bluuebunny/crossref_metadata_2025 huggingface dataset:
MWD /LWD Challenges and Solutions for Drilling the Longest Al Hosn Gas Well in an Aggressive Subsurface Environment
Authors: Bijjani Patrick , Coscia Marco , Hammon Kenneth , Hoffman Toby , Langson Sidney , Orr Robert , Shah Razza , Amer Reem , Ashraf Muhammad , Hassan Hassan Ali
Published: November 2015

This paper will detail the coordination between multiple teams and across technical discipline groups to successfully drill a +28000 feet (ft.) measured depth (MD) horizontal appraisal well in a high temperature, high hydrogen sulfide and carbon dioxide (H2S/CO2) environment and acquire high quality measurement and logging while drilling (MWD/LWD) data.

Strategic tripping practices were used to reduce the risk of temperature related MWD/LWD tool failures. Extensive fluid engineering work was conducted, to design a fit-for-purpose mud system to meet Al Hosn Gas's handling requirements. Effective surface gas removal techniques were used to preserve high quality drilling mud and insure communication with the MWD/LWD tools. Hole cleaning efficiency was determined and maintained by monitoring drilling trends against calibrated models. In addition, the bottom hole assembly (BHA) drive system was designed to maximize power at the bit.

Specific drilling parameters allowed for a high rate of penetration (ROP) that effectively reduced exposure time of the down-hole tools to very high temperatures minimizing tool failures. Carefully planned fluid engineering provided constant stable mud properties, which allowed the removal of H2S/CO2, and insured adequate borehole cleaning and lubricity to alleviate torque and drag. This resulted in high quality borehole images. Lubricants to reduce torque to manageable levels were selected after exhaustive in-house testing. Similar fluid engineering practices were used to select H2S scavenger. An extension of the horizontal section beyond the directional plan was accomplished within operational limits set by Al Hosn Gas after all drilling risks were fully assessed.

Acquisition of required high quality LWD data was successfully accomplished. LWD borehole images were available only in memory mode, however, azimuthal resistivity curves helped in making geosteering decisions in the absence of the real-time borehole image data. Despite the well being drilled in the pay zone for its entirety, a measurement after drilling (MAD) open-hole log was employed to acquire missing density data that was required after a tool failure. A full petrophysical analysis was completed using the recorded memory data. It was included in the reservoir geo-cellular model and helped to define reservoir properties with a high degree of confidence.

Close collaboration and trust between all partners to continually challenge and redefine perceived technical and operational boundaries led to the successful drilling of Al Hosn Gas's longest well. All teams and personnel were aware of the challenges and developed solutions to acquire excellent MWD/LWD data in one of Al Hosn Gas's most ambitious wells, to date.
Installing Temperature Sensing Fibers into Steel Tubes
Authors: Griffioen W. , Grobety S. , Gapany L.
Published: November 2015

In pipes for oil and gas there is a need to accurately control and monitor temperatures or other parameters. Distributed Temperature or Acoustic Sensing (DTS or DAS) with optical fibers is a technique used for this. In many applications the optical fibres (or small cables) are inserted into small (few mm) steel tubes, pre-installed in or around the pipes. In this paper a technique is decribed where the fibers are floated in with water (or other liquid) under pressure. Optical fibres upcoated to 485 μm have been installed over 3 km with 90 bar water pressure. Higher pressures (and installation lengths) are possible because the fiber pay-off is placed inside a pressure tank connected to the installation equipment. By adjusting the mechanical pushing force exerted on the fiber, it can be installed with extremely low stress.
Excellence in Projects: Path Breaking Approach to Project Management
Authors: Pushkarna A. , Mathew R. , Al-Suwaidi A. S. , Malhotra U. N. , Mukhtar A. , Belbissi F.
Published: November 2015

Organizations are always looking to approach production in innovative ways that will boost the results, increase productivity, cut down slack time and increase revenue while keeping the risks of HSE failures and asset integrity incidents down to a minimum. The challenges are greater when time pressure comes into play. Consequently when an operational rig is shutdown for maintenance it becomes important to execute the project in a shortest time while ensuring uncompromising HSE, Quality and Asset Integrity standards.

NDC examined its practices and put in place an innovative process and named this initiative Excellence in Projects (EiP). Simply put the Excellence in Projects follows the typical path of planning, execution, reviewing, and then once again planning. It follows the classic Deming cycle of PDCA and translates this in project terms.

Starting with an assumption of a "perfect world" with unlimited resources in terms of funds, material and manpower, the EiP allows teams to plan a Perfect Project on paper. The requirement is to come up with a perfect time and quality output – best quality with the shortest time. The output of this ideal project is then transferred into real-life actions taking account of the actual projects constraints. The final result is the happy medium of truly achievable goals against challenging odds. The project is allowed to run and the lessons learnt are captured on completion and feed into the next project thus ensuring a continuous improvement cycle at all times.

This paper is a case study on the successful implementation of this EiP project, using set KPIs and scoring systems, yielding excellent benefits not just in time and cost saving but also Team Building, Quality, Reliability and above all HSE and Asset Integrity.
A Case Study - Achieving Substantive Reduction In Production Downtime During Major Brownfield Interventions On Oil WHTs
Authors: Thallapalli B. , Mukunda V. , El-Sawah M. , Meligy E. , Morakhia Y. C. , Madhi S. A. , Al-Balooshi M. M.
Published: November 2015

ADMA OPCO is burdened with ageing assets and maintaining their integrity is a major challenge. Replacement of subsea pipelines and WHT top side facilities is an ongoing activity, which needs to be carried out without impacting production and compromising safety. The "Portable hydraulic safety shutdown system (HSSS) " is a key enabler in implementing strategies to achieve the desired end results. This is in line with ADMA OPCO's MISSION STATEMENT – To develop oil and gas production to maximize sustainability while maintaining the highest HSE standards". The Portable hydraulic safety shutdown system (HSSS) functionally works as a Wellhead Safety shutdown system in managing temporary modifications to mitigate production losses during Brown field projects. This is of specific importance in a Junction tower, when the concept of "jumper lines" is utilized to continue with the Terminal tower/s production. The jumper line is protected by the Portable HSSS maintaining the availability & reliability of the "Jumper line" Shutdown valves.
Comparing Effectiveness Between Cemented Plug and Perf and Open Hole Ball Drop Completion Assemblies to Ensure Optimal Multistage Fracturing Treatment and Well Performance — Field Examples
Authors: Rahim Zillur , Al-Kanaan Adnan , Al-Anazi Hamoud , Kayumov Rifat , Al-Jalal Ziad
Published: November 2015

Developing gas reserves from relatively tight formations are conducted by the use of a multistage fracturing (MSF) technique that enables maximizing reservoir contact by creating multiple fractures along the wellbore. The key to successful MSF treatment is to generate independent fracture propagation and ensuring the bottom-hole treating pressure (BHTP) is maintained above the fracture closure stress (FCS) also sometimes referred to as the fracture gradient or minimal horizontal stress (σmin), for the fracture to propagate.

Both the open hole (OH) multistage (OHMS) assembly and the cased hole plug and perforation completion (PPC) methods are applied for fracturing horizontal wells. Cement behind the liner in PPC provides excellent seal and isolation between stages that cannot be achieved using either mechanical or swellable OH packers used in OHMS. Failure to maintain complete isolation between stages will not allow stand-alone fracture propagation, thereby reducing the number of originally designed fracture stages. This will reduce contact area and well performance. PPC, on the other hand, depends on manually perforating reservoir intervals and missing the sweet spot due to any misinterpretation of the OH logs will misalign the perforation gun with the reservoir section, thereby reducing reservoir contact significantly, and consequently, gas production.

The OHMS fracturing has proven very effective in the carbonate reservoirs when wells are drilled parallel to σmin and completed with swellable packers. The chances of generating individual fractures are high and the open lateral allows gas flow into the wellbore directly in addition to the production through the induced fractures. The amount of gas flow through the OH section depends on the vertical permeability and how efficiently the near wellbore section is etched and cleaned by the acid pumped.

One type of PPC, where a single interval is perforated in multiple predetermined spots in clusters has proven promising. This will be addressed as cluster PPC (CPPC) in this paper. The short perforated intervals create an orifice pressure drop at the entrance of the fracture during the treatment, keeping the BHTP above σmin, thereby keeping the fracture open. With proper geomechanical modeling, a few perforation clusters can be optimally placed in one interval so that all can be treated by a single pumping stage, with individual fractures growing from each cluster and maximizing reservoir contact. A reservoir simulation performed to prove the benefits of CPPC completions showed that it outperforms the OHMS for a wide range of permeability values. Additional cumulative production varied from just 2% for a good quality reservoir with permeability of 1 millidarcy (md) up to 26% for a tight formation with 0.01 md permeability.
Seismic Imaging in Western Zagros and Impact on Hydrocarbon Exploration: A Case Study from Kurdistan Region of Iraq
Authors: Allouche Hassan , Sapin Francois , Chevallier Bertrand , Cheriyan Thomas , Brosille Eddy
Published: November 2015

This paper presents a case study from Kurdistan Region of Iraq where the integration of a priori geological knowledge (regional understanding based on surface geology, wells) played a crucial role in improving, step-by-step, the quality of the seismic image.

A first well was drilled on the studied structure based on the interpretation of the available seismic. It failed to reach the deep targets. Indeed, the wellbore structural data showed that it was located off structure on its SW flank. These data proved how misleading the seismic image was, and provided new information to the seismic image building process. In the mean time, an infill seismic program whose parameters were designed to better capture the structural complexity was acquired.

The quality of the reprocessed images improved substantially compared to the original data, moreover the newly acquired lines lay one step ahead in terms of seismic quality: Better imaging of shallow reflectors (key for Interpretation in structurally complex environments) and better imaging of steep dips.

Reliable seismic information is key for effective exploration in foothills domains. A reliable image cannot be obtained if the process is not fed with the relevant structural information, and this is equally important at all stages, from acquisition design to imaging parameters. In new exploration domains, such an image cannot be obtained from the first attempt and is not the result of a magic box, but comes as the fruit of perseverance and patient build-up of knowledge. And this requires a closer than ever interaction between the image processor and the interpreter.
The Design and Implementation of a Full Field Inter-Well Tracer Program on a Giant UAE Carbonate Oil Field
Authors: Wang D. , Al-katheeri A. B. , Al-Nuimi S. M. , Dey A.
Published: November 2015

This paper reviews the design and implementation of a full field inter well tracer program of a giant onshore oil field in Abu Dhabi. The field is under peripheral waterflooding in order to maintain reservoir pressure and provide a mechanism to sweep the oil. However, the existence of the strike-slip fault planes juxtaposed across the reservoirs added a variable to the complexity of the waterflood management. In order to improve the understanding towards the reservoir heterogeneity and reduce the uncertainties associated with major faults, a full field water tracer program which is possibly the largest in the Middle East has been designed.

Based on streamline model, unique chemical tracers have been injected in twenty three water injectors covering all the peripheral areas and dozens of associated offset producers across the field were selected to monitor the tracer movement. The program have been designed carefully in terms of tracer selection & compatibility test, chemical volume calculation, injection well and monitoring well selection, as well as the devise of the comprehensive monitoring plan. Ultimately the results of this tracer program will be used in combination with other reservoir surveillance tools to facilitate a better management of the reservoir.

Interwell tracers technology is a valuable tool for reservoir management, however, reliable tracer data can only be obtained through judicious design, implementation and monitoring. The preliminary results from designing the tracer program include: 1) Twenty three water injectors were identified based on streamline modeling for tracer injection and dozens of producers for monitoring. 2) Injected tracers were selected based on the uniqueness, stability, detection limit and environmental friendliness, and compatibility tests were done in advance between tracers and reservoir fluids. 3) Total dilution method was used to calculate the quantity of tracers injected in each of the well. 4) A comprehensive monitoring program was scheduled to capture the arriving of the tracer as well as to depict the entire tracer wave.

The presented full field water tracer program of a giant onshore oil field is possibly the largest in Middle East, and the described designing of the program, encountered problems and best practice could be of some use to those intended planning a tracer project.
Medium Voltage Electric Heating Technology for Downhole Heating Applications and Offshore Platforms
Authors: Molnar C. , Riley M. , Trussler R.
Published: November 2015

Offshore production facilities utilize a variety of process heating equipment to help start-up production and operate efficiently. Applications include glycol reboiling, oil and gas conditioning, knock-out drum heating, molecular sieve regeneration, sea or potable water, and fuel/lube oil maintenance. In addition, oil producers have long investigated downhole and subsea heating solutions capable of decreasing viscosity, preventing wax and hydrate buildup, and providing localized heating for improved productivity. The types of heating solutions are problematic due to the large capacity and extreme environmental and process conditions involved, especially with the downhole and subsea applications. Until recently, low voltage (below 1000V) heating elements and low power heating cables have been the typical solutions for downhole and subsea electric heating applications. These traditional solutions have limitations that prevent them from significant adoption and utilization.

This paper discusses the benefits of using medium voltage technology. The focus will be on the reduction of installation, maintenance, and operational costs, as well as the reduction of electrical power consumption and line loss associated with using medium voltage technology. Also, for large heating loads, the physical size and footprint of medium voltage electric heating systems are more compact than traditional low voltage systems. This is especially relevant on newly designed platforms which provide medium voltage power distribution.

Finally, medium voltage electric heating technology opens the door for completely new solutions in downhole, subsea and offshore heating, as well as other process heating, in the oil and gas industry that were not possible before. It is important to present such innovation to the marketplace so that producers and operators are aware of new solutions to existing problems.
Formation Damage: A Novel Approach to Evaluate Zonal Productivity Loss in Horizontal Wells
Authors: Maalouf C. B. , Espinoza I. Baca , Al-jaberi S. M. , Marrauld J. Y. , Amer M.
Published: November 2015

The development of a complex oil wet carbonate green field requires an integrated data approach to characterize the reservoir and build a robust dynamic model, which will allow evaluating different development scenarios. Nevertheless, the predicted productivity of highly deviated wells is usually different from the actual values. This problem can lead to poor well completion choices and to suboptimal reservoir development plan.

To overcome the issue, the detailed analysis of downhole wellbore damages and their impact on production per zone should be evaluated. In this study, a well productivity simulation model was built to model the flow behaviour in a horizontal well and was tested against the actual production logging data. The proposed formation damage estimation is based on the integration of conventional core analysis from nearby wells with logs aquired while drilling and wireline and with data from well testing pressure transient analysis before and after acidizing. The model was used to evaluate the impact of formation damage on zonal productivity.

The proposed formation damage evaluation methodology allows reconciling between actual and expected productivities of reservoir zones across horizontal wells. A synthetic production profile with distributed drilling and acid damage skin is generated by the well model and is matched with actual production profile of a recently drilled and logged well. The results show the progression of damages through various stages of the well cycle: for permeable zones, the invasion is progressing heterogeneously while drilling and acidizing; for less permeable zones, the invasion caused by drilling might not be completely overtaken by acid stimulation. The study demonstrates the importance of drilling and well completion duration in invasion progress across the wellbore length.

The paper describes a novel methodology to construct distributed formation damages across open hole wells in carbonate reservoirs and to evaluate the effects of damages on zonal productivity. This methodology improves the prediction of well productivity by identifying the contribution of various damages to zonal productivity. This is critical for efficient decision making concerning well completions and field development options, particularly at the early stages of green field development.
Continuous Improvement Strategy to Stimulate Sustainability and Enhance Environmental Management
Authors: Vargas Cheryll Manlapaz , Scott Hannah
Published: November 2015

An oilfield services company that recognizes the value of embedding sustainability into internal business processes has elevated environmental performance by expanding its existing continuous improvement program. This paper describes the program that has been successfully implemented globally over a five-year period. It is illustrated with actual case studies that exhibit both substantial savings in energy, water and waste, alongside business cost savings.

The program covers major facilities of the company's engineering and manufacturing division. Each year, participating sites have an objective to complete a minimum of one improvement project that actively targets elimination or reduction of environmental wastes. Each project executes the Define, Measure, Analyze, Improve, Control (DMAIC) process. The steps in DMAIC are incremental and data-driven, and use applicable statistical and analytical tools to enable solutions that deliver step change impact. The Control phase specifically facilitates sustainability as it requires implementing models for preserving short- and long-term improvements. These projects are tracked in a centralized repository and undergo a standard validation process.

The program entered its fifth year in 2014, with 28 participating locations worldwide. Project initiatives have generated significant financial benefits, exclusive of environmental savings. Annually, the program has saved an average of 2 378 000 kW-hr electricity, 19 704 000 L water, and 521 t of waste eliminated, reused or recycled.

The successes of the program are communicated both internally and externally, including contributions to the Carbon Disclosure Project. Internally, the program has provided a vehicle to positively engage employees across disciplines, to share innovations, technologies and best practices for the environment. Projects resulting in facilities-related enhancements have demanded initial capital expenditure, but the return on investment is projected to continue beyond the annual timescale captured by the program. The program has stimulated forward thinking management decisions on the future and sustainability within the organization.

DMAIC is a recognized continuous improvement process that use Lean and Six Sigma techniques. By leveraging on this approach to focus on the environment, the probability of overlooking environmental opportunities is substantially reduced. Lean's systematic elimination of waste is implemented in the very literal sense. Checkpoints in each DMAIC step reduce the risk of project failure, and Six Sigma's data analysis methods enable measurable, visible results that allow the organization to track continuous improvement actions towards sustainability.
Career Development:Empowering the Business with Talent Management Tools in Effective Career Discussions
Authors: Veettil Santhosh Koyadan , Al Mehairbi Ashwaq M.
Published: November 2015

Managing one's own career has become a challenge for any employee working in organisations where the emphasis is more on anything other than individual development. The lack of right tools and awareness of those – how to place it at the right level, how to interpret and use it - among managers add to this challenge as well. Only very few organisations have a well-established and robust systems and process in place which helps an employee to manage their own career within the organisation creating a win-win situation. "Individuals working for organisations have a pressing need to manage their own careers effectively. They need to do this to progress within their current employing organisation towards more interesting, more responsible and more highly rewarded work. This is the conventional, and still often relevant, meaning of 'career'. But individuals also need to manage their own careers to make sideway moves as well. Organisations who manages these expectations effectively and create an engaging workforce will stands out from the rest". [Dr Santhosh Koyadan Veettil, Why Career Development Discussions?, Drsanmantra:Exploring Synergies. 19 April 2015 https://drsanmantra.wordpress.com/]

This paper highlights the importance of Career Conversations in organisations and how to make it effective by using the various tools of Talent Management by managers in engaging his/ her employees. Although Career Conversations happen between a manager and the employee, but rarely one may find this as a well-structured process. It rather ends up in a very casual conversation, most of the time without managing any expectations. These short conversations may help but it may fire back due to the unclear nature of the discussions and expectations. In this paper, an attempt is made to give a structure to the Career Discussion process explaining the critical components of the process.
The Combined Application Of Innovative Rotary Steerable Systems And High Performance Water-Based Fluids Enabled The Execution Of A Complex 3D Well Trajectory And Extended Horizontal Section Through A Carbonate Reservoir
Authors: Puliti A. , Maliardi A. , De Grandis G. , Molaschi C. , Arpini F. , Bussaglia L. , Paoli F. , Zauli F.
Published: November 2015

This paper describes the successful drilling of a complex 3D High Dog Leg Severity (DLS) well trajectory with extended horizontal section, achieved thanks to the combined use of an innovative Rotary Steerable System (RSS) and a new type of High Performance Water-Based Mud (HPWBM).

The well under discussion is a 6 in. side-track of an existing wellbore, drilled to optimize production in a field characterized by a carbonate reservoir. The challenge has been to reach the target and land the well in the shallowest part of the reservoir, far away from the Oil Water Contact (OWC). Furthermore, high Rate Of Penetration (ROP), smooth borehole, real time logs and good hole cleaning had to be provided to ensure optimum drilling performance while reducing the risk of wellbore stability issues.

In the past, in this field, development wells have been generally drilled with a 2D trajectory design. In addition, standard drilling fluid practices have been using low weight calcium carbonate polymer muds to drill through the reservoir. Although generally successful, this resulted in high torque and low ROP in wells with extended horizontal sections.

In the case history described in this paper, the side-track well trajectory has been planned with a DLS developed in three dimensional planes. An innovative hybrid RSS, specifically developed for high DLS applications, has been selected to drill the curve section. Moreover, a novel HPWBM has been introduced to drill the curve and the horizontal section. The use of the New Generation HPWBM has further optimized drilling performance, showing excellent results in reducing torque and increasing ROP, allowing to extend the horizontal section and maintain wellbore stability.

The combined application of the innovative RSS and New Generation HPWBM has led to an improved control of the trajectory, reducing the well path tortuosity, and has greatly enhanced drilling performance compared to offset wells in the field. The curve section has been drilled with a DLS up to 10°/30 m and landed with a 90° inclination. Then, the side-track has reached the target with an extended lateral drain of 2010 m. In previous similar experiences, high torque values determined the maximum length of lateral drains.

An average ROP of 3.8 m/h has been achieved while drilling the curve while an average 7.5 m/h ROP has been registered in the horizontal section.

The outstanding results have opened up the way to further applications with similar challenging targets and high DLS requirements.
Pore-Scale Lattice Boltzmann Simulation of Oil-Water Flow in Carbonate Rock with Variable Wettability
Authors: Li Hongxia , Yang Weilin , Huang Haibo , Chevalier Sylvie , Sassi Mohamed , Zhang TieJun , Zahaf Kamel , Al-Farisi Omar
Published: November 2015

Rock surface wettability is one of the most important factors impacting the oil recovery efficiency. Carbonate reservoir rocks show highly heterogeneous wettability, which is imposing big challenges in Enhanced Oil Recovery. Because of the complicated porous morphology and interaction between oil/water phases, the mechanism of how surface wettability affects the relative permeability is still unclear. In this work, we develop a Lattice Boltzmann method (LBM) to study the oil-water-rock interaction through systematic water-flooding simulations. Our LBM model is validated by the analytical solution of co-current oil-water flow and lab-scale microchannel oil displacement experiment. To further investigate the effect of rock surface wettability and reveal the pore-scale oil trapping mechanism, a series of water-flooding oil displacement simulations are conducted under different initial oil saturation and surface wettability conditions. For realistic pore-scale flow visualization, a 2D micro-CT image of carbonate rock in Abu Dhabi is used. Our simulation results indicate that the surface wettability has significant influence on the volume of trapped oil at the end of the recovery process; the trapped oil residue in an oil-wet pore could be 2.5 times more than that in a water-wet pore. This study is an important step toward understanding the complicated oil trapping mechanism in heterogeneous carbonate reservoirs with variable wettability conditions.
A Method to Compute Water Saturation in Tight Rocks Accounting for Conductivity of Clay Minerals
Authors: Sarihi A. , Vargas-Murillo B.
Published: November 2015

The objective of this paper is to determine the water saturation applying the Waxman-Smits equation and using mineralogy analysis obtained from XRD/CT scanning and resistivity data for a tight sandstone formation. Contrarious to using Archie's equation, the suggested approach takes conductivity into account and provides more accurate water saturation calculations, in order to correctly predict oil and gas in place. Accurate computing of the correlations between rock resistivity and fluid saturations is vital to constructing 2D and 3D models of water saturation to understand the effect of microstructure on petrophysical properties of tight formations. The negative charges on the surface of monoclinic and triclinic clay minerals, with layered silica tetrahedra in shale rocks, hold electric interactions with bipolar molecules of water and free cations. The presence of clays in tight gas sandstone reservoirs may lead to the overestimation of water saturation, if the mineralogy is not properly included into the computations. This implies that proper water saturation characterization of tight gas reservoirs could lead to an increase of evaluated hydrocarbon resources. Such an increase may be significant in large newly discovered tight rock gas bearing basins with multiple shaley-sand sweet spots.

The case study in this paper shows a computational analysis made by comparing Archie versus Waxman-Smits equations. Results from tight rock samples illustrate a proportional relationship between the clay content and the quantity of exchangeable clay. A new term, named the clay factor, Cf, has been obtained from this linear relationship, and was found that it could possibly replace the BQv term in the Waxman-Smits equation. These results show a promising workflow method to calculate water saturation considering the conductivity and fraction volume of clay minerals. As the mineralogy of a rock can be accurately identified by high resolution imaging techniques, an approach based on mineralogy, as the proposed method can be utilized as a better way to compute saturation using modification of the Waxman-Smits model. Good assessment of saturation can have a large impact in the computation of transition zones and gas resources in tight rocks, revisiting volumes that were counted as water in past models.
Deep Water Nigerian Field Challenge: Increasing ROP with Centrally Located Conical Diamond Element Saves Operator 26Hours Rig-Time, Agbami Field
Authors: Jopling Jacquelynn , Dikko Mustapha , Obot Etido Rufus , Okoro Frank , Onyia Jennifer Chioma , Gjertsen Ole Jacob , Benny Praveen Joseph
Published: November 2015

Drilling a 12¼-in hole section in the Agbami field offshore Nigeria presents a number of challenges.The section contains abrasive sandstone and shale that are interbedded with sandstone and siltstone, and all have unconfined compressive strengths (UCS) that vary across the field. The abrasive sandstone/shale section has UCS of 12,000 psi, and the interbedded sandstone/siltstone section has UCS of 15,000 psi or higher. The variation in lithology, formation strength, and abrasion/impact index make ensuring shoe to total depth (TD) runs with consistent ROP difficult because the conditions dull the polycrystalline diamond compact (PDC) bit's cutting structure, leading to a significant reduction in ROP before reaching section TD.

An operator wanted to drill the 12¼-in section from shoe to TD in a single run with a 45% improvement in average ROP compared with the four-well offset median of 38.26 ft/h.

To accomplish the objectives, the operator required a PDC bit with a differentiating drilling action designed to increase penetration rates and extend bit life in heterogeneous formations. A finite element analysis (FEA)-based modeling system was used to experiment with cutter types and their placement to improve drilling performance.

Based on the modeling work, design engineers recommended a conical diamond element (CDE) with a thick synthetic diamond layer.

The diamond layer on the CDE is approximately twice as thick as a conventional PDC cutter and exhibits 25% more wear resistance with almost double the impact strength. The element's unique geometry delivers high point loading for effective formation fracture. To fully exploit the CDE's advantages, the PDC bit body was redesigned by selectively abbreviating the blades at bit center and positioning a single CDE in the void space. The modeling system was also used to generate an operating parameter roadmap to maximize performance.

The new 12¼-in central CDE bit drilled the 2,320-ft section from shoe to TD at 92.06 ft/h, a 102% increase in ROP compared with the best offset rate of 45.64 ft/h over a 2,419-ft interval. The performance improvement, which was achieved on the first deployment of the bit in this application, reduced drilling time by approximately 26 hours, saving the operator USD 1.2 million in offshore rig time. The bit design was deployed in another well where a comparatively heavier mud weight was used, but the run still recorded an outstanding increase in ROP over the best offset.
Process Safety - A Journey Towards Excellence
Authors: Khan Shamsuddin Ahmad
Published: November 2015

Process Safety has now become one of the key topics in industry. Process safety differs from personal safety and has to be dealt differently. ADGAS has taken initiative to lead in Process Safety Management by taking different multi-directional approach. The main objective is to enhance awareness towards Process Safety and develop Process Safety Culture within ADGAS & ADNOC Group of Companies whereby mitigation & elimination of potential hazards is embedded in the attitude of every individual.
Measuring Reservoir Fluid Composition Using a Novel Continuous Contact Flash Method Based on a Microfluidic Device
Authors: Shah Mohammad Khalid , Fisher Robert , Hassan Ibraheem , Makarov Evgeny , Medvedev Oleg , Memon Afzal
Published: November 2015

Live reservoir fluid samples are flashed to liquid and gas phases at atmospheric conditions to determine the live reservoir fluid compositions. This paper describes a new flash method based on microfluidic coil for reservoir fluid compositional analysis and named the Continuous Contact Flash (CCF) method. In contrast to traditional flash methodologies, the CCF involves flashing a reservoir fluid sample through a microfluidic coil. As it passes through the coil, the fluid gradually depressurizes from reservoir pressure to below saturation pressure creating segmented gas-liquid flow. This process provides continuous contact between the gas and liquid phases during the flash resulting in equilibrated gas and liquid phases at the exit of the coil. The technique is independent of the user as the depressurization process is governed by the properties of the coil. The CCF has been tested with a range of reservoir fluids including a black oil, volatile oil and gas condensate fluid. This paper summarizes a validation study of the CCF method by comparing the reservoir fluid composition and GOR values obtained by CCF with existing flash techniques. The validation study demonstrates that the CCF is a viable technique for reservoir fluid compositional analysis and produces repeatable results. Good agreement between reservoir compositions is obtained by this technique when compared with existing flash techniques. The small footprint of the CCF apparatus is suitable for wellsite use as well as laboratory reservoir fluids analysis applications.
Integrated Methodology for Production and Facilities Analysis to Optimize Barnett Shale Gas Production - A Case Study
Authors: Ahmed A. A. , Dwivedi P. , Ardila M.
Published: November 2015

The Barnett shale is one of the most prolific gas reservoirs in United States and its success has continued into 2015, with the latest data showing that total gas production in the region is now about 5 Bcf/D. However, operators are increasingly aware that the productivity rate of Barnett wells shown to decline by an average of 70% in the first year. Additionally, as the result of the current down energy market it is necessary to implement new methodologies to sustain and optimize the production moving from the quantity of the wells to the quality of the production, from drilling more wells to enhance the production from the existing wells. To achieve this goal; it became crucial to choose the optimum artificial lift techniques and to use the right dose for chemical treatments that that work best in the Barnett to draw the well with minimum investment to maximize the cash flow.

This paper illustrates the results of using an integrated methodology to evaluate and optimize the gas production for a brown field located in Dallas-Texas, USA. The methodology included a detailed field/wells production evaluation, optimization of the artificial lift system and design, review of the facilities configuration, identification of the flow challenges such as liquid loading, high line pressure and also down time management, Finally the study considered the economical evaluation for high lease operating expenses (LOE) wells. To make the work scalable and sustainable and to help engineers to be aware of any operational variance in timely manner two tools were implemented: 1) an artificial Lift screening methodology and 2) a surveillance tool for tracking the operational key performance indicator (KPIs) and containing an alarm system tool for spotting the variance.

Out of 150 wells considered for this study, 94 wells have been identified for production optimization to obtain production enhancement. A set of seven wells has been taken as a pilot test covering two initiative; well cleaning and utilizing compressor to reduce the well head pressure. The results were as expected. Two wells under well cleaning show a 100 % increase in production because of the reduction in bottom hole pressure and achieving high draw down. The other five wells, under compressor initiative; show an average increase in production by 14 %. Additionally, the target is to reduce the number of the compressors by 25% using the proper artificial lift system and reduce the LOE by 10%.
EVO Series 1.0 - Latest Generation of UT Crack and Corrosion Tools For High Speed Pipeline Inspection
Authors: Hennig T. , Lokwani G.
Published: November 2015

Intelligent inline inspections (ILI) are widely used to guarantee a safe operation of pipelines. The inline inspection provides reliable data in an economic way. Ultrasonic (UT) is currently the most accurate and reliable In-Line Inspection technology available in the market. These UT ILI Tools record data while travelling through the entire pipeline from Launcher to Receiver. In most cases, the Pipeline Operator does not need to make major adjustments to their pipeline. Nevertheless, pipeline operators may have to adjust medium flow rates to accommodate optimum inline inspection conditions, e.g. down to 1m/s.

NDT Global recently introduced the latest generation of UT tools - EVO SERIES 1.0. This generation offers inspection velocities of up to 4m/s. These high speed tools overcome reduction of flow rates for intelligent inspection runs. In addition, these high speed tools also offer the highest axial resolution available at the market (0.75mm) and circumferential resolution of 4mm, providing excellent input for accurate pressure calculations, e.g. based on Riverbottom and crack depth profiles or even 3D Finite element modeling.

The authors will present basic background information about ultrasound inspection technologies. Theoretical aspects of EVO Series 1.0 tools are discussed for crack and wall thickness inspections followed by a case study performed in a real pipeline. Furthermore, EVO generation offers capabilities of combining different technologies in one tool. One single inspection tool with corrosion and crack transducers enables pipeline operators to operate their system safely with a minimized impact from ILI.
Project Management Office: The Strategic Trend In Petroleum Industry
Authors: Al Ahmad A.
Published: November 2015

Objectives/Scope

Project Management and project execution in Oil & Gas industry have evolved extensively in the last decade; processes have taken a holistic approach rather than a mechanical one. The tendency today is to establish a centralized and strategic project core office to provide management with sound business recommendations and direct teams in the resolution of decisions in mega projects executions; this office is known as (PMO), Project/Program Management Office.

Methods, Procedures, Process

Many researchers, academics, and practitioners agree that a well-established and mature PMO ensures competence, credibility, and serves as a hub for project management and control. Surveys claim that the number of organizations with an established PMO has increased from 47% to 77%, while other studies suggest that 70% of established PMO closes in 2 to 3 years of their initiation. Accordingly; this presentation outlines the different types of PMO's and their benefits, it explains why do PMO's fail? It also displays methodology to ensure a PMO survival and ultimately. It discloses the prerequisites and the transition of a well-established PMO into a strategic office in the organization.

Results, Observations, Conclusions

This technical presentation addresses the purpose of PMO; how it is established? Its benefits and stakeholders expectations of this office involvement in project executions. Initially, the application of project management practices was the responsibility of a Project Support Office; a unit within the organization dedicated for projects execution. The mandate of this office was limited to accomplishing a specific shareholder's mission or "a project". Management expectations stretch today beyond the usual execution of projects and definition of success through the traditional golden triangle (quality, cost and time). Management are in pursuit of the establishment of a new generation PMO that is characterized as command center with established best practices, procedures and processes to ensure governance and to administer all project management activities within the projectized or operational organization. Their aim is to build a strategic office that promotes common language within the organization and serves as strategic alliance in the business decision making process. Finally; the effectiveness of the strategic PMO and its long survival is warranted by organizational attitude towards setting and achieving strategic goals.

Novel/Additive Information

A Strategic PMO is a rank achieved among successful PMO's, organizations find answers to a whole spectrum of business challenges and long term strategies. In conclusion; this paper dedicates lessons learned and experience from petroleum industry worldwide, bringing stories of pioneer organizations properly implemented strategic PMO. Strategic PMO's achieved success stories that I am privileged to share their stories with colleagues in the Oil and Gas industry.
Advances in Reservoir Management and Surveillance for a Giant Carbonate Reservoir
Authors: Al-Marzouqi M. A. , Owens J. D. , Tee A. , Khan S. A. , Al-Muhairi S. S. , Al-Hosani L. E. , Al Henshiri M. Y.
Published: November 2015

Significant advances in reservoir management have been achieved in recent years to address the many challenges in managing giant carbonate reservoirs. The advances are made possible due to culmination of three key elements working in harmony: Work Processes, Technology and People. Three major advances mentioned in this paper underpin this all important truth in reservoir management and surveillance. First is the development and implementation of a framework of recommended Integrated Reservoir Management Practices with detailed and structured multi-disciplinary workflows. Information Technology plays a key role in all these workflows via automation, data integration and visualization. Second is a new generation data integration and analysis tool facilitating data and work flow integration and providing a common platform for intelligent and interactive display, thus promoting collaboration to achieve synergistic benefits. Third is the application of advanced simulation-based streamline techniques whereby new technology and workflows are deployed, with full collaboration among stakeholders.

The Integrated Reservoir Management Practices include a set of highly interactive workflows set in a continuous improvement loop: Data Gathering Requirements, Data QC/QA, Data Analysis, Integration and Visualization, Opportunity Generation, Execution and Monitoring. ZADCO is following these workflows with significant improvement in work efficiency and results. In the collaborative environment, open communication and sharing of knowledge is strongly encouraged among stakeholders to assess the problem from different perspectives. This often results in creative solutions being developed. The new generation integration tool further facilitates collaboration as it retrieves data from reservoir static and dynamic models, surveillance data such as cased-hole logs and pressure data, and displays them for interactive work sessions, including animated display to give extra insight on time dependent data. The streamlines enable model-based well allocation factors (WAFs) to be calculated to supplement analytically derived WAFs, guiding injection optimization and thus resulting in improved reservoir management.

These advanced workflows and tools have helped ZADCO to make timely and informed decisions, resulting in significant savings to the company, and at the same time improving understanding of reservoir behavior and facilitating optimization of ongoing development plans. The advanced workflows and tools have been recognized by Shareholders as game changers greatly needed to better manage the complex giant carbonate reservoir.