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Collaborating Authors
Sherbeny, Wael El
Delivering Value Through Advanced Geomechanics in Complex Drilling Environments: From Well Planning to Real-Time
Imtiaz, Saad (Baker Hughes, a GE company) | Perumalla, Satya (Baker Hughes, a GE company) | Hynes, Laura (Baker Hughes, a GE company) | Basu, Pramit (Baker Hughes, a GE company) | Shinde, Ashok (Baker Hughes, a GE company) | Benmamar, Salim (Baker Hughes, a GE company) | Chakrabarti, Prajit (Baker Hughes, a GE company) | Sherbeny, Wael El (Baker Hughes, a GE company)
Abstract In today’s challenging market conditions, the probability of successful well delivery can be increased and influenced by implementing fit-for-purpose pre-drill and real-time geomechanical solutions. These tailored geomechanical solutions add value to the project by delivering a cost-effective well, with reduced non-productive time (NPT), and a lower risk of health, safety, and environment (HSE) concerns. Geomechanics guided decision making, both in the pre-drill and in the real time phases, has a wide range of applications depending on the complexity present in the drilling environment, e.g., high-pressure, high-temperature (HPHT) regimes, reactive clays, depleted reservoirs, weak shales, highly stressed areas, etc. This paper discusses the application of advanced geomechanics in three specific drilling environments (a) drilling a highly deviated well in a transitional fault regime, onshore the Nile Delta, (b) mitigating wellbore instability caused by reactive shales, in the Middle East and (c) drilling lateral wells in a highly-stressed carbonate formation. The paper also discusses how integrated pre-drill and real-time geomechanical solutions helped in achieving drilling success without adding major cost to the project. In study (a) the operator had successfully drilled many vertical wells in the onshore field on the Nile Delta without significant problems, yet was having severe issues drilling deviated wells. A detailed pre-drill model revealed the possibility of a transitional faulting regime, in association with anisotropic rocks, drilled by a slick Bottom Hole Assembly (BHA), could be a major reason for this. Real-time geomechanics were deployed to validate the pre-drill understanding, along with mud additive recommendations and a slight modification to the drill string. In a different study (b) performed in another onshore Middle East field, there was a challenge to drill high-angle wells through troublesome shale formations, which resulted in various sidetracks and a significant amount of wellbore instability issues. These issues limited well configuration options for field development to near vertical wells. A pre-drill geomechanical study was carried out to understand the root cause of the failures that resulted in customized mud weight and mud type solutions for drilling higher angle wells. With these customized recommendations and later on a 3D Geomechanical model, horizontal wells have been drilled successfully for optimal draining of the reservoir resulting in breakthrough in field development plan. In study (c) there was significant wellbore instability challenges while drilling lateral wells through highly-stressed carbonate reservoir. A comprehensive study helped in understanding the geomechanical behavior. In example highlighted the drilling team was using lower than required mud weights in a horizontal well. The geomechanical model was adjusted considering time and space for specific case using the geomechanical understanding. The focused geomechanical modeling helped to adjust the mud weight. Suitable mud weight along with pseudo real-time monitoring helped in successful delivery of the horizontal well. The three studies presented are onshore. Conventional wisdom for onshore drilling has a bias for low-cost solutions. However, the complexity of each drilling campaign was different. In all the cases the adoption of integrated geomechanics through the planning and operation phase ensured successful project completion with minimal non-productive time (NPT).
- Asia > Middle East (1.00)
- Africa > Middle East > Egypt > Nile Delta (0.45)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Raudhatain Field > Upper Burgan Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Raudhatain Field > Mauddud Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Raudhatain Field > Lower Burgan Formation (0.99)
- (2 more...)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Well Planning (1.00)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- (2 more...)
Abstract Success and failure of hydraulic fracturing is driven by a number of factors including operational procedures, fluid dynamics and the geomechanical response of the reservoir. Thus, the complex nature of the hydraulic fracturing process makes it difficult to correlate its success or failure to one of the many factors alone. However, in this paperwe demonstrate – based on real experiences–some successes and failures that show strong evidence of being driven by geomechanics aspects alone. The unsuccessful hydraulic fracturing of a well can be often interpreted as a failure in terms of operational procedures. However, there are cases where the unfavorable geomechanical setting plays the dominant role on the fracturing success. Modeling such complex processes can be very time consuming and costly, especially, if fluid dynamics of the pumped fluids is integrated into the calculations. One suggested way forward is to modestly simplify the world of (rock-) physics and hence focus on the problem down to the main contributors of the processes while still reaching the desired and representative result. In this work we focused on stress and pressure changes around the wellbore and perforations, that have strong influence on the end result of fracturing. In four wells that were hydraulically fractured, we observed two wells experiencing successful breakdown (and propagation), whereas the other two wells could not be fractured. Optimal application of analyticalgeomechanical modeling was more than sufficient to prove that the major cause for the failure in formation breakdown was stress field changes around the well bore and perforations in coherence with the rockmechanical properties. Thus, the specific geomechanical setting has led to an elevated breakdown pressure that was too high to be achieved by the horse powerof the pressure pumping equipment. At the same time the model also explains the underlying reasons for the two successfully stimulated wells. This experience not only leadsto a geomechanical explanation for hydraulic fracturing- (formation breakdown) failure and success, but also to more customized recommendations for avoiding loss in pump horse power. This is of importance when limitations in pump- and completion pressures are a concern. From this experience we learn also about the influence of geomechanical drivers on well placement, completion strategy, perforation schemes and injection point selection.
- North America > United States (0.93)
- Asia > Middle East (0.82)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
Delayed Reaction Micro-Emulsion Fluid to Clean Oil Base Mud Filter Cake Damage in Open Hole Completions
Addagalla, Ajay Kumar V. (Baker Hughes) | Kosandar, Balraj A. (Baker Hughes) | Lawal, Ishaq G. (Baker Hughes) | Jadhav, Prakash B. (Baker Hughes) | Imran, Aqeel (Baker Hughes) | Sherbeny, Wael El (Baker Hughes) | El-Araby, Mohamed (Baker Hughes) | Ansari, Adel (Saudi Aramco) | Pino, Rafael (Saudi Aramco) | Gad-Alla, Ahmed E (Saudi Aramco) | Olivaresantunez, Tulio (Saudi Aramco)
Abstract Minimizing formation damage is an important parameter to be considered to have expected production rates. Formation damage can happen at any phase during drilling, completion or production and is attributed by too many factors. Formation protection is critical while drilling the production zone because damage to the formation can adversely affect the well's production potential. This pay zone damage is minimized with the use of drill-in fluids, specialized fluids for "drilling in" and protecting oil/gas production formations. Damage to the pay zone, including fine solids migration into the formation permeability channels, in-situ emulsions, water block, organic deposition, oily debris, clay swelling within the formation pore spaces and irreversible reactions with invading polymers, reduce the average permeability of the formation, resulting in lower production rates. Most formation damage caused by conventional drilling fluids is by fluid invasion containing barite, finely ground drill solids and/or weighting material. The formation damage is even more critical in horizontal/inclined wells where the reservoir exposure is more and production rates are high. Micro-Emulsion fluids are thermodynamically stable, optically transparent solutions comprising two immiscible fluids. They differ from ordinary emulsions because they can be prepared with little or no mechanical energy input. Micro-Emulsions typically comprise a non-polar or oil phase, a polar or aqueous phase, surfactant(s) and an optional co-surfactant. Depending on how they are formulated, micoemulsions can exist in a single-phase or in a three-phase system, in which the middle-phase microemulsion is in equilibrium with the excess water and oil. The formulation characteristics, phase type, and ultimately, the cleaning efficiency of a microemulsion are dictated by the hydrophilic-lipophilic balance between the surfactant(s) and the physico-chemical environment. The microemulsions described in the study are single-phase where oil and water are co-solubilized by the surfactant(s) and co-surfactants. The water/oil interface has a zero or near-zero curvature, indicative of the bicontinuous phase geometry that produces very low interfacial tension and the rapid solubilization of oil upon contact. The Micro-Emulsion behavior and cleaning efficiency can be altered by salinity, surfactant, co-surfactant, oil type, temperature and particulates. A robust, optimized formulation is necessary and validation testing is required to determine the efficacy of a micro-emulsion for a specific application, i.e., OBM displacement/cleanup and removal of formation damage in openhole and cased-hole wells. Micro-Emulsion fluids were successfully developed to effectively resolve the persistent problem of near-wellbore damage. The physical-chemical properties of the micro-emulsion systems include high oil solubilization, high diffusion coefficients through porous media and the reduction of interfacial tension between organic and aqueous phases to near-zero, making them excellent candidates for removing formation damage. The chemistry of Micro-Emulsion fluids makes the systems excellent choices for superior synthetic or oil based mud (S/OBM) displacements in casing and for OBM filter-cake cleanup in openhole completion applications. This paper presents a technical overview of micro-emulsion technology and field applications that demonstrate the efficiency of Micro-Emulsion fluids for removing S/OBM debris and filter cakes, reducing near-wellbore damage and improving well productivity.
Overcoming OBM Filter Cake Damage Using Micro-Emulsion Remediation Technology across a High-Temperature Formation
Addagalla, Ajay Kumar (Baker Hughes) | Kosandar, Balraj A. (Baker Hughes) | Lawal, Ishaq G. (Baker Hughes) | Jadhav, Prakash B. (Baker Hughes) | Imran, Aqeel (Baker Hughes) | Al Saqer, Qassem R (Baker Hughes) | Sherbeny, Wael El (Baker Hughes) | Ansari, Adel (Saudi Aramco) | Pino, Rafael (Saudi Aramco) | Gad-Alla, Ahmed E (Saudi Aramco) | Olivaresantunez, Tulio (Saudi Aramco)
Abstract Formation damage is one of the main concerns at various stages of drilling, completion and production processes and is attributed to many factors. Either in open-hole or cased-hole completed wells, hydrocarbon flow in the reservoir may be impeded by various damaging mechanisms such as in-situ emulsions, water block, organic deposition and oily debris left downhole. Micro-emulsion fluids are thermodynamically stable, optically transparent solutions of two immiscible fluids formulated with a specialized surfactant blend and/or co-surfactant. They differ from normal emulsions because they can be prepared with little or no mechanical energy input. They typically comprise a non polar (oil) phase, a polar (aqueous) phase, surfactant(s) and an optional co-surfactant. Depending on how they are formulated, mesophase fluids can exist in a single-phase or in a three-phase system wherein the middle-phase microemulsion is in equilibrium with excess water and/or oil. The formulation characteristics, phase type, and ultimately, the cleaning efficiency of a microemulsion are dictated by the hydrophilic-lipophilic balance between the surfactant(s) and the physico-chemical environment. The microemulsions described in this study are single-phase where oil and water are co-solubilized by the surfactant(s) and co-surfactants. The water/oil interface has a zero or near-zero curvature, indicative of the bicontinuous phase geometry that produces very low interfacial tension and the rapid solubilization of oil upon contact. The formation of a micro-emulsion alone does not ensure the fluid will solubilize oil effectively to leave surfaces water-wet. The micro-emulsion behavior and cleaning efficiency can be influenced by salinity, surfactant, co-surfactant, oil type, temperature and particulates. No two wells are identical and the physical and chemical conditions can vary greatly depending on the application. As a consequence, robust, optimized formulations are necessary and validation testing is required to determine the efficacy of a mesophase for a specific application, i.e., OBM displacement/cleanup and removal of formation damage in openhole and cased-hole wells. Micro-emulsion fluids were successfully developed to effectively resolve the persistent problem of near-wellbore damage. The physico-chemical properties of the micro-emulsion systems include high oil solubilization, high diffusion coefficients through porous media and the reduction of interfacial tension between organic and aqueous phases to near-zero, making them excellent candidates for removing formation damage. The chemistry of micro-emulsion fluids makes the systems excellent choices for superior synthetic or oil-based mud (S/OBM) displacements in casing and for OBM filtercake cleanup in openhole completion applications. This paper presents a technical overview of micro-emulsion technology and field application in a high- temperature gas environment that demonstrate its efficiency in removing Non-Aqeuous Fluid (NAF) debris and filter cakes, whilst reducing near-wellbore damage and improving well productivity and solids mobility.
- North America > United States (0.47)
- Asia > Middle East (0.29)
- Geology > Mineral (0.69)
- Geology > Rock Type > Sedimentary Rock (0.47)
Steerable Drilling Liner Matches the Industry's Common Theme Regarding Cost Optimization Approaches and Minimize Geomechanics Related Challenges; Technology Overview, Applications and Limitations
Sherbeny, Wael El (Baker Hughes) | Dabyah, Ali Al (Baker Hughes) | Ghai, Gagan (Baker Hughes) | Merie, Ibrahim (Baker Hughes)
Abstract Because fracture gradient changes with rock type, some formations are more sensitive to induced fractures than others. Depending upon depth, the fractures created will either be horizontal or vertical. If the depth is 2500 feet or less, horizontal fractures are usually produced. Because horizontal fractures require lifting the entire overburden, they are limited to shallow depths. At depths over 3500 feet, fractures are usually vertical. Because vertical fractures occur without lifting the overburden, they can be created at much lower pressure. The propagation pressure is generally much less than the pressure that would be required to initiate the fracture. Consequently, fracture losses, once initiated, are difficult to control. Wellbore instability, particularly in shale formations, is a major challenge in drilling operations. Many factors such as rock properties, in-situ stresses, chemical interactions between shale and drilling fluids, and thermal effects must be taken into consideration in well trajectory designs and drilling fluid formulations to mitigate wellbore instability-related problems. The Steerable Drilling Liner service combines a rotary steerable system with a liner to help overcome the challenges: drilling in zones with lower pressure and unstable shale/coal layers, and with formations of varying flow and pressure regimes. Running the liner while drilling keeps the wellbore stable and eliminates the need to pull the drillstring to run casing. This is how it reduces your risks and NPT, saving the costs associated with contingency plans. Because the liner is isolated from the reamer shoe, you can rotate the liner at much lower RPMs than the pilot and reamer bits. This design lessens the load on the liner, improving its fatigue life. The Steerable Drilling Liner steerable drilling liner service helps you to mitigate the risk of hole collapse and formation damage by reducing openhole exposure, Reduce NPT by eliminating extra trips and ensuring that the liner is installed at TD from the first run Enhance wellbore integrity by drilling with the liner, leading to the plastering effect, which reduces fluid loss and cuttings volume, Lower health, safety, and environmental (HSE) risks by reducing pipe handling and rigsite footprint size Steerable Drilling Liner service developed and qualified using a rigorous processes including extensive onshore testing at the service provider Experimental Test Area (BETA) facility before being successfully deployed offshore. Rely on Steerable Drilling Liner service performance in extreme environments; the cost-effective Steerable Drilling Liner service promotes wellbore stability and performs reliably in the challenging downhole environments. This Paper will reveal the technology overview, updates, case histories and field limitations
- Asia > Middle East > Saudi Arabia (1.00)
- Africa > Middle East > Egypt (1.00)
- Asia > Middle East > Yemen (0.93)
- (3 more...)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.95)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Drillstring Design > Drill pipe selection (1.00)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
Abstract Drilling and completing reservoirs without inducing measureable skin damage is rare. Frequently, drilling fluids impact a reservoir’s flow potential while drilling as the rock matrix is invaded by solids and chemicals designed to enhance drilling performance. Drilling fluid can also cause formation damage if they are not properly removed during the displacement phase. These solids can migrate to the perforating zone and cause damage. Completion fluid designs governed by density for well control also often contribute to skin damage. Hydrocarbon flow may be impeded by damage caused by residual drilling debris or incompatible completion and workover fluids, in-situ emulsions, water block, organic deposition, or oily residue. Specialized surfactant systems have been developed to remediate near-wellbore damage caused by drilling and completion fluids, and damage induced by failed remediation attempts. The properties of these treatment systems include their ability to solubilize oil and, due to a significant reduction in interfacial tension between the organic and aqueous phases, effectively diffuse through the damaged zone to free up flow-resistant obstructions. The inherent properties of these systems make them ideal for removing induced formation damage as well as an excellent option for displacing synthetic or oil-based mud (S/OBM) from casing prior to the completion phase. In open-hole (OH) completions, specialized surfactant designs have proven very effective in removing S/OBM filter cake damage. In cased-hole (CH) completions, they have demonstrated a high degree of efficiency to clean damaged perforations. This paper presents a technical overview of surfactant systems for OH and CH remediation operations. The testing to qualify these fluids for the removal of damage and field results are presented that show the efficacy of these specialized surfactant systems to remove damage caused by OBM filter cakes and other oily debris to improve hydrocarbon recovery while addressing the operational challenges associated with these jobs.
- Africa > Middle East > Egypt (0.69)
- Asia > Middle East > Saudi Arabia (0.46)