Case Study - Evaluation of Horizontal Well Multi-stage Fracturing in the Viking Oil Formation

Mogensen, A.C.; Bachman, R.C.; Singbeil, Peter Peter

doi:10.2118/162813-ms

Cited by 6 publications

(1 citation statement)

References 6 publications

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“…1 and 2). This is very close to the formation temperature, which is between 28 and 35 ºC (Mogensen 2012). It was speculated that due to the characteristics of the oil and the environment in which it moves, precipitation could be occurring in the near-wellbore region or in the formation.…”

Section: Introductionmentioning

confidence: 54%

Solid Paraffin Inhibitors Pumped in Hydraulic Fractures Increase Oil Recovery in Viking Wells

Wornstaff

Hagen

Ignacz

et al. 2014

Day 2 Thu, February 27, 2014

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The Viking formation in southern Saskatchewan Canada represents an active area where steep production declines in the first year of production are common and are often attributed to wellbore or near-wellbore precipitation of paraffin. Excessive decline rates within the first year on production have been observed.A producer was experiencing paraffin deposition in the wellbore and suspected it to be the reason for production declines. Conventional treatments targeted at wellbore deposition were carried out with little effect on production rates. In an effort to improve production rates horizontal treatments were attempted. These treatments resulted in brief increases in production (up to 6 weeks). Horizontal treatment success led to investigation into other treatment options. Precipitation in the formation may contribute to reduced conductivity and, therefore, lower oil production rates. Solid paraffin inhibitors delivered via hydraulic fracturing offered the best potential for success in new wells.The chemical additive treatment was designed through product selection testing using cold finger deposition tests, compatibility testing with the hydraulic fracturing fluid system, and proppant crush prediction models. A baseline of the untreated oil characteristics was determined using offset wells. Pour point, carbon number distribution and wax percentage were analyzed in offset untreated wells and each treated well. Production trends were used to track the performance of the treatments. The solid inhibitor application effectively prevented conductivity restrictions due to paraffin precipitation issues in the proppant pack.Placement of solid paraffin inhibitors into the Viking formation with the proppant during hydraulic fracturing increased cumulative production by approximately forty percent in the first 350 days on production and reduced decline rates. Comparing 150 untreated wells with the 90 wells treated with the solid paraffin inhibitor in 2012 has increased revenue by about 15.8 million USD over the 350-day period. Wells drilled in the same area, with similar frac treatments, depths, horizontal lengths and stages were compared.

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Section: Introductionmentioning

confidence: 54%

Solid Paraffin Inhibitors Pumped in Hydraulic Fractures Increase Oil Recovery in Viking Wells

Wornstaff

Hagen

Ignacz

et al. 2014

Day 2 Thu, February 27, 2014

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Drivers to the workover rig problem

Bissoli

Chaves

Ribeiro

2016

Journal of Petroleum Science and Engineering

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A Comparison of the Effectiveness of Various Fracture Fluid Systems Used in Multi-Stage Fractured Horizontal Wells: Montney Formation, Unconventional Gas

Reynolds

Bachman

Peters³

2014

All Days

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Recently, there has been discussion of the need to advance hydraulic fracturing technology from the current ‘operational effectiveness’ mode of high-rate slickwater fracture designs, to a ‘fracture effectiveness’ mode provided by optimizing designs to achieve higher recoveries and better economics. This case study shows how advanced fracture fluid system designs have increased fracture effectiveness in an area of the Montney unconventional gas play. The study focused on fifty multi-stage fractured horizontal wells in the dry gas area of the Heritage Montney Field in British Columbia, Canada. These wells were stimulated by different operators with a number of different fracturing techniques, fluid systems, etc. Wells were selected such that a sufficient variety of completion techniques were represented, and there was over 18 months of production history. A thorough review of the geology and petrophysical data within the area was undertaken in order to develop individual well descriptions for use in the production analysis (Rate Transient Analysis). Wells were history matched by varying reservoir permeability and fracture treatment properties. The results demonstrate that fracture effectiveness is a function of the fracture type and has a large effect on well productivity and economics. This case study shows there is value in optimizing fracture designs through look-back studies, and that there is a need to focus on more effective fracture treatment designs in unconventional gas development. The results of the study show the importance of fracture fluid selection as well as both effective fracture half-length and fracture conductivity in maximizing the economic returns in this area of the Montney.

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Case Study - Evaluation of Horizontal Well Multi-stage Fracturing in the Viking Oil Formation

Cited by 6 publications

References 6 publications

Solid Paraffin Inhibitors Pumped in Hydraulic Fractures Increase Oil Recovery in Viking Wells

Solid Paraffin Inhibitors Pumped in Hydraulic Fractures Increase Oil Recovery in Viking Wells

Drivers to the workover rig problem

A Comparison of the Effectiveness of Various Fracture Fluid Systems Used in Multi-Stage Fractured Horizontal Wells: Montney Formation, Unconventional Gas

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