HORIZONTALWELLFRACTURING水平井压裂英文

1、horizontal well fracturingwellbore orientation affects recovery & fracture complexitytransverse fracturesfractures oblique to wellbore orientationlongitudinal fractureshz well pathkey issues in horizontal well fracturing fracture complexity initiation, perforating, proppant slugs, cement bondint

2、erval coveragewellbore-to-fracture communicationwellbore trajectorywellbore clean-out & stage isolationminimize fracture complexity, good communication to the perfs, & optimum interval coveragemultiple transverse fractures thick reservoirs effective when long xf possible compartmentalized re

3、servoirs preferred for intersecting existing fractures can be difficult and expensive to place in desired locationsfrom barree and associateslongitudinal fractures thin reservoir sections low kv/kh in thick reservoirs better when effective xf is low better in continuous reservoirs large volume treat

4、ments easy to place and pump effectivelyfrom barree and associatesfracture treatment design and execution in chalk reservoirssouth 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

5、-out (tso) fracturing over-pressured (0.67 psi/ft) low modulus chalk (0.5 1.5 mmpsi) moderate permeability (0.1 4 md)the settingsouth arne fieldsouth arne discovery by duc:1969amerada hess:1994 proven commercial:1996 first oil: 1999 over pressured chalk reservoir faults & natural fractures low w

6、ater saturation formation: 80-100% caco3 porosity: 20-45% permeability: 0.1-5 md 240fsouth arne development conceptproducer - injector - producerconceptual well design. horizontal parallel wells aligned with fracture directionreservoir data & layer properties240 ftormarll. ekofisktight zonem. ek

7、ofisku. ekofiskshale9425 ftstress h0.77 psi/ft20 -30%0 - 25 m12 -83 m20 - 43%0. 66 to 0.77 psi/ft12 - 24%0 - 2 m12 -83 m 5 - 15 m25 -35%0.83 psi/ft0.77 psi/ft0.77 psi/ft0.78 psi/ft0.83 psi/ft15 -35%123456789101112240 ftormarll. ekofisktight zonem. ekofisku. ekofiskshale9425 ftstress h0.77 psi/ft20 -

8、30%0 - 25 m12 -83 m20 - 43%0. 66 to 0.77 psi/ft12 - 24%0 - 2 m12 -83 m 5 - 15 m25 -35%0.83 psi/ft0.77 psi/ft0.77 psi/ft0.78 psi/ft0.83 psi/ft15 -35%123456789101112triaxial compaction test data(north sea chalk fields - jcr)e = f() = 19,558e-8,8016 0.00.51.01.52.02.510%20%30%40%50%porosityyoungs modul

9、us, e (10e6 psi)time (mins)dead string press (psi)slurry flow rate (bpm)btm prop conc (ppg) 0.0 116.0 232.0 348.0 464.0 580.0 0 1000 2000 3000 4000 5000 0.00 10.00 20.00 30.00 40.00 50.00 0.00 2.00 4.00 6.00 8.00 10.00annulus pressureslurry ratebh prop conc.inj. #1screen-outinj. #2inj. #3inj. #4prop

10、ped treatmenttime (mins)dead string press (psi)slurry flow rate (bpm)btm prop conc (ppg) 0.0 116.0 232.0 348.0 464.0 580.0 0 1000 2000 3000 4000 5000 0.00 10.00 20.00 30.00 40.00 50.00 0.00 2.00 4.00 6.00 8.00 10.00annulus pressureslurry ratebh prop conc.inj. #1screen-outinj. #2inj. #3inj. #4propped

11、 treatmentfirst three treatments failed700071007200730074007500760077007800790000.511.522.533.54g-functionbhp (psi)050100150200250300350400bhpdp/dggdp/dgfissure opening700071007200730074007500760077007800790000.511.522.533.54g-functionbhp (psi)050100150200250300350400bhpdp/dggdp/dgfissure openingsec

12、ond south arne treatment: 30% porosity zone70007200740076007800800082008400860000.511.522.533.54g-functionbhp (psi)050100150200250300350400bhpdp/dggdp/dgfissure opening70007200740076007800800082008400860000.511.522.533.54g-functionbhp (psi)050100150200250300350400bhpdp/dggdp/dgfissure opening6500660

13、067006800690070007100720073007400750000.20.40.60.811.21.41.61.82g-functionbhp (psi)050100150200250300350400450500bhpdp/dggdp/dgfissure opening?6500660067006800690070007100720073007400750000.20.40.60.811.21.41.61.82g-functionbhp (psi)050100150200250300350400450500bhpdp/dggdp/dgfissure opening?bhpdp/d

14、ggdp/dgfissure opening6500670069007100730075007700790081008300850000.511.522.533.544.55g-functionbhp (psi)01002003004005006007008009001000bhpdp/dggdp/dgfissure opening6500670069007100730075007700790081008300850000.511.522.533.544.55g-functionbhp (psi)01002003004005006007008009001000first three treat

15、ments failedtime (mins)dead string press (psi)slurry flow rate (bpm)btm prop conc (ppg) 0.0 116.0 232.0 348.0 464.0 580.0 0 1000 2000 3000 4000 5000 0.00 10.00 20.00 30.00 40.00 50.00 0.00 2.00 4.00 6.00 8.00 10.00annulus pressureslurry ratebh prop conc.inj. #1screen-outinj. #2inj. #3inj. #4propped

16、treatmenttime (mins)dead string press (psi)slurry flow rate (bpm)btm prop conc (ppg) 0.0 116.0 232.0 348.0 464.0 580.0 0 1000 2000 3000 4000 5000 0.00 10.00 20.00 30.00 40.00 50.00 0.00 2.00 4.00 6.00 8.00 10.00annulus pressureslurry ratebh prop conc.inj. #1screen-outinj. #2inj. #3inj. #4propped tre

17、atmenttime (mins)dead string press (psi)slurry flow rate (bpm)btm prop conc (ppg) 0.0 116.0 232.0 348.0 464.0 580.0 0 1000 2000 3000 4000 5000 0.00 10.00 20.00 30.00 40.00 50.00 0.00 2.00 4.00 6.00 8.00 10.00annulus pressureslurry ratebh prop conc.inj. #1screen-outinj. #2inj. #3inj. #4propped treatm

18、enttime (mins)dead string press (psi)slurry flow rate (bpm)btm prop conc (ppg) 0.0 116.0 232.0 348.0 464.0 580.0 0 1000 2000 3000 4000 5000 0.00 10.00 20.00 30.00 40.00 50.00 0.00 2.00 4.00 6.00 8.00 10.00annulus pressureslurry ratebh prop conc.inj. #1screen-outinj. #2inj. #3inj. #4propped treatment

19、second south arne treatment: 30% porosity zoneproppant slugs & xl gel reduce complexitybefore proppant slugafter proppant slugdominant fractureplugged off multiple hydraulic fracturessa-1c, zone 4 mini-frac pressure responseekofisk and tor time (mins)surf press ann (psi)slurry flow rate (bpm)bh

20、prop (ppg) 125.0 129.0 133.0 137.0 141.0 145.0 0 1000 2000 3000 4000 5000 0.0 20.0 40.0 60.0 80.0 100.0 0.00 10.00 20.00 30.00 40.00 50.00annulus pressure100-m esh sand20/40-m esh proppantratebh p conc.a nnulus pressure decreases 1000-psi w hen 1-4 ppg 100-m esh slug passes though the perforationssl

21、ight decrease in annulus pressure w hen 20/40-m esh proppant slug passes through perforationswell 4, zone 6: typical south arne treatmenttor porosity 33%time (mins)net pressure (psi)observed net (psi)bth prop conc slurry rate (bpm) 150.0 180.0 210.0 240.0 270.0 300.0 0 500 1000 1500 2000 2500 0 500

22、1000 1500 2000 2500 0.0 20.0 40.0 60.0 80.0 100.0 0.0 20.0 40.0 60.0 80.0 100.0slurry ratebh prop conc.model net pressureactual net pressuremini-fractime (mins)net pressure (psi)observed net (psi)bth prop conc slurry rate (bpm) 150.0 180.0 210.0 240.0 270.0 300.0 0 500 1000 1500 2000 2500 0 500 1000

23、 1500 2000 2500 0.0 20.0 40.0 60.0 80.0 100.0 0.0 20.0 40.0 60.0 80.0 100.0slurry ratebh prop conc.model net pressureactual net pressuremini-fractso dp/dt = 21 psi/minpad = 24 kgal (15%)(90m3)slurry = 163 kgal(617.8m3)9 klbs 100-mesh(4.5 t)950 klbs 16/30-mesh(427.5t)47% efficiency15+ ppa4 ppa 100-me

24、sh4 ppa 100-meshwell 4, zone 4 fracture geometry60006750750082509000 9650 9600 9550 9500 9450 9400 9350 9300 9250 9200 9150stress profileclosure stress (psi)permeabilitylowhighproppant concentration (lb/ft)0.002.04.06.08.0 10 12 14 16 18 20concentration of proppant in fracture (lb/ft) 0125250375500l

25、ength (ft)depth (ft)torek60006750750082509000 9650 9600 9550 9500 9450 9400 9350 9300 9250 9200 9150stress profileclosure stress (psi)permeabilitylowhighproppant concentration (lb/ft)0.002.04.06.08.0 10 12 14 16 18 20concentration of proppant in fracture (lb/ft) 0125250375500length (ft)depth (ft)tor

26、eksouth arne fieldnorth developmentwells 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 kgal proppant(360 t)800 klbs 100-mesh (9 t) 20 klbs tso dp/dt 25 psi/min fluid efficiency 40% avg. tor poros

27、ity 35%mini-fracs prior to almost all treatments-3000-3000-3000-3000-3000-3000-3000-3000-3125-3125-2875-2875-2875-2875-2875-2875-2875-2875-312505001000150020002500m1:380151234579hydraulic fracture directionpropped fracacid frac-3000-3000-3000-3000-3000-3000-3000-3000-3125-3125-2875-2875-2875-2875-28

28、75-2875-2875-2875-312505001000150020002500m1:380151234579hydraulic fracture directionpropped fracacid fractop tor depth, msouth arne fieldsouth flank developmentwell 9 11 zones (12 treatments) 6.7 million pounds of proppant(3015 t)wells 9 treatment parameters pad size (795m3)210 kgal (53%) slurry (1

29、516m3)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-3000-3000-3000-3000-3000-3000-3000-3000-3125-3125-2875-2875-2875-2875-2875-2875-2875-2875-312505001000150020002500m1:380151234579hydraulic fracture di

30、rectionpropped fracacid frac-3000-3000-3000-3000-3000-3000-3000-3000-3125-3125-2875-2875-2875-2875-2875-2875-2875-2875-312505001000150020002500m1:380151234579hydraulic fracture directionpropped fracacid fractop tor depth, m100-mesh volume & proppant placed: well 90200400600800100012001400050100150200250100-mesh volume (klbs)proppant volume (klbs)0200400600800100012