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1、HORIZONTAL WELL FRACTURINGWellbore orientation affects recovery & fracture complexity,Key Issues in Horizontal Well Fracturing,Fracture Complexity Initiation, perforating, proppant slugs, cement bond Interval Coverage Wellbore-to-Fracture Communication Wellbore Trajectory Wellbore Clean-out & Stage
2、Isolation,Minimize Fracture Complexity, Good Communication to the Perfs, & Optimum Interval Coverage,Multiple Transverse Fractures,Thick reservoirs Effective when long Xf possible Compartmentalized reservoirs Preferred for intersecting existing fractures Can be difficult and expensive to place in de
3、sired locations,From Barree and Associates,Longitudinal Fractures,Thin reservoir sections Low kv/kh in thick reservoirs Better when effective Xf is low Better in continuous reservoirs Large volume treatments Easy to place and pump effectively,From Barree and Associates,Fracture Treatment Design and
4、Execution in Chalk Reservoirs,South Arne, Amerada Hess Denmark Case History,South Arne Field, Danish North Sea Horizontal Wells 9500 TVD (2890m) 3000-6000 ft HZ section, (915-1830m) 10-15 stages Tip Screen-out (TSO) Fracturing Over-pressured (0.67 psi/ft) Low Modulus Chalk (0.5 1.5 MMpsi) Moderate P
5、ermeability (0.1 4 mD),The Setting,South Arne Field,South Arne Discovery by DUC:1969 Amerada Hess:1994 Proven commercial:1996 First oil: 1999 Over pressured chalk reservoir Faults & natural fractures Low water saturation Formation: 80-100% CaCo3 Porosity: 20-45% Permeability: 0.1-5 md 240F,South Arn
6、e Development Concept,Conceptual well design. Horizontal parallel wells aligned with fracture direction,Reservoir Data & Layer Properties,First Three Treatments Failed,Second South Arne Treatment: 30% porosity zone,First Three Treatments Failed,Second South Arne Treatment: 30% porosity zone,PROPPANT
7、 SLUGS & XL GEL REDUCE COMPLEXITY,Before Proppant Slug,After Proppant Slug,Dominant Fracture,Plugged off multiple hydraulic fractures,Well 4, Zone 6: Typical South Arne TreatmentTor Porosity 33%,TSO dP/dt = 21 psi/min,Pad = 24 kgal (15%)(90m3) Slurry = 163 kgal(617.8m3) 9 klbs 100-mesh(4.5 t) 950 kl
8、bs 16/30-mesh(427.5t),47% efficiency,15+ ppa,4 ppa 100-mesh,4 ppa 100-mesh,Well 4, Zone 4 Fracture Geometry,South Arne FieldNorth Development,Wells 1-5 64 zones (67 treatments) 51 million pounds of proppant (22950 t) Wells 1-5 treatment parameters Pad size (132.7m3) 35 kgal (22%) Slurry (606.4m3)160
9、 kgal Proppant(360 t)800 klbs 100-mesh(9 t) 20 klbs TSO dP/dt 25 psi/min Fluid Efficiency 40% Avg. Tor Porosity 35% Mini-fracs prior to almost all treatments,top Tor depth, m,South Arne FieldSouth Flank Development,Well 9 11 zones (12 treatments) 6.7 million pounds of proppant (3015 t) Wells 9 treat
10、ment parameters Pad size (795m3)210 kgal (53%) Slurry (1516m3)400 kgal Proppant(3015t)670 klbs 100-mesh(49.5t)110 klbs TSO dP/dt 26 psi/min Fluid Efficiency 6% Avg. Tor Porosity 25% Mini-fracs eliminated,top Tor depth, m,100-mesh volume & Proppant Placed: Well 9,South Arne Field Wide Results,Wells 1
11、-5 Average porosity35% Average modulus1.0 MMpsi Well 7 Average porosity29% Average modulus1.5 MMpsi Well 9 Average porosity25% Average modulus2.2 MMpsi,top Tor depth, m,100-mesh Volume & Pad size,DIFFICULTIES OF HORIZONTAL WELL FRACTURING IN BELRIDGE FIELD,COMPLEXITIES OF HORIZONTAL WELL FRACTURING,