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1、HORIZONTAL WELL FRACTURINGWellbore orientation affects recovery&fracture complexity,Key Issues in Horizontal Well Fracturing,Fracture ComplexityInitiation,perforating,proppant slugs,cement bondInterval CoverageWellbore-to-Fracture CommunicationWellbore TrajectoryWellbore Clean-out&Stage Isolation,Mi
2、nimize Fracture Complexity,Good Communication to the Perfs,&Optimum Interval Coverage,Multiple Transverse Fractures,Thick reservoirsEffective when long Xf possibleCompartmentalized reservoirsPreferred for intersecting existing fracturesCan be difficult and expensive to place in desired locations,Fro
3、m Barree and Associates,Longitudinal Fractures,Thin reservoir sectionsLow kv/kh in thick reservoirsBetter when effective Xf is lowBetter in continuous reservoirsLarge volume treatmentsEasy to place and pump effectively,From Barree and Associates,Fracture Treatment Design and Execution in Chalk Reser
4、voirs,South Arne,Amerada Hess Denmark Case History,South Arne Field,Danish North SeaHorizontal Wells 9500 TVD(2890m)3000-6000 ft HZ section,(915-1830m)10-15 stagesTip Screen-out(TSO)FracturingOver-pressured(0.67 psi/ft)Low Modulus Chalk(0.5 1.5 MMpsi)Moderate Permeability(0.1 4 mD),The Setting,South
5、 Arne Field,South Arne Discovery by DUC:1969Amerada 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 Arne Development Concept,Conceptual well design.Hori
6、zontal 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 SLUGS&XL GEL REDUCE COMPLEXITY,Before Proppant Slug,Aft
7、er 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 klbs 16/30-mesh(427.5t),47%efficiency,15+ppa,4 ppa 100-mesh,4 ppa 100-me
8、sh,Well 4,Zone 4 Fracture Geometry,South Arne FieldNorth Development,Wells 1-564 zones(67 treatments)51 million pounds of proppant(22950 t)Wells 1-5 treatment parametersPad size(132.7m3)35 kgal(22%)Slurry(606.4m3)160 kgalProppant(360 t)800 klbs100-mesh(9 t)20 klbsTSO dP/dt 25 psi/minFluid Efficiency
9、 40%Avg.Tor Porosity 35%Mini-fracs prior to almost all treatments,top Tor depth,m,South Arne FieldSouth Flank Development,Well 911 zones(12 treatments)6.7 million pounds of proppant(3015 t)Wells 9 treatment parametersPad size(795m3)210 kgal(53%)Slurry(1516m3)400 kgalProppant(3015t)670 klbs100-mesh(4
10、9.5t)110 klbsTSO dP/dt 26 psi/minFluid 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 1-5Average porosity35%Average modulus1.0 MMpsiWell 7Average porosity29%Average modulus1.5 MMpsiWell 9Average 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,
