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206-170
• • 20 6 1 70 WELL LOG TRANSMITTAL#904248777 29381 To: Alaska Oil and Gas Conservation Comm. June 14, 2018 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JUN 202013 RE: Depth Determination: 2Z-13A AOGCC Run Date: 8/21/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2Z-13A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21360-01 Depth Determination(Field Print) 1 color log 50-029-21360-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating 2 �� �� Attn: Fanny Sari SCANNED JUN 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 . i FRS ANC @hal l iburton.com Date: 0/p1 W/LO & Signed: .4,J, I RECEIVED 2 3� SEP 2 9 2017 WELL LOG TRANSMITTAL#904252024 AOGCC To: Alaska Oil and Gas Conservation Comm. September 26, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 DATA LOGGED to 3 izoi-Z M K BENDEP SCANNED RE: Multi Finger Caliper : 2Z-13A Run Date: 8/21/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2Z-13A Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21360-01 Multi Finger Caliper (Field Log) 1 color log, ea. 50-029-21360-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3527 FRS_ANC@halliburton.com Date: Signed: / ✓aiztip.• r° r • 0 1 (.9 ie, C) T o > ? v CI cn ol �rwv ° N (7 N Z OA +-' r° > (D 0 °�.w t v� ra 4- '0 CO �7m u ° a E > 3 ao Y u° o` a ra C C + °) O ra +J ca 'C +, sr ilLjem - ca O -a a co c ci, ri Q o_ Y E a Q m Q J w N. 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LL a a a a a a aaa ° a 4 +' o Y Y Y Y Y Y Y Y Y ro uV to f0 '-/fit UW CO N CO O 0 0 r N N X N fa 3 _w CC : N N N N M CO t00 CO tD �) Q", 0 0 0 0 0 0 0 0 0 a) O O O O O O O O O 1.11011CD U It F- n N n N N co Cl)N co co co co co co O O O C 1111 Cr) ce N E E E E E E co N co as 0 0 0 0 0 0 0 0 0 0 C W CO N CO LU W 4- Q O O O O O O O O \C Ce k O O (73 O O O O O O to V CON CO N 4 4 N O O CO O O 6) a111 E t0 COt0 L 0 (41 N CO CO 0 O) 6) M M_ O U r',.. N N r r N N N N N N CC's! N N Nt. _a I.Z. T CD 6) Cf) CA C) C) 6) 6) a) N 0 N N N N N N N N N t re 61 O O O O O O O 0 0 3 i 00 0 0 0 0 0 0 0 a+ O a) _, 00 in in u) IC) U) U) � Unu) a 0 aa w u�iv CO 0Ci L1- rn E a) Y w �' o w cc C C OD U 0) Q Oh ns 3 O. Wz Y oo ri z NO O _ _ CO CO N N a- M M Y E N V3 = d N ria N w > > X CO O Q < N N E 03 i s c — CL Q ° N —IN N N N M N N N z a) r0 0 CO3 a Q —i H ai a Q'. STATE OF ALASKA AliPKA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ ' Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well it Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development 0 Exploratory❑ 206-170 3.Address: P. O. Box 100360,Anchorage, Stratigraphic❑ Service❑ 6.API Number: Alaska 99510 50-029-21360-01 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 2Z-13A ADL 25646,ADKL 25653 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9,300 feet Plugs measured None feet true vertical 6,089 feet Junk measured None feet Effective Depth measured 9,142 feet Packer measured 7,818 feet true vertical 6,095 feet true vertical 5,766 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 44 feet 16 80'MD 80 TVD ������ SURFACE 4,168 feet 9 5/8 " 4,203'MD 3360 TVD PRODUCTION 8,474 feet 7 " 8,507'MD 6091 TVD LINER A 512 feet 2 3/8 " 9,142'MD 6095 MD SEP 2 1 2017 AOG Tubing(size,grade,measured and true vertical depth) 3.5" L-80/J-55 8,154' MD 6,012'TVD Packers and SSSV(type,measured and true vertical depth) FHL PACKER-PACKER,BAKER,4762 FHL 7,818'MD 5,766'TVD FB-1 PACKER-BAKER PERMANENT PACKER 8,151' MD 6,010'TVD SSSV -NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A SCANNED NOV 0 12U17 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN — — — — Subsequent to operation: SHUT-IN — — — — 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development 0 Service❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR El WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Name:Andrew Beat Authorized Name: Andrew Beat Contact Email:Andrew.T.Beat@cop.com Authorized Title: Sr.Wells Engineer 17Z-VI � Z- ' ? Contact Phone: (907)265-6341 Authorized Signature: ;\ - Date: V77- I o/b /17- Ai oi4it !AitO14I(7 RBD liS k;V SE.? �e�. 2 J LU i7 Form 10-404 Revised 4/2017 _Submit Original Only S I Operations Summary (with Timelog Depths) ... 2Z-13 CortocoPhiffips • Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftK6} 8/7/2017 8/7/2017 1.75 MIRU MOVE RURD P Release Doyon 14 off 2G-15. Skid rig 0.0 0.0 14:00 15:45 to center of carrier. 8/7/2017 8/7/2017 1.50 MIRU MOVE MOB P Move rig off 2G-15 and stage on other 0.0 0.0 15:45 17:15 side of pad. 8/7/2017 8/7/2017 1.00 MIRU MOVE RURD P Remove BOPE from cellar and install 0.0 0.0 17:15 18:15 on transport cradle. 8/7/2017 8/7/2017 0.75 MIRU MOVE RURD P Remove bell nipple. 0.0 0.0 18:15 19:00 8/7/2017 8/7/2017 1.00 MIRU MOVE MOB P Move and stage rig at 2G pad 0.0 0.0 19:00 20:00 entrance on double matting boards. 8/7/2017 8/8/2017 4.00 MIRU MOVE SVRG P PJSM-Remove BOPE pedestal. 0.0 0.0 20:00 00:00 Change out one of two tires on cellar ODS.Sim-ops/Lay mats on 2G access road. 8/8/2017 8/8/2017 2.25 MIRU MOVE SVRG P Change second tire on cellar ODS. 0.0 0.0 00:00 02:15 Continue to lay mats on 2G access road. 8/8/2017 8/8/2017 0.50 MIRU MOVE RURD P !natal!BOPE pedestal and rear 0.0 0.0 02:15 02:45 steering link.Continue to lay mats on 2G access road. 8/8/2017 8/8/2017 1.50 MIRU MOVE RURD P Install front and rear booster wheels. 0.0 0.0 02:45 04:15 Continue to lay mats on 2G access* road. 8/8/2017 8/8/2017 1.75 MIRU MOVE WAIT P Continue to lay mats on 2G access 0.0 0.0 04:15 06:00 road.Allow 2G pad operators to change out. 8/8/2017 8/8/2017 2.75 MIRU MOVE MOB P Move rig to end of mats laid on 2G 0.0 0.0 06:00 08:45 access road. 8/8/2017 8/8/2017 3.15 MIRU MOVE WAIT P Pick up mats behind rig and triple 0.0 0.0 08:45 11:54 stack behind rig.Sim-ops/Prime and paint rig. 8/8/2017 8/8/2017 1.50 MIRU MOVE MOB P Back rig over stacked mats. 0.0 0.0 11:54 13:24 8/8/2017 8/8/2017 1.50 MIRU MOVE WAIT P Lay out mats in front of rig.Sim- 0.0 0.0 13:24 14:54 ops/Prime and paint rig. 8/8/2017 8/8/2017 1.50 MIRU MOVE MOB P Back up rig to clear more mats. 0.0 0.0 14:54 16:24 8/8/2017 8/8/2017 5.75 MIRU MOVE WAIT P Lay out mats in front of rig to 0.0 0.0 16:24 22:09 intersection of 2G access road and Spine road.Sim-ops/Perform housekeeping,work on MP2's. 8/8/2017 8/8/2017 1.75 MIRU MOVE MOB P Move rig to intersection of 2G access 0.0 0.0 22:09 23:54 road and Spine road. 8/9/2017 8/9/2017 0.50 MIRU MOVE MOB P Move rig to intersection of 2G access 0.0 0.0 00:00 00:30 road and Spine road.Total of 2 miles moved. 8/9/2017 8/9/2017 2.50 MIRU MOVE WAIT P Pick up mats on 2G access road and 0.0 0.0 00:30 03:00 stage ahead of rig. 8/9/2017 8/9/2017 0.25 MIRU MOVE MOB P Back up rig to allow mats to be laid in 0.0 0.0 03:00 03:15 front. 8/9/2017 8/9/2017 0.50 MIRU MOVE WAIT P Lay mats in front of rig to allow rig to 0.0 0.0 03:15 03:45 make turn onto Spine road. 8/9/2017 8/9/2017 1.00 MIRU MOVE MOB P Move rig from 2G access road 0.0 0.0 03:45 04:45 towards CPF2. 8/9/2017 8/9/2017 1.25 MIRU MOVE WAIT T 200 yds short of CPF2 ODS rear 0.0 0.0 04:45 06:00 wheels sank in road.Stage mats/plywood behind and under rig to back onto. Page 1/17 Report Printed: 8/28/2017 , 'rs • • ' Operations Summary (with Timelog Depths) ,fit :, .._ 2Z-13 OzincicaPhillips A,�hai Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P.T-X Operation {ftKB} End Depth MKS) 8/9/2017 8/9/2017 0.25 MIRU MOVE MOB T Back rig up onto mats. 0.0 0.0 06:00 06:15 8/9/2017 8/9/2017 1.25 MIRU MOVE RURD T Pick up plywood and dunnage. 0.0 0.0 06:15 07:30 8/9/2017 8/9/2017 2.50 MIRU MOVE WAIT P Prep road and lay mats on Spine road 0.0 0.0 07:30 10:00 to CPF2.Sim-ops/Prep pump room for prime and paint. 8/9/2017 8/9/2017 1.50 MIRU MOVE MOB P Move rig to CPF2.Total of 3 miles 0.0 0.0 10:00 11:30 moved. 8/9/2017 8/9/2017 7.50 MIRU MOVE WAIT P Lay mats over culverts and pipeline 0.0 0.0 11:30 19:00 crossings on the Spine road to 2Z access road.Lay mats on 2Z access road.Sim-ops/Prime and paint floors in pump and centrifugal room,clean rig.Remove and repair two electric heaters in SCR room.Repair derrick climber pedestal on roof. 8/9/2017 8/9/2017 0.50 MIRU MOVE WAIT T Alarms sounding at CPF2.Wait on all 0.0 0.0 19:00 19:30 clear to proceed with rig move. 8/9/2017 8/10/2017 4.50 MIRU MOVE MOB P Move rig from CPF2 to 2Z access 0.0 0.0 19:30 00:00 road.Make turn onto 2Z access road. Total of 6.7 miles moved. 8/10/2017 8/10/2017 0.50 MIRU MOVE MOB P Stage rig on 2Z pad. 0.0 0.0 00:00 00:30 8/10/2017 8/10/2017 1.00 MIRU MOVE RURD P Remove rear booster wheels.Lay 0.0 0.0 00:30 01:30 mats on pad to well 2Z-13 8/10/2017 8/10/2017 1.50 MIRU MOVE RURD P Stage BOPE in cellar. Install bell 0.0 0.0 01:30 03:00 nipple.Rack back and secure BOPE onto pedestal.Cont to lay mats on pad to 2Z-13 8/10/2017 8/10/2017 1.00 MIRU MOVE WAIT P Cont to lay mats on pad to 2Z-13.Sim 0.0 0.0 03:00 04:00 -ops/Perform housekeeping on rig. 8/10/2017 8/10/2017 0.75 MIRU MOVE MOB P Move rig to well 2Z-13 0.0 0.0 04:00 04:45 8/10/2017 8/10/2017 1.25 MIRU MOVE MOB P Spot rig over well 2Z-13.Total of 0.0 0.0 04:45 06:00 7.lmiles moved. 8/10/2017 8/10/2017 1.00 MIRU MOVE RURD P Level and shim rig. 0.0 0.0 06:00 07:00 8/10/2017 8/10/2017 1.00 MIRU MOVE RURD P Skid rig floor to drilling position. 0.0 0.0 07:00 08:00 Accept rig at 08:00 hrs 8/10/17 8/10/2017 8/10/2017 3.00 MIRU WELCTL RURD P Rig up lines in cellar.Take on 0.0 0.0 08:00 11:00 seawater.Sim-ops/Make up inter • connects,extend drag chain and prime pumps 8/10/2017 8/10/2017 0.75 MIRU WELCTL SEQP P Rig up and pressure test lines to kill 0.0 0.0 11:00 11:45 tank to 2500 psi. 8/10/2017 8/10/2017 0.50 MIRU WELCTL OWFF P IA=40 psi.Bleed pressure off IA to kill 0.0 0.0 11:45 12:15 tank. 8/10/2017 8/10/2017 0.75 MIRU WELCTL OWFF P Monitor well for 30 mins.Static. 0.0 0.0 12:15 13:00 8/10/2017 8/10/2017 1.00 MIRU WHDBOP CIRC P Fill IA w/36 bbls seawater.Test BPV 0.0 0.0 13:00 14:00 to 1000 psi/10 mins.Charted. 8/10/2017 8/10/2017 1.00 MIRU WHDBOP NUND P Nipple down tree.Lift threads on 0.0 0.0 14:00 15:00 hanger look good. Install blanking plug. 8/10/2017 8/10/2017 3.00 MIRU WHDBOP NUND P Nipple up DSA and BOPE.Acquire 0.0 0.0 15:00 18:00 RKB's. Install turnbuckles and riser. Page 2/17 Report Printed: 8/28/2017 i • Operations Summary (with Timelog Depths) 2Z-13 ConocoPhiilips Rig: DOYON 14 g Job: RECOMPLETION Time Log Start Depth Start Time; End Time our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftK6): 8/10/2017 8/10/2017 1.00 MIRU WHDBOP RURD P Rig up rig floor and clean cellar. 0.0 0.0 18:00 19:00 8/10/2017 8/10/2017 0.50 MIRU WHDBOP RURD P Function rams and break in new 0.0 0.0 19:00 19:30 annular packing element. 8/10/2017 8/10/2017 1.00 MIRU WHDBOP RURD P Rig up test equipment.Make up top 0.0 0.0 19:30 20:30 drive connection.Make up FOSV's to x-o's. 8/10/2017 8/10/2017 1.50 MIRU WHDBOP RURD P PJSM-Purge lines and perform shell 0.0 0.0 20:30 22:00 test. 8/10/2017 8/11/2017 2.00 MIRU WHDBOP BOPE P Conduct initial BOPE test.All tests 0.0 0.0 22:00 00:00 250/3000 psi for 5 mins each.Test.#1- 3 1/2"test jt.Annular,CV 1,12,13,14 and kill line Demco#20.Test#2-3 1/2"test jt.Upper 2 7/8 x 5 VBR's,CV 9, 11,Kill HCR,4"FOSV.Test#3-CV 5,8,10,4"Dart Valve.Test#4-CV 4, 6,7,3 1/2"EUE FOSV. 8/11/2017 8/11/2017 5.00 MIRU WHDBOP BOPE P Continue with initial BOPE test.Test 0.0 0.0 00:00 05:00 #5-CV 2.Test#6-Choke HCR.Test #7-Manual choke and manual kill valves.Test#8-Lower 2 7/8"x 5" VBR's w/3 1/2"test jt.Test#9-Lower 2 7/8"x 5"VBR's w/4"test jt.,upper IBOP.Test#10-Annular preventer w/4"test jt,CV 3.Test#11-Upper 2 7/8"x 5"VBR's w/4"test jt.,lower IBOP.Test#12-Blind rams.Test#13- Hydraulic and manula chokes to 1500 psi bleed off. Conduct Koomey Draw Down Test: Starting Accumulator Pressure=3100 psi Accumulator Pressure After Closer= 1750 psi Pressure Gain of 200 psi=40 seconds Full System=195 Seconds Average N2(6 Bottles)=2066 psi 8/11/2017 8/11/2017 0.50 MIRU WHDBOP RURD P Rig down test equipment. 0.0 0.0 05:00 05:30 8/11/2017 8/11/2017 0.50 COMPZN RPCOMP RURD P Rig up circ lines for circulating diesel 0.0 0.0 05:30 06:00 out of well bore. 8/11/2017 8/11/2017 2.75 COMPZN RPCOMP MPSP P PJSM-Pull blanking plug.Rig up 0.0 0.0 06:00 08:45 FMC BPV running tool.RIH and unseat poppet. IA on vacuum,tubing w/slight pressure.Bleed off pressure. 8/11/2017 8/11/2017 0.75 COMPZN RPCOMP CIRC P Pump 10 bbls 9.0 ppg seawater down 0.0 0.0 08:45 09:30 tubing to balance pressures. 1.5 bpm at 150 psi. 8/11/2017 8/11/2017 1.00 COMPZN RPCOMP MPSP P Monitor well.Static.Pull BPV. 0.0 0.0 09:30 10:30 8/11/2017 8/11/2017 2.75 COMPZN RPCOMP CIRC P Rig up to circulate diesel out of 0.0 7,835.0 10:30 13:15 wellbore. Reverse circulate 72 bbls 8.5 ppg seawater taking returns to flow back tank.2.5 bpm, 180 psi.Shut down pump and line up and circulate 260 bbls 8.5 ppg seawater taking returns to flow back tank.2.5 bpm, 240 psi. Page 3/17 Report Printed: 8/28/2017 • • Operations Summary (with Timelog Depths) 2Z-13 Conoczehillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Tune End Time Our(hr)' Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(itKS) 8/11/2017 8/11/2017 2.50 COMPZN RPCOMP PULL P PJSM-BOLDS.Unseat hangerw.65K 7,835.0 7,803.0 13:15 15:45 up weight.Attempt to pull seal assy. free.Work up to 150K 20+times. Stage up to 185K and work 4 times. Pulled free and up weight dropped to 110K.Pull hanger to rig floor and lay down. 8/11/2017 8/11/2017 0.25 COMPZN RPCOMP OWFF P Monitor well.Static. 7,803.0 7,803.0 15:45 16:00 8/11/2017 8/11/2017 0.50 COMPZN RPCOMP PULL P POOH laying down 5 jts tubing.Well 7,803.0 7,646.0 16:00 16:30 swabbing/Improper displacement. 8/11/2017 8/11/2017 0.50 COMPZN RPCOMP PUTB T Pick up and RIH 4 jts tubing to 7773' 7,646.0 7,773.0 16:30 17:00 MD 8/11/2017 8/11/2017 0.25 COMPZN RPCOMP CIRC T Attempt to bullhead.Pump down IA 7,773.0 7,773.0 17:00 17:15 1.4 bbls to 1000 psi.Pressure held and could not bullhead.Bleed off pressure. 8/11/2017 8/11/2017 0.75 COMPZN RPCOMP OTHR T Suspect packer released rather than 7,945.0 7,945.0 17:15 18:00 seal assy.Work pipe from 7945'MD to 7914'MD in attempt to relax/wear out packer elements while waiting on slickline.PU=105K SO=80K. 8/11/2017 8/11/2017 2.00 COMPZN RPCOMP SLKL T Rig down FOSV.Make up side entry 7,945.0 7,945.0 18:00 20:00 pump in sub below FOSV.Rig up slickline.Observe crude oil migrating up IA.. 8/11/2017 8/11/2017 2.00 COMPZN RPCOMP CIRC T Line up to CBU taking returns to flow 7,945.0 7,945.0 20:00 22:00 back tank.Pump down tubing 2 bpm. 90 psi. Increase pump rate to 5 bpm, 850 psi. After 170 bbls pumped slow rate to 2.5 bpm, 180 psi.Pump 275 bbls with 220 bbls returns. 8/11/2017 8/11/2017 0.50 COMPZN RPCOMP CIRC T Shut in IA.Bullhead down tubing at 3 7,945.0 7,945.0 22:00 22:30 bpm,220 psi.After 7.7 bbls pumped pressured up to 1000 psi at 1.2 bpm. Shut down pump.Pressure bled off to 70 psi in 10 mins. 8/11/2017 8/12/2017 1.50 COMPZN RPCOMP SLKL T Continue to rig up slickline.Monitor 7,945.0 7,945.0 22:30 00:00 well with trip tank.Losing 2 bph. 8/12/2017 8/12/2017 0.75 COMPZN RPCOMP SLKL T Continue to rig up slickline. 7,945.0 7,945.0 00:00 00:45 8/12/2017 8/12/2017 0.50 COMPZN RPCOMP SLKL T Test lubricator to 500 psi.RIH w/2.66 7,945.0 7,945.0 00:45 01:15 centralizer and TTS equalizing prong to 7753'WLM. 8/12/2017 8/12/2017 0.50 COMPZN RPCOMP SLKL T Pressure up on IA to 500 psi.Equalize 7,945.0 7,945.0 01:15 01:45 RBP.Observe pressure drop to 280 psi.POOH w/slickline.Monitor well w/trip tank. Losing fluid to formation at 2-6 BPH. 8/12/2017 8/12/2017 2.00 COMPZN RPCOMP SLKL T Change out tools to TTS pulling tool. 7,945.0 7,945.0 01:45 03:45 RIH w/slickline to 7748'WLM.Pull plug free.Allow plug to relax to 30 mins.POOH w/slickline. 8/12/2017 8/12/2017 1.75 COMPZN RPCOMP SLKL T Change out tools to 42BO fishing tool. 7,945.0 7,945.0 03:45 05:30 RIH to 7726'WLM.Shift sliding sleeve closed.POOH w/slickline.Confirm that pins did not shear indicating sleeve shifted closed. 8/12/2017 8/12/2017 0.75 COMPZN RPCOMP SLKL T Rig down slickline. 7,945.0 7,945.0 05:30 06:15 Page 4/17 Report Printed: 8/28/2017 • • Operations Summary (with Timelog Depths) 2Z-13 ConacoPhifiips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time; End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKE) 8/12/2017 8/12/2017 0.75 COMPZN RPCOMP CIRC P PJSM-Circulate oil cap to flow back 7,945.0 7,945.0 06:15 07:00 tank. 1.5 bpm,200 psi.Pump 18 bbls seawater. 8/12/2017 8/12/2017 5.75 COMPZN RPCOMP PULL P POOH and lay down 3 1/2'tubing and 7,945.0 5,246.0 07:00 12:45 jewelry from 7945'MD to 4805'MD. Calc disp=10.5 bbls Act disp-15 bbls. 8/12/2017 8/12/2017 0.25 COMPZN RPCOMP CIRC P Crude began u-tubing out of tubing. 5,246.0 4,805.0 12:45 13:00 Pump 5 bbls 9.0 ppg seawater down tubing at 1.5 bpm,200 psi. 8/12/2017 8/12/2017 0.50 COMPZN RPCOMP PULL P Pull 8 more jts from 4805'MD to 4565' 4,805.0 4,565.0 13:00 13:30 MD with pipe running over. 8/12/2017 8/12/2017 0.50 COMPZN RPCOMP CIRC P Circulate a tubing volume and pump 4,565.0 4,565.0 13:30 14:00 10 bbl 9.0 ppg dry job.2 bpm,200 psi. Pump total of 41 bbls with minimal returns. 8/12/2017 8/12/2017 0.75 COMPZN RPCOMP PULL P POOH from 4565'MD to 4385'MD 4,565.0 4,385.0 14:00 14:45 with improper displacement.Gained 4 bbls. 8/12/2017 8/12/2017 0.25 COMPZN RPCOMP OWFF P Monitor well.Bubbling at flow nipple 4,385.0 4,385.0 14:45 15:00 with no flow. 8/12/2017 8/12/2017 0.75 COMPZN RPCOMP PULL P POOH from 4385'MD to 4235'MD. 4,385.0 4,235.0 15:00 15:45 Improper hole fill.Gained 2.5 bbls. 8/12/2017 8/12/2017 3.25 COMPZN RPCOMP PULL P POOH from 4235'MD to 3124'MD 4,235.0 3,124.0 15:45 19:00 filling tubing with hole fill line every 5 jts.Proper hole fill until last 12 jts and then gained 2.5 bbls.With slight flow. 8/12/2017 8/12/2017 1.00 COMPZN RPCOMP CIRC P Rig up and attempt to circulate down 3,124.0 3,124.0 19:00 20:00 tubing.4 bpm,500 psi.No returns. Line up and attempt to bullhead IA. 1.8 bpm,500 psi. 8/12/2017 8/12/2017 0.50 COMPZN RPCOMP PULL P POOH from 3124'MD to 3048'MD. 3,124.0 3,124.0 20:00 20:30 Improper hole fill.Gained 1 bbl. 8/12/2017 8/12/2017 1.50 COMPZN RPCOMP CIRC P Consult with workover engineer. 3,124.0 3,124.0 20:30 22:00 Bullhead 400 bbls seawater down tubing at 8 bpm.ICP=1550 psi. FCP=1850 psi.Shut down pumps. Pressure dropped to 300 psi.Bleed off pressure.Bleed back 40 bbls in 30 mins. 8/12/2017 8/12/2017 1.00 COMPZN RPCOMP OWFF P Open annular preventer and monitor 3,124.0 3,124.0 22:00 23:00 bleed back with trip tank. Flowing up tubing and IA.Bleed back 20 bbls. 8/12/2017 8/12/2017 0.50 COMPZN RPCOMP CIRC P Mix and pump 10 bbl 9.0 ppg dry job. 3,124.0 3,124.0 23:00 23:30 4 bpm,500 psi. 8/12/2017 8/13/2017 0.50 COMPZN RPCOMP PULL P POOH from 3124 to 2974'MD. 3,124.0 2,974.0 23:30 00:00 8/13/2017 8/13/2017 1.00 COMPZN RPCOMP PULL P POOH from 2974'MD to 2818'MD 2,974.0 2,818.0 00:00 01:00 filling each joint with hole fill line.Well swabbing.Gain 3 bbls. 8/13/2017 8/13/2017 9.00 COMPZN RPCOMP PULL P Rig up and pump out of hole from ' 2,818.0 0.0 01:00 10:00 2818'MD to surface.Circulate 1 bpm, 40 psi. Calc disp=11.26 bbls Act disp=58 bbls 8/13/2017 8/13/2017 0.50 COMPZN RPCOMP PULL P Lay down packer and cut joint.Cut 0.0 0.0 10:00 10:30 joint length=15.21' No corrosion noted on tubing string or jewelry. Page 5/17 Report Printed: 8/28/2017 • Operations Summary (with Timelog Depths) va ,,,,.„i gs ,, 2Z-13 ConocoPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log t Depth Start Time End Time Dur star (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 8/13/2017 8/13/2017 1.50 COMPZN 'RPCOMP RURD P Clean and clear rig floor of crude and 0.0 0.0 10:30 12:00 tools. 8/13/2017 8/13/2017 0.25 COMPZN RPCOMP RURD P Mobilize fishing tools to rig floor. 0.0 0.0 12:00 12:15 8/13/2017 8/13/2017 0.50 COMPZN RPCOMP RURD P PU and MU wear ring running tool to a 0.0 0.0 12:15 12:45 joint of DP,install the wear ring, RILDS,lay down the wear ring running tool and lay down the joint of DP. Wear ring ID=6.375" 8/13/2017 8/13/2017 1.25 COMPZN RPCOMP BHAH P PU and MU BHA#1 -Overshot/rattler 0.0 241.0 12:45 14:00 assembly for 3-1/2"tubing/blast its. 8/13/2017 8/13/2017 7.00 COMPZN RPCOMP PULD P RIH with BHA#1 on 4"DP from the 241.0 5,927.0 14:00 21:00 pipe shed from 241'MD to 5927'MD. 8/13/2017 8/13/2017 0.50 COMPZN RPCOMP CIRC P Filling pipe at 5927'MD at 2 bpm, 5,927.0 5,927.0 21:00 21:30 1600 psi.Rattler briefly rattled then pressure dropped to 170 psi.Shut down pump.Break out top drive. Seawater u-tubing up drillpipe indicating rupture disc in circulation' control sub had failed.Make up top drive. 8/13/2017 8/13/2017 0.50 COMPZN RPCOMP CIRC T Line up to circulate crude cap to flow 5,927.0 5,927.0 21:30 22:00 back tank.Circ at 2 bpm, 190 psi. Pump 28 bbls w/16 bbls returns. 8/13/2017 8/13/2017 0.75 COMPZN RPCOMP CIRC T CBU taking returns to pits.5 bpm,410 5,927.0 5,927.0 22:00 22:45 psi.Lost 7 bbls while circulating. 8/13/2017 8/13/2017 0.25 COMPZN RPCOMP OWFF T Monitor well.Static. 5,927.0 5,927.0 22:45 23:00 8/13/2017 8/14/2017 1.00 COMPZN RPCOMP TRIP T POOH on elevators from 5927'MD to 5,927.0 3,747.0 23:00 00:00 3747'MD. Calc disp=13.5 bbls Act disp=13.9 bbls 8/14/2017 8/14/2017 1.50 COMPZN RPCOMP TRIP T POOH on elevators from 3747'MD to 3,747.0 334.0 00:00 01:30 334'MD. Calc disp=36.7 bbls Act disp=46.1 bbls 8/14/2017 8/14/2017 0.50 COMPZN RPCOMP BHAH T Monitor well.Static.Stand back DC's. 334.0 36.0 01:30 02:00 Inspect BHA.Confirm that rupture disc had failed.Lay down circulation control sub. 8/14/2017 8/14/2017 0.50 COMPZN RPCOMP BHAH T Make up BHA#2.to 239'MD 36.0 239.0 02:00 02:30 8/14/2017 8/14/2017 2.50 COMPZN RPCOMP TRIP T RIH from 239'MD to 5925'MD.Fill 239.0 5,925.0 02:30 05:00 pipe every 20 stands. 8/14/2017 8/14/2017 2.75 COMPZN RPCOMP PULD P RIH with BHA#2 on 4"DP from the 5,925.0 7,851.0 05:00 07:45 pipe shed from 5925'MD to 7851'MD. 8/14/2017 8/14/2017 1.25 COMPZN RPCOMP SLPC P Slip and cut 60'drilling line 7,851.0 7,851.0 07:45 09:00 8/14/2017 8/14/2017 0.50 COMPZN RPCOMP SVRG P Service rig. 7,851.0 7,851.0 09:00 09:30 8/14/2017 8/14/2017 2.00 COMPZN RPCOMP SVRG P Change out saver sub on top drive. 7,851.0 7,851.0 09:30 11:30 8/14/2017 8/14/2017 0.50 COMPZN RPCOMP PULD P RIH with BHA#2 on 4"DP from the 7,851.0 7,900.0 11:30 12:00 pipe shed from 7851'MD to 7900'MD. Calc disp for trip=50.2 bbls Act disp for trip=34 bbls Page 6/17 Report Printed: 8/28/2017 • • Operations Summary (with Timelog Depths) 2Z-13 +Conochitltps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X °pera[ron (ftKB) End Depth(SKS) 8/14/2017 8/14/2017 1.25 COMPZN RPCOMP FISH P PJSM-PU=157K SO=105K 7,900.0 7,970.0 12:00 13:15 Rot=125K. RIH from 7900'MD.Tag TOF at 7975'MD.Set down 5K. Engage fish 3'.Not fully located.Pump at 1 bpm and rattle down over fish. Fully engage fish at 7976'MD.Pick up to 7973'MD with 10K overpull.Pull to 35K over and pump at 1 bpm. Rattle fish uphole 3'to 7970'MD. 8/14/2017 8/14/2017 1.25 COMPZN RPCOMP CIRC T Observe flow from wellbore and gas at 7,970.0 7,970.0 13:15 14:30 bell nipple.Close annular.0 psi SICP. Circulate through open choke at 1 bpm, 1200 psi.Total of 69 bbls pumped.Pit gain of 17 bbls. 8/14/2017 8/14/2017 1.50 COMPZN RPCOMP CIRC T Bullhead 315 bbls seawater down IA 7,970.0 7,970.0 14:30 16:00 at 5 bpm. ICP=250 psi FCP=1425 psi. 8/14/2017 8/14/2017 1.25 COMPZN RPCOMP OWFF T Monitor well. Bleed back 50 bbls. 7,970.0 7,970.0 16:00 17:15 8/14/2017 8/14/2017 5.75 COMPZN RPCOMP FISH P Continue to rattle on fish from 7970' 7,970.0 7,969.0 17:15 23:00 MD to 7969'MD w/55K overpull.3 bpm,1310 psi. PU=157K SO=105K Rot=125K.Work string 7'while rattling 8/14/2017 8/14/2017 0.50 COMPZN RPCOMP OWFF P Monitor well.Static.Pick up to 7915' 7,969.0 7,915.0 23:00 23:30 MD.Break off TD. 8/14/2017 8/15/2017 0.50 COMPZN RPCOMP TRIP P POOH from 7915'MD to 7441'MD. 7,915.0 7,441.0 23:30 00:00 8/15/2017 8/15/2017 4.50 COMPZN RPCOMP TRIP P Continue to TOOH with BHA#2 from 7,441.0 240.0 00:00 04:30 7441'to 240'MD. 8/15/2017 8/15/2017 0.50 COMPZN RPCOMP BHAH P Lay down BHA#2-overshot 240.0 0.0 04:30 05:00 assembly with rattler. 8/15/2017 8/15/2017 1.25 COMPZN RPCOMP BOPE P Drain the BOP stack,pull the wear 0.0 0.0 05:00 06:15 ring and install the test plug. 8/15/2017 8/15/2017 0.75 COMPZN RPCOMP BOPE P RU to test the annular. 0.0 0.0 06:15 07:00 8/15/2017 8/15/2017 1.25 COMPZN RPCOMP BOPE P PT the annular to 250/2500 psi with 3- 0.0 0.0 07:00 08:15 1/2"and 4"test joints(both passed). 8/15/2017 8/15/2017 0.50 COMPZN RPCOMP BOPE P RD annular testing equipment and. 0.0 0.0 08:15 08:45 blow down lines. 8/15/2017 8/15/2017 0.50 COMPZN RPCOMP BOPE P Install the wear ring. 0.0 0.0 08:45 09:15 8/15/2017 8/15/2017 0.50 COMPZN RPCOMP RURD P Mobilize fishing tools to the rig floor. 0.0 0.0 09:15 09:45 8/15/2017 8/15/2017 1.00 COMPZN RPCOMP BHAH P PU and MU BHA#3-5-3/4"wash 0.0 366.0 09:45 10:45 pipe assembly. 8/15/2017 8/15/2017 3.75 COMPZN RPCOMP TRIP P TIH with BHA#3 to 7094'MD. 366.0 7,094.0 10:45 14:30 8/15/2017 8/15/2017 0.25 COMPZN RPCOMP OWFF T Observe the well for flow and had 7,094.0 7,094.0 14:30 14:45 crude with some gas bubbles migrated to surface. Close the annular to bullhead and remove crude from well bore to keep it out of the pits. 8/15/2017 8/15/2017 1.25 COMPZN RPCOMP CIRC T Bullhead 315 bbls down the IA 7,094.0 7,094.0 14:45 16:00 through the kill line at 5 BPM(ICP= 350 psi and FCP=1730 psi)per fluid management plan. Page 7/17 Report Printed: 8/28/2017 S • Operations Summary (with Timelog Depths) lit 2Z-13 cnocoPtaiill�Ps ; Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation {MKS) End Depth(ftKD) 8/15/2017 8/15/2017 3.50 COMPZN RPCOMP OWFF T Observe the well for flow,the well 7,094.0 7,094.0 16:00 19:30 flowed back a total of 76 bbls from a charged formation and then was static. 8/15/2017 8/15/2017 0.50 COMPZN RPCOMP TRIP P Continue to TIH wit BHA#3 from 7,094.0 7,947.0 19:30 20:00 7094'to 7947'MD. 8/15/2017 8/15/2017 3.50 COMPZN RPCOMP WASH P Obtain parameters: PU=163K,SO= 7,947.0 8,017.0 20:00 23:30 105K,rotating weight= 127K at 30 RPM=4-5K ft-lbs free torque and 3 BPM=160 psi. Wash down at 8 BPM =980 psi to tag at 7973'MD with 5K down. Continue to wash down 8017' MD at 11 BPM=1920 psi but unable to get past. PU,rotate at 50 RPM=4- 5K ft-lbs,wash down to 8017'MD but still unable to get past with/without rotating and with/without pumps. 8/15/2017 8/16/2017 0.50 COMPZN RPCOMP OWFF P Observe the well for flow and the well 8,017.0 8,017.0 23:30 00:00 flowed back 36 bbls at midnight from a charged formation. 8/16/2017 8/16/2017 0.25 COMPZN RPCOMP TRIP P TOOH with BHA#3 from 8017'to 8,017.0 7,947.0 00:00 00:15 7947'MD. 8/16/2017 8/16/2017 0.75 COMPZN RPCOMP WAIT P Wait for additional seawater to arrive 7,947.0 7,947.0 00:15 01:00 while continuing to monitor the well. SimOps: Work on MP2's and housekeeping. 8/16/2017 8/16/2017 0.75 COMPZN RPCOMP COND P Take on a load of seawater to the pits. 7,947.0 7,947.0 01:00 01:45 8/16/2017 8/16/2017 2.00 COMPZN RPCOMP WAIT P Wait for 11.5 ppg brine to arrive to 7,947.0 7,947.0 01:45 03:45 weight up to 8.8 ppg while continuing to monitor the well. SimOps: Work on MP2's and housekeeping. 8/16/2017 8/16/2017 0.75 COMPZN RPCOMP COND P Take on 85 bbls of 11.5 ppg brine. 7,947.0 7,947.0 03:45 04:30 8/16/2017 8/16/2017 2.25 COMPZN RPCOMP COND P Condition the pits to 8.8 ppg brine. 7,947.0 7,947.0 04:30 06:45 SimOps: Work on MP2's and housekeeping. 8/16/2017 8/16/2017 2.25 COMPZN RPCOMP CIRC P Circulate the well over to 8.8 ppg brine 7,947.0 7,947.0 06:45 09:00 at 2.5 BPM=70 psi out to the kill tanks. Pumped 290 bbls with 229 bbls returned to the kill tank. 8/16/2017 8/16/2017 0.50 COMPZN RPCOMP OWFF P Observe the well for flow and the well 7,947.0 7,947.0 09:00 09:30 was losing at 30 BPH. 8/16/2017 8/16/2017 2.25 COMPZN RPCOMP COND P Lighten up the pits from 8.8 ppg to 8.7 7,947.0 7,947.0 09:30 11:45 ppg. 8/16/2017 8/16/2017 3.00 COMPZN RPCOMP TRIP P TOOH with BHA#3 from 7947'to 366' 7,947.0 366.0 11:45 14:45 MD. 8/16/2017 8/16/2017 1.25 COMPZN RPCOMP BHAH P Lay down BHA#3-5-3/4"wash pipe 366.0 0.0 14:45 16:00 assembly. 8/16/2017 8/16/2017 1.00 COMPZN RPCOMP BHAH P Clean and clear the floor. Mobilize 0.0 0.0 16:00 17:00 fishing tools to the rig floor. 8/16/2017 8/16/2017 0.50 COMPZN RPCOMP SVRG P Service the top drive. 0.0 0.0 17:00 17:30 8/16/2017 8/16/2017 1.00 COMPZN RPCOMP BHAH P PU and MU BHA#4-overshot 0.0 9.0 17:30 18:30 assembly without grapple. Page 8/17 • Report Printed: 8/28/2017 0 • r '3 Operations Summary (with Timelog Depths) ,tet .: ,"."- '''';',P-4::0 ' 2Z-13 ConocoPhitllps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 8/16/2017 8/17/2017 5.50 COMPZN RPCOMP PUTB P RIH with BHA#4 on 3-1/2",9.3#,L-80, 9.0 5,675.0 18:30 00:00 EUE 8rd tubing from the pipe shed to 5675'MD at midnight 8/17/2017 8/17/2017 2.00 COMPZN RPCOMP PUTB P Continue to RIH with BHA#4 on 3- 5,675.0 7,931.0 00:00 02:00 1/2"tubing from the pipe shed from 5675'to 7931'MD. 8/17/2017 8/17/2017 1.00 COMPZN RPCOMP HOSO P Obtain parameters: PU=100K and 7,931.0 7,982.0 02:00 03:00 SO=79K. RIH and tag at 7978'MD with 5K down. Set the slips,rotate the string one turn and RIH to no-go at 7982'MD. Space out with two 10'pup joint. RIH to no-go and PU to up weight. 8/17/2017 8/17/2017 0.50 COMPZN RPCOMP RURD P RD the power tubing tongs and clear 7,982.0 7,982.0 03:00 03:30 the floor for E-line operations. 8/17/2017 8/17/2017 1.50 COMPZN RPCOMP ELNE P PJSM. RU SLB E-line. 7,982.0 7,982.0 03:30 05:00 8/17/2017 8/17/2017 3.75 COMPZN RPCOMP ELNE P PU, MU and RIH with string shot. Fire 7,982.0 7,982.0 05:00 08:45 the string shot from 8072'to 8082.5' WMD and POOH. 8/17/2017 8/17/2017 1.00 COMPZN RPCOMP ELNE P Lay down the string shot. PU and MU 7,982.0 7,982.0 08:45 09:45 the chemical cutter. 8/17/2017 8/17/2017 2.75 COMPZN RPCOMP ELNE P RIH with the chemical cutter,cut the 7,982.0 7,982.0 09:45 12:30 tubing at 8081'WMD and POOH. 8/17/2017 8/17/2017 1.00 COMPZN RPCOMP ELNE P RD SLB E-line. 7,982.0 7,982.0 12:30 13:30 8/17/2017 8/17/2017 4.25 COMPZN RPCOMP TRIP P TOOH with BHA#4 standing back 3- 7,982.0 9.0 13:30 17:45 1/2"tubing in the derrick. 8/17/2017 8/17/2017 0.25 COMPZN RPCOMP BHAH P Lay down BHA#4-overshot • 9.0 0.0 17:45 18:00 assembly without grapple. 8/17/2017 8/17/2017 0.75 COMPZN RPCOMP BHAH P Clean and clear the floor. Change 0.0 0.0 18:00 18:45 elevators to 4"DP. 8/17/2017 8/17/2017 0.75 COMPZN RPCOMP BHAH P PU and MU BHA#5-overshot with 0.0 239.0 18:45 19:30 rattler assembly 8/17/2017 8/17/2017 0.50 COMPZN RPCOMP TRIP P TIH with BHA#5 from 239'to 2261' 239.0 2,261.0 19:30 20:00 MD. 8/17/2017 8/17/2017 0.50 COMPZN RPCOMP CIRC T While filling the pipe at 1.5 BPM it 2,261.0 2,261.0 20:00 20:30 pressured up to 1650 psi and the rattler did not function. Increased to 2 BPM=1750 psi and still no rattler action. Shut down the pumps and ramp up to 3 BMP=1760 psi,the rattler functioned for about 5 seconds then the pressure dropped and rattle action stopped. Attempted to get rattler to function at various pump rates but could not even at 3 BPM= 450 psi. 8/17/2017 8/17/2017 0.75 COMPZN RPCOMP TRIP T TOOH with BHA#5 from 2261'to 239' 2,261.0 239.0 20:30 21:15 MD. 8/17/2017 8/17/2017 0.50 COMPZN RPCOMP BHAH T Lay down BHA#5-overshot with 239.0 0.0 21:15 21:45 rattler assembly. Found the float to be in pieces. 8/17/2017 8/17/2017 0.75 COMPZN RPCOMP BHAH T PU and MU BHA#6-overshot with 0.0 236.0 21:45 22:30 new rattler assembly(no float). Shallow test of the rattler was . successful. 8/17/2017 8/18/2017 1.50 COMPZN RPCOMP TRIP P TIH with BHA#6 to 3364'MD at 236.0 3,364.0 22:30 00:00 midnight. Page 9/17 Report Printed: 8/28/2017 0 • t.'"'A 0 .,r Operations Summary (with Timelog Depths) 2Z-13 conooziehimps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation _ (ftKB) End Depth(itKB) 8/18/2017 8/18/2017 2.00 COMPZN RPCOMP TRIP P Continue to TIH with BHA#6 from 3,364.0 7,912.0 00:00 02:00 3364'to 7912'MD. 8/18/2017 8/18/2017 0.25 COMPZN RPCOMP FISH P Obtain parameters: PU=159K,SO= 7,912.0 7,978.0 02:00 02:15 110K,rotating weight=130K at 20 RPM=4-5K ft-lbs free torque and 2.5 BPM=1340 psi. RIH to tag at 7978' MD with 5K down,PU 10K over to engage the grapple,set down 10K, and PU 35K over to ensure grapple is engaged. 8/18/2017 8/18/2017 3.25 COMPZN RPCOMP JAR P Begin rattling up to 3 BPM=1400 psi 7,978.0 7,978.0 02:15 05:30 and up to 55K over pull. 8/18/2017 8/18/2017 0.25 COMPZN RPCOMP FISH P Release the overshot from the tubing 7,978.0 7,912.0 05:30 05:45 stub and stand back the stand of DP. 8/18/2017 8/18/2017 0.25 COMPZN RPCOMP OWFF P Observe the well for flow and the well 7,912.0 7,912.0 05:45 06:00 is on a slight vac. 8/18/2017 8/18/2017 3.50 COMPZN RPCOMP TRIP P TOOH with BHA#6 from 7912'to 236' 7,912.0 236.0 06:00 09:30 MD. 8/18/2017 8/18/2017 1.00 COMPZN RPCOMP BHAH P Lay down BHA#6-overshot with new 236.0 0.0 09:30 10:30 rattler assembly(no float). 8/18/2017 8/18/2017 0.50 COMPZN RPCOMP BHAH P Clean and clear the rig floor. Change 0.0 0.0 10:30 11:00 the elevators to 5-3/4"wash pipe. Mobilize the drag tooth shoe to the rig floor. 8/18/2017 8/18/2017 1.50 COMPZN RPCOMP BHAH P PU and MU BHA#7-5-3/4"wash 0.0 366.0 11:00 12:30 pipe with drag tooth shoe assembly. 8/18/2017 8/18/2017 4.50 COMPZN RPCOMP TRIP P TIH with BHA#7 to 7947'MD filling 366.0 7,947.0 12:30 17:00 the DP every 20 stands. 8/18/2017 8/18/2017 0.75 COMPZN RPCOMP WASH P Obtain parameters: PU=155K,SO= 7,947.0 8,017.0 17:00 17:45 106K,rotating weight=125K at 40 RPM=4-5K ft-lbs free torque and 6 BPM=600 psi. Wash down to tag at 7973'MD with 5K down at 6 BPM= 600 psi. Rotate one turn to the right and continue to wash down to tag at 8017'MD with 10K down. 8/18/2017 8/18/2017 4.25 COMPZN RPCOMP MILL P Start milling on obstruction rotating at 8,017.0 8,018.0 17:45 22:00 40-60 RPM=4-9K ft-lbs,2-6K down and 6 BPM=600 psi. Milled down to 8018'MD and stopped make progress. 8/18/2017 8/18/2017 1.50 COMPZN RPCOMP CIRC P PU above the fish. Pump 15 bbl 8,018.0 7,947.0 22:00 23:30 sweep and circulate out of the hole at 8.6 BPM=1080 psi. 8/18/2017 8/18/2017 0.25 COMPZN RPCOMP OWFF P Observe the well for flow and had 7,947.0 7,947.0 23:30 23:45 slight flow that was decreasing. 8/18/2017 8/19/2017 0.25 COMPZN RPCOMP TRIP P TOOH with BHA#7 from 7947'to 7,947.0 7,473.0 23:45 00:00 7473'MD at midnight. 8/19/2017 8/19/2017 0.50 COMPZN RPCOMP TRIP P Continue to TOOH with BHA#7 from 7,473.0 6,999.0 00:00 00:30 7473'to 6999'MD with 2 bbl gain. , 8/19/2017 8/19/2017 0.25 COMPZN RPCOMP OWFF P Observe the well for flow and had 6,999.0 6,999.0 00:30 00:45 slight flow decreasing. 8/19/2017 8/19/2017 2.25 COMPZN RPCOMP TRIP P Continue to TOOH with BHA#7 from 6,999.0 366.0 00:45 03:00 6999'to 366'MD. 8/19/2017 8/19/2017 2.00 COMPZN RPCOMP BHAH P Lay down BHA#7-5-3/4"wash pipe 366.0 0.0 03:00 05:00 with drag tooth shoe assembly. Recovered 25 lbs of metal debris in the boot basket. Drag tooth shoe is worn down 2"in length and is now 5- 11/16"OD. Page 10/17 Report Printed: 8/28/2017 Operations Summary (with Timelog Depths) >- 2Z-13 C cs 'hiti®ps ' Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur{hr) Phase Op Code Activity Code Time P-T-X Operation (ftKE) End Depth MKS}, 8/19/2017 8/19/2017 1.00 COMPZN RPCOMP BHAH P Clean and clear the floor. Change 0.0 0.0 05:00 06:00 elevator to 4"elevators. Off load Baker tools from the rig floor. 8/19/2017 8/19/2017 2.00 COMPZN RPCOMP WAIT P Wait on orders. 0.0 0.0 06:00 08:00 SimOps: Off load rig tong for inspection,mobilize backup rig tong to the rig floor and RU. 8/19/2017 8/19/2017 2.00 COMPZN RPCOMP WAIT P Wait for fishing tools to arrive from 0.0 0.0 08:00 10:00 Deadhorse. SimOps: Slip and cut 50'(8 wraps)of drilling line. 8/19/2017 8/19/2017 1.00 COMPZN RPCOMP WAIT P Wait for fishing tools to arrive from 0.0 0.0 10:00 11:00 Deadhorse. • SimOps: Inspect the derrick and top drive. 8/19/2017 8/19/2017 1.00 COMPZN RPCOMP WAIT P Wait for fishing tools to arrive from 0.0 0.0 11:00 12:00 Deadhorse. SimOps: Remove 4"elevators and install 4'bail extensions. General housekeeping. 8/19/2017 8/19/2017 1.00 COMPZN RPCOMP RURD P Mobilize fishing tools to the rig floor. 0.0 0.0 12:00 13:00 8/19/2017 8/19/2017 1.50 COMPZN RPCOMP BHAH P PU and MU BHA#8-spear assembly 0.0 122.0 13:00 14:30 with 2-1/8"DC's 8/19/2017 8/19/2017 3.00 COMPZN RPCOMP TRIP P TIH with BHA#8 from 122'to 5898' 122.0 5,898.0 14:30 17:30 MD. 8/19/2017 8/19/2017 2.00 COMPZN RPCOMP CIRC P Establish circulation at 2 BPM=1000 5,898.0 5,898.0 17:30 19:30 psi,increased to 3 BPM=2000 psi and at 300 strokes pressure dropped to 1550 psi. Increased to 4.5 BPM= 2960 psi. 8/19/2017 8/19/2017 0.25 COMPZN RPCOMP OWFF P Observe the well for flow and had 5,898.0 5,898.0 19:30 19:45 crude with some gas migrated to surface. Close the annular to bullhead to keep the crude out of the pits. 8/19/2017 8/19/2017 0.50 COMPZN RPCOMP CIRC P Bullhead 220 bbls down the IA at 9 5,898.0 5,898.0 19:45 20:15 BPM= 1570 psi. • 8/19/2017 8/19/2017 0.25 COMPZN RPCOMP OWFF P Observe the well for flow and had 5,898.0 5,898.0 20:15 20:30 slight flow that was decreasing. 8/19/2017 8/19/2017 1.00 COMPZN RPCOMP TRIP P Continue to TIH with BHA#8 from 5,898.0 7,893.0 20:30 21:30 5898'to 7893'MD 8/19/2017 8/19/2017 0.75 COMPZN RPCOMP FISH P Obtain parameters: PU=153K and 7,893.0 8,053.0 21:30 22:15 SO=103K. Continue to RIH through the top of the tubing stub(did not see any indication on the weight indicator) to 8053'MD and PU 40K over to engage the spear. Continue to PU in 10K increments to max pull of 283K (130K over PU,80%of the 2-1/8" DC's)with no movement. SO to 175K and contact town Engineer. 8/19/2017 8/19/2017 0.75 COMPZN RPCOMP WAIT P Discuss options with town Engineer, 8,053.0 8,053.0 22:15 23:00 Baker,and Doyon. 8/19/2017 8/19/2017 0.25 COMPZN RPCOMP FISH P Release the spear and pull out of the 8,053.0 7,988.0 23:00 23:15 fish. Page 11/17 Report Printed: 8/28/2017 • 0tz Operations Summary (with Timelog Depths) 2Z-13 Conocdl''hilllps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKE) End,Depth MKS)'> 8/19/2017 8/20/2017 0.75 COMPZN RPCOMP TRIP P TOOH with BHA#8 from 7988'to 7,988.0 6,376.0 23:15 00:00 6376'MD at midnight. 8/20/2017 8/20/2017 3.25 COMPZN RPCOMP TRIP P Continue to TOOH with BHA#8 frohi 6,376.0 122.0 00:00 03:15 6376'to 122'MD. 8/20/2017 8/20/2017 0.75 COMPZN RPCOMP BHAH P Lay down BHA#8-spear assembly 122.0 0.0 03:15 04:00 with 2-1/8"DC's 8/20/2017 8/20/2017 0.75 COMPZN RPCOMP BHAH P PU and MU BHA#9-overshot 0.0 306.0 04:00 04:45 assembly. RIH with one stand of DP. 8/20/2017 8/20/2017 0.50 COMPZN RPCOMP BHAH P Clean and clear the floor. Off load tiny 306.0 306.0 04:45 05:15 tools from the rig floor. 8/20/2017 8/20/2017 3.75 COMPZN RPCOMP TRIP P TIH with BHA#9 to 7887'MD. 306.0 7,887.0 05:15 09:00 8/20/2017 8/20/2017 0.50 COMPZN RPCOMP FISH P Obtain parameters: PU=159K,SO= 7,887.0 7,976.0 09:00 09:30 107K,rotating weight=126K at 30 RPM=4K ft-lbs free torque,3.5 BPM =270 psi. Wash down to tag 7976' MD with 5K down. PU 40K over to engage the grapple and straight pull to 245K. 8/20/2017 8/20/2017 0.50 COMPZN RPCOMP JAR P Begin jarring at 150K with straight pull 7,976.0 7,976.0 09:30 10:00 of 220K. Work up to jarring at 155K with straight pull to 240K. 8/20/2017 8/20/2017 1.00 COMPZN RPCOMP SFTY P Excessive jarring derrick inspection. 7,976.0 7,976.0 10:00 11:00 8/20/2017 8/20/2017 0.50 COMPZN RPCOMP JAR P Continue to jar working jarring up to 7,976.0 7,887.0 11:00 11:30 255K with straight pull up to 330K. After 15 jar hits pulled free,PU to 7887'MD(PU=164K). 8/20/2017 8/20/2017 0.50 COMPZN RPCOMP SFTY P Post jarring derrick inspection. 7,887.0 7,887.0 11:30 12:00 8/20/2017 8/20/2017 3.00 COMPZN RPCOMP TRIP P TOOH with BHA#9 from 7887'to 211' 7,887.0 211.0 12:00 15:00 MD. 8/20/2017 8/20/2017 0.75 COMPZN RPCOMP BHAH P Lay down BHA#9-overshot 211.0 0.0 15:00 15:45 assembly. 8/20/2017 8/20/2017 1.25 COMPZN RPCOMP PULL P Release overshot from the cut joint. 45.0 0.0 15:45 17:00 Lay down cut joint=14.13'and blast ring joint=30.86'(parted at the first thread of the pin). Lost 14.73'of blast rings. 8/20/2017 8/20/2017 1.00 COMPZN RPCOMP BHAH P Clean and clear the floor. Mobilize 0.0 0.0 17:00 18:00 fishing tools to the rig floor. 8/20/2017 8/20/2017 0.75 COMPZN RPCOMP BHAH P PU and MU BHA#10-metal muncher 0.0 42.0 18:00 18:45 junk mill assembly to 42'MD. While MU BHA crude was observed at surface. Pull the BHA from the hole to be able to bullhead to keep the crude out of the pits. 8/20/2017 8/20/2017 1.25 COMPZN RPCOMP CIRC P Close the blind rams and bullhead 311 0.0 0.0 18:45 20:00 bbls at 10 BPM(ICP=1340 psi and FCP=1560 psi). 8/20/2017 8/20/2017 0.50 COMPZN RPCOMP OWFF P Observe the well for flow. Gained 0.0 0.0 20:00 20:30 back 29.5 bbls from a charged formation with flow decreasing. 8/20/2017 8/20/2017 0.50 COMPZN RPCOMP BHAH P Continue to PU and MU BHA#10. 42.0 230.0 20:30 21:00 8/20/2017 8/21/2017 3.00 COMPZN RPCOMP TRIP P TIH with BHA#10 to 6389'MD at 230.0 6,389.0 21:00 00:00 midnight filling every 20 stands. Page 12/17 Report Printed: 8/28/2017 • • ..`f `°` Operations Summary (with Timelog Depths) 2Z-13 ConocoPhillips Rig: DOYON 14 ' Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity CodeTime P-T-X Operation (ftK6) End Depth(ftKE) 8/21/2017 8/21/2017 1.00 COMPZN RPCOMP TRIP P Continue to TIH with BHA#10 from 6,389.0 7,905.0 00:00 01:00 6389'MD to 7905'MD filling every 20 stands. 8/21/2017 8/21/2017 2.00 COMPZN RPCOMP MILL P Obtain parameters: PU= 160K,SO= 7,905.0 8,015.0 01:00 03:00 105K,rotating weight=130K at 30 RPM=4-5K ft-lbs free torque,5 BPM =520 psi. RIH to tag at 8012'MD with 5K down. Start the rotary and begin milling on blast rings at 50 RPM=7- 8K ft-lbs torque with 5-10K down. Shut down the rotary and tag at 8015' with 5K down. 8/21/2017 8/21/2017 0.50 COMPZN RPCOMP CIRC P PU to 7990'MD. Pump 40 bbl hi-vis 8,015.0 7,990.0 03:00 03:30 sweep and circulate it out of the well at 12 BPM=2580 psi. 8/21/2017 8/21/2017 0.50 COMPZN RPCOMP OWFF P Observe the well for flow. Gained 7,990.0 7,990.0 03:30 04:00 back 12 bbls from a charged formation with flow decreasing. 8/21/2017 8/21/2017 1.75 COMPZN RPCOMP TRIP P TOOH with BHA#10 from 7990'to 7,990.0 3,072.0 04:00 05:45 3072'MD. 8/21/2017 8/21/2017 1.25 COMPZN RPCOMP OWFF P Obsereve the well for flow. Recorded 3,072.0 3,072.0 05:45 07:00 gain every 10 minutes:0.5 bbls, 1 bbl, 0.7 bbls,0.8 bbls,0.6 bbls,0.8 bbls, 0.6 bbls. Total of 5 bbls in 70 minutes. 8/21/2017 8/21/2017 1.00 COMPZN RPCOMP TRIP P Continue to TOOH from 3072'to 230' 3,072.0 230.0 07:00 08:00 MD. 8/21/2017 8/21/2017 0.50 COMPZN RPCOMP OWFF P Obsereve the well for flow. Gained 1 230.0 230.0 08:00 08:30 bbl in 20 minutes. 8/21/2017 8/21/2017 1.00 COMPZN RPCOMP BHAH P Lay down BHA#10-metal muncher 230.0 0.0 08:30 09:30 junk mill assembly. Recovered 30 lbs of metal debris in the boot baskets. The junk mill OD was 5-1/2"(original OD=6-1/8"). 8/21/2017 8/21/2017 0.50 COMPZN RPCOMP DSL P Install the Dutch riser and spot the 0.0 0.0 09:30 10:00 HES DSL unit. 8/21/2017 8/21/2017 3.50 COMPZN RPCOMP DSL P RU HES DSL. MU gamma ray/CCL 0.0 0.0 10:00 13:30 tool string. 8/21/2017 8/21/2017 0.50 COMPZN RPCOMP DSL P PT the lubricator to 500 psi(good 0.0 0.0 13:30 14:00 test). 8/21/2017 8/21/2017 2.00 COMPZN RPCOMP DSL P RIH with gamma ray/CCL to tag at 0.0 0.0 14:00 16:00 8013'DSLM,log back to surface, pressure on the well increased to 70 psi,close the blinds,bleed off the pressure and lay down the tool string. 8/21/2017 8/21/2017 2.00 COMPZN RPCOMP CIRC P Bullhead 350 bbls at 5 BPM=230 pis 0.0 0.0 16:00 18:00 ICP/1578 psi FCP. 8/21/2017 8/21/2017 0.50 COMPZN RPCOMP DSL P MU gamma ray/40-arm caliper. 0.0 0.0 18:00 18:30 SimOps fill the gas buster with . seawater. 8/21/2017 8/21/2017 0.50 COMPZN RPCOMP DSL P PT the lubricator to 500 psi(good 0.0 0.0 18:30 19:00 test). 8/21/2017 8/21/2017 3.00 COMPZN RPCOMP DSL P RIH with gamma ray/40-arm caliper to 0.0 0.0 19:00 22:00 8013'MD. Wait for the caliper arms to open. Log from 8006'to 6911'with the caliper and POOH with the tool string. 8/21/2017 8/21/2017 1.00 COMPZN RPCOMP DSL P RD HES DSL and pull the Dutch riser. 0.0 0.0 22:00 23:00 Page 13/17 Report Printed: 8/28/2017 • s Operations Summary (with Timelog Depths) 2Z-13 Conoco oan ifiI ' Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation {ftkES) End Depth(ftKB) 8/21/2017 8/21/2017 0.50 COMPZN WHDBOP RURD P PU a joint of DP,MU wear ring pulling 0.0 0.0 23:00 23:30 tool,pull the wear ring and lay down the wear ring pulling tool. MU the test plug,install the test plug and lay down the joint of DP. RU IA to monitor the well to the flow back tank. 8/21/2017 8/22/2017 0.50 COMPZN WHDBOP RURD P RU to test BOPE. Flush lines free of 0.0 0.0 23:30 00:00 air. Shell test the BOPE stack(good test). SimOps: Monitor the well through the IA to the flow back tank. 8/22/2017 8/22/2017 6.50 COMPZN WHDBOP BOPE P Conduct weekly BOPE test: test 2- 0.0 0.0 00:00 06:30 7/8"x 5"VBR's(upper pipe rams)to 250/3000 psi with 3-1/2"and 4"test joints;test 2-7/8"x 5"VBR's(lower pipe rams)to 250/3000 psi with 3-1/2" and 4"test joints;test annular to 250/3000 with 3-1/2"and 4"test joint; conducted Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Jeff Jones via email on 8/20/17 at 18:43 hours. Tests: 1) 2-7/8"x 5"VBR's(lower pipe rams) with 3-1/2"test joint,4"TIW(Passed) 2) Annular with 3-1/2"test joint,4" dart valve,kill valve 20,choke valves 12, 13&14(Passed) 3) 2-7/8"x 5"VBR's(upper pipe rams)with 3-1/2"test joint,HCR valve 22,choke valves 1,9&11 (Passed) 4) Choke valves 5,8&10(Passed) 5) 3-1/2"EUE 8rd TIW,choke valves 4,6&7(Passed) 6) Choke valve 2(Passed) 7) HCR choke(Passed) 8) Manual choke,manual kill (Passed) 9) Blind ram,choke valve 3(Passed) 10) Super choke and manual choke (Passed) 11) 2-7/8"x 5"VBR's(lower pipe rams)with 4"test joint,upper IBOP (Passed) 12) 2-7/8"x 5"VBR's(upper pipe rams)with 4"test joint,lower IBOP (Passed) 13) Annular with 4"test joint to 250/2500(Passed) Conduct Koomey Draw Down Test: Starting Accumulator Pressure=3100 psi Accumulator Pressure After Closer= 1700 psi Pressure Gain of 200 psi=38 seconds Full System=210 Seconds Average N2(6 Bottles)=2033 psi Page 14/17 Report Printed: 8/28/2017 • • Operations Summary (with Timelog Depths) 2Z-13 cniiiips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code' Activity Cede< Time P-T-X Operation (ftK6) End'Depth(ftKB) 8/22/2017 8/22/2017 2.00 COMPZN WHDBOP RURD P RD BOPE testing equipment. Blow 0.0 0.0 06:30 08:30 down the choke and kill. Pull the test plug. 8/22/2017 8/22/2017 1.00 COMPZN WELLPR CIRC P Close the blinds,bullhead 310 bbls at 0.0 0.0 08:30 09:30 10 BPM=1720 psi ICP/1920 psi FCP and open the blinds. 8/22/2017 8/22/2017 1.50 COMPZN WELLPR OWFF P Observe the well for flow. Gained 0.0 0.0 09:30 11:00 back 29 bbls from a charged formation with flow decreasing. 8/22/2017 8/22/2017 0.50 COMPZN WELLPR RURD P MU wear ring running tool to a joint of 0.0 0.0 11:00 11:30 DP,install the wear ring, RILDS,lay down the wear ring running tool and lay down the joint of DP. 8/22/2017 8/22/2017 0.50 COMPZN WELLPR BHAH P PU and MU BHA#11 -casing scraper 0.0 254.0 11:30 12:00 with junk mill assembly. 8/22/2017 8/22/2017 3.75 COMPZN WELLPR TRIP P TIH with BHA#11 to 7930'MD. 254.0 7,930.0 12:00 15:45 8/22/2017 8/22/2017 0.25 COMPZN WELLPR WASH P Wash down from 7930'MD to tag at 7,930.0 8,015.0 15:45 16:00 8015'MD with 5K down. 8/22/2017 8/22/2017 1.00 COMPZN WELLPR CIRC P PU to 7989'MD and circulate the well 8,015.0 7,989.0 16:00 17:00 over to 8.6 ppg seawater at 6 BPM= 720 psi. 8/22/2017 8/22/2017 0.50 COMPZN WELLPR COND P 'Weight up the pits to 8.6 ppg while 7,989.0 7,989.0 17:00 17:30 monitoring the well. 8/22/2017 8/22/2017 1.50 COMPZN WELLPR CIRC P Circulate and condition the well to 8.6 7,989.0 7,989.0 17:30 19:00 ppg in/out at 3 BPM=200 psi. 8/22/2017 8/22/2017 0.75 COMPZN WELLPR OWFF P Observe the well for flow and the well 7,989.0 7,989.0 19:00 19:45 is on slight losses. Blow down the top drive. 8/22/2017 8/23/2017 4.25 COMPZN WELLPR PULD P POOH with BHA#11 lay down 4"DP 7,989.0 3,413.0 19:45 00:00 from 7989'to 3413'MD at midnight. 8/23/2017 8/23/2017 3.25 COMPZN WELLPR PULD P Continue to POOH with BHA#11 3,413.0 254.0 00:00 03:15 laying down 4"DP from 3404'to 254' MD. 8/23/2017 8/23/2017 1.25 COMPZN WELLPR BHAH P Lay down BHA#11 -casing scraper 254.0 0.0 03:15 04:30 with junk mill assembly. Recovered 7 lbs of metal on the magnets and minimal metal debris in the boot baskets. 8/23/2017 8/23/2017 1.00 COMPZN WELLPR BHAH P Off load all fishing tools from the rig 0.0 0.0 04:30 05:30 floor. Clean and clear the rig floor 8/23/2017 8/23/2017 0.50 COMPZN RPCOMP RURD P Pull the wear ring,change elevators to 0.0 0.0 05:30 06:00 3-1/2"tubing and break out crossover on 4"TIW. 8/23/2017 8/23/2017 0.75 COMPZN RPCOMP RURD P RU power tubing tongs. 0.0 0.0 06:00 06:45 8/23/2017 8/23/2017 0.25 COMPZN RPCOMP SFTY P PJSM for running completion. 0.0 0.0 06:45 07:00 8/23/2017 8/23/2017 0.50 COMPZN RPCOMP PUTB P PU,MU and RIH with completion to 0.0 80.0 07:00 07:30 80'MD. 8/23/2017 8/23/2017 1.00 COMPZN RPCOMP RURD T Change out the power tubing tongs. 80.0 80.0 07:30 08:30 8/23/2017 8/23/2017 3.50 COMPZN RPCOMP PUTB P Continue to MU completion and TIH 80.0 3,120.0 08:30 12:00 with completion on 3-1/2"tubing from the derrick to 3120'MD. 8/23/2017 8/23/2017 1.50 COMPZN RPCOMP RURD T Change out the power tubing tongs. 3,120.0 3,210.0 12:00 13:30 Page 15/17 Report Printed: 8/28/2017 • • 0 `�'ont Operations Summary (with Timelog Depths) 2Z-13 Conoc%, oPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Ume End Time Dur(hr) Phase Op Code Activity CodeTime P-T-X Operation (ftKB) End Depth(ftKB) 8/23/2017 8/23/2017 4.00 COMPZN RPCOMP PUTB P Continue to TIH with completion on 3- 3,210.0 7,985.0 13:30 17:30 1/2"tubing from the derrick from 3120' to 7985'MD(PU=101K and SO= 79K). 8/23/2017 8/23/2017 0.50 COMPZN RPCOMP PUTB P MU joint#253,drop the ball&rod,MU 7,985.0 8,017.0 17:30 18:00 head pin to joint#254,MU cement line and MU joint#254. RIH to tag at • 8018'MD with 3K down and PU to 8017'MD. 8/23/2017 8/23/2017 1.00 COMPZN RPCOMP PACK P Pressure up on the tubing to 1715 psi, 8,017.0 7,805.0 18:00 19:00 hold for 5 minutes,pressure up to 2500 psi and hold for 5 minutes to set the packer. Bleed the pressure to 2000 psi,PU and shear the PBR. 8/23/2017 8/23/2017 0.50 COMPZN RPCOMP PRTS P Bleed the tubing to 1500 psi and PT 7,805.0 7,805.0 19:00 19:30 the IA to 1000 psi for 10 minutes (good test). 8/23/2017 8/23/2017 1.00 COMPZN RPCOMP HOSO P RIH locate out,mark the pipe,lay 7,805.0 7,768.0 19:30 20:30 down four joints,MU space out pup joints and MU joint#245. 8/23/2017 8/23/2017 1.00 COMPZN RPCOMP THGR P MU the tubing hanger,MU the head 7,768.0 7,768.0 20:30 21:30 pin to the landing joint,MU the cement line and MU the landing joint to the tubing hanger. 8/23/2017 8/23/2017 2.00 COMPZN RPCOMP CRIH P Reverse circulate 210 bbls of 7,768.0 7,789.0 21:30 23:30 corrosion inhibited seawater down the IA taking returns up the tubing at 4 BPM=440 psi. 8/23/2017 8/24/2017 0.50 COMPZN RPCOMP RURD P Drain the BOP stack and blow down 7,789.0 7,789.0 23:30 00:00 the kill/choke/hole fill lines. 8/24/2017 8/24/2017 1.00 COMPZN RPCOMP THGR P Land the tubing hanger and RILDS. 7,789.0 7,802.0 00:00 01:00 8/24/2017 8/24/2017 1.50 COMPZN RPCOMP PRTS P PT the tubing to 3000 psi for 30 0.0 0.0 01:00 02:30 minutes(good test),bleed the tubing to 1500 psi and PT the IA to 2500 psi for 30 minutes(good test). Bleed the IA to 0 psi and bleed the tubing to 0 psi. Pressure up on the IA to shear the SOV at 2475 psi. 8/24/2017 8/24/2017 0.50 COMPZN RPCOMP OWFF P Observe the well for flow for 30 0.0 0.0 02:30 03:00 minutes and the well is static. 8/24/2017 8/24/2017 0.75 COMPZN RPCOMP RURD P RD and blow down circulating 0.0 0.0 03:00 03:45 equipment. Back out the landing joint, break out the head pin and lay down the landing joint. SimOps: Start emptying the pits. 8/24/2017 8/24/2017 0.50 COMPZN WHDBOP MPSP P PU and MU the dry rod. Install the 3" 0.0 0.0 03:45 04:15 ISA BPV. Pressure up on the IA to 1000 psi to test the BPV from below in 1 the direction of flow(good test). 8/24/2017 8/24/2017 1.00 COMPZN WHDBOP PULD P Lay down the remaining two stand of 3 0.0 0.0 04:15 05:15 -1/2"tubing in the derrick in the mouse hole. 8/24/2017 8/24/2017 3.25 COMPZN WHDBOP OTHR P RD the 3-1/2" elevators and power 0.0 0.0 05:15 08:30 tubing tongs. Clean the rig floor and drip pan.Pull the mouse holes. Page 16/17 Report Printed: 8/28/2017 r e ,, • • Operations Summary (with Timelog Depths) '., „4,47,1 0 2Z-13 ConacoPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code. Time P-T-X Operation tftKB) End Depth(ftKB) 8/24/2017 8/24/2017 1.50 COMPZN WHDBOP NUND P PJSM,pump out BOP stack,pull riser, 0.0 0.0 08:30 10:00 remove choke/kill lines and disconnect Accumulator lines SimOps: Cleaning rig pits. 8/24/2017 8/24/2017 0.25 COMPZN WHDBOP SFTY P Test ESD for rig power(passed). 0.0 0.0 10:00 10:15 Disconnect high line power to rig. 8/24/2017 8/24/2017 0.75 COMPZN WHDBOP NUND P Continue to ND the BOP stack. ND 0.0 0.0 10:15 11:00 13-5/8"x 11"DSA and ND 7-1/16"x 11"DSA. NU two foot 13-5/8"spacer spool and set the BOP stack on the stump. 8/24/2017 8/24/2017 1.50 COMPZN WHDBOP NUND P NU 7-1/16"x 3-1/8"tubing head 0.0 0.0 11:00 12:30 adapter and NU the tree. SimOps: Cleaning rig pits. 8/24/2017 8/24/2017 0.50 COMPZN WHDBOP PRTS P PT the tubing hanger void to 250/5000 0.0 0.0 12:30 13:00 psi for 10 minutes(good test). SimOps: Cleaning rig pits. 8/24/2017 8/24/2017 1.25 COMPZN WHDBOP MPSP P RU the lubricator and PT to 1000 psi 0.0 0.0 13:00 14:15 (good test). Attempt to pull BPV but having trouble engaging the pulling tool. SimOps: Cleaning rig pits. , 8/24/2017 8/24/2017 2.50 COMPZN WHDBOP MPSP T Engage the pulling tool in to the BPV 0.0 0.0 14:15 16:45 and pull the BPV. SimOps: Cleaning rig pits. 8/24/2017 8/24/2017 0.25 COMPZN WHDBOP MPSP P Install the tree test plug. 0.0 0.0 16:45 17:00 SimOps: Cleaning rig pits. 8/24/2017 8/24/2017 0.50 COMPZN WHDBOP PRTS P PT the tree to 250/5000 psi for 5 0.0 0.0 17:00 17:30 minutes(good test). SimOps: Cleaning rig pits. 8/24/2017 8/24/2017 1.00 COMPZN WHDBOP MPSP P Pull the tree test plug and install the 3" 0.0 0.0 17:30 18:30 ISA BPV. RD the lubricator and testing equipment. Pressures: Tubing=0 psi,IA=0 psi &OA=360 psi. SimOps: Cleaning rig pits. 8/24/2017 8/24/2017 0.50 DEMOB MOVE RURD P Clean and install gauges on the tree. 0.0 0.0 18:30 19:00 SimOps: Cleaning rig pits. 8/24/2017 8/24/2017 1.00 DEMOB MOVE RURD P Continue to clean the rig pits. Clean 0.0 0.0 19:00 20:00 up the cellar. Secure the BOP stack. 8/24/2017 8/24/2017 1.00 DEMOB MOVE RURD P Continue to clean the rig pits. 0.0 0.0 20:00 21:00 SimOps: Remove the pitcher nipple from the BOP stack. *Rig released at 21:00 hours.* Page 17/17 Report Printed: 8/28/2017 z ,� KUP •OD SICon©coPhillips J Well AttriMax Ang MD TD AIN*;ka.inc : Wel!bore API/UWI Field Name Wellbore Status ncl(°) MO(ftKB) Act atm(ftKB) coaocatiaos 500292136001 KUPARUK RIVER UNIT PROD 95.12 9,036.06 9,300.0 """ Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2Z-13A,9/2020172:20:15 PM SSSV:NONE 50 12/2/2016 Last WO: 1/5/2013 42.10 7/7/1985 Varaul.schemaac(actua) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Hanger;32.6 ,ai,uiLast Tag:SLM 8,123.0 11/24/2014 Rev Reason:SET BAITSUB,GLV C/O,PULL pproven 9/12/2017 BALL&ROD&RHC PLUG II Casing Strings • I. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread „�,,,CONDUCTOR 16 15.062 36.0 80.0 80.0 62.50 H40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(1..Grade Top Thread SURFACE 9 5/8 8.921 35.3 4,202.8 3,359.7 36 00.J 55 BTC CONDUCTOR,36.0-80.0 _� I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I.. Grade Top Thread IM WINDOW AL1 8 6.000 8,161.0 8,166.0 6,020.0 26.00 J-55 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Mandrel;2,903.3 ' PRODUCTION 7 6.276 32.6 8,506.8 6,091.1 26.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread UPPER LINER A 2 3/8 1.972 8,185.2 8,632.7 6,096.4 4.40 L-80 STL Liner Details Nominal ID SURFACE,35.3-4,202.8--. 1 li Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (In) Hi 8,185.2 6,030.3 61.99 DEPLOY BTT ALUMINUM DEPLOYMENT SUB 1.000 Mandrel;4,728.4 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LOWER LINER A 2 3/8 1.992 8,632.7 9,142.0 6,095.3 4.40 L-80 STL lir Liner Details il Mandrel;6111 1 Nominal ID P' Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com (in) 8,632.7 6,096.4 85.74 DEPLOY BTT STEEL DEPLOYMENT SUB 1.910 9,106.5 6,096.6 92.53 0-RING BTT 0-RING SUB 1.000 Mandrel,7,083.5 Tubing Strings 11,L I Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..1 Set Depth(ND)(...Wt(lb/ft) Grade Top Connection Tubing RWO 2017 3 1/2 2992 32.6 8,027.0 5,920.6 9.30 L-80 EUE 8rd Mod Mandrel,7,744.5ft Completion Details Nominal ID Top(MB) Top(TVD)(ftKB) Top Inc)r) Item Des Com (in) 101 Locator;7,691.5 �- 32.6 32.6 0.08'Hanger Tubing Hanger,FMC,TC-1A-EN,7-1/16"x 3-1/2"EUE 2.992 Seal Assembly;7,802.4 - 8rd Top x Bottom with 3"IS-A BPVG PER;7,804.9 r 7,801.5 5,753.6 43.30 Locator Locator,Baker,GBH-22(bottom of locator spaced out 2.990 FHL Packer;7,818.3 -- 3.97') 7,802.4 5,754.3 43.29 Seal Seal Assembly,Baker 80-40(total seal assembly= 2.990 Assembly 11.80') 7,804.9 5,756.1 43.25 PBR PBR,Baker,80-40(10') 4.000 7,818.3 5,765.8 43.07 FHL Packer Packer,Baker,4762 FHL(shear release=60K) 2.910 e. BAIT sue;7,e5e.0- a�.� 7,871.7 5,805.1 42.35 Nipple- Nipple,Camco,2.813"DS profile,SN:3651-16 2.813 >I%', 2.813"DS Nipple-2.813"DS;7,871.7 8,011.9 5,909.4 42.04 Wedge Wedge Assembly,Northern Solutions 2.992 Assembly 8,025.9 5,919.7 42.36 Nipple-2.81" Nipple,Halliburton,2.813"X profile,SN: 003,X-lock 2.813 J ` X installed with 1-3/4"ID T I Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection Original Tubing 31/2 2.967 8,030.0 8,154.4 6,012.5 9.30 J-55 FL4S Mandrel;7,966.3 (� a Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) T CCC 8,030.0 5,922.8 42.45 BLAST CARBIDE BLAST RINGS(2 FL4S Joints) 2.967 SLOTS;7E17.4-8,085.0-. { RINGS I I 8,097.1 5,971.7 43.93 BLAST JT BAKER STEEL BLAST COLLAR"HAS LEAK" 2.867 Wedge Assembly,8,011.9 COLLAR X-Lock;8,025.9 �J Nipple-2.81"X;8,025.9 r_-;'.-.. 8,150.3 6,009.6 44.97 LOCATOR BAKER LOCATOR SUB 3.000 Broken Carbide Blast Rings; ',:',,!`,1- 8,0270 8,151. , 2 45.19 - 3.000' _ Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) ' Top(ND) Top Incl Top(ftKB) (ftKB) CI Des Com Run Date ID(in) FISH;8,098.0 ` 8,025.9 5,919.7 42.36 v -Lock '8/24/2017 1.750 :: 8,027.0 5,920.6 42.38 Broken Broken Carbide Blast Rings 8/20/2017 0.000 PRODUCTION.6130.8 e ,, Carbide Blast M IMI Rings LOCATOR;8,150.3 Ell'!"-- ----1 i 8,098.0 5,972.3 43.96 FISH Caliper lost an arm aprox.DIM 6"X 1"X 0.125" 2/1/2013 0.125 PACKER;8,151.1 _ 8,156.0 6,013.6 47.74 WHIPSTOCK AL1 BTT MECHANICAL WHIPSTOCK 1/21/2007 Matrix;Acid Mar;8,139.8 '' I ',. ' Perforations&Slots WHIPSTOCK,8,156.0 . WINDOW AL1;8,161.0-8,168.0 '� Shot Dens win Top(TVD) Btm(TVD) (shots) . 0 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com PUNCH;8,1820-8,192. ia 7,917.4 8,085.0 5,839.0 5,963.0 C-4,C-1,2Z- 2/6/2007 32.0 SLOTS PERFORATIONS 13A ABOVE THE SIDETRACK WINDOW- IPRODUCTION LINER AL1 Past 2012 CutI RESTOREDw/acid job 8,144 49,1070 I of 6/26/13 . , 8,182.0 8,192.0' 6,028.8 6,033.4 UNIT B,2Z- 4/6/2007 6.0 PUNCH LINER HOLE PUNCHES 13A 6 SPF w/PJ1606 SLOTS;8,308.0-6629.0 PRODUCTION;32.68,506.7 - 1 8,308.0 8,629.0' 6,075.7 6,096.2 A-4,A-3,2Z- 1/21/2007 32.0 SLOTS Alternating solid/slotted • 13A pipe 8,634.0 8,729.0' 6,096.5 6,104.6 A-4,2Z-13A 1/21/2007 32.0 SLOTS Alternating solid/slotted pipe UPPER LINER A;8,1852- 8,822.0 9,043.0 6,108.7 6,101.0 A-4,2Z-13A 1/21/2007 32.0 SLOTS Alternating solid/slotted 8,632.7 Pipe SLOTS;8,634.0-8,729.0 Stimulations&Treatments CProppant Designed(Ib) Proppant In Formation(Ib) Date sLOTs;e,e22.o-9,043.0�� 6/26/2013 Stimulations&Treatments . Vol Clean Pump 0 Stg# Top(ftKB) Btm(ftKB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) 1 8,130.8 8,182.0 6/26/2013 <fluidname>,<fluidtyp> LOWER LINER A.6632.7- r 9,142.0 KUP OOD41110 2Z-13A . ,, 0., Con©caPhimps Alaska,nc. c°noc4nietpz ••• 2Z-134,9120120172:20:15 PM Vertical schematic(actual) Hanger,32.6 I .� f Mandrel Inserts III at 1uvu,,,,,u,—.„„,,u,umu.,.,.una,w, ■■ .0... ti ^� on Top(TVD) Valve Latch Port Size TRO Run NTop(ftKB) (ttKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn CONDUCTOR:38.080.0 ► 1 2,903.3 2,475.0 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,277.0 8/29/2017 2 4,726.4 3,699.2 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,273.0 8/28/2017 3 6,111.2 4,601.4 Camco MMG 1 1/2 GAS LIFT SOV RK 0.250 8/28/2017 Mandrel;2,903.3 I�: :; 4 7,083.5 5,256.7 Camco MMG 1 1/2 GAS LIFT SOV RKP 8/24/2017 Shea 14 red 5 7,744.5 5,712.4 Camco MMG 1 1/2 GAS LIFT Dumm RK 8/24/2017 Y 6 7,956.3 5,868.0 Camco MMG 11/2 PROD Dumm RK 8/24/2017 SURFACE,35.3-4,202.13----• y 7 8,130.8 5,995.8 MERLA TPDX 11/2 PROD DMY RM 0.000 0.0 12/26/1992 Mandrel;4,726.4 :' IIII General&Safety End Date Annotation Mandrel,6111 1 2/8/2007 NOTE:GLMs#9 blocked by solid pipe portion of Sidetrack Lateral AL1 12/8/2007 NOTE:MULTILATERAL SIDETRACK,2Z-13A&2Z-13AL1(AL1 off main wellbore) 11111 AB -9/13/2009 NOTE:WAIVERED WELL T x IA x OA COMMUNICATION Mandrel;7083.5 12/30/2010 NOTE:View Schematic w/Alaska Schematic9.0 .� 12/21/2012 NOTE:TOP 298'AL1 LINER TOP PULLED FOR 2012 WORKOVER Mandrel,7,743.5 — 7/16/2013 NOTE:DUMP 8'SILICA SAND ON WRP @8145',TOP OF SAND 8133' 5/7/2014 NOTE: DELETED GS SPEAR(running tool) a Locator;7,801.5 Seal Assembly;7,802.4 _...-. PBR;7,804.9 FHL Pecker,7,818.3 s BAIT SUB;7,859.0 .rt Nipple-2.813'DS;7,871.7 igg. 15 9 Mandrel;7,956.3 ! SLOTS;7,917.4-8,085.0—.T�0 '$ yr Wedge Aaeemb9,8,011.9 X-Lock;8,025.9 ) r Nipple-2.81'X;8,025.9 ',y Broken Carbide Blest Ringo; q I. 8,027.0:,('1.'1� FISH;8,098.0 _. `NIB PRODUCTION;8,130.8 • 11-1111-11�O LOCATOR,8,150.3 'R , PACKER;8,151.1 i , Acid Metrix;8,130.8E WHIPSTOCK,8,156.0 ,-- WINDOW AL1;8,181.0-8,186.0' PUNCH;8,182.0-8,102.0 -- .in■ LINER AL1 Post 2012 Cut 8144.4-9,107.0 JJ SLOTS;6308.08,629.0�T PRODUCTION;32.6-8,506.7 1 UPPER LINER A;8,185.2- 8,832.7 SLOTS;8,634.08,723 0—„ SLOTS;8,822.0-9,043.0--. , iii 0 LOWER LINER A;8,832.7- 4+ 0 9,142. 0 � ! a / 1T r N L r r r ~ co V n T X co j O � NN W r W Coo N NOw o 4 • '. f0 > co 00 170 `0 7 u_., 0 ,, , z- will , > Q Y V d N u O 0 Q C O n�� ° c 0 * a u r co o 'a a @ o• .1 E n n n n a Q. r r r r cn L a o co Q ' 01 0) o> Ln Q) m t' L -O O Vl 0 7 7 > > 3 7 7 L "6 of M Q Q Q Q Q Q O v L 41 N O N U) N CO p '�'' C Z N U C Q U Z N > E -O a O C i i 0000000 * rO O p• a -p N u J J J J J J J - C '� U 0 W W W W W W W in a LL LL LL LL LL LL LL +-' a a a -0 O J J J J J J J O' L > C aQ Q Q Q Q Q Q '_ ^ CwO• rn z z z z z z z v s a > LL LL LL LL U.. LL LL cc L E E - 4t a RS p L .c- N u O Cr Z 'n O' U > • O H a u a. > u a = yy• UU Q v a n it G L. O 0 J 0 0 0 c Y Cu � p _, � a aa zU TS m O = N a \� g al E. U `, r a w N ii (ISof W = (24• O n 2 \ 414 g ip b.44 A4 W O 2 03 Z 40 to - a J J J J J J J , Q mac u2 � 3 � 33 � 3 Z � z � M v, W P CCCGCLCLOLCLC W W W W W W W4 Feceo W > > > > > > > z Y Y Y Y Y Y Y 02222222 a' IXa a Q: a v N Q w Q Q Q Q Q Q Q LL a a a a a a a WY Y Y Y Y Y Y co .,C: C ti X N O W 0 OCP N O 0 f0 CV O r C U) anN N 11.11110 CC rocI 0 0ot:raOcyoc LU cv, 0 0 0 0 02I 0 0 N V n N N U) n n n E o o I _ 0 0 0 0 0 0 0 > VEcntnv0o 2 Q c X N V f0 N CC 0 9 0 0 0 0 0 +' o CO 0 0 0 0 0 0 0 @ N Q ✓ N co on '' CCD °n° `N �_ a fit y� N 00 co M M N N N. O O M M M M N a N N N N N N N 0 < M Orn T to T CP Orn C •O a pO N N N N N N f0 V 0 Q1 ▪ 0 0 0 0 0 0 ++ O L. O 0�0 C N i() V) c() 1f1 U) N a 0 C aaW 11' u C , U tir Z E CD W O . C -L) �� F , a rh Q N n r- O < O 0o a Y Y d Z_ z N O r r •,- -I CO h aa+ ya,, ., m Vl �0 n J Q V N �� a Q p N w N N = _ £ zC 0 0 O c/'. a 3 Q H a a H H Pio -- ISD Loepp, Victoria T (DOA) From: Beat,Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Thursday,August 17,2017 4:13 PM To: Regg,James B(DOA) Cc: Loepp,Victoria T(DOA);Quick, Michael J (DOA) Subject: Re: [EXTERNAL]RE: BOPE Test Extension - Doyon 14 on 2Z-13 (PTD 206-170) Follow Up Flag: Follow up Flag Status: Flagged Jim, Understood. Would an extension of 72 hours be acceptable? Based on our plan forward we should have the completion installed by Sunday so 72 hours would give us a little time for any potential delays in addition to what is planned. Thanks, Andrew SCANNED 1 %j Andrew From: Regg,James B(DOA)<jim.regg@alaska.gov> Sent:Thursday,August 17,2017 3:56:59 PM To: Beat,Andrew T Cc:Loepp,Victoria T(DOA);Quick, Michael J (DOA) Subject: [EXTERNAL]RE: BOPE Test Extension-Doyon 14 on 2Z-13(PTD 206-170) We can grant an extension if needed but not for 7 days. We are continuing to review the request to test the BOPE on Doyon 14 at intervals up to 14 days. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Beat,Andrew T[mailto:Andrew.T.Beat@conocophillips.com] Sent:Thursday,August 17,2017 10:28 AM To: Regg,James B(DOA)<jim.regg@alaska.gov>; Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov> Cc: Buck, Brian R<Brian.R.Buck@conocophillips.com>; Kneale, Michael L(SolstenXP) <Michael.L.Kneale@contractor.conocophillips.com>; Kanady, Randall B<Randall.B.Kanady@conocophillips.com>; Doyon 14 Company Man<doyon14cm@conocophillips.com>; Doyon 14 Toolpusher<doyon14tp@conocophillips.com>;CPA 1 Wells Supt<n1030@conocophillips.com> • Subject: BOPE Test Extension-Doyon 14 on 2Z-13(PTD 206-170) Jim, We would like to request a 7 day BOPE test extension for Doyon 14 on 2Z-13.We understand that you are currently reviewing our request for a 14 day test interval for the remainder of Doyon 14's campaign so this request only applies to the current workover,2Z-13.Approval of the previously submitted 14 day interval request would also satisfy this request. Our next test is due by the end of tomorrow(8/18).Currently,we are fishing the first of two remaining pieces of the existing completion.We will then perform a cleanout run before installing the new completion. Planned release date as Saturday or Sunday,however,that could slipif we have issues removingthe remainder of the completion. of now is Sa ay p Please let me know if you have any questions or would like to discuss. Thanks, Andrew (303)378-8881 2 • • Loepp, Victoria T (DOA) From: Regg,James B (DOA) Sent: Wednesday,August 16, 2017 5:19 PM To: Beat,Andrew T; Loepp,Victoria T(DOA); DOA AOGCC Prudhoe Bay Cc CPA Wells Supt; Buck, Brian R; Doyon 14 Company Man; Doyon 14 Toolpusher; Herbert, Frederick 0; Kanady, Randall B; Marti, Marty K Subject: RE:2Z-13 (PTD 206-170) Update Follow Up Flag: Follow up Flag Status: Flagged I agree Sent from my Samsung Galaxy smartphone. Original message From: "Beat,Andrew T"<Andrew.T.Beat@conocophillips.com> Date:08/16/2017 5:07 PM (GMT-09:00) To: "Regg,James B(DOA)"<jim.regg@alaska.gov>,"Loepp,Victoria T(DOA)"<victoria.loepp@alaska.gov>, DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov> Cc: CPA Wells Supt<n1030@conocophillips.com>, "Buck, Brian R"<Brian.R.Buck@conocophillips.com>, Doyon 14 Company Man<doyon14cm@conocophillips.com>, Doyon 14 Toolpusher<doyon14tp@conocophillips.com>, "Herbert, Frederick 0"<Frederick.O.Herbert@conocophillips.com>,"Kanady, Randall B"<Randall.B.Kanady@conocophillips.com>, "Marti, Marty K"<Srinagesh.K.Marti@conocophillips.com> Subject: RE:2Z-13(PTD 206-170) Update All, We talked with Jeff Jones on the slope for the AOGCC and he agreed with our logic behind not re-testing the annular. We will continue forward with our plans of not re-testing. Thanks, Andrew (303)378-8881 From: Beat,Andrew T Sent:Wednesday,August 16,2017 2:30 PM To: 'Regg,James B(DOA)'<jim.regg@alaska.gov>; Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov> Cc:CPA Wells Supt<n1030@conocophillips.com>; Buck, Brian R<Brian.R.Buck@conocophillips.com>; Doyon 14 Company Man<doyon14cm@conocophillips.com>; Doyon 14 Toolpusher<doyon14tp@conocophillips.com>; Herbert, Frederick 0<Frederick.O.Herbert@conocophillips.com>; Kanady, Randall B<Randall.B.Kanady@conocophillips.com>; Marti, Marty K<Srinagesh.K.Marti@conocophillips.com> Subject:2Z-13(PTD 206-170) Update Importance: High 1 • • Jim, This email is in response to the voice messages I have left today. Yesterday evening(8/15),we again closed our annular preventer, however,this time it was to bull head an IA volume as part of our annular fluid management plan on 2Z-13.The small amount of crude that we had observed in our returns over the previous days separated out in our pits which required extensive clean up efforts to remove. Because of this, we did not want to bring more contaminated seawater onto the rig and made the decision to bull head it back into the formation. In order to do so we needed to close the annular. Like Monday, no pressure or flow was observed at any point so the component was not used for well control nor did the use of it compromise its effectiveness. We believe this use of the annular preventer does not warrant a re-test and do not plan to do so. If you disagree, please let me know at your earliest convenience.We will be out with our BHA in about an hour and be ready to make the next run shortly after that. ThankY ou, Andrew Beat Senior Wells Engineer ConocoPhillips Alaska (303)378-8881 cell (907)265-6341 office From:Regg,James B(DOA) mailto:iim.regg@alaska. ov Sent: Monday,August 14,2017 5:08 PM To: Beat,Andrew T<Andrew.T.Beat@conocophillips.com>; Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov> Cc:CPA Wells Supt<n1030@conocophillips.com>; Buck, Brian R<Brian.R.Buck@conocophillips.com>; Doyon 14 Company Man<dovonl4cm@conocophillips.com>; Doyon 14 Toolpusher<doyonl4tp@conocophillips.com>; Herbert, Frederick 0<Frederick.O.Herbert@conocophillips.com>; Kanady, Randall B<Randall.B.Kanady@conocophillips.com> Subject: [EXTERNAL]RE:2Z-13(PTD 206-170) Update This is a grey area regarding the need to test. Past interpretations have been to require testing used equipment before next trip in hole unless it(closing annular or rams)was a planned event. Just to be clear,the regulation states: "...used for well control or other equivalent purpose,or when routine use of the equipment may have compromised its effectiveness,the components used must be function-pressure tested." Not testing seems to be inconsistent with how CPAI has approached this in the past. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.reggPalaska.gov. 2 • • • From: Beat,Andrew T[mailto:Andrew.T.Beat@conocophillips.com] Sent: Monday,August 14,2017 4:14 PM To:Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Regg,James B(DOA)<jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bav@alaska.gov> Cc:CPA Wells Supt<n1030@conocophillips.com>; Buck, Brian R<Brian.R.Buck@conocophillips.com>; Doyon 14 Company Man<doyon14cm@conocophillips.com>; Doyon 14 Toolpusher<doyon14tp@conocophillips.com>; Herbert, Frederick 0<Frederick.O.Herbert@conocophillips.com>; Kanady, Randall B<Randall.B.Kanady@conocophillips.com> Subject:2Z-13(PTD 206-170) Update Victoria, This is to notify you that Doyon 14 on RWO 2Z-13(PTD 206-170)functioned the annular preventer today(8/14/17)at approximately 1200 hours to circulate production gas through an open choke. During a routine fishing trip,gas was observed at surface after circulating with drill pipe on bottom.The annular was shut in to route the fluid through the choke and gas buster, NOT to prevent the flow of fluids from the well.To ensure that the source of this gas was not an influx,the choke was closed with NO pressure build up.The rig continued to circulate and verified zero build up a second time confirming sufficient fluid density.We do not plan to re-test the annular element. Please let me know if you have any questions or concerns. Thank you, Andrew Beat Senior Wells Engineer ConocoPhillips Alaska (303)378-8881 cell (907)265-6341 office 3 • • • Loepp, Victoria T (DOA) From: Beat,Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Monday,August 14,2017 7:06 PM To: Regg,James B(DOA); Loepp,Victoria T(DOA); DOA AOGCC Prudhoe Bay Cc: CPA Wells Supt; Buck, Brian R; Doyon 14 Company Man; Doyon 14 Toolpusher; Herbert, Frederick 0; Kanady, Randall B Subject: Re: [EXTERNAL]RE:2Z-13 (PTD 206-170) Update Follow Up Flag: Follow up Flag Status: Flagged Jim, We understand and cannot disagree with the inconsistencies regarding this situation. Due to the short timeline,we will test our annular tonight once we our out with our fishing BHA. However, in the near future we would like to discuss this further to remove the grey area and ensure we are all on the same page. Thank you and have a good evening. Andrew Andrew From: Regg,James B(DOA)<jim.regg@alaska.gov> Sent: Monday,August 14,2017 5:07:31 PM To:Beat,Andrew T; Loepp,Victoria T(DOA); DOA AOGCC Prudhoe Bay Cc:CPA Wells Supt; Buck, Brian R; Doyon 14 Company Man; Doyon 14 Toolpusher; Herbert, Frederick 0; Kanady, Randall B Subject: [EXTERNAL]RE: 2Z-13(PTD 206-170) Update This is a grey area regarding the need to test. Past interpretations have been to require testing used equipment before next trip in hole unless it(closing annular or rams)was a planned event. Just to be clear,the regulation states: "...used for well control or other equivalent purpose,or when routine use of the equipment may have compromised its effectiveness,the components used must be function-pressure tested." Not testing seems to be inconsistent with how CPAI has approached this in the past. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. 1 • From: Beat,Andrew T[mailto:Andrew.T.Beat@conocophillips.com] Sent: Monday,August 14,2017 4:14 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Regg,James B(DOA)<jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov> Cc:CPA Wells Supt<n1030@conocophiilips.com>; Buck, Brian R<Brian.R.Buck@conocophillips.com>; Doyon 14 Company Man<doyon14cm@conocophillips.com>; Doyon 14 Toolpusher<doyon14tp@conocophillips.com>; Herbert, Frederick 0<Frederick.O.Herbert@conocophillips.com>; Kanady, Randall B<Randall.B.Kanady@conocophillips.com> Subject:2Z-13(PTD 206-170) Update Victoria, This is to notify you that Doyon 14 on RWO 2Z-13 (PTD 206-170)functioned the annular preventer today(8/14/17)at approximately 1200 hours to circulate production gas through an open choke. During a routine fishing trip,gas was observed at surface after circulating with drill pipe on bottom.The annular was shut in to route the fluid through the choke and gas buster, NOT to prevent the flow of fluids from the well.To ensure that the source of this gas was not an influx,the choke was closed with NO pressure build up.The rig continued to circulate and verified zero build up a second time confirming sufficient fluid density.We do not plan to re-test the annular element. Please let me know if you have any questions or concerns. Thank you, Andrew Beat Senior Wells Engineer ConocoPhillips Alaska (303)378-8881 cell (907)265-6341 office 2 • • K c4 —(3 PrO ZeGi7ao Regg, James B (DOA) From: Regg,James B (DOA) Sent: Thursday,August 17, 2017 7:38 PM67f 6( ti I �1 To: Beat, Andrew T t Subject: RE: [EXTERNAL]RE: BOPE Test Extension - Doyon 14 on 2Z-13 (PTD 206-170) 72 hr extension granted. If still run up against that new due date contact me. Sent from my Samsung Galaxy smartphone. SCANNED Original message From: "Beat,Andrew T" <Andrew.T.Beat@conocophillips.com> Date: 08/17/2017 4:13 PM (GMT-09:00) To: "Regg,James B (DOA)" <jim.regg@alaska.gov> Cc: "Loepp,Victoria T(DOA)" <victoria.loepp@alaska.gov>, "Quick, Michael 1 (DOA)" <michael.quick@alaska.gov> Subject: Re: [EXTERNAL]RE: BOPE Test Extension - Doyon 14 on 2Z-13 (PTD 206-170) Jim, Understood. Would an extension of 72 hours be acceptable? Based on our plan forward we should have the completion installed by Sunday so 72 hours would give us a little time for any potential delays in addition to what is planned. Thanks, Andrew Andrew From: Regg,James B (DOA)<jim.regg@alaska.gov> Sent:Thursday, August 17, 2017 3:56:59 PM To: Beat, Andrew T Cc: Loepp,Victoria T(DOA); Quick, Michael J (DOA) Subject: [EXTERNAL]RE: BOPE Test Extension - Doyon 14 on 2Z-13 (PTD 206-170) We can grant an extension if needed but not for 7 days. We are continuing to review the request to test the BOPE on Doyon 14 at intervals up to 14 days. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, 1 • • please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 orjim.reggPalaska.gov. From:Beat,Andrew T [mailto:Andrew.T.Beat@conocophillips.com] Sent:Thursday, August 17, 2017 10:28 AM To: Regg,James B(DOA)<jim.regg@alaska.gov>; Loepp,Victoria T(DOA) <victoria.loepp@alaska.gov>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov> Cc: Buck, Brian R<Brian.R.Buck@conocophillips.com>; Kneale, Michael L(SolstenXP) <Michael.L.Kneale@contractor.conocophillips.com>; Kanady, Randall B<Randall.B.Kanady@conocophillips.com>; Doyon 14 Company Man <doyon14cm@conocophillips.com>; Doyon 14 Toolpusher<doyon14tp@conocophillips.com>; CPA Wells Supt<n1030@conocophillips.com> Subject: BOPE Test Extension - Doyon 14 on 2Z-13 (PTD 206-170) Jim, We would like to request a 7 day BOPE test extension for Doyon 14 on 2Z-13. We understand that you are currently reviewing our request for a 14 day test interval for the remainder of Doyon 14's campaign so this request only applies to the current workover, 2Z-13. Approval of the previously submitted 14 day interval request would also satisfy this request. Our next test is due by the end of tomorrow (8/18). Currently, we are fishing the first of two remaining pieces of the existing completion. We will then perform a cleanout run before installing the new completion. Planned release date as of now is Saturday or Sunday, however,that could slip if we have issues removing the remainder of the completion. Please let me know if you have any questions or would like to discuss. Thanks, Andrew (303)378-8881 2 • • • Kat . 2 -,3 P71� Z (7uc, Regg, James B (DOA) From: Regg,James B (DOA) ! Sent: Monday,August 14, 2017 5:08 PM l(1 /i /t 7 To: Beat, Andrew T;Loepp,Victoria T (DOA); DOA AOGCC Prudhoe Bay Cc: CPA Wells Supt; Buck, Brian R; Doyon 14 Company Man; Doyon 14 Toolpusher; Herbert, Frederick 0; Kanady, Randall B Subject: RE: 2Z-13 (PTD 206-170) Update This is a grey area regarding the need to test. Past interpretations have been to require testing used equipment before next trip in hole unless it (closing annular or rams) was a planned event. Just to be clear,the regulation states: "...used for well control or other equivalent purpose, or when routine use of the equipment may have compromised its effectiveness, the components used must be function-pressure tested." Not testing seems to be inconsistent with how CPAI has approached this in the past. Jim Regg Supervisor, Inspections AOGCC SCANNED r.r:% ,11 ,,,, 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: Beat,Andrew T[mailto:Andrew.T.Beat@conocophillips.com] Sent: Monday, August 14, 2017 4:14 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Regg,James B (DOA) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov> Cc: CPA Wells Supt<n1030@conocophillips.com>; Buck, Brian R<Brian.R.Buck@conocophillips.com>; Doyon 14 Company Man <doyon14cm@conocophillips.com>; Doyon 14 Toolpusher<doyon14tp@conocophillips.com>; Herbert, Frederick 0<Frederick.O.Herbert@conocophillips.com>; Kanady, Randall B<Randall.B.Kanady@conocophillips.com> Subject: 2Z-13 (PTD 206-170) Update Victoria, This is to notify you that Doyon 14 on RWO 2Z-13 (PTD 206-170)functioned the annular preventer today(8/14/17) at approximately 1200 hours to circulate roduction as through an open choke. 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IIIf•���7 N 0I N M N_ R M C•1 0 r O r r N M N O C - N N N N N N N N N N N N N N L h. CII T 0) 0) 6 0) 6 CII CII 6 Of M C 0.. 0 N N N N N N N N N N N 0 CO v 0 01 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 y,+ }' 00 O DI u) In N In In In In N) In In In O. "O 0 C co g N A .- C11 C U L z E ._ CO U a a 5 E E c 'a ~ as a •i Q In 0 A Q to „- o N Cl. a) 44.., v C E Z .b ho 0 z r o r N O O +' E a) Y al 2 0 (4 -II r X N J m { Q O Q E ro N N �m a s { N ti r N N r r N N N Z CII 0 O .0 V. C O , m . E E O Q a1 H a` a 1°- H "2-0(0-c-10 • • k(Nfl WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 19, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA L GOGEED Anchorage, Alaska 99501 K.BENDER 1301 RE: Production Profile: 2Z-13A (1 , Run Date: 7/30/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2Z-13A Digital Data in LAS format, Digital Log Image file, Interpretation Report v _ 1 CD Rom 50-029-21360-01 Production Profile Log 1 Color Log 50-029-21360-01 %AWED PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 7). `Ati2"2"1-4(A1/7) 6-e-welt Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ ~ - 1 ~ ~ Well History File Identifier Organizing (done) ~wo-sided III II~I'I II III II III ^ Rescan Needed III IIIIII II11 III III RE CAN DIG AL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. , ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Lags of various kinds: NOTES: ^ Other.: BY: Maria Date: ~ /s/ Prvect Prvofng III IIIIIIIIIII IIIII BY: Maria Date: ~ ' ~ ~g /s/ ~ N 1 Scanning Preparation _ ~~ x 30 = ~r~ + ~ ~ =TOTAL PAGES-- ~~~ ~~ ~~ ~ ~ ~ (Count does not include cover sheet) ~~ BY: Maria Date: ~1 ~ ~' /s/ J IIIIIIIIIIIIII 1111 Production Scanning Stage 7 Page Count from Scanned File: (Count does include co er sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date: ~ ~~ ~~ /s/ ~~ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I I~ II ll I II II IIIII ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: o,. ~.~~~~en iuuiuiuiuiim 10!6/2005 Well History File Cover Page.doc • 2_21\ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. February 5, 2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper (MFC): 2Z -13A Run Date: 2/1/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2Z -13A Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 21360 -01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood SCANNED JUL . 1 ;_ 1 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com r !a ate: 21 I Signed: )73,0,_ STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM•SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon E Repair w ell M Aug Perforations r Perforate 1 Other 1- Alter Casing 1— Pull Tubing 1✓ Stimulate - Frac "° Waiver I Time Extension E Change Approved Program EOperat. Shutdow n F Stimulate - Other 1 Re -enter Suspended Well f 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ,; Exploratory r 206 -170 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic ( Service 1 r 50 029 - 21360 - 01 7. Property Designation (Lease Number : 8. Well Name and Number: M ADL 025653 " )s r 4 co aZ L6i 2Z - 13A 9. Logs (List logs and submit electronic and printed data per 20 C25.071): 10. Field /Pool(s): v none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9300 feet Plugs (measured) none true vertical 6089 feet Junk (measured) none Effective Depth measured 9142 feet Packer (measured) 7849, 8151 true vertical 6095 feet (true vertical) 5789, 6010 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 80 80 SURFACE 4167 9.625 4203 3360 PRODUCTION 8474 7 8507 6091 R E :' LINER A 512 2.375 9142 6095 FEB 06 ZO 1 AOG rs Perforation depth: Measured depth: 8308 - 8629, 8634 - 8729, 8822 - 9043 True Vertical Depth: 6075 - 6096, 6097 - 6105, 6109 -6101 SCANNED APR 2 4 2013 Tubing (size, grade, MD, and TVD) 3.5, L -80, 7828 MD, 5772 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL RETRIEVABLE PACKER @ 7849 MD and 5789 TVD PACKER - BAKER FB -1 PERMANENT PACKER @ 8151 MD and 6010 TVD SSSV - CAMCO DS NIPPLE @ 505 MD and 505 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut -in Subsequent to operation shut -in 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory IT Development 1.i • Service 1 Stratigraphic E 16. Well Status after work: - Oil rw Gas 1 WDSPL E Daily Report of Well Operations XXX GSTOR E WINJ F WAG (° GINJ I" SUSP 1` SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Brett Packer an. 265 -6845 Email J. Brett.Packer@ Printed Name Brett Packer Title Wells Engineer //x Signature �� Z - Phone: 265 -6845 Date Z/s RBDMS FEB 0 6 201 3 Vi-l' ,� /� Form 10 -404 Revised 12/2012 *lf oi Submit Original Only 2Z -13A and 2Z -13AL1 PRE -RIG WELL WORK DATE SUMMARY 10/6/12 (PRE -RWO) MITOA- PAD; T POT- PASSED; T PPPOT- PASSEL POT - (HAS SEALTITE) IC PPPOT- RE- ENERGIZED WITH HYDR. FLUID. 11/28/12 SET 2.79" CATCHER SUB ON 2 3/8" LINER @ 7920' RKB. MEASURE BHP @ 7901 RKB (2999 PSI) & 7763' RKB (2965 PSI), IN PROGRESS. 11/29/12 STOOD BY FOR SCAFFOLD TO BE BUILT. SET 1.5" CV ON RM LATCH @ 7888' RKB. PULLED 1" OV @ 7474' RKB, IN PROGRESS 11/30/12 PULLED 1" GLV'S @ 6735', 5702', 4132', & 2010' RKB. IN PROGRESS. 12/1/12 SET 1" DV'S @ 2010', 4132', 5702' & 6735' RKB. DHD SHOT FLUID LEVEL IN IA @ —786' , IN PROGRESS. (NOTE: HAD TO SETA BTM LATCH IN STN# 2 @ 4132' RKB, BK WOULD NOT LATCH IN PROFILE) 12/2/12 PULL CATCHER FROM 7920' RKB. SET 2.68" SPECIAL CLEARANCE WRP @ 7870' RKB. CMIT T X IA TO 3000 PSI PASSED, IN PROGRESS. 12/3/12 PULLED 2.68" WRP @ 7870' RKB. ATTEMPT TO DRIFT 2 3/8" LINER W/ 1.85 ", UNABLE TO GET INSIDE LINER TOP. RAN 2.5" LIB, SHOWS A JAGGED CUT (SEE PICTURE IN ATTACHMENTS), IN PROGRESS. 12/4/12 ATTEMPT TO DRIFT LINER FOR UPCOMING JET CUT WITH 1.81" CENT & 1.50" S. BAILER, UNABLE TO WORK PAST 7905FT SLM (31 FT INTO LINER), RDMO 12/7/12 DRIFTED INSIDE 2 -3/8" LINER TO 8180' SLM, EST. 8183' RKB WITH 1.75" x 5' BAILER. TIGHT @ 8146' SLM, —8149' RKB. ABLE TO DRIFT THROUGH TIGHT SPOT @ 140 TO 150 FPM. READY FOR E/L. 12/21/12 CUT 2 3/8" LINER WITH JET CUTTER AT A DEPTH OF 8155'. ((( NORDIC 3 RIG JOB ))) SET 2.78" WRP ON DPU @ 75' SLM. PULLED 2.78 "WRP @ 75' SLM POST -RIG WELL WORK 1/10/13 PULLED BALL & ROD @ 7777' RKB. PULLED & REPLACED DV @ 7722' RKB. PULLED SOV @ 3031' RKB & REPLACED WITH DV. PULLED RHC PLUG BODY @ 7777' RKB. SET CAT SV @ SAME. MIT TBG 2500 PSI ( PASS) PULLED CAT SV. RAN SHIFTING TOOL AND CONFIRMED CMU @ 7777' RKB IS CLOSED, UNABLE TO DRIFT PAST 8124' RKB. DRIFTED TBG WITH 5' x 2" BAILER TO LINER TOP @ 8144' RKB. IN PROGRESS. 1/11/13 _ MEASURED BHP @ 7953' RKB ( 3056 psi) . DISPLACED TBG WITH 80 BBLS DSL ( 1BBL PER MIN. @ 2300 PSI) . READY FOR E /L. • • ConocoPhillips Time Log & Summary Wel/view Web Reporting Report Well Name: 2Z - 13 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 12/29/2012 3:00:00 AM Rig Release: 1/5/2013 4:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/28/2012 24 hr Summary Nordic Rig 3 move from 3S -pad to 1Y turn off towards 2Z -13 04:00 19:00 15.00 MIRU MOVE MOB P Move Nordic Rig 3 from 3S pad to CPF -3, Check tires and equipment while waiting on field change out. 19:00 00:00 5.00 MIRU MOVE MOB P Move Nordic Rig 3 from CPF -3 to Y turn off heading for 2Z pad. 12/29/2012 Nordic Rig 3 move from 1Y turn off to 2Z -13. Prepare location for MIRU. Pull rig over well, Spot support equipment and RU hardline. Pull BPV. Circulate 10.3 ppg brine KWF. 00:00 01:00 1.00 MIRU MOVE MOB P Move Nordic Rig 3 from 1Y turn off traveling towards 2Z pad. 01:00 02:00 1.00 MIRU MOVE MOB P PJSM. Roll up tarps and pull over well. DTH on site and building containment for kill tank. 02:00 05:30 3.50 MIRU MOVE MOB P Spot, level and shim rig, spot cuttings box. 05:30 12:00 6.50 MIRU MOVE MOB P Accepted Nordic Rig 3 at 03:00 hrs on 12 -29 -2012. Berm up Cellar. Warm up Rig. Spot support equipment. Load pits with 10.3 ppg brine. Spot kill tank and rig Up Hard line. RU cellar hoses and \\ fill lines to test. Load BPV lubricator. 12:00 14:30 2.50 MIRU WHDBO P PJSM -RU BPV lubicator. Pull BPV. 940 psi on tbg. Bleed gas off IA to kill tank 980 psi.. Check tbg , fluid packed. 14:30 18:00 3.50 MIRU WELCTL CIRC P Begin killing the well. Pump 10.3 4 brine down tbg taking returns up IA X" _to kill tank. Pumping at 4 bpm 200 psi pump pressure. 400 psi on ia. 130 bbls away, still no fluid on ia. Slow rate down to 2 BPM open choke more, still no fluid to surface, @ 170 away, bump back up to 5 BPM. Started getting fluid to surface but still have gas coming back. 18:00 21:00 3.00 MIRU WELCTL OWFF P Shut down, BDHL, Bleed OA pressure down to 400 psi, 386 bbls pumped, 325 bbls return, Tbg= 70 psi, IA =230 psi, 8.85 ppg water /crude to surface on IA. Empty kill tank. Bring on 290 bbls 10.3 ppg brine to pits. confer with town engineer. Page 1 of 8 • Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 22:30 1.50 MIRU WELCTL CIRC P Tbg= 210 psi, IA= 270 psi. circulate 100 bbls 4 bpm, ICP 600 psi, 300 psi choke pressure, 95% returns, FCP 590 psi. Bullhead 10 bbls into formation 1 bpm at 1150 psi, resume circulating 4 bpm, ICP 590 psi, 280 psi choke pressure, 180 bbls pumped FCP 460 psi, 160 psi choke pressure, 280 bbls pumped with 280 bbls returned. 22:30 00:00 1.50 MIRU WELCTL OWFF P Tbg /IA = 10 psi, monitor well. BDHL. Empty kill tank. Tbg= 40 psi, IA= 50 psi , Calculate and order up new KWF 10.9 ppg brine. Start load, rack and tally of 3.5" DP while _ waiting on KWF. 12/30/2012 Monitor well while waiting on new KWF. Circulate 10.9 ppg new KWF. Set BPV. ND Tree. Install blanking plug. NU BOPE. Unable to get shell test. Pull blanking plug and BPV. MIRU Slickline. 00:00 05:30 5.50 MIRU WELCTL OWFF T Continue to wait on new KWF from Prudhoe, call from dispatch at 00:50 truck with KWF stuck behind Doyon rig with problems on Spine road. Continue to load, rack and tally DP, DC's, load Baker equipment. 05:30 08:00 2.50 MIRU WELCTL OWFF T Still waiting on fluid. There is a hang up on the main spine road. 08:00 10:30 2.50 MIRU WELCTL CIRC P PJSM- Going to pump directly off truck. 11.0 heavy brine. Starting pressures T /IA/OA 20/50/300 Pump 10.3 vis pill 20 bbls. Pump at 3 BPM taking returns to the kill tank, some gas and dirty returns. After 20 bbls pill, swap to 11.0 heavy brine, taking returns to the pits. Circulate 290 bbls fully unload the truck. 10:30 11:30 1.00 MIRU WELCTLOWFF P Getting 10.7 brine in returns. shut down pump. well dead, observe well for flow. T /IA/OA= 0/0/350 watch for 45 minutes, good. 11:30 13:00 1.50 MIRU WHDBO NUND P FMC hand on location. PJSM- Set BPV with T -bar. RD hoses in cellar 13:00 16:00 3.00 MIRU WHDBO NUND P PJSM for nipple down. Nipple down tree. Threads on tubing hanger in bad shape, decide to install blanking plug, order up spear for pulling tubing hanger to floor as per FMC rep. 16:00 19:30 3.50 MIRU WHDBO NUND P NU BOP_E_, test equi ment, fill with water. 19:30 22:00 2.50 MIRU WHDBO BOPE T Attempt shell test against blanking , _ plug, eliminate BOP breaks and choke, surge pressure to get blanking plug to hold, no joy, call out for WRP. 22:00 22:30 0.50 MIRU WHDBO BOPE X PJSM- Pull blanking plug and BPV, both in good shape. Page 2 of 8 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 23:30 1.00 MIRU WHDBO BOPE X MU landing joint carefully with pump -in -sub, FOSV and Slick line quick union. 23:30 00:00 0.50 MIRU WHDBO SLKL X Slickline on site, spot equipment and PJSM- hazards associated with rigging up slickline. 12/31/2012 RU Slickline. Set WRP. Stand back Slickline. Test WRP 3000 psi. Funtion and test BOPE 250/3000 psi. RU Slickline. Pull WRD. RD Slickline. Spear tubing hanger and pull to floor. Circulate well clean. Pull 3 -1/2" completion. 00:00 02:00 2.00 MIRU WHDBO SLKL X Continue to RU Slickline. P/T equipment 500 psi. 02:00 03:30 1.50 MIRU WHDBO SLKL X TIH with Weatherford 2.74" OD WRP on Halliburton DPU, set WRP in middle of 2nd full joint down at 78 -ft, POOH and stand back Slickline equipment. 03:30 04:30 1.00 MIRU WHDBO PRTS X RD landing joint and close in blind rams, shell test against WRP 3000 psi. 04:30 10:00 5.50 MIRU WHDBO BOPE P Perform BOP ram choke, manifold and annular test 250/3000 psi with 3 -1/2" test joint. Perform Accumulator draw down test. 10:00 11:30 1.50 MIRU WHDBO BOPE P BOPE test complete. Rig down testing equip. Install landing joint for slickline W/ TIW valve. 11:30 14:30 3.00 MIRU WHDBO SLKL P PJSM -RU up slickline. RIH to 75', pull WRP -POOH. All elements are there. RD slickline. 14:30 17:30 3.00 7,840 7,830 COMPZ RPCOM THGR P PJSM -MU Joints to plant baker spear w/ seal cup. Hook up to top drive. BOLDS. Pull up, 120k, 135k,145k. Still not coming free. Kick on the pump, 4 BPM, work pipe up & down. Pull up to 150k pump still going, came free. Pull up, drag for 15' then pulled smoother. RIH smoothly. Get below bag, circulate a bottoms up prior to pulling hanger to the floor. BDTD. Pull hanger to floor and remove, PU and cut control) line 2 joints down and tie off, position tubing across bag and close. 17:30 18:30 1.00 7,830 7,830 COMPZ RPCOM CIRC P Reverse circulate 2 tubing volumes 6 bpm at 760 psi untill clean. 18:30 19:00 0.50 7,830 7,830 COMPZ RPCOM OWFF P Monitor well for flow, well on slight vac. 19:00 23:00 4.00 7,830 6,010 COMPZ RPCOM PULL P PJSM- tripping pipe. TOOH laying down 3 1/2" EUE tubing from 7,830 -ft, UP wt 95k, spooling control) line recovering 31 SS flat bands to 6,010 -ft, lay down SSSV. 23:00 23:30 0.50 6,010 6,010 COMPZ RPCOM OTHR P PJSM- NORM control line, good, offload spool and spooler. Page 3 of 8 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 6,010 5,820 COMPZ RPCOM PULL P Continue to TOOH with 3 1/2 "EUE tubing from 6,010 -ft, strapping and off loading as needed to 5,820 -ft, UP wt 75k. 01/01/2013 Continue to pull 3 -12" mpletion. MU and TIH with 2 3/8" liner fishing BHA to 7,825 -ft. 00:00 09:00 9.00 5,820 0 COMPZ RPCOM PULL P Continue to POOH with 3 1/2" EUE tubing from 5.820 -ft, tally and off load as needed, UP wt 75k. 09:00 11:00 2.00 0 0 COMPZ RPCOM OTHR P Clean and clear work area along pipe shed. 11:00 11:15 0.25 0 0 COMPZ WELLPF SFTY P Held PJSM with Rig crew and Baker fishing hand. 11:15 12:00 0.75 0 0 COMPZ WELLPF OTHR P Change over TBG equipment 12:00 15:00 3.00 0 341 COMPZ WELLPF PULD P PU and MU Itco spear w/ 1.992" Grapple BHA #2 to 341 -ft 15:00 23:00 8.00 341 7,825 COMPZ WELLPF PULD P TIH with BHA #2 on 3 1/2" DP to 7,825 -ft, Up wt 140k, Dn wt 95k. 23:00 00:00 1.00 7,825 7,825 COMPZ WELLPF CIRC P PJSM- Circulating. Establish slow pump rates and circulate 1 DP volume. P1= 20 spm at 350 psi, 40 spm at 1100 psi P2= 20 spm at 360 psi, 40 spm at 1130 psi 01/02/2013 Wash down and engage top of liner fish at 7,906 -ft. Circulate well clean. TOOH with BHA #2 and 237.62 -ft of 2 -3/8" liner, top of cut liner at 8,144 -ft. TIH with clean out BHA to PBR. Reverse circulate well clean. TOOH with BHA #3 laying down DP. 00:00 01:00 1.00 7,825 7,911 COMPZ WELLPF FISH P Wash down from 7,825 -ft, 2 bpm at 110 psi, get Up wt at 7,883 -ft of 143k, SO 3k at 7,911 -ft, PU with 4 -5k drag, TIH SO 4k at 7,911 -ft corrected, no change in pump pressure. 01:00 02:00 1.00 8,144 7,792 COMPZ WELLPF FISH P PUH slowly standing back 2 jts and 3 stands DP, 3 -4k overpull to 7,792 -ft, Up wt 140k. 02:00 04:00 2.00 7,792 7,792 COMPZ WELLPF CIRC P Drop 1 -7/8" dart, pressure up to 2200 psi, pump- out -sub open, pump 20 bbl high -vis sweep 2 bpm at 200 psi, circulate around STS, 8 bpm, ICP 2000 psi until well clean, FCP 2000 psi. 04:00 04:30 0.50 7,792 7,728 COMPZ WELLPF OWFF P Lay down 2 joints, Up wt 145k, monitor well, 04:30 08:30 4.00 7,728 574 COMPZ WELLPF TRIP P PJSM- TOOH with BHA #2 standing back DP from 7,728 -ft, Up wt 138k, to BHA #2. 08:30 09:30 1.00 574 238 COMPZ WELLPF PULL P POOH to spear and 2 3/8 TBG fish. 09:30 10:00 0.50 238 0 COMPZ WELLPF PULL P POOH laying down 237.63 -ft of 2 3/8 liner..._ Top of fish at 7,906 -ft corrected to ORKB, bottom of fish at 8,144 -ft corrected to ORKB. Page 4 of 8 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 10:45 0.75 0 0 COMPZ WELLPF OTHR P Change over to DP equipment, Clean and Clear work area and pipe shed. 10:45 11:00 0.25 0 0 COMPZ WELLPF SFTY P Held PJSM on PU and MU of BHA #3 with rig crew and Baker Fishing hand. 11:00 12:00 1.00 0 238 COMPZ WELLPF PULD P PU and MU BHA #3 (CSG Scraper) to 238 -ft 12:00 15:00 3.00 238 7,823 COMPZ WELLPF TRIP P RIH w/ BHA #3 from 238 -ft to 7,819 -ft -tag up - locate Top of PBR @ 7,822.5 -ft RKB Corrected depth 15:00 17:30 2.50 7,823 7,819 COMPZ WELLPF CIRC P Reverse circulate 104 bbls @ 4 bpm @ 800 psi. Wash down and No go in bottom of PBR @ 7,835.5 -ft RKB Corrected depth. Spot 35 bbl hi visc sweep at PBR - Pull out of PBR to 7,819 -ft and Reverse circulate @ 4 bpm @ 1,050 psi. - 43 bbl loss to Perfs during circulating. 17:30 18:00 0.50 7,819 7,819 COMPZ WELLPF OWFF P Monitor well for flow - No flow - Static 18:00 18:45 0.75 7,819 7,819 COMPZ WELLPF SFTY P PJSM- laying down DP. Crew change out, check alarms. 18:45 00:00 5.25 7,819 3,915 COMPZ WELLPF TRIP P TOOH laying down DP off loading as needed to 3,915 -ft. 01/03/2013 Continue to TOOH with BHA #3 laying down DP to 722 -ft. MU -RIH and set storm packer, BHA #3 below. test S.P. ND BOPE. ND tbg spool. ND csg spool. Casing grew total of 17 ". Spear and set 7" csg in emergency slips. Change out IC pack -off. Cut off excess 7" csg. NU New tbg spool test pack -offs. Shell Test BOPE. Retrieve BHA #4, continue to lay down DP and BHA #3. Prep to run 3 1/2" EUE gas lift completion. 00:00 02:30 2.50 3,915 733 COMPZ WELLPF TRIP P Continue to TOOH from 3,915 -ft laying down DP off loading qas needed to 835 -ft, stand back 1 stand. 02:30 03:30 1.00 733 803 COMPZ WHDBO MPSP P PJSM- PU MU 7" Model "EA" Retrievamatic storm packer to top of 15 jts of 3 -1/2 ", 13.3# DP and BHA #3. TIN with Top of Storm Packer set at 70 -ft. Stand back 1 stand SP, lay Town running tool. 03:30 04:00 0.50 803 803 COMPZ WHDBO PRTS P Pressure test storm packer to 3,000 psi, good, no flow test, good. 04:00 04:15 0.25 803 803 COMPZ WHDBO SFTY P PJSM- discuss hazards associated with ND BOPE, casing head and casing growth. Continue to load, drift and tally 3 -1/2" completion. Page 5 of 8 • Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 11:00 6.75 803 803 COMPZ WHDBO NUND P Make breaks at BOPE and tubing head, Iossen casing head, csg growing. Stand BOPE back on stump, ND tubing head. RU Hydratight system, Starting pressure was 8,000 psi and ending pressure was 1,600 psi - overall growth was 5 -1/4" Flange to Flange - 11 -1/4" . When lock downs were backed out 7" casing grew another 8" - engage spear and pull 55k over block wt - pack off never moved. Land 7" casing in 50k tension in slips with 4 -1/2" gain for a total of 17.75 ". Break down spear assy. 11:00 16:00 5.00 803 803 COMPZ WHDBO OTHR P Pull old FMC pack off, RU Wach's cutter and cut 16" off 7" casing stub. Install New FMC Gen II/ Gen IV inner casing pack off and NU FMC ben IV11 "3Mx7- 1%16 "5M. PT _pack off 250_/ 3,000 psi for 15 minutes - good test. 16:00 18:00 2.00 803 803 COMPZ WHDBO NUND P NU 11" 5M Class III BOPE stack install riser and RU choke and kill line. ....._ 18:00 19:00 1.00 803 803 COMPZ WHDBO OTHR Continue to load, drift and tally 3 -1/2" EUE gas lift completion, set wear bushing. 19:00 19:30 0.50 803 803 COMPZ WHDBO BOPE P PJSM- Close blind rams and conduct shell test at 250 / 3,000 psi against Baker Storm packer - good test. 19:30 21:30 2.00 803 0 COMPZ WHDBO PULD P PJSM- TIH with running tool and retrieve Model 'RA' retrievamatic BHA #4/3 from 71 -ft, TOOH lay down storm packer, conting TOOH laying down DP, DC's and BHA #3 used for storm packer BHA. 21:30 00:00 2.50 0 0 COMPZ RPCOM OTHR P PJSM- off Toad Baker tools, DC's and DP from rig. Clean cellar and floors. Change over floor equipment. Pull wear bushing. Prep to run 3 1/2" EUE gas lift complaetion, confirm running order. 01/04/2013 Run 3 -1/2" EUE gas lift completion. Unable to get IA to pressure up. RU Slickline, pull failed SOV, set DV in GLM #5, test IA to 500 psi. Pull DV, set SOV in GLM #1. RD Slickline. Sace out. load well with corrosion inhibited 10.9 ppg brine. Land completion. Attempt to test tbg. 00:00 05:30 5.50 0 7,768 COMPZ RPCOM RCST P PJSM- PU locator / seal ass'y and TIH with 3 1/2" EUE gas lift completion as per run order. 1p wt 95k, Dn wt 75k. Page 6 of 8 • Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 08:00 2.50 7,768 7,828 COMPZ RPCOM HOSO T PU joints #249, #250 and #251, no -go out with locator at 7828.15 -ft corrected to ORKB. Attempt to Verify seals in place by pressuring up IA to 300 psi - failed - returning up TBG string. Pump down TBG string w/ no returns up IA. Failed SOV. RU for slickline. 08:00 10:30 2.50 7,828 7,828 COMPZ RPCOM OTHR T Call out slick line - spot equipment. 10:30 13:00 2.50 7,828 7,828 COMPZ RPCOM RURD T PJSM - RU slick line - (Stop the job - 4 part shackle failure, nut fell off while picking up lubricator - result dropped object) - double checked all hook up. Finish up RU. 13:00 19:30 6.50 7,828 7,828 COMPZ RPCOM SLKL T RIH and recovered SOV - found to be sheared. RIH w/ DV, failed to set, POOH found small piece of metal in KO arm - caused damage to KO tool. - change out and back in hole w/ DV. PT IA to 500 psi - good test, PT TBG to 500 psi - good test - no communication to IA. POOH and change tools - RIH to GLM #1 and pull DV - failed sheard JD OS, RIH to GLM #1 and pull DV. POOH, dress tools. and Change tools - RIH w/ SOV and set in GLM #1- PT TBG to 500 psi - good test - POOH and RD Slick line. 19:30 21:00 1.50 7,828 7,795 COMPZ RPCOM THGR P PJSM- Pull out of PBR, MU full joint in completion for space out, tubing hanger and landing joint. MU head pin and circulating hoses. 21:00 22:15 1.25 7,795 7,795 COMPZ RPCOM CIRC P Reverse circulate 200 bbls 10.9 ppg corrosion inhibited brine, chase with 45 bbls 10.9 ppg KWF, 3 bpm at 360 psi ICP, 400 psi FCP. monitor well. Drain BOP stack 22:15 22:45 0.50 7,795 7,828 COMPZ RPCOM THGR P Land tubing hanger, RILDS. RD head pin and circulating hoses. 22:45 23:15 0.50 7,828 7,828 COMPZ RPCOM OTHR P Ball & Rod (6' -10" OAL, 1 3/8" fishneck, 1 5/16" OD) RU head pin and circulating hoses. 23:15 00:00 0.75 7,828 7,828 COMPZ RPCOM PRTS P PJSM- Pressure test tubing to 3,000 psi, monitor with casing valve open, pressure started to level out then fell off, Bump up to 3100 psi, leak of same, bleed pressure to 0 psi. 01/05/2013 Continue to Test tbg, RHC plug leaks. Test IA 3,500 psi. Shear SOV. Set BPV and test. ND BOPE. NU tree. Pull BPV, Set TWCV. Test tree and hanger void. Pull TWCV. Freeze protect. Set BPV. RDMO. �^ Page 7 of 8 • Time Logs • • Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 01:00 1.00 7,828 7,828 COMPZ RPCOM PRTS P Pressure test tubing to 3,000 psi, monitor with casing valve open, same slow leak off 500 psi in 15 minutes with no visible fluids coming from open IA vale, confer with town engineer, bleed tubing to 2,000 psi, Pressure test IA to 3,550 psi, tubing 2600 psi, on chart 15 minutes IA/T= 3450/2250 psi, 30 minutes IA/T= 3425/1900 psi, MIT -IA passed, bleed tubing down to shear SOV, SOV sheared 1500 psi, bleed tubing and casing to 0 psi. 01:00 01:30 0.50 7,828 7,828 COMPZ RPCOM OWFF P Monitor well for flow, static. 01:30 02:00 0.50 7,828 7,828 COMPZ WHDBO MPSP P PJSM- RD landing joint. Install 3 1/2" �S A BPV. Pressure up under BPV down IA to 1250 psi, good 10 minutes. Barriers in place 02:00 05:30 3.50 COMPZ WHDBO NUND P ND BOPE, NU tree, DSO witness to verify tree orientation. 05:30 06:00 0.50 COMPZ WHDBO MPSP P Pull BPV and set TWCV. 06:00 06:30 0.50 COMPZ WHDBO PRTS P Pressure test tree and tubing hanger voids 250/5000 psi. 06:30 07:00 0.50 COMPZ WHDBO MPSP P Pull TWC 07:00 10:00 3.00 COMPZ WHDBO FRZP P Held PJSM, Spot and RU Little Red Services. PT lines @ 2,000 psi, FP well w/ 80 bbls @ 2 bpm @ 650 psi. RD LRS. Allow well to swap - stablized @ 320 psi. 10:00 14:30 4.50 COMPZ WHDBO MPSP P Lubricate in BPV and secure well. Clean and dress well head. SI pressures 320/320/0. 3" HBPV failed while running - retrieve and install a different one. RD Lubricator. 14:30 16:00 1.50 COMPZ MOVE DMOB P Raise tarps, Jack up rig, and pull off well. Clean cellar with super sucker and Release Nordic 3 @ 16:00 hrs. Page 8 of 8 KU P • 2Z -13A ConoccPhiJI ps ='` Well Attributes M ax Angle & MD TD Alaska. Inc , Wellbore APVUWI Field Name Well Status !nci (°) MD (ftKB) Act Btm (ftKB) i. 500292136001 KUPARUK RIVER UNIT PROD 95.12 _ 9,036.06 9,300.0 Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date "' _ SSSV: LOCKED OUT 130 10/11/2007 Last WO: 1/5/2013 42.10 7/7/1985 Well C 80: 2Z -13A, 1/[8!2013 3'.02:08 PM Shematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7.920.0 9/13/2009 Rev Reason: WORKOVER osborl 1/16/2013 HANGER,31 - Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 36.0 80.0 80.0 62.50 H WELDED 4 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String W .... String ... String Top Thrd I SURFACE 95/8 8 35 4 3 36 J -55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd WINDOW AL1 8 6.000 8,161.0 8,166.0 6,020.1 26.00 J -55 CONDUCTOR, Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 36-80 PRODUCTION 7 6.276 32.6 8,506.7 6,091.1 26.00 J -55 BTC t- Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER A 23/8 1.992 8,634.2 9,142.0 6,094.9 4.40 L - 80 STL NIPPLE, 505 C i_'' Liner Details Top Depth - (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID (In) GAS LIFT, °_ 9,106.5 6,096.6 92.53 0 - RING BTT 0 - RING SUB 1.000 3,031 Mr Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (5... Set Depth (TVD) ... ng Wt... 'String ... String Top Thrd II TUBING WO 3 1/2 2.992 I 30.9 I 7,827.5 I 5,772.3 'String Wt... L-80 EUE8rd Completion Details Top Depth SURFACE. L. (TVD) Top Intl Nomi... 35-4,203 Top (ftKB) (ftKB) (°) Item Description Comment ID (in) ar 30.9 30.9 0.26 HANGER FMC Gen3 7' X 3 1/7 Tubing Hanger w/ 2.62 -ft pup 2.992 GAS LIFT, 505.2 505.2 0.66 NIPPLE Camco DS Nipple w/ 2.875" profile (SN: T061243) 2.875 ar IIR 7,776.7 5,735.6 43.58 SLEEVE Baker CMU Sliding Sleeve w/ 2.813" "DS" Profile (RHC plug installed) 2.813 inkl 7,825.5 5,770.8 42.11 SEAL ASSY Baker Locator Assembly w/ 11.89 -ft of seals spaced out 2 -ft 2.990 GAS LIFT, Tubing Description String 0... String ID ... Top (ftKB) Depth (f... Set Depth (TVD) ... String Wt... StrIng ... Top Thrd 6,114 f- TUBING Original 1 1/2 I 2.967 I Set 7,827.5 I 8,154.4 I 6,012.7 I 9.30 I J -55 I String FL4S - Completion Details Top Depth (TVD) Top Inc! Nomi... GAS LIFT, _ ,�� Top (ftKB) (ft68) (°) Item Description Comment ID (In) 7,086 7,835.6 5,778.3 42.09 PBR BAKER PBR 3.000 7,849.3 5,788.4 42.07 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 7,999.5 5,900.1 41.78 BLAST RINGS CARBIDE BLAST RINGS (3) 2.967 GAS LIFT, 7,722 8,097.1 5,971.7 43.94 BLAST JT BAKER STEEL BLAST COLLAR ""HAS LEAK" 2.867 COLLAR 8,150.3 6,009.6 44.97 LOCATOR BAKER LOCATOR SUB 3.000 8,151.1 6,010.4 53.59 PACKER BAKER FB-1 PERMANENT PACKER 3.000 SLEEVE. 7,777 - -- i - Other In Hole (Wireline retrievable plugs, valves, pump : „ ,' „" is 1 1 .. Top Depth (TVD) Top Inc/ Top (ftKB) (ftKB) (°) Description Comment Run Date ID (In) SEAL ASSY. - 8,156,0 6,013.8 54.79 WHIPSTOCK AL1 BTT MECHANICAL WHIPSTOCK 1/21/2007 7.826 0 TUBING PUP, 7.838 PBR, 7,838 f I Perforations & Slots Shot PACKER, 7,849 4 Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date Oh- Type Comment PRODUCTION.' 8,182.0 8,192.0 6,028.8 6,033.2 UNIT B, 2Z -13A 4/6/2007 6.0 PUNCH LINER HOLE PUNCHES 6 SPF 7,888 w/PJ1606 8,308.0 8,629.0 6,075.4 6,096.2 A-4, A -3, 2Z -13A 1/21/2007 32.0 SLOTS Altemating solid/slotted pipe PRODUCTION, 8,634.0 8,729.0 6,096.5 6,104.5 A-4, 2Z -13A 1/21/2007 32.0 SLOTS Alternating solid/slotted pipe 7,961 SLOTS. 8,822.0 9,043.0 6,109.1 6,101.0 A -4, 2Z -13A 1/21/2007 32.0 SLOTS Alternating solid /slotted pipe 7,917 -8,085 I I I Notes: General & Safety I End Date Annotation I I 2/8/2007 NOTE: MULTILATERAL SIDETRACK, 2Z -13A & 2Z -13AL1 (AL1 off main wellbore) I i 2/8/2007 NOTE: GLMs #9 & #11 blocked by solid pipe portion of Sidetrack Lateral AL1 PRODUCTION. u I 9/13/2009 NOTE: WAIVERED WELL T x IA x OA COMMUNICATION 8,131 LOCATOR, 12/30/2010 NOTE: View Schematic w/ Alaska Schematic9.0 8,150 -� PACKER, 8,15 12/21/2012 NOTE: TOP 298' AL1 LINER TOP PULLED FOR 2012 WORKOVER W HIPSTOCK 8,156 WINDOW AL1, 8,181 -8,166 PUNCH, 8,182-8,192 SLOTS, 8,308-8,629 PRODUCTION, 33-8,507 SLOTS, 8,834 -8,729 SLOTS, III LINER LINER AL1 Post 2012 Cut, 8,144-9,107 1 1 Mandrel Details Top Depth Top Port (TVD) 1001 OD Valve Latch Size TRO Run _Stn Top (ftKB) (989) (°) Make Model (in) Seta Type Type OM Wig Run Date Com... 1 3,030.9 2,561.1 47.55 Camco MMG 1 12 GAS LIFT SOV RKP 0.000 0.0 1/4/2013 2 4,801.0 3,745.6 51.71 Camco MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/4/2013 3 6,114.4 4,603.6 48.43 Camco MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/4/2013 4 7,086.2 5,258.4 48.56 Camco MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/4/2013 5 7,721.7 5,696.0 44.19 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 1/4/2013 6 7,887.8 5,817.0 41.99 MERLA TPDX 1 12 PROD CV RM 0.000 0.0 11/29/2012 7 7,960.6 5,871.2 41.85 MERLA TPDX 1 12 PROD DMY RM 0.000 0.0 12/16/2006 8 8,130.8 5,995.8 44.60 MERLA TPDX 1 12 PROD DMY RM 0.000 0.0 12/26/1992 LINER A, 8,634 -942 TD (2Z -138A), 9.300 • ~ .` ~~~ ~~~~. . ~ ~~ ~. ;~.~ ~~ ~ ~ ~ ~_ ,~ ~~ ,~~ ~~` 8 ~ ' ~.. ( e `~~h ~ MICROFILMED 6/30/2010 D O NOT P LAC E ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc Cc~coPhllips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~~~ ~~~ ~PR~~2o~Q ~~~g~ Ciif ~ ~2s . Wis. ~ommiss~c~ Q~~vrage April 17, 2010 / ~ / ~O ~~ ~~~ Mr. Dan Seamount - d~• Alaska Oil & Gas Commission ~„ f . ~;,, :, ~ ~ x 333 West 7~` Avenue, Suite 100 ,"~~~ ~ `~'`' d- ~ "' Anchorage, AK 99501 Dear Mr. Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRiJ). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped January 16, March 21, 2010. The corrosion inhibitor/sealant was pumped April 15, 16 and 17, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. " Please call Peny Klein or MJ Loveland at 907-659-7043, if you have any questions. Projects Supervisor ! ! ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field 4/17/2010 26. 2E_ 2G_ 2H_ 2K_ 2M_ 2V_ 2W_ 2X_ 2Z & 3S PAD's WeIlName API# PTD# Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 26-05 50029210670000 1840040 24" n/a 24" Na 4.2 4/16/2010 2B-08 50029210790000 1840260 21" 3.30 7" 1/16/2010 2.5 4/16/2010 2B-16 50029211460000 1841140 92" 0.65 3/21/2010 2.5 4/16/2010 2E-10 50029212460000 1842300 SF Na n/a n/a 5.9 4/16/2010 2E-17 50029224190000 1931740 8'9" 1.50 19" 1/16/2010 3.4 4/16/2010 2G-13 50029211600000 1841290 SF n/a 22" n/a 3.4 4/16/2010 2H-07 50103200450000 1851700 SF n/a 17" Na 2.1 4/15/2010 2H-09 50103200500000 1852590 SF n/a 17" n/a 2.5 4/15/2010 2H-15 50103200340000 1840860 SF n/a 17" n/a 2.5 4/15/2010 2H-16 50103200350000 1840870 SF n/a 17" n/a 2.5 4/15/2010 2K-19 50103201180000 1891090 53" 0.50 9" 1/16/2010 2.1 4/15/2010 2M-07 50103201780000 1920800 SF n/a 17" Na 3.4 4/15/2010 2M-08 50103201840000 1921010 SF n/a 17" Na 2.1 4/15/2010 2M-20 50103201690000 1920480 SF n/a 17" Na 2.5 4/15/2010 2M-22 50103201700000 1920490 SF n/a 17" n/a 2.5 4/15/2010 2M-28 50103201740000 1920700 SF Na 18" Na 2.1 4/15/2010 2V-O6 50029210540000 1831790 SF Na 19" Na 7.6 4/16/2010 2V-10 50029213100000 1850480 SF n/a 19" Na 2.5 4/16/2010 2V-16 50029212960000 1850330 SF Na 21" n/a 5.1 4/16/2010 2W-03 50029212740000 1850110 SF Na 3T' Na 4.2 4/16/2010 2X-11 50029211880000 1841640 SF Na 17" n/a 6 4/17/2010 2Z-11 50029213790000 1851380 SF n/a 19" n/a 2.5 4/15/2010 2Z-12A 50029213800100 1951480 SF Na 19" Na 2.5 4/15/2010 2~ 13A 50029213600100 2061700 SF Na 22" Na 4.25 4/15/2010 2Z-19 50029218820000 1881300 SF Na 16" n/a 2.1 4/15/2010 3S-09 50103204320000 2022050 SF Na 45" Na 23 4/17/2010 • „ • ~~~~i~~~~ ~~~~~~~ .~~~~ ..a: ~~~~ ~~~~~;~~~~?~~r~ ~~c~~~~~~s No otfaer dastribut~~n is allow~d wst~toca~ O~ ~g~~~ ~~i ~Bi4A~ vuritten approval frorn ~~nocoPhollips ~mage fiiEes arod/or ~igi#al ~ata contact: Lisa Wright, 907 263-4823 hardcopy pr6nts ~~s~~~~Y~~39~9tlY~e~9 ~Y~e~~~y 3~`~, ~ . _ ~ . .. ~ ~'9~fA ~~~9~~~~~ ~~'~~g ~~~6"~ a~~'J ;5~~~ ~; ~Ia~~~ ~a~.~'s~s.~l`~ ~~'!,.a '~ ~~~'~~~, ~IYCliiV@VA~vy ~I(~'~ ~~~Y~~~~~1 ~Ov~~ . ~. ~ ~ . .,. ~ ~hr9s~ine ~ah~ak~n 1 Graphic image file ~ ~. 333 W~st 7~h Ave, SaaOt~ ~~0 in lieu of sepia** Electronic Anchorage, Alaska 99501 CGM / TIFF LIS ~P , u~ , ~ -':-~ , Petrotechraicai Data ~era~~r, M~33 1 Graphic image file ~; ~:~;_~l David Douglas in lieu of sepia** Electronic P.O. ~ox 196612 CGM / TIFF LIS Anchorage, Alaska 99519-6612 CHEVRONlKRU REP ~ =: ~ ;~;1 ~e'~~ ~~; Glenn Fredrick 1 Graphic image file v,~~e`~i P.O.~ox 196247 in lieu of sepia** Electronic l~nchorage, Alaska 99519 CGM / TIFF LIS Kristen Dirks, GeologBst State of.4laska; DNR, Div. ~f Oil and Gas :~~~5~~`~% 550 W. 7th Ave, Suite 800 Electronic Anchorage, s4laska 99501-3510 LIS #**s L~~~~ ~oaa.A~~ T~iE m~'a a 9-81~eT W~~'s ~iER1T ~F°c~~`8~!S~L'~l. °~°~~ ~A 3 ~ i~~S ~E~~ ~~RRE~TE~ ~~ ~FitS ~~. ~,~~ =t't:'~~~~"`: ~G~}~`~ ~ . ~~'.~~.`~~ ,,~ „~•.,~ ~0~- l'3 U 1 `b 3Cl ~ Page 1 of 9 ~ Greater Kuparuk Area*** Data Distribution RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and/or Digital Data contact: Lisa Wright, 907 263-4823 hardcopy prints ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 AOGCC 1 Hardcopy Print, Christine Mahnken 1 Graphic image file 1 Disk*/ 333 West 7th Ave, Suite 100 in lieu of sepia*" Electronic Anchorage, Alaska 99501 CGM / TIFF LIS BP 1 Hardcopy Print, Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk*/ David Douglas in lieu of sepia** Electronic P.O. Box 196612 CGM / TIFF LIS Anchorage, Alaska 99519-6612 CHEVRON/KRU REP 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file 1 Disk*/ P.O.Box 196247 in lieu of sepia*~ Electronic Anchorage, Alaska 99519 CGM / TIFF LIS Kristen Dirks, Geologist State of Alaska; DNR, Div. of Oil and Gas 1 Disk*/ 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501-3510 LIS J'~ r~`-/ i~r~ 1rA 1_./ ~ - ~ _. ~ 1 ~~ ~ ... ~ .. / ... ~i! A~$'~^ S ^t S~:-i:- - \ l ~~ ~ • ~1~.. ~~~~~~~ ~ <) ZOu~i ~1UL W ~ ~iask~ Uil ~ C3as ~%o~~~ C;f,m~~issi~r3 Asrchora~~ Page 1 of 2 DATA SUBMITTAL COMPLIANCE REPORT 11 /18/2008 Permit to Drill 2061700 Well Name/No. KUPARUK RIV UNIT 2Z-13A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21360-01-00 MD 9300 TVD 6089 Completion Date 2/8/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey s DATA INFORMATION Types Electric or Other Log s Run: MWD DIR, GR, RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Tye Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D Asc Directional Survey 8100 9300 Open 2/26/2007 Rp t Directional Survey 8100 9300 Open 2/26/2007 ~ c.l%g . Pressure Blu 1 7700 7876 Op€n 2/13/2008 SBHPS, Pres, Temp (,/Log Leak C Pds 17043!/Leak ~i ell Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? ~Id~ Analysis 4`tid~ Received? Interval Start Stop Ggyar Gradio, GR, CCL 11-Feb- 2008 5 Blu 800 7890 Case 11/7/2008 LDL, Pres, Temp, CCL, GR, Gradio, ILS, FBS 15- Sept-2008 800 7890 Case 11/7/2008 LDL, Pres, Temp, CCL, GR, Gradio, ILS, FBS 15- Sept-2008 Sample Set Sent Received Number Comments Daily History Received? !"`"' Formation Tops ~J Comments: O ~ ~„~ DATA SUBMITTAL COMPLIANCE REPORT 11 /18/2008 Permit to Drill 2061700 Well Name/No. KUPARUK RIV UNIT 2Z-13A MD 9300 TVD 6089 ,Completion Date 2/8/2007 Compliance Reviewed By: -_ _ _~/•_.+~_ _____ _____.__ Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21360-01-00 Completion Status 1-OIL Current Status 1-OIL UIC N Date: __ /~~ov_±_~ ~~~~~~~ NO.4914 `~ <',;. Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 10/14/08 1 L-23 12097405 SBHP SURVEY / 07/17/08 1 1 2A-17 11975793 PRODUCTION PROFILE 9 - /(. p G 09/10/08 1 1 3G-25X 12080437 LDL ~ - 3 L/(o 09/21/08 1 1 2C-04 12100444 INJECTION PROFILE .C.r C ( 09/14/08 1 1 3M-13 12096541 LDL - (~L( ( UC-( 09/10/08 1 1 2Z-13A 12100446 LDL O(o- I'3O ~U 3 09/15/08 1 1 1 F-06 12096510 PRODUCTION PROFILE 07/17/08 1 1 3C-14A 12080436 SCMT - 5 ct 09/22/08 1 1 1C-111 12100451 INJECTION PROFILE "t p ~ 09/20/08 1 1 30-15 12100452 LDL - ~ 5a 09/21/08 1 1 1C-117 12100453 INJECTION PROFILE o ~ r 09/23/08 1 1 iR-11 11966277 SBHP SURVEY -- (~ 09/25!08 1 1 1 R-35 11966279 SBHP SURVEY p 09/25/08 1 1 1 R-14 11966286 LDL ( 09/29/08 1 1 2X-18 12080443 PRODUCTION PROFILE _ 09/30!08 1 1 1 R-34 12080444 GLS ~jL ,,. 10/01/08 1 1 2A-13 12096547 PRODUCTION PRO ILE .= L C/ 10/02/08 1 1 1 D-01 12097422 GLS 10/03/08 1 1 1 R-07 12097425 PRODUCTION PROFILE ~''~ '~ ( 10/06/08 1 1 1 H-19 12096548 INJECTION PROFILE L~ 10/03/08 1 1 1 B-16 12097426 GLS ~ =' 10/07/08 1 1 3B-09 12100442 PRODUCTION PROFILE - 09/12/08 1 1 3K-103 12096550 USIT 10/06/08 1 1 2X-05 12096551 INJECTION PROFILE - ~~ 10/07/08 1 1 iB-04 12096552 INJECTION PROFILE -- ~ 10!08/08 1 1 1A-02 12096553 INJECTION PROFILE ~ 10/09/08 1 1 1 B-16 12096554 PRODUCTION PROFILE q C" - G 10/10/08 1 1 2D-15 12096555 PRODUCTION PROFILE ~'~C , 10/11/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. FW: 2Z-13A (PTD 206-170) Request For Production Test Page 1 of 2 Maunder, Thomas E (DOA From: Maunder, Thomas E (DOA) Sent: Wednesday, October 29, 2008 8:21 AM To: 'NSK Problem Well Supv' Subject: RE: 2Z-13A (PTD 206-170) Request For Production Test MJ, It is acceptable to bring the well on to test for the 30-day period. Please keep us advised. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Wednesday, October 29, 2008 5:22 AM To: Maunder, Thomas E (DOA) Subject: FW: 2Z-13A (PTD 206-170) Request For Production Test Tom, Have you had a chance to review this request? Please advise. Thanks MJ Loveland From: Salas, ]ose Ricardo Sent: Tuesday, October 28, 2008 4:43 PM To: NSK Problem Well Supv Cc: CPF2 Prod Engrs Subject: RE: 27-13A (PTD 206-170) Request For Production Test Brent, Have you hear a response for this petition? Thanks, Jose Salas KRU Drillsite Engineer Tel: 263 4249 From: NSK Problem Well Supv Sent: Wednesday, October 2Z, 2008 12:16 PM To: 'tom.maunder@alaska.gov' Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Salas, Jose Ricardo 10/29/2008 FW: 2Z-13A (PTD 206-170) Request For Production Test Page 2 of 2 • Subject: 2Z-13A (PTD 206-170) Request For Production Test Tom, Kuparuk gaslift producer 2Z-13A (PTD 206-170) was reported to AOGCC on 9/13/08 as being identified to have possible TxIA communication. The leak was confirmed using an electric line leak detection log on 9/15/08. The 2Z-13 has been internally waivered since 1/30/02 for IAxOA communication which allows the two annuli to equalize at gaslift pressure of 1400 psi. The nature of the leak allows IA gas to pressure up the OA but will not allow fluid to leak based upon multiple passing MITs since the well has been waivered. The well underwent a coiled tubing sidetrack in early 2007 and was completed as an A sand dual lateral gaslift producer. Due to less than expected production in the A sand, an effort was undertaken to reestablish C sand production from the isolated selective. It was during this work that the TxIA communication was observed. Base upon the diagnostics to date it is becoming apparent that the well may require a workover to establish long term production from this wellbore. We are however, unable to substantiate the case for a workover due to no combined A and C sand production tests from this well in its current configuration. ConocoPhillips would like to return the well to production with TxIA communication for a period not to exceed 30 cumulative days to gather enough production data to justify additional wellwork. Attached is a 90 TIO plot, wellbore schematic, and the most recent CMIT form. « File: 2Z-13A TIO Plot.ppt » « File: 2Z-13A Wellbore Schematic.pdf » « File: MIT KRU 2Z-13A 10-14- 08.x1s » Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 10!29/2008 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg~alaska.gov; tom.maunc~r~alaska.gov;bob.tleck ~ a~sira.gov;dog.aogcc.prudhoe.bay~alaska.gov OPERATOR: FIELD / UNIT t PAD DATE: OPERATOR REP: AOGCC REP: GorocoPhi~ips Alaska trtc_ Kuparuk t KRU t 2Z 10/14108 Bates / Greertvrood Packer Pretest Ind 15 Min. 30 Min. Well 2Z-13A Type Inj. W TVD 5,789" Tubing ' 550 2,600 2,550 2,540 Interval O P.T.D. 206170 Type test P Test ~ 150Q Casir~ 650 2,760 2,710 2,700 P/F P Notes: Diagnostic TxiA CMIT f7r4 7 760 760 760 Well Type Inj. TVD Tuts Interval P.T.D. Type test Test Case P/F Notes: OA Well Type Inj. TVt:} Ttttnng ' Interval P.T.D. Type test Test Easing P!F Notes: OA Well T Inj. TVD Tubing Interval P.T.D. Type test Test psi Easing. .. P/F Notes: QA Well T Inj. TVD Tubing, Interval P.T.D. T test Testpsr` Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M = Armak~s P = Started Pressure Test. R = Irrterr~t Tracer Surv~r A = Temperatwe Anorr~iy Survey D = 'al Terraper~ure Test INTERVAL Codes 1=Initial Test 4 =Four Year Cycle V = Required by Variance T =Test during Workover O =Other (descrit~ in notes) MIT Report Form BFL 11/27/07 MIT KRU 2Z-13A 10-14-08.x1s IAP 1200 1000 800 N a 600 400 200 0 OAP t ................................~............................................, ........................................................................~ ................................................................................................................................................... ~-- ~~ _-~ ---- T/l/4 Plot - 2Z-13 )0 150 a E as 100 Y 0 s V 50 01-Aug-08 01-Sep-08 Date 01-Oct-08 0 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION s~: :~:'~~ SE° ~ g 7_t~~:Y REPORT OF SUNDRY WELL OPERATI~~ ~ ~ ~, ' ~x~. • 1. Operations Performed: Abandon ^ Repair Well ^ • Plug Pertorations ^ Stimulate ^ Ot '' ^' Alter Casing ^ Pull Tubing ^ Perforate New Pooi ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ Exploratory ^ 206-170 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21360-01 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 32.6' 2Z-13A ' 8. Property Designation: 10. Field/Pool(s): ADL 025653 • Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9300' - feet true vertical 6089' feet Plugs (measured) Effective Depth measured 9142' feet Junk (measured) true vertical 6095' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SURFACE 4170' 9-5/8" 4203' 3360' PRODUCTION 8474' 7" 8506' 6091' LINER 512' 2-3/8" 9142' 6095' Perforation depth: Measured depth: 8308'-8629', 8634'-8729', 8822'-9043' true vertical depth: 6076'-6096', 6097-6105', 6109'-6101' -- Tubing (size, grade, and measured depth) 3-1/2" , J-55, 8175' MD. Packers & SSSV (type & measured depth) no packer Baker FVL ~ 1820' ' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 7882' Treatment descriptions including volumes used and final pressure : 15 bbls of oil Safe AR 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 75 - 845 45 -- 217 Subsequent to operation shut-in -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ 'Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact John Peirce @ 26 5-6471 Printed Name John Peirce Title Wells Engineer S~~c~/ Signature A ~ Phone: 265-6471 Date ~li l / ~ Q G~' Pre a Sharon A11/ u Drake 263-4612 Form 1 -404 Revised 04/2006 *~ ~> ~~~ ~ ~ ~QQg Submit Original Only 2Z-13A Well Events DATE 'SUMMARY 8/11/08 ATTEMPTED TO SET WRP B ~ PRODUCTION MANDREL AT 7888'. ~LD NOT GET WRP THROUGH PRODUCTION MANDREL. TAGGED UP HARD WITH BOTH 2.78" AND 2.69" WRP. WENT IN WITH 2 1/8" IBP. SET IBP CENTER OF ELEMENT AT 7910'. 8/12/08 SPOTTED 15-BBL OF OIL SAFE AR (OSAR) (WITH NanoBOOST) AT CATCHER SUB AT 7882'. DISPLACED ENTIRE TUBING ABOVE OSAR PILL TO DIESEL. LEFT WELL SHUT-IN AND FREEZE PROTECTED. 8/12/08 SET CATCHER SUB @ 7882' SLM, ON IBP. COMPLETE. 8/15/08 BRUSHED TBG WITH 3.5" BLB FROM 7879' TO 7000' SLM. 8/17/08 BRUSHED TBG & GLM Cad 7888' RKB TO AGITATE SOAKING OSAR. ATTEMPTED PULL DV, NO SUCCESS. IN PROGRESS. 8/18/08 ATTEMPTED REMOVE CMT / DEBRIS AROUND LATCH ON DV @ 7888' RKB WITH PULLING /RUNNING TOOLS ON K.O.T. JOB SUSPENDED. 8/20/08 ATTEMPT TO REMOVE CMT /DEBRIS FROM CSM @ 7888' RKB. IN PROGRESS. 8/21/08 ATTEMPT TO REMOVE CMT /DEBRIS FROM CSM @ 7888' RKB. IN PROGRESS 8/25/08 BRUSH CSM AT 7888' RKB. LATCH DV 7888' RKB & ATTEMPT TO PULL. VALVE STILL IN POCKET. JOB SUSPENDED DUE TO TREE VALVES NEED REPLACEMENT. 8/31/08 BRUSH & FLUSH TBG FROM 7800' SLM TO 7872' SLM FOR WRP. PULLED AVA CATCHER @ 7882' SLM. "**RECOVERED SAMPLE*"". JOB COMPLETE. 9/2/08 SET 3.5" WRP MID-ELEMENT AT 7864'. 9/4/08 DRAW DN IA TO 250 PSI, DRAW DN TBG TO 500 PSI, PULL OV STA #7 @ 7474' RKB. JOB IN PROCESS. 9/5/08 LOAD TBG& IA W/ 272 BBLS DIESEL. CMIT TO 2500 PSI,PASSED. DRAW DOWN (TxIA) _TO_500 PSI, PASSED. WELL READY FOR BPV. 9/6/08 DD -TEST T8~ IA- PASSED (FOR TREE CHANGE), 9/7/08 SET 2.75" AVA CATCHER @ 7838' SLM. ATTEMPT TO SET OV @ 7474' RKB, NO SUCCESS. JOB IN PROGRESS. 9/8/08 SET 1/4" OV (BTM LATCH) @ 7474' RKB. TEST ON TBG FAILED, IA TRACKED. RAN TEST TOOL.*** DETERMINED LEAK BETWEEN 6795' & 6786' SLM""" IN BETWEEN r STN# 5 & 6. PULLED CATCHER @ 7838' SLM. E-LINE LDL CANDIDATE. 9/12/08 PULLED 3.5" WRP @ 7864' MD , PULLED C SAND DV @ 7888' RKB. IN PROGRESS. 9/13/08 SET HFCV @ 7888' RKB. REPLACED GLV @ 6735' RKB WITH NEW. TEST TOOL CONFIRMED APPARENT COMMUNICATION ETWEEN 6800' 8~ 6792' SLI~Q. PULLED HFCV @ 7888' RKB, SET DV. TESTED TBG/IA 2000 PSI, GOOD TEST (2.75" AVA CATCHER @ 7885' SLM). READY FOR LDL. 9/15/08 LOG LEAK DETECTION LOG FROM SURFACE TO 7890'. LEAK LOCATED AT 6914' CONFIRMED. PROBABLE LEAK AT 6860'. IBP IS NOT LEAKING. DID NOT TAG TD. .T ~ • Cono~o~hilfi~as Alal~kal, lnc. KRU 2Z-13A ' 2Z-13A APL 500292136001 Well T e PROD An le TS: d _SSSV Type: Locked Out _ Orig Completion: 2/8!2007 Angle aQ TD: 93 de 9300 Annular Fluid: Last W/O Rev Reason: _ Cut 8 Pull to 41' liner Reference Log_ --_ 32.6_'_ RKB Ref Loq Date: Last U date: 4/12/2008 _ _ Last Ta TD: _ -- 9300 ftK6 Last Ta Date: -- Max Hole An le: 95 de 9036 Casin Strin - COM STRINGS fi a Descri lion Size Top Bottom TVD Wt Grade Thread - PRODUCTION _ _ 7.000 __ _ _ 0 8507 6091 26.00 J-55 BTC SURFACE 9.625 0 4203 3360 36.00 J-55 BTC CONDUCTOR 16.000 0 80 80 _ 62.50 H-40 WELDED Lateral AL1 Slotted Liner To 2.375 7920 8068 5950 4.40 L-80 STL Lateral AL1 Solid Liner Top 2.375 8068 8183 6029 4.40 L-80 STL WINDOW #1 3.300 8183 8184 _ 6030 0.00 _ 1 _ WINDOW #2 7.500 8183 8184 6030 0.00 Casin Strin -SIDETRACK Description _ Size __ _ Top Bottom _ TVD Wt Grade Thread Sidetrack A To Slotted Liner 2.375 8183 8634 6097 4.40 _ L-80 _ _ STL Sidetrack BoL'cr P, S!c;tod Liner 2.3?5 8630 9142 6095 4.40 L-80 STL Tubin Strin -TUBING Size _ Top _ _ Bottom TVD Wt Grade_ _ Thread 3.500 0 8175 6025 9.30 J-55 _ 8rdEUE I Pe_ _rForatio_ns Summa_ _ _ _ _ Interval TVD Zone Status Ft SPF Date T e Comment 7902 - 8068 5828 - 5950 _ 166 32 2/6/2007 SLOTS_ 2 Z-13AL1 Slotted Liner To 8308 - 8629 6075 - 6096 321 32 1/21/2007 SLOTS 2 Z-13A Slotted Liner 8634 - 8729 6097 - 6104 95 32 1/21/2007 SLOTS 2 Z-13A Slotted Liner 8822 - 9043 6109 6101 221 32 1/21/2007 SLOTS 2 Z-13A Slotted Liner St_i_m_ ulations__8 Treatments_ _ --_ Interval Date T e Comment 8182 - 8192 416200? HOLE PUNCHES LINER HOLE PUNCHES 6 SPF w/PJ1606 _ Gas Lift MandrelsNalves _ St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2011 1865 Merla TMPD GLV 1.0 BK 0.188 1304 2/24/20 07 - 2 4132 3311 Merla TMPD GLV 1.0 BK 0.188 1307 _ 2/24/2007 3 5702 4324 Merla TMPD GLV 1.0 BK 0.188 1303 2/24/2007 Perf _ 4 6360 4768 Merla TMPD DMY 1.0 BK 0.000 0 2/1/2004 (7902068) 5 6735 _5023 Merla TMPD GLV 1.0 BK 0.188 1296 2!24!2007 6 7119 5280 Merla TMPD DMY 1.0 BK 0.000 0 2/1/2004 - __ 7 74%4 5522 Merla TMPD OV 1.0 BK 0.250 0 2/24/2007 _ _ 8 7795 5749 Merla TPDX DMY 1.5 RM 0.000 0 7/17/1985 Production MandrelsNalves_ St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 9 7888 5817 - Merla - TPDX DMY 0.0 RM 0.000 0 12/24/2006 10 79G1 5871 Merla TPDX DMY 0.0 - RM 0.000 0 12/16/2006 _ 11 8131 5996 _M_er_la TPDX DMY 0.0 RM 0.000 0 12/26/1992 Other lu s e ui .etc. -COMPLETION _Depth TVU Type Description ID 1820 1722 SSSV BAKER FVL LOCKED OUT 6!5!1990 WAIVERED 2/16/1997 2.810 7836 5779 PBR BAKER PBR 3.000 7849 5789 PACKER BAKER'FHL'PACKER 3.000 _ 7881 5812 Deploy Sleeve BTT DEPLOYMENT SLEEVE set 1/21/2007 2.250 TUBING (0-8175, OD:3.500, ID:2.992) 8097 5972 Blast Ring BOT BLAST STEEL COLLAR "HAS LEAK"_ 2.992 8151 6010 PACKER ,BAKER'FB-1' PACKER 3.000 8159 6015.._ Whipstock BTT MECHANICAL WHIPSTOCK set 1/21/2007 2.992 ---- Other lu s e ui .~ etc. - SIDETRACK'A' LINER DETAIL -- ;. Depth_ TVD Type Descryion ID - -- -- 8185 6030 De to Sub 13A LINER TOP SECTION BTT ALUMINUM DEPLOYMENT SUB 1.000 8631 6096 SHOE 13A LINER UNIQUE INDEXING GUIDE SHOE w/CEMENTRALIZER 0.500 8632 6096 De to Sub 13A LINER BOTTOM SECTION BTT STEEL DEPLOYMENT SLEEVE 1.910 9106 6097 O-RING SUB 13A LINER BTT O-RING SUB 1.000 HOLE 914_1 6095 SHOE 13A LINER UNIQUE INDEXING GUIDE SHOE w/CEMENTRALIZER 0.500 PUNCHES General NOteS - ~+~ - _-- ---- ~~ ~- (8182-8192) Date Note 2/8/2007 _ NOTE: MULTILATERAL SIDETRACK 2Z-13A 8 2Z-13AL1 _ 2/8/2007 NOTE: GLMs #9 8 #11 blocked by solid pipe portion of Sidetrack Lateral AL1 - 3/18/2008 NOTE: CUT 8 PULLED TOP 41' OF 2Z-13AL1 LINER SHOE (8631-8632, OD:2.600) 2Z-13A (PTD 206-170) Report O~spected TxIA Communication ~ Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com) Sent: Saturday, September 13, 2008 9:58 AM To: Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Regg, James B (DOA) Subject: 2Z-13A (PTD 206-170) Report Of Suspected TxIA Communication Attachments: 2Z-13A Wellbore Schematic.pdf; 2Z-13A TIO Plot.ppt Tom, Kuparuk gas lifted producer 2Z-13A (PTD 206-170) was identified to have possible TxIA communication while normalizing the well after a tree replacement and has been added to the Weekly SCP report. a T/I/O pressures before and after the work were 400/450/760 and 300/300/760 respectively. A leaking GLV is suspected so slickline will continue to troubleshoot the leak and repair if possible. The well is currently shut in and will be repaired or shut in by 10/06/08. Attached is a 90 day TIO plot and schematic. «2Z-13A Wellbore Schematic.pdf» «2Z-13A TIO Plot.ppt» Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 12/10/2009 IAP 1500 looo a 500 0 OAP ...................~................~~~...........~ vP ....................~.................................................... T11/0 Plot - 2Z-13 200 150 a E 100 Y O t V 50 01-Jul-08 01-Aug-08 Date 01-Sep-08 0 ~~ ,' Ccrr"IdcaP~iltips ,~laska~, ~r~~, ' 2z-isA ti ~ '=- ~~~ ~~ ~~~ F: _ ~,`~ ~5 ~~ c ~~:1.;~ ~~ r.,~~.,., c+~L,., _ rnnennnr.l c-rRlnlr_c • KRU 2Z-13A Descri tion Size To Bottom TVD Wt Grade Thread PRODUCTION 7.000 0 8507 6091 26.00 J-55 BTC SURFACE 9.625 0 4203 3360 36.00 J-55 BTC CONDUCTOR 16.000 0 80 80 62.50 H-40 WELDED Lateral AL1 Slotted Liner To 2.375 7920 8068 5950 4.40 L-80 STL Lateral AL1 Solid Liner To 2.375 8068 8183 6029 4.40 L-80 STL WINDOW #1 3.300 8183 8184 6030 0.00 WINDOW #2 7.500 8183 8184 6030 0.00 __ _ _ Casing String - SIDET_R_ACK ____ _ ____ _ - Descri tion Size To Bottom TVD Wt Grade Thread Sidetrack A To Slotted Liner 2.375 8183 8634 6097 4.40 L-80 STL Gidetrack Bottom A Slotted Liner 2.375 8630 9142 6095 4.40 L-80 STL c' Tubin S ~F I etring -..TUBING r _ 9 _. Siz ~ s Op 8175 6025 t i Grade _ Thread ~~ ,~ PerfOrat l To I Bottom TVD W J 55 _ _ 8rdEUE ~ - _ --- - - I ~~ ions Summary ~~. - ~,,,; 'i Interval ~ TVD 1 Zone ~ Status ~ Ft SPF ~ Date ~ Tvpe GT Commen _ _ Treatments _ Stimu atlons --- - Ga_sl Lift Mand Date f- - Type - ~ __ - commeni _ W ~~~ ~ 8182- 8192 4/6/2007 HOLE PUNCHES LINER HOLE PUNCHE_ S 6 SPFw/PJ160(i St MD TVD elMan Mfre Man Type V Mfr V Type V OD~ Latch I Port I TRO I Date Run ~ Vlv ~ ~ ..,- ~ ~ I 1 2011 1865 Merla TMPD GLV 1.0 _ ' 2 4132 3311 Merla TMPD GLV 1.0 3 5702 4324 Merla TMPD GLV 1.0 4 6360 4768 Merla TMPD DMY 1.0 I (7902-8068) . ~ ~" 5 6735 5023 Merla TMPD GLV 1.0 J ~ ~~ 6 7119 5280 Merla TMPD DMY 1.0 a ~" 1 7 7474 5522 Mer1a TMPD OV 1.0 T ~ 8 7795 5749 Merla TPDX J _ __ __ DMY _ _ 1.5 _ Pro ductio n Mandrels/Valves - - St - M[) TVD Man Mfr Man Type V Mfr V Type V OD 9 7888 5817 Merla TPDX DMY 0.0 10 7961 5871 Merla TPDX DMY 0.0 ' 11 8131, 5996 Merla Other (plus, equip etc De th TVD T e TPDX _ __DMY_,_ __0.0 h-_COMPLETION _ Descri tia 1820 1722 SSSV BAKER FVL LOCKED OUT 6/5/1990 WAIVES _ 7836 5779 PBR BAKER PBR ~ Y.~ 7849 5789 PACKER BAKER'FHL'PACKER 7881 5812 Deploy BTT DEPLOYMENT SLEEVE set 1/21!2007 Sleeve - 8097 5972 Blast Rin BOT BLAST STEEL COLLAR *'HAS LEAK" TUBING - 8151 6010 PACKER BAKER'FB-1' PACKER (0-8175, OD:3.500, ID:z.ssz) P-~ G 8159 Rn15 Whipstock BTT MECHANICAL WHIPSTOCK set 1/21/200. - -- - Other (plu s egui etc. - SIDETRACK'A' LINER DETAIL De th TVD T e Descri tic 8185 6030 De to Sub 13A LINER TOP SECTION BTT ALUMINUM DE 8631 6096 SHOE 13A LINER UNIQUE INDEXING GUIDE SHOE ~~ 8632 6096 De to Sub 13A LINER BOTTOM SECTION BTT STEEL DI , 9106 6097 O-RING SUB 13A LINER BTT O-RING SUB ~ a 9141 6095 SHOE 13A LINER UNIQUE INDEXING GUIDE SHOE. HOLE PUNCHES i ._ ____ Gerlera) NOteS (alaz-8192) I Date ( . _ Note __ - 3/18/2008 NOTE: CUT & PULLED TOP 41' r Port TRO Date 0.000 0 12124 D_DOO o tuts SHOE (6631-8632, OD:2.600) Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, April 07, 2008 9:02 AM To: 'Peirce, John W Subject: RE: 2Z-13A (206-170) and 2Z-13AL1 (206-171)-PTD numbers John, Thanks for the reply. I don't wish to increase your load, but it is probably best to send in a 404 for 2Z-13AL1. Any additional work would only need to be reported for 2Z-13A. Call or message with any questions. Tom Maunder, PE AOGCC From: Peirce, John W [mailto:John.W,Peirce@conocophillips.com] Sent: Monday, April 07, 2008 8:50 AM To: Maunder, Thomas E (DOA) Subject: RE: 2Z-13A (206-170) and 2z-13AL1 (206-171}--PTD numbers Hi Tom, Objective of 2Z-13A liner cut was to cut off a long enough top piece of 2-3/8" slotted liner to regain access to the upper mandrel in the C sand selective. As a result of not getting the liner to bottom during the CTD job, the upper section of liner was left too high up the tubing to allow us access to the mandrels in the C sand selective. We had no way to pull valves to establish C sand flow to the wellbore. With the top liner piece removed, we now have access to the top C sand mandrel, and we're trying to pull the DV from the mandrel. The well does not have enough flow rate as A sand only, and has been continually freezing off. With C sand flow we alleviate that problem and should be able to increase oil production. Slickline attempts to pull the DV have failed so far. We believe the valve is cemented (as a result of Pre-CTD cement job) &/or scaled in the pocket. Next step will be to run a video log, then we'll decide what to try next to remove the valve. We're considering a few possible future work options like acid soak mandrel loose, CT scale blast mandrel, punch holes to set POGLM, cut out more liner sections to get down to next station, etc. I'll be happy to send a 10-404 for the work we've done under well name 2Z-13AL1. Regards, John Peirce Wells Engineer CPAI Drilling & Wells (907)-265-6471 office From: Maunder, Thomas E {DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, Aprit 04, 2008 2:22 PM To: Peirce, John W Subject: RE: 2Z-13A (206-170) and 2Z-13AL1(206-171)--PTD numbers John, Sorry, I messed upon the PTD numbers. Tom From: Maunder, Thomas E (DOA) Sent: Friday, April 04, 2008 2:19 PM To: Peirce, john W 4/9/2008 Page 2 of 2 Subject: 2Z-13A (206-170) and 2Z-13AL1 {206-171) John, I am reviewing the 404 you submitted for -13A regarding cutting and evidently removing the tap part of the 2-3/8" liner. What was the issue there? It appears that the cut portion was u{timately successfully recovered. Have you also filed a 404 for -13AL1? From my read of ~e file, it appears that "technicalry" the cut liner section was run during the -13AL1 operations. Where sections are not accessible, it gets confusing. Send a message back and we can discuss it. Tom Maunder, PE AOGCC 4/9/2008 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR ~ 3 ZOOS REPORT OF SUNDRY WELL OPERATIQ~V~ n;I g ~,~ f nnc t:nmmiSSlbn 1. Operations Pertormed: Abandon ^ Repair Well ^~ Plug Perforations ^ Stimulate ^ Other~~h~~Ly Alter Casing ~ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 206-170 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21360-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 32.6' 2Z-13A 8. Property Designation: 10. Field/Pool(s): ADL 025653 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9300' feet true vertical 6089' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SURFACE 4170' 9-5/8" 4203' 3360' PRODUCTION 8474' 7" 8507' 6091' LINER 512' 2-3/8" 9142' 6095' Perforation depth: Measured depth: 8308'-8629', 8634'-8729', 8822'-9043' true vertical depth: 6076'-6096', 6097'-6105', 6109'-6101' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 8175' MD. Packers &SSSV (type & measured depth) no packer Baker FVL SSSV @ 1820' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Prod uction or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 90 790 35 -- 167 Subsequent to operation SI -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce @ 265-6471 Printed Name John Peirce Title Wells Engineer / r Signature ~f ~ ~ Phone ~ ~ ib Date ( ` C7 I~G. Pre ared b Sharon All u Drake 263-4612 ~ ~~ ~If~AL~ ~~~.a~~~d Form 10-404 Revised 04/2006 ,; `~ Submit Original Only 2Z-13A Well Events Summary DATE SUMMARY 2/14/08 RIH WITH PBMS/GRADIO/PEGS. UNABLE TO ENTER 2 3/8" LINER TOP AT 7881'. RIH WITH 1 11/16" CHG. UNABLE TO ENTER LINER TOP AT 7881'. 2/18/08 TAG TOP OF 2 3/8"LINER WITH 2.25" SWAGE @ 7881' RKB.WORK 1.875" O.D. AND BLB'S INTO LINER AND BRUSH FROM 8105' SLM TO TOP OF LINER.IN PROGRESS 2/19/08 DRIFTED 1.75" OD OAL=211" BAILER INTO 2 3/8" LINER TO 7979' RKB WITHOUT SITTING DOWN.STIFFEN TOOLSTRING FLATTER BTM WILL SIT DOWN.WORKED 1.85" DRIFT THROUGH 7881' RKB TO 8029' RKB TO DRIFT FREELY. 3/7/08 RAN DUMMY RUN WITH GRADIO AND 1.85" SLICKLINE CENTRALIZER. ABLE TO ENTER LINER TOP WITH 1.85" SLICKLINE CENTRALIZER. DIESEL PRESENT AT CUT DEPTH DEPTH IN 2 3/8" LINER. PUMPED 55 BBLS SEAWATER, 20 BBLS DIESEL, AND 1 BBL METHANOL TO PUT SEAWATER AT CUT DEPTH. CUT 2 3/8" LINER AT 7920'. SUSPECT ANCHORS PICKED UP LINER TOP WHEN THEY EXITED AND DROPPED CUT LINER BACK OFF AT GLM #7. 3/18/08 PULLED DEPLOYMENT SLEEVE AND CHEM CUT 2 3/8" LINER OAL=41' 8.5" FROM 7835' SLM.SET 3 1/2" CATCHERSUB ON CUT LINER @ 7920' RKB.ATTEMPT TO PULL STA #9 DV.IN PROGRESS ~. '~ KRU 2Z-13A ~~~~~~a~F~lt~~ Ata~sk~,1~n~. -- -- - --- ..... _ 2Z=i 3A Perf (7902-8068) TUBING (0-8175, OD:3.500, ID:2.992) =':. HOLE PUNCHES (8182-8192) SHOE (8631-8632, OD:2.600) Reference Lo :32.6' RKB Ref Lo Date: Last U date: 12/28/2007 Last Ta TD: 9300 ftK6 Last Tag Date: Max Hnle Angle• 95 deg Cal 9036 - -- _ _ Casing String- COMMON STRINGS Description i Size i 70o i Bottom i TVD I Wt i Grade I Thread Lateral ALt Solid Liner To 2.375 7881 7902 5828 4.40 L-80 STL Lateral AL1 Slotted Liner To 2.375 7902 8068 5950 4.40 L-80 STL Lateral AL7 Solid Liner To 2.375 8068 81.83 6029 4.40 L-80 STL WINDOW #1 3.300 8183 8184 6030 0.00 WINDOW #2 __ 7.500 8183 - 8184 6030 _ 0.00 _ - Casing String -SIDETRACK _ ~escnpUOn Sze Top Bottom TVD Wt Grade Threa Sidetr-~ckATol. 'IottedLiner ~ i5 ~~-;.', rr^4 r,0~)7 440 L-80 d STL bidet cy< I Eot[oni A Slotted Liner l 75 t,',0 514E r 195 4 4(1 L~S~I STL Tubing String -TUBING f S¢e Top Botto m TVD Wt Grade _ Thread 35010 ~ 0 ' _ 3175 ~_ X625 x.30 JSS -=- =YdEUE . Perforations Summary mtervat I vu cone status rt srr uate I comment 7902 - 8068 5828 - 5950 166 32 2/6/2007 SLOTS 22-13AL7 Slotted liner To 8308 - 8629 6075 - 6096 321 32 1/21/2007 SLOTS 2Z-13A Slotted Liner 8634 - 8729 6097 - 6104 95 32 1/21/2007 SLOTS 2Z-13A Slotted Liner 8822 - 9043 6M9 - 6101 5timulaion_s & Treatments Interval Date _ TYPe 8182 - 81924 ~~'2007 HOL_C_PUN_C_HE ~ Gas Lift Mandi'~IsNalves St MD TVD Man Mfr Man T V Mfr ype 221 32 1/2112007 SLOTS 2Z-13A Slotted Liner _ Comment. LINER H_(iL_E PUNCHES 6 SPF w~PJ160G _ ype V OD Latch Port TRU Date Run Vlv V T Cmnt 1 2011 1865 Merla TMPD GLV 1.0 BK 0.188 1304 2/24/2007 2 4132 3311 Meda TMPD GLV 1.0 BK 0.188 1307 .2/24/2007 3 5702 4324 Merla TMPD GLV 1.0 BK 0.188 1303 2/24/2007 4 6360 4768 Merla TMPD DMY 1.0 BK 0.000 0 2/1/2004 5 6735 5023 Merla TMPD GLV 1.0 BK 0.188 1296 2/24/2007 6 7119 5280 Merla TMPD DMY 1.0 BK 0.000 0 2/1/2004 7 7474 5522 Merla TMPD OV 1.0 BK 0.250 0 2/24/2007 R 7795 57d9 Merla TPr1X nMV 15 RM 0.000 0 7/17/1985 Produrtinn Mandrels/Valves - St MD ND Man Mfr Man Type _ - V Mfr V Type - V OD Latch Port TRO Date Run Vlv Cmnt 9 7888 5817 Merla TPDX DMY 0.0 RM 0.000 0 12/24/2006 10 7961 5871 Meda TPDX DMY 0.0 RM 0.000 0 12/16/2006 11 8131 5996 Merla TPDX DMY 0.0 RP.4 n n00 0 12/26/1992 Other (plugs, egalp., etc.} - GOMPt(= I ION ue to I vu I e uescn Ion ru 1820 1722 SSSV BAKER FVL LOCKED OUT 6/5/1990 WAIVERED 2/16/1997 2.810 7836 5779 PBR BAKER PBR 3.000 7849 5789 PACKER BAKER'FHL'PACKER 3.000 7881 5812 Deploy Sleeve BTT DEPLOYMENT SLEEVE set 1/21/2007 2.250 8097 5972 Blast Rin BOT BLAST STEEL COLLAR "HAS LEAK" 2.992 8151 6010 PACKER BAKER'FB-1' PACKER 3.000 8159 Other ( De th 6015 plugs, TVD Whipstock equip., etc_ T e BTT MECHANICAL WHIPSTOCK set 1/21/2007 .} - SIDETRACK'A' LINER DETAIL Descri ion 2_.992 ID 8185 6030 De to Sub 13A LINER TOP SECTION BTT ALUMINUM DEPLOYMENT SUB 1.000 8631 6096 SHOE 13A LINER UNIQUE INDEXING GUIDE SHOE w/CEMENTRALIZER 0.500 8632 6096 De to Sub 13A LINER BOTTOM SECTION BTT STEEL DEPLOYMENT SLEEVE 1.910 9106 6097 O-RING SUB 13A LINER BTT O-RING SUB 1.000 9141 6095 SHOE 13A LINER UNIQUE INDEXING GUIDE SHOE w/CEMENTRALIZER 0.500 91 Ngtes ~NMe r NOTE: LTILATERAL SIDETRACK, 2Z-13A & 2Z-13AL1 r NOTE: GLMs #9 & #11 blocked b solid i e ortion of Sidetrack Lateral AL1 ~' t~c'~_e~ `tie '~'o p ~'~.~ r~~ ~ ~r$ti ~ ~ ot~'ed L.1 n e; f tf,~~ ~ O v1~ ~'t ~ N '"~"~ ~ S S C~ P- w-'°Ir-11 C was Gt3`~s'4 rer+tio~te,~ {'ro w~ .f"~Q, Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 02/12/08 ~~~'~s ~. ~~ ~~~C ` ` Isi ; , ~., ~ as~~; N0.4585 ' °,~,~r Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD • 'l 1J-136 11964574 INJECTION PROFILE fJ 02/02108 1 2A-04 11964576 INJECTION PROFILE _ 02/04/08 1 1A-01 11970631 PRODUCTION PROFILE 02/06/08 1 1Y-17 11994613 GLS 02/09108 1 1A-17 11996600 PRODUCTION PROFILE ! 02!10/08 1 2Z-13A 11996601 SBHP SURVEY (c. - 02/11108 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~~i~D STATE OF ALASKA ~ p~Q~ ~ ~ 2U07 ALASKA OIL AND GAS CONSERVATION COMMISSIOI'~I' WELL COMPLETION OR RECOMPLETION REPq~Ig~~~Cons. Commission Anchorage (Sub Wellbore} 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAAC zs.,os zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ~ ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 2!8/2007 ' 12. Permit to Drill Number 206-170 ' 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 1/17/2007 '~ 13. API Number 50-029-21360-01-00 4a. Location of Well (Governmental Section): Surface: ~ 11 ' FS 4' FE 7. Date T.D. Reached 1/20/2007 ~ 14. Well Name and Number: Kuparuk 2Z-13A ' 31 L, 24 L, SEC. 11, T11 N, R09E, UM Top of Productive Horizon: 3934' FNL, 1288' FEL, SEC. 14, T11 N, R09E, UM 8. KB Elevation (ft): 109' ~ 15. Field /Pool(s): Kuparuk River Unit /Kuparuk Total Depth: 3214' FNL, 933' FEL, SEC. 14, T11N, R09E, UM 9. Plug Back Depth (MD+TVD) 9142 + 6095 Ft River Pool - 4b. Location of Well (State Base Plane Coordinates): Surface: x- 529467 ' y- 5965890 `Zone- ASP4 10. Total Depth (MD+TVD) y 9300 + 6089 Ft 16. Property Designation: ADL 025653 TPI: x- 528447 y_ 5960821 Zone- ASP4 Total Depth: x- 528798 _ y- 5961542 Zone- ASP4 11. Depth where SSSV set 1820' MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1539' (Approx.) 21. Logs Run: TpP k~~i~,fnJ $/S~ ~~D~ 6D/O' ?'VG MWD DIR, GR, RES •;, ~ ~ - - © ,~Sa 3~7~~ 22. CASING, LINER AND CEMENTING RECORD CASING °SETTING DEPTH MD SETTING DEPTW TVD HOLE AMOUNT SIZE WT. PER FT. .GRADE TOP BOTTOM' TOR BOTTOM SIZE CEMENTING RECORD PULLED 2-3/8" 4.4# L-80 8183' 9142' 6029' 6095' 3" Uncemented Slotted Liner 23. Perforations open to Production (MD + TVD of Top and 24. TUB{NG RecoazD Bottom Interval, Size and Number; If none, state "none"): SIZE DEPTH SET MD PACKER SET MD 2-3/8" Slotted Section See 2Z-13AL1 MD TVD MD TVD 8308' - 8629' 6076' - 6096' Well Branch Well Branch 8634' - 8729' 6097 - 6105' 2Z-13A 2Z-13A 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8822' - 9043' 6109' - 6101' Departs From IS nOt DtreCtly DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Well Branch Accessible 2Z-13AL1 8151' Kick Off From Aluminum Billet , PTD # 206-171 at 8182' MD 6029' TVD ( ) 26. PRODUCTION TEST Date First Production: Reported on 2Z-13AL1 Method of Operation (Flowing, Gas Lift, etc.): See 2Z-13AL1 10-407 (Dated 03/05/07, PTD 206-171) for Production & Test Data Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO FIOW TUbing PreSS. CaSing PreSSUre CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). . _~„ Submit core chips; if none, state "none". ~ .t:7ip None ~ t~4Ar~ I) 1DU% 3 .,~,- ~. ~~ lEI3 Form 10-407 Revised 12/2003 AC NTINUED ON REVERSE SIDE ~ Z~~-~~ ~ 3` 7 ~ 07 o~f~~~ ~~ ~3/r/~ 28 GEOLOGIC MARKER 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD ND and attach detailed supporting data as necessary. If no tests were conducted, state "None". Base Kuparuk 62 /Top 61 8182' 6029' None Base Kuparuk A5 / Tpp A4 - 8295' 6072' ~~. 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~ Signed Terrie Hubble ~ Title Technical Assistant Date /~S Q Kuparuk 2Z-13A 206-170 Prepared ey Name/Number. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Aras Worthington, 564-4102 Permit No. / A royal No. INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP Operations Summary Report Page 1 of 28 ~ Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/10/2007 00:00 - 00:15 0.25 MOB P PRE Safety mtg re: move off well 00:15 - 03:00 2.75 MOB P PRE Move off of 1 C-01 after removing ESD from 1 C-17 and rewarming rig hydraulics. Move to center of Pad. PU handiberm, plywood and cellar dikes. Post Pad inspection w/ DSO. Safety mtg re: move rig to 2Z-13 03:00 - 05:20 2.33 MOB P PRE Move rig down the Pad and onto 1C access road. Move to the west end of the KOC pad by 0520 hrs. Set rig down for Kuparuk AM crew change 05:20 - 07:00 1.67 MOB P PRE Wait for Nordic crews and Kuparuk Field personnel to change out. PJSM on crew change. 07:00 - 10:30 3.50 MOB P PRE Moved rig from Kupuark KOC to DS2Z-13 10:30 - 11:45 1.25 MOB P PRE Held PJSM and RU the handi berb and rig mats around the well. 11:45 - 17:00 5.25 MOB P PRE Made ready to move rig ove well and found hydraulic leak on the drive system Spill approximately 10 gal of hydraulic fluid into their containment barrier around the drive motor. Clean up mess and refill w/ hydraulic fluid. Move rig over 2Z-13 tree and set down 17:00 - 23:00 6.00 BOPSU P WEXIT Accept rig for operation at 1700 hrs 1 /10/2007 NU BOPE Move office camp, TL camp and rig camp from 1 C Pad Offload KWF and one load of fresh mud in uprights Kup telecom personnel AOL @ 2100 hrs w/dish on trailer along w/ a generator. Before final hookup of Kup comms, decide to try current BP system. Hans from MPU tuned us in to the Z Pad tower and got comms and data! W III need to raise antenna for other half of lines tomorrow. This setup should also work on 2D Pad for the next well 23:00 - 00:00 1.00 BOPSU P WEXIT Fill stack w/ water. Begin BOPE test 1/11/2007 00:00 - 07:00 7.00 BOPSU P WEXIT Initial BOPE test. AOGCC waived the right to witness 07:00 - 12:00 5.00 BOPSU P WEXIT Working to unthaw the choke and kill line. Finished RUWorking on SLB's traction motor. RU Vetco Gray to pull BPV with lubricator. Found ice in the SV area 12:00 - 16:15 4.25 BOPSU P WEXIT Worked on removing ice from tree and pulling FMC BPV with Vetco Gray. Unable to pull BPV using Vetco Gray, released them and FMC tec is in route to rig Electrican working on SCR3 16:15 - 17:30 1.25 BOPSU P WEXIT Working at removing BPV with FMC Unable to get latch on BPV. Trash on top of the BPV. Lost pluck /SCR Silicon Controlled Rectifiers in # 3. Will have to call IPS in Texas to find replacement part. 17:30 - 18:30 1.00 BOPSU P WEXIT RU to jet the trash off BPV. Loading CT with SW, then jet trash off BPV. Recovered a few pieces of rubber over shaker. Set back injector 18:30 - 19:45 1.25 BOPSU P WEXIT RU FMC lubricator and pull BPV first try. No pressure noted on well. LD load out lub and tools 19:45 - 20:00 0.25 BOPSU P WEXIT Safety mtg re: slack management 20:00 -00:00 4.00 CLEAN P WEXIT PT inner reel valve ~ 4000 psi. Blow CT back w/ air. Cut off CTC. Change packoff. Dress stub/wire to reverse. Reverse slack into reel. Blow CT back w/ air. Cut off 250' of CT and 223' wire. Install CTC. PT 35k, 4000 psi. Head up BHI 1/12/2007 00:00 - 01:00 1.00 CLEAN P WEXIT Fin slack management and head up BHI. Resume circ CT over bung hole Pnntetl: "Ln 7sLtx1/ 1U:74:1D AM BP Operations Summary Report Page 2 of 28 Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours ~ Task Code NPT Phase 1/12/2007 01:00 - 01:15 0.50 CLEAN P WEXIT 01:15 - 01:45 01:45 - 03:00 ( 1.251 CLEAN P IWEXIT 03:00 - 04:30 I 1.50, CLEAN I P I IWEXIT 04:30 - 06:00 I 1.50 I CLEAN I P I IWEXIT 06:00 - 12:30 I 6.501 CLEAN (P ( IWEXIT 12:30 - 12:40 0.17 CLEAN P WEXIT 12:40-14:00 1.33 CLEAN P WEXIT 14:00 - 15:00 I 1.001 CLEAN I P I IWEXIT 15:00 - 17:00 ( 2.OO) STWHIPI P I IWEXIT 17:00-20:00 I 3.OOISTWHIPIP I IWEXIT 20:00 - 22:00 I 2.00 I STW H{PI P I IWEXIT 22:00-23:00 I 1.OOISTWHIPIP I IWEXIT 23:00-00:00 1.00 STWHIP P WEXIT 1/13/2007 00:00 - 03:00 3.00 STWHIP N DPRB WEXIT 03:00 - 03:30 I 0.501 STWHIPI N 03:30 - 04:15 0.75 STWHIP N 04:15 - 06:35 2.33 STWHIP N DPRB IWEXIT DPRB WEXIT DPRB WEXIT Description of Operations Safety mtg re: MU BHA Open up to well and find no pressure. MU milling BHA (2.74" D331 w/ MWD assy) Unable to get BHA below 22'. Looks like SSV won't stroke fully open. Steam the tree and cycle SSV. Install fusible cap. GPB Level 1 w/ -60CF. Set BHA in wellbore. Stab on w/ tubs. Check spacing for pressure undeployment at 2.6' RIH w/ BHA #1 circ thru mill 0.55/300 while take diesel returns to tiger tank Tag at 8000' CTD. PUH 26.6k. Start motor 1.4/1950 and stall two times before getting a pattern established. Drill hard cement from 7998.9' at <20'/hr. Swap returns to pits after disposing of 110 bbls of returns. Drill @ 1.4/ 1980 w/ 3-400 psi dill, 1.2k wob w/ 9.9 ECD Drilling Cement HArd at 8130 ft, PM #11 Bad Discriminator Pump 10 bbl biozan pills OA/IA at 700 / 551 psi. RU to blow down to TT. TD mill at 8183 ft MD. Reaming out cement area. Stopped at 8,050 ft and PT the casing to 900 psi and pressure curve was straight lined POOH chasing cement to surface. .Temp = -25f Winds at 35mph and Phase II on roads and Pads in CPF2 Asset area OOH, flow check, OK, unstab lubricator and stand back in bung hole LD tool and make ready BHI tool if required to assist in setting the whipstock. Refurbishing MP# 1 RU SLB Eline to run tie-in log. Install 7" Otis X 5-1/2" cross-over forpackoff. RIH with GR/CCL logging tool to 8173' ELMD. Log up hole to 7700'. POOH RU WFT 3-1/2 LSX WS w/ BTT #10 Hyd Setting tool on SWS tool string SWS RIH w/ WS to set down at 45'. POOH w/ tool and had ice on bottom. Rig RIH w/ two jts 1"CSH. Steam wellbore. POOH LD CSH. RIH w/ WS as before and set down at same spot. Found that centralizer at top of tool string was not collapsing because operator was not running in hole fast enough. RIH w/ WS Phz 1/2 -13F, 20-35 mph W, -37CF Continue RIH w/ WFT WS on eline. Hung up at 7884' WLM and couldn't go either direction. Pull 70% of weak point at 1650# after 30 min and came free. POOH w/ WS. LD WS assy complete in pipeshed. SWS a-line personnel out of hours. Wellbore needs cleanout run Steam frozen kill line then blow down while wo string reamer from WFT MU cleanout BHA RIH w/ BHA #2 (2.80" tapered mill + 2.81" string reamer + straight motor) circ thru mill 0.5/370 Saw some wt at 7888 ft while RIH at 0.4 bpm. PU and Washed through at 1.65 bpm. While circulating, lost out returns and out density on micro motion. LEL monitors didn't go off. Circulate well bore and wash to bottom. After 10 minutes, MMin = MMout and same with density Printed: 2/12/2007 10:14:1 S AM BP Operations Summary Report Page 3 of 28 ~ Legal Well Common W Event Name Contractor Rig Name: Date ~ Name: 2 ell Name: 2 : R Name: N N From - To ~ Z-13 Z-13 EENTE ORDIC ORDIC Hours ~ R+COM CALIST 2 Task PLET A Code E NPT Start Rig R Rig N Phase Spud Date: 1/3/2007 : 1/10/2007 End: 2/8/2007 elease: 2/8/2007 umber: Description of Operations 1/13/2007 04:15 - 06:35 2.33 STWHIP N DPRB WEXIT PVT = 149 bbl 06:35 - 11:05 4.50 STWHIP N DPRB WEXIT W/R to bottom at 1.67 bpm still seeing the erratic out flowrate while RIH. Saw some motor work at: Mandel # 9 at 7,888 ft Mandel #10 at 7,961 ft, Leaky blast ring area at 7,999 ft. Stalled twice while cleaning out and final) washed through with some motor work. PU at 8,001ft, clean to 7,993 ft. RIH. Stall at 8,002 ft, Stall at 8,004 ft. Stall at 8,086 ft. Stall at 8,130 ft, 8,131 ft; 8132 ft; 8,135 ft; 8136 ft Prod Mandel #11 (Bent Discriminator). Could be pushing something a head of us. SD pump and RIH, tagged at 8148 ft, PUH and wash down. Stall at 8,155.5 ft (Perf 3-1/2" Pup Jts) Stalled 8161 ft; 8163 ft, 8164 ft 11:05 - 11:16 0.18 STWHIP N DPRB WEXIT Reamed and backed reamed, clean 11:16 - 12:45 1.48 STWHIP N DPRB WEXIT POOH chasing biozan out of hole Held PJSM while POOH to change mills. 12:45 - 13:45 1.00 STWHIP N DPRB WEXIT RIH 1.7 ft to simulate pressure deploying BHA. Close 2-3/8" combi's and set at 3000 psi, Strip off well and check BHA (2.6 ft slack off for pressure deploying BHA. Changed out mills to 2.74" 13:45 - 15:10 1.42 STWHIP N DPRB WEXIT RIH with 2.74" mills 15:10 - 15:25 0.25 STWHIP N DPRB WEXIT Washed from 8164 ft at 1.64 / 1.64 bpm and a CTP = 2165 psi. Tagged 8172 ft with 300 psi motor work and then fell off. . W/R from 8172 ft (lip) to 8184 ft, Back reamed 3 times clean, and left biozan in this section 15:25 - 16:47 1.37 STWHIP N DPRB WEXIT POOH 16:47-17:10 0.38 STWHIP N DPRB WEXIT LD BHA 17:10 - 17:30 0.33 STWHIP N DPRB WEXIT PJSM on RU SLB and WFT Whipstock 17:30 - 18:30 1.00 STWHIP N DPRB WEXIT RU SLB 18:30 - 21:30 3.00 STWHIP N DPRB WEXIT RIH w/ WS on a-line. Take +/-15 min each to get by last 3 GLM's and MO Ext. Get bottom of WS to 8152', but need it to be at 8156' otherwise we will mill part of MO Ext and XO below it. Can't determine if tool is setting down at D nipple, or more likely centralizer is hanging up at btm GLM 21:30 - 23:00 1.50 STWHIP N DPRB WEXIT POH to reconfigure tool string 23:00 - 23:45 0.75 STWHIP N DPRB WEXIT Inspect tool string-no marks. Had cement at bottom of the WS. Add 6' of 1-11/16" stem below centralizer and above orientor 23:45 - 00:00 0.25 STWHIP N DPRB WEXIT RIH w/ WS on a-line 1/14/2007 00:00 - 01:30 1.50 STWHIP N DPRB WEXIT Continue RIH w/ WS on a-line. Work by same mandrels. Get bottom of WS to same depth as before, 8153'-need 3' more 01:30 - 03:15 1.75 STWHIP N DPRB WEXIT POH. LD toolstring in pipeshed. More cement on the bottom of tools. RD SWS sheaves and send personnel in for rest 03:15 - 03:50 0.58 STWHIP N DPRB WEXIT MU BHA (2.74" tapered mill w/ 2.74" string reamer) 03:50 - 05:30 1.67 STWHIP N DPRB WEXIT RIH w/ BHA #4 circ thru mill 0.44/290 clean to tag at 8184' CTD 05:30 - 06:40 1.17 STWHIP N DPRB WEXIT PUH 30.8k, start pump 1.47bpm 2030 psi . Ream and backream from 8,000' to TD Circulated up gas from bottomhole. Pump bio sweep 06:40 - 08:00 1.33 STWHIP N DPRB WEXIT POOH to rerun WFT WS 08:00 - 08:45 0.75 STWHIP N DPRB WEXIT LD Mill / FCO BHA 08:45 - 08:55 0.17 STWHIP N DPRB WEXIT Held PJSM with Crews and discussed the hazzards associated with RU Eline on Nordic 2 08:55 - 09:30 0.58 STWHIP N DPRB WEXIT RU Eline, High sided WS to setting tool I, Printed: 2/12/2007 10:14:15 AM BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ~ From - To 1/14/2007 09:30 - 13:00 13:00 - 15:45 15:45 - 16:15 16:15 - 18:30 18:30 - 00:00 1/15/2007 00:00 - 02:40 02:40 - 04:15 04:15 - 05:45 05:45 - 08:05 08:05 - 09:10 09:10 - 10:40 2Z-13 2Z-13 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Hours I Task Code 10:40 - 12:00 12:00 - 14:30 14:30 - 15:55 15:55 - 16:40 16:40 - 16:51 16:51 - 18:20 18:20 - 19:25 3.50 STWHIP N 2.75 STWHIP N 0.50 STWHIP N 2.25 STWHIP N 5.50 STWHIP N 2.67 STWHIP N 1.58 STWHIP N 1.50 STWHIP N 2.33 STWHIP N 1.08 STWHIP N 1.50 STWHIP N 1.33 STWHIP N 2.50 STWHIP N 1.42 STWHIP P 0.75 STWHIP P 0.18 STWHIP P 1.48 STWHIP P 1.08 STWHIP P Start: 1 /10/2007 Rig Release: 2/8/2007 Rig Number: NPT ~ Phase --- - DPRBWEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Page 4 of 28 Spud Date: 1 /3/2007 End: 2/8/2007 Description of Operations RIH with SLB's WRP tool and WFT Whipstock Logged and tie in. Made corrections. RIH and set down at 8155 ft which is the D Nipple. PUH and tie iin again and tagged at the same place, 8155'. This puts the top of the WS 2 ft into the Mill out Extension below the packer. Tried several things including turning TF around and still was unable to get below the D Nipple. Call HTC fora 2.8" DSM. POOH with WS Stand back loggers Make ready to PU 2.80" mills. MU 2.8" Parabolic Mill and 2.81" string mill RIH with 2.8" mill BHA Tagged at 8,167 ft. PUH Milling up D Nipple slowly Starting at 8,165.66 ft Op = 1.60 / 1.59 bpm at CTP 2,273 psi Stall at 8,165 ft Taking some time to get started 8165.05 ft Continue milling D nipple 1.68/2460. Unabfe to drill w/dill, wob or time w/o stalling. Drill using 0.01'/10 min. Were at 8165.10' at 1830 hrs, but had numerous early stalls and lost ground to 8164.81'. By midnite were at 8164.90' and actually getting 500# drilloffs in 10 min Continue milling D nipple from 8164.9' making slow hole to 8164.95'. Start pushing too hard and had several stalls. Remill from 8164.31' to 8165.0' 1.5/2000. Had more stalls, total is 30. Assuming the cutrite SR may be too aggressive and is causing the stalls. Time to change motor anyway POOH circ thru mill 1.53/1900 to check mill/motor OOH. Inspect 2.80" D331 and it appears to have cut the nipple and still drifts 2.80". SR shows virtually no wear, except for in a couple spots on the largest OD. HCC does not have another 2.80" D331 (or close). Remove SR, add fresh motor and rerun the 2.80" D331 Adjust gooseneck RIH w/ BHA #6 Started milling at 8.165.40 ft, working down at 0.05 ft and numerous stalls. Loggin Tie-in down from 7980 ft to 8,110 ft. Corrected -10 ft as per the SLB Jewelry Log ran 1/12/2007 Tagged at 8,156ft. TOWS is thertically at 8,147.3 ft, which is the top of the 8 ft 3-112" pup joint. POOH Held PJSM while POOH OOH, check for flow, (OK) LD milling BHA and RD SLB Eline. Woody sighting. loading BOT WS into the pipe shed. Install RA tag in WS at 5.3ft from the top. With EDC open, set counters and RIH with BOT's RWS WS Tied in from 8,000 ft to 8,055 ft and cporrected -10 ft. Confirmed correction WT check at 8,054 ft = 31.5k at 20 fpm f WS at 8157 ft TOWS at 8148 ft Working to pressure set WS, Cycled pumps 5 times an finally the WS set at 4600 psi 2LHS Toolface. TOWS at 8,148.3 ft and RA Marker at 8,153.60 ft POOH LD BTT WS setting tool and BHI MWD tool. MU WFT milling assy on BHI MWD assy Printed: 2/12/2007 10:14:15 AM BP Operations Summary Report Page 5 of 28 ~ Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/15/2007 19:25 - 20:50 1.42 STWHIP P WEXIT RIH w/ BHA #8 (2.74" WM and SR on WFT motor) circ thru mill 0.59/570 20:50 - 21:50 1.00 STWHIP P WEXIT Log tie-in down from 8000', corr -10' Repeat tie-in and got -2' corr 21:50 - 22:45 0.92 STWHIP P WEXIT RIH and lost wt at 8149.1'. PUH 28.9k, start motor 1.6/2700. Park 1' above WS for 10 min 1.6!2700. Ease in hole and first MW ~ 8148.3' which was the tied in setting depth of the TOWS. Flag CT and motor stalled. PUH w/ 4k overpull, then clean. Continue PUH and started getting pressure cycles thru motor and acting like motor is stalled (1.5/3800). More like motor is chunking out ... ? PUH and pressure slowly dropped by 8040' to new press/rate of 1.54/2930 and assume must have been trash. RBIH 22:45 - 23:15 0.50 STWHIP P WEXIT Pressure returned to normal at 1.55/2755 while ease back in hole to stall at 8148.0'. PUH w/ 5k overpull. Ease back in hole to first MW and w/ flag at 8148.0' 23:15 - 00:00 0.75 STWHIP P WEXIT Mill window from 8148.0' according to WFT rep. At 8149.0' at midnite - 1/16/2007 00:00 - 04:15 4.25 STWHIP P WEXIT Continue milling from 8149.0' to 8153.0' 1.55/2400 while pumping 10 bbl biozan pills each hour. Good metal on magnets, milled like textbook. From 8152.0'+ appear to be on 7" 04:15 - 05:15 1.00 STWHIP P WEXIT Pump 10 bbl pill, then ream and backream window area prior to POOH 05:15 - 06:39 1.40 STWHIP P WEXIT POOH for window milling assy #2 (for 2 strings) , Held PJSM on BHA handling 06:39 - 07:55 1.27 STWHIP P WEXIT LD straight motor BHA Gauged at 2.74" (tight). Found stator rubber in jets 07:55 - 09:20 1.42 STWHIP P WEXIT RIH with #2 window ext BHA (2.5 deg motor) 09:20 - 09:45 0.42 STWHIP P WEXIT Logged tie-in and corrected - 10 09:45 - 09:55 0.17 STWHIP P WEXIT Close EDC and RIH and orient TF 15 R HS 09:55 - 12:30 2.58 STWHIP P WEXIT Milling window as per WFT. Yellow flag at back of counter Started 8153.60 ft to 8155.12 ft Op = 1.69 / 1.69 bpm at 3000 psi on btm PVT = 140 bbl's 12:30 - 15:00 2.50 STWHIP P WEXIT Milling window at 8155.12 ft to 8157' Started 8153.60 ft to 8155.12 ft Op = 1.69 / 1.68 bpm at 3050 psi on btm 15:00 - 17:30 2.50 STWHIP P WEXIT Drill open hole in B shale from est BOW at 8157.0' _ 1.7/2760/tOL slowly w/ 400 psi dill, 5-7k wob. Swap to used Flo Pro mud. Ream 7" exit area. 17:30 - 18:30 1.00 STWHIP P WEXIT Ream window area some more. Dry run thru window was clean 18:30 - 20:15 1.75 STWHIP P WEXIT Open EDC. POOH circ 1.35/2400 20:15 - 21:00 0.75 STWHIP P WEXIT LD milling BHA. Mill was gauge and had little wear 21:00 - 00:00 3.00 DRILL P PROD1 Displace CT to FW while over bung hole. Stab on, blow CT back w/ air. Cut off CTC. Fill CT then reverse slack back (twice). Cut off 21' CT. Dress stub 1/17/2007 00:00 - 02:00 2.00 DRILL P PROD1 Install CTC and PT ~ 35k. Head up BHI. PT ~ 4000. 02:00 - 03:30 1.50 DRILL P PROD1 Function test BOP rams as part of bi-weekly ROPE test MU build BHA. Circ CT to mud over bunghole 03:30 - 05:15 1.75 DRILL P PROD1 RIH w/ BHA #10 (2.6 deg motor, used bi bit) circ thru EDC 0.3/800. Set down at 7850' in packer. Orient to get by Punted: Luizuui iuaaaSAnn BP Operations Summary Report Page 6 of 28 ~ Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 'Event Name: REENTER+COMPLETE Start: ~ 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task .Code NPT ~ Phase Description of Operations 1/17/2007 05:15 - 05:35 0.33 DRILL P PROD1 Log tie-in down from 8000', Corr -9' 05:35 - 06:05 0.50 DRILL N PROD1 RIH to set down at bottom of window at 8157' and could not 06:05 - 07:45 1.67 DRILL N PROD1 07:45 - 08:00 0.25 DRILL N PROD1 08:00 - 09:00 1.00 DRILL P PROD1 09:00 - 10:30 1.50 DRILL P PROD1 10:30 - 10:45 0.25 DRILL P PROD1 10:45 - 13:45 3.00 DRILL P PROD1 13:45 - 15:45 I 2.001 DRILL I P I I PROD1 15:45 - 17:10 1.42 DRILL P PROD1 17:10 - 17:45 0.58 DRILL P PROD1 17:45 - 18:30 0.75 DRILL P PROD1 18:30 - 20:00 1.50 DRILL P PROD1 20:00 - 20:20 0.33 DRILL P PROD1 20:20 - 20:35 0.25 DRILL P PROD1 20:35 - 00:00 I 3.421 DRILL I P I I PROD1 11!18/2007 100:00 - 02:50 I 2.831 DRILL I P I I PROD1 02:50 - 03:15 ~ 0.42 ~ DRILL ~ P ~ ~ PROD1 03:15 - 05:30 I 2.251 DRILL I P I I PROD1 05:30 - 10:45 I 5.251 DRILL I P I I PROD1 10:45 - 11:05 I 0.331 DRILL I P I I PROD1 11:05 - 13:00 I 1.921 DRILL I P I I PROD1 13:00 - 13:30 0.50 DRILL P PRODi 13:30 - 14:15 0.75 DRILL P PROD1 14:15 - 14:40 0.42 DRILL P PROD1 14:40 - 16:00 1.33 DRILL P PROD1 16:00 - 16:20 0.33 DRILL P PROD1 16:20 - 17:30 1.17 DRILL P PROD1 17:30 - 18:00 0.50 DRILL P PROD1 18:00 - 20:15 I 2.251 DRILL P I PROD1 work by w/ multiple attempts Open EDC. POOH for crayola mill PJSM - UD build BHA and P/U crayola mill(BHA #11) UD build BHA. Changeout injector packoff. P/U crayola mill. RIH with BHA #11. Tie in around 8000'. Correct -8'. RIH to window depth. Attempt to mill out the bottom of the window. Multiple stalls ~ 8157 with very slow approaches. Progress made using increments of .01' while increasing and decreasing pump rates - 8156.70 - 8158.0. Able to move to bottom of the openhole section 8167'. Backream up thru hole at 2'/hr at various orientations - 45 degrees LOHS, 45 ROHS, 75 ROHS, 75 LOHS, 105 LOHS, 105 RHS. Pass thru dry, max WOB of 500 Ibs going thru. POH to UD BHA #11 and P/U build BHA. PJSM for BHA Changeout prior to reaching surface. LD crayola milling assy. Mill looked okay. MU build BHA RIH w/ BHA #12 (2.6 SR motor, used bi bit) circ thru EDC 0.5/1400 Log tie-in down from 8000', Corr -9' to PDC. Close EDC RIIH 0.25/1000 thru window, clean to tag at 8166'. PUH 26k, start motor PVT 315 Drill from 8166' 1.60/3150/10L-80L w/ 50-250 psi dill, 1-5k wob w/ 11.0 ECD while concentrate on 180 deg LH turn. See RA pip at 8156.0' and tie all depths to it (ie TOWS -5.3'=8150.7'=-8151'). Drill to 8257' w/ two wipers Continue drilling from 8257' 1.6/3300/85L w/ 100-300 psi dill, 1-4k wob w/ 11.2 ECD to 8330' Geowiper was clean both directions PVT 313 Need to build quicker since target is 10' TVD higher due to unexpected faulting PVT 314 Drill from 8330' 1.59/3320/30L and get in a hard spot. ', Hopefully this is the 5' TVD of Ankerite on top of the target ,sand. NBI is 88 deg so have cut -2.5' so far. Drill from 8355' 1.56/3300/105L. Fluctuating between ankerite and sand. Very slow ROP's in the ankerites. Drilling break up to 30' per hour at 8389. Drill to 8400' and pull for lateral assembly. POOH to LD build assembly and PU lateral assembly. PJSM to Changeout tools just prior to reaching surface. LD build assembly(BHA#12). Bit graded 1-2. Insert resistivity tool and initialize. PU lateral assembly(BHA#13). RIH with lateral assembly. tie-in to depth logs. Correct -8'. MAD pass hole with resistivity, downward at 250'/hr Wiper back to window. Trip gas coming up. Circulate trip gas to surface while perform wiper back to TD at drilling rate PVT 334 Drill from 8400' 1.54/1.5/3270/30L-90L w/ 100-300 psi dill, Printed: 2/12/2007 10:14:15 AM BP Operations Summary Report Page 7 of 28 Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations _ _ - - 1/18/2007 18:00 - 20:15 2.25 DRILL P PROD1 1-3.5k wob w/ 11.1 ECD while level out to stay at 5980' TVD. 20:15 - 20:40 0.42 DRILL P PROD1 20:40 - 00:00 3.33 DRILL P PROD1 1/19/2007 100:00 - 02:20 I 2.331 DRILL I P I I PROD1 02:20 - 03:00 I 0.671 DRILL I P I I PROD1 03:00 - 06:00 3.00 DRILL P PROD1 06:00 - 07:05 1.08 DRILL P PROD1 07:05 - 08:30 1.42 DRILL P PROD1 08:30 - 11:10 I 2.671 DRILL I P I I PROD1 11:10 - 12:20 1.17 DRILL P PROD1 12:20 - 14:50 2.50 DRILL P PROD1 14:50 - 15:00 0.17 DRILL N SFAL PROD1 15:00 - 17:10 2.17 DRILL N PROD1 17:10 - 17:45 0.58 DRILL N PROD1 17:45 - 18:30 0.75 DRILL N PROD1 18:30 - 20:10 1.67 DRILL N PROD1 20:10 - 00:00 I 3.831 DRILL I N 1/20/2007 00:00 - 00:15 0.25 DRILL P 00:15 - 03:50 3.58 DRILL P 03:50 - 05:25 I 1.581 DRILL I P Drill to 8520' and are apparently on an ankerite streak w/ geo wanting to go up Wiper to window while geodecide was clean PVT 324 Drill from 8520' 1.54/1.54/3200/160L w/ 100-250 psi dill, 1-3k wob w/ 11.12 ECD and will point TF down to follow the dip and hold 87 deg. Orill to 8624' in and out of hard streaks w/ GR avg of 58 apt in A4 PVT 318 Continue drilling from 8624' 1.63/3250/90L in a hard streak. Break out at 8635' and drill to 8680'. Seem to be bumping up against the ankerite every time TF is pointed above 80L. Consequently, slow progress until TF is pointed down. Drill to 8680' W iper to window was clean. Wiper back to TD had set downs at 8248' and 8550' w/ TF 60 deg off PVT 187 after take off mud prior to mud swap. Mud has turned dark brown due to the tar zone we are drilling Drill from 8680' 1.53/1.45/3100/80L w/ 100-300 psi dill, 1-3k wob w/ 11.09 ECD and appear to have drilled into the A4 shale. Point TF HS @ 0545 hrs at 8800' (5998' TVD). Drill to 8810' W iper to window Drilling ahead. 1.60/1.56/3340lfF340-285. 11.07 ECD on bottom drilling. 1-1.2k wob. Swapped for new FloPro, 450 bbls. Bled off IA from 650psi down to 140psi. Drilled to 8870'. Drilling ahead. 90-91 degrees inc. 1.60/1.56/3340JTF285. 11.07 ECD. 50' wiper trips. -40'/hr ROP. Progress slowed near end. Drifted to 8945'. Wiper trip to window. Drilling ahead. 1.59/1.57/3200lTF300. 10.8 ECD. PVT 319bb1s. Very slow ROP's thru ankerite. Lost power to Inteq computers, and as a result lost data screens at surface. Drilling ahead. 1.60/1.58/3250lTF0285. Very slow drilling through ankerite. Inteq still having problems with UPS(Uniterupted power supply) for computers. Able to drill ahead due to slow ROP's. Drilling ahead. 1.60/1.58/3250/TF0285. Very slow drilling through ankerite. Freespin jumped from 3150psi to 3540psi. Pull to look at motor and bit. Wiper to window. Open EDC at window. POOH circ thru EDC 1.7/3050 while follow pressure schedule to control open shales w/ EMW=11.0 by RP. Safety mtg re: pressure undeploy Tag up w/ 700 psi (11.0 ECD). WHP immediately began slowly bleeding off to formation PVT 277 Close EDC Pressure undeploy by procedure. Final whp was 305 psi and stable for 50 min. Found mousehole frozen so broke down BHA in pieces Safety mtg re: pressure deploy MU BHA and pressure deploy w/ 280 psi whp. Replace hose to lubricator packoff after it was found to leak RIH w/ BHA #14 (1.0 deg) circ thru bit 0.5/1700 following PROD1 PROD1 PROD1 PROD1 Printed: 2/12/2007 10:14:15 AM BP Operations Summary Report ,Legal Well Name: 2Z-13 (Common Well Name: 2Z-13 ,Event Name: REENTER+COMPLETE Start: 1/10/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Page 8 of 28 Spud Date: 1 /3/2007 End: 2/8/2007 Date From - To Hours Task Code NPT Phase Description of Operations 1/20/2007 03:50 - 05:25 1.58 DRILL P PROD1 pressure schedule 05:25 - 05:45 0.33 DRILL P PROD1 Log tie-in down from 8000'. Corr -8'. 05:45 - 06:30 0.75 DRILL P PROD1 RIH thru window, clean. RIH to 8310' and set down. RIH at 06:30 - 10:00 ~ 3.501 DRILL P PROD1 10:00 - 15:00 5.001 DRILL P ~ PROD1 15:00 - 17:00 2.001 DRILL P PROD1 17:00 - 18:45 1.751 DRILL ~ P PROD1 18:45 - 19:30 0.75 DRILL P PROD1 19:30 - 23:00 3.50 DRILL P PROD1 23:00 - 23:30 I 0.501 DRILL I P I I PROD1 23:30 - 00:00 0.50 DRILL P PROD1 1/21/2007 00:00 - 00:20 0.33 DRILL P PROD1 00:20 - 00:45 I 0.421 DRILL I P I I PROD1 00:45 - 01:25 0.67 DRILL P PROD1 01:25 - 03:00 1.58 DRILL N DPRB PROD1 03:00 - 05:00 2.00 DRILL N PROD1 05:00 - 05:30 0.50 DRILL N PROD1 05:30 - 06:00 0.50 DRILL N PROD1 06:00 - 06:45 0.75 DRILL N PROD1 06:45 - 07:10 0.42 DRILL N PROD1 07:10 - 09:00 I 1.831 DRILL I N 09:00 - 10:45 I 1.751 DRILL I N slower speed thru build section, clean. Drilling ahead. 1.62/1.59/3420/TF0300. FS 3300psi. ECD 11.13. ROP's 5-10'/hr. PVT 306bb1s. Drilling ahead 1.62/1.58/3320/60L-120LTno high of TF and can make hole, too low and is slow going. Mostly slow going so we don't blow thru the top of the sand PVT 296 Drill from 9060' and penetration rate has picked up. Drill to 9140' Wiper to window was clean at 25'/min. Wiper in hole was clean to set down at stall at 9040' Ream to bottom w/ numerous stalls 9040-9060' PVT 280 Drill from 9140' 1.63/1.59/3340/90L at 92 deg in the A5 shale ,planning to intersect the next fault at 9300' and enter the A4 'I sand. Steady 40'/hr progress. See resistivity change +X8 at 9235', but no PR change Wiper to window. Overpull and MW at 9070'. RBIH, then slow backream. Got bit stuck at 9050'. Took several tries to get free. Slow backream to 9020' before pulling clean Continue wiper to window Continue wiper to window. Start pulling tite w/ MW at 8258'. RBIH, clean. Wiper to window at 7'/min from 8260' and was real sticky and packing off until past 8230'. Had full returns past 8230', but still sticky w/ MW. Pull thru window, then POH to 8000' Log tie-in down from. 8000', corr +4' Geo's decide to continue building angle once at TD looking for A4 sand RIH clean thru window. Slow wiper back thru build and set down at 8254' at DTF. Red rate to 0.5 bpm and hold 11.5 ECD w/ choke. Spud at various TF's and cannot get by. This is interface of bottom of B shale and A5 shale w/ A6 faulted out. The 1.0 deg motor will not follow the 2.6 deg hole in incompetent formation Pull thru window, open EDC. POOH circ 1.6/3000 for larger bend motor for cleanout run following pressure schedule for 11.0 ECD Safety mtg re: pressure undeploy Pressure undeploy w/ 470 psi Adjust motor, remove res tool Pressure deploy BHA SD for tour change out. Hold PJSM for pressure depoloying BHA. Step thru proceedure. Discuss hazards. Discuss job assignments. Discuss trainee hand expectations, and minimizing extra hands on the rig floor. Pressure Deploy cleanout BHA. Pick up 1.7 deg motor, rebuilt Hughes Bicenter. Deploy with no incidents. First pressure deployment this year for this crew in Kuparuk. Shallow hole test of BHA #15. No problems. RIH with open EDC, pumping at 0.25 BPM. PVT=223 bbls. Order 150 bbls PROD1 PROD1 Printed: 2/12/2007 10:14:15 AM BP Legal Well Name: 2Z-13 Operations Summary Report Page 9 of 28 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 'Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name; NORDIC 2 Rig Number: i Date From - To Hours Task Code NPT Phase Description of Operations 1/21/2007 09:00 - 10:45 1.75 DRILL N PROD1 additional mud. I,O,T=0,265,650. Following pressure schedule white RIH. 10:45 - 11:05 0.33 DRILL N PROD1 Log tie in pass over GR charecter at 8000'. Make -6' correction. 11:05 - 12:15 1.17 DRILL N PROD1 Shut the EDC, orient to "As drilled" toolface and RIH thru the window. No problems at window. RIH, pumping minimum rate at 0.35 bpm. Holding 560 psi on WHP with choke. Holding "As Drilled" TF in open hole. (90 deg LOHS at 8250') RIH slow, it was slick until tag up at 8255'. PU and tag "dry" several times. No progress. Same depth each time. Clean PU each time. See DHWOB sensor each time. We are definately tagging up with the bit. Tag up and stack weight on it dry several times. 4400 Ibs on DHWOB. No luck. Adjust tool face to 45 deg LOHS. PU, and RIH dry. Tag up several times at the same place. Adjust tool face to 0 deg, high side. RIH dry. Tag up solid. 5600# DHWOB. Repeat set downs several times at high side orientation. DD reports they have been successful previously on this well at 150L. Try it with pumps down. Tag up several times. PU, orient to 45L. RIH dry, tagged up, then fell thru to 8264', then hit with a mushy bottom. 12:15 - 12:30 0.25 DRILL N PROD1 Bring pumps up to 1.5 bpm, try to work down hole. Weight fell off quickly. It appears that we had a ledge at 8255', then some junk in the hole below that. Wash down, chasing something as seen on DHWOB sensor. Tag at 8277'. PU sticky. Continue trying to wash thru junk. Packing off. 1.5/0.6 bpm. Continue washing down thru junk. Trying not to pickup above ledge at 8255'. Finally made it down thru the junk. Clean down to 8323', then set down again. Retums errattic, but mostly 1.50/1.0. 12:30 - 13:00 0.50 DRILL N PROD1 Start mixing high vis sweep. Make mini wiper up to chase the debris OOH. Returns errattic on mini wiper. Pull up to 8265', at 8 fpm, staying below ledge. Weight on wiper draggy, but never over 30 klbs. Normal up weight 25 klbs. Able to work up hole, but still packing off, and can't run back down. Decide to continue wiper up past ledge at 8255', chasing debris up to window. Cleaned up as we got the last 50' below the window. Geo reports bottoms up sample is light brown in color and is either from the 61, or A5 shales. There is no sand present in the sample. 13:00 - 13:50 0.83 DRILL N PROD1 RBIH, TF 45 LOHS. Pumps at 1.56/1.60. Clean down from the window at 6400 Ibs string wt, 5401bs DHWOB. Tag up at 8255', drop pumps to 0 immediately. PU and RIH dry. Tag up hard at 8255'. Repeat 6 times with no success. Clean PU's and solid set downs. PU, bring pumps to 0.35 bpm. RIH, TF=45L, tag up at 8255'. Roll pumps up momentarily. No luck. Orient to 145L, RIH, tag up 2 times, Orient to 45L and RIH. Tag up at 8255'. Repeat, made it thru finally. (Whew!). Kick pumps on to 1.3 bpm, TF as drilled, RIH. 13:50 - 14:40 0.83 DRILL N PROD1 RIH, Pumping high vis sweep. Seeing ratty weight, looks like debris still. Returns 100%. Run down to end of build at 8400'. Holding "As drilled" tool face. Pump 20 bbls of high vis sweep to clean up debris in build section of hole. Chase it up to 8265'. Nrmtea: zn rJZUUi iuaa: a rwi g p Page 10 of 28 Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: i Date ~ From - To Hours Task Code ( NPT Phase Description of Operations _- 1/21/2007 13:50 - 14:40 1 0.83 DRILL N 14:40 - 15:15 I 0.58 DRILL N 15:15 - 15:35 15:35 - 16:00 16:00 - 18:00 18:00 - 20:20 20:20 - 21:40 0.33 ~ DRILL ~ N 0.421 DRILL I N 2.001 DRILL I N 2.331 DRILL I N 1.331 DRILL ~ N PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 21:40 - 22:15 0.58 DRILL N PROD1 22:15 - 23:45 1.50 DRILL N PROD1 23:45 - 00:00 0.25 DRILL N PROD1 1/22/2007 00:00 - 00:45 0.75 DRILL P PROD1 Clean, with 100% returns. The build section is ok. Bottoms up from sweep had lots of debris; mostly shale. Caught a sample for Geo. Sample was rounded pea gravel sized pieces of shale. It was not shale cuttings from drilling, but was consistent with shale sloughing. Shales look to be coming apart on us. RIH to clean out to TD. Clean from 8275' to 8500', slightly ratty but we washed thru. Clean down to 8790', tagged up hard. Work A4 shale at 8790'. Geo reports that latest bottoms up sample is from the A4 shale, and that some of the materal is shoughings, not cuttings. Note -The A4 shale is open in this lateral at at least 4 locations. It is not possible to identify which is the one that is contributing the sloughings. (Maybe all of them?) Continue to ream A4 clean at 8790'. Clean down to the start of the A4 shale at 9050'. Set down, reaming slowly. PU at 9064', had to pull 20 klbs over to get free. Yuck. Continue to work it. The A4 shale below 9050' is coming apart. We can't make any headway on cleaning it up. Got to 9064' ok, but no go past there. Call town to Cuss and discuss. Got thru 9064', got down to 9123'. Packing off. Heavy overpulls. Just about planted it. This hole is in very poor condition in the A4 shales. Pump 20 bbl high vis sweep. Chase it up hole to 8400'. Pump a 2nd high vis sweep at 9040'. Chase it up hole. Hole is very clean up to 8255'. Pulled 44 klbs over at 8255', then ratty up to 8200'. Suspect shale in larger section of hole above ledge. INC at ledge 68 deg. Pump another 20 bbls of high vis sweep. Run back down to ledge to clean cuttings in 68 deg section of hole above dog leg. Did not see ledge, clean back down to 8300', pump 20 bbl sweep. Empty vac trucks for KW F and used mud AOL. PUH thru window, clean. Open EDC. Performed both using pressure schedule (held 11.0+ ECD). Resume circ while reciprocate at 5'/min between bit depths of 8000' and 8120'. Got bottoms up gas back that set off alarms. Continue to get life spots while circ 1.46/1.41/2650 w/ 11.0 ECD. Assume C Sand perfs behind straddle packers are leaking thru blast rings 8000-8097' again (and EDC is above this point). Begin recip between .8110' and 8150' to put EDC below assumed leak point. Take off used mud to make room for KWF while CBU 1.46/1.42/2740 w/ 11.07 ECD and no life spots PVT 177 W ith concern that the 10.5 ppg KW F may not be heavy 'i enough, decided to lower pump rate to simulate KWF of 10.5 ppg after park CT at 8140' Red rate to 1.31/1.24/2520 and had 11.14 ECD after 27 bbls Red rate to 1.11/1.07/2230 and had 11.02 ECD after 20 bbls Red rate to 0.82/0.78/1820 and had 10.78 ECD after 15 bbls w/ no life spots Swap to KWF. Incr rate to 1.38/1.31/2610 POOH circ thru EDC 1.7/2640 pumping avg 10.35 ppg brine Check for flow/safety mfg LD drilling BHA Printed: 2/12/2007 10:14:15 AM ~' • BP Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Event Name: REENTER+COMPLETE Start: 1/10/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase 1/22/2007 00:45 - 01:00 0.25 CASE P RUNPRD 01:00 - 01:30 0.50 CASE P RUNPRD 01:30 - 05:45 4.25 CASE P RUNPRD 05:45 - 07:45 2.001 CASE I P I RUNPRD 07:45 - 08:15 0.50 CASE ~ P RUNPRD 08:15 - 08:30 0.25 CASE P RUNPRD 08:30 - 09:40 I 1.171 CASE I P I I RUNPRD ~~- 09:40 - 11:30 I 1.831 CASE I P I I RUNPRD 11:30 - 12:00 I 0.501 CASE I P I I RUNPRD 12:00 - 12:20 0.33 CASE P RUNPRD 12:20 - 12:40 0.33 CASE P RUNPRD 12:40 - 13:45 I 1.081 CASE I P I I RUNPRD 13:45 - 14:10 I 0.421 CASE ~ P I I RUNPRD Page 11 of 28 Spud Date: 1 /3/2007 End: 2/8/2007 Description of Operations Safety mtg re: liner Bring BTT tools to floor. RU floor to run liner MU Unique indexing guide shoe on BTT 2 deg bent sub on one jt 2-3/8" solid liner w/ O-ring sub. MU a total of 16 jts 2-3/8" 4.44# L-80 STL solid and slotted liner w/o cementralizers. Set 2-3/8" combis. Install false table. RU and run 7 stds of 1" CSH out of derrick and space out. Work on little jerks. MU deployment sleeve and CTLRT. MU MWD assy w/ orientor RIH with liner string #1. Liner length = 509.27', total BHA length with MWD is 562.39'. Wait at window for morning call to complete. PJSM to discuss plan forward for running liner in open hole. Discuss GS operation, circulation proceedure to disconnect, splined GS limitations, etc. Weight check at the window. DHWOB=-2000 Ibs (Liner in tension), RIH wt = 10400 Ibs, PU wt = 29500 Ibs. Orient bent sub to high side. RIH with pumps at 0.2 bpm. RIH thru the window slick. Orient to 45deg LOHS, continue RIH at 15 fpm. 8232, bobble, fell thru. 8258, large wt loss, then fell thru. 8264', ratty weight, then cleaned up. DHW06=-1000 lbs. String wt=10400 Ibs. 8300', solid set down, fell thru, but ratty weight. Stow down to 150 fph at 8490' "bit depth", and start tie in log. Make -9' correction. Continue RIH. RIH slick down to 9030', bobble. RIH from 9030', started getting ratty weight all the way to TD. Tagged up solid several times and stacked 4 klbs on DHWOB sensor, finally had final tag at 9142'. Picked up 50'. PU wt = 340001bs, DHWOB=-2800 Ibs. RIH fast. Solid tag up at 9142'. Stack out at surface, 4000 Ibs on DHWOB sensor. Bring on pumps to 3500 psi, 1.6 bpm. PU string wt = 27 klbs, DHWOB=-700 Ibs (CS hydril). (MWD is a wonderful thing). Confirmed liner is in place. Botto~,~of liner BHA at 9142', Solid liner 9142'-9043', Slotted finer 9043'-8822', Solid I- finer 8822'-8729', Slotted 8729'-8634'. Top of dep oyment sleeve at 8632.73'. '.;, r-1,~®~ fpcct~ w~ ~~ POH with liner running BHA. Pumping enough to maintain positive returns at surface, but not trying to clean the hole. (Don't want to hit it with excessive ECD's as we have KWF in the hole). Talk to town. Decided to modify mud system to try for better shale inhabition. We will weight up the mud to 9.1 ppg, increase the KCL concentration from 3% to 5%, and increase KlaGard from 12 ppg to 14 ppb. Getting gas bubbles and traces of crude back from open C sand perfs. Stop and circulate well taking retums to the tiger tank. Returns cleaned up to 10.3+ ppg. Short flow check. No flow observed. Continue POH. Circulating to get positive returns. Tag up at suface. Flow check well while holding PJSM to discuss standing back CS hydril. Check for flow at end of safety meeting. No flow observed. Rig down BHI MWD tool. Lay down 3 spaceout pups. Stand back 7 stands of 1" CS hydril. PJSM for running 2nd string of liner. Discuss hazards, safety joint, kicks, pinch points and other aspects of operation. Printed: 2/12/2007 10:14:15 AM gp Page 12 of 28 Operations Summary Report 'Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours I Task I Code ~ NPT I Phase Description of Operations 11/22/2007 113:45 - 14:10 I 0.421 CASE I P I I RUNPRD 14:10 - 15:45 I 1.581 CASE I P I I RUNPRD 17:15 - 18:45 I 1.50 CASE N RREP ,RUNPRD 18:45 - 19:00 ~ 0.25 ~ CASE ~ P ~ ~ RUNPRD ~-. ti~ 3~, w~~Jo 19:00 - 20:15 I 1.251 CASE I P I I RUNPRD 20:15 - 21:45 I 1.501 CASE I P I I RUNPRD 21:45 - 23:15 1.50 CASE P RUNPRD 23:15 - 23:30 0.25 CASE P RUNPRD 23:30 - 00:00 0.50 CASE P RUNPRD 1/23/2007 00:00 - 00:30 0.50 CASE P RUNPRD 00:30 - 01:00 0.50 STKOH P PROD1 01:00 - 01:15 0.25 STKOH P PROD1 01:15 - 05:45 4.50 STKOH P PROD1 05:45 - 06:40 0.92 STKOH P PROD1 06:40 - 09:45 3.08 STKOH N SFAL PROD1 Discuss job assignments, and hazard mitigation. Check well for flow. No flow observed. Make up Liner BHA #2. BHA (Top-Bot): BTT Aluminum Deployment Slv 2 Jts - 2-3/8" STL Solid 10' pup joint 3 Jts - 2-3/8" STL Solid liner 10 jts - 2-3/8" STL Slotted liner 1 ea - BTT 1.5 deg bent sub 2 ea - BTT 2-3/8" STL 1' solid pup joints 1 ea -Unique indexing guide shoe (4, 1/2" holes) Total liner length = 447.5'. Total BHA length with MWD tools = 500.84'. RIH wittiuoger section of liner. At 7800' while RIH lost communication to MWD tool. Found damaged wire between swivel and junction box inside reel. Stop at window to make repairs. Getting crude and gas back. Apply 200 psi whp and circ to tiger tank at min rate while repair connection After repairs, PUH 20' as wt chk, function orientor and verify tool is receiving signal, etc Continue RIH w/liner and went thru window at 40'/min at HS, clean. RIH at 50'/min and 45L to TD. Minor wt loss at prior liner spots verify that we are on depth. RIH to wt loss at 8640.3' CTD which is a normal -9' correction from where the top of the bottom section was left. PUH 30k surface wt, 0.4k wob. RIH and stack 6k down on top of bottom liner. Increase pump rate to 1.6 bpm @ 3550 while drop whp to zero. PUH and released from top liner w/ GS. TOL @ 8185' Solid liner down to 8308'. Slotted liner 8308'-8629'. Solid liner to BOL. BOL is 8632.73'. Note -guide shoe does not have the 1" thru ho a on a ip oTthe nose, but does have 4, 112" holes on the circumference of the guide shoe 3" up from the nose. PUH 50' to put GS ~ 8135' and circ out gas and oil at 0.31550 w/ 400 psi whp at 11.6 ECD (?) to tiger tank while wo a vac truck to arrive to get more KW F from the upright tank PVT 63 Incr rate to 1.42/3200 and circ out gas/oil to tiger tank. Pumped 40 bbls before registering any density (of 8.9 ppg) on 'out' MM. After one full circ, out density was up to 10.22 ppg w/ 11.44 ECD. After several circ's in/out density is 10.42 ppg while circ 1.42/3550 w/ 11.67 ECD. Took 87 bbls total to tiger tank POOH circ 1.42/3320 Check for flow LD MWD assy and liner running tools Finish LD and load out liner running tools Cut off CTC, dress stub. Stab back on well. SI swab Safety mtg re: pump slack/cut CT Reverse slack back. Blow back reel w/air. RU cutter and cut 290' CT for fatigue management. Dispose of CT. Install CTC and PT at 35k. Head up BHI UOC and test line. Fill CT and PT 4000 psi. Pump slack forward MU sidetrack assy Made up injector, perforrned shallow hole test, and found an Printed: 2/72/2007 10:14:75 AM • • gp Page 13 of 28 Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - To 1 Hours Task ~ Code NPT Phase 1/23/2007 06:40 - 09:45 I 3.08 STKOH I N SFAL PROD1 09:45 - 12:30 ~ 2.75 ~ STKOH ~ N ~ SFAL ~ PROD1 12:30 - 12:50 I 0.331 STKOH I N I SFAL I PROD1 12:50 - 13:50 I 1.001 STKOH I N I SFAL I PROD1 13:50 - 14:10 0.33 STKOH N SFAL PROD1 14:10 - 18:00 3.83 STKOH N SFAL PROD1 18:00 - 19:40 1.67 STKOH P PROD1 19:40 - 20:10 0.50 STKOH P PROD1 20:10 - 20:30 0.33 STKOH P PROD1 20:30 - 20:50 0.33 STKOH P PROD1 20:50 - 00:00 ~ 3.17 ~ STKOH ~ P ~ ~ PROD1 1/24/2007 00:00 - 01:15 1.25 STKOH P PROD1 01:15 - 02:15 1.00 STKOH P PROD1 02:15 - 03:15 1.00 STKOH P PROD1 03:15 - 05:00 1.75 STKOH P PROD1 05:00 - 06:00 ~ 1.00 ~ STKOH ~ P ~ ~ PROD1 06:00 - 08:00 ~ 2.00 ~ STKOH ~ P ~ ~ PROD1 08:00 - 14:30 I 6.501 WHSUR I P I I PROD2 Description of Operations electrical short in the corns line to the MWD. Broke off the MWD tools and tested the E-line, and had intermittant short. Troubleshot surface system. Found wire pulled out of Jupiter plug where it goes into the collecter on the reel. Repair same. Surface test. Passed ok. Pickup injector. Stab back onto MW D tools. Surface test MWD tools. Tools not working. Break injector back off. Continue troubleshooting. Lay down MWD tools on catwalk. Check with test cable to MWD cabin to bypass the E-line coil. MWD tool checks ok. Change out flow sub in UOC. Pick up MWD tools. Stab coil. Surface check of entire system. Not working. Leave coil stabbed. Isolate collector. Check from MWD cabin up thru collector. Hold discussion with SLB CTD Cell leader, SLB ET, SLB crew, BHI DD and 2 MWD hands, Nordic electrician to discuss troubleshooting problem. Set plan forward for finding problem. Resume troubleshooting problem with a clear step by step plan forward. Regroup, discuss plan forward. Attach BHA to coil. Test in the slips. No go, change out LOC. No luck. Continue trouble shooting, focusing on BHI equipment. All coil equipment appears to be working properly. Cable passes a meg-ohm and continuiety test. MWD tool works properly with a test jumper directly to the MWD cabin. Use rig electrician to check voltage at the end of the coil. Found polarity reversed. Jumper installed between Junction box and collecter in reel has reversed wires. This is the jumper that was changed for a new one this morning. It passes insulation and continuity checks, but is reversed from what the BHI tool requires. Schlumberger ET will switch it back. RIH with BHA #18 to sidetrack off of aluminum billett. Logged tie-in, corrected (-9 ft). Circulate KW F through open EDC Circulate 9.1ppg fluid around Closed EDC with 9.1 ppg at surface. RIH and tagged 8182.7 ft without pump. PUH and start pump at 1.56 bpm. RIH and tagged with Pp at 8142.3 ft. Set TF at 60deg R HS Time drill off ofAl~ billet starting at 8,182 ft at 5 min / 0.1 ft. Op = 1.54 / 1.47 bpm CTP = 3325 psi BHP = 3,880 psi at 11.65 ppg ECD ~ Z.. ~'?~ ~~ Finished time drilling 8,187.2 ft Drill slowly from 8,187 ft to 8,197 ft Reaming sidetrack at +/-30 deg from 65 deg RHS. POOH with open EDC following pressure schedule. Held PJSM. .OOH, trapped 700 psi on well. RIH 2.6 ft and closed EDC. i Tourpusher directing pressure undeploying BHA Crew change and PJSM to discuss remainder of undeployment of BHA. Weekly BOP pressure test witnessed by AOGCC, Lou Grimaldi. Had a leaking pressure test hose on 2-3/8" ram test. Repaired same. Had to grease choke valves to get pressure test. YnntBU: zn [/zVVi w: w:~o ruv, a BP Operations Summary Report Legal Well Name: 2Z-13 ,Common Well Name: 2Z-13 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours Task Code NPT 14:30 - 14:50 0.331 DRILL I P 1 /24/2007 14:50 - 17:30 I 2.671 DRILL I P 17:30 - 19:00 I 1.501 DRILL I P 19:00 - 19:45 ~ 0.75 ~ DRILL ~ P 19:45 - 23:50 I 4.081 DRILL I P 23:50 - 00:00 I 0.171 DRILL I P 11/25/2007 100:00 - 01:55 I 1.921 DRILL I P 01:55 - 05:00 I 3.081 DRILL { P Start: 1 /10/2007 Rig Release: 2/8/2007 Rig Number: Phase PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 05:00 - 06:00 1.00 DRILL N I RREP PROD2 06:00 - 06:30 0.50 DRILL N RREP PROD2 06:30 - 06:45 0.25 DRILL N RREP PROD2 06:45 - 07:00 0.25 DRILL P PROD2 07:00 - 09:10 2.17 DRILL P PROD2 09:10 - 10:30 I 1.331 DRILL I P I I PROD2 10:30 - 10:45 0.25 DRILL P PROD2 10:45 - 11:45 1.00 DRILL N DPRB PROD2 Page 14 of 28 ~ Spud Date: 1 /3/2007 End: 2/8/2007 Description of Operations PJSM prior to pressure deploying BHA. Safety meeting conducted by trainee Schlumberger hand, Jack Hougtaling. Discussed procedure in detail. Made job assignments. Discussed hazards and mitigations. Pressure deploy build section BHA. 2.6 deg motor, rebuilt Hycalog Bi-center bit. No Res tool. RIH with BHA #19 to drill build section of L2 lateral. Following revised pressure schedule. Tagged TPDX Vaive at 7,961 ft PU hole orient TF tp HS RIH and stopped at 8000 ft to tie-in Tie in Corrected (-8 ft) RIH wo pimp and correct TF past WS and billet. Drlling Build section from 8,202 ft to w/ 180 TF Hydrocarbons to surface from bottoms ups. 9.1 ppg flo-pro gas cut. Circulated 26 bbl gas cut flow-pro to tiger tank. Tumed TF to HS at 8245 ft Op = 1.55 / 1.55 bpm at 3,750 psi Vp=284 bbl DHWOB = 1 to 4 klb' ROP = 40-60 fph. WHP = 175 psi, BHP = 3.700 psi w/ 11.8 ppg ECD NOTE: No fault was cut in this leg, formation tops as in the parent wellbore After landing as per programme at 8371 ft, PUH, close well in, SD pump and trap 700 psi on wellhead. PUH, at 8,029 ft open EDC and POOH circulating at 1.70 bpm following pressure schedule Held PJSM on Pressure Undeploying BHA. Review PJSM on prevoius trip out of hole using pressure undeploying techniques. OOOH, RIH 2.6 ft and pressure undeploy BHA with 700 psi on wellhead. WHP stablized at 64 psi while undeploying BHA which equates to 9.3 ppg EMW at 6,000 ft TVD. Change out DGS due to wet connect failure. PU USMPR (Res Tool). No comms in top half of tool. Trouble shoot communications in upper coiltrac BHA. Shut down for crew change out. Sort out BHI problem. Tools working ok. It was a bad test jumper PJSM Re: Pressure Deploying Lateral section BHA. Pressure deploy L1 lateral section BHA #1. Had 264 psi on WHP when we opened up to the well. RIH with BHA #20, first L1 lateral section BHA. HCC 2.7 x 3.0 Bicenter bit, 1.1 deg motor, RES tool. Appear to be losing fluid a bit. About 0.1 bbl/min, 6 bbl /hr. Log tie in pass down over GR charecter at 8000'. Make -7' correction. Shut EDC. RIH dry thru window and top of whipstock holding "as drilled" toolface. No bobbles. Kick pumps on to 1.6 bpm. RIH. Tag up at 8331'. Work thru it. Tag up at 8354'. Heavy pick up at 40 klbs. Cleaned up at 8315'. Ream back up to 8300. RIH, set down and stall at 8328'. Pick up at 27 klbs, better, but still ratty. RIH with pumps at 0.25 bpm, TF = 0. Made it slick down to 8363'. Pumps on. Clean PU. Pump pressure ratty. May have debris above us packing off. 1.5 Printed: 2/12/ZOV/ 1U:14:15 AM gp Page 15 of 28 ~ Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/25/2007 ~ 10:45 - 11:45 ~ 1.00 ~ DRILL ~ N I DPRB PROD2 bpm, 4000 psi. Pressure fell off as we got up to 8300'. RBIH 11:45 - 13:00 1.25 DRILL P PROD2 13:00 - 13:10 0.17 DRILL P PROD2 13:10 - 14:10 1.00 DRILL P PROD2 14:10 - 14:20 0.17 DRILL P PROD2 14:20 - 14:25 0.08 DRILL P PROD2 14:25 - 16:30 2.08 DRILL P PROD2 16:30 - 17:45 1.25 DRILL P PROD2 17:45 - 18:00 0.25 DRILL P PROD2 18:00 - 20:00 2.00 DRILL P PROD2 20:00 - 21:10 1.17 DRILL P PROD2 21:10 - 22:55 1.75 DRILL P PROD2 22:55 - 00:00 1.08 DRILL P PROD2 1/26/2007 00:00 - 01:00 1.00 DRILL P PROD2 01:00 - 01:40 0.67 DRILL P PROD2 01:40 - 06:00 4.33 DRILL P PROD2 06:00 - 06:30 0.50 DRILL P PROD2 06:30 - 13:15 6.75 DRILL P PROD2 13:15 - 14:20 1.08 DRILL P PROD2 14:20 - 18:30 4.17 DRILL P PROD2 dry to 8369'. PU slightly ratty, but better. RIH at 0.25 bpm, 30 fpm. Ran to bottom slick. Log MAD pass up from TD to acquire RES data in the build section. 150 fph. Pumping 1.5 bpm. No problems on MAD pass. Lots of pumping and slow pulling. Probably really cleaned the hole. Run back in hole at 0.25 bpm, slick with no problems. Free spin 3500 psi at 1.65 bpm. Begin drilling at 1.65/1.58 3700 psi. PVT=246 bbls. Bringing on 200 bbls of new mud from the tank farm. I/O 234/298. String wt = 5600 lbs. DHWOB=1600 lbs. 50-60 fph. Finished taking on mud. PVT=351 bbts. Make a precautionary wiper trip. PU off bottom at 26 klbs clean. Free spin of bottom is 3420 psi at 1.6 bpm. Clean up to 8300. RIH, TF=90R, set down a# 8360'. PU, orient to 20L, "As drilled". Pumps off, RIH. Slick to bottom. Free spin 3450 psi ~ 1.62 bpm. Resume drilling. ROP 50 fph drilling A4 shale. Trying to drill up into the A4 sand. Continued to drill ahead. Held Parted/Pinholed coil tubing, Spill and H2S drills. Pump 10 bbl high vis sweep. Wiper trip to window as sweep exited bit. Smooth trip. Droped pumps to 0.25 bpm when running. down past 8300', made it to bottom slick. Resume drilling. PVT=346 bbls. I/0=159/181 psi. Free spin = 3300 psi @ 1.6 bpm. Drilling at 1.59/1.58/3700 psi. Still drilling shale. Geo wants to increase INC to 95+ (from 94) to get up out of the shale. Drilling break, ROP up to 120 fph. Wiper trip. Clean PU off bottom at 24 klbs. Free spin 3435 psi at 1.59 bpm. Clean up to 8190'. Ran down past 8300' at 0.25 bpm. Pumps back up at 8500'. Set down at 8630 with motor work. Picked up shut down pumps and got thru ok. Resume drilling lateral section. Continue drilling ahead. Make wiper trip to the window. Note that last 10' drilled very slowly. Log tie in pass, correction -0.5'. Ran back in the hole with pumps at 1.0 bpm thru 8300', and had no problems getting to bottom. ROP very slow on bottom. Drilling ahead at -10 fph. Geo confirms we are in the Ankorite. Plan is to drill up thru it, then level off. Continue drilling while holding crew change. Drill ahead. PVT=393 bbls. IAP/OAP=363/199 psi. Drilling at 1.56/1.52/3440 psi. Pump 10 bbl high vis sweep. Make wiper trip to the window. Overpulls and MW at 8922', 8682', 8350. The sweep seemed to bring up more cuttings than usual when it got to surface. RIH at 0.6 bpm, and went slick to bottom. One set down at 8935'. Resume drilling. Free Spin 1.59 3480 psi. PVT=378 bbls. Appear to be losing a couple of bbls of mud an hour. Drilling at 1.62/1.56/3900 psi. DHWOB=1200 lbs. String wt = 4000 lbs. Printed: 272/2007 10:14:15 AM r gp Page 16 of 28 Operations Summary Report Legal Well Name: 2 Z-13 i Common W ell Name: 2 Z-13 Spud Date: 1/3/2007 Event Name : R EENTE R+COM PLETE Start : ~ 1/10/2007 End: 2/8/2007 Contractor N ame: N ORDIC CALIST A Rig R elease: 2/8/2007 Rig Name: N ORDIC 2 Rig N umber: Date ~ From - To ! Hours Task Code NPT Phase Description of Operations 1/26/2007 14:20 - 18:30 4.17 DRILL P PROD2 Start pumping sweeps at 1, 10 bbl sweep per hour. Seeing more cuttings in returned sweeps. 18:30 - 19:50 1.33 DRILL P PROD2 Wiper trip back to 8200'. Motor work and increased weight pulling up from 8920' thru 8850' and at 8680'. PVT = 354bb1s. Set down once at each of 8910', 8940', 9025', 9110 -slowed pump to .2 bbl/min and used as drilled tool face to pass thru. 19:50 - 22:45 2.92 DRILL P PROD2 Resume drilling. Free spin 3500psi. Drilling at 1.59 3950 TFO 100 degrees. ECD 12.63ppg. PVT=354 bbls. DHWOB 10001bs. Instantaneous ROP 26-60'/hr. Some weight transfer issues. 22:45 - 23:50 1.08 DRILL P PROD2 Wiper trip back to the 8010' for tie-in. Overpull at 8940', and 8350'. Pumps shut down passing TOL and thru window. Open EDC inside casing. 23:50 - 00:00 0.17 DRILL P PROD2 Log down at 150'/hr to tie in. Correct -1'. 1/27/2007 00:00 - 01:00 1.00 DRILL P PROD2 RIH back to bottom after tie in. set down at 8937'. 01:00 - 03:30 2.50 DRILL P PROD2 Resume drilling. FS 3850 @ 1.56bpm. Drilling 1.47/1.43/4100psi, DHWOB 14001bs, TFO 195, ECD 12.4ppg. Pumped 30bbls high vis sweep to use up pill when swapping to new mud. Large amount of cuttings came to surface, ECD as high as 13.5ppg. New mud in hole at 2:40. Increased ROP's to 120'/hr once in the hole. 03:30 - 05:20 1.83 DRILL P PROD2 Wiper trip back to 8200'. Overpull at 8350' while POOH and set down at 9160' RIH. Fairly clean trip. 05:20 - 06:00 0.67 DRILL P PROD2 Resume drilling. Drilling 1.54/1.48/3660, DHWOB 11001bs, TFO 270, ECD 12.33ppg. Pumping hourly 10bb1 high vis sweeps. 06:00 - 06:15 0.25 DRILL P PROD2 Tour crew change. Continue drilling. 06:15 - 07:15 1.00 DRILL P PROD2 Continue drilling. PVT=354 bbls. IAP/OAP=458/222. 07:15 - 08:30 1.25 DRILL P PROD2 Drilling ROP slowed way down, and having difficulty getting back to bottom. Pump 10 bbl sweep. As sweep exits bit, make wiper trip to window. Clean PU off bottom and clean pulling up to 8960'. Started pulling heavy and packing off. PLF. Work it up slow. Pump another 20 bbls of high vis sweep. Very heavy overpulls, packing off up to 8850'. Suspect poor hole cleaning. Continue up hole. Overpull at 8660', 8350. 2nd sweep had lots of cuttings. Hole cleaning is the issue. 08:30 - 10:30 2.00 DRILL P PROD2 Run back in hole. Holding "as drilled" tool face. Ran it at 1.0 bpm past 8350', and didn't see a bobble. Raise rate to 1.3 bpm at 8750'. RIH smooth to 8930'. Started seeing weight. Pumps to 0.25 bpm, slid right thru. Kick pumps on to full rate, pump another 20 bbl sweep. Run to 8960', wash back up thru it with sweep. Looking much better than last time. Virtually no overpulls, and no motor work or packing off. Caught a sample from the last sweep. Geo reports it looks Ilike cuttings, and not cavings. Shale 70% and sand 30%. Probably not cleaning the hole as good as we need to. Increase high vis sweep viscosity from 100 k to 150 k Isrv. 10:30 - 12:00 1.50 DRILL P PROD2 Tag bottom. Resume drilling. Free spin 3560 psi at 1.55 bpm. ECD=12.1 ppg, BHP=3729 psi. Higher than yesterday. Probably from viscosity of new mud + sweeps. Drill ahead at 60 fph. 1.55/1.51/3650 psi. String wt=2800 Ibs, DHWOB=1200 Ibs. Plan to pump 20 bbl sweep of higher vis sweep 1 per hour. Printed: 2/12/2007 10:14:15 AM gp Page 17 of 28 Operations Summary Report 'Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To ~ Hours ~ Task Code NPT - - 1/27/2007 12:00 - 12:50 0.83 (DRILL P 12:50-13:10 ~ 0.33~DRILL (P 13:10 - 14:15 ~ 1.08 ~ DRILL ~ P 14:15 - 15:30 I 1.251 DRILL I P Spud Date: 1/3/2007 Start: 1 /10/2007 End: 2/8/2007 Rig Release: 2/8/2007 Rig Number: Phase Description of Operations PROD2 Hit hard streak at 9532'. Stack -85001bs string wt. 1200 Ibs DHWOB. Hard hard hard. PROD2 PJSM for confined space entry into pit #1. Continue drilling on hard spot. PROD2 Continue trying to drill. Getting 1500 Ibs to DHWOB sensor, but not making any ROP. PROD2 Not making any progress except 3' of stacked pipe. 1.55/1.52/3630 psi. About 40 Ibs of motor work. 2000 Ibs DHWOB should be enough to drill with. Pump 20 bbl of Jesus sweep to clean hole again. Sweep to bit and start POH. Going to pull OOH for a new bit and to check the BHA. Note - 1166' on this bit. 15:30 - 16:50 I 1.331 DRILL I P 16:50 - 17:10 I 0.331 DRILL I P 17:10 - 19:15 2.08 DRILL P 19:15 - 19:20 0.08 DRILL P 19:20 - 19:50 I 0.501 DRILL I P 19:50 - 22:45 2.92 DRILL P 22:45 - 23:00 0.25 DRILL P 23:00 - 00:00 1.00 DRILL P 1/28/2007 00:00 - 01:10 1.17 DRILL P PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 01:10 - 06:00 4.83 DRILL N SFAL PROD2 06:00 - 06:30 0.50 DRILL N SFAL PROD2 06:30 - 07:50 1.33 DRILL N SFAL PROD2 07:50 - 08:15 0.42 DRILL N SFAL PROD2 08:15 - 09:20 ~ 1.08 ~ DRILL ~ N ~ SFAL ~ PROD2 09:20 - 14:45 ~ 5.42 ~ DRILL ~ N ~ SFAL ~ PROD2 8950, minor bobble on wt. 8330' overpull and motor work. Got thru is ok. Hole is in better shape than last trip OOH. Pull past L1 billet and window slick with no problems. POOH pumping at full rate. Hold PJSM Re: Undeploying while POH. EDC gave error message when closing. Discussed checking for flow very carefully when undeploying to ensure that EDC is not leaking. Pressure undeploy BHA #20. SL parted during undeploying. BHA(68' long) dropped 15' to land on swab valve. Well was secured and dog collars set. Stop job. Gather team in doghouse and develop procedure to safely lay down tools without SL. ID and review hazards associated with the new procedure. Ensure all members comfortable with new plan, and proceed to execute. Finish undeploying and lay down tools. BHI swapping entire string due to dropped BHA when SL parted. Slipped and cut 70' off of SL unit, twist tested new section to 30 turns(pass is 17 turns). Thread SL through lubricator and re-head SL on rope socket. PJSM prior to picking up BHA and pressure deploying. Pressure deploy BHA. Continue to pressure deploy BHA and connect injector. BHI testing tools. No communicataions to BHI tools. Troubleshoot same. Shut down for crew change out. Continue troubleshooting toms problems. WSL's are in camp sorting out slickline failure of the previous evening. Group up with all hands on rig. Discuss where we are, and the best plan forward for sorting out problems. Resume troubleshooting corns problems. BHA works fine with test jumper. Problem is in the coil/eline system somewhere. With the assistance of the rig electrician, Mike Shic, we quickly identified the problem as the SLB collector. Discuss plan forward with SLB hands. Need to replace collector with the spare. To do this we can not circulate, and will need to swap the coil to water, then blow it back. Swap 'from mud to 9.1 ppg. Circulate brine from pit 1, takiing mud to active system. Blow brine back after getting coil loaded with brine to give us a void space to avoid freeze up. Change out f~nntea: urr~zuw iunaa~r{nn gP Page 18 of 28 Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/28/2007 09:20 - 14:45 5.42 ~ DRILL N SFAL PROD2 collector. Inspect old collerctor. Found burned wire inside 14:45 - 15:10 ~ 0.42 ~ DRILL ~ P ~ ~ PROD2 15:10 - 16:10 I 1.001 DRILL I P I I PROD2 16:10 - 18:50 I 2.671 DRILL I P I I PROD2 18:50 - 19:05 ~ 0.25 ~ DRILL ~ N ~ SFAL ~ PROD2 19:05 - 21:45 I 2.671 DRILL I N I SFAL I PROD2 21:45 - 23:55 2.17 DRILL N SFAL PROD2 23:55 - 00:00 0.08 DRILL N SFAL PROD2 1/29/2007 00:00 - 01:00 1.00 DRILL N SFAL PROD2 01:00 - 01:15 0.25 DRILL N SFAL PROD2 01:15 - 03:20 2.08 DRILL N SFAL PROD2 03:20 - 03:40 0.33 DRILL N SFAL PROD2 03:40 - 04:05 0.42 DRILL N SFAL PROD2 04:05 - 05:30 1.42 DRILL N SFAL PROD2 05:30 -05:45 0.25 DRILL N SFAL PROD2 05:45 - 06:00 0.25 DRILL N SFAL PROD2 06:00 - 06:30 0.50 DRILL N SFAL PROD2 06:30 - 11:00 I 4.501 DRILL I N I SFAL I PROD2 11:00 - 11:30 I 0.501 DRILL I N I SFAL I PROD2 11:30 - 13:00 1.501 DRILL ~ N ~ SFAL ~ PROD2 13:00 - 16:40 I 3.671 DRILL I N I SFAL I PROD2 16:40 - 18:00 I 1.33 DRILL IN SFAL PROD2 18:00 - 19:00 1.00 DRILL N SFAL PROD2 19:00 - 19:20 0.33 DRILL N SFAL PROD2 19:20 - 21:20 2.00 DRILL N SFAL PROD2 21:20 - 21:35 0.25 DRILL N SFAL PROD2 21:35 - 23:15 1.67 DRILL N SFAL PROD2 electrical connection. Tested new collector and coil. Perfect insulation. PJSM about deploying lateral section BHA. Discuss hazards of resuming a job that has been half way completed. Discuss double checking status of all valves and equipment prior to being deployment. Open inner reel valve. Check eline 1 last time. Checks ok. Resume deployment proceedure from step 26. MW D BHA checks good! Continue with deployment. RIH with BHA #21.1.1 deg motor, Hycalog Bicenter bit, Andergauge Agitator. Following pressure schedule as we RIH. Noted pinhole in coil with bit @7979. PJSM prior to reeling the pinholed coil back from injector to reel. POOH to surface for pressure undeploy. Stop to check roof for fluid once the pinhole was safely under a wrap of coil, no fluid noted. PJSM for pressure undeploy prior to reaching surface. Pressure undeploy BHA. Prepping for N2 displacement. Continue prep for N2. PJSM prior to blowing down the reel with N2. Blow down coil with N2. Take first 30 bbls to pits, remainder directed to tiger tank. PJSM to Unstab CT and reel swap. Unstab CT and lock down for moving. Lower CT from reel house to trailer. Lift new CT reel from trailer to reel house. Start rigging up hardline inside reel. Shut down operations for tour crew change. Hold PJSM to discuss plan forward. Continue rigging up hardline in reel (inner reel valve, pressure bulkhead, etc.). Hold PJSM to discuss stabbing pipe. Review proceedure. Discuss hazards. Discuss mitigations. Make job assignments, and review expectations. All unnecessary personnel to remain off the rig during this operation. Pull coil off reel and stab pipe into injector. Change out packoffs. Dress end of coil. Install boot on end of eline. Stab on well. Circulate to load the reel with fluid. Pump slack management. Heard good movement of eline inside coil. Reverse in 10 bbls of methanol inside end of coil. SD pumps. Unstab lubricator. Pick up hydraulic pipe cutter. Cut 20' of pipe and found end of elilne. Cut a total of 300' of pipe for coil management. Attach CTC. Pulltest. Attach eline UOC. PT. Circulate methanol through coil followed by water and pressure test CTC. PJSM to PU BHA and pressure deploy. Pressure deploy BHA. Troubleshoot BHI tools. RIH to tie-in depth of 8015. Intial returns mixed with crude and gas sent to tiger tank. Printed: 2/12/2007 10:14:15 AM gp Page 19 of 28 Operations Summary Report Legal Well Name: 2 Z-13 Common W ell Name: 2 Z-13 Spud Date: 1/3/2007 Event Name : R EENTE R+COM PLET E Start : 1/10/2007 End: 2/8/2007 'Contractor Name: N ORDIC CALIST A Rig R elease: 2/8/2007 Rig Name: N ORDIC 2 Rig N umber: Date From - To Hours Task Code NPT Phase Description of Operations 1/29/2007 23:15 - 23:30 0.25 DRILL P PROD2 Tie-in to log at depth of 8015. 23:30 - 00:00 0.50 DRILL P PROD2 Circulate until returns are full density prior to entering openhole. 1/30/2007 00:00 - 00:05 0.08 DRILL PROD2 Circulate until returns are full density prior to entering openhole. 00:05 - 00:55 0.83 DRILL PROD2 RIH circulating at 1.25bbls/min and set down at 8332 -start of shales. ECD rose to 15.5. Short wiper. Tried again at 0.4bbls/min and saw ECD of 17. Assuming packing off, but ECD remained high once pulled back to the aluminum billet. Cuttings over the shakers. 00:55 - 01:45 0.83 DRILL PROD2 Pull into casing to circulate and monitor ECD. 01:45 - 02:30 0.75 DRILL N PROD2 BHI screens down in ops cab. 02:30 - 03:20 0.83 DRILL PROD2 Attempt to run to bottom again. ECD 11.70 at 8200' and 1.6bbls/min. sat down at 8323' at .75 bbls, passed thru at .5 bbls/min. Sat down again at 8393. Overpulls when pulling back, wiper to below aluminum billet. RIH at .45bbls/min, sat down at 8434'. Max overpull of 53klbs with pump rates of 1.4bbls/min. 03:20 - 04:05 0.75 DRILL PROD2 Wiper trip back to casing and circulate. 04:05 - 05:15 1.17 DRILL PROD2 Continue to attempt to run to bottom. Low rates of .4bbls/min seem to be working for moving down and up. Sat down twice at 8461. 05:15 - 06:00 0.75 DRILL PROD2 Wiper trip back to below aluminum billet. 06:00 - 06:40 0.67 DRILL PROD2 Continue to ream and backream. Making progress in 25' bites. Hole is pretty sticky and it looks as if the shales have started to come apart a bit in the past 48 hours while we were OOH. PVT=303 bbls. IA/OAP=7/127. 06:40 - 08:15 1.58 DRILL N DPRB PROD2 Take bite to 8679', wash back up and stuck with bit at 8665'. Packed off. pumping 1.0 bpm, 4000 psi. Returns 0.1 bpm. Work pipe down hole. No luck. Returns go to 0, completely packed off. Can't go up or down. Pull 46 k lbs. No luck. Put in coil at neutral weight. Try to open EDC, try to circulate thru it. No luck. The EDC is not functioning, and BHI hands on the rig can't get it to work. (Note -May not be able to disconnect if we need to). Pull to max. 58 klbs. Bring on pumps. Slight trickle of returns. DHWOB=-1170 lbs. Shut choke, pressure up wellhead. Stops pressuring up at 520 psi. Pull again to max. Got -747 Ibs tension on DHWOB sensor. Bit is rotating. Orienter turns. We appear to be stuck between the orienter and the DPS. Hold pull on coil. DHWOB bleeding off slowly. Bled off to -700 Ibs, then stopped. 08:15 - 08:40 0.42 DRILL N DPRB PROD2 Pressure up backside to 1500 psi. 500 psi inside coil. -700 on DHWOB. Pull 60 klbs. DHW06=-700 psi. ANN pressure=4769 psi, Bore pressure = 3971 psi. Dump backside pressure. DHWOB=-800 Ibs, ANN pressure =4785 psi, Bore pressure = 3800 psi. Stack wt. Start alternately pumping down the coil for 5 minutes, then down the backside for 5 minutes. Trying to wash the stuff out around the BHA. 08:40 - 14:00 5.33 DRILL N DPRB PROD2 Start alternately pumping down the coil for 5 minutes, then down the backside for 5 mintues. Trying to wash the cuttings out from around the BHA. Orienter free to turn. Stuck above orienter and motor. DHWOB and Ann Pressure sensor not reactive when pulling, or pumping down the backside. No retums when pumping down the coil. Down the coil WHP=640 psi. DHWOB=-1350 Ibs, AP=4958, Printed: 2/12/2007 10:14:15 AM • BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ~ From - To 1 /30/2007 108:40 - 14:00 2Z-13 2Z-13 REENTER+COMPLETE Start: 1 /10/2007 NORDIC CALISTA Rig Release: 2/8/2007 NORDIC 2 Rig Number: Hours Task Code l NPT Phase 5.331 DRILL I N 14:00 - 15:30 1.50 DRILL N 15:30 - 17:12 1.70 DRILL N 17:12 - 18:30 1.30 DRILL N 18:30 - 20:30 20:30 - 22:00 22:00 - 00:00 1 /31 /2007 00:00 - 00:30 00:30 - 02:15 02:15 - 02:30 02:30 - 04:30 04:30 - 05:30 2.00 DRILL N 1.50 DRILL N 2.00 DRILL N 0.50 DRILL N 1.75 DRILL N 0.25 DRILL N 2.00 DRILL N 1.00 DRILL N 05:30 - 06:00 0.50 DRILL N 06:00 - 08:00 2.00 DRILL N 08:00 - 18:00 ~ 10.00 DRILL ~ N DPRBIPROD2 DPRBIPROD2 DPRBIPROD2 DPRBIPROD2 DPRB IPROD2 DPRB PROD2 DPRB PROD2 DPRB PROD2 DPRB PROD2 DPRB PROD2 DPRB PROD2 DPRB IPROD2 DPRB PROD2 DPRB PROD2 WAIT I PROD2 Page 20 of 28 ~ Spud Date: 1 /3/2007 End: 2/8/2007 Description of Operations Bore Pressure=5289 psi. No returns. Down the backside WHP=1500 psi. DHWOB=-700 Ibs, AP=4744 psi, BP=4085 psi. Injecting at 0.6 bpm. Down the coil @ 0.74 bpm. WHP=400 psi. DHW06=-1000 Ibs, AP=4913 psi, BP=5176 psi Slight retums. Down the backside 0.5 bpm. WHP=1670 psi. DHWOB=-1100 Ibs, AP=4874 psi, BP=3895 psi. Continue cycling pressure both ways. Trying to get some sore of movement at the BHA. HOT and DPS seem to be working. Oriented TF around while working the CT CT at 8660 ft is 38 fatigue Pumped 15 bbl of Kupuark Slick diesel down CT (Vct = 38.7 bbls) Placed CT in neutral CTW. Located Dead crude at WOA GC1. With 36 bbls diesel pumped, motor stall at 4300 psi. Op = 0.67 / 112" stream. MM not working at these lower Op Pumped 43 bbl. (5 bbl diesel out) SD and moved TF from 90L to 270 deg. Saw some movement PUH from 8,658 ft to 8,393 ft Placed CT in neutral at 11 k and moved TF from 90R to 90 L while pumping 20 bbl diesel down CT. INTEO building new tool string minus agitator and USMPR (res tool) With 3 bbl diesel out worked CT and started moving again Worked BHA into 3-1/2" tubing. Gas/oil to surface. Take returns to tiger tank while working CT. Circulate wellbore clean taking returns to tiger tank. Returns slowly increasing. Mud weight also increasing. Circulate out of hole with drilling assembly. Maintain WHP as per schedule. Hold PJSM in Ops cab before getting to surface. Pressure undeploy BHA. MU 1.1 deg motor with re-run Hyc bi center ibt. Continue to deploy lateral clean out assembly. Stab coil and test tools. Get on well. Run in hole. Maintain WHP as per pressure schedule. Log GR tie in from 7990'. Subtract 8' correction. Run into open hole. 3420 psi fs at 1.52 in/1.59 out. Set down at 8300'. Back ream. Set down at 8316'. PU to back ream. Pulled 44k#. Varypump rate and tool face to left and right. 8316'. Not able to get past. Drill ahead 2'-3'. PU to back ream. Pulled 56k# to get free. This section is very sticky. j Decide not to risk BHA. Circulate out of hole. Maintain WHP as per schedule. Hold PJSM in Ops cab to discuss undepfying the BHA. PJSM Pressure undeploy BHA with 600 psi on wellhead Crew change, PJSM on BHA handling while pressure undeploying Pressure Undeploying BHA with 500 psi on wellhead. Turned Phase II in the GPB and Kup field. Talked through proposed ST options with Town and decided on plan forward. Waiting on BOT convey from Deadhorse. Working on removing huge drift at entrance to 2Z Pad Kupuark tuned to Phase III at 10:30 hrs. Recoverd all field personnel and setup in mancamp. Hunkered down and make 30 minutes walk arounds. Called in fuel and water numbers to GPB Field Engineers Printed: 2/12/2007 70:14:15 AM ~~ gp Page 21 of 28 ~ Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 ,Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/31/2007 18:00 - 00:00 6.00 DRILL N WAIT PROD2 2/1/2007 00:00 - 00:30 0.50 DRILL N WAIT PROD2 00:30 - 02:00 1.50 DRILL N WAIT PROD2 02:00 - 02:30 0.50 BOPSU P PROD2 02:30 - 03:00 0.50 DRILL N DPRB PROD2 03:00 - 05:00 ~ 2.00 ~ DRILL ~ N ~ DPRB J PROD2 05:00 - 06:20 ~ 1.33 ~ DRILL ~ N ~ DPRB ~ PROD2 06:20 - 06:45 0.42 DRILL N DPRB PROD2 06:45 - 07:15 0.50 STWHIP N DPRB PROD2 07:15 - 09:05 ~ 1.83 ~ STW HIPS N ~ DPRB ~ PROD2 09:05 - 09:50 I 0.751 STWHIPI N I DPRB I PROD2 09:50 - 13:00 I 3.171 STWHIPI N I DPRB I PROD2 13:00 - 14:45 I 1.751 STWHIPI N I DPRB I PROD2 14:45 - 15:00 I 0.251 STWHIPI N I DPRB I PROD2 15:00 - 16:00 I 1.001 STWHIPI N I DPRB I PROD2 16:00 - 17:15 f 1.25! STWHIPI N I DPRB I PROD2 17:15 - 19:00 1.75 STWHIP N DPRB PROD2 19:00 - 21:00 2.00 STWHIP N DPRB PROD2 21:00-23:001 2.OOISTWHIPIN IDPRB IPROD2 23:00 - 23:30 0.50 STWHIP N DPRB I PROD2 23:30 - 00:00 0.50 STWHIP N Cotniue to wait on weather (Phase 3). Discuss buddy system for periodic outside walk arounds. Establish water & fuel conservation measures on rig and in camps. Winds calming but roads still not passable. Continue to wait on Phase Three weather condtiions. Main roads now phase two. Pads remain phase three. Clear a path to Spine Road with loader. Fuel truck on location. Function test BOP equipment. Hold PJSM with all crew. Discuss making up Baker billet assembly, Review pressure deployment highlights. Bring Baker tools to pipe shed. Heat same. MU slim hole billet assembly (1.1.1' x 2.625") with Model J setting tool and full Inteq MWD. Found 450 psi on well. Run in hole. Maintain WHP as per schedule. Snubbing wt high -6k running in the hole. Mud thick from inactivity (thick) and having trouble getting displacement. Stopped and unable to open EDC due to delt P on the EDC tool. PUH to reduce the delta P on the BHA from 600 psi to 50 psi. Stopped at 4,264 ft and open EDC with 30 psi differential RIH slowly at 0.25 bpm down CT. Nordic's out MM is still not working correctly. Using WHP to try an achieve some circulation Unable to get any returns to surface due to high yield /gel muds. RIH to 4,965 ft. POOH slowly due to tool OD, high yields and gel strengths mud. Order trucks for mud swap flollowing cleanout. Held PJSM and review new Hydraulic Winch /slickline RP with crews. BHI setting up 1.1 motor for cleanout Tagged up, bleed CTP down to 250 psi to keep delta P on the billet setting tool. Pressure up on wellhead to 500 psi, open EDC and pressures equalize to 250 psi. Pressure undeploy BHA / BOT Billet Set billet in pipe shed and pressure deploy cleanout BHA Crew change. RIH. open EDC at 125 ft, RIH as per pressure schedule. At 5000 ft started taking returns to tiger tank due to hydrocarbons Tie-in at 8000 ft, corrected -6 ft. Started new flo pro down CT SD pump, SWI and closed EDC RIH with correct TF and cleaned out to 8,300 ft MD Hole clean to 8300 ft PUH chasing new Flo-pro to surface. PUH with correct TF. open EDC POOH chasing new flo-pro to surface. Held PJSM and review new RP for operating the slickline unit used in pressure deploying or undeployment of BHA's Pressure undeploy BHA. 485 psi on wellhead. MU Baker TT aluminum billet and Model J setting tool on Inteq MWD. Test tools. Get on well. Open EDC. Run in hole. Maintain 500 psi WHP. Circ at min rate. Log gr tie in from 8000'. Subtract 8' correction. Run in hole. CT wt: 8.4k# dn, 22.5k# up. Run to 8285'. PU to up weight. Close EDC. Pressure up coil to 4500 psi. Pull to 35k# on coil. Slips set, tool not sheared. Pull to 50k#. Set down -5k# on billet. PU again. Toll sheared at 52k# up wt. Pressure bled off ~i J tool too. 3500 psi at 0.55 bpm. Something not quite right. Printed: 2/12Y2007 10:14:15 AM gp Page 22 of 28 Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: ~ 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours, Task Code NPT :Phase 2/1/2007 23:30 - 00:00 0.50 STWHIP N PROD2 2/2/2007 00:00 - 01:45 1.75 STWHIP N DPRB PROD2 01:45 - 03:15 1.25 STWHIP N DPRB PROD2 03:15 - 06:00 2.75 STWHIP N WAIT PROD2 06:00 - 10:30 I 4.501 STWHIPI N I WAIT I PROD2 10:30-11:15 0.75 STWHIP N WAIT PROD2 11:15 - 11:30 0.25 STWHIP N DPRB PROD2 11:30 - 15:00 3.50 STWH-P N SFAL PROD2 15:00 - 17:00 I 2.001 STWHIPI N I WAIT I PROD2 17:00 - 19:30 ~ 2.501 STWHIP N STUC ~ PROD2 19:30 - 20:00 ~ 0.50 ~ STWHIP~ N ~ STUC ~ PROD2 20:00 - 21:00 I 1.001 STWHIPI N I STUC I PROD2 21:00 - 21:45 I 0.751 STW HI PI N I STUC I PROD2 21:45 - 22:30 ~ 0.75 ~ STWHIP~ N ~ STUC ~ PROD2 Description of Operations Pull into casing. Bleed off coil and open EDC. Pull out of hole. Fill hole and maintain WHP as per schedule. Hold PJSM to review undeploy. Pressure undeploy billet BHA. LD tools. Left setting rod inside billet, 2' down inside of billet. LD BHA components. Request Baker put together another billet assembly. BOT is testing the setting rod on the billet. BHI found their shipment at the Deadhorse yard Trying to track down EDC tool enroute to slope from Anchorage. Having trouble finding anyone on the slope with Lynden. Unable to locate the BHI shipment. BHI needs to start their repair shop back up in Deadhorse. Lots of times has been spent waiting on tools from Anchorage and it will increase with both rigs using BHI Coiltrac. Research on the operations of the BOT's AI billet at BOT Deadhorse faculities. Waiting on the replacemenmt EDC from Lynden's yard. BHI tools arrived at 10:30 hrs Pre EDC tool after shipment MU to string and ckeck (OK). Hold PJSM on pressure deploying BHA Pressure Deploy BHA as per procedure. WHP at 470 psi While pressure deploying BHA (AKO 2.5 deg) at 450 psi, the BHA became stuck in the well head. The counter on the wireline machine is not working correctly and the correct position/depth of the BHA in the wellhead is difficult to determine at this time. Unable to closed MV and SV. Measured the distance and found it to be 35 ft, this places the bit at the top of the tubing hanger. Open well and after 1 bbl the well is flowing at 100 psi with 9.1 ppg fluid in the well. SWI, WHP increased to 350 psi which equates to 10.3 ppg. We presently have 240 bbl of 10.5 ppg brine KW F on location. Ordered vac truck from Kupuark to assist in fluid packing wellbore. Closed Annular and bled pressure down above annular. Phase 111 was called at CPF2 area by Kupuark Security. KW F truck and slick diesel truck on location on standby. Security took 2Z Pad on Phase II Fluid pack CT with 40 bbl of slick diesel. low flowrate due to plug in bung hole. Displace pump suction with water. Spot KW F vac truck. RU equalization line to lubricator. Hold planning meeting with Nordic, SLB, WSL leaders. Review plan steps, hazards, contingencies. Document same. Hold PJSM with all crew members. Discuss plan steps, roles, hazards. Equalize pressure across annular. (400 psi). Pump up packoff to 500 psi. Open annular. SITP: 395 psi. Begin pumping 10.5 brine down tubing. Formation taking fluid at 1750 psi, at 3.0 bpm. Monitor lubricator for leaks etc while circulating. 1505 psi at 3.0 bpm with 1 tubing volume (70 bbls) away. Pump 140 bbls. Bleed pressure off well. Monitor well for pressure /flow. Well flowing at 0.75 bpm with well open. Shut in well. WHP increased up to 455 psi and stabilzed. This is 60 psi higher than before killing well. Printed: 2/12/2007 10:14:15 AM • • gp Page 23 of 28 ~ Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours Task Code NPT ~ Phase 2/2/2007 22:30 - 00:00 I 1.501 STWHIP N STUC ~ PROD2 12/3/2007 00:00 - 00:15 0.25 STWHIP N STUC PROD2 00:15 - 01:15 1.00 STWHIP N STUC PROD2 01:15 - 03:00 1.75 STWHIP N DFAL PROD2 03:00 - 05:00 2.00 STWHIP N DFAL PROD2 05:00 - 06:15 125 STWHIP N DFAL PROD2 06:15 - 08:45 2.50 STWHIP N DPRB PROD2 08:45 - 09:00 0.25 STWHIP N DPRB PROD2 09:00 - 09:30 0.50 STWHIP N DPRB PROD2 09:30 - 09:50 0.33 STWHIP N DPRB PROD2 09:50-13:50 ~ 4.OO~STWHIP~P ~ ~PROD2 13:50 - 16:40 2.831 STWHIP P ~ PROD2 16:40-18:00 ~ 1.33~STWHIP~P ~ ~PROD2 18:00 - 20:30 I 2.501 STWHIPI P I I PROD2 20:30 - 22:15 1.75 STWHIP P PROD2 22:15 - 00:00 1.75 STWHIP P PROD2 12/4/2007 100:00 - 01:00 I 1.001 STWHIPI P I I PROD2 01:00 - 03:30 2.50 FISH I N DFAL PROD2 03:30 - 05:00 1.50 FISH N DFAL PROD2 05:00 - 06:30 I 1.501 FISH I N I DFAL I PROD2 Description of Operations SITP: 450 psi. Bleed 2.5 bbls. Shut in. Build up to 234 psi. Bleed 2.5 bbls. Build up to 165 psi. Shut in. Repeat several more times until WHP remains zero. Continue to bleed and monitor well. Very slight flow from well. Lift lubricator. Attempt to turn and lower BHA with pipe wrenchs. No downward progress. Pull BHA free with tugger. Re-run. No go. PU BHA. Grind edges off kick pad on motor. Grease bit & motor. Run in hole to no go. Continue to MU BHA using open hole procedure. Calibrate Inteq tools. Problems communicating with the EDC. Undeploy BHA. Lay down Inteq tools. Trouble shoot same on catwalk. Deployed BHA, well still static RIH to 200 ft, open EDC and displaced diesel out of CT to flow-pro. BHI's EDC ready in the Anchorage shop. BHI needs to setup to have it flow to the slope as soon as possible. Tie-in from 80000 ft down at 150 fph, Corrected -7 ft PUH working at regaining circulation with the 9.1 ppb mud Closed well in and shut EDC at 8,135 ft RIH and tagged the top of the AI billet at 82_74 ft MD. PUH 5 ft to start ST Start trough at 8,2_69 ft at 0.1 ft / 5 min at 90-96deg RTF Took W OB Op = 1.50 / 1.5 bpm w/ CTP of 2,800 / 3240 psi Density = 9.23 / 9.1 ppg BHP = 3407 psi at 11.02 ppg ECD. Backed reamed trough, then reamed trough 2nd time at 3min/ 0.1 o n Op = 1.50 / 1.55 bpm w/ CTP of 2,800 / 3295 psi Density = 9.27 / 9.12 pP9 BHP = 3660 psi at 11.84 ppg ECD. WHP = 153 psi ST off the AI billet top at 8273.9 ft w/ 90 R TF Op = 1.59 / 1.58 bpm w/ CTP of 2,800 / 3274 psi Density = 9.24 / 9.12 ppg BHP = 3660 psi at 11.83 ppg ECD. WHP = 190 psi Begin stacking a lot of weight at 8278'. 3-4.2k# DHWOB. Not making much progress. PU and RIH several times. Wear pad on motor may be hanging upon top of billet ? Working to bottom ok. WOB lower and able to get on btm. Drill to 8794'. Back ream from 8280 to 8270 two times each at 60R and 120 R. Dry drift. Hole and kick off area smooth. Open EDC. Circulate out of hole. 3000 psi at 1.75 bpm. Maintain WHP as per schedule. PJSM with crew in Ops Cab. Pressure undeploy sidetrack BHA. Inteq motor and float sub left in hole. 1-112" MT box looking up on fish. Saw no evidence of this while drilling and reaming. 1-1/2" MT pin on btm of HOT shows good threads and evidence of blue loctite. Call for Baker fishing hand and tools (motor with 1-1/2" MT pin down sub). PU Baker tools. PJSM. MU and pressure deploy fishing BHA. Found 460 psi on well. Run in hole. Follow WHP schedule. 300 psi inc in Pp at 769 ft while RIH Printed: 2/12/2007 10:14:15 AM • • gP Page 24 of 28 Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date I From - To I Hours I Task I Code ~ NPT ~ Phase 2/4/2007 06:30 - 07:00 07:00 - 07:25 07:25 - 09:15 09:15 - 15:45 0.50 FISH N 0.42 FISH N 1.83 FISH N 6.50 DRILL N DFAL IPROD2 DFAL PROD2 DFAL IPROD2 DFAL IPROD2 15:45 - 17:15 17:15 - 17:30 17:30 - 18:15 18:15 - 00:00 1.50 DRILL P 0.25 DRILL P 0.75 DRILL P 5.751 DRILL I P 2/5/2007 00:00 - 02:15 2.25 DRILL P 02:15 - 03:45 1.50 DRILL P 03:45 - 08:30 4.75 DRILL P 08:30 - 10:05 1.58 DRILL P 10:05 - 10:25 0.33 DRILL P 10:25 - 12:00 1.58 DRILL P 12:00 - 12:30 I 0.501 DRILL I P PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 Description of Operations Tie-in at 8000 ft. Corrected -7 ft RIH and tagged the top of the fish at 8,283 ft (bottom of fish at 8,294 ft TD) Inc. Op to 1.25 bpm, RIH, stalled motor 6 times at 8,283 ft. PUH and at 8120 ft open EDC POOH as per pressure schedule. Held PJSM in the Ops Cab while POOH. Spoke of possible Hazards and how to mitigate them safety. Tagged up, RIH 3.00 ft and trap 600 psi on wellhead Closed EDC and power down tool. Pressure undeploy BHA and fis? became stuck in the BOP. Worked several things and fish came free of BOP'. LD BHA and fishing tool. LD fish.. BHI RU Coiltrac and 2.5 AKO setting for build section. Grinding down wear pad on the next motor in the hole. Worked at getting the 2.5 AKO setting motor in the hole. Turned the wear pad to the inside of the AKO /bend and working the slickline to get BHA in the hole. Finally after 3 hrs, got the 2.5 deg motor in the hole. Finish pressure deploying the BHA in the hole. RIH with EDC open following pressure schedule Tied in and corrected -8 ft, closed EDC. RIH using correct TF at 8150 ft, 8183 and 8274 ft. Tagged at 8294 ft. BHP high with a low ECD. PUH working on the BHP numbers. Reboot computer. Mud thinning. Drill ahead. 3650 psi fs at 1.65 in/1.62 out. 300 dpsi. DHWOB: 1k#. WHP/BHP/ECD: 205/3746/12.07 ppg. IA/OA/PVT: 156/186/345 bbls. INC/AZM/TF: 53.2/186-187 / 15R. Drill ahead in build section. ROP: 40-60 fph. Getting 30 deg dog legs instead of the 45 planned. Not able to get a higher angle motor through BOPS based on deployment experience, so drill ahead. W III build to 105 deg to help get out of shale section as soon as possible. Drill ahead from 8420'. 3400 psi fs at 1.55 in/1.53 out. 200 dpsi. DHWOB: 4.3k#. WHP/BHP/ECD: 210/3744/11.97 ppg. IA/OA/PVT: 520/210/377 bbls. INC/AZM/TF: 97.5/205.9/15L. ROP: 10-20 fph. Complete build and turn. Projected inc at bit: 105 deg. Wiper trip to window. Open EDC. Circulate out of hole. Maintain WHP as per schedule. Hold PJSM in Ops Cab while POH. Pressure undeploy BHA. Chabged out BHA, crew change and PJSM on pressure deploying BHA RIH with EDC open j Tied-in a from 8,000 ft (Corrected -8.5 ft) RIH with correct TF. At 8,183 ft having trouble getting TF to 65 R. Got TF to 65R, RIH, MAD pass down from 8250 ft and checking survey points. Set down at 8,362 ft PU. RIH Having trouble getting in the hole at 8380 ft 70 ft into the A4 Shale. Working up through shales using low flowrates and slow running speeds. Set TF to 90L at 8,434 ft. WHP = 300 to 350 psi Tagged bottom, PUH and working way back to bottom after zeroing the BHI WOB. Final back on bottom, stalled Working to get back to bottom using negative CTW. Took 60 min to get back to bottom Finally on bottom but that not any improvement, TF at 90 L HS. Printed: 2/12/2007 10:14:15 AM • • gp Page 25 of 28 Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - To I Hours Task Code i NPT Phase Description of Operations 2/5/2007 12:00 - 12:30 0.50 DRILL P PROD2 Drilling at 3 fph Dri-ling up in A4 Shale. Op = 1.50 / 1.52 bpm Density = 9.24 / 9.20 ppg CTP 3,666 psi Vp = 350 bbls at 12:00 hrs WOB =negative CT weight (-2000 Ib). DHWOB = 1.5 - 2.5 klb BHP = 3,920 psi (12.53 ppg ECD) 12:30 - 13:00 0.50 DRILL P PROD2 Unable to drill, PUH to 8,350 ft. W/R back to bottom. 13:00 - 16:40 3.67 DRILL P PROD2 Drilling A4 Shale with 90-100L L TF PU hole at 8,466 ft and was able to get back to bottom wo/ much trouble. Turned TF down to 170E TF at 8,548 ft. Op = 1.58 / 1.54 bpm CTP = 3,790 psi Vp = 349 bbl at 13:00 hrs DHWOB = 2.65 klb. CTW / WOB = -3,600Ibf. BHP = 3,715 psi w/ EDC of 11.70 ppg 16:40 - 17:05 0.42 DRILL P PROD2 W ipoer trip to clean the hole and check the shale stability. Trip out of hole was clean to 8,280 ft RIH and tagged at 8,390 ft, PU and worked through with low flowrate. Set down at 8,460 ft PUH reduced Op. RIH and tagged bottom at 8,600 ft 17:05 - 19:00 1.92 DRILL P PROD2 Drilling A4 Sand with 170E TF. Op = 1,52 / 1.52 bpm CTP = 3,450 psi Vp = 350 bbl at 17:00 hrs DHWOB = 1.5 klb. CTW / WOB = 30001bf. BHP = 3,799 psi w/ EDC of 12.2 ppg 19:00 - 20:00 1.00 DRILL P PROD2 Wiper trip to window. Smooth out. Set down at 8400', 8450', 8490'. Got through with reduced pump rate. 20:00 - 22:00 2.00 DRILL P PROD2 Drill ahead. 3380 psi fs at 1.50 iN1.51 out. 200 dpsi. DHWOB: 1.5k#. WHP/BHP/ECD: 205/3900/12.35 ppg. IA/OA/PVT: 181/220/346 bbls. INC/AZM/TF: 92.8/159.1/808. ROP: 75- 125 fph. Continue to drill at +/- 94 deg inc. 22:00 - 23:30 1.50 DRILL P PROD2 Wiper trip to window. Log GR tie in. Add 2' correction. RIH. Sat down at 8480' and 8460'. Rreduce circ rate and get past ok. 23:30 - 00:00 0.50 DRILL P PROD2 Drill ahead from 8900'. 2/6/2007 00:00 - 01:15 1.25 DRILL P PROD2 Drill ahead. 3200 psi fs at 1.50 in/1.48 out. 250 dpsi. DHWOB: 0.75 - 1.5k#. WHP/BHP/ECD: 205/3766/12.17 ppg. IA/OA/PVT: 205/220/333 bbls. INC/AZMlTF: 96.4/181.7/1058. ROP: 50-100 fph. Drilling sand. 01:15 - 02:45 1.50 DRILL P PROD2 Wiper trip to window. Smooth in up direction. A few minor set downs from 8400' to 8500'. 02:45 - 05:00 2.25 DRILL P PROD2 Drill ahead from 9050'. LSRV at 30,000. Add flo vis to bring LSRV up to 35-40k. ROP slowing in shale section. I N ClAZM/TF: 90.8/197.3/ 165 R. 05:00 - 06:55 1.92 DRILL P PROD2 Drilling A4 Sand at 90 L TF Op = 1.55 / 1.51 bpm at CTP @ 3050 / 3655 psi BHP 3790 psi at 12.27 ppg ECD DHWOB = 1.50 to 2.0 klb. CTW 2700 Ibf 06:55 - 08:20 1.42 DRILL P PROD2 Wiper trip to base of Billet # 2 at 8274 ft Small set downs at 9030 ft and 9150 ft. Used low flow rates to get through trouble shale 08:20 - 10:15 1.92 DRILL P PROD2 Drilling A4 Sand at 90-105 L TF Printed: 2/12/2007 10:14:15 AM • • gp Page 26 of 28 Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase 2/6!2007 08:20 - 10:15 1.92 DRILL P PROD2 10:15 - 14:45 4.50 DRILL P PROD2 14:45 - 15:30 0.75 DRILL P PROD2 15:30 - 19:00 3.50 DRILL P PROD2 19:00 - 20:00 1.00 DRILL P PROD2 20:00 - 21:15 1.25 DRILL P PROD2 21:15 - 21:40 0.42 DRILL P PROD2 21:40 - 22:25 0.75 DRILL P PROD2 22:25 - 23:00 0.58 DRILL P PROD2 23:00 - 00:00 1.00 DRILL P PROD2 2/7/2007 00:00 - 00:30 0.50 DRILL P PROD2 00:30 - 01:15 0.75 DRILL P PROD2 01:15 - 01:30 0.25 CASE P RUNPRD 01:30 - 02:00 0.50 CASE P RUNPRD 02:00 - 06:30 4.50 CASE P RUNPRD Description of Operations i Op = 1.55 / 1.51 bpm at CTP @ 3,050 / 3,655 psi BHP 3790 psi at 12.16 ppg ECD DHWOB = 0.50 to 2.0 klb. CTW 3,200 Ibf Constant ROP of 60-65 fph to 9,244 ft Tagged possible fault at 9,244 ft ROP doppped down to 7 fph Possibel ankerite) Drilling A4 Sand at 150 L TF Op = 1.55 / 1.51 bpm at CTP @ 3,050 / 3,655 psi BHP 3790 psi at 12.16 ppg ECD DHWOB = 0.50 to 2.0 klb. CTW 3,200 Ibf Turned TF to 150 L to get out of ankerite and then will level out in sand at 88 deg Started mud swap at 1255 hrs at 9,273 ft Drilling A4 Sand at 90 L NBI at 86 deg After drill through the ankerite, made 100 ft wiper trip. OK Op = 1.55 / 1.51 bpm at CTP @ 3,050 / 3,655 psi BHP 3790 psi at 12.16 ppg ECD DHWOB = 0.50 to 2.0 klb. CTW 3,200 Ibf Finally drilled through the ankerite at 9283 ft ROP increased from 5 fpm to 87 fph. Wiper trip to window. Got hung up at 8370'. Worked pipe and pull to 48k# to get free. Ream and back ream. Continue with wiper. Several other shale spots. Set down, reduce pump rate, then run in hole ok. Set down at 9038'. Work past. Continue in hole. Having trouble getting past 9080'. Reduce pump rate and WHP from 300 to 200 psi. Work to bottom. Orienter has locked up. Repower. re-boot, try all surface options. Orienter still not working. Call Town Team to discuss. Call TD. Mix 70 bbl bead pill while continue slow wiper._ RBIH two 9w350~ POOH from TD while perform 30'/min wiper back to window while leaving 2 ppb beads in open hole 1.43/3000 w/ 200 psi whp. Had 10k overpull w/ MW at 8375', and couldn't go back in hole. Pull free at 58k w/ red pump rate. Continue wiper to window seeing other shales. Pull thru window, open EDC. Resume circ 1.55/2670 w/ 200 psi whp Log tie-in down from 8000'. Corr +5' (this will not change 'official' TD) Park w/ EDC at 8100' and circ 1.56/2670 w/ 200 psi whp while wo vac truck to deliver KW F Start 10.6 ppg brine down CT 1.58/2500 to displace 9.1 ppg mud POOH for liner while fin displace wellbore to 10.6 ppg brine Finish POOH w/drilling assy while fin displace wellbore to 10.6 ppg brine. Flow check, dead LD drilling BHA. Bit was 1-1-I. The bottom section of the BHI HOT had seperated -3" at an assumed internal keeper-got lucky in not leaving a fish Safety mtg re: liner RU floor tools to run liner. Perform kick drill w/ safety jt MU Unique Indexing Guide shoe + BTT O-ring sub on 30 slotted and 7 solid joints of 2-3/8" 4.44# L-80 STL liner (1209'). Install false table. Run CSH from derrick. MU singles and Printed: 2/12/2007 10:14:15 AM • i gp Page 27 of 28 ~ Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Date: 1/3/2007 Event Name: REENTER+COMPLETE Start: ~ 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/7/2007 02:00 - 06:30 4.50 CASE P 06:30 - 07:15 0.75 CASE P 07:15 - 14:30 I 7.25 I CASE I P 14:30 - 15:00 I 0.50 I CASE I P 15:00 - 16:30 I 1.501 CASE I P 16:30 - 16:45 0.25 CASE P 16:45 - 18:45 2.00 CASE P 18:45 - 19:30 ~ 0.75 ~ RIGD. ~ P 19:30 - 21:00 I 1.501 RIGD I P 21:00 - 22:45 I 1.751 RIGD I P 22:45 - 23:20 0.58 RIGD P 23:20 - 00:00 0.67 RIGD P 2/8/2007 00:00 - 00:45 0.75 RIGD P 00:45 - 03:00 2.25 RIGD P 03:00 - 04:00 I 1.001 BOPSUR P 04:00 - 04:45 0.75 BOPSUFj P 04:45 - 05:45 1.00 BOPSU P RUNPRD space out with pups. RUNPRD MU Inteq MWD tools. Stab coil. Get on well. Circulate to get air out of BHA before running in hole. RUNPRD Run in hole with liner assy. Getting gas and crude back. Circulate to try and clean up rtns. Weight check: 30K # up, 10k# do at 8000'. Run in open hole. Set down at 9092'. PU and makes several runs at it. Break circulation and make several runs, slow and fast. Pressure well to 300 psi. Make sevaeral attempts. Pressure well to 500 psi. Make several more attempts. Pressure up coil and well to 450 psi. Dump pressure quickly and run in hole. No progess. Wait on decisionfrom Town Team to release. Consider possible trip for orientor/agitator, but BTT indicates low probability of reentering splined deployment sub and risk of breaking off a spline RUNPRD Release from jOL at 7880'. Liner bottom at 9092'. Pult CSH to 8149'. Circulate 10.5 ppg KW F back to surface holding 300 psi W HP to re-kill well. RUNPRD Circulate out of hole holding 300 psi WHP. Get 10.5 ppg brine back to surface. Hold PJSM before tagging up. RUNPRD Bleed off WHP. Monitor well for flow. RUNPRD Get off well. Unstab coil. LD BHA tools. Stand back CSH in derrick. Load out CTLRT and false table. MU 2.25" nozzle assy. Stab onto well POST Oncoming crew found a leak at SWS pressure bulkhead. Safety mtg. Tighten and PT at 3000 psi POST RIH w/ nozzle assy while circ KWF 0.551300. Swap to SW, incr rate 1.6/3000 and take returns to tiger tank while RIH. Got gas and crude back to surface by 7200'. Continue to circ 1.6/3050 w/ 300 psi whp and took 80 bbls of gas/crude cut KW F before returns were clean SW while parked at 7850' POST POOH white circ SW getting good SW returns back and following pressure schedule. Swap to diesel while POOH to FP the top 2500' of wellbore. Tag up, close swab and master valves SITP 640, IA 20, OA 200 POST Circ over swab while MIRU SWS N2 Safety mtg re: N2 POST Pump 10 bbls McOH followed by N2 and blow down reel POST Finish reel blowdown and bleed off to tiger tank POST LD BHA. Cut off CTC. Install internal grapple. Pull CT back to reel and secure, Set injector on legs and prep for move POST Begin ND BOPE (since Kuparuk valve shop won't set BPV thru rig GOP's). However, determine that stack is too high to use bridge crane to move BOP's out of the way. Then, Kuparuk valve shop determines they can set a BPV thru rig BOP's. NU ROPE. Find diesel leak on wellhead at flange below MV. Tighten all nuts and avg 3/4 turn each POST Fin clean pits, vac and supersuck cuttings box while wo valve crew to bring lubricator and extensions to BPV POST RU Kuparuk BPV crew w/ 24' of extensions and HP lubricator w/ 3" FMC BPV. PT lub at 650 psi. Open tree valves to 550 psi whp. Set BPV and PT from below w/ whp. Secure tree Printed: 2/12/2007 10:14:15 AM • gp Page 28 of 28 ~ Operations Summary Report Legal Well Name: 2Z-13 Common Well Name: 2Z-13 Spud Dater 113!2007 Event Name: REENTER+COMPLETE Start: ~ 1/10/2007 End: 2/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 2/8/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/8/2007 04:45 - 05:45 1.00 BOPSU P POST valves. RDMO Kuparuk BPV crew 05:45 - 10:30 4.75 BOPSU P POST ND BOPE. NU tree cap. Fill tree with diesel. Pressure test treee cap to 5000 psi. Continue to prep for move. Load out trailers, extra liner, misc equipment. Release tanks and hard line. Release rig at 1030 hrs on 2/8/07. Printed: 2/1?J2007 10:14:15 AM ~„ by ~ BP Alaska Baker Hu hes INTE Surve Re ort g Q Y P ~.~ '~.. u ~.,~ Company: BP Amoco Date: 2/15/2007 Time: 08:34:34 Page: 1 Field: Kuparuk Co-ordinate(NE) Reference: Well: 13, True North Site: KRU 2Z Pad Vertical (TVD) Reference: 2Z Orig Datum1 109.0 Nell: 13 Section (VS) Reference: Well (O.OON,O.OOE,188.96Azi) Wellpath: 2Z-13A Survey Calculation Method: Minimum Curvature Db: Oracie ~ Field: Kuparuk Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2006 Site: KRU 2Z Pad Site Position: Northing: 5964759.45 ft Latitude: 70 18 53.244 N From: Map Easting: 529716.16 ft Longitude: 149 45 32.972 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.23 deg Well: 13 Slot Name: Well Position: +N/-S 1131.45 ft Northing: 5965889.81 ft Latitude: 70 19 4.372 N +E/-W -244.55 ft Easting : 529467.16 ft Longitude: 149 45 40.107 W Position Uncertainty: 0.00 ft Wellpath: 2Z-13A Drilled From: 2Z-13 Tie-on Depth: 8100.00 ft Current Datum: 2Z Orig Datuml Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 12/14/2006 Declination: 23.59 deg Field Strength: 57609 nT Mag Dip Angle: 80.82 deg Vertical Section: Depth From ('I'VD) +N/-S +E/-W Direction ft ft ft deg 109.00 0.00 0.00 188.96 Survey Program for Definitive Wellpath Date: 1/22/2007 Validated: No Version: 9 Actual From To Survey Toolcode Tool Name ft ft 0.00 8100.00 Gyro (0.00-8525.00) (0) GCT-MS Schlumberger GCT mukishot 8150.70 9300.00 MWD (8150.70-9300.00) MWD MWD -Standard Annotation MD TVA ft ft 8100.00 5973.78 TIP 8150.70 6009.94 KOP 9300.00 6089.10 TD Survey: MWD Start Date: 1/19/2007 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD lncl Azim TVD Sys TVD N/S E/N MapN MapE ft deg deg ft ft ft ft ft ft 8100.00 44.00 188.37 5973.78 5864.78 -4924.16 -1095.13 5960961.88 528391.47 8150.70 44.98 188.35 6009.94 5900.94 -4959.31 -1100.30 5960926.71 528386.44 8181.73 61.13 170.31 6028.63 5919.63 -4983.85 -1099.60 5960902.18 .528387.24 8209.77 68.04 156.18 6040.71 5931.71 -5007.97 -1092.24 5960878:09 528394.69 8240.47 68.10 143.05 6052.22 5943.22 -5032.47 -1077.88 5960853.65 528409.15 8266.12 69.24 133.53 6061.56 5952.56 -5050.27 -1062.00 5960835.91 528425.10 8297.35 70.70 112.36 6072.37 5963.37 -5066.10 -1037.53 5960820.18 528449.62 8330.90 79.33 98.22 6081.08 5972.08 -5074.53 -1006.37 5960811.87 528480.82 8358.14 88.66 89.43 6083.93 5974.93 -5076.32 -979.40 5960810.19 528507.79 8412.46 86.48 70.75 6086.25 5977.25 -5067.03 -926.17 .5960819.69 528560.97 8441.47 87.34 67.02 6087.82 5978.82 -5056.59 -899.16 5960830.23 528587.95 VS DLS Tool ft deg/100ft 5034.64 0.00 MWD 5070.17 1.93 MWD 5094.29 69.44 MWD 5116.98 51.70 MWD 5138.94 39.66 MWD 5154.05 34.85 MWD 5165.87 63.81 MWD 5169.35 48.11 MWD 5166.91 46.91 MWD 5149.45 34.59 MWD 5134.93 13.18 MWD a~ ~- r`t~ . by ~ BP Alaska Baker Hu hes INTE Surve Re ort g Q Y P iNTEQ Company: BP Amoco Date: 2/15!20 07 Tim e: 08:34:34 Page: 2 Field: Ku paruk Co-or dinate(NE) Reference: Well: 13, True North Site: KR U 2Z Pad Vertical (TAD) Reference: 2Z Orig Datum! 109.0 Well: 13 Sectio n (VS) Ref erence: Well (O.OON,O. OOE,188.96 Azi) Wellpath: 2Z- 13A Surve y Calculati on Method: Minimum Curv ature Db: Oracle Survey IND lncl Azim TVll Sys TVD NlS E1W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 8470.00 86.60 62.96 6089.33 5980.33 -5044.55 -873.34 5960842.37 528613.71 5119.02 14.45 MWD 8503.34 87.71 58.20 6090.98 5981.98 -5028.20 -844.35 5960858.83 528642.64 5098.35 14.64 MWD 8534.06 88.91 55.94 6091.89 5982.89 -5011.51 -818.58 5960875.62 528668.34 5077.84 8.33 MWD 8565.49 88.36 54.92 6092.64 5983.64 -4993.68 -792.70 5960893.55 528694.14 5056.20 3.69 MWD 8595.92 86.57 52.53 6093.98 5984.98 -4975.70 -768.20 5960911.63 528718.57 5034.62 9.81 MWD 8632.86 85.74 48.66 6096.46 5987.46 -4952.30 -739.72 5960935.13 528746.95 5007.08 10.69 MWD 8675.01 85.00 42.44 6099.87 5990.87 -4922.90 -709.75 5960964.65 528776.81 4973.36 14.81 MWD 8708.34 84.82 37.55 6102.82 5993.82 -4897.47 -688.42 5960990.16 528798.04 4944.93 14.62 MWD 8743.19 86.11 31.90 6105.58 5996.58 -4868.93 -668.64 5961018.77 528817.71 4913.65 16.58 MWD 8782.98 86.97 26.76 6107.99 5998.99 -4834.32 -649.19 5961053.46 528837.02 4876.43 13.07 MWD 8816.27 90.51 23.66 6108.72 5999.72 -4804.21 -635.02 5961083.62 528851.07 4844.49 14.13 MWD 8847.53 91.71 20.19 6108.11 5999.11 -4775.22 -623.35 5961112.65 528862.62 4814.03 11.74 MWD 888020 90.94 16.66 6107.36 5998.36 -4744.24 -613.03 5961143.67 528872.82 4781.82 11.06 MWD 8909.20 90.60 12.39 6106.97 5997.97 -4716.18 -605.76 5961171.76 528879.98 4752.97 14.77 MWD 8944.37 91.24 6.72 6106.40 5997.40 -4681.52 -599.92. 5961206.44 528885.68 4717.82 16.22 MWD 8974.80 91.86 4.16 6105.58 5996.58 -4651.24 -597.04 5961236.73 528888.44 4687.46 8.65 MWD 9004.43 93.84 1.33 6104.10 5995.10 -4621.68 -595.62 5961266.28 528889.74 4658.05 11.65 MWD 9036.07 95.12 357.58 6101.63 5992.63 -4590.15 -595.92 5961297.81 528889.32 4626.94 12.49 MWD 9066.88 94.60 353.68 6099.02 5990.02 -4559.54 -598.26 5961328.41 528886.86 4597.08 12.73 MWD 9098.69 92.72 348.71 6096.99 5987.99 -4528.18 -603.12 5961359.74 528881.88 4566.86 16.67 MWD 9129.94 91.95 344.52 6095.72 5986.72 -4497.81 -610.34 5961390.08 528874.53 4537.98 13.62 MWD 9163.36 90.85 338.97 6094.90 5985.90 -4466.10 -620.81 5961421.75 528863.95 4508.29 16.92 MWD 9192.57 91.92 335.51 6094.19 5985.19 -4439.18 -632.10 5961448.63 528852.55 4483.45 12.40 MWD 9221.57 92.32 332.10 6093.12 5984.12 -4413.18 -644.89 5961474.57 528839.66 4459.76 11.83 MWD 9252.07 93.09 328.11 6091.68 5982.68 -4386.77 -660.07 5961500.92 528824.38 4436.04 13.31 MWD 9300.00 93.09 328.11 6089.10 5980.10 -4346.13 -685.36 5961541.45 528798.93 4399.84 0.00 MWD 11/09/04 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: ,~ir~..~f'g~ z+~~r~i~3_si_~fc_~>t_ c~L~~~...i~...~~tEi~i1E?£?.. x3c:4~t`~~~cEC~.'T?ii~.:~~c~F'.c$~4.EeS b~)~;..'£?~.~E`f1S~£3E{t ~~Li!F~"EE~3.S~c~'~f.~K_~f4 Contractor: Nordic Rig No.: 2 DATE: 1/24/07 Rig Rep.: Wedin/Lancaster Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Sarber/ Hildreth E-Mails~~~c~~~,s~rlcrt_~:~3c~~c?~~~?~S~E~E_~~~7.~_~_3 Well Name: 2Z-13A PTD # 206-170 Operation: Drlg: XXX Workover: Explor.: Test: Initial: Weekly: Bi-Weekly XXX Test Pressure: Rams: 250-4000 Annular: 250-2500 Valves: 250-4000 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NA Housekeeping: P Drl. Rig P Lower Kelly NA PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Inside BOP NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind /Shear P Flow Indicator P P #2 Rams 1 2" combi's P Meth Gas Detector P P #3 Rams 1 2 3/8"combi's P H2S Gas Detector P P #4 Rams 1 2" Combi's P #5 Rams N/A NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 1 NT HCR Valves 2 3 1/8" P Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve 2 2 1/16" P Time/Pressure Test Result System Pressure 2900 P CHOKE MANIFOLD: Pressure After Closure 2300 P Quantity Test Result 200 psi Attained 18sec P No. Valves 14 P Full Pressure Attained 56sec P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 2100 Test Results Number of Failures: 0 Test Time: 7 Hours Components tested 29 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervises at: ,E3E'3,..Cf'g~~ i~~r~i~3_st~tt__~>t, Remarks: Inner Reel Valve test was waived by state rep. Relay for Methane alarm light was changed out and was tested and is fully functional. H2S head at shaker was changed and calibrated and is fully functional. Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES X)OC NO c - Oper./Rig Waived By c -Database Date 1/23/07 Time 0900 c -Trip Rpt File Witness Lou Grimaldi c -Inspector Test start 0730 Finish 1430 Coil Tubing BFL 11/09/04 Nordic 2 BOP 1-24-07.x1s 11/09/04 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BO PE Test Report Submit to: .13f"3_..rE'r~~t~r~it3_s~~tc ~~c.u c~C:C~~.~~~...~:'t.E~~~E?£'.., i3r'+O~~~fE~~`?71EE1.'t~~..~~,'.celE.Ee~i ~3f,i",.. ~~?v~E't~S~£??f~ ~ ~t~£~';i~3..S~~k f. ~X_i~ . Contractor: Nordic Rig No.: 2 DATE: 1!11/07 Rig Rep.: Sloan /Cook Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Sevcik/ Hildreth E-Mail ~~~c7c~~~sc~rl~rE~7_~3f'h~L?L~~~?LES~3€`E,r3ri1~i7~)_f_~.I Well Name: 2Z-13A PTD # 206-170 Operation: Drlg: XXX Workover: Explor.: Test: Initial: XXX Weekly: Bi-Weekly Test Pressure: Rams: 250-4000 Annular: 250-3500 Valves: 250-4000 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NA Housekeeping: P Drl. Rig P Lower Kelly NA PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Inside BOP NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind /Shear P Flow Indicator P P #2 Rams 1 2" combi's P Meth Gas Detector P P #3 Rams 1 2 3/8"combi's P H2S Gas Detector P P #4 Rams 1 2" Combi's P #5 Rams N/A NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 1 P HCR Valves 2 3 1/8" P Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve 2 2 1/16" P Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 2100 P Quantity Test Result 200 psi Attained 16 sec P No. Valves 14 P Full Pressure Attained 1 min/20sec P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 2100 Test Results Number of Failures: 0 Test Time: 7 Hours Components tested 30 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at ,l~E"3...rE~r~;~;~~~rti;3_st~tf_~>c_u Remarks: Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES XXX NO c - Oper./Rig Waived By John Crisp c-Database Date 1/10/07 Time 1200 c -Trip Rpt File Witness c -Inspector Test start 0000 Finish 0700 Coil Tubing BFL 11/09/04 Nordic 2 BOP 1-11-07.x1s ~\~"J?j i< ;/;-~'1 ;IIIIII~ !: 1:~~1 ~'~ Ti~1~~(t~;~}A!y>~~3~ ~~~j)`~~t ,~ ALASKA OIL AND GAS ;~~ CONSERVATION COMMISSION ~~ Aras Worthington CT Drilling Engineer ConocoPhillips Alaska, Inc. c/o PO Box 196612 Anchorage, AK 99519-6612 SARAH PAUN, GOVERNOR 333 W. 7`h AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-75423 Re: Kuparuk River Field, Kuparuk River Oil Pool, Kuparuk 2Z-13A ConocoPhillips Alaska, Inc. Permit No: 206-170 Surface Location: 1131' FSL, 244' FEL, SEC. 11, T11N, R09E, UM Bottomhole Location: 1404' FNL, 1263' FEL, SEC. 14, T11N, R09E, UM Dear Mr. Worthington: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the. Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's. petroleum field inspector at (907) 6y5~-3607 (pager). Chairman DATED this ~O day of December, 2006 cc: Department of Fish & Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. ~~~iv~® STATE OF ALASKA ~~C OIL AND GAS CONSERVATION COMMI~N Alaska Oil & Gas Cons. Cotnmissio'h ERMIT TO DRILL 20 AAC 25.005 ~'~(~y 1 a. Type of work ^ Drill ®Redrill - ^ Re-Entry 1 b. urren I Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 ' 11. Well Name and Number: Kuparuk 2Z-13A- 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11350 ' TVD 6013ss - 12. Field /Pool(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Governmental Section): Surface: 244' FEL 1131' FSL 11 T11N R09E UM ' SEC 7. Property Designation: ADL 025653 ~ River Pool , , , , . , Top of Productive Horizon: 3731' FNL, 1353' FEL, SEC. 14, T11 N, R09E, UM 8. Land Use Permit: 13. Approximate Spud Date: December 25,2006 Total Depth: 1404' FNL, 1263' FEL, SEC. 14, T11 N, R09E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 25,600' 4b. Location of Well (State Base Plane Coordinates): Surface: x-529467 - y-5965890 ~ Zone-ASP4 10. KB Elevation (Height above GL): 109' feet 15. Distance to Nearest Well within Pool: 500' 16. Deviated Wells: Kickoff Depth: 8185 ~ feet Maximum Hole An le: 95 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2616 ' Surface: 2026 18. C in P ra To - Se in De th -Bottom uan i of ment c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 2-3/8" 4.6# L-80 STL 3100' 8250' 5970' 11350' 6013' Uncem nted Slotted Liner 19. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 8525 Total Depth TVD (ft): Plugs (measured): 6261 None Effective Depth MD (ft): 8424 Effective Depth TVD (ft): 6195 Junk (measured): 8297 asrng Length ize Cement Volume - D Conductor /Structural 102' 16" 2 sx Permafro 102' 10 ' Surface 4203' 9-5/8" 11 0 sx C Idset III 45 sx C II 4203' 360' Intermediate Pro i n 8507' 7" 37 s Cla s ' 180 sx PF ' 85 7' 6249' Liner Perforation Depth MD (ft): 8010' - 8285' Perforation Depth TVD (ft): 5908' - 6103' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Aras Worthington, 564-4102 Printed Name Aras orthington Title CT Drilling Engineer Prepared By NameMumber: Si nature ~- ~ "Phone 564-4102 Date Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Num er: - / API Number: 50-029-21360-01-00 Permit Approval Date: See cover letter for oth rre it m nts Conditions of Approval: ~~yy~~..~~;;~~ {~ !~If boxlis checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained shales: ~WV 71 ~JO~G '~iT GlS ~Ut~i~`~ , ,_,/ ,_,/ Q ~' Samples Req'd: ^ Yes 1J No Mud Log Req'd: ^ Yes L!1 No ~l-~Cr~Kti~ 13`~~ a~Pros~~ ~OP~C.~-S~3 ~~~~ HZS Measures: ^ N rectional Survey Req'd: ['Yes ^ No Other: APPROVED BY THE COMMISSION Date ~p~ ~,r~ • Q ,COMMISSIONER Form 10-401 Revised 12/2005 ' Submit In Duplicate ~ ~ ~ ~~~ ~`~~ t2•l3•~ ~~/~~~ KRU 2Z-13A & AL1 Sidetrack -Coiled Ting Drilling Summary of Operations: A coiled tubing drilling unit will drill two laterals in KRU 2Z-13 using the managed pressure drilling technique (MPD, see description below). 2Z-13A and 2Z-13AL1 horizontal laterals will target Kuparuk A4 sand reserves for production. ' CTD Drill and Complete 2Z-13A & ALl: Planned for December 25.2006 Pre-Rid Work 1. S Obtain pressure data (SBHPS) from A&C sand reservoirs via tbg-tail plug 2. S DGLVS, pull Station #9 (production valve) 3. DHD MIT-IA and OA 4. E Shoot holes in tbg tail w/ tbg puncher, 10' interval (8165' - 8175') 5. C or F Pump CaC03 pill into C-sands through straddle to plug off C-sand 6. S Tag Top of CaC03 and correct depth to RKB 7. C FCO through CaC03 plug & PT/drawdown test to see if plug holds 8. C Cement P&A 9. O PT cement plug to 500 psi `Z ~ ~ -- ~ ~ ( 10. S ~ ~ Tag TOC 11. DHD PT Master & Swab to 4500 psi (Done, passed, 11/5/2006) 12. DHD Drawdown test on Master & Swab to 0 psi (Done, passed, 11/5/2006) 13. S Drift & tag to PBTD 14. O Torque wellhead flange-bolts to spec. 15. O Set BPV. Bleed OAP and IAP to 0 psi 16. O Bleed gas lift and production flowlines down to zero and blind flange 17. O Remove wellhouse, drill mouse hole, level pad Rie Work 1. MIRU Nordic 2. NU 7-1/16" BOPE, test ~ ~``? ~ ~~~`-%-~- 2. Mill 2.74" window off of cement plug. The planned KOP is at 8185' in the B shale. 3. Drill northern 3" bicenter hole horizontal lateral (2Z-13A) from window to 11,350' TD targeting Kuparuk A4 sands. ~`w, ~1~ ---~ Note: If ankerite layer is thick, may add a lateral above the ankerite rather than undulate through the ankerite. ~ 4. Kill well & com lete with 2 3/8" slotted liner and Aluminum kick-offbillet from TD to 8250' md. ~`~,`' ~°cr`'~ m 2Z-13A @ 8250' MD and drill southern 3" bicenter hole horizontal lateral (2Z-13AL1) from window to 10,250' TD targe A4 sands. Note: If ankerite layer is thic teral above the ankerite rather than undulate through the ankerite. 6. Kill well & complete with 2 3/8" slotted liner from TD to or ~'2. , _..__ Post RiQ work 8. Post CTD rig -Run GLVs. Mud Program: • Step 1-3 & 5: chloride-based flo-pro (8.6 ppg} • Steps 4 & 6: chloride-based brine or flo-pro (8.8 ppg) ' Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 2Z-13A: 2 3/8", 4.6#, L-80, STL o Slotted liner from 8,250' and -11,350' and w/ Aluminum billet top • 2Z-13AL1: 2 3/8", 4.6#, L-80, STL o Slotted liner from 8160' and - 10,250' and KRU 2Z-13A & AL1 Sidetrack -Coiled Tubing Drilling Casing/Liner Information 9 5/8", J-55, 36#, Burst 3520; collapse 2020 psi. 7", J-55, 26#, Burst 4980; collapse 4320 psi 3-1/2", J-55, 9.3#, Burst 6980; collapse 7400 psi Well Control: • Two well bore volumes 0250 bbls) of KWF will mixed and in the Kuparuk field during drilling operations. • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4000 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan for 2Z-13A and 2Z-13AL1. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. ' • The nearest well to 2Z-13A is 2Z-O1 which is offset by 500'. The KPA boundary is 25,600' away. ' • The nearest well to 2Z-13AL1 is 2D-03 which is offset by 750'. The KPA boundary is 24,700' away. - Logging • MWD directional, Gamma Ray, and resistivity will be run over all of the open hole section. Hazards 2Z-13A and 2Z-13AL1 laterals will cross several mapped faults. Lost circulation risk is moderate. Well 2Z-13 has an H2S level of 50 ppm. All H2S monitoring equipment will be operational. -` Reservoir Pressure • The most recent SBHP survey (11-15-06) was gauged at 2616 psi after a short term shut-in. The EMW is 8.6 ppg at 5900' TVD. Max. surface pressure with gas (0.1 psi/ft} to surface is 2026 psi. - Variance request • BPXA requests a variance to the provisions of 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION. This is regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes. The variance will not apply when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) While drilling 2Z-13A and 2Z-13AL1 it will be routine to close the 2" combi rams (pipe/slip) on the BHA during deployment and undeployment. These activities will not compromise the integrity of the BOP equipment. Managed Pressure Drilling Managed pressure drilling techniques will be employed to provide constant bottom hole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant ~ BHP will be utilized to reduce pressure fluctuations to help with hole stability_ Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPS choke. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe/slips (2" rams, see attached BOP configuration). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at the 2Z-13A and 2Z- 13AL1 at TD: KRU 2Z-13A & AL1 Sidetrack -Coiled Tubin Drillin 9 9 • Estimated reservoir pressure: 2600 psi at 5900' TVD, 8.6 ppg EMW. ' • Expected annular friction losses while circulating: 740 psi (based on 90 psi/1000 ft) • Planned mud density: 8.6 ppg equates to 2640 psi hydrostatic bottom hole pressure. ' • While circulating 8.6 ppg fluid, bottom hole circulating pressure is estimated to be 3380 psi or 11.0 ppg ECD • When circulation is stopped, a minimum of 740 psi surface pressure will be applied to maintain constant BHP. KRU 2Z-13 CTD Sidetrack A4-sand CTD Completion Total Proposed Footage = 6000' 9-5/8" shoe C-sand perfs (isolated w/ CaCO3 and/or cement) Leak in straddle @ 8082' RKB 2-3/8" liner top @ 8160' Wrxlow in T' 26# J55 1000' 2Z-13AL2 north lateral (contingency~y~ r ankerite "'"", ~O~- 1.`Z~ ~~ ~~N~~ ~~M~r ~~M~~ ~~~M~~~~~~~~~~~~N~~ fiD @ 11350' and (agitator limit 300# wob) liner Optional ~ Aluminum billet (ankerite contingency) A5 sand perfs G. 3-'/2" SSSV set at 1820' (locked out) F. 3-1/2" 9.3# J-55 EUE 8rd Mod tubing w/ 3-1/2" x 1"gas lift mandrels E. 3-'/2° x 7" packer at 7849' D. 3-1 /2" production mandrels C. 3?/s" x 7" packer at 8151' B. 3-'/z" nipple with 2.75" ID at 8167' A. 3-1/2" tubing tail at 8175' Cement KOP at 8185' MD ~ ~ ~ ~ ~ ~~I a A4 sar perfs 7" shoe ~' ~:~:~:~:~:~:~:~:~:~:~ Aluminum billet @ 8250' ~ and ---- - - ------ 2-3/8" slotted liner Optional Aluminum billet (ankerite • 2Z-13AL1 sou lateral, TD @ 1 1000' 2Z-13AL3 south lateral (contingency for ankerite) ConocoPhillips Alaska, Inc. 2Z-13 API: 500292136000 sssv SSSV Type: LOCKED OUT (1820-1821, OD:3.500) Annular Fluid: KRU Angle @ TD: 2Z-13 I Anin - Rn60 I 590A - 5944 IC-4.C-2.C-11 150 112 17/15/1985 I IPERF 15 1/2" Schlumberger Type ~ V Mfr ~ V Type ~ V OD ~ Latch PBR (7836-7837, OD:3.500) PKR (7849-7850, OD:6.151) Fish - General Notes on V Type ~ V OD ~ Latch ~ Port 7' (WLM) (10/10/97) ator Bent Over -SEE PKR (8151-8152, OD:6.151) NIP (8167-8168, OD:3.500) TUBING (0-8175, OD:3.500, ID:2.992) Perf (8228-8238) Perf (8255-8285) Vlv V • C~ ~p BP Alaska Baker Hughes INTEQ Planning Report 1NTE Q Compaay: BP Amoco Date; 11/30/2006 Time: 10:33:47 Page: i Freldr Kuparuk Co-ordinate(NE) Reference: Well: 13, True North Site: 'KRU 2Z Pad Vertical (TVD) Reference: 2Z-13 109.0 Well: 13 Section (VS) Reference; Well (O.OON,O.OOE,359. OOAzi) Wellpaths . Plan 3 2Z-13A Sarvey Calculation Method: Minimum Curvature Db: OraGe Fteid: Kuparuk Map System:US State Plane Coordinate System 1927 Map Zoae: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Site: KRU 22 Pad Site Position: Northiug: 5964759 .45 ft Latitude: 70 18 53.244 N From: Map Eastiug: 529716 .16 ft Longitude: 149 45 32.972 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.23 deg Well: 13 Slot Name: Well Position: +N/-S 1131.45 ft Northing: 5965889 .81 ft ~ Latitude: 70 19 4.372 N +E/-W -244.55 ft Easting : 529467 .16 ft /Longitude: 149 45 40.107 W Positron Uncertainty: 0.00 ft Welipath: Plan 3, 2Z-13A DrDled From: 2Z-13 Tie-on Depth: 8100.00 ft Current Datum: 2Z-13 Height 109 .00 ft Above System Datum: Mean Sea Level Magnetic Data: 11/30/2006 Declination: 23.61 deg Field Strength: 57608 nT Mag Dip Angle: 80.82 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 109.00 0.00 0.00 359.00 Plan: Plan #3 Date Composed: 11 /30/2006 Copy Lamars plan 3 Version: 4 Principal: Yes Tied-to: From: Definitive Path Targets Map Map ~-- Latitude --> <- Longitude --> Name Deseript~n TVD +N/-S +E/-W Northing Eastins Deg ;Miu Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 2Z-13A Polygon 109.00 -5213.68 -1449.78 5960671.00 528038.00 70 18 13.094 N 149 46 22.380 W -Polygon 1 109.00 -5213.68 -1449.78 5960671.00 528038.00 70 18 13.094 N 149 46 22.380 W -Polygon 2 109.00 -5331.07 -587.15 5960557.00 528901.00 70 18 11.941 N 149 45 57.227 W -Polygon 3 109.00 -4661.94 -348.49 5961227.00 529137.00 70 18 18.522 N 149 45 50.270 W -Polygon 4 109.00 -3832.46 -702.28 5962055.00 528780.00 70 18 26.679 N 149 46 0.588 W -Polygon 5 109.00 -2567.81 -833.33 5963319.00 528644.00 70 18 39.117 N 149 46 4.414 W -Poygon 6 109.00 -2530.02 -1289.23 5963355.00 528188.00 70 18 39.488 N 149 46 17.712 W -Polygon 7 109.00 -5177.84 -1407.63 5960707.00 528080.00 70 18 13.447 N 149 46 21.152 W 2Z-13AL1 Polygon 109.00 -4928.87 -1391.65 5960956.00 528095.00 70 18 15.895 N 149 46 20.687 W -Polygon 1 109.00 -4928.87 -1391.65 5960956.00 528095.00 70 18 15.895 N 149 46 20.687 W -Polygon 2 109.00 -6955.50 -1542.62 5958929.00 527952.00 70 17 55.963 N 149 46 25.077 W -Polygon 3 109.00 -7044.08 -885.90 5958843.00 528609.00 70 17 55.093 N 149 46 5.932 W -Polygon 4 109.00 -4995.62 -692.84 5960892.00 528794.00 70 18 15.240 N 149 46 0.310 W -Polygon 5 109.00 -4957.93 -1377.77 5960927.00 528109.00 70 18 15.609 N 149 46 20.282 W -Polygon 6 109.00 -4928.87 -1391.65 5960956.00 528095.00 70 18 15.895 N 149 46 20.687 W 2Z-13A Target3 6079.00 -4176.98 -833.64 5961710.00 528650.00 70 18 23.291 N 149 46 4.418 W 2Z-13A Target2 6087.00 -4586.72 -656.23 5961301.00 528829.00 70 18 19.261 N 149 45 59.244 W 2Z-13A Targets 6087.00 -3322.28 -989.30 5962564.00 528491.00 70 18 31.697 N 149 46 8.961 W 2Z-13A Target4 6089.00 -3681.99 -819.70 5962205.00 528662.00 70 18 28.159 N 149 46 4.013 W 2Z-13A Target6 6099.00 -3076.13 -1020.34 5962810.00 528459.00 70 18 34.117 N 149 46 9.867 W 2Z-13A Targetl 6104.00 -4880.66 -681.38 5961007.00 528805.00 70 18 16.370 N 149 45 59.976 W • by BP Alaska s~ Baker Hughes INTEQ Planning Report 1NTE Q Company: BP Amoco Date: . 11/30/2006 Time: 10:33:47 Page: 2 Field: Kuparuk Go-ordinate(NE) Refereace: Well: 13, True North Site: KRU 2Z Pad Vertical fTVD) Reference: 2Z-13 109.0 Well: 13 Section (V5) Reference: Wetl (O.OON,O.OOE,359. OOAzi) Wellpatb: . Plan 3, 2Z- 13A Sdrvey Cakalatioa Metbal: Minimum Curvature Db: OraGe Targets -Map Map <- Latitude --> <- Longitude -> Name Deseriptioe TVD +N/-S +E/-W NortYing Eastieg Deg Min Sec Deg Mia Sec Dip. Dir. 1t ft _'ft ft ft 2Z-13A Target? 6112.00 -2831.28 -975.38 5963055.00 52 8503.00 70 18 36.526 N 149 46 8.557 W 2Z-13A Target8 6122.00 -2542.0 1 -1038.25 5963344.00 528439.00 70 18 39.370 N 149 46 10.392 W Annotation Nm TVD ft ft --- 8100.00 5973.78 TIP 8185.00 6034.07 KOP ' 8199.00 6043.35 End of 40 Degl100' DLS 8239.00 6063.77 4 8383.71 6096.63 5 8483.71 6098.86 End of 45 Deg/100' DLS 8858.71 6103.53 7 9058.71 6095.45 8 9208.71 6087.10 9 9408.71 6081.85 10 9633.71 6079.54 11 9883.71 6084.60 12 10133.71 6089.32 13 10358.71 6087.77 14 10558.71 6086.74 15 10808.71 6101.85 16 10858.71 6106.24 17 11058.71 6112.41 18 11158.71 6114.36 19 11350.00 0.00 TD Plan Section Information Mll Incl Azim TVD tN1-S +E/-W DLS ' Build Taro TFO Target fE deg deg ft ft' ft degHQOft deg/t00ft deg/100ft °deg 8100.00 44.00 188.37 5973.78 -4924.16 -1095.13 0.00 0.00 0.00 0.00 8185.00 45.64 188.33 6034.07 -4983.44 -1103.84 1.93 1,93 -0.05 359.00 8199.00 51.24 188.33 6043.35 -4993.80 -1105.35 40.00 40.00 0.00 0.00 8239.00 67.25 178.68 6063.77 -5027.95 -1107.20 45.00 40,02 -24.11 330.00 8383.71 89.00 115.37 6096.63 -5137.72 -1032.03 45.00 15.03 -43.76 280.00 8483.71 88.59 70.36 6098.86 -5142.59 -934.73 45.00 -0.41 -45.01 269.00 8858.71 90.06 25.38 6103.53 -4897.44 -663.77 12.00 0.39 -11.99 271.50 9058.71 94.51 1.77 6095.45 -4704.61 -617.16 12.00 2.22 -11.80 281.00 9208.71 91.83 343.94 6087.10 -4556.62 -635.74 12.00 -1.79 -11.89 262.00 9408.71 91.14 319.94 6081.85 -4381.49 -729.11 12.00 -0.34 -12.00 268.70 9633.71 90.02 346.92 6079.54 -4182.12 -828.82 12.00 -0.50 11.99 92.20 9883.71 87.72 16.84 6084.60 -3935.15 -820.75 12.00 -0.92 11.97 94.60 10133.71 90.17 346.93 6089.32 -3688.17 -812.65 12.00 0.98 -11.96 274.30 10358.71 90.60 319.93 6087.77 -3488.79 -912.35 12.00 0.19 -12.00 271.00 10558.71 89.98 343.93 6086.74 -3313.60 -1005.77 12.00 -0.31 12.00 91.40 10808.71 83.23 13.23 6101.85 -3067.00 -1012.12 12.00 -2.70 11.72 103.60 10858.71 86.70 18.15 6106.24 -3019.07 -998.66 12.00 6.92 9.84 55.00 11058.71 89.82 354.34 6112.41 -2821.79 -977.12 12.00 1.56 -11.91 277.00 11158.71 87.96 342.48 6114.36 -2724.03 -997.17 12.00 -1.86 -11.86 261.00 11350.00 87.73 5.45 6121.66 -2535.21 -1017.14 12.00 -0.12 12.01 91.00 r by BP Alaska ~ Baker Hughes INTEQ Planning Report itNTE Q Company: BP AMOCO Date: 11/30/2006 Time: 10 :33:47 Page: 3 Reid: KUparuk Co-otdinate(NE) Reference: Well: 13, True North -Site: KR U 2Z Pad Vertical (TVD) Reference: 2Z-13 109.0 Weli: 13 Sectioa (VS) Reference: Well ( O.OON,O. OOE,359.OOAzi) Weilpat6 Plan 3, 2Z-13A Sarvey Cako~tioa Method: Minimum Curvature Db: OraGe Sarvey MD Iecl Azim SS TYD N!S FJW MapN - MapE DLS VS TFO Tool ft -deg deg ft ft ft tt ft deg/100ft ft deg 8100.00 44.00 188.37 5864.78 -4924.16 -1095.13 5960961.88 528391.47 0.00 -4904.30 0.00 MWD 8185.00 45.64 188.33 5925.07 -4983.44 -1103.84 5960902.57 528383.00 1.93 -4963.41 359.00 MWD 8190.00 47.64 188.33 5928.50 -4987.03 -1104.36 5960898.97 528382.49 40.00 -4967.00 360.00 MWD 8199.00 51.24 188.33 5934.35 -4993.80 -1105.35 5960892.21 528381.53 40.00 -4973.75 0.00 MWD 8210.00 55.57 185.33 5940.91 -5002.56 -1106.40 5960883.44 528380.52 45.00 -4982.49 330.00 MWD 8220.00 59.56 182.87 5946.27 -5010.98 -1106.99 5960875.02 528379.95 45.00 -4990.90 331.79 MWD 8230.00 63.59 180.60 5951.03 -5019.77 -1107.26 5960866.23 528379.72 45.00 -4999.68 333.11 MWD 8239.00 67.25 178.68 5954.77 -5027.95 -1107.20 5960858.05 528379.81 45.00 -5007.86 334.19 MWD 8250.00 68.19 173.43 5958.95 -5038.10 -1106.50 5960847.90 528380.55 45.00 -5018.02 280.00 MWD 8260.00 69.19 168.72 5962.58 -5047.30 -1105.06 5960838.71 528382.03 45.00 -5027.25 281.99 MWD 8270.00 70.32 164.08 5966.04 -5056.42 -1102.85 5960829.60 528384.27 45.00 -5036.40 283.70 MWD 8280.00 71.57 159.51 5969.31 -5065.39 -1099.90 5960820.64 528387.26 45.00 -5045.42 285.31 MWD 8282.20 71.86 158.51 5970.00 -5067.34 -1099.15 5960818.70 528388.02 45.00 -5047.38 286.81 2Z-13A 8290.00 72.92 155.00 5972.36 -5074.17 -1096.21 5960811.88 528390.98 45.00 -5054.27 287.12 MWD 8300.00 74.37 150.56 5975.18 -5082.70 -1091.83 5960803.37 528395.40 45.00 -5062.87 288.18 MWD 8310.00 75.91 146.18 5977.74 -5090.93 -1086.76 5960795.16 528400.50 45.00 -5071.19 289.43 MWD 8311.06 76.08 145.72 5978.00 -5091.78 -1086.18 5960794.31 528401.08 45.00 -5072.05 290.55 2Z-13A 8319.81 77.50 141.95 5980.00 -5098.65 -1081.16 5960787.46 528406.13 45.00 -5079.01 290.67 2Z-13A 8320.00 77.53 141.87 5980.04 -5098.80 -1081.04 5960787.31 528406.25 45.00 -5079.16 291.53 MWD 8330.00 79.21 137.61 5982.06 -5106.27 -1074.71 5960779.86 528412.60 45.00 -5086.74 291.55 MWD 8340.00 80.96 133.40 5983.78 -5113.30 -1067.81 5960772.87 528419.53 45.00 -5093.88 292.40 MWD 8350.00 82.75 129.23 5985.20 -5119.83 -1060.38 5960766.37 528426.99 45.00 -5100.54 293.13 MWD 8360.00 84.57 125.09 5986.30 -5125.83 -1052.46 5960760.40 528434.93 45.00 -5106.68 293.72 MWD 8370.00 86.43 120.98 5987.09 -5131.26 -1044.10 5960755.00 528443.31 45.00 -5112.26 294.18 MWD 8380.00 88.30 116.88 5987.55 -5136.09 -1035.36 5960750.20 528452.07 45.00 -5117.24 294.50 MWD 8383.71 89.00 115.37 5987.63 -5137.72 -1032.03 5960748.58 528455.40 45.00 -5118.93 294.69 MWD 8390.00 88.95 112.53 5987.75 -5140.28 -1026.28 5960746.05 528461.16 45.00 -5121.58 269.00 MWD 8400.00 88.88 108.03 5987.94 -5143.74 -1016.91 5960742.62 528470.55 45.00 -5125.21 269.05 MWD 8410.00 88.82 103.53 5988.14 -5146.46 -1007.29 5960739.94 528480.18 45.00 -5128.10 269.14 MWD 8420.00 88.76 99.03 5988.35 -5148.42 -997.49 5960738.03 528489.99 45.00 -5130.22 269.23 MWD 8430.00 88.71 94.53 5988.57 -5149.60 -987.56 5960736.89 528499.92 45.00 -5131.58 269.32 MWD 8440.00 88.67 90.03 5988.80 -5150.00 -977.57 5960736.53 528509.90 45.00 -5132.15 269,42 MWD 8450.00 88.64 85.53 5989.03 -5149.61 -967.59 5960736.95 528519.89 45.00 -5131.94 269.52 MWD 8460.00 88.61 81.03 5989.28 -5148.44 -957.66 5960738.16 528529.81 45.00 -5130.94 269.63 MWD 8470.00 88.59 76.53 5989.52 -5146.49 -947.86 5960740.15 528539.60 45.00 -5129.17 269.74 MWD 8480.00 88.59 72.02 5989.77 -5143.78 -938.24 5960742.89 528549.21 45.00 -5126.63 269.85 MWD 8483.71 88.59 70.36 5989.86 -5142.59 -934.73 5960744.10 528552.71 45.00 -5125.49 269.96 MWD 8500.00 88.64 68.40 5990.25 -5136.85 -919.49 5960749.90 528567.93 12.00 -5120.02 271.50 MWD 8525.00 88.72 65.40 5990.83 -5127.05 -896.50 5960759.79 528590.88 12.00 -5110.62 271.55 MWD 8550.00 88.81 62.40 5991.37 -5116.05 -874.06 5960770.87 528613.28 12.00 -5100.02 271.62 MWD 8575.00 88.90 ~ 59.40 5991.87 -5103.90 -852.22 5960783.11 528635.07 12.00 -5088.25 271.68 MWD 8600.00 88.99 56.40 5992.33 -5090.62 -831.04 5960796.47 528656.18 12.00 -5075.34 271.74 MWD 8625.00 89.08 53.40 5992.75 -5076.25 -810.59 5960810.92 528676.58 12.00 -5061.33 271.80 MWD 8650.00 89.18 50.41 5993.13 -5060.83 -790.92 5960826.42 528696.18 12.00 -5046.26 271.85 MWD 8675.00 89.28 47.41 5993.46 -5044.40 -772.09 5960842.92 528714.95 12.00 -5030.16 271.89 MWD 8700.00 89.38 44.41 5993.75 -5027.01 -754.14 5960860.38 528732.84 12.00 -5013.08 271.93 MWD 8725.00 89.49 41.41 5994.00 -5008.70 -737.12 5960878.75 528749.78 12.00 -4995.07 271.97 MWD 8750.00 89.59 38.41 5994.20 -4989.53 -721.08 5960897.98 528765.74 12.00 -4976.18 272.00 MWD 8775.00 89.70 35.41 5994.35 -4969.54 -706.07 5960918.03 528780.68 12.00 -4956.46 272.02 MWD 8800.00 89.81 32.42 5994.46 -4948.80 -692.12 5960938.82 528794.54 12.00 -4935.97 272.04 MWD 8825.00 89.91 29.42 5994.52 -4927.35 -679.27 5960960.32 528807.30 12.00 -4914.75 272.05 MWD 8850.00 90.02 26.42 5994.54 -4905.27 -667.57 5960982.45 528818.91 12.00 -4892.87 272.06 MVW 8858.71 90.06 25.38 5994.53 -4897.44 -663.77 5960990.29 528822.68 12.00 -4885.10 272.06 MWD • • by BP Alaska $ Baker Hughes INTEQ Planning Report 1NTEQ Company: BP Amoco Date: 11/3U{2006 Time: 10 :33:47 Page: 4 Field: KuparUk Go-ordLtate(NE) Reference: Well: 13, True North Ske: KRl12Z Pad Vertical (1'VD) Reference: 2Z-13 109.0 Weli: 13 Scctioo (VS)Reference: WeII( O.OON,O. OOE,359.OOAzi) Welipaki Plan 3, 2Z-13A Survey Calculatiou Method: Minimum Curvature Db: Orade Survey Mb Incl A2im SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft- ft deg/100ft ft deg 8875. 00 90.43 23.46 5994.46 -4882.60 -657.03 5961005.15 528829.36 12.00 -4870.39 281.00 MWD 8900. 00 91.00 20. 51 5994.15 -4859.42 -647.68 5961028.37 528838.63 12.00 -4847.38 280.99 MWD 8925. 00 91.57 17. 56 5993.58 -4835.80 -639.52 5961052.02 528846.68 12.00 -4823.90 280.95 MWD 8950. 00 92.14 14. 62 5992.77 -4811.79 -632.60 5961076.05 528853.51 12.00 -4800.02 280.89 MWD 8975. 00 92.70 11. 67 5991.72 -4787.47 -626.92 5961100.39 528859.10 12.00 -4775.80 280.79 MWD 9000. 00 93.25 8. 71 5990.42 -4762.90 -622.50 5961124.97 528863.42 12.00 -4751.31 280.67 MWD 9025. 00 93.79 5. 76 5988.89 -4738.15 -619.36 5961149.73 528866.46 12.00 -4726.62 280.52 MWD 9050. 00 94.32 2. 80 5987.12 -4713.28 -617.50 5961174.60 528868.22 12.00 -4701.79 280.33 MWD 9058. 71 94.51 1. 77 5986.45 -4704.61 -617.16 5961183.28 528868.54 12.00 -4693.13 280.12 MWD 9075. 00 94.23 359. 82 5985.21 -4688.37 -616.93 5961199.52 528868.70 12.00 -4676.89 262.00 MWD 9100. 00 93.80 356 .85 5983.46 -4663.44 -617.65 5961224.44 528867.88 12.00 -4651.95 261.85 MWD 9125. 00 93.36 353 .88 5981.89 -4638.58 -619.67 5961249.30 528865.76 12.00 -4627.05 261.64 MWD 9150.00 92.91 350 .90 5980.53 -4613.84 -622.98 5961274.02 528862.36 12.00 -4602,26 261.46 MWD 9175. 00 92.45 347 .94 5979.36 -4589.29 -627.56 5961298.55 528857.68 12.00 -4577.64 261.30 MWD 9200. 00 91.99 344. 97 5978.39 -4565.01 -633.41 5961322.80 528851.73 12.00 -4553.26 261.16 MWD 9208. 71 91.83 343 .94 5978.10 -4556.62 -635.74 5961331.18 528849.37 12.00 -4544.84 261.04 MWD 9225. 00 91.78 341 .98 5977.59 -4541.05 -640.52 5961346.73 528844.54 12.00 -4529.18 268.70 MWD 9250. 00 91.71 338 .98 5976.82 -4517.50 -648.86 5961370.24 528836.10 12.00 -4505.49 268.64 MWD 9275. 00 91.63 335 .98 5976.10 -4494.42 -658.43 5961393.28 528826.44 12.00 -4482.25 268.55 MWD 9300. 00 91.54 332 .98 5975.41 -4471.87 -669.20 5961415.79 528815.59 12.00 -4459.51 268.46 MWD 9325. 00 91.46 329 .98 5974.75 -4449.92 -681.13 5961437.70 528803.57 12.00 -4437.35 268.38 MWD 9350. 00 91.37 326 .98 5974.13 -4428.61 -694.19 5961458.94 528790.42 12.00 -4415.82 268.30 MWD 9375. 00 91.27 323 .98 5973.56 -4408.02 -708.35 5961479.48 528776.18 12.00 -4394.99 268.22 MWD 9400. 00 91.17 320 .98 5973.02 -4388.20 -723.57 5961499.24 528760.89 12.00 -4374.90 268.16 MWD 9408. 71 91.14 319 .94 5972.85 -4381.49 -729.11 5961505.93 528755.32 12.00 -4368.10 268.09 MWD 9425. 00 91.06 321 .89 5972.54 -4368.84 -739.38 5961518.53 528745.00 12.00 -4355.27 92.20 MWD 9450. 00 90.94 324 .89 5972.10 -4348.78 -754.29 5961538.53 528730.02 12.00 -4334.95 92.24 MWD 9475. 00 90.82 327 .89 5971.71 -4327.96 -768.12 5961559.29 528716.11 12.00 -4313.90 92.29 MWD 9500. 00 90.70 330 .89 5971.38 -4306.45 -780.85 5961580.75 528703.30 12.00 -4292.17 92.34 MWD 9525. 00 90.57 333 .89 5971.10 -4284.30 -792.44 5961602.85 528691.62 12.00 -4269.82 92.38 MWD 9550. 00 90.45 336 .88 5970.88 -4261.58 -802.85 5961625.54 528681.12 12.00 -4246.92 92.41 MWD 9575. 00 90.32 339 .88 5970.71 -4238.34 -812.06 5961648.74 528671.82 12.00 -4223.52 92.44 MWD 9600. 00 90.19 342 .88 5970.60 -4214.65 -820.04 5961672.39 528663.75 12.00 -4199.70 92.46 MWD 9625. 00 90.06 345 .87 5970.54 -4190.58 -826.77 5961696.43 528656.92 12.00 -4175.51 92.47 MWD 9633. 71 90.02 346 .92 5970.54 -4182.12 -828.82 5961704.89 528654.84 12.00 -4167.01 92.48 MWD 9650. 00 89.86 348 .87 5970.56 -4166.19 -832.24 5961720.80 528651.36 12.00 -4151.03 94.60 MWD 9675. 00 89.62 351 .86 5970.67 -4141.54 -836.42 5961745.43 528647.08 12.00 -4126.31 94.60 MWD 9700. 00 89.38 354 .85 5970.89 -4116.71 -839.31 5961770.24 528644.09 12.00 -4101.44 94.58 MWD 9725. 00 89.14 357 .84 5971.21 -4091.77 -840.91 5961795.18 528642.40 12.00 -4076.47 94.56 MWD 9750. 00 88.91 0 .83 5971.64 -4066.78 -841.20 5961820.17 528642.01 12.00 -4051.48 94.52 MWD 9775. 00 88.68 3 .82 5972.16 -4041.81 -840.18 5961845.14 528642.93 12.00 -4026.53 94.47 MWD 9800. 00 88.45 6 .81 5972.79 -4016.92 -837.87 5961870.03 528645.15 12.00 -4001.69 94.41 MWD 9825. 00 88.22 9 .81 5973.52 -3992,20 -834.26 5961894.76 528648.66 12.00 -3977.03 94.33 MWD 9850. 00 88.00 12 .80 5974.34 -3967.70 -829.36 5961919.28 528653.46 12.00 -3952.62 94.24 MWD 9875. 00 87.79 15 .80 5975.26 -3943.49 -823.19 5961943.51 528659.54 12.00 -3928.53 94.14 MWD 9883. 71 87.72 16 .84 5975.60 -3935.15 -820.75 5961951.86 528661.95 12.00 -3920.22 94.03 MWD 9900. 00 87.86 14 .89 5976.23 -3919.48 -816.30 5961967.54 528666.33 12.00 -3904.64 274.30 MWD 9925. 00 88.10 11 .89 5977.11 -3895.18 -810.51 5961991.86 528672.02 12.00 -3880.44 274.38 MWD 9950. 00 88.33 8 .90 5977.89 -3870.61 -806.00 5962016.45 528676.44 12.00 -3855.95 274.48 MWD 9975. 00 88.57 5 .91 5978.56 -3845.83 -802.78 5962041.24 528679.56 12.00 -3831.23 274.57 MWD 10000. 00 88.82 2 .92 5979.13 -3820.91 -800.86 5962066.16 528681.39 12.00 -3806.35 274.65 MWD 10025. 00 89.07 359 .93 5979.59 -3795.93 -800.24 5962091.15 528681.91 12.00 -3781.38 274.72 MWD • by BP Alaska s~ Baker Hughes INTEQ Planning Report INTE Q Goropany: BP Amoco Date: 11/30!2006 Time: 10 :33:47 Page: 5 Field: Kuparuk Co-ordiuate(NE) Reference: Well: 13, True North Site: KRU 2Z Pad Vertieal (TVI)) Reference: 2Z-13 109.0 Well: 13 Section(VS)'Reference: Well (O.OON,O. OOE,359.OOAzi) Wellpat6: Plan 3, 2Z-13A Survey Calculation nletbod: Minimum Curvature Db: OraGe Survey MD Inc! lzim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft' deg ..deg ft ft ft ft ft degl100ft ft deg 10050.00 89.32 356.94 5979.95 -3770.94 -800.92 - 5962116.13 - 528681.13 12.00 -3756.39 274.78 MWD 10075.00 89.57 353.95 5980.19 -3746.02 -802.90 5962141.03 528679.04 12.00 -3731.44 274.82 MWD 10100.00 89.83 350.96 5980.32 -3721.24 -806.19 5962165.80 528675.67 12.00 -3706.61 274.85 MWD 10125.00 90.08 347.97 5980.34 -3696.67 -810.76 5962190.35 528671.00 12.00 -3681.96 274.86 MWD 10133.71 90.17 346.93 5980.32 -3688.17 -812.65 5962198.84 528669.08 12.00 -3673.43 274.87 MWD 10150.00 90.20 344.98 5980.27 -3672.36 -816.60 5962214.63 528665.06 12.00 -3657.55 271.00 MWD 10175.00 90.25 341.98 5980.17 -3648.40 -823.71 5962238.57 528657.86 12.00 -3633.47 270.99 MWD 10200.00 90.31 338.98 5980.05 -3624.84 -832.07 5962262.09 528649.41 12.00 -3609.77 270.98 MWD 10225.00 90.36 335.98 5979.90 -3601.75 -841.64 5962285.14 528639.75 12.00 -3586.51 270.97 MWD 10250.00 90.40 332.98 5979.74 -3579.19 -852.41 5962307.65 528628.89 12.00 -3563.77 270.95 MWD 10275.00 90.45 329.98 5979.55 -3557.23 -864.35 5962329.57 528616.87 12.00 -3541.60 270.93 MWD 10300.00 90.50 326.98 5979.34 -3535.92 -877.42 5962350.82 528603.72 12.00 -3520.07 270.91 MWD 10325.00 90.55 323.98 5979.11 -3515.33 -891.58 5962371.36 528589.47 12.00 -3499.23 270.88 MWD 10350.00 90.59 320.98 5978.87 -3495.50 -906.81 5962391.12 528574.17 12.00 -3479.14 270.86 MWD 10358.71 90.60 319.93 5978.77 -3488.79 -912.35 5962397.81 528568.60 12.00 -3472.34 270.83 MWD 10375.00 90.56 321.89 5978.61 -3476.14 -922.62 5962410.42 528558.28 12.00 -3459.51 91.40 MWD 10400.00 90.48 324.89 5978.38 -3456.08 -937.53 5962430.42 528543.30 12.00 -3439.19 91.42 MWD 10425.00 90.40 327.89 5978.19 -3435.26 -951.37 5962451.18 528529.38 12.00 -3418.14 91.45 MWD 10450.00 90.33 330.89 5978.03 -3413.75 -964.10 5962472.64 528516.57 12.00 -3396.40 91.47 MWD 10475.00 90.25 333.88 5977.90 -3391.60 -975.68 5962494.74 528504.89 12.00 -3374.06 91.49 MWD 10500.00 90.17 336.88 5977.81 -3368.88 -986.09 5962517.42 528494.39 12.00 -3351.15 91.50 MWD 10525.00 90.09 339.88 5977.76 -3345.64 -995.30 5962540.62 528485.10 12.00 -3327.76 91.52 MWD 10550.00 90.01 342.88 5977.73 -3321.95 -1003.28 5962564.28 528477.02 12.00 -3303.93 91.52 MWD 10558.71 89.98 343.93 5977.74 -3313.60 -1005.77 5962572.61 528474.50 12.00 -3295.55 91.52 MWD 10575.00 89.52 345.83 5977.81 -3297.88 -1010.02 5962588.32 528470.19 12.00 -3279.75 103.60 MWD 10600.00 88.82 348.74 5978.17 -3273.49 -1015.52 5962612.68 528464.60 12.00 -3255.27 103.59 MWD 10625.00 88.12 351.66 5978.84 -3248.87 -1019.77 5962637.28 528460.25 12.00 -3230.58 103.55 MWD 10650.00 87.42 354.58 5979.81 -3224.07 -1022.77 5962662.07 528457.16 12.00 -3205.73 103.47 MWD 10675.00 86.73 357.51 5981.08 -3199.17 -1024.49 5962686.96 528455.34 12.00 -3180.80 103.36 MWD 10700.00 86.05 0.43 5982.66 -3174.22 -1024.94 5962711.90 528454.79 12.00 -3155.85 103.21 MWD 10725.00 85.38 3.36 5984.53 -3149.31 -1024.11 5962736.82 528455.52 12.00 -3130.96 103.02 MWD 10750.00 84.72 6.30 5986.68 -3124.49 -1022.01 5962761.64 528457.52 12.00 -3106.18 102.81 MWD 10775.00 84.08 9.25 5989.12 -3099.85 -1018.65 5962786.30 528460.79 12.00 -3081.60 102.55 MWD 10800.00 83.45 12.20 5991.84 -3075.43 -1014.03 5962810.73 528465.31 12.00 -3057.26 102.26 MWD 10808.71 83.23 13.23 5992.85 -3067.00 -1012.12 5962819.17 528467.18 12.00 -3048.86 101.94 MWD 10825.00 84.36 14.84 5994.61 -3051.28 -1008.20 5962834.90 528471.05 12.00 -3033.22 55.00 MWD 10850.00 86.09 17.29 5996.69 -3027.34 -1001.30 5962858.86 528477.85 12.00 -3009.41 54.83 MWD 10858.71 86.70 18.15 5997.24 -3019.07 -998.66 5962867.15 528480.46 12.00 -3001.18 54.62 MWD 10875.00 86.94 16.20 5998.14 -3003.52 -993.85 5962882.71 528485.20 12.00 -2985.72 277.00 MWD 10900.00 87.31 13.22 5999.40 -2979.38 -987.51 5962906.88 528491.45 12.00 -2961.69 277.11 MWD 10925.00 87.69 10.24 6000.49 -2954.93 -982.43 5962931.34 528496.43 12.00 -2937.33 277.26 MWD 10950.00 88.08 7.27 6001.41 -2930.24 -978.63 5962956.05 528500.13 12.00 -2912.71 277.39 MWD 10975.00 88.48 4.29 6002.16 -2905.38 -976.12 5962980.91 528502.55 12.00 -2887.90 277.50 MWD 11000.00 88.87 1.32 6002.74 -2880.42 -974.89 5963005.87 528503.68 12.00 -2862.96 277.59 MWD 11025.00 89.27 358.34 6003.15 -2855.42 -974.97 5963030.86 528503.51 12.00 -2837.97 277.66 MWD 11050.00 89.68 355.37 6003.37 -2830.46 -976.34 5963055.82 528502.04 12.00 -2812.99 277.70 MWD 11058.71 89.82 354.34 6003.41 -2821.79 -977.12 5963064.48 528501.22 12.00 -2804.31 277.73 MWD 11075.00 89.51 352.41 6003.51 -2805.61 -979.00 5963080.66 528499.28 12.00 -2788.10 261.00 MWD 11100.00 89.04 349.44 6003.82 -2780.93 -982.94 5963105.32 528495.24 12.00 -2763.35 261.01 MWD 11125.00 88.58 346.48 6004.34 -2756.49 -988.15 5963129.74 528489.93 12.00 -2738.82 261.05 MWD 11150.00 88.12 343.51 6005.06 -2732.35 -994.62 5963153.85 528483.37 12.00 -2714.58 261.11 MWD 11158.71 87.96 342.48 6005.36 -2724.03 -997.17 5963162.16 528480.79 12.00 -2706.21 261.20 MWD 11175.00 87.92 344.44 6005.95 -2708.42 -1001.80 5963177.74 528476.09 12.00 -2690.53 91.00 MWD • by BP Alaska sus Baker Hughes INTEQ Planning Report ATE Q Compaayc BP AMOCO late: 11/30/2006 Time: 10:33:47 Page: 6 :Field: Kuparuk Co-ordinate(NE) Reference: Well: 13, True N orth -Site: KRU 22 Pad Vertical (TVID) Reference: 2Z-13 109.0 Well: 1$ Sectioe (VS)1~2efereace: Well (O.OON,O.OOE,359.OOAzi) Wellpath Pfan 3, ZZ-13A Survey Calcaiatioe Metdod: Minimum Curvature Db: OraGe Survey MD Intl Azim SS TVD N/S-' 1~/W MapN btapE DLS VS TFO Tool ft deg deg ft ft ft ft` ft deg/100ft ft deg 11200.00 87.88 347.44 6006.86 -2684.19 -1007.87 5963201.95 528469.93 12.00 -2666.19 90.93 MWD 11225.00 87.84 350.44 6007.80 -2659.67 -1012.67 5963226.44 528465.04 12.00 -2641.60 90.82 MWD 11250.00 87.81 353.44 6008.75 -2634.94 -1016.17 5963251.16 528461.44 12.00 -2616.81 90.71 MWD 11275.00 87.78 356.44 6009.71 -2610.06 -1018.37 5963276.03 528459.14 12.00 -2591.89 90.59 MWD 11300.00 87.76 359.44 6010.68 -2585.10 -1019.27 5963300.99 528458.15 12.00 -2566.92 90.48 MWD 11325.00 87.74 2.45 6011.67 -2560.12 -1018.86 5963325.96 528458.46 12.00 -2541.95 80.36 MWD 11350.00 87.73 5.45 6012.66 -2535.21 -1017.14 5963350.88 528460.08 12.00 -2517.07 90.24 2 3/8" ~p BP Alaska Anticollision Report ~.r s INTEQ Company: BP AMOCO Date: 11/30/2006 Time: 21:42:54 Page: 1 Field: Kuparuk Reference Site: KRU 2Z Pad r Co-ordinate(NE) Reference: Well: 13, True North Reference Well: 13 Vertical (TVD) Reference: 2Z Orig Datuml 109.0 'Reference Welipath: Plen 3, 2Z-13A Db: Oracle NO GLOBAL SCAN: Using aser defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 8100.00 to 11350.00 ft Scan Method: Trav Cylinder North Maximum Radius: 3000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Welipath Date: 11/30/2006 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 109.00 8100.00 Gyro (0.00-8525 .00) (0) GCT-MS Schlumberger GCT multishot 8100.00 11350.00 Planned: Plan #3 V5 MWD MWD -Standard Casing Points MD TVD Diameter Hok Size Name ft ft in in 11350.00 6121.66 2.375 3.000 2318" Summary "~--- ' OftsetWetlpath ~ Referee& Offset = Ctr-Ctr No-Go Allowable Site Well Welipath MD MD Distance Area Deviation Warning ft ft ft ft ft KRU 2D Pad 2D-03 2D-03 VO 8440.00 7905.00 2345.84 138.63 2207.20 Pass: Major Risk KRU 2D Pad 2D-04 2D-04 VO Out of range KRU 2D Pad 2D-05 20-05 VO Out of range KRU 2D Pad 2D-05 Plan 3, 2D-05L1 VO Pla 9011.13 10933.00 1405.79 286.78 1119.00 Pass: Major Risk KRU 2D Pad 2D-05 Plan 3, 2D-05L2 VO Pla 8750.00 9800.00 2299.88 228.21 2071.67 Pass: Major Risk KRU 2Z Pad 01 2Z-01 VO Out of range KRU 2Z Pad 02 2Z-02 VO 8186.02 9000.00 2040.281080.78 959.50 Pass: Major Risk KRU 2Z Pad 03 2Z-03 VO Out of range KRU 2Z Pad 04 2Z-04 VO Out of range KRU 2Z Pad 05 2Z-OS VO Out of range KRU 2Z Pad O6 2Z-06 VO Out of range KRU 2Z Pad 07 2Z-07 VO Out of range KRU 2Z Pad O8 2Z-08 VO 9050.00 8700.00 2425.041054.91 1370.13 Pass: Major Risk KRU 2Z Pad 09 2Z-09 VO Out of range KRU 2Z Pad 10 2Z-10 VO Out of range KRU 2Z Pad 11 2Z-11 VO 11110.61 6700.00 2407.87 218.92 2188.94 Pass: Major Risk KRU 2Z Pad 12 2Z-12 V1 Out of range KRU 2Z Pad 12 2Z-12A VO Out of range KRU 2Z Pad 13 2Z-13 V1 8100.00 8100.00 0.00 206.95 -206.95 FAIL: Major Risk KRU 2Z Pad 13 Plan 4, 2Z-13AL1 VO PI 8200.00 8200.00 0.00 206.85 -206.85 FAIL: Major Risk KRU 2Z Pad 14 2Z-14 VO 11325.00 7800.00 2659.24 249.37 2409.86 Pass: Major Risk KRU 2Z Pad 15 2Z-15 VO Out of range KRU 2Z Pad 16 22-16 VO Out of range KRU 2Z Pad 18 ZZ-18 VO Out of range KRU 2Z Pad 19 ZZ-19 VO Out of range KRU 2Z Pad 20 2Z-20 VO Out of range KRU 2Z Pad 21 2Z-21 VO Out of range KRU ZZ Pad 22 2Z-22 VO Out of range KRU 2Z Pad 23 2Z-23 VO Out of range KRU 2Z Pad 29 2Z-29 VO Out of range KRU 2Z Pad WS-1 WS-1 VO Out of range Site: KRU 2D Pad Well: 2D-03 Rule Assigned: Major Risk Welipath: 2D-03 VO Inter-Site Error: 0.00 ft Reference. Offset Semi-MajorAais Ctr-Ctr No-Go Allowable MD TVD MD TVD. Ret Ottset TFO+AZI TF0.HS:Casing/HSflistance Area Deviation Warning ft ft ft ft ft_ ft deg deg in ft ft ft 8440.00 6097.80 7000.00 5597.74 23.85 17.44 170.40 80.37 2986.73 132.48 2854.25 Pass 8440.00 6097.80 7100.00 5673.54 23.85 17.72 171.66 81.63 2910.50 133.08 2777.42 Pass 8440.00 6097.80 7200.00 5749.53 23.85 18.00 172.98 82.96 2835.95 133.74 2702.21 Pass 8440.00 6097.80 7300.00 5825.04 23.85 18.27 174.37 84.34 2762.62 134.46 2628.16 Pass 8440.00 6097.80 7400.00 5900.06 23.85 18.58 175.83 85.80 2690.47 135.19 2555.28 Pass by BP Alaska Anticollision Report • ~iilr s 1LNTEQ .'Company: BP Amoco Date: 11/30/2006 Time. 21:42:54 Page: 2 FieM: Kuparuk Reference Site: KRU 2Z Pad Go-ordinatc(NE) Reference:. Well: 13, True North Reference Well: 1 3 . - Vertical (TVD) Refereece: . 2Z Orig Datum1 109. 0 leference Welipat6: Plan 3, 2Z-13A' Db: OraGe Site: KRU 2D Pad Well: 2D-03 Rule Assigned: Major Risk Wellpath: 2D-03 VO Inter-Site Error: 0.00 ft Reference" Offset Semi-MajorAais Ctr-Ctr No-Go rltbwable MD TVD MD TVD Ref Oi}'set TFO+AZI TFO-HS Casing/)ISDestaeee Area •. Deviation Warning ft ft ft ft ft ft _ deg deg in ft ft ft 8440.00 6097.80 7500.00 5974.24 23.85 18.92 177.34 87.31 2619.22 135.93 2483.30 Pass 8440.00 6097.80 7600.00 6047.65 23.85 19.26 178.92 88.89 2549.04 136.66 2412.38 Pass 8440.00 6097.80 7700.00 6120.59 23.85 19.60 180.58 90.55 2480.39 137.37 2343.02 Pass 8440.00 6097.80 7800.00 6193.25 23.85 19.96 182.32 92.29 2413.57 138.01 2275.56 Pass 8440.00 6097.80 7900.00 6265.82 23.85 20.32 184.15 94.12 2349.00 138.60 2210.40 Pass 8440.00 6097.80 7905.00 6269.45 23.85 20.34 184.25 94.22 2345.84 138.63 2207.20 Pass Site: KRU 2D Pad Well: 2D-05 Rule Assigned: Major Risk Wellpath: Plan 3, 2D-05L1 VO Plan: Plan #3 V5 Inter-Site Error: 0.00 ft Referenee Offset Semi-MajorAais Ctr-Ctr No-Go Allowable NII) T~?D MD TVD ;Ref Offset TFO+AZL TFO-HS Casing/Fl~istance Area Deviation Warning ft ft _ ft ft ft ft deg deg in ft. ft ft 8800.00 6103.46 8900.00 6108.14 33.71 32.76 122.51 90.09 3.125 2993.38 236.90 2756.48 Pass 8800.00 6103.46 9000.00 6104.06 33.71 32.92 122.43 90.01 3.125 2897.42 237.59 2659.83 Pass 8800.00 6103.46 9100.00 6101.29 33.71 32.97 122.37 89.95 3.125 2797.91 237.82 2560.09 Pass 8800.00 6103.46 9200.00 6099.76 33.71 32.91 122.34 89.92 3.125 2698.36 237.71 2460.65 Pass 8800.00 6103.46 9300.00 6097.81 33.71 32.95 122.29 89.87 3.125 2598.76 237.91 2360.85 Pass 8800.00 6103.46 9400.00 6093.22 33.71 33.10 122.18 89.76 3.125 2502.89 238.53 2264.35 Pass 8814.79 6103.50 9500.00 6089.39 33.95 33.61 120.31 89.67 3.125 2415.04 241.12 2173.93 Pass 8825.00 6103.52 9600.00 6090.08 34.12 34.18 119.09 89.67 3.125 2339.90 243.61 2096.29 Pass 8838.53 6103.54 9700.00 6093.45 34.31 34.93 117.54 89.75 3.125 2273.15 246.69 2026.46 Pass 8850.00 6103.54 9800.00 6096.84 34.48 35.64 116.25 89.83 3.125 2194.89 249.54 1945.35 Pass 8858.71 6103.53 9900.00 6100.02 34.59 36.20 115.28 89.90 3.125 2106.39 251.80 1854.59 Pass 8858.71 6103.53 10000.00 6104.09 34.59 36.45 115.39 90.02 3.125 2010.69 252.71 1757.99 Pass 8868.78 6103.50 10100.00 6108.80 34.70 36.91 114.35 90.16 3.125 1915.07 254.66 1660.41 Pass 8875.00 6103.46 10200.00 6113.31 34.77 37.48 113.77 90.31 3.125 1828.27 256.80 1571.47 Pass 8900.00 6103.15 10300.00 6117.42 34.99 38.67 110.96 90.45 3.125 1755.26 261.38 1493.88 Pass 8911.63 6102.91 10400.00 6120.75 35.07 39.69 109.74 90.60 3.125 1700.64 264.86 1435.79 Pass 8932.67 6102.36 10500.00 6121.96 35.19 41.03 107.33 90.67 3.125 1667.23 269.34 1397.89 Pass 8950.00 6101.77 10600.00 6122.27 35.26 42.36 105.36 90.74 3.125 1629.92 273.64 1356.29 Pass 8975.00 6100.72 10700.00 6122.35 35.29 43.86 102.44 90.77 3.125 1577.68 278.45 1299.23 Pass 8991.30 6099.90 10800.00 6121.89 35.27 45.11 100.58 90.83 3.125 1511.77 282.33 1229.44 Pass 9000.00 6099.42 10900.00 6120.63 35.25 46.07 99.62 90.91 3.125 1433.88 285.39 1148.49 Pass 9011.13 6098.77 10933.00 6120.04 35.21 46.55 98.27 90.87 3.125 1405.79 286.78 1119.00 Pass Site: KRU 2D Pad Well: 2D-05 Rule Assigned: Major Risk Wellpath: Plan 3, 2D-05L2 VO Plan: Plan #3 V4 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Al[owable NII) TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDi4tance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 8800.00 6103.46 8900.00 6108.14 33.71 32.76 122.51 90.09 3.125 2993.38 236.90 2756.48 Pass 8800.00 6103.46 9000.00 6104.06 33.71 32.92 122.43 90.01 3.125 2897.42 237.59 2659.83 Pass 8800.00 6103.46 9100.00 6101.29 33.71 32.97 122.37 89.95 3.125 2797.91 237.82 2560.09 Pass 8800.00 6103.46 9200.00 6099.76 33.71 32.91 122.34 89.92 3.125 2698.36 237.71 2460.65 Pass 8800.00 6103.46 9300.00 6097.49 33.71 32.94 122.28 89.87 3.125 2598.68 237.88 2360.80 Pass 8800.00 6103.46 9400.00 6093.19 33.71 32.87 122.18 89.76 3.125 2500.67 237.71 2262.97 Pass 8800.00 6103.46 9500.00 6091.61 33.71 32.63 122.14 89.72 3.125 2418.62 236.87 2181.75 Pass 8775.00 6103.35 9600.00 6092.63 33.24 31.94 125.15 89.74 3.125 2357.64 233.01 2124.63 Pass 8762.63 6103.28 9700.00 6095.24 32.98 31.47 126.70 89.80 3.125 2317.19 230.53 2086.66 Pass 8750.00 6103.20 9800.00 6098.08 32.72 31.05 128.29 89.88 3.125 2299.88 228.21 2071.67 Pass • by BP Alaska Anticollision Report ~~r s 1NTEQ Company: 13PAmoco Date: 1 1 /3 01200 6 Time: 21:42:54 Page: 3 Field: Kuparuk Reference S ite: KRU 2Z Pad ,Go~erdinate(NE) Reference: Weil: 13, True North .:Reference Nell: 1 3 Vertieal (TVD) Referener. 2Z Orig Datuml 109.0 Reference Wellpath: Plan 3, 2Z-13A' Db: OraGe Site: KRU 2D Pad Well: 2D-05 Rule Assigned: Major Risk Wellpath: Plan 3, 2D-051.2 VO Plan: Plan #3 V4 Inter-Site Error: 0.00 ft Reference Offset- Semi-MajorAai~ ' Ctr-Ctr No-Go Allowable MD ' TVD MD TVD Ref Offset TFO+AZI TFO-HS: Casing/HSflistance Area Deviation Warning ft ft R ft ft ft deg deg in ft ft ft 8725.00 6103.00 9900.00 6099.04 32.16 30.49 131.31 89.90 3.125 2306.83 224.50 2082.33 Pass 8712.46 6102.88 10000.00 6096.92 31.86 30.22 132.77 89.85 3.125 2337.38 222.62 2114.76 Pass 8700.00 6102.75 10100.00 6090.05 31.56 30.01 134.11 89.70 3.125 2389.24 221.00 2168.24 Pass 8686.52 6102.60 10200.00 6078.77 31.22 29.81 135.47 89.44 3.125 2459.06 219.34 2239.72 Pass 8675.00 6102.46 10300.00 6069.01 30.93 29.65 136.65 89.24 3.125 2543.10 217.93 2325.18 Pass 8675.00 6102.46 10400.00 6064.67 30.93 29.67 136.59 89.18 3.125 2636.91 218.02 2418.90 Pass 8675.00 6102.46 10500.00 6063.74 30.93 29.64 136.61 89.20 3.125 2732.60 217.98 2514.63 Pass 8661.50 6102.29 10600.00 6062.67 30.57 29.38 138.22 89.20 3.125 2820.84 215.93 2604.91 Pass 8650.00 6102.13 10700.00 6061.47 30.27 29.17 139.60 89.19 3.125 2898.57 214.20 2684.37 Pass 8650.00 6102.13 10800.00 6060.18 30.27 29.18 139.61 89.20 3.125 2963.23 214.20 2749.03 Pass 8650.00 6102.13 10808.00 6060.07 30.27 29.18 139.61 89.21 3.125 2967.78 214.21 2753.57 Pass Site: KRU 2Z Pad Well: 02 Rule Assigned: Major Risk Wellpath: 2Z-02 VO Inter-Site Error: 0.00 ft Reference OlYset' Semi-Major Aaiv Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSIAstaoce Area Deviation Warning ft " ft ft ft ft ft deg deg in ft ft ft 11317.78 6120.38 5200.00 3468.08 47.48 156.86 348.48 346.90 2725.33 221.61 2503.73 Pass 11284.97 6119.10 5300.00 3518.01 47.01 157.84 343.71 346.07 2681.94 231.61 2450.33 Pass 11254.35 6117.91 5400.00 3568.47 46.41 158.07 339.06 345.09 2640.18 242.12 2398.06 Pass 11225.00 6116.80 5500.00 3619.12 45.69 157.58 334.41 343.98 2600.57 253.31 2347.26 Pass 11200.00 6115.86 5600.00 3669.85 44.96 157.15 330.15 342.71 2563.44 265.48 2297.96 Pass 10743.46 6095.09 5700.00 3720.62 42.88 189.37 346.84 341.31 2516.64 301.14 2215.50 Pass 10725.00 6093.53 5800.00 3771.25 42.75 192.88 343.82 340.45 2471.68 315.14 2156.54 Pass 10700.00 6091.66 5900.00 3822.19 42.48 194.89 339.95 339.52 2429.21 328.25 2100.96 Pass 10683.50 6090.59 6000.00 3873.70 42.24 197.65 336.87 338.37 2389.28 343.75 2045.53 Pass 10664.75 6089.52 6100.00 3925.51 41.93 199.52 333.40 337.10 2352.43 359.31 1993.11 Pass 10650.00 6088.81 6200.00 3978.31 41.66 201.64 330.24 335.66 2318.10 376.65 1941.46 Pass 10625.00 6087.84 6300.00 4033.48 41.12 200.58 325.80 334.14 2285.04 389.51 1895.52 Pass 10614.07 6087.51 6400.00 4091.39 40.84 202.14 322.81 332.42 2252.82 408.37 1844.44 Pass 10600.00 6087.17 6500.00 4151.06 40.49 202.40 319.35 330.60 2222.62 425.72 1796.90 Pass 10585.00 6086.91 6600.00 4212.32 40.06 201.88 315.67 328.68 2194.61 442.10 1752.51 Pass 10575.00 6086.81 6700.00 4276.08 39.78 202.35 312.47 326.65 2167.71 461.26 1706.45 Pass 10558.71 6086.74 6800.00 4342.81 39.27 200.25 308.44 324.52 2141.67 475.43 1666.24 Pass 10550.00 6086.73 6900.00 4412.64 38.99 199.98 305.14 322.26 2117.12 496.05 1621.07 Pass 10536.10 6086.74 7000.00 4484.18 38.51 197.21 301.05 319.84 2097.02 512.35 1584.68 Pass 10525.00 6086.76 7100.00 4555.92 38.12 194.93 297.18 317.30 2083.09 529.37 1553.72 Pass 10525.00 6086.76 7200.00 4628.09 38.12 196.78 294.59 314.70 2073.77 554.78 1518.99 Pass 10512.07 6086.78 7300.00 4700.82 37.64 193.25 290.40 312.07 2068.43 567.09 1501.34 Pass 8186.02 6034.77 9000.00 6053.50 34.88 322.47 279.06 90.73 2040.281080.78 959.50 Pass 8210.00 6049.91 9100.00 6138.45 34.75 317.74 278.95 93.62 2073.571077.80 995.77 Pass 8214.69 6052.50 9200.00 6223.56 34.68 317.45 279.67 95.52 2110.391081.18 1029.21 Pass 8220.00 6055.27 9300.00 6308.67 34.59 316.55 280.35 97.48 2150.971082.13 1068.84 Pass 8230.00 6060.03 9394.00 6388.67 34.39 312.03 280.42 99.82 2192.351071.39 1120.97 Pass by BP Alaska Anticollision Report ~.r S 1NTEQ Company: BP Amoco Date: 11/30/2006 Time: 21:42:54 Page: 4 Field: Kuparuk Reference Site: KRU 2Z Pad Go•ordinate(NE) Reference: Well: 13 , True North Reference WeIL 13 Vertical (TVD) Reference: 2Z Orig Datuml 109. 0 Reference Weltpat6: Plan 3, 2Z-13A Db: Oracle Site: KRU 2Z Pad Well: 08 Rule Assigned: Major Risk Wellpath: 2Z-08 VO Inter-Site Error: 0.00 ft Reference Offset Semi-Major Aais Ctr-Ctr No-Go .4liowable MD TVD MD ' 1'VIJ Ref Offset TFO+AZI TFO-HS Casing/HSQistance Area Deviation Warning ft ft ft ft ft ft deg ~9 in ft ft ft 10175.00 6089.17 6100.00 4087.04 35.91 205.51 29.48 47.50 2963.82 568.70 2395.12 Pass 10150.00 6089.27 6200.00 4146.02 36.41 210.42 33.32 48.34 2923.70 588.33 2335.36 Pass 10142.06 6089.30 6300.00 4205.46 36.55 215.35 35.17 49.24 2885.63 607.45 2278.19 Pass 10127.15 6089.34 6400.00 4265.08 36.80 219.98 37.92 50.20 2850.01 626.98 2223.04 Pass 10111.92 6089.34 6500.00 4324.66 37.04 224.39 40.75 51.21 2817.09 646.65 2170.44 Pass 10100.00 6089.32 6600.00 4384.56 37.22 228.79 43.25 52.28 2786.72 666.70 2120.02 Pass 10075.00 6089.19 6700.00 4444.93 37.53 231.79 47.36 53.41 2758.93 684.84 2074.09 Pass 10075.00 6089.19 6800.00 4505.46 37.53 236.92 48.55 54.60 2733.93 706.94 2026.99 Pass 10050.00 6088.95 6900.00 4566.14 37.77 239.18 52.77 55.83 2712.10 724.16 1987.94 Pass 10039.16 6088.81 7000.00 4627.13 37.84 242.78 55.36 57.13 2693.36 744.03 1949.33 Pass 9250.00 6085.82 7100.00 4688.36 31.54 256.89 37.20 58.22 2655.96 766.81 1889.15 Pass 9225.00 6086.59 7200.00 4749.91 32.14 262.58 41.33 59.35 2620.91 792.01 1828.90 Pass 9218.26 6086.80 7300.00 4811.72 32.29 267.81 43.27 60.47 2588.62 814.65 1773.97 Pass 9204.53 6087.23 7400.00 4873.61 32.59 272.92 46.11 61.68 2559.33 838.03 1721.30 Pass 9191.19 6087.71 7500.00 4935.45 32.87 277.87 48.94 62.92 2533.31 861.15 1672.16 Pass 9175.00 6088.36 7600.00 4998.02 33.20 282.38 52.19 64.25 2510.28 883.60 1626.69 Pass 9164.76 6088.81 7700.00 5062.38 33.39 286.76 54.77 65.62 2489.46 905.44 1584.02 Pass 9150.00 6089.53 7800.00 5128.68 33.66 290.41 58.00 67.10 2470.68 925.81 1544.87 Pass 9139.22 6090.09 7900.00 5196.94 33.84 293.95 60.81 68.63 2454.45 945.66 1508.79 Pass 9125.00 6090.89 8000.00 5266.78 34.07 296.75 64.13 70.25 2441.10 963.59 1477.51 Pass 9114.64 6091.52 8100.00 5338.04 34.22 299.64 67.01 71.91 2430.85 981.26 1449.59 Pass 9100.00 6092.46 8200.00 5410.88 34.43 301.55 70.50 73.66 2423.49 996.03 1427.46 Pass 9091.12 6093.06 8300.00 5485.33 34.54 303.97 73.32 75.41 2418.461011.50 1406.97 Pass 9075.00 6094.21 8400.00 5561.45 34.74 304.75 77.10 77.28 2415.811021.90 1393.91 Pass 9068.80 6094.67 8500.00 5639.25 34.80 307.02 79.67 79.10 2415.991035.65 1380.34 Pass 9058.71 6095.45 8600.00 5718.82 34.90 308.21 82.78 81.01 2419.121045.60 1373.52 Pass 9050.00 6096.12 8700.00 5799.90 34.98 309.39 85.74 82.94 2425.041054.91 1370.13 Pass 9037.21 6097.05 8800.00 5881.68 35.07 309.38 89.22 84.91 2434.551059.71 1374.84 Pass 9025.00 6097.89 8900.00 5963.59 35.15 309.24 92.63 86.87 2448.191062.93 1385.26 Pass 9025.00 6097.89 9000.00 6045.65 35.15 312.24 94.47 88.71 2465.521074.10 1391.42 Pass 9000.00 6099.42 9100.00 6128.07 35.25 308.03 99.44 90.73 2486.021063.12 1422.90 Pass 9000.00 6099.42 9200.00 6211.10 35.25 310.91 101.26 92.55 2509.141071.96 1437.18 Pass 8990.02 6099.97 9300.00 6294.60 35.27 310.62 104.30 94.41 2535.201070.13 1465.07 Pass 8975.00 6100.72 9378.00 6359.74 35.29 307.81 107.54 95.87 2558.021060.14 1497.88 Pass Site: KRU 2Z Pad Well: 11 Rule Assigned: Major Risk Wellpath: 2Z-11 VO Inter-Site Error: 0.00 ft Reference Offset Semi-Major Aaiv = Ctr-Ctr No-Go< ' Allowable MD TVD MD TVD Ref Offset TFO+AZL TFO-HS Casing/HSDistance Area Deviation Warning it ft ft ft' ft ft deg. deg in ft ft ft 11110.61 6113.02 6700.00 5693.23 44.21 18.94 68.14 79.96 2407.87 218.92 2188.94 Pass 11100.00 6112.82 6800.00 5770.82 44.34 19.33 71.28 81.84 2410.64 221.54 2189.10 Pass 11090.61 6112.68 6900.00 5847.41 44.42 19.79 74.25 83.70 2416.35 223.97 2192.38 Pass 11075.00 6112.51 7000.00 5922.17 44.55 20.21 77.90 85.49 2425.75 226.26 2199.48 Pass 11069.38 6112.47 7100.00 5995.00 44.58 20.70 80.31 87.24 2439.35 228.20 2211.15 Pass 11058.71 6112.41 7200.00 6066.05 44.65 21.17 83.26 88.92 2457.10 229.97 2227.13 Pass 11050.00 6112.37 7300.00 6135.32 44.68 21.67 85.90 90.53 2478.25 231.56 2246.69 Pass 11035.97 6112.27 7400.00 6203.52 44.71 22.13 89.13 92.09 2501.80 232.76 2269.05 Pass 11025.00 6112.15 7500.00 6271.51 44.73 22.60 91.96 93.61 2528.10 233.83 2294.28 Pass 10186.09 6089.12 7523.00 6287.14 35.67 23.71 75.13 94.49 2530.97 210.55 2320.42 Pass • by BP Alaska Anticollision Report • ~.r ~riEs INTEQ Compaay: BP Amoco Date: 11/3012006 Time: 21:42:54 Page: 5 F eld: Kupai-uk Reference Site: KRU 2Z Pad Co-ordirntt(NE) Reference: Well: 13, True North Reference Well: 13 Vertical (TVI)}Reference: 2Z Orig Datuml 109. 0 Reference.Wellpath: Play 3, 2Z-13A' Db: Oracle Site: KRU 2Z Pad Well: 13 Rule Assigned: Major Risk Wellpath: 2Z-13 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go ~llowab{e MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSflistance Area Deviation Warning ft it ft ft ft . ft deg deg in ft ft ft 11168.05 6114.70 4800.00 3744.91 43.87 17.27 352.20 8.60 2398.25 114.90 2283.35 Pass 11132.59 6113.54 4900.00 3806.94 43.93 17.97 353.45 7.87 2329.41 116.46 2212.95 Pass 11103.04 6112.88 5000.00 3868.99 44.30 18.75 356.27 7.18 2262.00 118.42 2143.57 Pass 11071.36 6112.48 5100.00 3931.26 44.57 19.43 -0.56 6.61 2195.86 120.22 2075.64 Pass 11006.96 6111.87 5200.00 3994.07 44.69 20.28 6.63 6.14 2130.37 120.58 2009.78 Pass 10922.12 6109.37 5300.00 4057.78 43.96 21.00 16.37 5.78 2063.83 120.24 1943.59 Pass 10736.47 6094.48 5400.00 4122.52 42.83 21.24 11.36 6.65 1992.66 115.82 1876.83 Pass 10688.42 6090.89 5500.00 4188.17 42.31 21.35 5.98 6.91 1920.50 116.94 1803.56 Pass 10641.18 6088.43 5600.00 4254.81 41.47 21.34 0.37 6.82 1848.21 118.11 1730.10 Pass 10595.46 6087.08 5700.00 4322.24 40.36 21.21 354.58 6.36 1776.08 119.41 1656.67 Pass 10544.60 6086.74 5800.00 4390.08 38.80 20.87 347.78 5.54 1704.62 120.50 1584.12 Pass 10468.45 6086.93 5900.00 4458.31 35.92 20.00 337.39 4.29 1633.21 120.48 1512.73 Pass 10407.15 6087.32 6000.00 4526.71 33.29 19.32 328.36 2.62 1562.29 121.64 1440.65 Pass 10356.36 6087.80 6100.00 4594.02 31.21 18.97 320.79 0.57 1493.94 123.93 1370.01 Pass 10300.23 6088.34 6200.00 4660.65 32.79 20.30 325.48 358.50 1428.23 126.47 1301.77 Pass 10229.67 6088.87 6300.00 4727.86 34.66 21.96 331.97 356.55 1363.51 128.50 1235.01 Pass 10142.55 6089.29 6400.00 4795.45 36.54 23.90 340.71 354.85 1299.11 129.71 1169.40 . Pass 10007.95 6088.29 6500.00 4863.28 38.01 26.01 355.48 353.51 1233.15 127.77 1105.38 Pass 9877.60 6084.36 6600.00 4931.17 37.61 26.88 8.85 352.75 1163.37 124.39 1038.98 Pass 9829.37 6082.65 6700.00 4999.20 37.52 27.36 3.09 352.76 1092.70 126.75 965.95 Pass 9780.61 6081.29 6800.00 5067.83 37.15 27.65 356.80 352.31 1022.96 129.53 893.43 Pass 9731.23 6080.31 6900.00 5135.46 36.50 27.76 349.91 351.32 955.90 132.85 823.06 Pass 9681.84 6079.72 7000.00 5201.49 35.57 27.68 342.38 349.70 892.63 136.96 755.67 Pass 9634.45 6079.54 7100.00 5267.59 34.46 27.43 334.32 347.31 832.27 142.21 690.06 Pass 9588.41 6079.64 7200.00 5334.33 33.19 27.02 325.55 344.06 775.13 148.60 626.53 Pass 9546.39 6079.91 7300.00 5402.03 31.92 26.58 316.31 339.86 722.06 156.14 565.92 Pass 9508.35 6080.28 7400.00 5470.51 30.71 26.15 306.52 334.63 674.91 164.53 510.38 Pass 8100.00 5973.78 8100.00 5973.78 34.67 34.67 188.37 0.00 0.00 206.95 -206.95 FAIL 8199.95 6043.94 8200.00 6044.53 34.87 35.16 8.29 180.24 0.74 174.05 -173.30 FAIL 8285.39 6079.98 8300.00 6112.77 30.08 30.77 313.36 156.29 37.59 173.23 -135.64 FAIL 8333.83 6091.75 8400.00 6178.98 25.30 26.16 281.25 145.26 107.82 142.44 -34.61 FAIL 8357.91 6095.10 8500.00 6244.48 24.28 25.41 266.65 140.70 194.03 115.45 78.58 Pass 8361.96 6095.48 8525.00 6260.85 24.17 25.38 264.26 139.98 216.77 110.43 106.34 Pass Site: KRU 22 Pad Well: 13 Rule Assigned: Major Risk Wellpath: Plan 4, 2Z-13AL1 VO Plan: Plan r4k4 V6 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Aais Ctr-Ctr No-Go '. Albwable MD TVI) NID TW Ref' Otfset TFO+AZI TFO-KS Casing/HSUistance Area Deviation VVaruing ft ft ft ft ft ft deg deg in ft ft ft 11168.05 6114.70 4800.00 3744.91 43.87 17.27 352.20 8.60 3.000 2398.25 114.93 2283.33 Pass 11132.59 6113.54 4900.00 3806.94 43.93 17.97 353.45 7.87 3.000 2329.41 116.49 2212.92 Pass 11103.04 6112.88 5000.00 3868.99 44.30 18.75 356.27 7.18 3.000 2262.00 118.45 2143.55 Pass 11071.36 6112.48 5100.00 3931.26 44.57 19.43 -0.56 6.61 3.000 2195.86 f 20.25 2075.62 Pass 11006.96 6111.87 5200.00 3994.07 44.69 20.28 6.63 6.14 3.000 2130.37 120.61 2009.76 Pass 10922.12 6109.37 5300.00 4057.78 43.96 21.00 16.37 5.78 3.000 2063.83 120.27 1943.56 Pass 10736.47 6094.48 5400.00 4122.52 42.83 21.24 11.36 6.65 3.000 1992.66 115.85 1876.81 Pass 10688.42 6090.89 5500.00 4188.17 42.31 21.35 5.98 6.91 3.000 1920.50 116.97 1803.53 Pass 10641.18 6088.43 5600.00 4254.81 41.47 21.34 0.37 6.82 3.000 1848.21 118.14 1730.08 Pass 10595.46 6087.08 5700.00 4322.24 40.36 21.21 354.58 6.36 3.000 1776.08 119.44 1656.64 Pass 10544.60 6086.74 5800.00 4390.08 38.80 20.87 347.78 5.54 3.000 1704.62 120.53 1584.09 Pass 10468.45 6086.93 5900.00 4458.31 35.92 20.00 337.39 4.29 3.000 1633.21 120.50 1512.71 Pass by BP Alaska Anticollision Report • mar ~ciEs INTEQ .Company: BP Amoco Date: 1 1130/2 0 0 6 Time: 21:42:54 Page: 6 Field: Kuparuk Reference Site: KRU 2Z Pad Go-ordinate(NE)'Reference: Well: 13 , True North Reference Well: 13 Vertical (TVb)Reference: 2Z Orig Datum1 109.0 :'Reference Wellpath: Plan 3,' 2Z-13A Dh: Orate Site: KRU 2Z Pad Well: 13 Rule Assigned: Major Risk Wellpath: Plan 4, 2Z-13AL1 VO Plan: Plan #d V6 Inter-Site Error: 0.00 ft Reference ' Offset Seroi-Major Adis Ctr-Ctr No-Go Allowable MD TVD MD TVD : Ref Offset. TFO+A2:I TFO-H$ Casing/HSflistance Arra Deviation Warning ft ft ft ft ft ft deg deg in ft _ ft ft 10407.15 6087.32 6000.00 4526.71 33.29 19.32 328.36 2.62 3.000 1562.29 121.67 1440.63 Pass 10356.36 6087.80 6100.00 4594.02 31.21 18.97 320.79 0.57 3.000 1493.94 123.95 1369.98 Pass 10300.23 6088.34 6200.00 4660.65 32.79 20.30 325.48 358.50 3.000 1428.23 126.49 1301.74 Pass 10229.67 6088.87 6300.00 4727.86 34.66 21.96 331.97 356.55 3.000 1363.51 128.53 1234.99 Pass 10142.55 6089.29 6400.00 4795.45 36.54 23.90 340.71 354.85 3.000 1299.11 129.73 1169.37 Pass 10007.95 6088.29 6500.00 4863.28 38.01 26.01 355.48 353.51 3.000 1233.15 127.80 1105.35 Pass 9877.60 6084.36 6600.00 4931.17 37.61 26.88 8.85 352.75 3.000 1163.37 124.42 1038.95 Pass 9829.37 6082.65 6700.00 4999.20 37.52 27.36 3.09 352.76 3.000 1092.70 126.78 965.93 Pass 9780.61 6081.29 6800.00 5067.83 37.15 27.65 356.80 352.31 3.000 1022.96 129.56 893.40 Pass 9731.23 6080.31 6900.00 5135.46 36.50 27.76 349.91 351.32 3.000 955.90 132.87 823.03 Pass 9681.84 6079.72 7000.00 5201.49 35.57 27.68 342.38 349.70 3.000 892.63 136.99 755.64 Pass 9634.45 6079.54 7100.00 5267.59 34.46 27.43 334.32 347.31 3.000 832.27 142.24 690.03 Pass 9588.41 6079.64 7200.00 5334.33 33.19 27.02 325.55 344.06 3.000 775.13 148.62 626.51 Pass 9546.39 6079.91 7300.00 5402.03 31.92 26.58 316.31 339.86 3.000 722.06 156.17 565.90 Pass 9508.35 6080.28 7400.00 5470.51 30.71 26.15 306.52 334.63 3.000 674.91 164.56 510.35 Pass 8100.00 5973.78 8100.00 5973.78 34.67 34.43 188.37 0.00 3.000 0.00 206.58 -206.58 FAIL 8200.00 6043.97 8200.00 6043.97 34.86 34.44 188.04 0.00 3.000 0.00 206.85 -206.85 FAIL 8296.32 6083.17 8300.00 6082.81 28.81 28.47 240.51 88.33 3.000 12.91 204.82 -191.91 FAIL 8342.53 6093.17 8400.00 6092.83 24.83 24.55 222.12 89.78 3.000 90.54 168.40 -77.87 FAIL 8362.34 6095.52 8500.00 6092.14 24.16 23.90 213.06 88.93 3.000 182.52 154.64 27.88 Pass 8380.02 6096.55 8600.00 6091.48 23.83 23.59 205.81 88.93 3.000 271.24 143.93 127.31 Pass 8395.75 6096.85 8700.00 6090.69 23.56 23.33 198.95 89.01 3.000 355.63 136.79 218.84 Pass 8407.86 6097.09 8800.00 6087.99 23.47 23.25 193.32 88.82 3.000 442.13 134.37 307.76 Pass 8413.03 6097.20 8900.00 6084.26 23.47 23.27 190.79 88.62 3.000 538.74 134.49 404.25 Pass 8413.45 6097.21 9000.00 6079.71 23.47 23.28 190.41 88.43 3.000 638.52 134.82 503.70 Pass 8414.19 6097.23 9100.00 6074.73 23.47 23.31 189.90 88.25 3.000 738.20 135.14 603.06 Pass 8420.00 6097.35 9200.00 6069.68 23.50 23.36 187.16 88.13 3.000 835.14 135.69 699.44 Pass 8420.00 6097.35 9300.00 6065.49 23.50 23.39 187.06 88.03 3.000 931.43 135.97 795.46 Pass 8420.00 6097.35 9400.00 6062.47 23.50 23.42 187.08 88.05 3.000 1031.14 135.98 895.17 Pass 8420.00 6097.35 9500.00 6059.19 23.50 23.45 187.10 88.07 3.000 1129.77 135.89 993.88 Pass 8420.00 6097.35 9600.00 6053.03 23.50 23.48 186.98 87.95 3.000 1229.05 136.06 1092.99 Pass 8420.00 6097.35 9700.00 6043.47 23.50 23.52 186.71 87.68 3.000 1328.14 136.54 1191.60 Pass 8420.00 6097.35 9800.00 6031.15 23.50 23.56 186.34 87.31 3.000 1423.55 137.27 1286.28 Pass 8420.00 6097.35 9900.00 6021.06 23.50 23.61 186.12 87.09 3.000 1521.37 137.76 1383.61 Pass 8420.00 6097.35 10000.00 6015.66 23.50 23.65 186.10 87.07 3.000 1621.17 137.80 1483.37 Pass 8420.00 6097.35 10100.00 6012.95 23.50 23.70 186.19 87.16 3.000 1720.45 137.63 1582.82 Pass 8420.00 6097.35 10200.00 6007.05 23.50 23.75 186.15 87.12 3.000 1819.93 137.75 1682.18 Pass 8420.00 6097.35 10250.00 6002.85 23.50 23.78 186.09 87.06 3.000 1868.55 137.93 1730.62 Pass Site: KRU 2Z Pad Well: 14 Rale Assigned: Major Risk Wellpath: 2Z-14 VO Inter-Site Error: 0.00 ft Reference Ofteet Semi-Major Aais Ctr-Ctr l~io-Go Allowable 1VID TVD MD TVD Ref Offset TFO+AZI TFO-HS Casieg/HSDistance Area Deviation Warning ft ft ft ft ft ft deg .deg in ft ft ft 11325.00 6120.67 7800.00 5988.37 47.57 23.75 275.28 272.84 2659.24 249.37 2409.86 Pass 11315.29 6120.28 7900.00 6055.60 47.45 23.95 272.65 271.37 2715.20 248.86 2466.34 Pass 11300.00 6119.68 8000.00 6121.67 47.26 24.03 269.45 270.01 2774.56 247.39 2527.17 Pass 11300.00 6119.68 8100.00 6186.48 47.26 24.45 268.11 268.67 2836.98 247.96 2589.02 Pass 11300.00 6119.68 8200.00 6250.60 47.26 24.87 266.84 267.40 2902.18 248.44 2653.74 Pass 11300.00 6119.68 8300.00 6314.68 47.26 25.29 265.63 266.18 2969.44 248.90 2720.55 Pass 11300.00 6119.68 8305.00 6317.89 47.26 25.32 265.57 266.12 2972.86 248.92 2723.94 Pass • ~ a • • a ',§ :viii J1 ~-~rtj~~ k~~~ll~~ ~I~~i~+ lll}1I+I I}I{~{+it tll{l l'TC i~~t1~~ ~Cf~ r5 fr ~_~ ~ t' ~ ~ i a i s i i ? ~ L ~ ' ,t ,;1~~ i} ~-lij ail j~~4 ~~ ~~ +1~1 ~ it ~ 1 } I ti 1. ~ ~~ ~ ~ _ ~, ~}~, 1C+f I Pik. { t r+ . ~~~ ~ ~ r ~+I~~t~ i, r' i ~ ~5 I ~ ~ i ~ ~ II i ~ u 1 ~'i lf.ttt +}!t t +1 i`tt Itl+ t ~ 1 I ~'ti 'Il ~,I_ t'I, II I i ! g ~ 4 ~ I ~ ~I I I i{,i1f t f ifs h ~ i+ ~ ~ ~~}~ ~+~ 4rrt~I(Tr in trT~rTt k~~' ti#f 1-r:T~T~ ~ It ~ ; L i ,_ ~t: i ( 1 1 I i ~I a`k ' ~ ~ ~ I ~ I 1 1~1-all I lj ii I ~ ,i.. 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' , , . ..........e..... s ~ _ -. .. - . i ~ ~' [wnwoU ae•a t~~~ •w RE: 2Z-13 A, et al • Subject: RE: 2Z-13 A, et al From: "Worthington, Aras J" <Aras.Worthngton@bp.com> Date: Thu, 14 Dec 2006 13:09:30 -0900 To: `I1lomas 11~1aunc~er °--tom ~»aunder("~-i-~,admin.statc.ak.us~=° Roger that, Tom. If it looks like we need to add a lateral I'll be on the phone with you asking for a verbal and sending paperwork your way for the added lateral. Cheers, Aras -----Original Message----- From: Thomas Maunder [mailto:tom ma.urder:a~admi.n.state.ak.us] Sent: Thursday, December 14, 2006 12:19 PM To: Worthington, Aras (ConocoPhillips) Cc: Worthington, Aras J; Dave Roby; Steve Davies Subject: 2Z-13 A, et al Aras, In the permit applications for 2Z-13A and -AL1 it is mentioned that additional laterals may be added if the ankerite proves to be too difficult to undulate through. If this becomes the chosen path, additional permits may be necessary. Please stay in touch. Call, or message with any questions. Tom Maunder, PE AOGCC 1 of 1 12/14/2006 1:31 PM • From: "Venhaus, Dan E" <Dan.E.Venhaus~a,conocophillips_com> Date: Thu, 07 Sep 2006 09:5:20 -0800 To: Thomas ~Vlaunder <tom maunder~adm~n.state.ak.us> CC: HubbleTL@BP.com, "~llsup Drake, Sharon K" <Sharon.K.Al~sup-Drake@cor~ocophillips.eom>, "Eder, J Gary" <S.Gary.Eller@conoeo~htllips.corn>, GanttLL@BP.com Torn, We are currently planning on bringing Nordic 2 to Kuparuk for an 8 waif CTD program starting October 1 Oth and completing around February 2007. The candidate list thus far is 1 C-14, 1 C-25: 1 C-20, 1 f_-28; 2Z-13, 30-02, 30-01. 1 C-01 will have a workover prior to the CTD sidetrack, _•..--- As in the past, BP's CT drilling services are being provided to the operator ConocoPhiliips via a Shared Service operation. As such, BP will submit the drilling permits and ConocoPhillips authorizes the delivery of said permits to BP (Terry Hubble). ConocoPhi(lips does request that BP provide a copy of the approved permits. Thanks, Dan Venhaus Wells/CTD Engineer ConocoPhillips AK, Inc. 907-263-4372 office 907-230-0188 cell t of 1 10/16;'2006 12:2 PM • • ss-siv2sz 314 Terri Hubble BP Exploration AK Inc• ^Mastercard Check" PO Box 196612 MB 7-5 ~ ~ 5_~ Anchorage, AK 99519: SATE PAY TO THE ^~ $ I O%~ • C7C7 O ER OF ~ lJ First National Bank Alaska. Anchorage, AK 99501./~ . ~. MEMO ~ ~~i ~F~ .I`~ ~ J/ \ ~:L25:200060~:99L46227L556~~' 0314 • • Ti2ANSMITTAL LETTER CHECKLIST WELL NAME K2~.G z ~ -- ~3~ PTD# 2v~ " ~ ~~ V Development Service Ex lorato Strati ra hic Tes P r3' g p t - Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK i ADD-ONS WHAT ~ (OPTIONS) APPLIES I TEXT FOR APPROVAL LETTER I MliLTI LATERAL ~ The permit is for a new wellbore segment of existing j well (If last two digits i API number in ~ permit No. , API No. 50- - - ~i between 60-69) are ~ ;Production should continue to be reported as a function of the ~ original API number stated above. PILOT HOLE In accordance with 20 A.AC 25.005(f), all records, data and logs 'acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (~0- - -_) from records, data and logs acquired for well SPACING ~ The permit is approved subject to full compliance with 20 AAC EXCEPTION ~ 23.053. Approval to perforate and produce / infect is contingent upon issuance of a conservation order approving a spacing ~ exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH I All dry ditch sample sets submitted to the Commission must be in SAMPLE I no greater than 30' sample intervals from below the permafrost or from where samples are first caught and IO' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: i ~ Well production or production testing of coal bed methane is not allowed ~ for (name of well} until after (Company Name} has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the i Commission to obtain advance approval of such water well testing Rev: V25i06 C:ljodyitransmittal checklist • • ^^ N , , , rn o o_ , N N , m O , : o ~ ( a ~ ~ v~ c ~ o ~ a> N , c o o: m. c ~- ~ c o` 3' ~ ~ m' c o o ~ ~' y a ` ` a, ~ c s •3, a , ! ° °S ~ a iu m, a N ; 3 o, o. ~ ~ ~ ° O ~, . N, , 3. a OO, ~ o. t , ' ' ' ~ _ O N ~ ~ a ` ~; O C _ ~ , , c oa m , N N N ~ ~ d C ~ ~ ~, ~; ~ ~ ~~ d ~ W N ' p. O W~ •_, C. `~ ~ ~ ~•'i N N W N 'N a . O OD , ~ C O . : ~ O ~ ~ O Z i ~ O ~~ , C. ~ ~ ~, ~ ~ ~ p• f0' ~~ O~ ~ ~ L• P N' ~ o a`i U U, U ~ ~, N c ~ .~' a d, ~ ~, ~ Q m, Y ~ N. p. M. M: M, L ~ ~~ C.), N a: N. Or ~ O C: ~ a ~ ~ ~ p, Q ~ O. o. Z. Z. 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