distance sensor and selected Sick DL 100 as the main laser sensor, as well as a laser measurement prototype in lab. After thousands of trials and errors, it turns out to be applicable. In order to be compatible with the new well depth measurement system, we developed a corresponding software by .Net Framework and WPF. With the help of .Net framework and WPF, UI and core codes of the software are separated in physical isolation, which can improve the development efficiency and make preparation for further extension and optimization. The software supports portal communication and ethernet, which can connect with the laser distance device conveniently.
By the well depth measurement system software based on laser distance measuring device, we simplified the well depth measurement calibration, reduced the system error and improved the accuracy of measurement. The application of this system contributes to the drilling operation and shortens the drilling period.
Research on Tubing and Casing Anti-Bending Technology for Salt Cavern Gas Storage Cavity Construction
Authors: Cen Xueqi , Zeng Hao , Wang Haibo , Huang Xiao , Zhang Rusheng , Wang Lei , Gao Shengen , Liu Fang , Huang Qingfeng , Wu Junwen , Zhang Le 
Published: November 2020

Abstract
Benefiting from its outstanding gas injection-production capability and fully recoverable cushion gas, salt cavern gas storage technology was developed rapidly in recent years. Wangchang salt cave gas storage is characterized by deep burial depth and multiple interlayers. The project of water-soluble cavity construction faces problem of serious tubing and casing bending and deformation. Therefore, development of effective tubing and casing string damage-prevention and risk control method remains an ongoing challenge.
Both theoretical study and field tests are presented in this article. Through field observation, mechanical analysis and production data analysis, it was identified that the main reasons causing tubing and casing bending are liquid-solid coupling instability, interlayer rock impact and smashing, as well as pipe string wear and corrosion. By optimizing the tubing and casing strings design and adjusting production parameters, tubing and casing bending problem could be effectively improved. Besides, remedial measures to deal with bending pipe string were proposed.
Critical destabilizing flow rate of the tubing and casing was calculated under different diameter and wall thickness conditions. Analysis of calculation results showed that the current water injection volume of the Wangchang gas storage well was higher than the critical displacement. It was verified that the liquid-solid coupling instability was the main reason causing tubing and casing bending in the gas storage well. Field data analysis showed that large water injection displacement and high water injection pressure fluctuation was more likely to cause bending and damage of tubing and casing. Technical measures are listed as following: (1) strengthening the steel grade wall thickness of intermediate casing; (2) equipping the central tubing column with a drop connector to optimize the distance between the central tubing shoe and the middle casing shoe; (3) Optimizing the cavity water circulation method to stabilize the water injection pressure and displacement.
The anti-bending technology presented in this study unlocks a critical bottleneck during the salt cave building progress, which is the tubing and casing bending and deformation problem. With the application of this method, efficiency of water-soluble cavity building can be greatly improved. More importantly, this technology might pave a new way for the deep multi-interlayer salt cavern gas storage design.
Virtual Reality Simulators in the Oil & Gas Industry Review of Existing Solutions and Method for Evaluation
Authors: Qrain Afra Al , Reddy Ganga , Jadhav Satyaprasad 
Published: November 2020

Abstract
Plant operators and maintenance personnel form majority of the workforce in ADNOC Gas Processing. Ensuring their safety and competency is crucial. Over the past few years, ADNOC Gas Processing (company) has observed that a great deal of resources are spent annually on conventional training methods that are inefficient in terms of time, cost, and knowledge retention. With the advent of many technologies, Virtual Reality is found to be gaining ground; however, there are no clear guidelines on how to properly assess and select a one-stop VR solution that is sustainable and fit for the future.
This paper presents a review of VR solutions in the oil and gas industry through the development of multiple prototypes (proof of concepts) in collaboration with many solution providers. The objective was to: 1) Establish a learning experience and knowledge about VR main features, hardware, software and applications, 2) Evaluate the capabilities of various VR solutions in the context of field operator and maintenance training, 3) and develop guidelines or minimum functional design requirements for implementing VR.
Although all VR solutions shared similarities, there were some key differentiators that are considered success factor when selecting a one-stop VR solution. Examples of such factors include the ability to seamlessly convert CAD format to VR environment with high graphic and visual effects. VR should also allow the interactivity of 3D objects to its finest details, and render spatial sounds. Moreover, it should have inbuilt or integrated learning management system to record competency assessments of the trainees, and so many more as explained throughout this paper.
VR Field simulator is used in many applications and accrues several benefits such as reducing raining cost, improving people's competency, increasing efficiency as projects investment is recovered quickly, improving HSE as all types trainings can be delivered off-site, enhancing performance since it allows accurate off-site planning, and validates ergonomic design before commissioning
Leverage Energy Optimization to Reduce Carbon Capture Cost
Authors: Sajjad Saqib 
Published: November 2020

Abstract
The cost of carbon capture is the major impediment in its mainstream acceptance, but its ability to abate the carbon emissions at a considerable scale, makes it a technology with promising potential. The paper presents detailed account of the energy optimization meticulous review carried out for a brownfield project to capture carbon from the Sulphur Recovery Unit (SRU) Tail Gas. The paper demonstrates the vital role of energy optimization in restraining the carbon capture cost.
The methodology comprised development of an overall integrated heat & power model of the process encompassing energy supply sources, including power generation and import, and major energy consumers like CO2 absorption solvent regenerator, CO2 compressor and dense phase CO2 pump etc. The optimization was achieved by setting the objective function to minimize energy cost in terms of steam & power demand, by relating the selection of major drivers i.e. electric motor or steam turbine, as well as solvent, with the total energy cost in conjunction with the associated CAPEX. It followed with a meticulous review of individual systems and components.
Comprehensive energy optimization exercise, equating energy supply, major drivers’ selection and process decisions with the total energy cost and the associated CAPEX minimization, facilitated in carbon capture cost reduction by more than 10%. The optimized scheme helped in maximizing the utilization of available waste heat as well as in minimizing the spare steam dumping in condensers. The exercise confirmed the absolute significance of the energy optimization measures in reducing the cost of carbon capture.
Determining Initial Hydrocarbon Saturation Under Petrophysical Uncertainty Applying Machine Learning
Authors: Neff Pascale , Steineder Dominik , Stummer Barbara , Clemens Torsten 
Published: November 2020

Abstract
The initial hydrocarbon saturation has a major impact on field development planning and resource estimation. However, it is derived from indirect measurements from spatially distributed wells applying saturation height modelling based on uncertain parameters. The methodology presented here is deriving posterior parameter distributions by using Machine Learning in a Bayesian Framework honouring the petrophysical uncertainty in the field. The results are used for initialization and will be applied for forecasting under uncertainty.
To determine the initial hydrocarbon saturation, the Saturation Height Model (SHM) needs to be conditioned to the interpreted logs. 2500 geological realizations were generated to cover the interpreted ranges of porosity, permeability and saturations for 15 wells. For the SHM, twelve parameters and their ranges were introduced. Latin Hypercube Sampling was utilized to generate a training set for Machine Learning models (ML). The trained ML models were conditioned to the log derived saturation data. To ensure a field wide consistency of the models only parameter combinations honouring the interpreted saturation range for all wells were selected.
The presented method allows for consistent initialization and for rejection of parameters that do not fit to observed data. In our case study, the most significant observation concerns the posterior parameter distribution of the Free Water Level range which is narrowed down. Furthermore, the SHM parameters are proven independent; thus the resulting posterior parameter ranges for the SHM can be used for conditioning production data to models and subsequent hydrocarbon production forecasting. Additional observations can be made from the ML results such as the correlation between wells, this allows interpreting groups of wells that have a similar behaviour, favour the same combinations and potentially belong to the same compartment.
A workflow is introduced honouring the interpreted error of log derived porosity-permeability and saturation data. The workflow is based on Saturation Height Modelling (SHM) to generate a training set for Machine Learning. The SHM is conditioned to all wells in a Bayesian Framework to ensure that the posterior parameter distributions of the SHM are consistent and can be used for conditioning dynamic models to dynamic data and production forecasting.
Efficient Utilization of N2 During Commissioning and Startup
Authors: Al Jarwan Abdulla , Bin Kuwair Majid , Mokhbat El-Hachemi , Al Ali Hassan , Al Khanbooli Mohamed , Al Shamsi Mohammad , Kobbia Ibrahim , Al Wahedi Faisal 
Published: November 2020

Efficient Utilization of N2 during Commissioning and Startup
In one of ADNOC's mega projects, Nitrogen was utilized for commissioning as well as start-up purposes, saving time and assessing equipment performance much earlier than planned. This paper which will be sectionalized in two parts, presents an extraordinary approach out of the norms for the usual nitrogen use in upstream oil and gas industries of purging and blanketing, resulting in significant savings in time and expenditure.

Commissioning with N2
There are many arguments about the risk / reward relation when it comes to applying Field test run with an inert gas (N2) ahead of hydrocarbon in, involving high pressure centrifugal compression systems. This part aims to discuss the advantages of adopting N2 testing well ahead of gas-in, challenges and rewards. Although the codes from API and ASME give details on the requirements of running compressors with gases different of design ones. The installation, the procedure, and the acceptance criteria are subject of agreement between vendor and company. Therefore, it's important to detail and agree with the Vendors on all process and mechanical criteria, limitations and necessary precautions ahead of adopting such tests. Additionally In this part, the various requirements to adopt testing high pressure compressor with N2 gas will be presented and along with a discussion on their capabilities to detect a variety of problems. Some issues which occurred during the N2 test run at site will be described.
Based on test characteristics and at the related cases, recommendations are made when ordering new compression system with considerations regarding the return of investment of these tests.

Startup with N2
Nitrogen (N2) was used as a stripping medium during the initial startup of the plant facilities. The target was to start producing stabilized crude simultaneously with the hot commissioning of the gas circuit. This part presents the overall results of adopting this approach. An assessment was carried out utilizing simulation software HYSYS prior to the startup. Post startup, actual field results were collected to analyze the effectiveness of N2 stabilization. N2 was proven to be an effective stripping medium in crude stabilization.
A Flow Network Model Based on Time of Flight for Reservoir Management
Authors: Sankaran Sathish , Sun Wenyue 
Published: November 2020

Abstract
Closed loop reservoir management is challenged with building reliable and fast predictive reservoir models to make field decisions. Traditional numerical simulation models can be difficult to characterize, tedious to build and calibrate, and at times computationally prohibitive for short term decision cycles in field applications. On the other hand, pure data-driven methods often lack physical insights and have limited range of applicability. For operational scenarios such as short-term production forecasting, waterflood optimization, production control and understanding major reservoir mechanisms, it is desirable to use a reservoir modeling methodology that is easy to build, history match, compute and interpret.
In this work, we propose to use a hybrid and efficient reservoir graph network (RGNet) modeling approach based on time of flight concept that can be built using routinely measured field measurements (such as pressure and rates) and can be used for real-time forecasts, scenario modeling, production optimization and control.
We propose a gridding method based on discretized time of flight for multi-well scenario with interference. It simplifies the 3D reservoir flow problem into a graph network representation that can be solved with any commercial reservoir simulator, which enables the RGNet model to be readily applied for various types of fluid physics. The parameters in RGNet model are obtained through assimilating observed data. The RGNet model has a very compact model representation that requires significantly less complexity compared with full-physics 3D models, which leads to very fast simulation. The efficiency of RGNet makes it appealing for applications where many simulation runs are needed.
We applied the proposed approach on SPE benchmark reservoir simulation models for single well, multi-well with interference and injector-producer pairs. The calibrated models are used to quantify uncertainty for production forecasting. In all cases, the range of uncertainty is reduced effectively and efficiently with data assimilation. The posterior RGNet models are also shown to provide reasonable estimates of reservoir and well drainage volumes. By virtue of the reduced complexity, the modeling methodology is highly scalable while still retains physical interpretability (in terms of pore volume and transmissibility). We also discuss the potential applications of the method such as reservoir connectivity analysis and well control optimization.
The proposed reservoir graph network (RGNet) modeling approach provides a unique and sustainable way to combine advanced analytics and physics to develop an explainable dynamic reservoir model that can be effectively used to understand reservoir behavior and optimize performance. The lightweight model lends itself naturally to fast computation that are required for scenario analysis and optimization.
New Generation NMR T1-T2 Logging and Integrated Formation Evaluation in Unconventional Reservoirs in China
Authors: Zhang Hao , WU JIAN FA , WANG YUE , ZHONG GUANG HAI , LIU QUN MING , LIAO MAO JIE , FANG TAO , GAO XIANG , ZHAO XIAN RAN , ZHAO HAI PENG , ZHAO JING KAI , WANG WEI , WEN JUE MEI , XIE TAO 
Published: November 2020

Abstract
The strong domestic need for oil in China requires further exploration in unconventional reservoirs, such as volcanic and shale oil reservoirs. Sweet zone identification is one of the most critical missions in formation evaluation. The complex mineralogy and low porosity in unconventional reservoirs result in little variations of resistivities from oil zones to water zones. The uncertainties in fluid typing lower the efficiency in finding the sweet zone.
In conventional reservoirs, nuclear magnetic resonance (NMR) logging based on cutoff analysis is the optimum choice for evaluating the porosity and pore geometry of hydrocarbon bearing reservoirs. However, the routine one-dimensional T2 measurement may not be sufficient for the formation evaluation in unconventional reservoirs, because of the overlap of signals of various fluids in the T2 space. This paper shows a new generation NMR tool with advanced measurements of continuous two-dimensional T1-T2. The T1-T2 measurements enable quantification of different fluids in the pores. Fluid typing is supported by the integration of other wireline logs, such as nuclear spectroscopy and dielectric dispersion.
Case studies are presented from volcanic and shale oil reservoirs in the Xinjiang Oilfield of PetroChina. In the volcanic reservoir case, a modern methodology based on the concept of 2D analytics for extracting signals from two-dimensional NMR T1-T2 measurements is proposed. An integrated workflow derived from wireline borehole image, spectroscopy, dielectric and NMR T1-T2 gives an insight into the fluid composition in the pore system. Besides accurate measurements of lithology independent porosity and pore geometry from NMR, clay bound water volume and total water volume derived from cluster volumetric analysis of NMR T1-T2 match well with those from spectroscopy and dielectric tools. It lowers the uncertainties of fluid typing in the volcanic reservoir where resistivities fail to differentiate water zones and oil zones. In the shale oil case, the reservoir producibility index (RPI) which takes the oil volume as a positive reservoir quality (RQ) index, and kerogen and bound hydrocarbon as negative RQ indexes is illustrated. It proves to be robust in sweet zone identification.
This paper discusses a novel application of a new generation NMR T1-T2 logging method in unconventional reservoirs, which helps the operator ascertain the potential of the reservoirs. The oil zones identified by the new method have promising oil productions. The workflow can also be applied to other unconventional plays in China.
Successful Water Shutoff Treatment of Fractured Carbonate Horizontal Well Under Aquifer Pressure Support
Authors: Hernando Louis , Martin Nicolas , Zaitoun Alain , Al Mufargi Hilal , Al Harthi Hamood , Al Naabi Ahmed , Al Subhi Khamis , Al Harrasi Mohammed Talib 
Published: November 2020

Abstract
Many horizontal wells in GCC (Gulf Cooperation Council) are producing from fractured carbonate reservoirs under aquifer pressure support. After water breakthrough, these wells suffer from high water cut rise due to water channeling through the fractures, inducing a strong and quick loss of well productivity. The wells being completed horizontal open hole, zonal isolation is very difficult to isolate the water producing zone. Moreover, mechanical water shut off like using liners or open hole packers is normally costly and challenging as well. Therefore, bullheading chemicals is often the only remaining option. The fractures being producing mixture of both oil and water, water shutoff in this type of well is very challenging.
To solve this problem, an original method was used consisting of microgel and gel injections. The strategy is to create a flow barrier deep in the fracture while preserving oil production from the matrix. The optimized procedure enables control of chemical placement by bullhead injection. Laboratory tests were conducted to optimize Microgel and gel chemistry (injectivity, gelation time and gel consistency/stability, return oil permeability).
The treated candidate was 530m long horizontal well and produced at around 600 bpd with water cut of 92%. Temperature and salinity were 62°C and around 100,000ppm respectively. Well behavior indicated existence of fractures along the wellbore.
The treatment consisted of 230m3 of successive Microgel/Gel injection at an average rate of 2.5 BPM. The treatment proceeded bullhead through annulus. WHP remained low throughout injection (150 psi). After curing time of 10 days for gel set, production was released with ramp up rate. The well, which was facing strong production decline, stopped declining, with a water cut drop of around 10%. Incremental daily oil rate was around 50 bopd with cumulative oil for the first 4 months of around 4500 bbls of oil.
This technology may have many applications in fractured carbonate fields and may lead to better oil potential from such high water cut highly fractured reservoir wells, with strong aquifer.
Advances in Clamp-On Flow Measurement Techniques
Authors: Arsalan Muhammad 
Published: November 2020

Abstract
This paper addresses the need and challenges associated with the clamp-on gas and oil flow and water-cut measurement techniques for efficient and reliable flow allocation and production management. This will be useful for production, as well as, reservoir engineering in both traditional and unconventional multiphase flow environments. Furthermore the paper reviews the advancements in the available clamp-on measurement techniques and evaluate their advantages and shortcomings in different flow conditions.