bluuebunny/crossref_metadata_2025_split huggingface dataset:
Using In-Bit Data Capturing Sensors to Identify and Reduce Dysfunctions Using a Higher Drilling Efficiency Shaped Cutter Solution
Authors: Kouzaiha Rami , Sayyaleh Salem , Khalil Ahmed , Borayek Ahmed , Reyad Mahmoud , Al Otaibi Atheer 
Published: October 2022

Abstract
Drilling oil wells with long laterals in extended reach reservoirs present one of the hardest challenges for drilling companies in the demanding environment especially given their propensity to high downhole vibrations causing many premature tool failures. Managing to attenuate these sources of vibrations can lead to reduced drilling risks and lower section times with less exposure to reservoir hazards. Through a downhole vibrations study using in-bit sensor captured data along with a force simulations model between the drill bit and the formation, lower vibrations are expected with improved drilling efficiency.
Understanding the drilling vibrations using a high frequency reading sensor placed in the bit is the key to differentiate the types and excitation sources of dysfunctions downhole in order to quickly and effectively address and reduce them through parameter optimization and drill bit design modification. The 6 1/8" lateral section drilled with a standalone push the bit Rotary Steerable System (RSS) was studied deeply to understand the types of vibrations coming from the bit to attenuate any identified dysfunctions. The high frequency readings in this drilling application demonstrated high stick and slip vibrations typically excited from the increased engagement of Polycrystalline cutters into the formation which led to increased BHA vibrations and lower rates of penetration (ROP) increasing well time and cost. Mitigating this destructive dysfunction caused in part by certain drilling limitations of the conventional round PDC cutter was found to be the key to a higher drilling efficiency with lower vibrations and improved stability extending the life of the bits and the downhole tools. This led to an overall decrease in section drill time and an increase in the consistency of well delivery.
Point loading shaped cutters with an adapted drill bit design profile were used in several lateral wells in MENA. The new bit attenuated the overall torsional related dysfunctions in the section by 15% and producing more efficient drilling which resulted in an improved average ROP of the lateral section by 34% as well as a reduction in the rate of downhole tool failures from 11% to less than 7%. Using image recognition technology to assess, analyze and digitize the bit dulls, each cutter on the bit was evaluated, and the new bit design illustrated a 9% improvement in the average dull with a lower requirement for bit repair.
The digitally enhanced drill bit design with the point loaded shaped cutters enabled a pre-fracturing of the formation while also benefitting from the shearing mechanism of the shaped PDC cutters enhancing the overall drilling efficiency of the bit. These shaped cutters also added stability to the bit which resulted in reduced overall drilling dysfunctions and extending the BHA life along with an improved section ROP.
Intelligent Pipe: A Multi-Annuli Monitoring Solution
Authors: Bulard Francois-Xavier , Tavernier Emmanuel , Kling Lucas 
Published: October 2022

Abstract
Well integrity has always been a challenge for the oil and gas industry. The main concern for operators is to prevent catastrophic well failure during their operations, which could have a dramatic impact on the environment and put people working on site at risk. The industry is therefore looking for new solutions to monitor well activity in real time, especially for subsea wells where the annuli are inaccessible. By anticipating any abnormal behavior, operators will then be able to act faster and adapt their operations to avoid any damage to the well.
The multi-annulus monitoring solution will provide pressure and temperature for each well annulus. These key parameters are captured by innovative sensors based on MEMS technology. An innovative transmission methodology is used that allows power supply and data retrieval even for annuli beyond the "B-annulus". All electronic elements of the solution will be qualified through the international recommendation (called AWES) which consists of a series of mechanical and long-term tests to ensure that our system will survive for 20 years at 125°C.
This paper will present the results of the different tests carried out to qualify the electronics, those performed to qualify the performance of the multi-annulus transmission, as well as the results of the first field trial carried out with this product. During this first trial, the operator encountered several operational issues. Our system provided actual data that was used in their own simulation to investigate the root causes of these operational difficulties. This clearly demonstrated the importance of having data from inside the well to confirm and complete the well simulation. This article describes the development of a continuous monitoring solution through to its deployment.
This system offers oil and gas operators a new tool to monitor their wells and enhance the safety of their operations. It could be used in all storage applications, especially those related to the energy transition, including CCS and H2 storage.
Enhanced Single Trip Upper Completions for ERD Applications
Authors: Parihar Shardul , Wang Zhihua , Andrew Wills John , Mason Jane 
Published: October 2022

Abstract
An Abu Dhabi offshore field development plan comprises of ERD wells requiring intermediate / production casing depths of up to 23,000 ft with horizontal sail sections of approximately 10,000 ft of length. The original completion design involved drill pipe deployed intermediate completions, followed by a separate upper completion run with anchor latched seals. Over time, operational practices enabled the use of single-trip completions with tubing mounted packers, saving 2 – 3 rig days per well, but introduced some challenges. The objective was to maximize the usage of single-trip completions while continuing to leverage the advantages of an intermediate completion. Additionally, deployment enhancers such as lubricated fluid, low drag centralizers, and / or upsized tubing were included in the design to extend deployments deeper.
A comprehensive application review was conducted covering the system technical limits during installation and well life cycle operations. Detailed testing and modelling were carried out to understand the impact of deployment enhancers. This paper will provide insight as to the detailed drivers and design of the lubricated fluid and low drag centralizers. Additionally, the strategy for well trials and their successful results will be covered.
Several enhanced single-trip completion systems were successfully installed, confirming the efficiency gain of 2 – 3 rig days per well in high angle, deep casing ERD wells. The fluid lubrication provided 30 – 50% cased hole friction factor reduction. Additional long term well life cycle efficiencies were achieved, such as OPEX savings during future workover operations resulting from the anchor-latch feature and maintaining the same ID from the production packer down to the liner for future lower completion retrofit without requiring the production packer to be retrieved.
While single-trip upper completion systems have been used in the past, achieving the two-trip completion system advantages with a single-trip system was not possible before. Additionally, deploying the enhanced system coupled with deployment enhancers has allowed the completion of high angle and deep
casing ERD wells. Expectations are to extend application of this completion design to even deeper casing depths.
Quantifying Smart Liner Acid Stimulation Efficiency in Heterogeneous Carbonate Reservoir Using Inline Tracers and PLT
Authors: Bazuhair Ahmed , Mogensen Kristian , Al-Marzouqi Laila , Mustafa Hammad , Chitre Sunil , Al Maazmi Mariam , Gadelhak Abdelrahman , Al Jawhari Mohamed 
Published: October 2022

AbstractMatrix-acid stimulation is a key production enhancement technique for carbonate reservoirs. The ability to control acid placement by diversion along the reservoir section is often challenging, particularly for heterogeneous formations where low-permeability intervals may remain under-stimulated. In this paper, we demonstrate via subsequent inflow profiling that efficient stimulation of both low- and high-permeability segments can be achieved using a completion method called a Smart Liner and a new methodology of downhole flow monitoring without operational well intervention by utilizing inline tracer system across the lower completion.The Smart Liner is a completion technique, which relies on a number of small and unevenly spaced holes to divert acid along a horizontal drain, while incorporating swellable packers to isolate segments with different reservoir properties. The hole spacing design is unique for each well and requires a software algorithm to balance the outflow. The inflow monitoring is assessed through both inline chemical tracers and conventional PLT. Main components of this algorithm has been presented in an earlier publication.The inline tracer system can provide "wireless" continuous production profiling without the risk & cost associated with conventional PLT methods. The inline tracer samples were collected during both stages of pre-stimulation and post-stimulation activities on oil producer wells, which shows downhole contribution of all segments, acid arrival and enhancement of Mid section of the reservoir drain. Moreover, PLT was conducted to validate inline tracer results.Past deployments of Smart Liners have targeted homogeneous reservoir intervals, but in this paper, we show that also reservoirs with significant permeability variation can be effectively matrix-acid stimulated. It is to our knowledge the first time that inflow profiling of a long horizontal well has been probed with inline tracers as well as PLT. Furthermore, we quantify the incremental impact of a given acid volume on injectivity based on the high-frequency data from the stimulation job.
An Innovative Method to Enable Well Kick-Off and Liquid Unloading Using Dry Ice
Authors: Karadkar Prasad , Alkhowaildi Mustafa , Bulekbay Aslan 
Published: October 2022

Abstract
Gas production can be enhanced by the unloading of liquid accumulated in the wellbore. Conventionally, it is addressed by dropping soap sticks into a gas well. The foamability of soap sticks tends to decrease in the presence of condensate. Alternativity, well can be kicked-off by using N2 lifting but it is an expensive method that involves coil tubing operation. In this paper, an innovative and simple method of unloading a condensate-bearing gas well using dry ice is described.
Gas wells accumulated with liquid or condensate can be unloaded by displacing it with CO2 gas. It also helps to reduce hydrostatic pressure during kick-off well. Dry ice pellets can be inserted inside the wellbore, which can be settled down by gravity and CO2 gas formation inside the wellbore due to dry ice sublimation. The dry ice sublimation rate can be restricted by encapsulating it with self-degradable polymers that can be hydrolyzed inside the wellbore. Cylindrical dry ice pellets from the food industry having a half-inch diameter and a couple of inches long were used in this work.
Dry ice is the solid form of CO2 having an expansion ratio of 1 to 554 for solid to gas at sublimation point −78.5 °C and atmospheric pressure. The density of dry ice is 1.562 gm/cm3. A series of lab experiments were conducted to show CO2 gas generation from dry ice in the water. After inserting a dry ice pellet into the water column, it settled down at the bottom and started releasing CO2 gas with a sudden expansion in volume. CO2 foam was also generated by inserting dry ice pallets with foaming agents inside the water column. The release of CO2 gas in the wellbore and foam generation can assist in decreasing hydrostatic pressure and lifting liquid inside the wellbore. At the well site, a simple modification is required to insert dry ice into the wellbore. The cylindrical chamber needs to be installed above the master value of the Christmas tree. This is described in the paper with the procedure to follow during the operation. A mathematical tool has been developed to estimate the amount of dry ice pallets required for a given well geometry. For 4.5 inch, 1000 ft long production tubing, 1000 kg dry ice can release 51.7 bbl of CO2 gas, which can generate a 495 psi increase in pressure.
Well intervention operations are complex and expensive processes. It is preferred to use simpler, quicker, safer, and more cost-effective methodologies. The use of dry ice to unload gas well is simple, cheaper and an innovative solution. The release of CO2 gas from dry ice can offer additional benefits such as better and faster cleanup and the removal of condensate blockage in the near-wellbore area.
Development Mechanism of Ultra-Low Permeability Limestone Reservoirs: A Case Study of the Cretaceous S-Reservoir in H Oilfield, Iraq
Authors: Ning Chaozhong , Deng Xili , Liao Xuan , Wang Youjing , Zhu Guangya , Han Haiying , Yang Jing , Chen Jiaheng , Wang Nai , Li Nan , Lan Yukun , Zhu Changqian , Peng Shudai , Shao Lei 
Published: October 2022

Abstract
Ultra-low permeability limestone reservoirs in the Middle East have huge untapped reserves. In Iraq, Field H has nearly one quarter of reserves in the S-Reservoir with permeabilities of (0.02-0.4 mD). It is difficult to identify optimal drilling locations, or sweet spots, that maximize recovery factors due to poor understanding of reservoir characteristics. Using the S-limestone reservoir, this study aims to clarify the environment of deposition, diagenetic evolution, reveal the development mechanism of ultra-low permeability, and predict the distribution of more favorable areas.
Whole core, thin sections, scanning electron microscope (SEM), mercury injection (MICP), well logs, and seismic data were utilized for the analysis. Through core and thin section observation, lithology, biostratigraphic sequences, pore type, and sedimentary structures were determined. Through these observations the environment of deposition of the S-Formation is interpreted as mid to outer carbonate ramp. The lithology is mainly wackestone to packstone deposited in a low energy environment below fair weather wave base. Primary fossils are planktonic foraminifera tests as grains and coccolith microfossils in the matrix.
Thin sections and MICP analysis helped delineate the porosity classes and diagenetic history. The pore throat size, determined by MICP data, was 0.03 - 0.1 μm. Primary porosity is around 10-25% and is driven by intragranular voids in foraminifera tests, followed by intergranular, and intercrystalline microporosity of the matrix. Foraminifera tests are generally intact and float in the mud matrix. As a result, large intragranular pores are well developed but not connected, causing overall medium-high porosity but ultra-low permeability. Early marine calcite cement is the primary diagenetic process which destroyed porosity and permeability. Little to no evidence of secondary dissolution was observed.
Identification of Trends Driving Reservoir Heterogeneity at Multiple Stratigraphic Intervals in a Giant Middle Eastern Carbonate Reservoir.
Authors: Sellar Christopher , Contreras Perez David Rafael , McGeer Alicia , Al Mansoori Maitha Mubarak , Vršic Aleš 
Published: October 2022

Abstract
Oilfield A is a low relief structure consisting of multiple stacked reservoirs. Three reservoir intervals show different trends of reservoir property distribution. Lateral reservoir property degradation in Oilfield A is correlated to increased vertical heterogeneity. Understanding the driving mechanism for the controls on reservoir property distribution is therefore essential for effective well placement, well spacing and achieving the expected ultimate recovery from the oilfield.
Previous integrated reservoir characterization studies in Oilfield A have identified a link between chemical compaction, reservoir thickness, cementation and reservoir property distribution in Reservoir 2. As part of reservoir model building and subsequent structural updates, thickness maps have been constructed from well data for each reservoir unit as an early indicator of possible reservoir property trends. The maps show trends which are integrated with other data, both static and dynamic in order to validate their impact. To establish correlations, thickness maps were compared to maps of log porosity, facies, diagenetic features, geophysical attributes, cumulative oil production and water cut.
Reservoir thickness shows a good correlation to reservoir property distribution in several different reservoirs in Oilfield A. Reservoir 3 shows a south-east to north-west trend of reservoir degradation, Reservoir 2 shows a north to south trend of reservoir degradation, while Reservoir 1, shows a west to east trend of reservoir degradation.
Chemical compaction has been shown to drive reservoir property degradation in all three reservoirs. An increased abundance of stylolites is noted in the thinnest, most cemented, poorest quality parts of the three reservoirs. Since chemical compaction (stylolitisation) is a process which starts in the burial diagenetic realm and since all three reservoirs show a similar paragenetic history it is logical to expect all three reservoirs have a similar burial history. However, the trends observed in the three stacked reservoir intervals are orthogonal to opposite.
Reservoir properties are rarely randomly distributed in oil reservoirs. Integrating static and dynamic data together in Oilfield A has shown that compaction is the dominant driver of reservoir degradation in three stacked reservoirs. Understanding the trends controlling lateral and vertical reservoir heterogeneity due to compaction is essential in appraisal and development well planning as well as increasing expected ultimate recovery as part of increased and enhanced oil recovery projects.
New Exploration Plays in Sohar Basin UAE
Authors: Williams Glen , Thurley Callum , Cox Edward , Stewart Donald Neil , Sarssam Mark , Al Hamadi Masoud 
Published: October 2022

Abstract
The Sohar Basin, located offshore the East Coast of the Arabian Peninsula, is a long-ignored area adjacent to the super basins of the Arabian Plate. Three dry wells were drilled in the northern Sohar Basin between 1969 and 1980 on structural anomalies. In 2001, a 3D survey was acquired over the UAE portion of the basin in the belief that the Arabian Platform Carbonates extended from the Rub al Khali Basin, beneath the Semail Ophiolite to the east. This study depicts how this legacy 3D dataset has been re-evaluated to define new prospectivity.
A tectonic history defined by a sequence stratigraphic and structural interpretation of the 3D data as well as a basin modeling exercise has revealed a previously unexamined petroleum system. These include Miocene to Eocene-aged turbidite channel and fan complexes representing potential reservoir units. In the deeper section, high reflectivity layers within ‘mini-basins’, have seismic characteristics consistent with organic rich source rock layers. Basin modelling indicates that these layers would be mature for hydrocarbon generation. Shallow bright spots provide evidence for hydrocarbon migration along deep-seated faults.
Abu Dhabi Fold-Thrust Belt Dilemma of Jebel Jais Outcrops: Impact on Hydrocarbon Trapping Mechanism in Eastern Abu Dhabi
Authors: Noufal Abdelwahab , Aamir Muhammad , Obaid Khalid , Al Ali Ibrahim , Al Hosani Ismail 
Published: October 2022

Abstract
For the last decades, only a few scattered wells have explored the thrust fold belt in Abu Dhabi, with inconclusive results about the hydrocarbon potentiality. Drilling was avoided in these areas in the past due to the geological complexity and unavailable technologies that would reveal the subsurface geometries. Previous studies attempted to resolve the petroleum system elements in Eastern Abu Dhabi; however, they are still challenging, and require thorough investigation.
This paper is focusing on the integration of Jebel Jais outcrops in Ras Al Khaima with subsurface datasets (Geophysical and well data), which will help in understanding the subsurface structural trap geometries, reservoir and charge evolution and timing. The outcrops functioned as remarkable analogues for structural features that indicate complex tectonics of the region such as folding and faulting. They will also serve in guiding the mechanical and kinematic modeling of subsurface, where seismic image is undistinguishable.
ADNOC has recently completed a Mega 3D seismic survey in Eastern Abu Dhabi with higher acquisition parameters compared to the legacy 2D and 3D seismic surveys. The early fast track Seismic processing results revealed additional structural styles, which will be refined with advanced seismic imaging techniques, and calibrated with potential data such as gravity and magnetics in later stages.
The thrust nappes deformation and the fault-bend folds were observed in the outcrops. Most of thrusts are associated with strike-slip component and the detachment surface located at the base of Khuff units. Folding-stacked structures have different orientations with narrow duplexes that led to the growth of anticlinal stacked structures, which were the consequence of differential uplift of the rock units above the duplex, and were subjected to stretching. This process invoked strike-slip faulting along the lateral culmination wall and was facilitated by the regional, syn-thrusting arc–parallel transpression. Horizontal movement along the fault plane is a result of tear faulting accommodating a varied rate of advancement of Khuff units. The time of the fault formation is well-constrained post-Jurassic; however, the syn-thrusting origin showing its anticipation through Triassic onwards forming thrust-fold belt.
This paper will provide insights from Jebel Jais Outcrops that will help in understanding the substantial undiscovered hydrocarbon resources and prepare for future exploration activities.