bluuebunny/crossref_metadata_2025_split huggingface dataset:
Automated Identification of Optimal Deviated and Horizontal Well Targets
Authors: Castiñeira David , Toronyi Robert , Saleri Nansen 
Published: October 2018

Abstract
Horizontal or deviated wells provide a great way to maximize contact with the reservoir target of interest, reduce water and coning issues, allow for a larger drainage pattern, and as a result increase overall recovery. Placement of these wells has historically relied on history-matched simulation models, which require a multi-disciplinary team of people working over an extensive period of time. Moreover, in situations where static and dynamic reservoir models are unavailable, or are out of date, this approach can lead to inconclusive results in addition to being both cost and time prohibitive. In the present work, a new technology is developed to automate and streamline the process of optimal horizontal or deviated target identification in any type of reservoir and depositional environment. This technology relies on automated geologic and engineering workflows to map remaining oil and identify areas with high probability of success, advanced computational algorithms to perform an optimized global search with 3D pay tracking, statistical and machine learning techniques to assess neighborhood performance and geologic risk, and physics-based analytical and parametric models to forecast production. The algorithm can be fed multiple types of constrains including configuration constrains like length range, azimuth range, and deviation range as well as path constrains like zone-crossing, baffle-crossing, and fault surface crossing. An optimization engine allows the identification of targets that maximize a probability of success attribute, designed to reflect trends in key attributes known to influence production performance such as hydrocarbon pore volume, permeability, fracture intensity, baffle layers, spacing constrains, drainage maps, trends in WCT and GOR, fluid contacts, and so on. The identified targets are then further optimized using an interference analysis that selects the best set of non-interfering targets to maximize production. This framework has been successfully applied to several giant mature assets in the Middle East, North America and South America (with massive datasets and complexity), and in situations where static and dynamic reservoir models are unavailable, partially available, or are very out of date. In all these studies, hundreds of deviated or horizontal opportunities are initially identified. We then discuss key elements to consider during vetting to make sure the final set of identified opportunities are geologically sound, meet various validation criteria, and are feasible given the operational constrains.
Application of Jet Pumping Technology for Offloading a Killed Well in a Gas Condensate Field – A Case Study
Authors: Kalwar Shuaib Ahmed , Awan Abdul Quddos , Ahmad Hafiz Junaid , Khan Zubair 
Published: October 2018

Abstract
This paper describes a trial jet pump application for offloading a killed well. The Well-2A was naturally producing an average 1650 BCPD and 1.54 MMSCFD from two separate formations via dual strings of size 2-3/in. in a 7 in. casing. It later required a workover job because of tubing string and packer leakage. The well was recompleted with a single string of 3-1/2 in. tubing in order to produce both formations together. The well was killed and initially kicked-off by injecting nitrogen, but it was unable to flow even after continuous pumping of 4,000 gallons of nitrogen. Therefore, jet pumping technology was applied to offload the well.
A jet pump was run in the well on tubing, which was equipped with a bottomhole assembly (BHA) for a downhole jet pump. It was installed in a free-style after opening the swab and master valve of the Christmas tree. Once, the jet pump properly seated in the BHA housing, high pressure power fluid was pumped into the wellbore to lift the kill fluid.
Production results indicate that the killed well was successfully offloaded with cumulative production of 690 BPD, which was higher than the targeted production rates evaluated for this well. Freestyle jet pump deployment has achieved the expected performance and reliability. Moreover, the jet pump can easily be re-optimized by reversing it out to change the nozzle and/or throat without requiring a slick-line job. Hence, the jet pump was found to be the most economical artificial lift method and the trial achieved more than expected results.
Saving Rig Time on Exploration and Development in Deep Gas Wells with an Innovative Approach to Test and Prepare Liners Prior to Completion
Authors: Obari Wahid , Hegazy Mohamed , Ali Hasan , Markabi Mazen , AlAwfi Mohammed R. , Nafi Mohamed Khalil , Al-Fakih Abdulqawi 
Published: October 2018

Abstract
When deep gas drilling in the Middle East, the well completion operation is considered one of the most critical phases of the well construction process. This is due to the series of runs required in order to prepare the well for the lower and upper completions while ensuring well integrity and well barriers. The well completion preparation and complex cleaning requirements are time consuming, representing up to 16% of the total well time. This typically requires multiple clean-up runs after cementing the lower completion (production liner) and before running the upper completion. These additional trips not only consume rig time, but expose the operation to health, safety, and environment (HSE) and non-productive time (NPT) related problems.
Conventional operations, in some cases, may require up to six separate trips to set completions in the well. These extra trips can be reduced by combining different technologies based on specific completion applications to execute the necessary tasks while eliminating unnecessary working time from the drilling operations and the associated cost to a well.
Addressing the challenges associated with the wells in the Middle East required the development of a series of tools and procedures to optimize the operation by completing the required tasks in a single combined cleanout BHA. This paper will provide details about how the operation was successfully performed and can be recreated for other wells experiencing the same challenges.
This paper includes the procedures and the description of tools used to combine multiple runs into one single clean out BHA, which saved 3 to 5 days of rig time per well. In addition, it will review the challenges faced in developing and executing this novel approach to prepare the wellbore for the upper completion and the possible total savings.
Use of NMR and core flow to study the solid invasion in sedimentary rocks – Insights on drilling mud design
Authors: Kesserwan Hasan , Al Tawat Najeeb , Jin Guodong 
Published: October 2018

Abstract
The invasion of solids in the drilling mud into the pay zones have significant consequences on reservoir evaluation and production, hence composing a substantial challenge for the mud design. In principle, the mud contains solid particles denoted as bridging materials that are utilized to build up a mudcake at the wellbore to minimize the invasion of solids into the formation. The failure to build up proper mudcake might drive serious formation damage i.e. serious porosity and permeability reduction that are not reversible.
The purpose of this work is to characterize the effect of the particle size of the bridging materials on the integrity of the mudcake and its influences on filtrates invasion. An integrated approach is introduced combing formation damage experiments at reservoir conditions and Nuclear Magnetic Resonance relaxometry (NMR) to monitor any change in the formation properties. The mud flow experiments were performed on two sandstone and one carbonate rocks with two drilling muds in which the size of the carbonate particles was varied, however all the other mud properties were kept fixed. The barite particles are utilized to simulate the solids invasion. The obtained results showed that the growth of the mudcake is independent of the mineralogy of the rock, though, its porosity and permeability are key elements in determining the proper sizes of the bridging materials.
Pore Pressure Prediction While Drilling Using Fuzzy Logic
Authors: Abdulmalek Ahmed S , Elkatatny Salaheldin , Abdulraheem Abdulazeez , Mahmoud Mohammed , Abdulwahab Z. Ali , Mohamed I. M. 
Published: October 2018

Abstract
Formation pressure is the main function that affects drilling operation economically and efficiently. Knowing the pore pressure and the parameters that affect it will help to reduce the cost of the drilling process. Many empirical models reported in the literature were used to calculate the formation pressure based on different parameters. Some of these models used only drilling parameters to estimate pore pressure. Other models predicted the formation pressure based on log data. All of these models required different trends such as normal or abnormal to predict the pore pressure. Few researchers applied artificial intelligence (AI) techniques to predict the formation pressure by only one method or a maximum of two methods of AI.
The objective of this research is to predict the pore pressure based on both drilling parameters and log data namely; weight on bit (WOB), rotary speed (RPM), rate of penetration (ROP), mud weight (MW), bulk density (RHOB), porosity (ϕ) and compressional time (Δt). A real field data is used to predict the formation pressure using Fuzzy Logic (FL) which is one technique of AI.
Fuzzy Logic (FL) tool was compared with different empirical models. FL method estimated the formation pressure with a high accuracy (high correlation coefficient (R) of 0.998 and low average absolute percentage error (AAPE) of 0.234%). FL outperformed all previously published models. The advantage of the new technique is its simplicity, which represented from its estimation of pore pressure without the need of different trends as compared to other models which require a two different trend (normal or abnormal pressure).
Utilizing State of the Art Computational Intelligence to Estimate Oil Flow Rate in Artificial Lift Wells
Authors: Khan Mohammad Rasheed , Tariq Zeeshan , Abdulraheem Abdulazeez 
Published: October 2018

Abstract
Production rate is the single most important parameter that indicates performance of wells to subsurface/reservoir engineers so that they can efficiently monitor as well as optimize the behavior of the system (well and reservoir). Ironically, production rate in individual wells is not monitored usually in real-time, and wherever they are, flow transmitters are employed which carry their own inherent errors when multiphase flow occurs. Therefore, as an industry practice, daily conditions and well tests data is utilized to determine flow rates using developed correlations like Gilbert's. Nevertheless, the effectiveness of such correlations has been reduced due to lack of frequent production well tests and operational technical and cost issues.
For this reason, a model that can predict fluid rates, gives great advantage to the production engineers towards optimizing the well performance in real time. Accordingly, this paper focusses on adapting computational intelligence algorithms, to predict oil flow rate in artificial lift oil wells, which is robust, simple and can be applied universally. This study utilizes multiple computational intelligence (CI) techniques, which have not been utilized previously for this topic, namely; Artificial Neuro Fuzzy Inference Systems, Support Vector Machines alongwith Artificial Neural Network.
Separator production test data were acquired from a South Asian oil field operating on gas lift; followed by data cleaning and data type reduction to prepare the data for input to computational intelligence system. Consequently, only the readily available well head parameters were finalized to be used as the inputs. The output/target data was the separator measured oil rate. All the techniques are compared rigorously with each other and with currently used empirical models based on average absolute error and coefficient of determination. The analysis of the outcome of this work shows that the new model predicts oil flow rate with an accuracy of 98%, interestingly, example of such accuracy is not found in the current literature.
The results of this study show that the ANN outperforms all the current empirical correlations. This effort puts forth an industrial insight into the role of data-driven computational models for the production reconnaissance scheme, not only to validate the well tests but also as an effective tool to reduce qualms in production provisions.
Distributed Fiber Optic Sensing – A Technology Review for Upstream Oil and Gas Applications
Authors: Hveding Frode , Bukhamsin Ahmed 
Published: October 2018

Abstract
Real-time downhole measurement is essential for monitoring and optimizing well performance. For advanced wells, this enables zonal flow evaluation which leads to production control adjustments and ultimately closed loop optimization. The challenge is to turn these real-time measurements into real-time decisions for effective reservoir and production management. Optical fibers provides a great opportunity to achieve this in an economic and safe manner. This is because fiber optics is a non-intrusive tool that has the ability to detect acoustic and thermal effects anywhere along the well with very high frequency sampling both in terms of space and time.
The paper will establish the basic understanding of distributed measurement principles. Then, it will cover the different installation methods based on the parameter of interest. The fiber deployment can occur during initial well construction, or after completing the well as an intervention. The remainder of the paper focuses on different possible application of Distributed Acoustic and Temperature Sensing (DAS and DTS) that strive to solve day-to-day oil field challenges. The task of using real-time fiber optics measurements to monitor well performance is very complex and requires involvement from several disciplines within an organization. To illustrate the complexity of this task, we discuss the application of using distributed measurements for production and injection profiling as an example. An overview of algorithms commonly used to interpret flow from DAS and DTS measurements is presented. Furthermore, the use of DAS and DTS for sand detection and wellbore integrity applications is explained. Each application is supported with examples with the aim to provide reservoir and production engineers guidance to identify appropriate solutions for their challenges.
Expandable Liner System Provides Option for Repairing Corroded, Small-Diameter Casing
Authors: Benzie Scott , Huey Taylor , Cooper Charlie , Bufkin Christopher 
Published: October 2018

Abstract
Long, expandable liners offer practical solution for restoring well integrity in small-diameter wells with severe corrosion problems. Previous options for repairing these wells required running a tubing string to the producing interval, with a restrictive ID that limited production rates. New expandable liner technology, which has been proven in relining horizontal well sections exceeding 4500 ft, can be installed over the full length of vertical wells with small-diameter casing, sealing damaged areas with minimal ID reduction. The system includes packers and nipples that enable completion without a tubing string. In addition to extensive experience in North America, the system has been used successfully in Saudi Arabia to install a 315-ft casing patch to seal a corroded section in a demonstration well.
Many producing oil and gas wells in Saudi Arabia and throughout the Middle East were completed with cost-effective 4.5 in or 5.5 in production casing. Due to the casing's small diameter, options to repair corrosion or other integrity issues are limited. Running a production tubing string with completion packers can be costly, and the restricted ID can limit production rates. Expandable liner technology, originally developed to install casing patches of a few hundred feet, has been enhanced to enable installation of continuous expanded liners that can extend beyond 5,000 ft.
The liners are comprised of high-performing expandable alloy rated for high-H2S service and incorporate expandable threaded connectors. The liner is run to the desired depth and is expanded from the bottom using a downhole hydraulic jacking system to initiate the expansion and the rig's draw works to finish it. In typical 4.5-in casing, the resulting internal diameter is 3.4 in. The liner system includes metal-to-metal seals at top and bottom and can be fitted with production packers and nipples for gas lift valves, as required.
The expandable liner system has successfully addressed integrity problems on more than 100 wells. Recent applications in horizontal wells demonstrated the efficient installation and consistent expansion of the liner. Horizontal liners in excess of 4000 ft were expanded in an average of 29 hours and maintained integrity during hydraulic fracturing. The system also was used in Saudi Arabia to repair a corroded 300-ft section of 4.5-in casing in a producing well, with good results.
Knowledge Transformation to Develop Young Local Talent to be a Professional Workforce
Authors: Nugraha Budhi , AlKhaldi Latifah Kulaib , Al Ali Wassan Adel , Kashif Muhammad 
Published: October 2018

Abstract
A strategy to develop an efficient and effective workforce is to discover and attract the best candidates from our host countries and provide them with the best method of knowledge transfer and more opportunities to be nurtured to be a part of the business growth in the current and prospective future of the company. Various methods of training have been introduced and conducted with different approaches, however not many of these techniques are successful in grooming the young talent to be a potential next generation of the global industry.
The successful key of any training method is not only decided by the content of the training material, but there are some other factors that lead to the successful transfer of knowledge. The trainer can be a mentor and role model and a person that can motivate themselves and the trainee. This trainer should create a good ambience while transferring the knowledge so this process can be more effective, efficient and fun. Several other processes for transferring knowledge include: Self-Understanding – Delivery – the combination of visual, vocal and verbal. The delivering of information is not just about the content of what we say, but it is also related to how we say it, and the way we look when we say it. Vocal tone and body language of the non-verbal aspects influence the actual verbal message. This process also persuades the audience to follow a direction without denial. This can be done by creating a condition where the audience follows the direction because they are tempted with the effect offered in the statement. The strength of charisma from the trainer can also impact the success of this method.
To provide opportunity and development of young local talent, some companies have been adopting a strategy of knowledge transformation method. The recruitment process is done by using a variety of tools/methods and other tests to assess the skills and the candidates' competencies. Then the usage of both formal and informal combination training is done to progress careers and employee excellence. This execution showed an overall increase in the knowledge transfer. The backing of this method has helped them to quickly contribute to their departments or organizations by handling their regular duties in a shorter period of time.
Motivation is needed to attract the energy of young people so that the delivery of information can be done effectively and efficiently. When the process is well underway, the next thing is how the knowledge gained can be used in their professional lives so that it can be useful in developing their ability to be a more professional and dynamic workforce.
Carbonate Rock Resistivity Index Measurement Using Equivalent Rock Model
Authors: Tariq Zeeshan , Mahmoud Mohamed , Hassan Amjed , Khan Mohammad Rasheed , Sadeed Ahmed 
Published: October 2018

Abstract
The applicability of Archie's relation depends on the link between pore structure and resistivity of the rock, and because of this relationship, the rock maybe classified as Non-Archie. Keeping this factor in view, for carbonates, the intricate pore systems, the application of Archie's law becomes invalid and any estimate of water saturation using Archie's equation will most likely yield erroneous results. Many scholars and researchers have attempted to come up with models linking well logs and laboratory data to estimate water saturation in complex pore systems. To appropriately capture the conduction behavior of a rock is aimed at and the conduction mechanism is then related to not only the pore geometry but also other petrophysical factors including wettability and the existence of conductive exterior minerals. For complex lithologies, resistivity index curves cannot be accurately defined by Archie's law, and investigations at lower water saturation values are required to describe the non-Archie behavior.
The shape of the RI curves varies quite considerably and an attempt to describe the variation qualitatively as well as quantitatively requires the use of either dual or triple conductivity models. In these models, the pore systems are linked with each other electrically in series or parallel, in addition, a combination of the two is also possible. This enables the use of simply two of the three adjustable parameters to adequately model the experimental outcomes.
This study, presents a saturation model for dual porosity systems. Having NMR data will enable the use of this model to determine water saturation by utilizing the volume fraction of each contributing pore system (Macro and Micro) derived from NMR logs. Furthermore, this work also examined the effects of various influences on the electrical constraints which included cementation factor, the shape factor for the lithology and saturation exponent.
Successful Logging Operations through Y-Tool; Challenges and Lessons Learned On Restricted Completions
Authors: Al Zahrani Ahmed R. , Kalu-Ulu Torty C. , Al Nasser Ahmed N. , Al Yami Salem F. 
Published: October 2018

Abstract
Artificial lift utilizing Electrical Submersible Pump (ESP) supporting operations have evolved from pump installations with no access to the completion zone to the point where rigless logging intervention operations can access the lower wellbore using either coiled tubing or wireline. Access to the completion zone has been accomplished through the installation of Y-Tool and a by-pass leg in conjunction with the ESP.
The major challenge is to have the Coil Tubing (CT) plug seal assembly located on the coil otherwise a damage to the seal assembly is expected and consequently a fluid circulation might take place. CT conveyed production logging requires a CT plug to prevent production circulation across by-pass section while operating the ESP. The circulation is prevented by the seal assembly which exists in the CT plug and located on the coil tube. The Bottom Hole Assembly (BHA) consist of CT plug which included connector, sleeve and bottom crossover, all covered by the CT plug external body which has the seal assembly in addition to the Production Logging Tool (PLT). Changes in tools design and profiles allowed for a successful logging intervention into these Y-tool equipped wells while gathering required well logging data.
The paper presents technical and logistic challenges during rig-less logging operations on wells with a Y-tool and a by-pass leg with complicated downhole configuration including small restriction and dual pump layouts. Examples of both impaired and successful operations will be reviewed with challenges and lessons learned, including the changes made to allow the tools for logging activities. This paper will provide a path forward to well access and surveillance while ensuring adequate isolation during logging operation.