bluuebunny/crossref_metadata_2025_split huggingface dataset:
New Concentric Dual Diameter Fixed Cutter Technology Bit Drills 56 Faster and Saves Operator Drilling Time in Directional Application Through Challenging Abrasive Sandstone in One of the Largest Reservoirs in the Middle East
Authors: Al-Mayyan Haitham , Malik Abdullah , Sumait Bader , Fayed Moustafa , Khalil Karim , Khalil Ahmed 
Published: November 2016

Abstract
This paper will discuss the deployment of the concentric dual diameter fixed cutter bit technology which was introduced in January 2015. The bit was deployed and tested several times in a tangent, directional application and J-shap wells in Burgan Field, South of Kuwait and achieved the fastest penetration rate in the application.
The concentric dual diameter bit is composed of a smaller pilot and a larger reamer section, where the reamer section dictates the final drill size. Conventional fixed cutter bits take very little advantage of stress relieving the rock, as it only affects the borehole wall. Concentric dual diameter technology bits are able to initially drill with a leading smaller pilot section efficiently to relieve the stress of the rocks. Subsequently, the reamer section removes the stress-relieved rock with lower mechanical specific energy compared to regular fixed cutter bits, giving it the advantage to generate higher penetration rates. Another advantage of the concentric dual diameter technology bits is the stability of the bit, since two gauge sections are available to be in constant contact with the borehole while drilling.
The first 12 ¼ in. concentric dual diameter technology bit in conjunction with directional 8¼ in. PDM (0.16 R/G, 7/8 lobes, 4 stages, 1.5 BH) BHA was tested in a directional application J-Shape well in Burgan Field, South of Kuwait. The bit was able to deliver improved performance by drilling the tangent section from 4345 ft to 6019 ft from Ahmadi to Burgan formation, total 1674 ft in 17 hrs with 98.4 ft/hr. The bit showed excellent steerability, building from 39 deg to 43 deg with 3 deg/100 ft max DLG severity. The section lithology consists mainly of Shale, Limestone & Sandstone.
The performance capability was confirmed when the second bit run in conjunction with directional 8¼ in. PDM (0.16 R/G, 7/8 lobes, 4 stages, 1.5 BH) BHA was tested in a directional application S-Shape well in Burgan Field, South of Kuwait. The bit was able to deliver improved performance by drilling the dropping section total 940 ft from Ahmadi to Burgan formation. The bit showed excellent steerability, dropping from 15 deg to 0 deg with 3 deg/100 ft max DLG severity. The section lithology consists mainly of Shale, Limestone & Sandstone.
The 12 ¼ in. concentric dual diameter was able to surpass the average rate of penetration for the same application in the Burgan Field by 56% saving the operator drilling time and making the concentric dual diameter bit design the top performing drill bit in the field.
Integrated Off-Bottom Cemented Inflow Control Device System Design Toward Well Delivery Optimization
Authors: Al Madan Mohammed A. , Khamseen Mazen Bu , Suherdiana Hedy , Abdulmohsen Ahmad Al 
Published: November 2016

Abstract
Off-bottom cementing (OBC) operations are unique to Saudi Arabia and also represents one of the most challenging types of drilling and workover operations, when deployed in combination with inflow control devices (ICDs) across horizontal sections. In a conventional ICD system, an inner string with packer setting tools is required for setting open hole packers, and to have 100% circulation at the bottom of the completion, to wash down any tight spots. As a consequence, this introduces additional issues such as health, safety and environment, logistics and additional rig time. The inner string also increases the ICD completion string weight, while deploying the system in the horizontal section, creating more drag and increasing the risk of getting stuck.
The multitasking valve (MTV) feature in the upgraded ICDs offers safe, simple and cost-effective deployment operations. The MTV allows the system to be deployed without the need for an inner string. This will positively impact the deployment by simplifying the complexity in the rig operation while achieving 100% circulation at the shoe. Besides, all the hydraulically activated equipment, such as the liner hanger packer, open hole mechanical packers, etc., can be pressurized and set simultaneously. Furthermore, the ICD completion will weigh less in the horizontal section, resulting in less friction and drag to reach total depth (TD). The MTV feature provides an opportunity to deploy the ICD system and the OBC liner system together in one trip. This paper will discuss the first deployment of a combined ICD system with an OBC system for a workover operation, in a historical oil well producer in the Kingdom of Saudi Arabia. The merged system was successfully deployed to depth, then cemented off-bottom, saving approximately 40 hours of rig operation time.
Paradigm Shift in Development Strategy for a Giant Clastic Reservoir in North Kuwait: Vertical Conformance Initiative in North Kuwait
Authors: Jamal Mariam , Gonzalez Ron Angel , Slimani Karim , Abdulbasset Mohamed 
Published: November 2016

Abstract
Sabiriyah Upper Burgan is a multilayer clastic reservoir in North Kuwait under active water flood since 2000, which has been rated as one of the most heterogenous reservoirs as per analogous studies in the past. With five major flow units, poor sweep efficiency often results from spatial variation and/or heterogeneity in the permeability of the reservoir rock, usually resulting in an irregular displacement front of the injected fluid. The initial completion design did not address the injection profile control. Also, conventional techniques to improve vertical conformance did not give desired results. The objective of using Water Flooding Regulator (WFR) is flooding all the units so as to improve the overall sweep efficiency.
To optimize vertical & areal sweep efficiency and enhance production from the uncontacted portions of this reservoir, a paradigm shift in water flood strategy was adopted for selective injection strings using WFR. These devices[RAJ1] enable to control injection rates in specific layers irrespective of the reservoir pressure, permeability, skin damage or any other factors that would normally affect flow, focusing where the oil needs to be swept. The new completion design with WFR was installed in one of the water injector wells, thereby recompleting the well, switching from the conventional to the straddled packer completion, grouping five flowunits into three zones with WFR, rationalizing the splits as per needs per layer vis-a-vis to the perforations in nearby producers.
Prior to the installation of the WFR, surveillance actions such as re-perforation, ILT and injectivity test, were conducted. Workover rig was deployed with an integrated plan for running the completion. Since three units have been grouped in one zone, allocating the water in each unit during the design stage itself was done as per the best reservoir management practice involving all stakeholder teams.
The first implementation of WFR in Kuwait, has proved the concept of improving vertical injection profile by enabling higher injection rates into layers that never received water before and regulating the distibution into all layers. As most of the water injected into the well (more than 90%) was traversing through one zone only before the job, the vertical distribution of injected water due to WFR approach resulted in choking the flow through this layer to about 60% and improve the flow through the remaining uncontacted layers. In the long term, this approach is likely to to add to production, reserves and ultimate recovery factor.
Based on comprehensive evaluation, a campaign of completing nine more vertical injector wells with this selective-string design is planned by Kuwait Oil Company (KOC)[RAJ2][JMAR3]. The re-engineering of injection profile has paved the way for application of this technique in other similar reservoirs of Kuwait.
Casing Wear and Stiff String Modeling Sensitivity Analysis – The Contribution of DP Pipe-Body and Tool-Joint on Casing Contact
Authors: Vavasseur D. , Mackenzie N. , Nobbs B. , Brillaud L. , Aichinger F. , Dao N. 
Published: November 2016

Abstract
Casing wear due to pipe body and tool-joint of Range 2 and Range 3 DP is compared using a stiff-string torque & drag & buckling model coupled to a 3D meshed casing wear calculation. Results are compared for multiple well profiles, either smooth or tortuous, in addition to differing pipe-body and tool-joint wear factors.
The driving force behind the study was to investigate if the benefits Range 3 DP over Range 2 DP, such as reducing the ECD during drilling as well increasing the lifespan of rotating BOPs, outweigh the potential casing wear. To accurately determine casing wear, all rotating operations must be taken into account and therefore a complete BHA run program must be detailed. The casing wear was found by determining the evolution of tool-joint and pipe body contact points along the drillstring and during all the operations using a stiff-string Torque and Drag model. Then, based on the contact force history, a linear Hall model was applied to a detailed 3D casing mesh which takes into account the differing OD's of tool-joint and pipe body. A sensitivity analysis was performed by varying the wear factors attributed to either the pipe body or tool-joint along with the tortuosity and shape of the wells.
The results of the study show that, for smooth well trajectories, a Range 3 pipe will cause reduced overall casing wear even if an increased wear factor for the additional pipe body contacts is taken into account. If a realistic tortuosity is added to the well trajectory, the contact forces are much higher. For Range 3 drill pipe, the number of pipe body contact points increases significantly. For equal tool joint and pipe body wear factor, casing wear becomes preliminary dependent on the well shape and tortuosity. If an increased wear factor for the pipe body contacts is taken into account, Range 3 pipes will cause significantly more wear than Range 2 pipes depending on the well shape.
This paper will show the benefits of using a stiff string model, taking into account a 3D oriented casing contact, while performing casing wear calculations and which conditions the use of range 3 pipes may result in significantly increased casing wear.
A First In-Line Remove Geochemstuiry Pilot for an Offshore Field
Authors: Al-Amrie Omar , Blondeau Christophe , Berthier Maxime , Ruau Olivier , Baylaucq Antoine , Massoue Didier , Lescoute Laurent 
Published: November 2016

Abstract
Total has been operating oil and gas production from a series of heterogeneous reservoirs offshore Abu Dhabi since 1974. Today's world class recovery factor obtained on some of the fields is due to early application of new technologies such as enhanced artificial lift multi-lateral wells, field-wide tracer and state-of-the-art reservoir monitoring and well management. High-complexity in such a field required very fine reservoir monitoring to update production allocation from multi-drain wells, to extend field production.
Developing reliable and cost effective monitoring tools is primordial to reduce operating cost, especially for mature fields in a low oil price environment. Since the middle of the 1990's, allocation by geochemistry has been regularly used to allocate production between reservoirs with significant oil signature differences. It has been mainly used to reduce the number of production logging acquisition runs and to provide a production allocation in wells for which the production logging is not possible.
This technique has proved to be a reliable technique but has had a major drawback associated with the time and logistics required to collect and send well head samples to laboratories for batch analysis. Delays of up to 6 months from sample collection to results availability have had inevitable consequences on the implementation of the required actions.
The first in-line GeoChemistry remote Tool (GCT) has been developed by Total and successfully field tested on oil wells in 2015. This tool allows for automated sequential sampling operations, oil separation and oil signature analysis, enables within a few hours, an individual reservoir oil production allocation to be estimated. This tool connects directly to well heads while sampling produced fluids. Fluids are sent in the dual-skid system through a sampler where oil, gas and water are separated and from here then to an analyzer which is a coupling between gel permeation chromatography with ultra violet detector. Finally, results can be obtained in real time after processing and correlation of analytical data through statistical software (oil composition & production split between producing layers).
This paper describes challenges encountered to implement and test the tool in the field. Indeed, after validation of this first pilot, the offshore environment combined with a large typology of wells tested (high water cut, high GOR, H2S, gas activations, slugging behaviour) led to an upgrade of the prototype which will provide greater accuracy and wider range of application in the campaign planned for 2016.
Challenges of Commissioning Grass Root Ruwais Refinery West
Authors: Mukherjee Somen 
Published: November 2016

Abstract
Abu Dhabi Oil Refining Company, Takreer has recently commissioned the Ruwais Refinery Expansion Project. The Grass Root refinery having capacity to process 417,000 BPSD (Barrels per Stream Day) of Murban crude. Commissioning & Startup is one of the most critical milestones and phase of projects in refinery. It is the last visible step of a project execution process. It moves the project from the "end of construction" to the "commercial operation" status. This paper focus the challenges associated with new refinery commissioning and start-up situations, an understanding of the tools and techniques that can be used to facilitate the effective planning, execution, control and management of these situations. The work process on a Refinery project involves basic engineering, detail engineering, procurement, construction & erection, precommissioning and startup. While each of these activities has its own importance but construction and adoption of successful precommissioning Strategy are the two crucial activities that determine a safe flawless startup. This paper address some the critical commissioing issue encountered while strating a grass root refinery and petrochemical complex.
New Economical Process to Monetize High-CO2 Natural Gas
Authors: Ayasse Conrad , M. Shahin Ahmed , Ayasse Alan , Ayasse Rob 
Published: November 2016

Abstract
Objectives/Scope:
Presently, high capital and operating costs are preventing monetization of high-pressure natural gas containing substantial quantities of CO2. The objective of the paper is to highlight an advancement in the removal of CO2 from high-pressure natural gas, such as the Natuna and Llaird fields. In particular, the paper will show how the Verdis Process dramatically reduces the operating costs and energy demand of CO2 removal, and how the Process integrates with pipelining or deep well disposal of the CO2 while producing market-ready natural gas.
Methods, Procedures, Process:
The presentation will be structured in 3 parts. The first part will briefly outline the current state of the art in CO2 removal from high-pressure natural gas, the second part will explain the Verdis CO2 Process, which uses a solid-state absorbent, and the economic and environmental benefits it can bring, and the third part will explain the applicability over a wide range of gas compositions, including the presence of hydrogen sulfide.
Results, observations, Conclusions:
High-pressure gas (over 1100 psi) containing elevated levels of CO2 is difficult to monetize because of the high cost of CO2 removal. Although un-economical, cryogenic processes have been the leading technologies for treating this difficult gas because a liquid CO2 product facilitates deep well disposal of the CO2 without compression. However, the process is very energy-intensive. Verdis has now developed an energy-efficient solid state CO2 absorbent that can be stripped with dry gas at 90-130 ºC and at pressures higher than those of the feed gas. By using warm CO2 at over 1100 psi as the stripping gas, the stripped CO2 can be returned to the liquid state just by cooling to below 30 ºC ready for disposal downhole or pipelining. No compressors are needed. Even for lower-pressure natural gas, while a liquid CO2 is not produced directly, the CO2 compression costs for liquifying are substantially reduced.
Novel/Additive Information:
The Process is entirely novel. The Presentation will enhance the understanding of the audience members of CO2 recovery in general and the Verdis Process in particular, and provide a new alternative for treating high-pressure natural gas and other difficult gases containing CO2.
Pore Scale Characterisation of Coal: An Unconventional Challenge
Authors: Mostaghimi Peyman , Armstrong Ryan T. , Gerami Alireza , Hu Yibing , Jing Yu , Kamali Fetemeh , Liu Min , Liu Zhishang , Lu Xiao , Ramandi Hamed L. , Zamani Ali , Zhang Yulai 
Published: November 2016

Abstract
Coal seam gas is an unconventional resource for natural gas that is becoming popular due to its environmental benefit and abundance. This paper reviews recent developments on the pore-scale characterisation of coal from coal seam gas reserviors. The development of micro-computed tomography (micro-CT) imaging has enabled for the 3D characterization of the fracture system in coals. This provides detailed insights into understanding flow in these unconventional reservoirs. A novel image calibration method in which the skeleton of the fracture system is obtained from micro-CT imaging while the fracture apertures are measured from scanning electron microscopy (SEM) is described. We also show the application of micro-CT imaging for studying diffusion processes in ultralow permeability matrices and discuss the incorporation of the data into calculations of gas production from unconventional reservoirs. The extraction of statistical information from micro-CT images to reconstruct coal cleat system are also demonstrated. This technique allows for preserving the key attributes of the cleat system while the generated fracture network is not limited in terms of size nor resolution. The developments of microfluidic methods for understanding the complex displacement mechanisms in coal seams are also described. These low-cost experimental methods can provide unique information about the displacement mechanisms occurring during gas production from coal seam reservoirs. Variation of coal contact angle with pressure is analysed and results demonstrate important wettability processes that occur in coal seams. We describe numerical methods for prediction of petrophysical properties from micro-CT images of coal and discuss the associated limitations when dealing with coal samples. The paper concludes by addressing the challenges faced when characterising coal at the micro-scale and approaches for population of coal data into reservoir simulators for relaible prediction of reservoir behaviour during gas production as well as CO2 sequestration in coalbeds.
Development of Next Generation High Torque OCTG Premium Connection for Extended Reach Wells
Authors: Buster Jerry , Perkins Justin , Azeredo Leonardo 
Published: November 2016

Abstract
The development and installation of production casing for the mid-range laterals (2000’ to 5000’) has typically not presented substantial problems during installation and this technology has been mastered by most operators drilling these wells. However the longer laterals (&gt;6000’) is generating industry challenges that are not an issue with shorter lateral wells. The installation of the casing string in the longer laterals is exposed to dynamic loading on both the casing and connections which may exceed the capability of commercially available connections on the market today.
This progression from the mid-range length laterals has required for connection technology to follow. Therefore these wells require an Extreme High Torque OCTG threaded and coupled Premium Connection to aid the operator to reach their target location during the installation of long lateral casing and liner sections.
These longer lateral wells that require the connection to be exposed to extreme torques, bending, and rotational loads, may render some commercially available connections ineffective to get the string to location and could leave the sealability performance to be compromised also. Depending on the well bore conditions in these wells, based on the trajectory, may impose additional loads on the connections which may not have been validated through the connection design.
Therefore connections used for these wells require to be validated for combined loading conditions with temperature, while maintaining high torque requirement in order to install the production casing. The loads are experienced during the installation process, and once the string is installed the connections will still have to provide an effective seal to support the fracturing and production life cycle of the well.
This paper demonstrates how the latest generation of those connections have been tested and validated to the extreme loads prior to being installed in the well bore. This connection has been installed in several wells and experienced the above loading conditions through the installation and production phase and has maintained sealability performance. This paper will also cover a case study from the initial well design discussion, to installation and then production phase utilized for these wells.