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Keywords: upstream oil & gas
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Proceedings Papers
Publisher: Society of Petroleum Engineers (SPE)
Paper presented at the SPE/IADC Middle East Drilling Technology Conference and Exhibition, January 29–31, 2018
Paper Number: SPE-189366-MS
... control needs as well; this latter will be explained in detail. Upstream Oil & Gas deviation ECD drilling mud well control annular space mud weight conventional drilling Drilling drilling operation circulation pressure loss APL wellbore annular pressure drilling Simulation...
Abstract
The technique of drilling a wellbore by using casing instead of drill pipe (Casing Drilling-CD) is gaining in relevance within the Oil & Gas sector since its implementation in the last decades. This technique, aside from the evident reduction in drilling time and costs observed whenn applied is convenient to minder the effects of certain while-drilling issues as those arising while drilling unstable formations. The focus of concern in this work will be the geometry-related aspects of Casing Drilling influencing not only the drilling operation itself but its particular well control needs as well; this latter will be explained in detail.
Proceedings Papers
Publisher: Society of Petroleum Engineers (SPE)
Paper presented at the SPE/IADC Middle East Drilling Technology Conference and Exhibition, January 29–31, 2018
Paper Number: SPE-189304-MS
... selection and formulation annular pressure drilling modeling pipe drilling fluid property drilling fluid formulation pressure change velocity profile drilling fluid chemistry drilling fluids and materials Upstream Oil & Gas flow behavior index swab pressure equation power law fluid...
Abstract
Accurate numerical modeling of surge and swab pressures in concentric annuli is proposed. The numerical scheme is developed for the laminar flow occurring during the drillstring axial movement. The model incorporates Yield Power Law (YPL) fluids, which is a good representation of the most of the drilling fluids. A commercial computational fluid dynamics (CFD) package is used to validate the developed numerical model. Also, the mathematical model and CFD analysis are compared with the existing models from literature. A high order finite difference numerical model is developed that accurately captures the physics of laminar flow due to surge and swab phenomena in concentric annuli. The numerical scheme is prepared such that it accounts for both Newtonian and non-Newtonian fluids. YPL model is incorporated in the proposed scheme, and it accurately estimates the drilling fluid behavior in both high and low shear rates. CFD analysis is conducted using a commercial software to validate the accuracy of in house developed numerical model. The velocity profiles across the annulus are compared in order to verify the precision of the model. The proposed model for the surge and swab pressures is more accurate than narrow slot approximation model which is most commonly used in the drilling industry. With this proposed modeling, the physics of surge and swab pressures are better captured, because it accounts for the effect of curvature in annular geometries. The model is well-validated with the CFD analysis and the velocity profile comparison of the numerical solution and CFD analysis yields less than 5% average absolute percent error. With this work, dimensionless velocity profiles are presented which better explain the flow during surge and swab in concentric annuli, while the inner pipe is reciprocating in steady-state. Pulling out or running tubulars in the vertical section, or running casing with centralizers approximates the position of tubular to concentric. It is very important to accurately calculate these pressure losses to avoid fracturing the formation or having an influx from the formation. Therefore, CFD analysis and mathematical modeling of surge and swab pressures presented in this study has potential to optimize the tripping operations that will help avoid hole problems.
Proceedings Papers
Publisher: Society of Petroleum Engineers (SPE)
Paper presented at the SPE/IADC Middle East Drilling Technology Conference and Exhibition, January 29–31, 2018
Paper Number: SPE-189374-MS
... guidances for hydraulic fracturing on field. Artificial Intelligence Upstream Oil & Gas Modeling & Simulation perforation parameter diameter Completion Installation and Operations coplanar perforation hydraulic fracture initiation fracture initiation hydraulic fracturing cement...
Abstract
Coplanar perforation is a new perforation technology with unique perforation position that can improve the efficiency of hydraulic fracturing of horizontal wells in low permeability reservoirs which have low porosity, low permeability and are difficult to explore. So it is important to know how fractures initiate and propagate as well as the optimal perforation parameters. A large-scale true tri-axial hydraulic fracturing simulation experiment is conducted to study fracture initiation characteristic and propagation pattern of coplanar perforation in horizontal wells under different in-situ stresses, compared with conventional helix perforation in horizontal wells under the same in-situ stresses. In the meantime, the three-dimensional finite element method is used to study the influences of different perforation parameter combinations set according to field data on fracturing pressure in horizontal wells, including shot length, shot diameter and shot density. The experiment results show that the coplanar perforation has simpler fracture propagation pattern under higher stress difference and has following advantages compared to conventional helix perforation: (1) reducing the fracturing pressure, (2) controlling the fracture propagation to reduce the complexity of near-wellbore fracture and (3) reducing the near-wellbore friction resistance. The numerical simulation results show that: (1) the fracturing pressure does not decrease linearly as the shot density increases, it falls rapidly when the shot density increases from 9 to 15 holes per meter, but when the shot density increases from 15 to 21 holes per meter, it falls slowly and finally remains almost constant, (2) the fracturing pressure decreases as the shot diameter increases, and (3) the fracturing pressure stays the same as the shot length increases. Through the conclusions of experimental and numerical simulation, we could provide some valuable suggestions to the hydraulic fracturing on filed. During hydraulic fracturing process in low permeability reservoirs, coplanar perforation technology with high shot density (21 holes/m) and large shot diameter (0.03m) should be used. The experimental and numerical simulation conducted in this paper show a real process of hydraulic fracturing with coplanar perforation. The advantages and optimal perforation parameters of coplanar perforation are proposed to give guidances for hydraulic fracturing on field.
Proceedings Papers
Publisher: Society of Petroleum Engineers (SPE)
Paper presented at the SPE/IADC Middle East Drilling Technology Conference and Exhibition, January 29–31, 2018
Paper Number: SPE-189367-MS
... drilling processes like drilling with casing. casing and cementing tubular connection drilling operation lubricant seal surface setting casing Upstream Oil & Gas pressure distribution contact pressure distribution fluid tightness integrity application MTM seal proprietary tubular...
Abstract
As a significant contributor to Well Integrity, the use of Premium Connections has increased in modern oilfield developments, where combined mechanical loading and a growing need for fluid tightness are becoming more common than before. This type of "specialty connectors" feature a metal-to-metal seal (MTM) which assures enhanced fluid tightness by means of distribution of contact stress generated during the make up process. In applications in which high amounts of torque or where rough field handling are the norm (e.g. Casing Drilling), the risk for damage at the MTM are big enough to put at risk the integrity of the well against leakage events. By means of understanding the mechanical and tribological aspects impacting the performance of such connectors a better understanding of their importance can be given, at the same time well defined areas of opportunity can be identified in the context of challenging drilling processes like drilling with casing.
Proceedings Papers
M.. Mofti, M.. Al-Othman, A.. Alboueshi, J.. Davis, W.. Eid, A.. Allam, A. Al Hamad, S.. Sadeddin, A.. Buhamad, M.. Ashkanani, S.. Aloun, M.. Al-Haddad, H.. Al-Mehanna
Publisher: Society of Petroleum Engineers (SPE)
Paper presented at the SPE/IADC Middle East Drilling Technology Conference and Exhibition, January 29–31, 2018
Paper Number: SPE-189353-MS
... procedure Injection Rate multistage acid international association of drilling contractors horizontal well completion application bahrah field Upstream Oil & Gas successful application crosslinked gel gel carbonate formation reservoir fracture operation BHTP Abstract Throughout...
Abstract
Throughout the last few years, oil company strategies have moved toward recovery of the maximum oil in place from mature fields and reservoirs that were previously considered technically challenging. The Mauddud formation in the Bahrah field is a low permeability carbonate formation with moderate to high oil viscosity. Viscosity is between 2 and 7 cp at 170°F, but a 90-cp viscosity at surface conditions is commonly observed once a well is placed on production, creating challenges for a vertically drilled well that could not provide necessary levels of sustainable production. In an attempt to achieve economic continuous production, a 3,000-ft lateral horizontal well was drilled. The lateral length was designed as an optimal solution for such a challenging reservoir to help sustain the production flow. Additionally, a multistage acid fracturing (MSAF) treatment was performed. This paper discusses the design, execution, and production of the first MSAF treatment performed in the Mauddud reservoir using a cased openhole completion with swell packers and sliding sleeves that were placed in seven stages across the 3,000-ft lateral interval. Post-operation analysis exhibited highly sustained production, creating a shift in oil company plans toward drilling new horizontal wells and applying MSAF treatments to move the Bahrah field into the development phase. Results obtained from this operation were effectively used to help improve production in similar mature formations. Based on this pilot treatment, a wide-scale field development strategy was planned, and many wells were drilled, completed, and fractured similarly in Bahrah field.
Proceedings Papers
Qishuai YIN, Jin YANG, Bo ZHOU, Menglei JIANG, Xiaoliang CHEN, Chao FU, Li YAN, Lei LI, Yatao LI, Zhengli LIU
Publisher: Society of Petroleum Engineers (SPE)
Paper presented at the SPE/IADC Middle East Drilling Technology Conference and Exhibition, January 29–31, 2018
Paper Number: SPE-189330-MS
... breakdown machine learning Bayesian Inference Efficiency international association of drilling contractors normal distribution artificial experience model exploration drilling operation mathematical statistics data mining Upstream Oil & Gas recognition drilling operation efficiency society...
Abstract
Today's data is tomorrow's oil and gas. Only the data can tell us right or wrong, but not the experience or feel. The real-time logging data conforms to the 6V features of the Big Data (Velocity, Variety, Volume, Veracity, Visualization and Validity). As a result, the drilling operations efficiency is significantly improved by the Big Data mining of real-time logging. The Big Data mining helps recognize the drilling operations automatically and identify the invisible non-production time (INPT). Firstly, the real-time logging data is acquired by the comprehensive logging unit. Secondly, the drilling operations are recognized by applying restrictions to drilling parameters. Thirdly, the daily time and the total time is breakdown based on the above logging data and operations categories. Finally, the INPT is identified by setting the target value based on the Big Data mining and learning curve. The savings potential, which is determined by the average and target, is critical to improve the operations efficiency. On one hand, the Normal Distribution is established by setting the specific operation time (such as slips connection time, etc.) to the X-axis and the operation count to the Y-axis. The average and covariance of the Normal Distribution is calculated. On the other hand, the target value is based on the Big Data mining by the Bayesian network model and the total-time learning curve of batch wells. As a result, the real-time drilling efficiency can identify the best-performing operations, crews and rigs. The crew-based operational performance comparisons are effective to identify the best-performing crews and to indicate where best to focus training and crew supervision efforts in the future. And the real-time drilling efficiency can measure the rig performance in order to make INPT visible. At last, the real-time drilling efficiency yields cost and time savings on both deep-water and complex wells. The method is successfully applied to BD gas field in Indonesia which is HTHP and LW oil field in South China Sea which is in deep-water. Application shows the INPT represents about 32%. The Big Data mining of real-time logging significantly improve the drilling operations efficiency, detect and minimize the INPT. As a result, the Big Data mining yields cost and time savings for tomorrow's market.
Proceedings Papers
Ahmed Abdulla Mutawa, Abdalla Youssef ElBarbary, Fernando Quintero, Abdul Salam Awad, Moutaz Faysal Khaled, Mohammad Kamel Al-Mansi
Publisher: Society of Petroleum Engineers (SPE)
Paper presented at the SPE/IADC Middle East Drilling Technology Conference and Exhibition, January 29–31, 2018
Paper Number: SPE-189362-MS
... in a well (from the surface to the TD of the well) distributed along the fibre optic line at any time. Several challenges were anticipated and measures were taken to minimize the risks of such implementation to ensure smooth deployment successfully. real time system Upstream Oil & Gas...
Abstract
Permanent down Hole Gauges (PDHGs) are typically run in combination with Distributed Temperature Sensing (DTS) cable with Wellbore Segmentation using Swellable Packers. The interpretation of the signals of the DTS/PDHG is complex, but it provides the possibility to identify change in production / injection profile along the completion and changes to the composition of produced fluids. Permanent down Hole Gauges (PDHGs) is a system enables the user to measure the reservoir pressure and temperature at single fixed point on real time basis. Distributed Temperature Sensing (DTS) is a technology which provides the user with a technique to measure the temperature in a well (from the surface to the TD of the well) distributed along the fibre optic line at any time. Several challenges were anticipated and measures were taken to minimize the risks of such implementation to ensure smooth deployment successfully.
Proceedings Papers
Publisher: Society of Petroleum Engineers (SPE)
Paper presented at the SPE/IADC Middle East Drilling Technology Conference and Exhibition, January 29–31, 2018
Paper Number: SPE-189339-MS
.... drilling fluids and materials circulation flow rate fiber cement casing design Upstream Oil & Gas concentration fiber concentration drilling fluid management & disposal casing and cementing circulation zone Dammam formation well control fiber cement slurry downhole loss annular...
Abstract
The giant Iraqi Zubair oilfield is a hotspot for drilling activities. Many vertical and directional wells have been recently drilled in this oil field. Losing cement slurry into karstic facies of the Hartha formation is the main challenge on most wells. Achieving required top of cement behind the intermediate casing is a critical challenge because this casing is the main barrier against the corrosive sulfurous water of the underlying Um Er-Radhuma and Tayarat formations. In this field, in spite of the tremendous time and effort that have been spent to mitigate losses while drilling and before cementing, at least 55% of wells experience losses while cementing. Various conventional treatments have been implemented to bring cement to the surface in primary cementing operations, including one stage with lead and tail slurries and two stages with two cement slurries (lead and tail) for the second stage. Even when ample amount of extra excess of cement has been used for the second stage to compensate for the cement lost during first stage, there was still a need for top jobs subsequently after the cement job. Recently, the field applications of fiber cement have shown substantial success compared to the case of using only cement slurries as lost circulation material. This was confirmed by getting returns when displacing cement across the lost circulation zone (Hartha formation) in five out of six wells. The cement jobs of the six wells have been revised, and use of fiber cement has now become a standard practice for cementing the intermediate casing strings in this field. In addition to presenting six case studies in the use of fiber cement, this paper describes the previous efforts at solving the problem and the success criteria. This paper also discusses the mechanism and the properties of using fiber within cement slurries for curing lost circulation while cementing in fractured formations. Laboratory tests were conducted to evaluate the plugging efficiency and the magnitude of the developed compressive strength.
Proceedings Papers
Oleksandr Spuskanyuk, Saad Mumtaz, Amr Mahmoud, Chee Lam Gan, Walid M. Abdulhai, Edward Jason Wheatley, A.. Salim, David Khemakhem
Publisher: Society of Petroleum Engineers (SPE)
Paper presented at the SPE/IADC Middle East Drilling Technology Conference and Exhibition, January 29–31, 2018
Paper Number: SPE-189311-MS
... mould materials and corrosion well integrity repair method flowline corrosion Subsurface Corrosion Conductor Artificial Intelligence Upstream Oil & Gas conductor pipe wall thickness cofferdam Welding cement corrosion rate operation structural integrity clamp conductor guide...
Abstract
Exposure of offshore wells to marine environment may lead to significant corrosion of a conductor pipe and deterioration of its ability to carry well loads up to the point of well collapse. In order to ensure a safe operation of the well throughout its expected lifetime, a comprehensive well assessment, surveillance and maintenance program should be put in place to ensure long-term structural integrity of the wells. Several steps in assessing structural integrity of conductors have been developed and implemented: qualitative assessment to determine a general structural condition for wells; quantitative assessment by detailed Ultrasonic Testing to measure metal thickness from splash zone to wellhead; evaluation of corrosion effect on structural integrity using physics-based assessment involving detailed structural modelling and 3-dimensional finite-element analysis. It was demonstrated that the minimum mean wall thickness of the corroded pipe can be used as a measure to determine critical loads, which then allowed defining operational criteria for the conductor based on its measured metal thickness and typical expected well loads. The limits of acceptable conductor corrosion have been established for all offshore wells in the company. Several hundreds of wells were UT-scanned and a number of them needed to be repaired. All wells were scheduled for blasting and painting to prevent or slow down the external corrosion of the conductors. Annuli between the conductor and the surface casing were topped up with cement to take advantage of the additional strength and lateral stability provided by the cement and to slow down the internal corrosion of conductors and the external corrosion of surface casing. Structural integrity risks for all wells in the company were assessed and wells were categorized based on the risk matrix. Two types of risk categories included the higher risk wells to be repaired immediately and high-medium risk wells with repair decisions depending on business impact. Several innovative cost-effective rigless repair solutions were selected to re-establish full structural integrity of wells, three of which were successfully completed. Most repairs were performed without the need of a well shut-in, thus preserving significant production and injection volumes. The repairs were largely executed above the splash zone with a remote access to sub-sea areas of conductors, which eliminated or minimized diving operations and weather dependency. As a result, structural risks have been eliminated or significantly reduced by completing 100% repairs of all higher risk and several high-medium risk conductors using novel cost-effective rigless and diverless repair techniques. In addition, the life of existing wells was extended, and plug and abandonment operations were deferred. Future plans include enhancements in metal thickness measurements, improvements in surveillance, testing and further consideration of additional repair techniques and development of new methods in structural integrity assessment.
Proceedings Papers
Publisher: Society of Petroleum Engineers (SPE)
Paper presented at the SPE/IADC Middle East Drilling Technology Conference and Exhibition, January 29–31, 2018
Paper Number: SPE-189369-MS
... Upstream Oil & Gas drilling mud system mud system graft copolymer international association of drilling contractors shale sample permeability Drilling fluids basically play a vital role while drilling any natural oil & gas wells. Generally there are types of drilling fluids available...
Abstract
The major problems associated with shale formation when it interacted with water based mud are borehole instability. This Wellbore instability may be due to swelling and dispersion of clay present in shale and also leads to other well problems like pipe sticking, hole enlargement, improper rheological & fluid loss control properties, and additional reaming etc. In this research paper an attempt has been made to evaluate the feasibility of synthesized graft copolymer in the formulation of water based mud system for challenging formations. The microwave irradiation technique has been adopted for synthesizing PAA/AMPS-g-Sesbania gum copolymer. Further, it was processed in the formulation of mud system. The remarkable rheological and filtration properties of the mud system have been seen with synthesized additive. The developed mud has possessed strong pseudoplastic behavior which is a desired property of any mud which has been observed from shear rate vs. shear rate curve. In addition, shale stabilization properties were investigated with shale rotability test on the synthesized core sample prepared in the laboratory. Moreover, percentage reduction in permeability (i.e., formation damage effect) has been found lesser in developed copolymer system co paring to conventionally used PHPA system. Hence, the formulated mud system can be used as a potential drilling mud system for drilling any oil wells.
Proceedings Papers
Publisher: Society of Petroleum Engineers (SPE)
Paper presented at the SPE/IADC Middle East Drilling Technology Conference and Exhibition, January 29–31, 2018
Paper Number: SPE-189349-MS
... mud system shear stress drilling fluid chemistry drilling fluid formulation viscosity viscometer mud sample frictional pressure loss sepiolite clay drilling fluid selection and formulation Upstream Oil & Gas conventional viscometer lignosulfonate mud rheological behavior sepiolite...
Abstract
Thermal rheological properties of three drilling fluids suggested for hot environments were experimentally investigated using both HTHP dynamic rheometer and classical viscometer. Two of them were polymer based muds commercially used in geothermal drilling, and the third one was sepiolite base mud prepared with specially mixing order in this study. Rheological measurements at six different shear rates were performed in a programmed temperature range of 100 to 500°F with 10°F increments at a 700 psi of pressure differential. Flow characteristics of sample muds in a given well geometry were also considered using a numerical application. Two polymeric muds sampled from a geothermal field in Turkey exhibited very low viscosity with a low thermal viscosity variation interval at temperatures above 300°F. In contrary, the sepiolite mud demonstrated higher viscosity and kept its stability with increasing temperatures up to 500°F. Findings also indicated remarkable viscosity differences between the conventional viscometer and the dynamic HTHP rheometer. Hydraulic optimization in terms of circulation pressure losses, cutting transport, and surge and swab pressures were numerically modelled. Optimization results based on conventional viscometer measurements generated noticeable errors causing difficulties through drilling program. Numerical application revealed that the usage of improper viscosity values resulted in calculation of well design parameters beyond the safe drilling limits. Through this study, it was revealed that sepiolite based muds could be good candidate for drilling hot and/or hostile wells such as deep oil and gas wells, geothermal wells, and drilling through high saline formations. As excessive temperature through wellbore can lead to serious well problems, selecting thermally stable mud with proper rheological properties to improve penetration rates, hole cleaning properties, and borehole integrity can clearly express the importance of this study.
Proceedings Papers
Publisher: Society of Petroleum Engineers (SPE)
Paper presented at the SPE/IADC Middle East Drilling Technology Conference and Exhibition, January 29–31, 2018
Paper Number: SPE-189331-MS
... drilling fluid chemistry drilling fluid property Upstream Oil & Gas surge pressure formation pressure swab pressure sensitivity analysis pipe speed hydrostatic pressure drill string society of petroleum engineers turbulent flow equation It has been stated by many researchers and...
Abstract
Pressure changes due to surge and swab has been a concern in the drilling industry for many years. The fast and sudden movement of the drill string while pulling out of hole causes the wellbore pressure to decrease. This is due to the frictional forces between the pipe moving upward and the drilling mud that is stationary, which is known as the swab pressure. The opposite is also true, moving quickly inside wellbore will cause the pressure to increase, and this is known as the surge pressure. If these pressure changes become very high, the formation might get fractured which introduces influx leading to a kick. In severe cases, this kick might lead to a blowout which endangers human lives and environment. This article focuses on the fundamental theory of surge and swab in addition to the maximum pipe running speed that avoids surging and swabbing the well. Further, calculations are carried out to optimizing the maximum pipe tripping speed by employing different parameters as input values. Both laminar and turbulent flows are considered in addition to closed ended pipes since it is the most critical one. The objective of this study is to optimize the drilling parameters that specify the maximum pipe tripping speed with different hole's sizes and pipe dimensions. Moreover, this research offers the optimized values to identify the factors that heavily affect surge and swab pressures. The results show that annular space and bottom-hole assembly (BHA) length have significant effects on surge and swab pressure values. Sensitivity analysis shows that pipe size and mud rheology impacts surge and swab values, but not significant. In fact, it is the annular velocity which is heavily affected by BHA length and size. When it comes to casing, the size was not an issue because the annular space is larger compared to smaller casing sizes. In addition, study shows that depth plays vital roles that can be seen with smaller casing sized. This study will enhance the understanding of drilling problems while drilling due to surge or swab pressures.
Proceedings Papers
Hocine Khemissa, Zohaib Channa, Salman F. Nofal, Kevin Dean McNeilly, Ali AL-Felasi, Laila Sayed Al-Mazrooqi, Salama Darwish Al Qubaisi, Latifa Ali Al-Shamsi
Publisher: Society of Petroleum Engineers (SPE)
Paper presented at the SPE/IADC Middle East Drilling Technology Conference and Exhibition, January 29–31, 2018
Paper Number: SPE-189376-MS
... drilling operation stimulation horizontal drain Directional Drilling dual oil producer sidetrack dense zone formation society of petroleum engineers hazard acid stimulation case study lithology Upstream Oil & Gas dense formation Abu Dhabi landing point well path evaluation log...
Abstract
The company vision development plan to capitalize on oil production, sustainability, maximise recovery and as cost effective to reduce number of wells to be drilled requests to drill extended horizontal drains (Oil producer and water Injector). Subsurface well location optimisation, focus in detail on targets location and the related risks. The present offshore case study, demonstrate furthermore how important to study in detail all hazards along the well path, such as lithology of side-track formation. The risk of well bore stability, collapse is very high in such formation. Subsequently, in case of collapse or drop of scratched portion of rocks, the horizontal drain will be plugged and cease to produce. This case study, demonstrate how this event happens and adequate solution was successfully applied. To efficiently perform the proposed plan, and develop multilayer geological units with poor to moderate limestone, a detailed reservoir study was performed including all subsurface team and drilling division. It was proposed to drill and complete wells as extended horizontal drain (+3000 ft.), with several designs: multilateral drains or step down 6″open hole. The first planned well was dual oil producer, two targets, one deviated and the second 6 inch horizontal 3000 ft. length. Feasibility with drilling engineer was performed to study all drilling parameters, drilling hazards, logging requirement, geosteering, equipment preparation and simulation for acid stimulation was showing easy to be executed with barge.
Proceedings Papers
Publisher: Society of Petroleum Engineers (SPE)
Paper presented at the SPE/IADC Middle East Drilling Technology Conference and Exhibition, January 29–31, 2018
Paper Number: SPE-189306-MS
... resulting from this study can be used as cost-effective tools when planning for future neighboring deviated wells to create better drilling efficiency by reducing the nonproductive time and well costs. Wellbore Design orientation Reservoir Characterization Upstream Oil & Gas failure criteria...
Abstract
The Zubair Formation is the most prolific reservoir in Iraq, which is comprised of sandstones interbedded with shale sequences. Drilling deviated boreholes in this formation has always been a challenge due to the weak nature of the shale sequence. Historically, over 90% of wellbore problems in the Zubair Formation are due to wellbore instability. These wellbore instability problems, such as hole collapse, tight hole, stuck pipe, and sidetracks results in increasing the nonproductive time (NPT) and well costs. The present study aims to construct a calibrated post-drill 1-D mechanical earth model (MEM) that can be used to conduct a comprehensive geomechanical analysis of the Zubair Formation. A practical methodology was detailed for (1) constructing the 1-D MEM by using data from several open hole logs and (2) calibrating such a model using all the available data (e.g., observations of wellbore failures, measurements of well testing, laboratory test results of rock mechanical properties, etc.). Three failure criteria (i.e., Mohr-Coulomb, Mogi-Coulomb, and Modified Lade) were used to perform a root cause analysis of borehole breakouts and to address the minimum required mud weight to minimize wellbore instability-related issues for different well trajectories. The wellbore failure analysis showed that the mud weight, that was used previously, is insufficient to support the rock on the wellbore wall, and it is not appropriately adjusted according to the variation in the wellbore azimuth and inclination. In addition, the heterogeneity of the Zubair Formation and the inappropriate drilling practice have magnified the severity of the drilling problems. The predictions resulting from this study can be used as cost-effective tools when planning for future neighboring deviated wells to create better drilling efficiency by reducing the nonproductive time and well costs.
Proceedings Papers
Publisher: Society of Petroleum Engineers (SPE)
Paper presented at the SPE/IADC Middle East Drilling Technology Conference and Exhibition, January 29–31, 2018
Paper Number: SPE-189341-MS
... Oil & Gas continuous improvement stakeholder execution Wd Pg Drilling Process Stage project management pg process Implementation wd pg process integration Kuwait Oil Company (KOC) launched a Project Gate System (PGS) program in 2010, which resulted in the development of the KOC...
Abstract
Kuwait Oil Company (KOC) launched a Project Gate System (PGS) program in 2010, which resulted in the development of the KOC PGS Process. The PGS Process was implemented in 2012, and has been applied to surface facility capital projects only. However, subsurface projects were excluded from the PGS, at that time. In order to also improve the drilling of wells and facilitate the attainment of forecasted production targets efficiently and on time, a study of the development and implementation of a similar PGS Process for the delivery of wells was requested, in 2013. The study concluded that a parallel Well Delivery PGS (WD PGS) Process should be developed based on IOCs’ and NOCs’ best practices for well delivery, KOC's experience with the PGS Process, and the fit-for-purpose requirements of the concerned KOC stakeholders in all business Directorates.
Proceedings Papers
Ahmed El Hawy, Mahesh Shrichand Picha, Fathy Soliman, Patrick A Haeser, Moosa Al Hadhrami, Adil Al Kindi, Mounir Eljenni, Is'Haq Habsi, Ibrahim Al Busaidi, Adil Zahran Al Busaidi, Magdi Bazara, Ahmed Sadig Omara
Publisher: Society of Petroleum Engineers (SPE)
Paper presented at the SPE/IADC Middle East Drilling Technology Conference and Exhibition, January 29–31, 2018
Paper Number: SPE-189319-MS
... BHA designs, right choice of fit for purpose bits and effective real-time performance monitoring. Artificial Intelligence real time system machine learning Upstream Oil & Gas benchmark ROP ERD well section op drilling performance improvement lateral Drilling Performance Improvement...
Abstract
As conventional drilling learning curves mature from drilling simple vertical wells to deviated wells to complex multi-lateral horizontal wells, the boundaries needed to be broken to reach much deeper depths rather than consuming the time in drilling multiple shorter laterals. Horizontal ERD wells in Qarn Alam cluster were planned to be drilled in four sections where the 17.5-in section is drilled vertically followed by a deviated 12.25-in section and continued by landing in 8.5-in section and finally the 6.125-in horizontal lateral. Many attempts of performance improvement initiatives were executed over many years however there were always flaws and inconsistency in drilling performance delivery. As the need of ERD grew, a detailed offset wells analysis had to be performed where all the deficiencies and issues had to be pin pointed, RCA (Root Cause Analysis) had to be performed and plans for success had to be laid out. From challenges achieving required dog legs in the top sections with increased risks of axial and lateral vibrations, to the difficulties faced in the landing section drilling through unconsolidated and reactive shales, to the difficulties transferring weight to the bit at deeper depths in the horizontal laterals drilling highly porous zones of sticky limestones resulting in severe torsional vibrations. A new approach of drilling had to be executed with a renovated set of drilling parameters envelopes, revised trajectory designs, re-engineered BHA designs, right choice of fit for purpose bits and effective real-time performance monitoring.
Proceedings Papers
Publisher: Society of Petroleum Engineers (SPE)
Paper presented at the SPE/IADC Middle East Drilling Technology Conference and Exhibition, January 29–31, 2018
Paper Number: SPE-189371-MS
... flow control equipment Upstream Oil & Gas ICD screen deployment icd production control Directional Drilling new generation icd pressure drop sandstone reservoir simplify deployment treatment fluid successful installation packer installation MTV valve production monitoring drilling...
Abstract
Inflow Control Device (ICD) are deployed as a part of downhole completion across the horizontal section in consolidated or unconsolidated formations to overcome challenges posed by long horizontal drains like heel to toe effect and formation heterogeneities. The main objective of ICD completion is to delay water or gas breakthrough by enabling equalization of flux along the wellbore and promote oil by chocking back water in case of water breakthrough. Recently, for the first time in sandstone fields, a new ICD generation combining three advanced features in one was successfully installed enabling simple and safe deployment of an optimum completion design for a long horizontal well. The new ICD is a combination of new hybrid ICD design, multi-tasking valve (MTV) and premium sand screen. The new ICD generation incorporates a hybrid design in which the fluid flows in a labyrinth path to achieve optimum pressure drop. The new design makes the ICD highly density dependent and insensitive to viscosity while maintaining a larger flow area which makes is less prone to plugging and erosion compared to conventional ICDs. MTV, a delayed opening valves incorporated into the ICD allowing them to act as a pressure containing liner component. This enables a true flow through full circulation from the bottom of the completion assembly eliminating the need of inner string during deployment. Having MTV feature in the ICD has made the deployment not only simple and safe but also saved considerable amount of rig operation time compared to conventional ICD screens by eliminating the need for inner string. Risk of low productivity of well due to screen plugging by mud solids in OBM was also reduced by achieving a higher annular velocity during deployment and pumping wellbore clean-up treatment fluid. This paper will discuss the benefits of the new generation ICD on completion operation based on experience from the first deployment and highlight the operational cost saving by reducing the rig time. In addition, the impact of the new hybrid design on the well production performance will be discussed highlighting the post drilling benefits and how it would prolong the well life.
Proceedings Papers
Publisher: Society of Petroleum Engineers (SPE)
Paper presented at the SPE/IADC Middle East Drilling Technology Conference and Exhibition, January 29–31, 2018
Paper Number: SPE-189312-MS
... formation layers. This method provides a direct measurement of the fracture width without the influence of the used apparatus. hydraulic fracturing psia reduction percentage fracturing materials Upstream Oil & Gas closure stress proppant concentration fracture conductivity sand proppant...
Abstract
Hydraulic fracturing is a key treatment for economical production from shale formations. High surface pressure is used to fracture the formation, and proppant is pumped to prevent fracture closure after the pressure is removed. The ability of proppant to maintain high fracture width and permeability controls the flow of the hydrocarbon fluids towards the wellbore, and, hence, the behavior of different proppants at in-situ conditions is critical to the success of fracturing operations in shale formations. The objective of this paper is to experimentally evaluate the performance of two widely used proppants in Marcellus shale at elevated stress conditions. A proppant-crushing test between two samples of Marcellus shale was performed to evaluate the proppant performance at different closure stress values up to 10,000 psia. Two types of proppants were tested: sand and sintered bauxite at different concentrations. This work used a digital microscope to measure the width of the fracture at each closure stress; a series of photographs of the propped fracture were taken, and an image analysis software was used for fracture width measurements. The amount of crushed proppant and induced formation fines due to embedment were also quantified after each test. The results indicate that with partial monolayer proppant, both proppants experience a significant reduction in the fracture width at elevated closure stresses, reaching as high as 48% at 10,000 psia. Proppant physical properties were found to affect the initial fracture width even though the proppant concentration was the same. The use of multiple layers of bauxite proppant reduced the loss of fracture width to 14% at 10,000 psia closure stress. Results reveal that sand proppant shows a high degree of crushing at 0.05 and 0.25 lb/ft 2 proppant concentrations. On the other hand, the use of bauxite results in a higher amount of formation fines due to proppant embedment, which could cause severe damage to the fracture conductivity. The paper contributes to the understanding of how proppants behave at in-situ conditions of shale hydraulic fractures. Results can be used to optimize proppant and fluid selection, and reduce the sources of damage to fracture conductivity to maximize well productivity.
Proceedings Papers
Publisher: Society of Petroleum Engineers (SPE)
Paper presented at the SPE/IADC Middle East Drilling Technology Conference and Exhibition, January 29–31, 2018
Paper Number: SPE-189378-MS
... formulation Upstream Oil & Gas removal efficiency drilling fluid chemistry drilling fluid formulation Efficiency chemical coagulation method reference standard HDPT technology technological process Drilling sulfonated drilling cutting biological treatment method application recyclable barite...
Abstract
Due to high temperature, high pressure, and gypsum-salt formations in the Tian Mountain Front Block in Tarim Basin, the stability and rheology of traditional polymer drilling fluids are difficult to maintain, so sulfonated drilling fluids (SDF) are recommended to drill deep formations. The sulfonated drilling fluids can provide a powerful technical support for achieving high quality drilling, and it has been run for above 200 wells in the past year. However, a large number of sulfonated drilling cuttings are generated in the drilling operation. These drilling cuttings contain a large number of harmful substances, including petroleum hydrocarbon, sulfonated additives, soluble salts, and so on, which are toxic and difficult to be biodegradable, so the discharge of drilling cuttings into environment will lead to serious contamination of soil and groundwater. Conventional drilling cuttings treatment methods, include reinjection method, solidification with cement method, and chemical desorption method, have several disadvantages such as low efficiency, high cost, or recontamination, and they could not recycle any useful resource, so they are not applicable for large-scale treatment of sulfonated drilling cuttings. Innovative high temperature deep pyrolysis technology (HDPT) is currently developed to treat sulfonated drilling cuttings. HDPT consists of cuttings drying system, high temperature pyrolysis system and waste gas treatment system. By using of high temperature pyrolysis system, harmful organic compounds in drilling cuttings could be completely degraded. Owing to complete isolation between drilling cuttings and flames, nitrogen oxides and other harmful substances could be effectively avoided to produce. Then the obtained acidic gases, such as sulfur dioxide, hydrogen chloride, chlorine, and so on, could be rapidly eliminated by waste gas treatment system. The drilling cuttings, barite agent and waste gas could be obtained. The field results indicate that the content of petroleum hydrocarbon of obtained drilling cuttings is less than 16 ppm, and various indexes of obtained drilling cuttings could meet the requirement of environmental protection, so these drilling cuttings can be used to pave the road. The recyclable barite agent could be reused to prepare mud. The waste gas could be directly released into the atmosphere. HDPT technology is characterized by high treatment efficiency and no secondary pollution, and it is very suitable for harmless treatment of sulfonated drilling cuttings. HDPT technology can not only guard against environmental pollution from sulfonated drilling fluids, but also recycle and reuse useful resources, and thus produce great environmental and economic benefits. HDPT treatment plant has been built in this Block, and its handling capacity can be up to 1000 kiloliters per day. HDPT technology has been successfully run for treating sulfonated drilling cuttings from dozens of wells, and provides a strong technical support for cleaning production of drilling operation. This paper presents field data to illustrate the application of this technology and evaluate the potential technical and economic benefits that it might provide to petroleum development and production.
Proceedings Papers
Publisher: Society of Petroleum Engineers (SPE)
Paper presented at the SPE/IADC Middle East Drilling Technology Conference and Exhibition, January 29–31, 2018
Paper Number: SPE-189354-MS
.../mitigate the time-dependent failure in the production section. machine learning drilling rate drilling performance Artificial Intelligence mishrif well ROP MSE mechanical specific energy society of petroleum engineers real time system Upstream Oil & Gas drilling parameter drilling...
Abstract
The Mechanical Specific Energy (MSE) and Statistical Analysis Approach (SAA) have been widely implemented in oil and/or gas well drilling industry to enhance the Rate of Penetration (ROP) and reduce the operation cost. This work focuses on predicting and optimizing the drilling efficiency and performance in the production section of Mishrif reservoir in southern Iraq fields. The drilling data from twenty-five wells has analyzed and examined to improve the drilling productivity relied upon MSE and statistical approaches. By using MSE technique, the minimum required energy to drill unit volume of each formation has determined to improve the drilling speed and avoid unnecessary energy consumption that may come out in the form of bit wearing / balling or vibration. The optimum energy is achieved when the MSE value comes close to the unconfined compressive strength (UCS) value that obtained from the empirical formula for limestone and shale rocks. The flounder and threshold points have recognized to optimize drilling data in the offset wells to enhance ROP in the future wells. In the statistical approach, the regression coefficients have obtained from the screened and filtered fields drilling data then the empirical equations to estimate ROP have constructed by using linear regression analysis through a commercial software. The optimization techniques lead to an impressive increase in the rate of penetration in the production section of the Mishrif reservoir. The MSE surveillance provides a reliable tool to maximize the ROP and reduce some drilling problems by using sufficient energy to drill each formation below the flounder point. An excessive energy consumption throughout drilling can be observed in the majority of wells been investigated. Thus, the non-productive time has mitigated considerably by utilizing drilling variables that have induced MSE equal to the unconfined compressive strength of the rocks. On another hand, the statistical analysis of real-time data for twenty-seven wells revealed a remarkable improvement in drilling performance by suggesting an empirical equation that predicts ROP through changing some key parameters such as Flow Rate (FL), Weight On Bit (WOB), Torque (TQ), Revolution Per Minute (RPM), Mud Weight (MWT) and Total Flow Area (TFA). The recommended drilling parameters resulted from this work can be used to reduce the drilling cost and prevent/mitigate the time-dependent failure in the production section.