Investigating Near-Wellbore Diversion Methods for Refracturing Horizontal Wells

Abstract

Summary Near-wellbore diversion of fracturing fluid and proppant is a common approach to achieving improved treatment efficiency when refracturing horizontal wells for expanding treatment coverage within the lateral. There are five broad categories of near-wellbore diversion methods: particulate diversion for bridging open fractures connected to the wellbore; perforation sealing to limit injectivity into open perforation clusters at the wellbore; filling up the drained fracture system with water for achieving more uniform pressurization (i.e., fill-up); injection rate cycling/hesitation fracturing; and mechanical isolation by installing cemented or expandable liners in the lateral followed by plug-and-perforated stimulation. These tactics can be used standalone or combined. Particulate diverting agents can be additionally categorized by particle type (e.g., granular, fibrous) and solubility characteristics. Perforation sealing agents consist of deformable and rigid/spherical subtypes, both of which can be further categorized by solubility characteristics. In this study, treatment and production data for 72 ConocoPhillips refractured wells in a North America shale play were analyzed to evaluate the effectiveness of the various near-wellbore diversion methods and materials. An index was formulated using information on reservoir depletion to normalize changes in bottomhole fracture pressure over time. This was determined by periodically discontinuing injection to obtain instantaneous shut-in pressures (ISIPs) over the course of the treatment. The calculated indices were plotted for each type of diverting system to compare trends for gaining insight on in-situ stress buildup. Production data grouped by different diversion methods were also analyzed. The near-wellbore diversion methods included mixed-size particulates with and without fibrous materials, deformable and rigid perforation sealers, fill-up tactics in which near-wellbore diverting agents were not used, and mechanical isolation by cementing a newly installed liner in the lateral followed by plug-and-perforated stimulation. Fracture hit analysis of offset well treatments indicated that refracturing treatments using particulate diverters were heel biased with respect to reservoir repressurization. The study showed that the incremental pressure as a result of diverter landing on perforations is a poor indication of diverter efficiency. A non-normalized ISIP trend is misleading as an indicator for post-refracturing well performance. Refractured wells with either particulate diverters or perforation sealers both show initial fluid fill-up into the depleted region before the stress buildup plateaus. Wells that have liners installed and cemented inside the original wellbore and that are then restimulated with standard plug-and-perforated techniques show superior performance compared with all diversion methods used in bullhead refracturing treatments. Choice of diversion can have a significant impact on results, but not all particulate diverters or perforation sealers behave similarly. Wells refractured using only the fill-up method have long-term productivity on par with or better than wells refractured with most types of diverting agents.

Study on multi-cluster fracturing simulation of deep reservoir based on cohesive element modeling

“…Young's modulus (GPa) 35 Frontiers in Energy Research frontiersin.org model derived from Bernoulli's equation for modeling perforation friction. (Cramer et al, 2019).…”

Finite element study on the initiation of new fractures in temporary plugging fracturing

“…Research and field testing on temporary plugging fracturing technology began in the 1950s and 1960s, leading to significant progress in understanding the mechanisms, materials, numerical simulation, design, and construction of temporary plugging fracturing [1-3, 7, 8]. Field experiments have shown that several factors, such as initial artificial fractures, changes in reservoir pore pressure and temperature fields due to long-term production, artificial fractures in adjacent wells, and production/injection activities, can affect the size and direction of the in situ stress field [5,[9][10][11]. According to the theory of rock and fracture mechanics, artificial fractures are always perpendicular to the direction of minimum horizontal stress.…”

“…Refracturing old wells in low permeability oil fields has been established, mainly through intra-fracture diversion fracturing, which has become a leading technology for tapping potential and stabilizing production in many blocks [11][12][13][14][15][16]. By developing numerical models of the stress field and fracture propagation, we obtain new fracture propagation behaviors and optimal fracture timing based on different geological features and fracture design parameters generated by temporary plug fracturing [17][18][19].…”