bluuebunny/crossref_metadata_2025_split huggingface dataset:
Intelligent Drilling System: Expanding the Envelope of Wired Drill Pipe
Authors: Sehsah O. , Ghazzawi A. , Vie G. J. , Al-Tajar T. , Ali A. , Al-Mohammed A. H. , Itani M. , Ullah S. , Escalera H. , Balka M. 
Published: November 2017

Abstract
The intelligent drilling system (IDS), based on the 57,000 bits per second and bi-directional wired drill pipe telemetry, has been under experimental trial in the industry in a variety of applications. Several SPE papers have covered these applications, which include: drilling optimization, hole cleaning, drilling risks and NPT reduction. The IDS can also be utilized with other tools to expand the window of drilling optimization applications to include the risk management approach, where the system value and the impact on drilling operations will be greater.
To achieve this change, it is important to expand and improve the current techniques and develop new methods that will expand the application of the wired drill pipe (WDP) system. This paper will describe the application of WDP in middle east during a trial test, showing how it was expanded and customized to suit complex drilling environments.
This field trial involved a three-phase approach. Each of these phases tested the functionality and application of the IDS to determine the potential benefit for different projects.
Phase 1 aimed at testing the system functionality and integrity. This includes along string measurements (ASMs), logging while drilling (LWD) data transmission, wired bottomhole assembly components, top drive and surface system, and interface sub and signal boosters.
Phase 2 aimed at testing the top-of-mud measurements derived from the ASMs pressure readings. The objective was to test the algorithm and validate the results to ensure accurate readings. Measuring the fluid level is critical in managing total loss situations.
Phase 3 aimed at early kick detection simulation. In this phase, a kick was simulated by pumping a heavy mud pill and checking ASM response while the pill was progressing up the annulus. This simulation has important applications in early downhole kick detection in total loss situations where there are no returns to surface.
Finally, the paper will outline future applications of the IDS in managing risk in complex and risky drilling environments. This is where total losses are encountered while drilling across high-pressure reservoirs. Fluid level, in total losses situation, will be monitored by high-frequency downhole pressure measurments at multiple depths. These measurements of the downhole hydrostatic and dynamic pressure will also be providing early kick detection.
Novel Compositions Based on Nanomaterials Designed for Use as Conformance Sealants
Authors: Kalgaonkar Rajendra , Wagle Vikrant , Alnoaimi Khalid , Alhussain Ismail 
Published: November 2017

Abstract
Conformance sealants are widely used in the oil industry to prevent unwanted water production. Though a variety of chemicals are used by the industry to control water production, most of them are not accepted in the regions with strict environmental regulations.
This paper provides development of a novel plugging and sealing system for the water or gas producing zones. The newly developed conformance sealant is based on a delayed activation chemistry to gel up nanomaterial based dispersion. The nanomaterial used in this study is environmentally benign. The activator which are used in this study to gel up nano material enables the conformance pill to be precisely placed in to the target zone, before the nano material dispersion gels up thus avoiding premature plugging of pipe lines, coiled tubing or other tubulars. The newly developed system can effectively prevent water and gas flow with BHST up to 300°F. The static gelation times were evaluated at different temperatures up to 300°F. An increase in temperature causes increase in the particle collision leading to lower gelation times. The effects of concentration and particle size of activators on gelation times of the new conformance system over a range of temperatures have also been studied. We report the effect of surface charge modification of the nanomaterials on their ability to effectively seal the target zone. The effect of shear rate on geling time of the conformance sealant was also evaluated. Different activators ranging from inorganic to organic were investigated for their effect on the gelation properties of the nanomaterials. The plugging efficiency of the new system was evaluated using coreflood studies. It was shown that the gelation time of the conformace sealant can be controlled by surface charge modification as well as by adjusting the concentration of the activator, which is advantageous as it allows the sealant to remain pumpable over predictable periods of time.
The system can effectively prevent unwanted water production. It gives a predictable and controllable pumping time, ranging from a few minutes to several hours at over a wide range of temperatures. This is an important advantage of the present invention as it allows the sealant to remain pumpable for sufficient time for placement and develops the network structure that leads to gelation, over a predictable period of time. The set gel appears as a crystalline solid. It could remain homogenous and stay in place under confined conditions, such as fractures and pore spaces.
The novelty of the newly developed sealant is to have a controllable gelation time under a variety of downhole conditions to allow accurate placement without premature plugging inside the wellbore.
Sweet-Spotting and Unlocking Tight Gas Volumes of Lower Miqrat Formation
Authors: Lukmanov R. B. , Ibrahim E. G. , Shamsi K. 
Published: November 2017

Abstract
Miqrat is a complex clastic deep tight gas reservoir in the North of the Sultanate of Oman. The Lower unit of the Miqrat formation is feldspatic sand characterized by low permeability not exceeding 0.1 mD and porosity up to 12 %. Based on results of the appraisal campaign of Field X, it contains significant volume of gas. However the production test data after fraccing showed mixed results. The objective of this study was to explain the production behavior and identify the sweetspot area for further development.
Understanding the reason of possible overestimation of log derived Hydrocarbon saturation is important. Thus the interpretation of conventional and special logs was revisited. In parallel, all the available core data including SCAL and thin sections were scrutinized. Besides, the analysis of hydraulic fracture propagation, well tests, cement quality, PLT including Spectral Noise Log was performed. The wells were subdivided into categories according to their production results:–wells producing no water–wells with water channeling from the water leg of Middle Miqrat–wells with transition zone intervals with 2 phase inflow of water and gas.
Based on the integrated analysis, extend of the gas and transition zones was established, and the location of future wells optimized. From the Spectral Noise log and Temperature data, water crossflow/channeling from Middle Miqrat was identified in 2 wells, either because of broken thin sealing shale above Lower Miqrat or due to poor cement quality. The sweetspot area with commercial production was mapped. Substantial gas volumes have been unlocked. Besides, an explanation of the uncertainty in log derived saturation was suggested. Core plugs and thin sections revealed presence of partially filled vugs, which is not a typical case in a clastic environment. The origin of this porosity is puzzling and likely due to dissolution of early diagenetic nodules. The rock with poorly connected vugs has high resistivity even if it is water bearing. The review of capillary pressure data revealed that the transition zone could exceed 100 m. This finding is consistent with the interpretation from well tests.
The most practical implication of the current study potential of Lower Miqrat is unlocked. The integration of Open hole and cased hole logs and the additive information from Spectral Noise log for channeling/crossflow identification is shown. Presence of vuggy-like porosity in clastic sections and the impact of isolated vugs on log derived Saturation is demonstrated.
Performance Improvement: New 16-in. TCI Design Addresses Multiple Drilling Challenges Through Interbedded Shale and Carbonate Application
Authors: Beheiry Karim , Al Heiny Ahmed , Linnerud Blake , Maouche Zakaria , Al-Shelian Jasim , Muqaddas Zahraa , Al-Mekhyal Abdullah , Al-Enezi Dakhil 
Published: November 2017

Abstract
A 16-in. section is one of the most challenging sections to drill in southeast Kuwait. The section consists primarily of highly interbedded carbonates, anhydrites, shale, and marl intervals, with significant variations in compressive strength that range from 3 to 25 kpsi. There are potential loss of circulation zones in the Tayarat and Dammam formations, which complicates the drilling performance, required flow rate, and other drilling parameters to be controlled. Bit balling of the cutting structure was expected in some intervals where water-based mud was typically used. The drilling assembly was a pendulum rotary design for vertical wells. A positive displacement motor (PDM) assembly is typically used in directional wells.
In addition to the loss potential and long section interval, insufficient hydraulics and the high weight on bit (WOB) necessary in the Dammam to Ahmadi carbonates led to the premature failure of the cutting structure and bearings. A durable and reliable bit design was needed to drill the entire interval and the subsequent well to help reduce overall drilling costs.
Collaboration between the operator’s drilling team and the bit supplier team resulted in successfully drilling a challenging 16-in. section and multiple additional wells. Rock types, performance, and compressive strength were analyzed using an advanced software program to determine the required design changes to develop the new tungsten carbide insert (TCI) bit. The goal of the new design was to improve hydraulics configurations, create durable and robust rubber seals, and design new advanced cutting structure materials.
The new bit design provided exceptional performance in multiple wells in the 16-in. section in southeast Kuwait. The bit was used to drill three wells, with a cumulative footage of more than 9,000 ft in more than 240 drilling hours. Approximately two million revolutions were achieved with effective bearings and slight normal wear to the bit cutting structure elements. The new bit design helped to drill longer intervals and multiple wells with no risk of premature failure; it also helped to reduce drilling time and bit costs. A further test was implemented in directional drilling wells where the inclination was up to 50°.
When we Dare to Look Deeper: Drilling Downflank on Alternative Fluid-Fill and Reservoir Architecture Concepts for a Carbonate Field in the Sultanate of Oman
Authors: Ferrero M. Boya , Dhahli A. , Unal E. , Bazalgette L. , Wahabi A. , Holst M. , Doan H. 
Published: November 2017

Abstract
The development of thin oil rims in carbonate reservoirs requires good understanding of structural setting, reservoir architecture and transition zone saturations. Fields that have a tectonic and/or geochemical history after initial charge are likely to challenge standard assumptions of fluid distribution, contacts and saturation-depth relationships.
This paper is a case study illustrating downflank field extension opportunities in an oil rim, related to post-charge tectonics affecting fluid distribution and contacts.
The structure of this article encompasses four different aspects:begins by explaining the geological concepts that are being postulated for downflank hydrocarbon potential,proposes the alternative methodology of concept-driven analysis for log data interpretation,explains in detail the methodology applied to existing field data for reservoir architecture and fluid fill description,summarises the outcome of the appraisal well with respect to alternative concepts.
The workflows that justified the placement of appraisal wells downflank followed the philosophy of concept-driven analysis where data is used to eliminate hypothesis rather than averaged into one a-priori assumption or average fitting equations. The placement of the pilot appraisal well (at a depth interval and location where previous models predicted water-fill) has been enabled by the identification of stratigraphic rock types, regional variability of fracture intensity and the prediction of tilted contacts. The results of an appraisal well drilled in 2017 confirm the alternative concepts proposed from concept-driven analysis of legacy log data:–Flank reservoir thickness improvement due to post-deposition crestal erosion of best facies.–Fracture density reduction towards the northern flank of the dome structure.–Tilted oil contacts deepening towards the flank and related to paleo-charge.–Relatively dry oil production from deeper depth intervals with low oil saturation due to transition zone water mobility.
The drive mechanism and development options for the field should be investigated further.
Selected Best Practices for Geo-steering Jobs Opportunities to Grow and Enhance Customer Partnerships
Authors: Sitinjak Eri Sarmantua , Damiani Saverio 
Published: November 2017

Abstract
The objective of this paper is to summarize some good practices that must be in place to ensure that re-assigned geo-steering jobs run successfully. During recent years the amount of jobs that have been re-assigned to the BHGE from other Service Companies by the Drilling Team have increased significantly and were all executed successfully. This makes a strong statement, that re-assignment of jobs plays an important role in increasing the trust of the client to the services that are provided by BHGE. Job re-assignment typical results in optimized service and delivery not to mention the improved economics.
Developed a procedure for collecting data and documented some of the re-assigned jobs we did and found out the keys that can make the tool excel in execution. This good practice will really be needed in order to make successful re-assigned job. The re-assigned job comes in to play due to service provider’s (1) Tool failure, (2) Wellbore instability that causes stuck-pipe and lost in hole, and (3) Inability to provide back-up tool after tool failure or lost in hole. The unsuccessful service and inability to understand the wellbore problems become the most significant contribution in losing the job to another company. Some good practices in executing the re-assigned job will be summarized and concluded in order to get the idea how to provide expected service to client.
Integrated study from all aspect in drilling involving geo-steering engineer, geo-mechanic specialist, well planners, geoscientists, application engineers, workshop engineers, geologist, drilling engineer, drilling team and field engineer in location will enhance the ability to understand the situation in the hole and we will be able to provide faster decision how to execute the job successfully. Most of the re-assigned job initiated by wellbore stability issues in the hole, guide to another problem, and were not able to be recognized by the team in time. The second thing is series of tool failure and inability to provide the back-up tool in time. The last thing is the lack of service or unable to provide the service that is needed by the client. Successful execution in re-assigned job will increase the trust of the client to the tool and service, and also will become a good campaign in selling the service and make the client remember about our service quality. These findings will help service provider to learn about how to provide expected service and make a good decision while executing the re-assigned job.
Integrated Treatment and Disposal of Waste Drilling Fluid Onshore China: Laboratory Investigation and Process Design
Authors: Li Wai , Zhao Xionghu , Cai Bin , Liu Jishan , Yan Chao , Guo Wei , Zhang Jian , Jiang Jiwei , Peng Hui , Huang Danchao 
Published: November 2017

Abstract
The traditional methods of treating and disposing waste drilling fluid are encountering severe challenges with the tightening of environmental regulations in China. Commonly used chemical destabilization technology needs to be improved, and treating processes are required to be optimized and updated. This paper details a laboratory investigation on two waste water-based drilling fluids (a high-density drilling fluid and a reservoir drilling fluid) from the rig sites, as well as the corresponding treatment and disposal process design. The laboratory work focused on a solid-liquid separation technique on the basis of chemical flocculation and centrifugation. According to the properties of each waste drilling fluid, different flocculants were added to initiate chemical flocculation. The effects of type and concentration of flocculants as well as treating conditions (including sulfuric acid, dilution ratio, centrifugal speed and agent adding sequence) on the degree of separation were comprehensively investigated. To apply the separation technology in various fields, two integrated processes for collective and in-site treatments were designed and discussed respectively. The results showed that the correct combination of inorganic and polymeric flocculants can lead to a great degree of separation. In particular, a novel flocculant based on modified starch exhibited excellent performance. The molecular weight of polymeric flocculant substantially influences treatment efficiency, which can be explained by the combination of adsorption-bridging and sweep-flocculation mechanisms. Adding sulfuric acid to the waste drilling fluid in treatment is beneficial to solid-liquid separation due to the reduction of electrostatic repulsion between solid particles. Molecular weight of flocculant is also a crucial factor influencing the separation effectiveness and rate. For the two waste fluids studied, the optimal treating conditions were proposed. The weight fraction of separated liquid phase reached higher than 80% and the liquid content of the solid phase was lower than 30%. Detailed analysis and discussion of the advantages of this process were presented. Preliminary field practice of this technique exhibited its satisfactory performance. This highly-integrated technique based on novel chemical agents, rational design and high-efficiency equipment is helpful to deal with the increasing technical and environmental challenges. The information provided in this work offers a reference to relevant researchers, designers and engineers.
Integrating MPD into HPHT Well Planning
Authors: Cadd Michael , Steven Lewis , Graham Robert , van der Bos Fedderik , Maatschappij B. V , Leggett Craig , Stoian Emil 
Published: November 2017

Abstract
Managed Pressure Drilling (MPD) is an increasingly common technique in narrow margin HPHT wells. However, MPD is sometimes viewed as a 'bolt-on' technology, only added after much of the planning work has been carried out and all other alternatives have been exhausted. By this stage key aspects of the well design are already fixed and major benefits of MPD can therefore be missed. The decision to use MPD should be made at the earliest stage of well planning, not on the basis of having no remaining alternatives, but by understanding the value that MPD can bring to the project. By doing this, MPD can be fully integrated into the well design, rig specification, procedures and training. This paper describes how an early commitment to integrate MPD into an HPHT drilling operation can make MPD more than just an enabling tool, and turn it into a performance tool that offers significant operational benefits.
An Experimental Study on Interactions between Imbibed Fracturing Fluid and Organic-Rich Tight Carbonate Source Rocks
Authors: Liang Feng , Lai Bitao , Zhang Jilin , Liu Hui-Hai , Li Weichang 
Published: November 2017

Abstract
Carbonate reservoirs dominate 70% of oil and 90% of gas reserves in Middle East region, and imbibition is the main mechanism for fracturing fluid up-take during hydraulic fracturing stimulation process. Due to highly heterogeneous nature of tight carbonate source rocks, it is crucial to understand effects of the imbibed fluid on the mechanical, morphological and flow properties of the carbonate rocks. While the influence of imbibed fluids on the wettability of carbonate reservoir has been studied intensively, the research on effects of imbibed fluids on the texture and mineralogy of the carbonate rocks is very limited. This paper aims to provide a conceptual approach and workflow to characterize and quantify microstructure and mineralogy changes resulting from the imbibed fluids.
A thin-section of low permeability organic-rich carbonate rock sample with a dimension of 7mm × 7mm × 0.3mm (length × width × thickness) was used in the study. The sample was submerged into 2% KCl (pH = 7.1) fluid from one end to simulate the spontaneous imbibition process. Scanning Electron Microscope (SEM) was used to capture the sample’s morphological change before and after spontaneous imbibition. Energy Dispersive Spectroscopy (EDS) mapping was used to study mineralogy changes (dissolution and precipitation) before and after fluid treatment. Inductively coupled plasma (ICP) equipped with optical emission spectrometer (OES) detector has been used to quantify dissolved ion concentrations in the treatment fluid. Permeability and porosity were measured using core plugs (1" in diameter × 1.5" in length) before and after imbibition process with half-length of the sample submerged into the treatment fluid.
The SEM images for the thin-section sample show three zones with distinct fluid up-take characters. In Zone I, which was submerged into the testing fluid, considerable mineral dissolution has been observed. In Zone III, which was above the testing fluid level, considerable mineral precipitation was detected. While in the transition zone (Zone II, which was between the above two zones around the water-air level), minor amount of mineral dissolution was observed. The mineralogy changes resulting from the dissolution and precipitation have been identified by EDS analysis in all three zones. Gypsum and calcite were found to be dissolved in the imbibed fluids, while gypsum was found to be deposited on the rock surface in zones above fluid level. The observed gypsum deposition might result from the dissolution of the gypsum and calcite and re-precipitaion later from the imbibition experiment due to water evaporation and/or from sample drying process. Absolute permeability and porosity measurements for core plug samples show that both increased after the imbibition process.
Nano-Enabled Smart Materials and Sensors for Oil and Gas Applications
Authors: Ventura Darryl , Dolog Rostyslav , Darugar Qusai , Khabashesku Valery , Hughes Baker 
Published: November 2017

Abstract
This paper describes the use of nanotechnology for transforming conventional composites that are commonly used in oilfield applications into smart materials with the ability to transmit pertinent data from downhole operations and activities. The oil and gas industry already uses stimuli-responsive materials for numerous technologies including swellable elastomers in reactive packers and in heat/ fluid-activated expandable screens. This research details the digitization of stimuli-responsive materials through the integration of a network of conductive nanomaterials into an elastomer matrix. As a result, sensors with a wide array of detection capabilities become possible. For instance, it is possible to monitor the degree and rate of a material’s expansion downhole – such as in packers or sand screens. Such information can be used to detect tool deployment status, degradation, or even chemical detection. In addition, the conductivity data resulting from nano-enabled smart composites described here can be used to detect the presence of oil, water, or specific chemicals.