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INNOVATIVE NANOPARTICLE TECHNOLOGY FOR DRILLING FLUIDS
- 2. CONFIDENTIAL A Canadian Technology Company – Commercializing a leading edge Nanoparticle (NP) Technology Platform – 4 filed patent applications Target Market: Chemical additives for Oil & Gas drilling fluid nForcerTM – nFluids’ 1st commercial product – Improves packing, produces a thinner, stronger, smoother and less permeable filter cake1 – Seals micro-fractures and creates pressure barrier preventing further formation breakdown – Fills in surface roughness, reduces asperity and keeps moisture out – Reduces oil on cuttings Integrated Solution - 4 Cost Saving Benefits: Other potential applications: lubricants, catalysts, re-fracking, cements, composites, electronics, medical devices, ferromagnetic fluids, surface coatings, etc. nFluids Explained 2 1. Jiao, D. & Sharma, M. “Mechanism of Cake Buildup in Crossflow Filtration of Colloidal Suspensions.” Journal of Colloid and Interface Science, 162, 454–462, (1994). Drilling Fluid Loss Reduction Wellbore Strengthening Lubrication / Friction Reduction Oil on Cuttings Reduction
- 3. CONFIDENTIAL Drilling Challenge nFluids Benefit Potential Cost Savings Costly drilling fluid losses • Thinner, stronger filter cake Resulting in: 30 – 90% reduction in drilling fluid loss • Less formation damage • Reduced rig downtime • Typical well 3,500 m3, 3-5 m3 lost / 100 m drilled • Assume HPHT FLR = 60% • Drilling fluid cost: $1,000-1,500 m3 (WTI $80+ /bbl) • Drilling fluid cost: $700 (WTI $30-40 /bbl) Potential cost savings: $45-150k per well Weakened wellbore while drilling • Strengthened core, increase in fracture pressure resistance up to 60% Resulting in: • Reduction of rig downtime Potential Cost Savings: $42k per/day Increase ROP and Hz reach • Enhanced lubrication up to 50% reduction in friction (metal-on- metal) Resulting in: • Faster drilling and longer reach Potential Cost Savings: $42k per/day Improve environmental performance • 10-15% reduction of oil on cuttings Resulting in: • Less trucking , remediation & disposal costs • Drilling fluid losses to cuttings: 10 m3 per well Potential cost saving per well = $10k - $15k Drilling Challenges & the nFluids Benefit 3
- 4. CONFIDENTIAL nFluids Nanoparticles 4 Synthesized calcium- and iron-based NPs (CNP and INP) Patented bottom-up process, successfully scaled to 1,000 kg per batch Compatible with all types of mud systems and additives Readily dispersed in oil or water under low shear conditions Effective at a low concentration (0.5 wt%) Non-reactive, non-toxic, aerosol-free, non-polluting & acid-soluble 60 wt% INP20 wt% INP in carrier oil 0.5 wt% INP in mineral oil
- 5. CONFIDENTIAL NPs Characterization 5 Figure 8 High-resolution STEM images of INP. 60,000x magnification (left) and 450,000x magnification (right). Hitachi S5500 operating at 30 kV. Holey carbon grids. INP: 3.6 ± 0.6 nm CNP: 50 ± 5 nm
- 6. CONFIDENTIAL Lab Results – HPHT Fluid Loss 176-300 °F, 500 psi, paper or 12 μm disk 6 -65% -63% -45% -72% 0 2 4 6 8 10 12 14 16 18 Diesel OBM 1 Diesel OBM 2 Diesel OBM 3 Mineral OBM 1 APIFiltrateVolumeat30min(mL×2) Control 0.5 wt% nForcer™ 90/10 1050 kg/m3 78/22 1350 kg/m3 80/20 920 kg/m3 80/20 1500 kg/m3
- 7. CONFIDENTIAL Lab Results – Lubricity OFI Lubricity Tester, 60 rpm, 150 lbf·in 7 -48% -31% -26% -15% 0 1 2 3 4 5 6 7 Diesel OBM 1 Diesel OBM 3 Mineral OBM 2 Diesel OBM 7 CoefficientofFriction Control 0.5 wt% nForcer™ 90/10 1050 kg/m3 80/20 920 kg/m3 80/20 915 kg/m3 90/10 1060 kg/m3
- 8. CONFIDENTIAL Lubricity – Observations OFI Lubricity Tester, 60 rpm, 150 lbf·in 8 0.05 0.06 0.07 0.08 0.09 0.1 0.11 0.12 0.13 Control 0.5 wt% nForcer™ 1.0 wt% nForcer™ Control Post-NP MudLubricityCoefficient • Coefficient of friction reduced with nForcer™ • Reduction observed in subsequent control sample • Deposition of NPs observed on the instrument • Indicates interaction between NPs and metal surface
- 9. CONFIDENTIAL Lab Results – Wellbore Strengthening Roubidoux sandstone cores, 90/10 Diesel OBM2 9 39% 41% 55% 58% 1400 1600 1800 2000 2200 2400 2600 2800 3000 FractureBreakdownPressure(psi) Control INP 0.5%, Graphite 0.5% INP 2.5%, Graphite 0.5% CNP 0.5%, Graphite 2% CNP 2.5%, Graphite 2% CONTROL CORE FRACTURE BREAKDOWN PRESSURE, Pfb1 FRACTURE BREAKDOWN PRESSURE WITH ADDITIVE, Pfb1 2. Contreras, O.; Hareland, G.; Husein, M.; Nygaard, R. & Alsaba, M. “Wellbore Strengthening in Sandstones by Means of Nanoparticle-Based Drilling Fluids.” SPE Deepwater Drilling and Completions Conference, Galveston, Texas, 10-11 September (2014). SPE- 170263-MS.
- 10. CONFIDENTIAL Wellbore Strengthening – Observations Catoosa shale cores, 0.5 wt% CNP, SEM 10 At fracture end: At fracture mouth: Shale core showing two vertical fractures3 NPs form a continuous seal along the fracture3 3. Contreras, O.; Hareland, G.; Husein, M.; Nygaard, R. & Alsaba, M. “Experimental Investigation on Wellbore Strengthening in Shales by Means of Nanoparticle- Based Drilling Fluids.” SPE Annual Technical Conference and Exhibition, Amsterdam, The Netherlands, 27-29 October (2014). SPE-170589-MS.
- 11. CONFIDENTIAL Field Testing – Overview 11 9 total tests completed in Alberta – 6 field tests completed4 near RMH 1st gen nForcer™ (CNP) at 0.5 wt% 12 offset wells for comparison Horizontal wells, ~4,000 m TD Shale and coal zones in build section Cardium sandstone pay zone Focus on mud loss reduction Cutter-D 90/10 to 85/15 OBM system Mud weight: 1,030 to 1,150 kg/m3 (361 to 403 lb/bbl) Group D – different lithology, no offset data, not shown herein 4. Borisov, A. S.; Husein, M. & Hareland, G. “A Field Application of Nanoparticle-based Invert Emulsion Drilling Fluids.” Journal of Nanoparticle Research, 17, 340, (2015).
- 12. CONFIDENTIAL Field Results – Total Mud Losses 1st gen nForcer™ (CNP) 0.5 wt% 12 -29% -24% -28% -21% 0 10 20 30 40 50 60 70 80 90 Control A Test A Control B Test B1 Test B2 Control C Test C TotalMudLossesatTD,m3 NOTE: Total mud losses include final surface and subsurface losses calculated between surface casing and TD
- 13. CONFIDENTIAL Field Results – Total Mud Losses 1st gen nForcer™ (CNP) 0.5 wt% 13 -34% -29% -30% -23% 0 0.5 1 1.5 2 2.5 3 3.5 Control A Test A Control B Test B1 Test B2 Control C Test C AverageMudLossesper100mDrilled,m3/100m NOTE: Average mud losses per 100 m drilled account for variations in TD between wells - final mud losses at TD divided by the interval drilled and multiplied by 100
- 14. CONFIDENTIAL nFluids Technology Summary 14 nFluids nanoparticle (NPs) products: – Iron-based nanoparticle (INP) – Calcium-based nanoparticle (CNP) Lab work focusses on three properties of drilling fluids: – Fluid loss reduction (HTHP with paper and ceramic disks) – Inhibited pressure communication in the formation (sandstone, shale, and cement core fracturing) – Lubrication (OFI metal-on-metal lubricity tester) Fracture pressure lab tests: – Up to 60% increase in fracture initiation pressure in sandstone cores with CNP (Diesel OBM) – Up to 40% increase in fracture initiation pressure in sandstone cores with INP (Diesel OBM) Lubricity lab tests: – Up to 37% reduction in coefficient of friction with CNP (metal-on-metal, Diesel OBM) – Up to 48% reduction in coefficient of friction with INP (metal-on-metal, Diesel OBM) Recent field tests: – Six full-scale field tests completed in Alberta (RMH) in 2015 – Up to 30% reduction in mud volume losses while drilling with CNP – Field results consistent with lab HPHT observations
- 15. CONFIDENTIAL Formation Damage Prevention 15 Reduced filter cake thickness and permeability – HPHT/LPLT fluid loss tests, WBM and OBM, 0.5 wt% INP Acid-soluble product – Soluble in 10% HCl Shallow depth of penetration – From SEM and EDX experiments on filter cakes Up to 90% reduction in spurt loss – WBM formulation, LPLT fluid loss, 0.5 wt% INP Up to 55% reduction in 30 min fluid loss – WBM formulation, LPLT fluid loss, 0.5 wt% INP
- 16. CONFIDENTIAL O&G Production Applications 16 Fracturing/Re-Fracturing: – Creating a pressure barrier that prevents further formation breakdown (permeability reduction) – Mono-bore design Conformance control: – Creating a fluid barrier via permeability reduction would improve conformity of the flood front in EOR Cementing: – Reducing the permeability, increasing the strength and improving the bond with metal & rock Lubrication: – Drilling-Coil Tubing – Coatings Wellbore Integrity: – Reducing the permeability and increasing the strength of shale zones etc. Corrosion Control: – Nanoparticles can be capped with hydrophobic materials-preventing water from migrating into the asperities of the material Oil & Water treatment: – Utilizing magnetic nanoparticles to remove oil from water bodies & solid materials – Removal of Arsenic etc.
- 17. www.nfluids.com Jeffrey Forsyth, CEO jforsyth@nfluids.com Jeremy Krol, VP jkrol@nfluids.com Alex Borisov, R&D aborisov@nfluids.com Hai Wang, R&D hwang@nfluids.com
- 19. CONFIDENTIAL Filter Cake With and Without NPs: SEM Characterization Filter cakes produced by HPHT fluid loss test at 250 °F Cryo-SEM performed on the profile Control OBM shows many cracks and fractures that form filtrate flow channels OBM with INP do not contain any visible fractures – consistent with reduction of filtrate volume 19 Control OBM OBM with 0.5 wt% INP
- 20. CONFIDENTIAL Wellbore Strengthening – Roubidoux Sandstone 20 Graphite, INP and CNP at different concentrations were added to OBM to study their effect on the fracture breakdown pressure, Pfb1
- 21. CONFIDENTIAL Wellbore Strengthening – Sandstone2 – Diesel OBM 21 2. Contreras, O.; Hareland, G.; Husein, M.; Nygaard, R. & Alsaba, M. “Wellbore Strengthening in Sandstones by Means of Nanoparticle-Based Drilling Fluids.” SPE Deepwater Drilling and Completions Conference, Galveston, Texas, 10-11 September (2014). SPE- 170263-MS.
- 22. CONFIDENTIAL Wellbore Strengthening – Catoosa shale 22 Graphite, INP and CNP at different concentrations were added to OBM to study their effect on the fracture reopening pressure, Pfb2
- 23. CONFIDENTIAL Wellbore Strengthening – Catoosa shale 23 0 100 200 300 400 500 600 700 800 0 10 20 30 40 50 60 Pressure,psi Time, min Effect of CNP and INP on Fracturing Pressure in Shale Cores Control CNP 0.5wt%+Graph 2wt% CNP 2.5wt%+Graph 2wt% INP 0.5wt%+Graph 0.5wt% INP 2.5wt%+Graph 0.5wt% 27%
- 24. CONFIDENTIAL Wellbore Strengthening – Shale3 – Diesel OBM 24 3. Contreras, O.; Hareland, G.; Husein, M.; Nygaard, R. & Alsaba, M. “Experimental Investigation on Wellbore Strengthening in Shales by Means of Nanoparticle-Based Drilling Fluids.” SPE Annual Technical Conference and Exhibition, Amsterdam, The Netherlands, 27-29 October (2014). SPE- 170589-MS.