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ADVANCEMENTS IN NEAR NEUTRALLY BUOYANT PROPPANTS
- 1. Advancements in Near Neutrally Buoyant Proppants Nicole Hoffman SUN Specialty Products 2023
- 2. Advancements in Near Neutrally Buoyant Proppants • Latest updates on Near Neutrally Buoyant Proppants (NBPs) • Results of a 3 well field trial in the Bakken conducted over 2017-2020 • Production results, EUR, and economic impact after usage
- 3. Low viscosity fluids will not transport proppant to the high-side of the fracture leaving pay unpropped Sand-Only Created Area: 372,128 ft2 Propped Area: 118,296 ft2 Propped/Created: 32%
- 4. Near-neutrally buoyant proppant (NBP) has the ability to fill the fracture 4.4% NBP mixed w/ Sand Created Area: 425,952 ft2 Propped Area: 401,692 ft2 Propped/Created: 94%
- 5. What are NBPs? FracBlack®HT and OmniProp Third generation of near-neutrally buoyant proppant (ASG = 1.055), comprised of thermoset nanocomposite beads with intimately dispersed nano- filler providing strong reinforcement.
- 6. Superior proppant transport 0.6 2.4 36 144 258 80/120 ULW-1.05 30/80 ULW-1.05 100 mesh sand 40/70 mesh sand 30/50 mesh sand Static Settling Velocity (ft/hour) Settling Velocity in 2 cP Slickwater (ft/hr)
- 8. Middle Bakken Case Study URTEC 5120 - Newest State of the Art Neutrally Buoyant Proppant Facilitates Placement Throughout Created Vertical Fractures to Provide Substantial Production Uplift in Unconventional Wells SPE 205845-MS - Incorporation of Neutrally Buoyant Proppants in Horizontal Unconventional Wells to Increase Propped Fracture Area Results in Substantially Improved Well Productivity and Economics
- 9. Middle Bakken Study Area • NE McKenzie Co., ND • Comp. Q4 2017 – Q1 2020 • 15 mile radius of trial wells • Approx. 149 wells NBP-2 Trial Wells
- 10. Fracture Models for NBP-2 Trial Pad Cumulative Production Predictions for Trial 1 wells, MProd Proppant Placement for Trial Wells without NBP-2, MFrac Proppant Placement for Trial 1 NBP-2 Well, MFrac
- 11. Middle Bakken Wells in McKenzie Co., ND Completed Q4’2017-’Q1’2019 Well Count TVD Lateral Length Fluid Vol. Proppant Vol Operator A w NBP-2 3 10,118 9,002 11,471,040 7,425,053 Operator A w/o NBP-2 25 10,354 10,176 15,238,946 8,707,652 Operator B 12 10,664 9,913 7,762,071 8,975,402 Operator C 23 10,771 9,936 6,197,894 7,085,984 Operator D 11 11,078 10,125 18,183,312 10,222,331 Operator E 12 10,683 9,728 9,005,167 10,312,102 Operator F 20 10,921 9,698 5,777,192 8,356,158 Operator G 24 10,809 10,977 12,522,925 13,074,723 Operator H 10 10,918 9,726 6,766,982 10,727,170 Operator I 12 10,789 10,179 6,773,187 7,062,418 All non-NBP Wells 149 10,739 10,113 9,638,953 9,096,373 TVD and Lat Length were similar for all wells Largest differences found in Fluid and Proppant Volume
- 12. Cumulative Production Data Operator Well Count Average 6 month Cumulative Production Well Count Average 12 month Cumulative Production Well Count Average 24 month Cumulative Production Operator A w NBP 3 177,346 2 364,819 1 488,471 Operator A w/o NBP 25 112,117 17 228,771 12 371,569 Operator B 12 104,041 12 189,495 12 224,051 Operator C 23 146,223 23 224,597 23 426,677 Operator D 11 117,038 11 191,453 11 225,446 Operator E 12 202,370 12 283,538 12 375,906 Operator F 20 175,017 20 278,604 20 362,535 Operator G 24 128,074 24 197,175 24 278,496 Operator H 10 156,679 10 221,009 10 193,581 Operator I 12 155,023 10 238,120 9 284,619 All non-NBP Wells 149 141,823 139 228,085 97 322,691
- 13. Normalized 6-month Cumulative Production
- 14. Normalized 12-month Cumulative Production
- 15. Normalized 24-month Cumulative Production
- 16. Study Area Top 20 Middle Bakken Wells By Normalized Cumulative Production at 24 months, bbls/Mft
- 17. Cumulative Production Averages at 24 Months Cumulative Production, bbls Normalized Cumulative Production, bbl/Mft NBP-2 Avg 503,687 bbls 50,389 bbls/Mft Top 20 Offset Avg 418,264 bbls 45,087 bbls/Mft All Offset Avg 313,158 bbls 18,364 bbls/Mft
- 18. Average Production and Decline Rate at 24 Months NBP-2 Wells 478 bopd, 52% decline All Offsets 155 bopd, 60% decline Top 20 154 bopd, 59% decline Decline Rate @ 24 months Average Daily Production @ 24 months Higher daily production coupled with reduced decline rate results in more significant impact over time
- 19. Estimated Ultimate Recovery (EUR) at 20 Years NBP-2 Wells 1,493,588 bbls Top 20 Offsets 913,398 bbls All Offsets 644,047 bbls • Significant impact over the life of the well • NBP-2 wells • 37.8 bopd • 1.494 mbo • All non-NBP-2 • 13.3 bopd • 0.644 mbo • Top 20 non-NBP • 20.3 bopd • 0.913 mbo
- 20. Net Present Value @ 20 years Based on EUR Forecasts from Reported Production Operator Well Type Well Count NPV from start (20 year), $ A NBP-2 Wells 2 24,465,773 $ A Non-NBP-2 Wells 17 13,145,157 $ B Non-NBP-2 Wells 12 6,320,746 $ C Non-NBP-2 Wells 15 6,321,894 $ D Non-NBP-2 Wells 10 7,146,069 $ E Non-NBP-2 Wells 12 5,921,379 $ F Non-NBP-2 Wells 12 8,109,226 $ G Non-NBP-2 Wells 21 4,130,886 $ H Non-NBP-2 Wells 10 4,618,210 $ I Non-NBP-2 Wells 6 6,488,512 $ All Non-NBP-2 Well Averages 115 6,911,342 $ Top 20 Non-NBP Wells Avgs 20 13,530,625 $
- 21. Advancements in Near Neutrally Buoyant Proppant • Near Neutrally Buoyant Proppants have shown superior transport versus conventional proppants • This allows an increase in Propped vs. Created fracture area resulting in significant production improvements • NBP wells on average outperformed offsets by over 50% in Middle Bakken Case Study • Increased production over time resulted in significant economic impact both early on and over time
- 22. Questions?
Editor's Notes
- Proppant Transport additive Proppant Transport Solution Fracture Height Enhancement Additive Fracture Geometry Enhancement Additive Other thoughts that can be added on to these classifications: With propping capability, high conductivity Will fill the gaps where conventional proppant cannot get to. The material has adequate/exceptional conductivity and will not compromise well integrity, it will enhance productivity Sun leveraged several (x number) of years worth of chemical and polymer experience combined with fracture design skills (brought in by BJ / Harold) to develop an ultralightweight height/geometry enhancing additive with propping capabilities. This solution was developed to specifically address insufficiently propped fractures thus increasing value to wells.
- Due to superior transportability
- FracBlack is our 3rd generation material. We manufacture it with our rapid rate polymerization process. That means that when the beads start to form, they form quickly and in doing so literally become entangled with other chains giving them a multiplier effect in strength. The suspension of carbon black that is surrounding them becomes trapped in the process, providing the bead a stronger reinforcement that minimizes compression. As an example: Without the reinforcement, the bead would have a strength relative to a tennis ball … Now with the carbon black strengthening the bead, it becomes more like a golfball. FracBlack™ es nuestra 3ra generacion del material. Se fabrica con nuestro proceso de ritmo rápido de polimerización. Eso significa que cuando las esferas comienzan a formarse, se forman rápidamente de manera que se enredan con otras cadenas, dándoles un efecto multiplicador en la fuerza. La suspensión de carbón negro que le rodea, se atrapa en el proceso, produciendo una esfera más fuerte y reforzada que reduce la compresión Por ejemplo: sin el refuerzo, la esfera tendría la fuerza relativa a una pelota de tenis. Con el carbón negro fortaleciendo la esfera, la fuerza se compara a una pelota de golf.
- Note the multiple operators and well counts Average cumulative production recorded at 6, 12 and 24 months
- How and why is the data normalized? per 1000 feet of lateral length to make equivalent comparisons
- by Normalized Cumulative Production at 24 months, bbls/Mft
- Discussion on the latest updates on near neutrally Buoyant proppants Results of a 3 well field trial in the Bakken conducted over 2017-2020 Looking at the production results, EUR, and economic impact after usage