bluuebunny/crossref_metadata_2025_split huggingface dataset:
New Conical Diamond Element Bit Technology Coupled with FEA-Based Modeling for Bit Selection Demonstrates High Durability and Improved ROP in Compact Carbonate Formation in Deep Water
Authors: Muhammad Shafiq Shahrul Amar , Syed Muhamad Siddik , Sylvia Fayez , Ole Gjertsen , Nurul Ain Mohd Yakob 
Published: January 2020

Developing reserves offshore East Malaysia, especially in deep water, often requires the operator to drill -through formations that consists of compact carbonate with high unconfined compressive strength (UCS). Efficiently penetrating these carbonate formations with conventional PDC bits has been challenging; typically, when a bit encounters this formation, a high vibration level is induced that leads to impact cutter damage, forcing a round trip for a new bit and causing nonproductive time (NPT) and additional cost for a new bit. Consequently, the cost impact is more severe to the operator, especially in deep water environments.
Traditionally, an operator has used four- and five-bladed PDC bits to drill this formation because this configuration had set a benchmark in this field compared with roller cone bits. However, a recent engineering analysis on a recently drilled offset well showed that a minimum of two PDC bits are required to reach the section total depth (TD). On the first run, the bit was pulled out of hole (POOH) due to slow ROP 6.2 m/h) and received a poor dull grade (6-7-HC-ROP). Although the second PDC bit produced slightly higher ROP compared with the first bit, it was POOH with broken cutters.
A research initiative was launched to investigate new types of cutting elements. The project was successful and yielded an innovative conical-shaped polycrystalline diamond element (CDE). This element has twice the diamond thickness of conventional PDC cutters, resulting in higher impact strength and more resistance toward abrasive wear by approximately 25%. A new bit type was designed with the CDEs strategically placed across the bit face from gauge to the bit center utilizing FEA-based modeling system. The placement of CDEs is mainly to support and protect the conventional PDC cutters from impact damage and to strengthen the overall cutting structure.
The 8½-in CDE bit was run and drilled the entire 8½-in hole section through the hard carbonate formation to TD at a significantly higher ROP compared with the offset well. Although the CDE bit was POOH due to downhole tool failure and graded 1-2-BT-DTF, the same bit was rerun and successfully completed the hole section in good condition and dull graded as 1-3-BT-TD. Compared with the offset well that required two conventional PDCs to reach TD, the CDE bit delivered more drilled interval at a higher ROP while providing a smooth, high-quality wellbore, enabling casing to be set on the first attempt. Also, the dynamic response predicted by the modeling system matched the bit, BHA, and drill string vibration profile recorded during the actual field run. Improvement in drilling performance for this run has saved the operator 15 hours for the same drilling interval.
An Innovative Solution Enabled a Client to Drill Over 70 Horizontal Wells in a Very High Collision Risk Environment
Authors: Noor Marghub Nabi , Al Muqarshi Moosa Masoud , Ovezov Murad , Delavari Kamran , Heidari Mohammad Reza 
Published: January 2020

A client in South Oman was struggling to place additional wells to maintain the production levels in a Semi Steam Assisted Gravity Drainage (SAGD) project due to very high collision risks. Real Time High-Definition Surveys (HDS) application was used in conjunction with In-Field Referencing (IFR) to reduce the size of Ellipse of Uncertainties (EOU) and increasing the Separation Factor (SF) while drilling.
In a SAGD project, the placement of well either Horizontal Producer (HP) or Horizontal Injector (HI) is very critical and any deviation can cost dearly in terms of production rate. A post run survey enhancement will most likely is not going to produce the desired results and can lead to costly plug well situation. A special real time survey enhancement procedure with the help of an exclusive application was used to increase the survey density. This application provided high density industry standard MWD surveys, by using advanced algorithms with continuous azimuth & inclination data from MWD tool.
This combination benefited the client in multiple ways and most significantly, additional 70 horizontal producer & injector wells are drilled in last 4 years, which otherwise were not possible to drill. These additional wells resulted in over five million barrels of produced oil per year for the client, which translates into 204 million USD annual revenue. Additionally, it helped achieve the objective of placing the well at optimum spot to minimize the water break through and reduce the produce water. Also, the reduction in tortuosity by removing additional turns for collision avoidance resulted in longer well life and better production rates. In addition to that, managed to plan another 50 well trajectories with the help of this new technique to be drilled in near future. The well drilled with this approach has up to 30% smaller EOU size and will help the project in future with more room to place additional wells.
This survey enhancement application can benefit similar projects worldwide in a variety of ways. On one hand this will help operators to optimize the production by drilling additional wells in very congested areas, and on the other hand this will also help the Sub-Surface Team (SST) to calibrate their existing geological model with more accurate reservoir boundaries.
Evaluation of Lateral BHA Twist-Off Incidents and the Effect of a Redesigned Thread Connection on Reducing Twist-Off Risk in the Permian Basin, USA
Authors: Chen Zhenyu , Simon Aaron , Shen Yuelin , Chen Wei , Zhang Zhengxin , Shahid Tanveer , Liu Guoyu 
Published: January 2020

A common issue encountered when drilling in the Permian Basin involves the twist-off of a bottomhole assembly (BHA) component. A twist-off incident can result in significant costs incurred due to nonproductive time (NPT) as well as lost-in-hole (LIH) charges if retrieval of the fish is unsuccessful. The paper will present several case studies to illustrate the primary cause of the failures. An innovative thread connection for BHA components was designed in 2016 to reduce risk of twist-off. The paper will demonstrate its effect on reducing twist-off risk as well as the enablement of improved drilling performance in 2019.
The paper will illustrate statistical analysis of data gathered from 2016 through 2019 comparing the performance of the conventional thread connection versus the new thread design. The goal of the analysis is to evaluate whether the thread design is effective in reducing the frequency of twist-off incidents. The bending moment of each connection within the BHA will be analyzed using modeling software to understand the stress-loading profile. Memory data from the rotary steerable system (RSS), including near-bit attitude measurements and downhole drilling dynamics, will be analyzed in conjunction with data acquired from the rig's surface sensors to identify if any abnormal drilling events are observed prior to the twist off.
The BHA bending moment study concludes that connections between the measurements-while-drilling (MWD) tool and the RSS suffer higher stress loading compared to other connections in the BHA. Empirically, field statistics confirm that the connections between RSS and MWD exhibit the highest frequency of twist-off incidents. However, further analysis is required to understand the root cause of the connection failure. The memory data retrieved from the RSS enables the visualization of hole curvature and vibration at the time of the incident. Investigation into several field cases concluded that, immediately prior to connection twist off, there is sudden change in borehole curvature and/or emergence of shock and vibration (S&V) which can dramatically reduce the expected fatigue life of the connection. Based on the statistical analysis, it can be concluded that the new connection design is effective in reducing the twist-off failure rate of the BHA. Consequently, the implementation of the new thread design enabled a step-change in drilling performance through use of a more powerful positive displacement motor (PDM) to drive the RSS system.
Energy Query Language - An Oil and Gas Domain Query Language for Big Data Analytics in Real-Time Data Streaming
Authors: Djamaluddin Basirudin , Philip Shan , Alrebh Abdullah , Iqbal Arif 
Published: January 2020

Within the Oil and Gas industry, real-time data streaming is essential to conduct high-impact analytics. The Energistics Transfer Protocol (ETP) enables data to be streamed with low latency. The current mechanism of querying the data transferred through ETP is cumbersome, especially for the domain user who wants to realize the full benefits of this protocol.
Energy Query Language (EQL) is a domain-specific language (DSL) for querying data which is streamed through ETP with a concise SQL-like structure in real-time. The EQL System (EQLS) provides the ability to query streaming data in real-time across various platforms and business applications, as well as in web or analytics platforms like Python. The EQL grammar is simple enough to reduce the complexity of the current mechanism used for querying and aggregating real-time data. Built with components that can support advanced analytics requirements including big data analytics, EQLS is future-proof.
Historical Performance Analysis and Upcoming Development of Rotating Control Devices in the Kingdom of Saudi Arabia
Authors: Sehsah Ossama , Iturrios Carlos , Mahmood Azfar , Kadadha Abdallah 
Published: January 2020

Drilling companies are constantly evaluating ways to improve the efficiency and safety of their operations, the way the returns of the well are circulated while drilling has remained unchanged for decades, however, having a circulating system open to the atmosphere imposes a risk to the drilling crew in the rig flow.
Conventional influx detection methods can easily allow the gasification of the mud column in the annulus before it is noticeable and H2S or flammable gas alarm can be triggered before any action is taken.
A rotating control device (RCD) is a piece of equipment that diverts the returns of the well from the rig floor while allowing the drill pipe to be rotated and reciprocated, that means tripping and drilling operations can be performed while the well is isolated from the rig floor by the RCD.
The RCD is a key component in Managed Pressure Drilling (MPD) operations as it is responsible for containing the annular surface pressure and preserving the integrity of the circulation system, hence maintaining a slight overbalance condition on the well, additionally the RCD can be deployed independently for other applications that enhance the safety and optimize the costs of the drilling operation. For this reason, efforts are made to ensure that optimum operating conditions are present to reduce the chances of system failure. Historical data detailing the performance of RCD systems, including total stripped footage, total rotating hours and failure mechanisms were used to evaluate the reliability of this technology and to set operating limits to optimize its performance.
Historically there are conditions that are known to reduce the life span of RCD bearing assemblies, such as misalignment of the Blowout Preventer (BOP) stack, hard banding or bad condition of drill pipe tool joints, excessive drill pipe vibration, temperature and type of fluid out of the well, among others. Ensuring that the operating limits are observed regarding rotating speed, pressure and temperature were observed to be key to maximizing the life cycle. It was observed that the base technology over which RCDs are designed is far from recent and new additions to the current setup are needed to "smarten up" an otherwise very basic piece of equipment, this with the intention of obtain better data regarding its operating conditions and the parameters that affect its performance. New technologies in terms of elastomer compounds, seal design improvements, monitoring systems and implementation of artificial intelligence are some of the upcoming developments discussed in this document and that are to be implemented in the short and medium term in RCD operations in Kingdom of Saudi Arabia.
Characterizing Water Breakthrough Using Analytical Diagnostic Workflow
Authors: Dokhon Waleed , Alkayadi Fatimah , Dallag Mohammed 
Published: January 2020

Water management has always been a challenge especially in mature fields. Consequently, mechanical, chemical shutoff and other water reduction techniques have been developed and deployed to curb the menace in the hydrocarbon industry. However, poor diagnostic work can be a leading reason for the low success rate for any water control method. This paper introduces a holistic workflow to understand the candidate selection, filter the wells based on priority and determine the water breakthrough mechanism to eventually select the optimal remedial action.
In this paper, 7 wells are selected and prioritized to undergo a workflow to diagnose water breakthrough and characterize it. The first analytical tool is Chan correlation, which incorporates the water-oil ratio for determining the water signature. For determining the water entry zone, Production Logging Tool (PLT) will be used as the second investigative tool. Water source identification plays another major role in assessing whether the water is coming from an aquifer, nearby injector or native reservoir fluid, which can be determined by the frequent sample collection and lab analysis for ionic concentration. These three investigative tools will provide a basis to select the proper water management strategy.
The results of the diagnosis have revealed several facts regarding the aforementioned parameters. A number of the diagnosed wells have shown a steep increase in oil-water ratio and oil-water ratio derivative, which hints to a possible nearby thief zone according to Chan correlation. Reviewing the produced water ionic concentration suggests low salinity and that the water's chemistry is closer to that of an injected water than reservoir water. Finally, Production Logging Tool showed multiple water entries in the open hole section. According to the diagnosis, Inflow Control Device deployment for those wells are recommended. Couple of multilateral wells completed with Inflow Control Valves (ICV) showed rapid channeling of water, which can be caused by a thief zone or a lateral dominating the flow and contributing high water cuts. These wells were subjected to ICV optimization and it confirmed that a latera was dominating the flow with high water cut and was optimized. The water cut for those two wells dropped by 58%.
The workflow enables engineers to understand the water breakthrough mechanism in a timely-matter, which allows them to categorize the wells based on the different water signatures such as water coning, thief zone, and near wellbore breakthrough. The proposed workflow can be adopted and adjusted based on the water management problems associated to any field in order to find the optimal remedial action. This outcome played a role in the planning of placing and drilling new wells in the field.
Synthetic Time-Lapse Production Surveillance: Automated Workflow Technology to Monitor Oilfields Continuously and on Demand
Authors: Dallag Mohammed , Bawazir Mustafa , Shukla Sourabh 
Published: January 2020

One goal for oil fields of the future is acquiring continuous and on-demand data as required for field and reservoir management. Synthetic time-lapse production methods are becoming a way of providing this information at and away from wells. Time-lapse production log data acquired over oil fields is used to monitor water sweep in the reservoir. Production logs provide a direct measure of the fluid flowing downhole and detect the unwanted fluid entries. In field applications, this advanced scanning of fluid profiling successfully derisked several infill well locations and identified new workover candidates and drilling opportunities in the fields.
Synthetic time-lapse production logging is a useful complement to understanding reservoir heterogeneity and complexity through tailored synthetic and real data integration. A computer-based workflow has been developed to automate the downhole production flow profile. Production performance of the well is assessed, considering the dynamic time-lapse logging data. A synthetic flow profile is constructed to show the change in water production signature, and the well is further examined if it undergoes remedial actions. Reservoir characterization is a continuous process during the life of the oil field. As new data are available, the model is updated and contains more details. The incorporation of all data allows increased accuracy and reduced uncertainty in characterizing the reservoir.
The proposed methodology requires the acquisition of dynamic production logging data to establish a solid workflow and validate the model. Uncertainty can be eliminated with the acquisition of additional production logs. Recommendations for improvement of the current well condition can be made to reduce the well water cut and improve oil production from the well. Consequently, well classification and candidate selection for workover can be achieved. The results of this work demonstrate the strength of applying multidisciplinary team efforts to develop automated workflows that are relevant to reservoir and production engineers who deal with complex reservoirs with numerous wells.
Complex Stimulation Approach to Boost Eastern Siberia Oil Production
Authors: Demkovich Mikhail , Yudin Alexey , Vernigora Denis , Kurkin Petr , Vereschagin Sergey , Olennikova Olesya , Shakirov Renat , Rymarenko Andrey , Bakhurskiy Vladislav , Podberezhnyy Maxim 
Published: January 2020

An integrated approach was applied for production enhancement of the upper and lower shaly sandstone reservoirs of the Ignalinsky and Tympuchikansky fields in the Leno-Tunguska oil and gas province of the East Siberian Basin, Russia. The approach includes both comprehensive laboratory studies and a direct strategy of hydraulic fracturing design, as well as solutions to obtain optimum well performance. The approach can be implemented in future prospects and can form part of the strategy for future development in the region.
Extensive laboratory research was performed to select the proper fluid for proppant transport that could withstand all the complicated terrigenous conditions within the fields. One of the main challenges was rheological suitability of the fluid at low reservoir temperatures. The laboratory studies were important for identifying the best fluid for fast fracture cleanup while optimizing the sand-carrying capacity of the fracturing fluid. The hydraulic fracturing design incorporated calibrated petrophysical and geomechanical analysis with actual fluid rheology characterization taken from laboratory test results.
The laboratory work confirmed that the reservoir rock was water sensitive, with a significant presence of clay minerals including kaolinite, montmorillonite, and montmorillonite mixed with illite. A new generation of clay stabilizer was used to address this sensitivity. In addition, an enzyme breaker was used with the objective of effectively breaking the fracturing fluid at low reservoir temperatures. The fracturing operations that were performed during two winter campaigns resulted in high starting and operating production rates. The treatment designs incorporated a linear gel pre-pad stage prior to the crosslinked pad stage in an effort to extend fracture half-length while reducing the risk of the fracture growing in height into overlying gas-saturated layers. The results of the design efforts were analyzed using logging and fracture treatment data, which demonstrated that the design was effective in avoiding the gas-saturated formation. Overall, 23 hydraulic fracturing operations were done in five wells at Ignalinsky and Tympuchikansky fields for the B10 and B13 formations. Production results were analyzed, and further optimization paths were identified.
The study breaks new ground in enhancing the hydrocarbon extraction from low-temperature shaly sandstones with mixed wettability, not just with terrigenous reservoirs within the above-mentioned fields, but also with other reservoirs of a similar geological context, primarily the Leno-Tunguska oil and gas province of the East Siberian Basin, Russia. This is especially important in view of the depletion of oil reserves in Western Siberia and the growing interest in the development of hydrocarbon fields in Eastern Siberia.
Experimental Quantification of Slickwater Proppant Transport in Subsidiary Hydraulic Fractures
Authors: Alotaibi Msalli , Miskimins Jennifer L. 
Published: January 2020

Hydraulic fractures created by slickwater fluids are commonly known for generating fracture network complexity, which presents a challenge for the associated proppant transport. The difficulty of proppant transport in subsidiary fractures is attributed to the velocity inside them and slickwater's low viscosity. Subsidiary fractures are believed to have lower propped area relative to the primary fracture; however, this is not quantified and its effect on proppant grain distribution is not established. This paper presents laboratory measurements of such slickwater-created propped areas in subsidiary fractures and describes the dune development mechanisms and the associated effects on grain sorting.
Experiments were conducted using a 30/70 mesh brown sand and a specially designed slot flow apparatus that has a multi-fracture network of three secondary and two tertiary fractures, in addition to the main slot. The secondary fractures were attached at 90° angles from the primary fracture and separated at equal distances.
The study results show that slickwater transports large amounts of proppant into secondary fractures, reflected by the large developed dunes areas of 40.8% of the total fracture area. Fractures closer to the slurry entry point show higher propped area than ones further away. For tertiary fractures, they developed only 4.5% of the total network propped area, indicating poor slickwater proppant transport inside them. Distinct proppant transport mechanisms were identified for the subsidiary fractures with different dune heights. This finding indicates grain size sorting and different proppant size distribution in the fracture network.
This paper presents for the first time an experimentally quantified propped area distribution by slickwater in a complex fracture network. It reveals new insights about slickwater proppant transportability into subsidiary fractures and establishes a new understanding of proppant transport mechanisms and grain size distributions in subsidiary fractures, which can have a considerable impact on hydraulic fracture conductivity estimation and, hence, productivity enhancement.