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The channel fracturing technique achieves heterogeneous proppant placement by pumping pulses of proppant laden slurry and clean fluid in alternating sequence. Successful creation of proppant banks in the fracture provides stable channels of infinite conductivity which reduces pressure drop across the hydraulic fracture and enhances production. To date, more than 15,000 fracturing jobs have been successfully placed in various types of formation and completions using the heterogeneous proppant placement technique. The mechanics of delivering the treatment involves pumping pulses of alternating clean and dirty pulses of fluid with fibers that keeps the proppant in suspension. This is then followed by a continuous proppant "tail-in" stage towards the end of the job before the flush stage. This tail-in ensures continuous proppant bank at the near wellbore region to ascertain good connectivity between wellbore and the channel spaces created during the treatment. To understand importance and requirement of tail-in, simulations and field execution of jobs with or without tail-in in channel fracturing treatment have been done. Furthermore, a bigger sized unconventional rod-shaped proppants have been also used towards end of the channel fracturing treatments. The unconventional proppants not only helped on such treatments to minimize pressure drop across the tail-in but also helped to reduce proppant flowback in softer formations. The impact of tail-in on pressure drop and production rates in different formations have been consolidated in this study which provides proppant selection criteria for channel fracturing tail-in stage. Simulation results in shale and sandstone reservoirs and the field treatment case histories comparing the production results for wells completed with and without tail-in in channel fracturing treatment are presented.
The channel fracturing technique achieves heterogeneous proppant placement by pumping pulses of proppant laden slurry and clean fluid in alternating sequence. Successful creation of proppant banks in the fracture provides stable channels of infinite conductivity which reduces pressure drop across the hydraulic fracture and enhances production. To date, more than 15,000 fracturing jobs have been successfully placed in various types of formation and completions using the heterogeneous proppant placement technique. The mechanics of delivering the treatment involves pumping pulses of alternating clean and dirty pulses of fluid with fibers that keeps the proppant in suspension. This is then followed by a continuous proppant "tail-in" stage towards the end of the job before the flush stage. This tail-in ensures continuous proppant bank at the near wellbore region to ascertain good connectivity between wellbore and the channel spaces created during the treatment. To understand importance and requirement of tail-in, simulations and field execution of jobs with or without tail-in in channel fracturing treatment have been done. Furthermore, a bigger sized unconventional rod-shaped proppants have been also used towards end of the channel fracturing treatments. The unconventional proppants not only helped on such treatments to minimize pressure drop across the tail-in but also helped to reduce proppant flowback in softer formations. The impact of tail-in on pressure drop and production rates in different formations have been consolidated in this study which provides proppant selection criteria for channel fracturing tail-in stage. Simulation results in shale and sandstone reservoirs and the field treatment case histories comparing the production results for wells completed with and without tail-in in channel fracturing treatment are presented.
Hydraulic fracturing has evolved as the preferred completion strategy for low-permeability reservoirs in India. Hence, a hydraulic fracturing technique that maximizes production and is also operationally efficient will provide an optimum solution for the development of these reservoirs. A channel fracturing technique recently applied to more than 20 treatments for various operators in different fields and reservoirs in India has been delivering superior production results and has proved to be operationally more efficient compared to conventional hydraulic fracturing operations performed in India. Proppant is pumped in pulses at the surface during the channel fracturing technique. These pulses create stable channels within the hydraulic fractures thus decoupling fracture conductivity from the proppant pack itself which result in providing near-infinite fracture conductivity. An earth model was prepared from petrophysical measurements including acoustical data which allowed for the calculation of stresses that are required for hydraulic fracture modelling. These preliminary models were further calibrated based on pressure data gathered during fracture diagnostic tests and this calibrated model was used for the final treatment design. Post-treatment production evaluation was performed by applying nodal analysis and by comparing actual production with predicted production from a reservoir simulator. Treatment evaluation indicated higher fracture conductivity for channel fracturing technique than that of conventional treatments and this led to higher production. Fracturing fluid recovery has also been higher as compared to conventional treatments. Screenouts were eliminated on the treatments that applied the channel fracturing technique. This allowed fracturing zones that might not have been completed with conventional treatments. The amount of proppant pumped per stage has been reduced by nearly 50% as compared to conventional treatments and treating pressures in general have been lower which has led to lower horsepower consumption on the treatments. These successful hydraulic fracturing treatments have confirmed the applicability of the channel fracturing technique in the low-permeability reservoirs of India. This paper presents channel fracturing treatments that have been performed for the first time in India including treatments performed with heated fluid expanding the envelope for the technology application. This paper identifies a solution for screenouts during hydraulic fracturing treatments while maximizing production from low-permeability reservoirs.
Romania is a key pioneer in oil and gas industry with a history of more than 150 years'experience. Many of the oil fields discovered in the early days are still being produced. Extending the production life of mature fields presents a variety of challenges including low reservoir pressure, high water cut, limited well data, aging completions and bypassed pay. The target field is a mature oil field situated in the heart of Romania that has been operated since the 1960s and exhibits many of the aforementioned issues. This paper describes the reservoir, exploitation difficulties and new techniques applied to overcome the key challenges to effectively producing this aging asset. Production enhancement in mature assets require new approaches that can address key challenges and risks associated with the reservoir and completion age. Application of conventional can easily lead to failures including ineffective stimulation, completion failure, screen-out, and increased water cut, all causing difficulties to put wells back in production and resulting in disappointing results. In mature fields, a different approach is required. This paper details first time application of the flow channel hydraulic stimulation in one of the wells in the field, describing the importance of well candidate selection phase, engineered design, execution, and evaluation. The applied channel hydraulic stimulation combines geomechanical modeling with intermittent proppant pumping and degradable fibers to obtain heterogeneous placement of proppant within the fracture. A post job production evaluation compares the production after the conventional treatments versus post flow channel hydraulic stimulation job. The results for all conventional hydraulic stimulation treatments show a steep production decline rate, while the positive impact of channel hydraulic stimulation is apparent resulting in higher initial production and an overall slower production decline. The productive reservoirs besides of low reservoir pressure, are characterized by an increased degree of lamination. The target interval is usually described by a sequence of marls and lenticular streaks of sandstone and shaly-marly sandstone. Conventional hydraulic stimulation treatments have had a marginal effect in this reservoir. Due to the variable lithology, gained limited connection through conventional ways of stimulation and/or perforation end up in quick depletion and production decrease. Channel hydraulic stimulation was applied for the first time in this field and may now be considered to be an efficient way of enhancing production in this and similar reservoirs.
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