The Value Proposition for Applying Advanced Completion and Stimulation Designs to the Bakken Central Basin

Griffin, Lawrence Gene; Pearson, C. Mark; Strickland, Stacy; McChesney, Jeromy; Wright, C.A.; Mayer, Jerrold; Coleman, Bill; Roth, Michael; Weijers, Leen

doi:10.2118/166479-ms

Cited by 27 publications

(7 citation statements)

References 2 publications

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“…Consequently, it is not uncommon for different operators to have a difference of over 2 million dollars in their AFE's solely because of the differences in their approach to the well's completion and stimulation design. (Griffin et al 2013) To check the completion and stimulation cost effects on 18 months of cumulative production, a heat map was generated in Figure 22. The plot shows the completion cost effects on the cumulative 18 months of production.…”

Section: Cost Analysismentioning

confidence: 99%

Data Mining and Statistical Analysis of Completions in an Unconventional Play: The Canadian Montney Formation

Al-Alwani¹,

Britt²,

Dunn-Norman³

2015

Unconventional Resources Technology Conference

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The drilling, completion, and stimulation of multiple fractured horizontal wells has proven to be an effective means of extracting hydrocarbons from unconventional resources. Since the first application of this technology by Maersk in the Dan Field in the mid-1980's oil and gas reservoirs have seen improved productivity and profitability. However, identifying the key drivers for success of multiple fractured horizontal well technology has proven difficult especially in unconventional reservoirs where data is limited. With few vertical wells, logs and core data typically used for building a basis of completion and stimulation design are often lacking. As a result, other methods of identifying success drivers must be developed and utilized.To this end, this paper utilizes a data-mining and statistical analysis of well, completion, fracture stimulation, and production data to establish the important parameters for success in horizontal wells in the Montney Formation of Alberta and British Columbia, Canada. In this study more than 3,300 horizontal wells were characterized with respect to lateral length, completion type, number of stages, fracture fluids pumped, proppant loading, costs, and production. The study utilized the statistical software JMP to identify key relationships between well data. The software system allowed standard screening and more advanced graphical methods to be applied to validate the dataset. From the quality assured dataset various additional parameters were calculated and used in the analysis.Both regression analysis and statistical 'heat maps' were used to correlate and visualize data trends. Heat maps are shown as a useful tool for visualizing strongly trending data. Another finding from this study is that cased and cemented horizontal wells in the Montney Formation had significantly better initial productivity (ϩ31%) and first year cumulatives (ϩ42%) than open hole external packer completion systems even though the cased and cemented wellbores had fewer stages (-40%), larger stimulations (ϩ390%), and increased costs (ϩ14%).While additional completed stages may increase cumulative recovery in the Montney Formation, statistical analysis demonstrates the recovery per stage decreases after a certain stage density. This conclusion is consistent with recent findings (VISAGE and Jim Gouveia 2014). Results of the study clearly demonstrate that wells with the smallest frac fluid load recovery have the best cumulative gas recovery with time, and spending more for the completion translates into higher production. This work is important as it identifies relevant completion trends in the Montney Formation and completion and stimulation practices linked to higher recovery and well success. This is also the first field-wide statistical review of wells completed in the Montney Formation using more advanced data mining and statistical analysis. The work lays a foundation for application of these techniques to more unconventional and tight oil and gas reservoirs.

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Section: Cost Analysismentioning

confidence: 99%

Data Mining and Statistical Analysis of Completions in an Unconventional Play: The Canadian Montney Formation

Al-Alwani¹,

Britt²,

Dunn-Norman³

2015

Unconventional Resources Technology Conference

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“…Some recent studies have shown that water/ (oilϩwater) ratio based on cumulative production (water cut) has good correlation with vertical depth, thermal maturity, hydrocarbon generation, oil migration, pore-overpressureand and production (Cosima Theloy, 2013 andLarry Griffin, 2013).…”

Section: Well Selection Processmentioning

confidence: 99%

“…Larry Griffin (2013) pointed out that in the Central Basin area, in general, there is a direct and significant relationship with depth and water cut. Larry Griffin (2013) pointed out that in the Central Basin area, in general, there is a direct and significant relationship with depth and water cut.…”

Section: Well Selection Processmentioning

confidence: 99%

“…As one of the largest oil developments in the U.S. in the past 40 years, it gave a big boost to North Dakota's oil production, which leaped to the second place among oil-producing states in the United States (DuBose, 2012;Cosima et al, 2013). The Williston Basin is one of the most structurally simple basins with gentle regional dip (DuBose, 2012;Larry et al, 2013). 1).…”

Section: Introductionmentioning

confidence: 99%

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The Contributing Factors of Stimulation Design to Incremental and Long-Term Productivity in Bakken Play

Zhou

Xue

et al. 2015

All Days

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The combination of horizontal drilling, multistage completion and hydraulic fracturing has been the key factor for the successful development of the Bakken play. This dominant status reflects in two aspects: the enhancement of well production, making stripper well even dry well valuable for industrial development, and the effect of long-term flow conductivity on the 'sustained yield' of well. This paper quantitatively analyzed the stimulation design factors and their interactions contributing to incremental and long-term productivity of horizontal wells in Bakken respectively for different geologic environment.Data from more than 1000 wells located in the Bakken Central Basin area containing production and stimulation design have been collected from the Premium Services of North Dakota Industrial Commission (NDIC) website and the FracFocus.org. Wells were grouped and analyzed by similar water cut based on cumulative production for the normalization of variation in geologic heterogeneity. Response surface methodology (RSM) was applied as the methods of quantitative analysis to determine the contributing factors and their interactions. In this study, 2-month and 12-month cumulative oil production per perforated length were used as the indicators of incremental productivity and long-term productivity respectively.The data are divided into three reservoir-homogeneous groups according to different water cut range and a separate slickwater fracturing group. The effects of stimulation design factors and their interactions on the incremental productivity and long-term productivity were investigated. Results indicates that among all the factors, perforated length, proppant/perf length, water/ perf length, percentage of ceramic are the most contributing factors of stimulation design to incremental and long-term productivity. Different group are influenced by different combination of contributing factors. Most groups share the same significant interaction between perforated length and water/ perf length, as perforated length increases and water/ perf length decreases meawhile, the cumulative oil production per perforated pength climbs rapidly, with the amount of other design factors fixed.Previous similar analysis focused on 30, 60 and 90-day cumulative production with smaller data volume to generate well performance metrics for the lack of enough wells. This paper utilized the larger data set with longer production time span and analyzed the stimulation design factors contributing to incremental and long-term productivity of horizontal wells in Bakken respectively. These results are more valuable for optimization of stimulation design in the Bakken play and similar reservoirs faced with dynamic and changing oil market.

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“…Griffin et al (2013) and Pearson et al (2013) analyzed and compared the completion and production data from 1185 wells in the Central Basin of the Bakken Shale. It is possibly the easiest cost to control or lower.…”

Section: Economics Analysismentioning

confidence: 99%

Proppants Selection Based on Field Case Studies of Well Production Performance in the Bakken Shale Play

Sun

Wong

et al. 2014

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A brief overview of different proppant types and amounts used in stimulation designs in the Bakken shale play since 2011 is presented in this paper. The primary goal of the paper is to determine the long-term production and economical effectiveness on hydraulically fractured wells using different proppant types, percentages of proppant types and overall amount of proppant in the well completions. The results are based on four case studies that focus on 72 wells in four different fields in the Bakken formation of the Williston Basin.In these four case studies, the primary variable that affects the difference in long-term production of the different well groups is the percentage and amount of each proppant type used in the completion design. Completion and stimulation data was collected from public resources such as the North Dakota Industrial Commission (NDIC) database. In each case study, wells in the same field were grouped. For each group of wells, the average long-term production and economical effectiveness was analyzed.The case studies in the Capa Field in Williams County North Dakota and the Chimney Butte Field in Dunn County North Dakota shows that over a 270 day period, in each group of wells completed with about 30 percent ceramic proppant mixed with silica sand, the wells produced an average of over 100 percent more than the comparable group of wells completed using only silica sand. The case study in the East Fork Field in Williams County North Dakota shows that after 270 days of production, the group of wells using 100 percent ceramic proppant attained an average of 27 percent production increase over the group of wells using an average of 62 percent ceramic proppant. These wells also attained a 67 percent production increase over the group of wells using an average of 35 percent ceramic proppant.In comparing completion procedures in these high-producing fields, using a combination of high percentages and large amounts of ceramic proppant has yield higher production and EUR. The use of ceramic proppant not only covers the additional proppant cost in a short period of time, but also generates higher revenue in the long term. The findings from these case studies should apply to all fields that have similar reservoir characteristics.

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The Value Proposition for Applying Advanced Completion and Stimulation Designs to the Bakken Central Basin

Cited by 27 publications

References 2 publications

Data Mining and Statistical Analysis of Completions in an Unconventional Play: The Canadian Montney Formation

Data Mining and Statistical Analysis of Completions in an Unconventional Play: The Canadian Montney Formation

The Contributing Factors of Stimulation Design to Incremental and Long-Term Productivity in Bakken Play

Proppants Selection Based on Field Case Studies of Well Production Performance in the Bakken Shale Play

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