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197-073
STATE OF ALASKA EIV RECEIVED E V vED ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed NUV U 1 2019 Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ CYI�1gQ'7�0/lf6vyegcam ❑ Plug for Retlnll ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ OthFe1�. L eeze 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Dnll Number: 197-073 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 6. API Number: 50-029-22761-00-00 7 Property Designation (Lease Number): ADL 034622 & 365548 S. Well Name and Number: PBU P2-01 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PT MCINTYRE OIL 11. Present Well Condition Summary: Total Depth: measured 10975 feet Plugs measured 10750 feet true vertical 9272 feet Junk measured None feet Effective Depth: measured 10750 feet Packer measured 4705 feet true vertical 9085 feet Packer true vertical 4356 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 60 20" 36-116 36-116 3060 1500 Surface 5438 95/8" 35-5473 35-4957 5750 3090 Intermediate Production 10925 7" 33-10959 33-9258 7240/8160 5410/7020 Liner 9511 4-1/2" 4734-10245 4379-8668 8430 7500 Perforation Depth: Measured depth: 10392 - 10708 feet True vertical depth: 8788-9050 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 31 -4749 31-4391 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 4705 4356 true vertical depth) 4-112" DOS SSV 2126 2124 12. Stimulation or cement squeeze summary: Intervals treated (measured): OA WeIlLock Top Job Squeeze (Surface) Treatment descriptions including volumes used and final pressure: Used 0.75 gals WeIlLock to fill stand pipe and squoze an additional 0.75 gals WeIlLock to increase OAP to 2500 psi (1.50 gallons total WeIlLock used). Monitor OAP & SH Temp for next 24 his. Continue to monitor OA WeIlLock Squeeze until sample is firm. Final Pressures: IA = 975 psi, OA = 0 psi, TBG = 318 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 853 11882 6751 1125 347 Subsequent to operation: 820 11441 6251 2274 335 14. Attachments: (eguiredper20anc25070.25.071.&25.283) 15. Well Class after work: Daily Report of Well Operations 0 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 ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-000 Authorized Name: Lastufka, Joseph N Contact Name: Lastufka, Joseph N Authorized Title: IM Speciali t Contact Email: Joseph. Lastufka@bp.com Authorized Signature: Date: to �1 1 Contact Phone: +1 907 564 4091 Form 10.404 Revised 04/2017 X rein/4 A%&ZZWV*4 =nu_q FIS Nnv n c min �..._.,.__.__,�... Daily Report of Well Operations PBU P2-01 erTIVITVnATF �.........., T/I/O = 340/1100/0 (Pre Wellock). N/D FMC 120 OA valve and N/U 2" integral and block valve. ***Job Complete*** See log. Final WHP's 340/1100/0. Note: Valve left in wellouse and Viton gaskets 9/23/2019 installed in block valve assembly. T/I/O = 310/1040/10. Temp = 142°. Bleed IAP & OAP to 0 psi (WeIlLock Squeeze). AL online. No OA companion valve. 2" block valve installed on OA. Heater installed in wellhouse working properly. IA FL @ 4566', Sta #1 SO (80 bbls). Bled IAP & OAP from 1040/10 psi to 0 psi (all gas) in 1.75 hrs. Ops SI well @ IGV during bleed. Held open bleed on IA/OA for 30 mins. Monitored for 30 mins. IAP unchanged. OAP increased 120 psi. Bled OAP to 0 psi in 5 secs. Bled tree cap to 0 psi & left door open. Final WHPs = 2400/0/0. 10/9/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 1615 hrs. TWO = 2830/0/660. Temp = Si. OA WeIlLock Re -Squeeze. ALP = 30 psi, Sf @ CV & LV. OA cemented to surface. Bled OAP to OT from 660 psi to 0 psi in <1 min (all gas). Monitored OAP for no observable flow for 1 hr. Used 0.75 gals WeIlLock to fill stand pipe and squoze an additional 0.75 gals WeIlLock to increase OAP to 2500 psi (1.50 gallons total WeIlLock used). Monitor OAP & SH Temp for next 24 hrs. 10/10/2019 ***WSR continued on 10/11/19*** Job in progress. ***Continued from 10/10/19 AWGRS*** T/I/O = 2800/0/1350. Temp = SI. Monitor OA (WeIlLock Squeeze). ALP = 50 psi. Continue to monitor OA WeIlLock Squeeze. Increase OAP as needed. Monitored until 11:00, (see log for details). WeIlLock sample on wellhead is the consistency of thick honey. Final WHPs = 2800/0/1510. 10/11/2019 SV, WV = C. SSV, MV = 0. IA, OA = OTG. 11:00 T/I/O = 2800/0/1420. Temp = SI. WHPs & WH Temp (Post WeIlLock). ALP = 70 psi, SI @ CV & LV. WH Temp = 98°. Adjusted heater hose in wellhouse. WeIlLock sample is firm (not hard) and tacky. 10/12/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 21:00. T/I/0 = SSV/0/1380. Temp = SI. WHPs & WH Temp (Post WeIlLock). ALP = 70 psi, SI @ CV & LV. WH Temp = 65°. IAP unchanged, OAP decreased 40 psi, WH temp decreased 33° in 19.5 hrs. Adjust heater trunk in well house. WeIlLock sample is firm and tacky. 10/13/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 16:30 T/I/O = SSV/0/1260. Temp = SI. WHPs & WH Temp (Post WeIlLock). ALP = 70 psi, SI @ CV & LV. WH Temp = 80°. IAP unchanged, OAP decreased 120 psi, WH temp increased 15° in 4 hrs. WeIlLock sample is unchanged. 10/13/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 20:30. TWO = SSV/0/970. Temp = SI. WHPs & WH Temp (Post WeIlLock). ALP = 70 psi, SI @ CV & LV. WH Temp = 50°. Heater taken by instrument techs. Replaced heater and installed heater trunk in wellhouse. IAP unchanged, OAP decreased 410 psi. WeIlLock sample is firm and tacky. 10/14/2019 SV, WV, SSV = C. MV=O. IA, OA = OTG. 21:30 1/1/0=31/0/1100. (Post Welllock). RD OA block valve and intergal flange, RU Gate valve to OA. 10/16/2019 RDMO. ***Job Com lete***. IA/OA=OTG. I T>g= ? WELLHEAD= CNV ACTUATOR= BAKERC KB. ELEV =� 47.15' INf92VAL Opn1Sgz I SHOT KOP= 2498' /Naz Angle = 41-@4201- Tatum W = 10464' Datum TVD=.. _"_8600'SS OA CE MB SURFACE SCAB LNR 26#, L-80 TCIL D = 6276"1136' Minimum ID = 3.725" 10231' OTIS XN NIPPLE 4-12- TEG, 12.13# 13CR80 VAM TOP, .0152 bpf, ID = 3.958" = 6.276" NSCT, .0152 bpf, D = 3.958" 0152 bof. D = 3.958" 1 10246' I FEWORATIONSUMMRY REF LOG: RAT EXP ON 05/02/97 ANGLE AT TOP P9II�: 35" @ 10392' Note: Refer to Pnoducfion DB for historical perf data SIZE SPF INf92VAL Opn1Sgz I SHOT I SQZ 2-12" 4 10392 - 10412 O 05/18197 1 KBG-21 1 KBCi2 3-3/8" 6 10450- 10480 O 08!12197 12/18117 3-318" 6 10564 -10594 O 08/12197 BSE7JMJ GLV 00(01110/18) 3-31W 6 10605 - 10625 O 05/06/02 33/8" 6 10648-10708 O 08/12/97 m 7" CSG, 26#, MR SAFETY NOTES: WELL REQUIRES A SSSV. P2_01 "`CHROME4-12"TBG, 4-112" SCAR LNR 87"CSG HES HXO SLV NIP, D - 3.813" (.AS I IFTLMNEY]R C ST I M) TVD I DEA/ I TYPE I VLV LATCH FORT DATE 2 1 1 4276 4566 4021 4245 41 38 1 KBG-21 1 KBCi2 OW SO BK SK 0 20 04/08!06 01/10118 4-12" BKR S-3 PKR D = 3.87" i 5" BKR ZXP LNR TOP PKK w / FLIX-LOC LNR FNGR D = 4.430" !" WLEG D 10160' BKR BALL 8 SEAT SUB 13T X TCI XO, D = 392- 7"X4 -1)2' 92" 7"X4-12' W. { 1VZ31--T4-1/" 0MXNW,,1D=3.725' 10246' 4-1/2" WLEG, D=3.958' 10236' t3MDT7 LOGG®OS/13/97 DATE REV BY C7MaB4fS DATE Rel BY 05!06197 ORIGINAL COMPLETION 03118014 PJC PI3iF CORRECTION 03/06/06 M6 I WO 0920117 JPWJMD GLV 00(03/08108) 10117/08 JLOPJC PERF CORRECTION 12106/17 ZV/JMD GLV 00 (1128117) 02/18/11 M9/JMD ADD®SSSV SAFETY NOTE 12/18117 JLSUM)20067"CORMCTIDNS 03/14/12 MSSIJM) FISH(03/06/12) 01117118 BSE7JMJ GLV 00(01110/18) 04/06/12 1 EV. M) PULL.® RSH (04106112) PONT MCIN TY FE UNT WELL P2-01 PEFMT No' 1970730 AH No: 50-029-22761-00 SEC 11, T12K RME� 3918.04' FELS 37229 FNL BP Exploration (Alaska) THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Travis Montgomery Interventions and Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Pt McIntyre Oil Pool, PBU P2-01 Permit to Drill Number: 197-073 Sundry Number: 319-400 Dear Mr. Montgomery: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .00gcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this`ay of September, 2019. 3BDMS(� SEP 0 5 20, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request. Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other OA WeIILock Squeeze 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0 5. Permit to Drill Number 197-073 ' 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612Stratigrephic ❑ Service ❑ 6. API Number: 50-029-22761-00-00 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PBU P2-01 9. Property Designation (Lease Number): 10. Field/Pools: ADL 0346228 365548• PRUDHOE BAY. PT MCINTVRE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(fq Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10975 9272 10750 9065 10750 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 36-116 35-115 3060 1500 Surface 5438 9-5/81• 35-5473 35-4957 5750 3090 Intermediate Production 10925 7" 33-10959 33-9258 7240 / 8160 5410 / 7020 Liner 9511 4-1/2" 4734- 10245 4379 - 8668 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10392 - 10708 8788 - 9050 4-1/2•• 12.6# 13Cr80 31 -4749 Packers and SSSV Type: 4-1/2" Baker S-3 Perm Packer Packers and SSSV MD (ft) and TVD (ft): 4705 / 4356 41/2'• DOS SSV 2126 / 2124 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigrephic ❑ Development 0 ' Service ❑ 14. Estimated Date for Commencing Operations: September 8, 2019 15. Well Status after proposed work: Oil 0- WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Montgomery, Travis J be deviated from without prior written approval. Contact Email: Travis.Montgomeryiftibp.com Authorized Name: Montgomery, Travis J Contact Phone: +1 907 564 4127 Authorized Title: Interventions & Integrity Engineer Authorized Signature: ) .�wiJ / Date: elz'o COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ^ 1 ry I q 0 O `V I V Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ih Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ / Spacing Exception Required? Yes ❑ No GY/ Subsequent Form Required. IO —40 It APPROVED BVTHE Approved by: COMMISSIONER COMMISSION 'Date: I IgII` Form 10-403 Revised 04/2017 ORIGINAL RMSkM` SEP052019 I"`41140Y"- r l Submit Form and Approved application is valid for 12 months from the date of approval. ��i� Attachmen in Duplicate) 3/) 770 �" by Well: P2-01 P2-01 OA WeIlLock Squeeze Well Interventions Engineer: Travis Montgomery (907) 564-4127 Pad Engineer: Katie Burton (907) 564-5554 History P2-01 is a gas -lifted well completed in 2006. On 12/28/17, the well was flagged for high OAP as well as anomalous IA and OA pressures and was placed under evaluation. A PPPOT-IC had Passed on 11/13/17. OA gas sampling from 11/16/17 indicated that the source was external. A TIFL Failed on 12/29/17. Although Slickline obtained a passing MIT -IA during a GLV changeout on 1/10/18, OAP continued to rise and be unmanageable by bleeds even when GL was SI and IAP was below OAP. OAP appeared to rise quicker when GL was on. WeIlLock was squeezed into the OA to mitigate the repressurization. On 8/19/19, the OA was reported to have anomalous casing pressure above Normal Operating Limit (NOL). The OA repressurization was mitigated when DHD bled down the IAP. The rapid OA repressurization indicates that the WeIlLock squeeze has broken down and IAxOA communication exists. This program is to repeat the WeIlLock OA squeeze. Current Status The well is classified as "Under Eval." Objective Squeeze the OA with WeIlLock to mitigate OA repressurization Procedure 1. ND OA Gate Valves, NU OA Integrals. 2. Bleed Annuli, prep OA, WeIlLock OA top job squeeze to 2500 psi per RPs. WR1/F ACTUATOR= BAKER KB. ELEV = 47.15' BF. ELEV = SIZE KOP= 2498' Max Angle = 41° Q 4201' Datum MD = 10464' Datum TVD = 8800'SS Minimum ID = 3.725" @ 10231' OTIS XN NIPPLE t-12' TBG, 12.6# 13CR80 VAM TOP, 0152 bpf. ID = 3.958' 4-1lY SCAB LNR, 12.6#, 13CR80 NSC!, 10098' .0152 bpf, D = 3 958' .0152 bPf, D = 3.958' 4-12' TBG, 12.8#, 13CR .0152 bpf , D = 3.958' —F 0246'— FEiFORATIONSLAWRI REF LOG: PLAT EXP ON 05/02/97 ANGLEAT TOPPERF: 35-@1039Z Note: Fifer to Prodwbon DB for historical pert data SIZE SPF INTERVAL Opn/Sgz SHOT SO2 2-11T 4 10392 - 10412 O 05/18/97 ZV/JMD GLV (YO (1128117) 3-3/8' 6 10450-10480 0 08/12197 01/17/18 3-318' 6 10564-10594 0 08/12/97 3318' 6 10605 - 10625 O 05/06/02 3-3/8' 6 10648-10708 O 08112197 7' CSG 26#. 13CR D = 6.276' P2-01 SAFETY NOTES: WELL REQUIRES A SSSV. —CHROME4-12- TBG, 4-112' SCAB LNR. & 7- CSG— TAM PORT COLLAR -rx roto SLVNP,D= GAS LIFT VANDR9_S ST I MD I ND I DEV I TYPE I VLV I LATCHI FORT DATE 2 1 1 4276 140211 4566 42451 41 38 1 KBG-2 1 KB( DMI I BK SO BK 1 0 20 04108106 01/10/18 1 10149' {—j4-12'SKRPE PUP(CEPAWHi)J 10160' BKR BALL & SEAT SL)B BTXTCIXO,D-3.92' 1022W 4-1/2- OTIS X NP, D= 3.813' 101 231' 4-1/2' OTIS XN NP, D = 3.725' { 10245' 1 -14 -112 - VN -EG, D = 3,956- 1 10236' B -MD TT LOGGED 05/13/97 DATE RBI BY COWJENTS 4630' 4686' 4-1/2' FES X NP. D = 3.813' 7' X 4-12' BKR S3 R(R 10=3.B7 4721'4-1/7 FES X NP, D = 3.813' 4727 7-X5-BKRZXPLN2TOPR(Rwl BKR FLB(-LOC LNR HNGR D = 4.430' 1 10149' {—j4-12'SKRPE PUP(CEPAWHi)J 10160' BKR BALL & SEAT SL)B BTXTCIXO,D-3.92' 1022W 4-1/2- OTIS X NP, D= 3.813' 101 231' 4-1/2' OTIS XN NP, D = 3.725' { 10245' 1 -14 -112 - VN -EG, D = 3,956- 1 10236' B -MD TT LOGGED 05/13/97 DATE RBI BY COWJENTS DATE REV BY COMMINTS 05108197 ORIGINALCOMPLETTON 03/18/14 PJC FE7F CORRECTION 0310=6 MPS RWO 09/20/17 Jn(1JMD GLV C/O(03108/08) 10/17/08 JLCJPJC PEW CORRECTION 12/06/17 ZV/JMD GLV (YO (1128117) 02/18/11 ME/JMD ADDED SSSV SAFETY NOTE 12/18/17 JLS/JMD 20067' CORRECTIONS 03/14112 MSS/JMD F15H(03(06/12) 01/17/18 BSBJMI GLV 00(01110/18) 04/06112 LECJJMD PLA -LED FISH (04106112) PONT MICH Y RE UHT WELL. P2-01 PERM! No '1970730 AH No: 50-029-22761-00 SEC 11. TI 2N. R14E. 3918.04' FEL & 3722.9 FW BP Exploration (Alaska) STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION CO ION REPORT OF SUNDRY WELL OPE NS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redd! 0 Perforate New Pool 0 Repair Well I1 Re-enter Susp Well 0 Other:OA WeIlLock Squeeze 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number. 197-073 3. Address: P.O.Box 196612 Anchorage, Development II Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22761-00-00 7. Property Designation(Lease Number): ADL 365548&034622 8. Well Name and Number: Pet(P2-01 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PT MCINTYRE OIL F.r u._,, 11.Present Well Condition Summary: h •t E IVSD Total Depth: measured 10975 feet Plugs measured 10750 feet true vertical 9272 feet Junk measured None feet APR 18 2018 Effective Depth: measured 10750 feet Packer measured 4705 feet true vertical 9085 feet Packer true vertical 4356 feet AOG(V Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 36-116 36-116 3060 1500 Surface 5438 9-5/8" 35-5473 35-4957 5750 3090 Intermediate Production 10925 7" 33-10959 33-9258 7240/8160 5410/7020 Liner 5511 4-1/2" 4734-10245 4379-8668 8430 7500 Perforation Depth: Measured depth: 10392-10708 feet i ) / , True vertical depth: 8788-9050 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 31-4749 31 -4391 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 4705 4356 true vertical depth) 4-1/2"DOS SSV 2126 2124 12.Stimulation'or cement squeeze summary: Intervals treated(measured): OA Cemented to surface.OA down squeeze performed with HES WeIlLock.Pumped 3.5 gallons of WeIlLock into OA before seeing pressure increase.Once at recommended squeeze pressure monitored at 30 min intervals until minimal pressure loss.Daily monitors conducted by DHD getting pressures and temp on spool for fourteen days. Well sample setup hard. Treatment descriptions including volumes used and final pressure: Pumped 3.5 gallons of WeIlLock into OA.Final IA Pressure=37 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 640 7912 7257 2490 321 Subsequent to operation: No Test Available 37 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory 0 Development p Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil El Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 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: 318-025 Authorized Name: Worthington,Aras J Contact Name: Worthington,Aras J Authorized Title: Intery tions&Integrity En•ineer � /�� Contact Email: Aras.Worthington(o�bp.com Authorized Signature: !/ Date: �p �Jg Contact Phone: +1 907 564 4102 Form 10-404 Revised 04/2017olit 0/73( V-/-/ 4 127-/l RBDMS APR Z 3 2018 Submit Original Only / ,i lL! Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report Of Sundry Well Operations (10-404) April 17, 2018 To Whom it May Concern: Attached please find the Report Of Sundry Well Operations for Repair Well (OA Welllock Squeeze), covered under Approved Sundry#318-025 for Well PBU P1-02, PTD #197-073. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • S Daily Report of Well Operations PBU P2-01 ACTIVITYDATE SUMMARY T/I/O=SSV/0/150. Pre Wellock Treatment. N/D 2"FMC 120 OA valve and N/U 2"integral and block valve. ***Job Complete***See log. Final WHP's SSV/0/0. Note:Valve left in wellouse and Viton 3/19/2018 gaskets installed in block valve assembly. T/I/O=SSV/0/160. Temp=SI. OA down squeeze(prep). AL SI @ CV,ALP=2520 psi. Preform 1 hr LTI (PASS), preform LDD on OA found—15"void to hard bottom with fluid in it, reinstall 2"block valve. Install heater in well house, bled treecap to 0 psi. 3/24/2018 SV,WV, SSV=C. MV=O. IA, OA=OTG. 12:30 T/I/O=SSV/8/140. Temp=SI. OA down squeeze(prep). AL SI @ CV,ALP=2520 psi. Preform 1 hr LTI (PASS). Remove 2" block valve and flush OA void several times with 140°fresh water then use barrel pump to evacuate water from OA, reinstall 2"block valve cap and rosemont gauge. Heater in well house, bled treecap to 0 psi and back door left ajar. 3/25/2018 SV,WV, SSV=C. MV=O. IA, OA=OTG. 17:00 T/I/O=SSV/8/100. Temp Well SI. OA spool temp=90° Job Scope: OA down sqz w/HES WeIlLock. Pumped 3.5 gallons of WeIlLock into OA before seeing pressure increase. Once at recommended squeeze pressure monitored at 15 min intervals over 4 hour period. Continued process at 30 min intervals until minimal pressure loss. left 1500 psi pressure on OA. Daily monitors will be conducted by DHD getting pressures and temp on spool piece for fourteen days. Well secured and DSO notified of well condition. Note: Caution tags hung on OA stating Viton seals in 1502 connections temp rating of-20 deg F thru 400 deg. F. Post WeIlLock Treatment. POP well under eval after 14 days of curing resin. 3/27/2018 ***Activity complete*** T/I/O=SSV/8/900. Temp=SI. WHPs(post Wellock). AL SI @ casing valve,ALP=2520 psi. OA spool temp= 100°. OA casing valve's removed, intergal installed with cap and gauge. OAP decreased 600 psi psi since 3/27/18. OA spool temp decreased 100°, moved heater trunk away. Sample not set up. Heater working fine,tree cap bled. 3/28/2018 SV=C. WV, SSV, MV=O. IA, OA=OTG. 10:30 TWO=SSV/8/110. Temp=SI. WHPs(post Wellock). AL SI @ casing valve,ALP=2520 psi. OA spool temp= 150°. OA casing valve's removed, intergal installed with cap and gauge. OAP decreased 890 psi psi since 3/27/18. OA spool temp increased 50°, moved heater trunk away and left door open. Sample not set up. Heater working fine,tree cap bled. 3/29/2018 SV=C. WV, SSV, MV=O. IA, OA=OTG. 10:00 T/I/O=SSV/8/110. Temp=SI. WHPs(post Wellock). AL SI @ CV,ALP=2440 psi. OA spool temp= 160°. OAP unchanged since monitor on 3/29/18. Sample appears to be set up and hard. Heater working. Bled tree cap. 3/31/2018 SV,WV, SSV=C. MV=O. IA, OA=OTG. 03:15 T/I/O=SSV/8/180. Temp=SI. WHPs(post wellock). ALP=2440 psi, SI @ CV. OA SH spool= 68°. IAP unchanged, OAP increased 70 psi from 02:30 hrs. 4/1/2018 SV,WV, SSV=C. MV=O. IA, OA=OTG. 21:00 T/I/O=SSV/8/110. Temp=SI. WHPs(post Wellock). AL SI @ CV,ALP=2440 psi. OA spool temp= 105°. OAP unchanged overnight. Sample appears to be set up and hard. Heater working. Bled tree cap. 4/1/2018 SV,WV, SSV=C. MV=O. IA, OA=OTG. 02:30 T/I/O=SSV/10/240. Temp=SI. WHPs(Post Wellock). AL SI @ CV,ALP=2440 Psi. OA SH Spool= 102°. IAP increased 2 psi, OAP increased 60 psi overnight. 4/2/2018 SV,WV, SSV=C. MV=O. IA, OA=OTG. 16:00 T/I/O=SSV/10/240. Temp=SI. WHP's. (Post wellock). ALP=2440 psi&SI @ IA casing valve. No change in WHP's since day shift. 4/3/2018 SV,WV, SSV=C. MV=O. IA, OA=OTG. 01:42. T/I/O=SSV/10/240. Temp=SI. WHPs(Post Wellock). ALP=2440 psi, SI @ CV. OA SH Spool = 106°. Heater working properly. WHPs unchanged overnight. 4/4/2018 SV,WV, SSV=C. MV=O. IA, OA=OTG. 00:30 • Daily Report of Well Operations PBU P2-01 T/I/0=SSV/30/110. Temp=SI. WHPs(Post Wellock). ALP=2540 psi, SI @ CV. OA SH Spool = 108°. IAP increased 20 psi, OAP decreased 130 psi since 04/04/18. Heater installed in wellhouse and working properly. 4/6/2018 SV,WV, SSV=C. MV=O. IA, OA=OTG. 14:00 T/I/0=SSV/40/120. Temp=SI. WHPs(post wellock). ALP=2440 psi&SI @ casing valve. OA spool=78°. IAP increased 10 psi, OAP increased 10 psi since 4/6/18. Sample is set up(hard). Heater in wellhouse&working properly. 4/7/2018 SV,WV, SSV=C. MV=O. IA, OA=OTG. 15:00 T/I/0=SSV/40/120. Temp=SI. WHPs(Post Wellock). ALP=2540 Psi, SI @ CV. OA Spool= 72°. WHPs unchanged overnight. The OA outlet has a 1502 Intergal W/a 1502 cap RU on the casing spool,the jewelery consists of a 1/2"(1/4 turn)that is full of well lock and cannot be shut and a 1/2"6"riser with 3000 psi analog gauge. Heater installed inside wellhouse and is working properly. 4/8/2018 SV=C. WV, SSV, MV=O. IA, OA=OTG. 15:30 T/I/0=SSV/40/0. Temp=SI. RU OA casing valve(Post wellock). AL SI @ casing valve(2540). Rigged down OA integral flange. Rigged up 2"casing valve(OA,torqued to 188 ft lbs). No OA companion opening. FWPs=SSV/40/0. 4/11/2018 SV,WV, SSV=C. MV=O. IA, OA=OTG. 1100 hrs. T/I/0=SSV/40/60. Temp=SI. WHPs(Post Wellock). ALP=2540 psi, SI @ CV. OA SH Spool= 60°. IAP unchanged, OAP decreased 60 psi since 04/08/18. Unable to SI 1/2" 1/4 turn valve on OA jewelery, OAP taken from 3000 psi analog gauge. Heater installed in wellhouse and working properly. 4/11/2018 SV,WV, SSV=C. MV=O. IA, OA=OTG. 00:30 T/I/0=SSV/40NAC. Temp=SI. WHPs(Post Wellock). ALP=2440 psi,AL SI @ casing valve. WHPs unchanged overnight. 4/12/2018 SV, SSV=C. WV= LOTO. MV=O. IA, OA=OTG. 11:45 Fluids Summary Gallons Type 3.5 HES We!LLock T1 FETY NOTPS: WELL REQt11RES A SSSV. VU�LHEAD CANIII SG+» ACTUATOR BAKER C P 2-0 1 11 E 4-112"TBG.4-1/2"SCAB LNRS&7"G KB.E .EV= 47.15' BF.ELEl/= OA CEMENTED TO 1" • Ai 1133` 17"TAM PORT COLLAR KOP= 2498' SURFACE(02/27/06) 147 VMax Angle= 41"n 4201' 1�i 114 2119' 4-1/2"HES HXO SLV NP,D 3.813" E tum M)= 10464' QI 0111 Datum 1VD= 8800'SS 1�1 �1' GAS UFT MANDRELS 111 114, ST PA) TVD DEV TYPE VLV LATCH PORT DATE 11 2 4276 4021 41 KBG-2 DMY BK 0 04/08/06 7"SCAB LNR,26#,L-80 TCtI,D=8.276" —� 1136' 111 iA 1 1 4566 4245 38 KBG-2 SO BK 20 01/10/18 111 is 4630' —{4 1t2"i S X NP,D=3.813" Minimum ID =3.725„ @ 10231' A 11i OTIS XN NIPPLE 111 lipIDs 4698' H7”x 4-1/2"BKR 5-3 PKR,D=3.87" 1 /./ ..,TA ►411j 1111 . 4721' --I4-1/2"FES X Rte,ID 3.813' .5 1'1 4727' —{7"X 5"BKR 2XP LNR TOP PKR,w/ 111 11� I BKR FLEX-LOC LNR t1VGR,D=4.430" 4-1/2"TBG,12.6#13GR80 YAM TOP, H 4742' 111 [ 4742' 1-14-1/2"WLEG,C_3.958", li .0152 bpf,ID=3.958" �11►111 �Ii� f: 4764' —15"X 4-1/2"XO,D=3.950" 11111111 1111,111 9-5/8"CSG.40#,L-80,ID=8.835" H 6473" •A 11 11`• 1111 1111 •51 1.1 1111 111 7"CSG 26#,L-80,D=6276" H 10040' 11 11 1111 111 4-1/2"SCAB LNR 12.6#,13GR80 NSCT, H 10098' AA NX11/ .0152 bpf,D=3.958" 1111 111 11�` X11 10149' j-14-1/2"BKR PERF PUP(CBBvTER) 1111 111 1111 111 4-112'SCAB LNR 12.6#,L-80 BTC, H 10149' 1 111 10160' BKR BALL&SEAT SUB .0152 bpf,D=3.958" 1.11 5' ET X TCI XO,D=3,92" 1111 111 1111 1111 11/•f 11 j 10179' —{ IN E MACHOVERSHOT 14-1/2"TUBING STUB(02/10/06) H 10184'ELMD .1.4� ,1 44�4 1 10189' f H 7"X 4-1/2"BKR S-3 PIM D=3.875" 10220' 14-1/2"OTIS X NP,D=3.813" 4-1/2"TBG,12.6#,13CR.0152 bpf.M:)=3.958" I-i 10246' 10231' H4-i/2"OTIS XN NP,D=3.725" • PERFORATION SUMMARY 10246' —1-1/2"WIEG 13=3.958" REF LOG:FLAT EXP ON 05/02/97 10236' H ELMD TT LOGGED 05/13/97 ANGLE AT TOP PERF:35"@ 10392' Note:Refer to Production CO for historical perf data SIZE SPF IYTSNAL Opn/Sq7 SHOT SOZ 2-1/2" 4 10392-10412 0 05/18197 3-3/8" 6 10450-10480 0 08/12/97 3-3/8" 6 10564-10594 0 08/12/97 3-3/8" 6 10605-10625 0 05/06/02 3-38" 6 10648-10708 0 08/12/97 10760'CTM —TOP OF SAND(03/20/06) FBTD H 10879' •1.1.1.1.1.1.1.1.111.1 7"cSG,26#,13CR D=6.276" —{ 10968' 1.1.1.1.1.1.1.1.1.1.1. GATE Rel/BY CCI FLATS DATE REV BY COM4B4TS POINT MCNTY RE UNIT 05/06/97 ORIGINAL COMPLETION 03/18/14 PJC PERE CORRECTION WR3L: P2-01 03/06/06 N7E5 RWO 09/20/17 .EK/JMD GLV C/0(03/08/08) PERMIT No:"`1970730 10/17/08 ,LC/PJC PERF CORRECTION 12/06/17 ZV/JM) GLV C1O(11/28/17) AR No: 50-029-22761-00 02/18/11 M3/JMD ADDED SSSV SAFETY NOTE 12/18/17 .ES/JM) 2006 7"CORRECTIONS SEC 11,T12N,R14E,3918.04'FE..&3722.9'EN_ 03/14/12 MSS/JMO FISH(03/06/12) 01/17/18 BSE/JMD GLV C/O(01/10/18) 04/06/12 LEC/JM) PULLED FISH(04/06/12) BP Exploration(Alaska) OF Tit • • aw)" //7, 4. THE STATE Alaska Oil and Gas Nff�: 714, ®fA LAsKA Conservation Commission x 333 West Seventh Avenue ,trIIGOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 O .-•1FAr Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Aras Worthington 4 Interventions and Integrity Engineer tiNED BP Exploration(Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Pt McIntyre Oil Pool, PBU P2-01 Permit to Drill Number: 197-073 Sundry Number: 318-025 Dear Mr. Worthington: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P Cathy . Foerster Commissioner DATED this I1day of February, 2018. Rpr:ii'.S L FE - _018 STATE OF ALASKA RECEIVED • ALASKA OIL AND GAS CONSERVATION COM ION S 2 /G l gi APPLICATION FOR SUNDRY APPRO LS JAN 18 20 AAC 25.280 2018 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well RI • Operations shutdown 0 Suspend 0 Perforate p0 Other Stimulate 0 Pull Tubing 0 Chan C❑ Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other OA WellLock Squeeze gl' 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 197-073 • Exploratory 0 Development p, 3. Address: P.O.Box 196612 Anchorage,AK 6. API Number 50-029-22761-00-00 ' 99519-6612 Stratigraphic 0 Service ❑ 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No ® PBU P2-01 • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 365548&034622 ' PRUDHOE BAY,PT MCINTYRE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 10975 • 9272 • 10750 9085 10750 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 36-115 36-115 3060 1500 Surface 5438 9-5/8" 35-5473 35-4957 5750 3090 Intermediate Production 10925 7" 33-10959 33-9258 7240/8160 5410/7020 Liner 5511 4-1/2" 4734-10245 4379-8668 8430 7500 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10392-10708 8788-9050 4-1/2"12.6# 13Cr80 31-4749 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and TVD(ft): 4705/4356 4-1/2"DOS SSV 2126/2124 12.Attachments: Proposal Summary RI Wellbore Schematic 10 13.Well Class after proposed work: • Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 10 Service 0 14.Estimated Date for Commencing Operations: February 1,2018 15. Well Status after proposed work: Oil 0 • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR ❑ SPLUG 0 Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Worthington,Aras J be deviated from without prior written approval. Contact Email: Aras.Worthington©bp.com Authorized Name: Worthington,Ares J Contact Phone: +1 907 564 4102 Authorized Title: Intery tions&Integrity Engine j Authorized Signature: Date: //f�/A�)g• COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test 0 Location Clearance ❑ 2-S Other: F`L'i SS LC E5 G. r p Post Initial Injection MIT Req'd? Yes❑ No �/ '�7 ��-� - tU�p Spacing Exception Required? Yes 0 No Et Subsequent Form Required: / t ' /r 4' APPROVED BYTHE r/ Approved by:ate" COMMISSIONER COMMISSION Date:2_f T(8 r T L 2/`2/18 ORIGINAL /0. f e_c::/s5 le0fif Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • la • lth Well: P2-01 P2-01 OA WeIlLock Squeeze Well Interventions Engineer: Aras Worthington (907) 440-7692 Pad Engineer: Kaity Burton (907) 564-5554 History P2-01 is a gas lifted well currently flowing unassisted due to MI influence in the area. It is a prolific high WC well but still very competitive at PM2 and GC1. On 12/28 the well was flagged for high OAP as well as anomalous IA and OA pressures and was placed under evaluation. A TIFL was conducted 12/29 and failed. 01/10 SL came and loaded, set a plug, set dummy GLV and MITIA which passed. OAP has continued to rise and be unmanageable by bleeds even in durations when GL was SI and IAP was below OAP. Gas sampling indicates the source is external. A PPPOT IC passed 11/13/17. Path forward is for DHD to troubleshoot IAP re-pressurization which may be due to leaking casing valves. Monitor the OAP build-up rate with well SI. A Well lock treatment will then be squeezed into the cemented OA to mitigate the repressurization and pending success the well can be brought back to operable status with live GLVs. Current Status The well is currently shut-in and will be classified as "Not-Operable" by BP. Objective Squeeze the cemented OA with Well Lock to seal off the OA repressurization. Procedure 1. ND OA Gate Valve, NU OA Integral. 2. Bleed Annuli, Prep OA, WeIlLock OA top job squeeze to 2500 psi per RPs. • ID SAFLT"1'*1111, 14/Lit, Hi...Lb:AWL.,A • 4 ' i i P2-01 ,,tcH101447*4 1,7••TN, I -r- 1 4 ' I ••••••40.,—.1 1 133• , - ••,,•,,,„t,., „, I • X X,'--"f 2119' .14-1,,, 0 '"Ai __ LI-I 74474.4*ES k 4 ST (VD {TVD DEV TYPE VLV LATCH PORT BATE 1.44 14'0 *(iii. r-4276 40211' 41 KBG-2 CON BA 0 0443005 /t' r•ik,/ 1 4566142452.0 K13O2 SO INK 20 11/2417 , t ( (Xf 430" .14er HE'S 4 4P 0-14113* 1 Nt n -1 I a ID ","L a.,,. 10414,, ' '" 111 V.,' 0,......,.., (fir„.4 mor 1 r X X-vr 1POI 3-3 POI,117-3 sr 0- NI Is XN PPy ...E 4.4 410 'i 4721* H4-1,77f5 X 0?D 3$ir 1 _.........._.„ 144. 00 472T $-r A 5' 14 M 244 1, I TOP FUR 14,. ....,..;4.:X.0,..---t . SW HU ICC IAN 144M11,It 4 4.110* A 4 4 Fiz x,/t.,,,,,,,..,1 41,12 ,4 lir 04.83 D. rjr ,_ • t $3,77.100 vAm t t 4, li,/ Al 4 Of fif x x', 1:4 4164 . 15::x 4-o2 AO.I -30 $i 07 .A • ' 1 4 # ## #4#. I 7'CSG no 1.-60 D-0 • „i. $$ 441 g 14_1 IT SCA 0 LW,12 44,130441=CT 1.--; 14044* 0152 W,0-3155' 1 0 . .?„ _ • * . i 144417 1 14.t It•FIA*R RSV Fir tc1F44441110 1 44 ) .'YX'';'; 1014, 41 + [ 10100" ,-.•1.4 A',IA.( ET IL*40 0 v 3 ftT • 4. * * • X • 44 lain' t-440„),A.toc347,4LcsalsHt _ 4 i 4 ' - 1016.4.ELMO 41 P 4 1071.w •-•17 4.4 ter SKR S•3 PM,0.3 475° , .1--10220 • fx-yr cst%x vs,rt-1 sir 1 1024C N. 1 10231r --4.19,OTS 47414P 0,,,,17 — - - • ,- 1 4024r 4 l'Z'Ykti.x., La-.1 isr MARAS RON 44444646* - - PO LOG RAT CAPON 4, .•• .7 1073,4t ii tiX1.11 rk1449,35,)13,07 AMU.AT MN W.103112 NE40 flittat M' •• . • FM 444 hisbm44perf dale - •'4 MI 1', At 4• , 44474 KW 1 4 1,, • 12 • I i.„ 1-• 3-3r * IOW-MOO . 0 WNW' 34W 4 10944 IONS • 0 4*12647 414. 4 , 1- . , . 0 (44414/W 1-341* 4 4 taw . + . 0 0012707 • . -.- _ - 10740`C TM.,. -1OP 07 SAND/037204341 1 _ t POW 1i-1-10417T Oftttfttiktt littifitiffl ri.,-,sa,woo wit I)-4 774- f--- 141444' .-----_---„ __ DATE REV BY ommirs -r wit Fri By ' crs4tioN --- PONT briKEYREL040 015,0607 -ORIGPIAL COMPLETION ni&14 PK PEW COHLTUN *NELL P2-01 011M06 ICES MMO Nr20r17 14v-I1013 GLM 00 0008M) MORT OM 40370730 _ nt.,1711.43 A OPr. PRO-clifffa414 1 fx.)44 67 ?VM I GI/00 i WADI 71 AR ivio U1-029-22761-40 4 MIUM.41) AOCED SST/SAFETY WM 121871, A 87,1147 2006 C'(TY447-CDONS SEC 11,TIM,f464€OM 04 f-EI s Icn V 144 3•1,14,1,1'M5St.NAD FEHOMI€712) pi - 540€'12 LLOJAV PULLED FE4111)406112), EIP Bt4t4f4itift 1,410141141 2 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Alaska 99519 -6612 May 20, 2012 5LAiliNED AUG O 20)l Mr. Jim Regg rt. 093 Op Alaska Oil and Gas Conservation Commission 333 West 7 Avenue t Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA PM -2 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA PM -2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, )°( Mehreen Vazir BPXA, Well Integrity Coordinator • . i BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) GPMA PM -2 Date: 0413W2012 Corrosion Vol. of cement Final top of Cement top Corrosion inhibitor/ sealant Well Name PTD # API # Initial top of cement pumped cement off date inhibitor date ft bbls ft na gal -. P2 -01 1970730 _ 50029227610000 0.3 NA 0.3 NA 1.70 6/22/2009 P2 -03 1970440 50029227490000 2.0 NA 2.0 NA 10.20 6/22/2009 P2 -04 1981560 50029229070000 1.0 NA 1.0 NA 5.10 6/22/2009 P2-06 1931030 50029223880000 4.0 NA 4.0 NA 30.60 6/22/2009 P2 -07 1940580 50029224690000 2.0 NA 2.0 NA 13.60 6/22/2009 P2 -08A 2061690 50029228960100 0.8 NA 0.8 NA 4.30 6/21/2009 P2 -09 1980660 50029228760000 0.3 NA 0.3 NA 0.85 6/21/2009 P2 -10 1980970 50029228860000 0.3 NA 0.3 NA 1.70 6/21/2009 P2 -11A 2060260 50029229230100 3.5 NA 3.5 NA 69.70 6/21/2009 P2 -12 1931150 50029223950000 Sealed conductor NA NA NA NA NA P2 -13 1970600 50029227570000 0.5 NA 0.5 NA 2.60 6/21/2009 P2 -14 1981050 50029228880000 1.5 NA 1.5 NA 10.20 6/21/2009 P2 -15A 2070320 50029224090100 Sealed conductor NA NA NA NA NA P2 -16 1931230 50029223970000 3.0 NA 3.0 NA 28.10 6/20/2009 P2 -17 1981370 50029229020000 0.8 NA 0.8 NA 3.40 6/20/2009 P2 -18 1940600 50029224710000 0.8 NA 0.8 NA 2.60 6/20/2009 P2 -19A 2070120 50029227650100 0.3 NA 0.3 NA 0.90 6/20/2009 P2 -20 1960590 50029226640000 0.5 NA 0.5 NA 2.60 6/20/2009 P2 -21 1940530 50029224670000 0.8 NA 0.8 NA 3.40 6/20/2009 P2 -22 1972490 50029228500000 1.0 NA 1.0 NA 7.70 6/20/2009 P2 -23 1940320 50029224530000 1.3 NA 1.3 NA 11.10 6/20/2009 P2 -24 1980080 50029228540000 1.5 NA 1.5 NA 10.20 6/15/2009 P2 -25 1971110 50029227760000 1.8 NA 1.8 NA 17.90 6/10/2009 P2 -27 1971250 50029227850000 1.3 NA 1.3 NA 8.50 6/10/2009 P2 -28 1950440 50029225510000 3.3 NA 3.3 NA 37.40 4/18/2012 P2 -29 1931470 50029224070000 10.3 NA 10.3 NA 71.40 6/15/2009 P2 -30 1920950 50029222890000 2.8 NA 2.8 NA 17.90 6/10/2009 P2 -31 1940360 50029224560000 2.2 NA 2.2 NA 21.30 6/20/2009 P2 -32 1951350 50029225930000 Surface casing leak NA NA NA NA NA P2 -33B 1972310 50029228120200 2.0 NA 2.0 NA 16.60 6/9/2009 P2 -34 1950660 50029225580000 1.5 NA 1.5 NA 11.50 6/9/2009 P2 -35 1951790 50029226200000 1.0 NA 1.0 NA 13.60 6/9/2009 P2 -36A 2060220 50029228010100 1.1 NA 1.1 NA 6.00 6/9/2009 P2 -37A 2050570 50029225760100 2.0 NA 2.0 NA 23.00 6/9/2009 P2 -39 2111230 50029234540000 0.8 NA 0.8 NA 10.20 4/30/2012 P2-40 1972260 50029228370000 0.5 NA 0.5 NA 5.10 6/9/2009 P2 -41 1952050 50029226330000 1.5 NA 1.5 NA 17.00 6/9/2009 P2-42 1931430 50029224050000 19.3 NA 19.3 NA 121.60 6/20/2009 P2-43 2050240 50029232500000 0.8 NA 0.8 NA 6.00 6/8/2009 P2-44 1960630 50029226660000 2.3 NA 2.3 NA 23.80 6/8/2009 P2-45B 2080210 50029227690200 0.8 NA 0.8 NA 5.10 6/8/2009 P2-46 1931320 50029224010000 2.3 NA 2.3 NA 25.50 6/8/2009 P2-47 1951900 50029226280000 0.0 NA 0.0 NA NA NA P2-48 1921260 50029223090000 02 NA 0.2 NA 1.70 4/18/2012 P2-49 1920240 50029222520000 2.5 NA 2.5 NA 18.70 6/7/2009 P2 -50B 1950960 50029222610200 2.0 NA 2.0 NA 23.00 6/8/2009 P2 -51 1920380 50029222620000 0.3 NA 0.3 NA 0.85 6/7/2009 P2 -52 1972010 50029228260000 3.8 NA 3.8 NA 47.60 6/7/2009 P2 -53 1960410 50029226560000 2.0 NA 2.0 NA 21.30 6/7/2009 P2 -54A 2030300 50029224700100 0.8 NA 0.8 NA 3.40 6/7/2009 P2 -55 1920820 50029222830000 4.0 NA 4.0 NA 79.90 6/22/2009 P2 -56 1951620 50029226100000 2.8 NA 2.8 NA 17.90 6/7/2009 P2 -57A 2022140 50029221830100 15.5 NA 15.5 NA 77.40 6/22/2009 P2 -58 1900080 50029220000000 Sealed conductor NA NA NA NA NA P2 -59A 1982010 50029220960100 Sealed conductor NA NA NA NA NA P2-60 1910910 50029221920000 8.3 NA 8.3 NA 56.10 3/13/2012 PT6 q7/030 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, April 02, 2012 4:44 PM To: 'AK, D &C Well Integrity Coordinator' Subject: RE: March 2012 AOGCC MIT Forms P2 -01 results ok Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907- 793 -1236 From: AK, D &C Well Integrity Coordinator [ mailto :AKDCWellIntegrityCoordinator@ bp.com] Sent: Monday, April 02, 2012 1:09 PM To: Regg, James B (DOA); Brooks, Phoebe L (DOA) Subject: March 2012 AOGCC MIT Forms Jim, Phoebe, Please find attached MIT -IA forms for March 2012. Please let me know if the tests are acceptable as we are waiting on pulling the standing valve set for the MIT -T on P2 -01 (PTD #1970730 -11 P X180 SLOW() APR ,. (� t'012 16 -11 (PTD #1801180) W -24 (PTD #1880700) Already submitted MIT -IA forms for March 2012, please let me know if I should resubmit: S -111 (PTD #2050510) - Submitted on 03/08/2012 MPF -88 (PTD #2031930) - Submitted on 03/22/2012 NS31 (PTD #2010600) - Submitted on 03/25/2012 Thank you, Mehreen Vazir 1:91te//i ifc. Gerald N1urp >hv) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reao alaska.00v: doa. aoacc.prudhoe.bavCd?alaska.00v; phoebe.brooksaalaska.gov; tom.maunder(ialaska.aov OPERATOR: BP Exploration (Alaska), Inc. re ;Zij z.- FIELD / UNIT / PAD: Prudhoe Bay / GPMA / P2 DATE: 03/31/12 A,(` OPERATOR REP: Mehreen Vazir M- UV(L) 0 fc_ AOGCC REP: Declined to witness (Lou Grimaldi) ',-b i 1 CCfvuelE : Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well P2 -01 Type Inj. N '/ TVD 4,350' Tubing 365 3024 — 2928 2896 — Interval V ✓ P.T.D. 1970730 Type test P Test psi 1500 Casing 1248 1248 1248 1248 P/F P Notes: Two year MIT -T to verify liner integrity ✓ OA 60 60 60 60 Tested against standin valve at 10231' MD. 3.6 bbl crude to increase tubing to test pressure. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA - Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Infecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) i Form 10 -426 (Revised 06/2010) MIT GPMA P2 - 01 03 - 31 - 12 AOGCC MITIA Forms for P1-12 (1930), P2-O1 (1970730) MPC-28A (20530), MPF-82A ... Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comj Sent: Wednesday, March 31, 2010 8:35 PM 1\~~ ~~Z~~~ To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Cc: MPU, OMS Facility Coordinator; MPU, OMS Field Coordinator Subject: AOGCC MITIA Forms for P1-12 (1910130), P2-01 (1970730) MPC-28A (2051630), MPF-82A (2091350), MPH-15 (2051590), 04-40 (1911340), 13-31A(2051600), 16-01(1801360), AGI-01A (2091640), L-213(2060530), M-29(2000990), P-14(1910070), V-212(2051500), W-217(2091170) Attachments: March 2010 MIT Forms.zip Jim, Tom, and Phoebe, Please find the attached AOGCC MITIA forms for the following wells: 04-40 (PTD #1911340) 13-31A (PTD #2051600) 16-01 (PTD #1801360) AGI-01A (PTD #2091640) L-213 (PTD #2060530) M-29 (PTD #2000990) MPC-28A (PTD #2051630) MPF-82A (PTD #2091350) MPH-15 (PTD #2051590) P-14 (PTD #1910070) P1-12 (PTD #1910130) P2-01 (PTD #1970730) V-212 (PTD #2051500) W-217 (PTD #2091170) «March 2010 MIT Forms.zip» - -•~, ;, ~~~ ~~ r'£)~~, . t!.YJ~1~ Seto ..s+''" ,. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 4/2/2010 Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov ~`'`z~`~ OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Prudhoe Bay /GPMA / P2 03/08/10 Torin Roschinger Packer Depth Pretest Initial 15 Min. 30 Min. Well P2-01 T pe In'. N TVD 4,350' Tubin 900 / 3,000 2,840 2,820 Interval O P.T.D. 1970730 Type test P Test psi 1500 Casin 1,200 1,200 1,200 1,200 P!F P Notes:" IT-T for 24 month regulatory complaince due OA 0 0 0 0 to high packer set to confirm liner inte rit . AOGCC Chuck Scheve declined to witness Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casin P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casin P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT GPMA P2-01 03-OS-10.x1s Permission to flow well P2-Q1 without a SSSV after expiration of the 14 day clock Page 1 of 2 Regg, James B (DOA) ~ ~~~- ®~73 From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comJ Sent: Monday, February 15, 2010 4:34 PM ~e~~ Z~t6~ln To: Regg, James B (DOA); Jones, Jeffery B (DOA); DOA AOGCC Prudhoe Bay Cc: Warner, Ross L; NSU, ADW Wells Slickline Scheduler; Murphy, Gerald L; NSU, ADW Well Integrity Engineer; GPB, LPC DS Ops Lead; GPB, LPC DS Operator; GPB, LPC Board Operator; NSU, ADW WL & Completion Supervisor Subject: RE: Permission to flow well P2-01 (PTD #1970730) without a SSSV after expiration of the 14 day clock Jim and Jeff, ~ A SSSV was set in P2-01 (PTD #1970730} on 02/13/10 after having a little trouble getting the valve to set. The well has been returned to production. ~-' Please let us know if you have any questions. Thank you, Anna Dude, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group i ,~~' ~~~ ~ ~_ ZQ';~; Phone: (907) 659-5102 ~;ty~~~~~ t Pager: (907) 659-5100 x1154 From: Murphy, Gerald L Sent: Monday, February 08, 2010 9:50 PM To: GPB, LPC DS Ops Lead; GPB, LPC DS Operator; GPB, LPC Board Operator Cc: Warner, Ross L; NSU, ADW Well Integrity Engineer; NSU, ADW Wells Slickline Scheduler Subject: FW: Permission to flow well P2-01 without a SSSV after expiration of the 14 day clock Gentlemen, Jeff Jones with the AOGCC has given us permission to place well P2-01 back online to warm the tubulars for the pending slickline attempt to set the SSSV. Can we please have the well placed back online as soon as possible to begin warming the well back up. Slcikline should be on the well in the next 24-36 hours per the slickline scheduler. If there are any questions, please contact myself at 659-5102. Thanks, Jerry Murphy From: Jones, Jeffery B (DOA) [mailto:jeff.jones@alaska.gov] Sent: Monday, February 08, 2010 9:30 PM To: Murphy, Gerald. L Cc: Regg, James B (DOA) Subject: RE: Permission to flow well P2-01 without a SSSV after expiration of the 14 day clock 2/16/2010 Permission to flow well P2-O1 without a SSSV after expiration of the 14 day clock Page 2 of 2 Mr. Murphy, Your request for a variance to POP well P2-01 to conduct wire line repair operations and installation of the SSSV is granted, based on our telephone conversation today and the information you have provided. Please keep the AOGCC informed of your progress and any problems (inability to set the SSSV) that occur relating to this variance. Jeff Jones AOGCC 659-3607 From: Murphy, Gerald L [mailto:MurphyGL@bp.com] Sent: Monday, February 08, 2010 7:25 PM To: Jones, Jeffery B (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: Permission to flow well P2-01 without a SSSV after expiration of the 14 day clock Mr. Jones, This e-mail is in reference to our discussion over the telephone regarding well P2-01 at Point Maclntyre. P2-01 is a production well that had it's sub-surface safety valve pulled on January 5th in preparation for a coiled tubing scale milling operation and scale inhibition treatment. Due to inclement weather in January, the CT work was not performed until January 22nd through the 24th. Following the completion of the CT operation, the well was put onto production and scheduled for the bullhead scale inhibition treatment. Further inclement weather was encountered resulting in delay of setting the SSSV. On February 6th and 7th, the first attempt to reset the sub-surface safety valve was perfromed with by slickline. The SSSV setting was unsuccessful being unable to gain integrity on the balance line. At the time, oversize packing for the valve was unavailable. The 7th was day 13 of the 14 day clock. The packing is now available on the slope, but we are at the end of the 14 day clock. Currently the well is shut-in and slickline is scheduled to be ready to work on the well in the next 24-36 hours. We would like permission to bring the well back online to warm the tubulars prior to slicklines arrival on the well, which would assist with the setting of the sub-surface safety valve. I appreciate your time and consideration in this matter. If there are further questions, I can be reached at the numbers listed below. Best Regards, Gerald Murphy BP Exploration - Alaska Well Integrity Projects Engineer (907) 659-5098 (office) (907) 659-5100 pager #1446 2/16/2010 Permission to flow well P2-O1 with~t a SSSV after expiration of the 14 da~ock Page 1 of 2 Regg, James B (DOA) From: Jones, Jeffery B (DOA) Sent: Monday, February 08, 2010 9:30 PM To: Murphy, Gerald L Cc: Regg, James B (DOA) ~~ Z~~~o ,P~ I`(7-o7~ Subject: RE: Permission to flow well P2-01 without a SSSV after expiration of the 14 day clock Mr. Murphy, Your request for a variance to POP well P2-01 to conduct wire line repair operations and installation of the SSSV is granted, based on our telephone conversation today and the information you have provided. Please keep the AOGCC informed of your progress and any problems (inability to set the SSSV) that occur relating to this variance. Jeff Jones AOGCC ~rI , r-L ", rY ~Q~,l 659-3607 ~~~,~~~~ ~ ~' ~`~ From: Murphy, Gerald L [mailto:MurphyGL@bp.com] Sent: Monday, February 08, 2010 7:25 PM To: Jones, Jeffery 6 (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: Permission to flow well P2-01 without a SSSV after expiration of the 14 day clock Mr. Jones, This e-mail is in reference to our discussion over the telephone regarding well P2-01 at Point Maclntyre. P2-01 is a production well that had it's sub-surface safety valve pulled on January 5th in preparation for a coiled tubing scale milling operation and scale inhibition treatment. Due to inclement weather in January, the CT work was not performed until January 22nd through the 24th. Following the completion of the CT operation, the well was put onto production and scheduled for the bullhead scale inhibition treatment. Further inclement weather was encountered resulting in delay of setting the SSSV. On February 6th and 7th, the first attempt to reset the sub-surface safety valve was perfromed with by slickline. The SSSV setting was unsuccessful being unable to gain integrity on the balance line. At the time, oversize packing for the valve was unavailable. The 7th was day 13 of the 14 day clock. The packing is now available on the slope, but we are at the end of the 14 day clock. Currently the well is shut-in and slickline is scheduled to be ready to work on the well in the next 24-36 hours. We would like permission to bring the well back online to warm the tubulars prior to slicklines arrival on the well, which would assist with the setting of the sub-surface safety valve. I appreciate your time and consideration in this matter. If there are further questions, I can be reached at the numbers listed below. 2/9/2010 Permission to flow well P2-O1 wiut a SSSV after expiration of the 14 d~lock Page 2 of 2 Best Regards, Gerald Murphy BP Exploration - Alaska Well Integrity Projects Engineer (907) 659-5098 (office) (907) 659-5100 pager #1446 2/9/2010 STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS JAN ~ ~ ~~~ 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ 5~~,pVAL Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Dr~{Number: Name: Development Q Exploratory ^ ` 197-0730 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Nu ber: Anchorage, AK 99519-6612 ~ 50-029-22761-00-00 8. Property Designation (LeasB~Vumber) : 9. Well Name and Number: \ ADLO-034622 P2-01 10. Field/Pool(s): `PRUDHOE BAY FIELD / PT MCINTYRE OIL POOL 11. Present Well Condition Summary: Total Depth measured ~ 10975 feet Plugs (measured) None feet true vertical 9271.7 feet Junk (measured) None feet Effective Depth measured 10879 feet Packer (measured) 10189 4689 true vertical 9192 feet (true vertical) 8623 4350 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"133# H-40 30 - 110 30 - 110 3060 1500 Surface 5444 9-5/8"40# L-80 29 - 5473 26 - 4957 5750 3090 Intermediate Production 10930 7" 26# L-80/13CR80 28 - 10958 28 - 9258 7240 5410 Liner 51 4-1/2" 12.# 13CR80 N~ 10098 - 10149 8549 - 8590 Liner Pertoration depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ - _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 31 - 10245 31 - 8668 Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Packer 10189 8623 4-1/2" Baker S-3 Packer 4689 4350 12. Stimulation or cement squeeze summary: Intervals treated (measured): n Treatment descriptions including volumes used and final pressure: ~~r_~5~~~' E~~~~;~ ~ ~ U 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 930 4980 6255 865 Subsequent to operation: 910 4762 8045 849 14. Attachments: 't~. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ^ 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 Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 1/25/2010 Form 10-404 Revised 7/2009 ~~~ 2 J ,~~~~~~`" (~?~~O Submit Original Only n P2-01 197-073 PERF ATTACHMENT • • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base P2-01 5/18/97 PER 10,392. 10,412. 8,788.26 8,804.6 P2-01 8112/97 APF 10,450. 10,480. 8,835.66 8,860.21 P2-01 8/12/97. APF 10,564. 10,594. 8,929.65 8,954.64 P2-01 8/12/97 APF 10,648. 10,708. 8,999.67 9,049.79 P2-01 5/6/02 APF 10,605. 10,625. 8,963.8 8,980.48 P2-01 4/15/03 BPS 10,172. 10,879. 8,609.04 9,192.18 P2-01 4/30/03 BPP 10,392. 10,879. 8,788.26 9,192.18 P2-01 6/20/05 FIL 10,334. 10,879. 8,740.89 9,192.18 P2-01 7/26/05 FIL 10,332. 10,392. 8,739.26 8,788.26 P2-01 2/10/06 BPS 10,208. 10,332. 8,638.18 8,739.26 P2-01 3/11/06 BPP 10,208. 10,332. 8,638.18 8,739.26 P2-01 3/18/06 FCO 10,332. 10,392. 8,739.26 8,788.26 P2-01 3/19/06 FCO 10,334. 10,879. 8,740.89 9,192.18 P2-01 3/4/08 BPS 10,207. 10,879. 8,637.37 9,192.18 P2-01 3/10/08 BPP 10,207. 10,879. 8,637.37 9,192.18 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE n U P2-O1 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 1/22/2010~CTU #6 1.75" CT Job Scope: Mill/Under-ream scale. **** MIRU on P2-01. ;Make up Baker MHA, xtreme motor and 3.70" mill 1/23/2010~CTU #6 1.75" CT Job Scope: Mill/Underream Scale (Cont. from 01/22/10) Make up Baker MHA, 2-7/8" extreme'x' mud motor,and 3.70" turbo scale mill. ;Bring well on line to GC-1 @ 80 bn chk and 2.6 mscf AL. RIH and tag scale @ 39,861'. Mill to 10,120' w/o noticeable work on motor or WOB. SD pump after Hi-Vis sweep and dry tag @ 10,120'. Resume milling to 50' below end of 4-1 /2" production tubing to 10,300' ctm. Pump Hi-Vis sweep and chase OOH w/ XS 1 ?KCI .All returns to production. Break down BOT and make up Weathertord motor & 3.50" underreamer. RIH to underream 7" casing. *****Continued on 1/24/10****»»Interact publishing«« __. ~ ._ ._ ~_ _ ~ _ _____ ~~.___________. e ... ~~ __.~ 1/24/2010CTU #6 1.75" CT Job Scope: Mill/Underream Scale (Cont. from 01/23/10) Cont. RIH w/ WFD MHA, 2.875" motor,and 3.50" Reeve's underreamer dressed w/ 6.15" blades. Open blades in pilot hole @ 10,275' and undeream to requested ,~ ;depth of 10,750 ctm. Overall ROP averaged 45 fph with very little work noticed on the motor or weight on the reamer. Pump Hi Vis sweep each 50' of new hole. =Pump Hi Vis sweep after reaching TD and chase to EOT. Confirm UR blades will close while PU into tbg tail. Pump final Hi Vis sweep followed by ball to open circ sub. Run back to bottom with sweep exiting bit. Open circ sub and chase pill OOH w/ XS 1 %KCI and safelube. All returns to production w/ no upsets to GC-1. ;POOH. RDMO from P2.01 and move to P2-48 *****Job Completed**** FLUIDS PUMPED BBLS 109 GEOVIS 515 1 % KCL XS SL 17 60/40 METH 603 1 %KCL XS 1244 Total TREE _ WELLHEAD = CIW ACTUATOR = _ __ ~ BAKER G KB. ELEV = 47.15' BF. ELEV = KOP = 2498' Max Angle = 41 @ 4201' Datum MD = 10464' Datum TVD = 8800' SS' 7" SCAB LNR, 26#, L-80 TCII, ID = 6.276" 1089' Minimum ID = 3.725" ~ 10231' OTIS XN NIPPLE 4-112" TBG, 12.6# 13CR80 VAM TOP, 4742' .0152 bpf, ID = 3.958" 9-5/8" CSG, 40#, L-80, ID = 8.835" 5473` 7" CSG, 26#, L-80, ID = 6.276" ~~ 10040' 4-i/2" SCAB LNR, 12.6#, 13CR80 NSCT, ( 10098' .0152 bpf, ID = 3.958" 4-1/2" SCAB LNR, 12.6#, L-80 BTC, I 10149' .0152 bpf, ID = 3.958" 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf , ID = 3.958" ~ 10245` PERFORATION SUMMARY REF LOG: PLAT EXP ON 05!02/97 ANGLE AT TOP PERF: 35 @ 10392' r. Note: Refer to Production DB for historical perf data`r SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 10392 - 10412 O 05/18/97 3-318" 6 10450 - 10480 O 08/12/97 3-3/8" 6 10564 - 10594 O 08!12/97 3-318" 6 10605 - 10625 O 05!06/02 3-318" 6 10648 - 10708 O 08/12/97 NOTES: ***CHROME 4-112" TBG, 4- P 2 -O ~ 1/2" SCAB LNR, & 7" CSG"** ~~~ 1083' 7" TAM PORT GOLLAR~ ~•~• 2119' 4-112" HES HXO SLV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 4276 4021 41 KBG-2 DMY BK 0 04/08/06 1 4566 4245 38 KBG-2 DMY BK 0 03/05/08 4630' 4-112" HES X NIP, ID = 3.813" 469$' 7" X 4-1/2" BKR S-3 PKR, ID = 3.87" 4721' 4-1/2" HES X NIP, ID = 3.813"~ 4727' 7" X 5" BKR ZXP LNR TOP PKR w / ! BKR FLEX-LOC LNR HNGR, ID - 4.430" 4742' - 4-112" WLEG, ID = 3.958" 4754` 5" X 4-1/2" XO, ID = 3.950" 10149' 4-112" BKR PERF PUP (CEMENTER) 10160' BKR BALL & SEAT SUB IBT X TCiI XO, ID = 3.92" 1018$` ELM TBG STUB (02/10/06) 10179' UNIQUE MACHINE OVERSHOT 10189' 7" X 4-112" BAKER S-3 FKR, ID = 3.875" 10220` 4-1/2" OTIS X NIP, ID = 3.813" 10231' 4-1/2" OTIS XN NIP, ID = 3.725" cN 10245` 5" TUBING TAIL, WLEG, ID = 3.958" ' 0 10235' -~EIMD Tf LOGGED 05/13197 10750' CTM (-ITOP OF SAND (03/20!06} PBTD -~ 10879, 7" CSG, 26#, 13-CR, ID = 6.276" --r 1095$' DATE REV BY COMMENTS DRTE REV BY COMMENTS 05106!97 ORIGCNAL CQMPLEflON 10!17108 JLCJPJC PERF CORRECTION 03(06106 N7ES RWO 03/20!06 JAF/TLH CMT/FASDRILL SAND RE~VA 03!22!06 RWL/TLH DRLG DRAFT CORRECTIONS p4108/06 KSB/PJC GLV C/O 03114/08 SEW/1-LH GLV GO POINT MCINTYRE UNIT WELL: P2-01 PERMIT No:1970730 API No: 50-029-22761-00 SEC 11, T12N, R14E, 3918.04' FEL & 3722.9' FNL BP E~cploration (Alaska) MEMORANDUM To: Jim Regg ~~~ ~~~ P.I. Supervisor FROM: John Cnsp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, April O1, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC P2-01 PRUDHOE BAY LTI PTM P2-01 Src: Inspector NON-CONFIDENTIAL Reviewed Bv• P.I. Suprv ~P~ Comm Well Name: PRUDHOE BAY UN PTM P2-Ol Insp Num: mitJCr080314110942 Rel Insp Num: API Well Number: 50-02 9-22 76 1-00-00 Permit Number: 197-073-0 ~ Inspector Name: John Crisp Inspection Date: 3/7/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 601vIin. Well ', P2 Ol !.Type Inj. ~ ~] !' TVD i 4350 IA ~ i 690 ~ 690 I _ _ 690 ~ 680 680 _ P.T '9'0'30 !TypeTest ~ sPT I Test psi _~ T 3000 OA ~ 90 90 ! 90 90 9o _ Interval oTl-~R p/F P / Tubing' 260 3too ! 792 o a9oo ~ zsao NOteS' MIT-T for monobore requirements. ~`Q~l ~~~Q~K~1 ~1V~~ JUL ~ 20G8 Tuesday, Aprii 01, 2008 Page 1 of t MIT Forms: MPU F-88, L-16A~23 ;GPMA P2-O1 and PBU R-25A ~ Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Thursday, March 20, 2008 1:26 PM 2~~ ~~~ To: Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer; Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); NSU, ADW WI Tech Subject: GPMA P2-01 (PTD #1970730) Revised MIT form Attachments: MIT GPMA P2-01 03-07-08.x1s; P2-01.pdf / Ni Jim; [~~' Attached please find a revised MIT form fortG,~'MA P2-01 (' the test being conducted against a p(uq and the set depth. be set at any depth and does not have to be `set in a nipple Please let me know if you have any further questions. Thank you, ,~nnrz I~u6e, ~''. E. 'TD #1970730 This revised form includes information abo~ 'he type of p ug is a wireline~etrievable plug (WRP} that can A wellbore schematic has been included for reference. ~~N APR ~ 2 200$ Weil Integrity Coordinator GPB Wells Group Phone: (907) 659-5'iQ2 Pager; (9t17) 659-5100 x1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, March 12, 2008 10:38 AM To: NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: RE: MIT Forms: MPU F-88, L-16A, E-23 ;GPMA P2-O1 and PBU R-25A One more thing -please confirm that P2-01 MIT was performed against plug and where it was set; that would be appropriate info to report for monobore completion MITs. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Tuesday, March 11, 2008 11:17 AM To: Regg, James B (DOA) Subject: RE: MIT Forms: MPU F-88, L-16A, E-23 ;GPMA P2-01 and PBU R-25A Jim, I apalagize far the oversight. A revised version is attached. Thanks, Andrea Hughes 3/20/2008 MIT Forms: MPU F-88, L-16A~23 ;GPMA P2-O1 and PBU R-25A • Page 2 of 2 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, March 10, 2008 5:18 PM To: NSU, ADW Well Integrity Engineer Subject: RE: MIT Forms: MPU F-88, L-16A, E-23 ;GPMA P2-O1 and PBU R-25A P2-01: 15 min tubing pressure should be 2970 psi instead of 3970 psi (?) Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Sunday, March 09, 2008 9:23 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA) Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; MPU, Wells Ops Coord; MPU, Wells Ops Coord2 Subject: MIT Forms: MPU F-88, L-16A, E-23 ;GPMA P2-O1 and PBU R-25A Jim, Tom and Bob, Please see the attached MIT forms for the following wells: MPF-88 (PTD #2031930): MITIA for 4-year compliance MPL-16A (PTD #1990900): MITIA for 4-year compliance MPE-23 (PTD #1950940): MITIA for 4-year compliance P2-01 (PTD #1970730): MITT for regulatory compliance R-25A (PTD #1972300): MITIA for 4-year compliance, pre-MI swap «MPU F Pad MIT Form 03-07-08.x1s» «MPU L Pad MIT Form 03-07-08.x1s» «MPU E Pad MIT Form 03-07- 08.x1s» «MIT GPMA P2-01 03-07-08.x1s» «MIT PBU R-25 03-07-08.x1s» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 3/20/2008 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder~admin.state.ak.us OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay !GPMA / P2 03/07/08 Andrea John G Packer Depth Pretest Initial 15 Min. 30 Min. Wetl P2-01 Type Inj. N TVD 4,350' Tubing 260 X3100 2970 2900 Interval O P.T.D. 1970730 Type test P Test psi „/3000 Casing 690 690 680 680 P/F P Notes: MIT-T against WRP plug set at 10,207' for monobore OA 90 90 90 90 regultory compliance. Stabilzation exhibited during additional 15 mins: T/I/O = 2880/680/90. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi 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 =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT GPMA P2-01 03-07-08.x1s TREE _ ? P2-01 SAFETY NOTES: ***CHRt)N1E4112" 7BG, 4- 112" SCAB LNR, & 7" CSG*** VVELLHEAD= ACTUATOR = CIW BAKER C KB, ELEV = 47.15' BF. ELEV K_OP = 2498' tvtax Angle = 41 ~ 4201' datum MD = 10464' Datum TVD = 8800' SS' 7" 5CAB LNR, 26#, L-80 TCII, ID = 6.276"' 1089' Nlinlmum !D = 3.725" ~?a 10231' QT!$ X!d !!~"LE 4-112" TBG, 12.6# 13CR8011AM TOP, 4742' ,0152 bpf. ID = 3.958" 9-5!8" CSG, 40#, L-80, ID = 8.835" 5473' 7" CSG, 26#, L-80, ID = 6.276" 4-1(2" SCAB LNR, 12.6#, 13CR80 NSCT, 10098` .0152 bpf, ID = 3.958" 4-1?2" SCAB LNR, 12.6#, L-80 BTC, I 10149' .0152 by#, ID = 3.958`° 11 4-112" TBG, 12.6#, 13-CR, .0152 bpf , ID = 3.958" ~-} ~ PERFORATION SUILIM.ARY REF LOG: PLAT EXP ON 05/02197 ANGLEATTOPPERF: 35 @ 10392' Noce: Refer to Production DB far historical perf data SIZE SPF INTERVAL Opn?Sqz DATE 2-112" 4 10392 - 10412 O 05?18197 3-318" 6 10450 - 10480 O OS?12?97 3-318" 6 10564 - 10584 O 08112!97 3-3?$" 6 10605 - 10625 O 05106?02 3-3?8" 6 10648 - 10708 O 08?12?97 PBTD --~ 10879, 7'" CSG. 26#, 13-CR, ID = 6.276" 1095$' 1083' ~7"TANtPORTCOLLAR 2119' 4-112" HES HXO SLV NIP, ID = 3.813" r'~~ `...J GAS LIFT Iti1ANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 4276 4566 4021 4245 41 38 KBG-2 KBG-2 DMY DMY BK BK 0 0 04(08?06 03,05?08 4630' - r4-1 ?2" HES X MP, iD = 3.813" 4698' 7" X 4-112" BKR S-3 PKR, ID = 3.87" 4721' 4-112" HES X NIP, ID = 3.813" 4727" 7" X 5" BKR ZXP LNR TOP PKR, w! BKR FLEX-LOC LNR HNGR, iD = 4.430" 4742° 4-1?2" WLEG, ID = 3.958" 4754' S" X 4-1?2" XO, ID = 3.950" ~ 4-112°' BKR FERF PUP (CE€UENTER) ~ 10160' BKR BALL i~ SEAT SUB IBT X TCII XO, ID - 3.92" 10184' ELM -[TBG STUB {02?1o?a6)~ 10179' UNIQUE I~tACHINE OV ERSHOT 10189' 7" x 4-1?2" BAKER S-3 PKR, ID = 3.875" 10220' --1 4-1i2" OTIS X NIP, ID = 3.813" 10231' 4-11z°' OTIS XN NIP. ID = 3.725" 10245° 5" TUBING TAIL, v'VLEG, ID = 3.958" 10235' ELMD TT LOGGED 05!13/97 TOP OF SAND (03%20/06} DATE REV BY COMMENTS DATE RE1,f BY COMMENTS 05106/97 OWGINAL COMPLETION 03106/06 N7Fu RWO 03.:20.106 JAFITLH CMfiFASDRILL SAND REMOVA 03122?06 R~,NL?TLH DRLG DRAFT CORRECTIONS 04?08?06 KSB?PJC GLV CIO 03i'14i08 BEWITCH GLV Cl0 POINT IvICINTYRE lJNIT NlELL: P2-01 PERMfT Na: 1970730 API No: 50-029-22761-00 SEC 11, T12N, R14E, 3918.04' FF1_ ~ 3722.9' FNL. SP F..xpioratiorr {Alaska} e Job Log escriptlon ate L oor 15·12A 11211420 RST GRAVEL PACK 06/25/06 1 17-08 11211509 INJo:;v.1 ILE 06/24/06 1 P2-11A 11221564 JEWELRY/STATIC SURVEY 04/27/06 1 13-06A 11217266 INJECTION PROFILE 07/12/06 1 P2-01 11223106 STATIC PRESSURE/JEWELRY 03/25/06 1 L5-08 11217256 PROD PROFILE W/GHOST & DEFT 06/06/06 1 16-04A 11217245 PROD PROFILE W/DEFT 05/08/06 1 05-40 11223123 LDL 07/07/06 1 17-09 11211412 PROD PROFILE W/DEFT & GHOST 06/26/06 1 MPC-07 N/A SENSA/MEMORY GLS 04/22/06 1 04-18 1121584 USIT 06/27/06 1 1,¡·51 11212873 US IT 06/28/06 1 04-31 11217264 USIT 07/07/06 1 D-14A 11217265 USIT 07/09/06 1 PSI-07 10703937 MDT 10/13/03 1 02-16B 11209601 MCNL 04/25/06 1 1 L2-18A 11217234 MCNL 04/06/06 1 1 L5-09 11212847 MCNL 04/25/06 1 1 Z-26A 11216205 MCNL 07/05/06 1 1 12-01 11072866 RST 07/06/05 1 1 E-17A 10928602 MCNL (Prints sent 1/24/05) 10/30/04 1 ·,;;;.r ~ ;",.~",4r..:.r: ~...n;.o .., '1:'-_. ') Sc~luIIIbepger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth I (}9 - 0-:;3 WII # D D B ~ì '/ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 07/19/06 NO. 3880 Company: State of Alaska Alaska Oil & Gas Cons Comm Artn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay CI CD e e Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth . STATE OF ALASKA _ AlAS~ Oil AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS 15. Well Class after Droposed work: Exploratory Development 16. Well Status after proposed work: Oil (;t. . Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Ope rat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 47.15 KB 8. Property Designation: ADL-034622 ' 11. Present Well Condition Summary: Total Depth measured 10975 true vertical 9271.7 . Effective Depth measured 10879 true vertical 9192.18 Casing Conductor Surface Production Length 80 5444 10930 Size 20" 133# H-40 9-5/8" 40# L-80 7" 26# L-80 /13CR80 Perforation depth: Measured depth: 10392 - 10412 True Vertical depth: 8788.26 - 8804.6 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o x Contact Sharmaine Vestal Printed Name Sharmaine Vestal Signatu"'> <;;;:;( ¿ A A..A ,# ~ -.-L~ / "') / ~:' /j~;.o~Z¿ Ó Form 10-404 Revised 04/2004 Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Class: Development (;t Stratigraphic fJ Stimulate D '~r,!WI MillPIt.tg Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 197-0730 ' 6. API Number: 50-029-22761-00-00 Exploratory Service r 9. Well Name and Number: P2-01 10. Field/Pool(s): PRUDHOE BAY Field/ PT MCINTYRE OIL Pool' feet feet Plugs (measured) Junk (measured) None None feet feet ",' N" ..-,. 'I II" ., ,... "nr;,· 6íCi"\,:'\It:.J) Jvi'J 1. ¿¡ ¿JUJ MD 30 - 110 29 - 5473 28 - 10958 Burst 3060 5750 7240 TVD 30 - 110 29 - 4957.43 28 - 9257.62 10450 - 10480 10564 - 10584 10605 - 10625 8963.8 - 8980.48 8835.66 - 8860.21 8929.65 - 8946.31 4-1/2" 12.6# 13Cr80 31 - 10245 4-1/2" Baker S-3 Packer 4-1/2" Baker SABL-3 Packer 4698 10189 RBDMS 8Fl MAY 2 {; 2006 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 0 o 0 0 (;t. Service Collapse 1500 3090 5410 10648 - 10708 8999.67 - 9049.79 Tubing pressure o o GINJ 0 WINJ 0 WDSPL ISundry Number or N/A if C.O. Exempt: IN/A Title Data Mgmt Engr Phone 564-4424 Date 5/23/2006 Submit Original Only GINAl e e P2-01 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 3/11/2006 CTU #9. Mill Cement Plug / FCO. Move unit to PM2. Stand-by on ASRC to finish rigging up. **** Job continued on WSR 3/12/2006 *** 3/12/2006 CTU #9. Mill Cement Plug/ Mill Fasdrill/ FCO. Wait for ASRC to complete RU. MIRU CTU. Perform BOP test. MU and RIH with BOT 3.7" OD 3-blade opticutjunk mill. Set down at 10018' ctmd. Wash down to 10108'. @10108' motor appeared to stop working. POOH to inspect BHA #1. BHA had dis- connected at disconnect. Nothing found on seat. MU BHA #2 to fish tools in hole. ***Continued on WSR 3/13/2006 *** 3/13/2006 CTU #9. Fish BHAlMill Cement/FCO. *** Continuation of WSR 3/12/2006 *** RIH w/BHA #2 (fishing tools). Recover disconnect, motor and mill from well. MU and RBIH with BHA #3 - 3.70 3-blade mill. Appeared to start milling cement at 10128' ctmd. Milled to 10195' at -24 fph before encountering numerous stalls. Time drilled to 10212'. Time drilled slowly at 10212' with 7 stalls, 5 requiring jar hits to jar off. On last stall, appeared to drag up hole while trying to jar off to 10190' ctmd. Jarred free after 4 hits, free spin pressure down 300 psi, cannot stall motor (see WSR 3/14/2006). *** Continued on WSR 3/14/2006 *** 3/14/2006 CTU #9 1.75" Chrome Tubing. Mill Plug / FCO. *** Continuation of WSR 3/13/2006 *** Stuck with BHA @ 10190' ctmd. Jarred 4 times before coming free. Lost 300 psi from free spin of motor, and unable to initiate a stall. POOH to inspect tools. On inspection, disconnect was sheared. Left mill, motor, half of disconnect in hole (16.5') . RIH with BHA #4 (fishing string - 3" GS). SD and latch at 10158' ctmd. After several hard down licks, hit an up lick and pulled free. RBIH freely to 10160'. POOH. At surface, ele. counter at -45', mech counter at -12'. (explains why latch at 10158'). Recovered all of fish. Several metal scars on sides of mill. LD tools and cut 150' of pipe. MU and RIH with BHA #5 (31/8" venturi JB). Vacuum from 10100' down to 10220' with 2 passes. On way out of hole, CT pin holed at -10160' from end of coil. *** Continued on WSR 3/15/2006 *** 3/15/2006 CTU #9. Venturi Junk Basket Run. *** Continuation of WSR 3/14/2006 *** Spooling out of hole after venturi basket run. Load well with 60:40 meth down backside while POOH. Well freeze protected to 2000'. At surface, junk basket recovered approx 1 cup of steel and cement material. Blow down CT with 20k scf N2. Rig down CTU and return to shop to swap CT string. *** Job Incomplete *** 3/17/2006 CTU #9 - Venturi! Mill Fast Drill- MIRU after reel swap. Unable to raise mast safely due to wind speeds. Go to weather. 3/18/2006 CTU # 9, Venturi - Mill Fasdrill- FCO sandplug. Cont.from 3-17-06 WSR , Finish rigging up and drift coil with 1.25" ball. RIH with BHA #63.125" Burn shoe and Venturi Basket. Tagged down at 1 0182' with BHA. Attempted to work past with various methods with no luck. *** Continued on WSR 3/19/2006 *** 3/19/2006 CTU #9. Venturi Junk Basket / Mill Plug. *** Continuation of WSR 3/18/2006 ***. Tagged up at 10182' CTM with BHA #6. Unable to get deeper. Pumped 120 bbls of 1 % XS KCI with 0.6% SafeLube to coat chrome tubulars. POOH to inspect tools. Recovered about 8 Ibs of metal parts and a 2.5" x 7" tubing drift in the basket. RIH with same BHA. Dry tag at 10191' ctmd. Work venturin and burn shoe to 10270' with very little MW. TT at 10,245'. Recovered - 1 gallon of various debris (metal/fasdrill/rubber/sand). LD venturi and RIH with same BHA and 3.7" e e tapered junk mill. Set down at 10166' ctmd. and 10280' ctmd. Rotate to get down. Start FCO from 10270'. Find hard sand top at 10332'. Cleanout down to 10750' CTMD using 1078 bbls of 1 %XS KCI with 0.6% SafeLube and 129 bbls of FloPro taking 12 x 50' bites and chasing to tubing tail. GLR @ 1.5mm during cleanout. Chased out of hole pulling @ 50% of pump rate due to chrome tubing. *** Continued on WSR 3/20/2006 *** 3/20/2006 CTU #9. Fill Cleanout Sandplug. *** Continuation of WSR 3/19/2006 *** POOH pumping 1 % XS KCI chasing sand to surface. Bullhead 35 bbls of 60:40 MeOH to freeze protect well. Freeze protected flowline on Well #4 with 70 bbls of 60:40 MeOH through ASRC test seperator. Freeze protected well #1 flowline with 11 bbls of MeOH. Notified pad operator that the well is to be left shut in. *** Well to be left shut-in for 3 days prior to static survey *** Note: Area at Unique Overshot (10,170' on schematic) may not be a smooth transition. FLUIDS PUMPED BBLS 4066 1 % KCL 158 Flo pro 703 MeOH 50 1 % X-SLK 4977 TOTAL .II , 1. Operations Performed: -'uge o Abandon o Suspend o Operation Shutdown o Perforate o Other 181 Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 197-073 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22761-00-00 7. KB Elevation (ft): 47.15' 9. Well Name and Number: PBU P2-01 8. Property Designation: 10. Field / Pool(s): ADL 034622 Prudhoe Bay Field / Point Mcintyre Pool 11. Present well condition summary Total depth: measured 10975 feet true vertical 9272 feet Plugs (measured) 10750 Effective depth: measured 10750 feet Junk (measured) None true vertical 9085 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 5438' 9-5/8" 5473' 4957' 5750 3090 Intermediate Production 10924' 7" 10958' 9258' 8160 7020 Liner >s)~t·~h~~~;¡;;l.· < ~':,..., - - .". "'......."'.,- Perforation Depth MD (ft): 10392' - 10708' Perforation Depth TVD (ft): 8788' - 9050' Tubing Size (size, grade, and measured depth): 4-1/2", 12.6# 13Cr80 10245' Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker 'S-3' packer; 10189'; 7" xÆ" 'ZXP' packer; 7" x 4-1/2" Baker 'S-3' packer 4726'; 4698' 12. Stimulation or cement squeeze summary: Cement behind 7" Casing; and Cement placed behind section of tubing scab liner Intervals treated (measured): Two separate jobs; one at 4812' and one at 4687' - 10189' Treatment description including volumes used and final pressure: Cement with 387 sx Class 'G' and 241 sx Arcticset I to 7" x 9-5/8" annulus at 4812' (cut); Cement tubing scab liner between packers at 4687' - 10189' with 494 sx Class 'G' 13. Representative Dailv Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casina Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service DWell Schematic Diagram 16. Well Status after proposed work: 181 Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing IS true and correct to the best Of my Knowledge. I Sundry Number or N/A if C.O. Exempt: Contact Brandon Peltier, 564-5912 306-027 Printed Name Terrie Hubble Title Technical Assistant Signature /{QÃ!1ù . HI I ~ Phone Date 0¥t3/D<o Prepared By Name/Number: 564-4628 Terrie Hubble, 564-4628 STATE OF ALASKA tp~ ~ !Jö)q;; RECEIVED ALASKA __ AND GAS CONSERVATION COtlllSSION IV" J REPORT OF SUNDRY WELL OPERATlq.tf§Di;~~~s2/ 2006 ons. Commission Form 10-404 Revised 04/2004.1 0 RIG I N A L R8DMS BFL MAR .3 4 Ztlof\ Submit Original Only e e P2-01 Rig Workover Prudhoe Bay Unit 50-029-22761-00-00 197 -073 Accept: Spud: Release: Ri: 02/12/06 N/A 03/04/06 Nabors 7ES PRE-RIG WORK 02103/06 TAG XN AT 10,194' SLM, 10,231' MD. TARGET DEPTH 10,200' MD. RAN 3.80" SWAGE AND SAMPLE BAILER. BAILER CAME OUT EMPTY. 02109/06 SHOOT STRING SHOT FROM 10172' TO 10184' PRE-RWO. CCL STOP DEPTH = 10169'. TUBING PUNCH SHOT FROM 10177' TO 10179'. CCL STOP DEPTH = 10171'. 02110/06 HALIBURTON FASDRILL PLUG SET AT 10208'. CCL TOP DEPTH = 10199.5'. CHEMICAL CUTTER SHOOT DEPTH = 10184'. CCL STOP DEPTH = 10171.5'. SLIGHT STICKING OF ANCHORS AT BOTTOM. NOTIFY DSO OF WELL STATUS. JOB COMPLETE. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-01 P2-01 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 2/10/2006 Rig Release: 3/4/2006 Rig Number: 7ES Spud Date: End: 3/4/2006 2/10/2006 08:00 - 22:30 14.50 MOB P PRE Blow down water and steam. Move pits away from sub and install jeep. Load shop. Move camp, pits and shop from Z-pad to PM 02. Move sub off of Z-108. Stage sub base to lay down derrick. Lay down derrick. 22:30 - 00:00 1.50 MOB N WAIT PRE Satellite camp, truck shop and pit module arrived at Point Mcintyre 2 during Phase 2 weather condition. Weather too severe to safely move the sub base and derrick from Z Pad to Pt Mac 2 2/11/2006 00:00 - 06:00 6.00 MOB N WAIT PRE Lay down derrick. Clean pad, load miscellaneous equipment on trucks. Waiting on weather. Phase 2 weather conditions up to 06:00. 06:00 - 12:00 6.00 MOB N WAIT PRE Waiting on Security to escort Nordic #2. Security granted permission to move rig at 12:00 hrs once Nordic 2 cleared Oxbow road. Preparing well for rig. Removing snow drifts around pad. Move sub base from Z-Pad to SantaFe-Pad. Wait at Santa Fe Pad for security to escourt Nordic 1 from K-Pad road to G-Pad 12:00 - 18:00 6.00 MOB N WAIT PRE Wait at SantaFe Pad for security to escourt Nordic 1 from K-Pad road to G-Pad 18:00 - 00:00 6.00 MOB P PRE Move sub base from Santa Fe Pad to West Dock road 2/12/2006 00:00 - 10:00 10.00 MOB P PRE Move sub base from SantaFe-Pad to Point Mac 2 10:00 - 12:00 2.00 MOB P PRE Prepare well site. Speard herculite, Stage pits 12:00 - 14:30 2.50 MOB P PRE Move in and spot and level sub base over well PM2-01. 14:30 - 15:30 1.00 MOB P PRE Move in and spot and level mud pits 15:30 - 16:30 1.00 MOB P PRE Inspect and raise and pin derrick in place. Raise cattle chute. 16:30 - 20:30 4.00 MOB P PRE Bridal down, connect top drive to blocks, rig up rig floor, hook up lines and utilities. Take on 580 bbls of 9.8 ppg. 120 degree 3% KCL into the mud pits. Rig accepted @ 19:00 hours on PM2-01, 2/12/2006 20:30 - 21 :30 1.00 WHSUR P DECOMP Rig up lines on tree to circulate out freeze protect 21 :30 - 22:00 0.50 WHSUR P DECaMP Pre spud meeting with all parties involved 22:00 - 23:00 1.00 WHSUR P DECOMP Rig up DSM lubricator and pull TWC 23:00 - 00:00 1.00 KILL P DECaMP Pressure test lines to 3000 psi. Reverse circulate outfreeze prptect. pumping 15 bbl of 9.8 ppg KCL brine. Circulating thur choke taking returns out to the cuttings tank at 125 gpm at 200 psi. until returns clean up. 2/13/2006 00:00 - 01 :00 1.00 KILL P DECaMP Pump 20 bbls of 9.8 ppg of 120 degree KCL brine down tubing at 125 gpm 200 psi. Continue to take returns out to the cuttings tank until returns clean up. Stop pumping verify well is dead. Blow down line to cuttings tank. Recovered 32 bbls of diesel from well 01 :00 - 03:30 2.50 KILL N HMAN DECOMP Blow air thru gas buster to ensure gas buster is unobstructed, Unable to blow thru. Thaw ice plug out in the bottom of the U-Tube in the gas buster. 03:30 - 05:30 2.00 KILL P DECOMP Displace well with 9.8 ppg KCL brine thur choke manifold at 125 gpm 200 psi. taking returns to the mud pits. Pumped 1drum of Safe Surf 0 to assist in cleaning tubing. Mud weight in 9.8 ppg / Out 9.8 ppg. Confrim well is dead. Blow down and rig down lines. Printed: 3/6/2006 12:52:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-01 P2-01 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 2/10/2006 Rig Release: 3/4/2006 Rig Number: 7ES Spud Date: End: 3/4/2006 2/13/2006 05:30 - 06:00 0.50 WHSUR P DECaMP Install TWC valve and test from below to 1000 psi. 06:00 - 08:00 2.00 WHSUR P DECOMP Bleed pressure from control lines. Nipple down tree and adapter flange. Terminate control lines. Dress and verify hanger threads by installing a 4-1/2" NSCT cross over 9 turns to the right. Remove 4-1/2" NSCT cross over. Remove tree and adapter flange from cellar 08:00 - 11 :00 3.00 WHSUR P DECOMP Nipple up BOPE and adapter flange 11:00-13:00 2.00 WHSUR P DECaMP Rig up test equipment to 4-1/2 NSCT test joint. Fill up BOPE and choke manifold with water to test. 13:00 - 17:30 4.50 WHSUR P DECaMP Test BOPE and all associated valves to 250 psi low for 5 minute and 3500 psi high for 5 minute. Upper IBOP faied high pressure test. Wittness of BOPE test wavied by AOGCC rep. John Spalding. BOPE test wittnessed by Nabors tool pusher Jim Davidson and BP rep Duncan Ferguson. 17:30 - 20:00 2.50 WHSUR N SFAL DECaMP Remove upper IBOP valve from top drive and replace. 20:00 - 20:30 0.50 WHSUR P DECaMP Test upper IBOP valve to 250 psi low for 5 minutes and 3500 psi high for 5 minutes. Rig down test equipment. 20:30 - 21 :00 0.50 BOPSU P DECOMP Rig up DSM and pull TWC valve with lubiicator. Well took 20 bbls to fill after pulling the TWC valve. 21 :00 - 21 :30 0.50 PULL P DECaMP Make up landing joint 9 turns to the right into the hanger. Back out lock down screws Unseat hanger from tubing spool. Up weight 165k. Pull hanger to rig floor. 21 :30 - 00:00 2.50 PULL P DECOMP Circulate bottoms up at 200 gpm 290 psi. Half way thur bottoms up strokes circulating pressure increased to 2560 psi. 16 bbls from having calculated bottoms up gas was observed and brine wt. coming out of the hole was a 9.2 ppg. Continue to circulate until a 9.8 ppg was acquired going in the hole and coming out of hole. At 87 bbls into the second circulation the circulating pressure returned to 290 psi at 200 gpm. Observe well for 30 minutes with a static loss rate of 4 bbls an hour. 11 bbls were lost to the well bore while circulating. Pressure on 7" x 9-5/8" annulus is 50 Ibs 2/14/2006 00:00 - 00:30 0.50 PULL P DECaMP Break and lay down hanger and landing joint. 00:30 - 01 :00 0.50 PULL P DECOMP Change bails to accomadate compensator. Rig up torque turn equipment and Schlumberger air operated control line spooling unit. 01 :00 - 04:00 3.00 PULL P DECOMP POH and lay down 8 jts. (total out = 8) 4-1/2" 12.6# 13-Cr tubing to a depth of + - 9861 encountering 35 to 50k overpulls staying consistent. Installing thread protectors on all tubulars laid down. 04:00 - 04:30 0.50 PULL P DECaMP Change out Schlumbergers control line spooler from air operated to hydraulic operated spooler to mantain greater tension on control line. 04:30 - 12:00 7.50 PULL P DECaMP POH and lay down 19 jts. (total out = 27) 4-1/2" 12.6# 13-Cr tubing. At +- 9651 One of two controls lines parted. Drain stack to visually look for parted control line. Work pipe continually up and down w/very slow progress. Up weight 190 to 230k. SO string wt. 12:00 - 14:30 2.50 PULL P DECaMP POH and lay down 3 jts. (total out = 30) 4-1/2"12.60 # 13 Cr tubing. 230K Up wt. 14:30 - 16:30 2.00 PULL P DECaMP Reverse circulate 44 bbl. Safe-Lube pill. 84 gpm, 200 psi. Printed: 3/6/2006 12:52:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-01 P2-01 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 2/10/2006 Rig Release: 3/4/2006 Rig Number: 7ES Spud Date: End: 3/4/2006 2/14/2006 14:30 - 16:30 2.00 PULL P DECaMP Well u-tubing to tubing side when pumps shut down. MU head pin and circulate 120 deg. F, 9.8 ppg, 3 % KCL brine to balance fluids in well bore. 210 gpm, 1000 psi. 16:30 - 00:00 7.50 PULL P DECaMP Continue to POH and lay down 5 jts tubing (total out = 35). Found both control lines parted and wadded up on pipe. Cut and untangled same. Work pipe and overpull to 230K Up wt. Work pipe continually up and down w/very slow progress. SO string wt. of 95K. 120 bbls KCI brine lost in 24 hrs. Total of 5 SS bands recovered from 35 jts pulled from well. 2/15/2006 00:00 - 00:30 0.50 PULL P DECOMP Service rig and topdrive. 00:30 - 01 :00 0.50 MOB N SFAL DECaMP Change out slip type elevators to replace damaged unit. (Alignment pin lining up both halves of elevators when closed found to be broken off, recovered metal piece at surface). 01 :00 - 03:00 2.00 PULL P DECaMP Attempt to POH and no movement possible. PU wt. 235K, SO string wt. of 95K. No movement work pipe for 2 hrs. with no progress. SSSV 764', 03:00 - 07:00 4.00 MOB P DECaMP Mobilize Schlumberger wi reline unit. Mobilize Baker fishing hand. Circulate 120 deg. brine as per Schlumberger to facilitate function of chemical cutter. Temperature in 98 deg. F, temperature out 88 deg. F. Wt of brine in and out 9.8 ppg. 07:00 - 07:15 0.25 MOB P DECaMP PJSM w/Schlumerger, all hands, WSL on handling, rigging up and use of Schlumberger chemical cutter. 07:15 - 08:00 0.75 MOB P DECaMP RU Schlumberger wi reline. Receive notification f/town Schlumberger/BP that chemical cutter must not be used. 08:00 - 12:00 4.00 MOB N WAIT DECaMP Mobilize Schlumberger jet cutter from Deadhorse. 12:00 - 13:45 1.75 FISH P DECaMP Assemble and RU jet cutter. Circulate 210 gpm, 1000 psi. until fluid balanced. PJSM w/Schlumberger, all hands, WSL on handling, rigging up and use of Schlumberger jet cutter. 13:45 - 14:30 0.75 FISH P DECOMP Arm and RIH w/Schlumberger jet cutter. 14:30 - 15:00 0.50 FISH P DECaMP Log and correlate jet cutter on depth. Cut tubing at 734' in middle of full joint above SSSV. POH w/cutter. 15:00 - 15:30 0.50 FISH P DECaMP PU on string and string free wIno excess drag. Up wt. 38K. RD Schlumberger wireline. 15:30 - 17:00 1.50 FISH P DECaMP LD 19 jts and 22.46' stub leaving 10' pup 20' stub (at 734') sticking up on top of SSSV. Lay down total of 51 joints and cut-off. 17:00 - 18:00 1.00 FISH P DECaMP RD compensator and 4-1/2" tubing handling equipment. 18:00 - 18:30 0.50 FISH P DECaMP RU short bails and 3-1/2" elevators to handle fishing BHA. 18:30 - 20:30 2.00 FISH N HMAN DECaMP PU rope spear BHA w/6-1/8" spear stop. Spear stop would not fit inside of tubing hanger. Check records. All indicate 26# equipment. Call FMC has no records but all neighboring wells from period have 29# hangers. 20:30 - 21 :30 1.00 FISH P DECaMP Service rig. Slip and cut 130' of drilling line. 21 :30 - 22:30 1.00 FISH P DECaMP MU spear and 6.0" spear stop on BHA and RIH through tubing hanger wIno problem. PU and single in w/9 4-3/4" drill collars rotating two revolutions every 60' while running in per Baker rep. RIH to 337' and engage junk. PU HWDP and RIH to 377'. 22:30 - 23:00 0.50 FISH P DECaMP POH fishing BHA. 23:00 - 23:30 0.50 FISH P DECaMP Cut -200' of control line from spear. Find 7 bands (Total 13) Fluid lost to formation last 24 hrs. = 220 bbls. 2/16/2006 00:00 - 01 :00 1.00 FISH P DECaMP RIH w/spear. Tag junk at 372'. RIH to 408'. Printed: 3/6/2006 12:52:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-01 P2-01 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 2/10/2006 Rig Release: 3/4/2006 Rig Number: 7ES Spud Date: End: 3/4/2006 2/16/2006 01 :00 - 01 :30 0.50 FISH P DECOMP POH with fishing BHA. 01 :30 - 02:00 0.50 FISH P DECaMP Cut 60' of control line from spear. 02:00 - 03:15 1.25 FISH P DECOMP RIH wlspear. Tag junk at 550'. RIH to 581'. 03:15 - 03:45 0.50 FISH P DECaMP POH with fishing BHA. 03:45 - 04:00 0.25 FISH P DECOMP Cut 250' of control line from spear. 04:00 - 04:45 0.75 FISH P DECaMP RIH wlspear. Tag junk at 701'. 04:45 - 05:30 0.75 FISH P DECaMP POH. Recover 60' of control line. 05:30 - 06:30 1.00 FISH P DECaMP RIH and tag up @ 705'. 06:30 - 07:00 0.50 FISH P DECaMP POH. No control line recovered. 07:00 - 09:45 2.75 FISH P DECOMP LD spearlcirc sub assembly. PU overshot BHA # 2 wI 4-1/2" grapple and dressing mill for 4.5" tubing. 09:45 - 10:45 1.00 FISH P DECOMP RIH to 705'. 10:45 - 11:00 0.25 FISH P DECaMP Rotate wldressing mill and wash down over 4-1/2" stump w/60 I rpm, 110 gpm, 120 psi. Engage fish and work free w/250K maximum pull. 11 :00 - 15:00 4.00 FISH P DECOMP POH w/fish. Up wt. 275K, SO wt. 35K. Working pipe out of hole w/overpull on each stand. 15:00 - 16:00 1.00 FISH P DECaMP JAR and work pipe through well head equipment until fish is at rotary . 16:00 - 18:00 2.00 FISH P DECOMP Large wad of several hundred feet of control line tightly wrapped around tubing at top of fish. Cut line free. 18:00 - 19:00 1.00 FISH P DECOMP LD drill collars, jars, bumpers subs, overshot w/cutoff stub, SSSV, and pups. 19:00 - 19:30 0.50 FISH P DECOMP RU long bails to accomodate compensator for pulling/laying down chrome tubing string. 19:30 - 20:30 1.00 FISH P DECOMP Circulate, 210 gpm, 450 psi. Note: Performed derrick inspection after jarring operations. All ok. 20:30 - 21 :00 0.50 FISH P DECOMP RU compensator and all 4.5" tubing handling equipment. 21 :00 - 00:00 3.00 FISH P DECOMP POH and LD 45 jts. tubing. Up wt. 105K. Lost 162 bbls. of brine to formation for 24 hrs. 2/17/2006 00:00 - 10:00 10.00 FISH P DECaMP POH and lay down a total of 241 joints 4-1/2" NSCT chrome tubing using compensator when backing out joints. Lay down 6 GLM, 12 pup joints and 3.65' cut off. Top of cut 4 1/2" tubing stub at 1 0183'. Stick up above packer is 6.15' 10:00 - 11 :00 1.00 FISH P DECaMP RD 4 1/2" tubing handling tools and power tongs. Clear rig floor and clean up. 11 :00 - 12:00 1.00 BOPSU DECaMP RU top drive and rig floor for 4" drill pipe. Function all BOP rams. Retrieve junk from BOP with hook. 12:00 - 12:30 0.50 BOPSU DECaMP RU and run jetting tool and jet out BOP and wear bushing area. 12:30 - 13:00 0.50 BOPSU OTHCMP Install wear bushing and secure with lock down screws. 13:00 - 14:30 1.50 TIEBAC OTHCMP PU dressing mill BHA with 6" dressing mill, 37/5" OD inner mill, 3 boot baskets, 7" casing scraper, bumper sub and jars. 14:30 - 15:00 0.50 TIEBAC P OTHCMP RIH w/drill collars and heavyweight drill pipe. 15:00 - 00:00 9.00 TIEBAC P OTHCMP PU 4" HT-40 drill pipe singles and RIH to 10060'. Did not see any problems running in past suspected hole in 7" casing at 6806'. Taking weight at 10060'. Up wt. 205K, SO wt. 140K. Lost 100 bbls. of brine to formation for 24 hrs. 2/18/2006 00:00 - 02:30 2.50 TIEBAC P OTHCMP Wash down from 10060'. Unable to rotate, torque to 8K (tq. limit of 3-1/2" REG Baker equipment). Pump 80 gpm, 60 rpm. Printed: 3/612006 12:52:05 PM BP E Operations Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-01 P2-01 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 2/1 0/2006 3/4/2006 7ES Spud Date: End: 3/4/2006 Pump hi-vis sweep around and get free rotation with tq. 7K until fill is tagged then back to tq. limit 8K. Keep working pipe and rotating when possible down to 10080'. No progress past 10080' . 02:30 - 04: 15 1.75 TIEBAC P OTHCMP Begin washing f/10080'. Increase viscosity to 40 w/Duo-Vis. Rotating more freely. Still bumping torque limit 8K. Increase pump rate to 350 gpm, 1475 psi. Wash down in 3' to 5' bites wIno rotation. PU and circulate--rotating when below torque limit8K. Paraffin sludge and sand across shakers steadily. Repeat process every 3' to 5' rotating as allowed by torque limit of 8k. 265 gpm, 1304 psi. Up wt. 220K, SO wt. 153K. Rot wt. 163K. Cleanout to 10179'. Tag up solid on stub. 04:15 - 04:30 0.25 TIEBAC P OTHCMP Work pipe and attempt to dress top of tubing stub wlcleanout mill 6" OD(for casing ID) x 3.75" ID (for tubing OD) x 2.19" aD (pilot mill for tubing 10) at 10179'. Tq. bumping 8K limit. Very little rotation possible. Had difficulty getting down over stub w/mills. 05:00 - 06:30 1.50 TIEBAC P OTHCMP Circulate 40 bbl. 9.8 ppg Hi-Vis sweep. Circulate wellbore until fluids clean across shakers. 265 gpm, 1150 psi. 06:30 - 10:45 4.25 TIEBAC P OTHCMP Tag up after circulating and find bottom 6' higher at 10173'. LD 2 jts, blowdown top drive. POH f/10121'. 10:45 - 12:00 1.25 TIEBAC P OTHCMP Stand back drill collars and LD Baker milling equipment. Note: Cut-Rite on tubing dress mill showed wear indicating that mill had been down on top of tubing stub at 10179'. 12:00 - 14:00 2.00 TIEBAC P OTHCMP RU Schlumberger wireline f/USIT/CEMENT/BOND log in 7" casing. 14:00 - 14:30 0.50 TIEBAC P OTHCMP RIH wlSchlumberger USIT/BOND logging tools. 14:30 - 15:30 1.00 TIEBAC N DFAL OTHCMP Cartridge in USIT tool failed. POH and changeout cartridge. NOTE: 1 hr of NPT. 15:30 - 23:00 7.50 TIEBAC P OTHCMP RIH w/USIT/BOND logging tools to 10050' and run USIT/BOND log to 3800'. BOND log found cement top at 5158'. Found no holes, thin spots, or anomalies in casing w/USIT. Occasional cement stringers up to 4880'. Pick casing cut point 2 jts above last visible stringer midway between casing collars at 4806'. POH w/wireline. 23:00 - 23:30 0.50 TIEBAC P OTHCMP RD Schlumberger wireline service. 23:30 - 00:00 0.50 TIEBAC P OTHCMP MU Halliburton 3L retrievable bridge plug and onloff tool. 2119/2006 00:00 - 03:00 3.00 TIEBAC P OTHCMP RIH wlHalliburton 3L retrievable bridge plug and set packing elements at 5696'. 03:00 - 04:00 1.00 TIEBAC P OTHCMP RU and pressure test 7" casing wlchart to 3500 psi for 30 minutes from 5696' to surface. 04:00 - 06:00 2.00 TIEBAC P OTHCMP Pull 1 stand of drill pipe to 5600'. Circulate drill pipe volume of clean brine to clear 40 vis brine from drill pipe to allow sand to fall freely. RU wlfunnel and dump 700 pounds of 12/20 frac sand slowly down drill pipe for debris barrier over retrievable bridge plug during casing cutting operations. 06:00 - 08:00 2.00 TIEBAC OTHCMP POH and LD 3L bridge plug running tool. 08:00 - 08:30 0.50 BOPSU OTHCMP Clean rig floor. Pull wear bushing. Install test plug and test joint. Function test BOPs. 08:30 - 11 :00 2.50 BOPSU OTHCMP Change upper set of rams to 7" and test door seals to 250 psi low test and 3500 psi high test. 11 :00 - 11 :30 0.50 TIEBAC P OTHCMP PU BHA # 4, wlmultistring cutter for 7" casing, 6 bladed Printed: 3/6/2006 12:52:05 PM of 16 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-01 P2-01 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 2/10/2006 Rig Release: 3/4/2006 Rig Number: 7ES Spud Date: End: 3/4/2006 2/19/2006 11:00 -11:30 0.50 TIEBAC P OTHCMP stabilizer, 9 4.75" drill collars, x-over to HT-40 and 24 jts. of 4" HT-40 HWDP. 11 :30 - 13:30 2.00 TIEBAC P OTHCMP RIH to 4823' wlcasing cutter. 13:30 - 14:00 0.50 TIEBAC P IOTHCMP PU single jt of drillpipe, MU topdrive and bring pumps on line and pressure up to 500 psi. to push cutters out and use to locate collar immediately below desired cut zone. Shut down pumps. Correlate collar depth w/log depths-OK. LD single joint of drillpipe. Move cutter to 4812'. 14:00 - 14:30 0.50 TIEBAC P OTHCMP Cut casing pumping 210 gpm, 1250 psi, 45 rpm. 14:30 - 15:00 0.50 TIEBAC P OTHCMP Circulate down outer annulus at at 3 bpm 2280 psi. 15:00 - .17:00 2.00 TIEBAC P OTHCMP Diesel and crude oil circulated out. No Arctic Pack found. Gas to surface at 62 bbls. displacement. Shut well in wlannular preventer w/160 psi casing pressure. Put on choke and circulate gas and crude oil out of wellbore pumping 310 bbls 9.8 ppg brine at 84 gpm, monitoring casing pressure and adjusting with choke as required. Notify AOGCC and drilling management as required that well had been shut in. 17:00 - 17:30 0.50 TIEBAC P OTHCMP Shut down pumps. 0 psi on casing. Monitor well. Static. 17:30 - 19:30 2.00 TIEBAC P OTHCMP Circulate surface to surface through choke at at 2.5 bpm, 1000 psi. 19:30 - 20:00 0.50 TIEBAC P OTHCMP Shut down pump. Open choke, open annular. Monitor well. OK to pump surfactant treatment surface to surface. 20:00 - 22:00 2.00 TIEBAC P OTHCMP Circulate Safe-Surf 0 surfactant treatment surface to surface down 9-5/8" x 7" annulus and up 7" x 4" annulus at 168 gpm, 1950 psi. Monitor well. Static. Brine wt. 9.8 ppg in and out of well. 22:00 - 22:30 0.50 TIEBAC P OTHCMP POH w/8 stands. Up wt. 105K, SO wt. 100K. 22:30 - 23:00 0.50 TIEBAC P OTHCMP MU HES storm packer and RIH to 71' for required BOP test. Set packer. Test to 1000 psi. OK. POH and LD storm packer running tool. 23:00 - 23:30 0.50 TIEBAC OTHCMP Pull wear bushing and install test plug. Prepare for BOP test. 23:30 - 00:00 0.50 BOPSU OTHCMP Change out upper rams from 7" to 3-1/2"- 6" variable for BOP test. 2/20/2006 00:00 - 05:30 5.50 BOPSU OTHCMP Test BOPE as per BP and AOGCC regulations. 250 psi Low, 3500 psi and record on chart. Witness of test waived by Chuck Scheave, AOGCC. Test witnessed by Lowell Anderson BP WSL, and Lenward Toussant Nabors Tourpusher. 05:30 - 07:00 1.50 BOPSU OTHCMP Change out upper rams from 3 1/2"- 6" variable to 7" casing rams. 07:00 - 08:00 1.00 TIEBAC P OTHCMP RIH and engage storm packer wlleft hand threaded joint. POH and LD 7" storm packer. 08:00 - 10:30 2.50 TIEBAC P OTHCMP Continue POH w/4" drill pipe and LD multistring cutter BHA #4. 10:30 - 11 :30 1.00 TIEBAC P OTHCMP MU spear wlgrapple and packoff sized for 7" 26# casing. 11 :30 - 12:00 0.50 TIEBAC P OTHCMP RIH and engage 7" casing. Pull 350K. Unable to free casing at cut point of 4812'. 12:00 - 16:00 4.00 TIEBAC P OTHCMP PU and work string (no down movement possible wlcasing hanger in place). Pull to 375K. Unable to pull casing free. RU and circulate 225 gpm, 850 psi down drill pipe taking returns up the 9-5/8" x 7" annulus. Small chunks of cement across shakers. 16:00 - 16:30 0.50 TIEBAC P OTHCMP Release and LD spear. 16:30 - 17:30 1.00 TIEBAC P OTHCMP PU and RIH w/multistring casing cutter BHA to 930'. Printed: 3/6/2006 12:52:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-01 P2-01 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 2/10/2006 Rig Release: 3/4/2006 Rig Number: 7ES Spud Date: End: 3/4/2006 2/20/2006 17:30 - 18:00 18:00 - 19:00 19:00 - 20:00 20:00 - 21 :00 21 :00 - 23:00 - 00:00 2/21/2006 00:00 - 02:00 02:00 - 03:30 03:30 - 04:00 05:00 - 05:30 05:30 - 05:45 05:45 - 07:00 07:00 - 09:30 09:30 - 11 :00 11 :00 - 00:00 2/22/2006 00:00 - 08:00 08:00 - 08:30 08:30 - 11 :00 11 :00 - 12:00 12:00 - 12:30 12:30 - 18:00 18:00 - 20:00 0.50 TIEBAC P OTHCMP Establish depth by locating collar above cut point. Move back to 900 and cut casing w/45 rpm, 1.5K tq., 6 bpm, 1020 psi. Casing jumped slightly when it parted. OTHCMP POH and LD 7" multistring casing cutter. OTHCMP PU spear w/grapple sized for 7" 26# casing and RIH. Pull 50K and casing is free at 900'. OTHCMP POH until 7" casing hanger is at floor and LD spear. RU to LD 7" casing. OTHCMP POH and LD 21 its + 10.5' stub. RD casing equipment. OTHCMP PU spear w/grapple for 7" 26# casing, 8-1/8" stop sub, 6-1/4" bumper sub, 6-1/4" jars, 9 6-1/2" drill collars, 6-1/4" accelerator and 21 jts. of HT40 heavy weight drill pipe. Spear will locate 11.7' inside of 7" fish. Top of fish at 900'. OTHCMP RIH with fishing BHA to top of fish at 900' and engage fish with spear and packoff (Circulation up 9-5/8" x 7" OA). Up wt. 68K, SO wt.68K. Break circulation. 110 gpm, 1200 psi. OTHCMP Jar on fish. Pump hi-vis sweep, 84 gpm, 1000 psi. Pull to 275K, jars bleed to 200K and fire, pull to 400K. No upward movement with fish. Slack off to 0 and cock jars. No downward movement with fish. Repeat ad infinitum. No movement up or down at top of fish. Packing off. Pump 50 gpm, 1200 psi. OTHCMP Release spear from fish at 900' and POH to HWDP. OTHCMP PJSM about pinch points when standing back drill collars. Stand back HWDP and 6-1/4" drill collars. Brine wt. = 9.8 ppg. Function test BOPs. Inspect derrick and topdrive after jarring operations. OTHCMP Install wear bushing. OTHCMP PU multistring cutter BHA and RIH to 1956'. OTHCMP POH to 1000', Consult with town team on plan forward. Service rig and topdrive. Cut and slip drilling line. OTHCMP POH and LD multistring cutter. WAIT OTHCMP Phase 3 conditions. Secure well. Secure rig and crews. Account for all personnel. PJSM with hands on Phase 3 weather conduct. WAIT OTHCMP Phase 3 weather conditions. Well secured. Rig secured. All personnel accounted for. OTHCMP RU wireline equipment and MU tools. OTHCMP USIT log 7" casing for cement evaluation from 4500' to 900'. Good to medium cement from 1184' to 2520' and again between 2875' and 2930'. No significant cement over the rest of the interval. A clear channel is noted throughout all cement. 1.00 TIEBAC P 1.00 TIEBAC P 1.00 TIEBAC P 2.00 TIEBAC P 1.00 TIEBAC P 2.00 TIEBAC P 1.50 TlEBAC P 0.50 TIEBAC P 0.50 TIEBAC P 0.25 TIEBAC P 1.25 TIEBAC P 2.50 TIEBAC P 1.50 TIEBAC P 13.00 TIEBAC N 8.00 TIEBAC N 0.50 TIEBAC P 2.50 TIEBAC P 1.00 TIEBAC P 0.50 TIEBAC P 5.50 TIEBAC P OTHCMP RD wireline equipment and unit. OTHCMP Rig maintenance, service rig and top drive. OTHCMP Consult wltown team and interpret USIT log to determine best liner top point. Establish plan forward for next casing cut point and subsequent cementing program. Clean rig. Clear snow from access to pipe shed. OTHCMP MU casing cutter BHA #8 w/5.5" multistring cutter, 6" bladed stabilizer, nine 4.75" drill collars, and 7 stands of HWDP. RIH to 1100' and locate collar at 1094.4' by pressuring up on cutter to 300 psi and moving down until cutters engage collar midpoint recess. PU to 1084.9' w/cutters. Up wt. 60K, SO wt. 2.00 TIEBAC P Printed: 3/612006 12:52:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-01 P2-01 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 2/10/2006 3/4/2006 7ES Spud Date: End: 3/4/2006 2/22/2006 18:00 - 20:00 2.00 TIEBAC P OTHCMP 60K, ROT wt. 60K. Cut casing w/45 rpm, 85 gpm to 273 gpm, I tq. 1.5K to 2K, 1500 psi. After six minutes see 200 psi pressure drop and see torque drop. Hold pump rate and rotate for 5 more minutes to be sure casing cut is complete. Stop rotation and PU l' wI pressure on and had 3K Ibs. weight of pipe hanging on knives. Shut down pumps. Lost 3K Ibs. weight of pipe. 20:00 - 21 :00 1.00 TIEBAC P OTHCMP POH wlcasing cutter BHA #8. 21 :00 - 21 :30 0.50 TIEBAC P OTHCMP Pull wear bushing. 21 :30 - 22:30 1.00 TIEBAC P OTHCMP MU and RIH w/BHA #9 wI?" spear and packoff cup, 6.297" max aD ITCO spear, 7" spear extension, 8.125" spear stop sub, 7 stands of HWDP. RIH to 1079'. Up wt. 55K. Engage fish. PU and 7" casing fish is free. 22:30 - 23:30 1.00 TIEBAC P OTHCMP POH w/max up weight 65K. LD spear BHA #9. 23:30 - 00:00 0.50 TIEBAC P OTHCMP RU to LD 7" BTC-M casing fish. 2/23/2006 00:00 - 02:00 2.00 TIEBAC P OTHCMP LD 7" BTC-M casing fish. Stub = 32.13' + 3 full jts. Cut on bottom of fish was clean. 02:00 - 02:45 0.75 TIEBAC P OTHCMP PU cleanout and washover BHA # 10 w/8.5" aD mill shoe, 2 its of 8.375" washpipe, 8.375" drive sub, xovers, ?" boot basket, 9.625" casing scraper, bit sub, 6.25" bumper sub, 6.25" oil jar, xovers, nine 6.5" drill collars, xovers, 7 stands of HWDP. 02:45 - 04:00 1.25 TIEBAC P OTHCMP RIH wlcleanout and was,hover BHA # 10. 04:00 - 04:45 0.75 TIEBAC P OTHCMP Find top of stub at 1084:4'. Wash over slowly to collar at 1094.4'. PU wt 68K, SO wt. 68K. Rotate 30 rpm w/1.5K tq., pump 280 gpm at 270 psi. Circulate well and clean up annulus until brine clean over shakers. 04:45 - 05:30 0.75 P OTHCMP Circulate 25 bbls hi-vis sweep and circulate until clean brine across shakers 275 gpm, 250 psi. 05:30 - 06:00 0.50 TIEBAC P OTHCMP POH wlcleanout and washover BHA # 10 to drill collars. 06:00 - 08:00 2.00 TIEBAC P OTHCMP LD nine 6.5" drill collars 08:00 - 08:30 0.50 TIEBAC P OTHCMP Clean floor. 08:30 - 11 :00 2.50 TIEBAC P OTHCMP PU drill collars, 7" casing hydraulic backoff tools and RIH wlbackoff BHA # 11. 11 :00 - 12:00 1.00 TIEBAC P OTHCMP RIH to wldrill pipe to 1094'. 12:00 - 14:30 2.50 TIEBAC P OTHCMP Straddle collar locataed at 1094' wlBaker hydraulic backoff tool. Pressure up on tool to initial back off pressure of 1350 psi. Pressure cycle tool to back off 6-1/4 turns. Final backoff pressure 580 psi. 14:30 - 15:00 0.50 TIEBAC P OTHCMP LD single. Drop ball. BD lines. LD pup jt. 15:00 - 15:45 0.75 TIEBAC P OTHCMP POH 1 stand. MU topdrive to drill pipe. Pressure up to 2800 psi and open circulation sub. BD topdrive. 15:45 - 16:30 0.75 TIEBAC P OTHCMP POH to BHA. 16:30 - 17:30 1.00 TIEBAC P OTHCMP LD back off BHA # 11. 17:30 - 18:30 1.00 TIEBAC P OTHCMP PU BHA # 12 wlbull nose sub, 6.220" OD ITCO spear, 8.125" aD spear stop sub, Xovers, 21 jts of HWDP. 18:30 - 19:30 1.00 TIEBAC P OTHCMP RIH and engage fish at 1085'. 19:30 - 20:15 0.75 TIEBAC P OTHCMP POH wlBHA # 12. Find fish w/7"BTC-M collar down. 20:15 - 20:30 0.25 TIEBAC P OTHCMP Pull wear bushing. 20:30 - 22:00 1.50 TIEBAC P OTHCMP RU torque turn equipment and casing handling equipment to run 7" TC-II. 22:00 - 00:00 2.00 TIEBAC P OTHCMP PJSM wIWSL, tour pusher, safety man, and all hands on 7" premium thread pipe handling and run casing to 600'. Printed: 3/612006 12:52:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-01 P2-01 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 2/10/2006 Rig Release: 3/4/2006 Rig Number: 7ES Spud Date: End: 3/4/2006 02:00 - 02:30 0.50 TIEBAC P Run 7" 26# L-80 TC-II casing with screw-in sub to 1080'. PJSM at tour change wIWSL, tour pusher, safety man, and all hands on 7" premium thread pipe handling. OTHCMP Circulate over stub at 107 gpm, 0 psi. Up wt. 70K, SO 68K, Rot wt. 70 K. Rotate 7" string at 3 rpm. Move down slowly. Engage thread. Torque .5K at initial thread contact point and 9.3K at final point of makeup process. Worked pipe up and down after seeing 5K torque, 25K SO to 50K Up wt. Achieve 9.3K torque and work pipe 75K Up wt. to 25K SO wt. 9.3K constant. Pull test casing to 200K and hold. Split stack and install emergency slips in and slackoff with 100K on slips. Cut pipe with Wachs cutter. Lay down cut-off stub. Install packoff. Nipple up BOP. Rig up and pressure test packoff to 3500 psi for 30 minutes. Change rams from 7" to 3 1/2" to 6" variable. Test 250 psi high pressure, 3500 low pressure. RD test equipment. Install wear bushing. Make up milling BHA # 13 with swage, bit sub 6.059" string mill, double pin sub, two boot baskets, bit sub, bumper sub, oil jar, 3.5" IF pump out sub, XO, 21 jts of HWDP. RIH to 4812'. Circulate, rotate, and work mill up and down through cut section at 4812' to dress area several times. No indications of misaligned pipe or rough casing. PU wt 105K, SO wt, 95K, Rot. wt. 100K, 40 rpm, 3K tq., 250 gpm, 650 psi. OTHCMP Circulate down 7" casing through casing cut at 4812' and up 7" x 9-5/8" annulus with annular preventer closed. Pump at 165 gpm, 2600 psi with 587 bbl of brine. Good returns. Small pieces of cement over shakers. Shakers cleaned up. Dumped 101 bbls. brine contaminated with oil, diesel, and gas. Rig down lines and blow down topdrive. POH 4780' with string milling BHA. Lay down milling BHA # 13. Pick up Baker multistring cutter BHA # 14 with 5.5" multistring cutter fitted with 71/2" cutters, 6" bladed stabilizer, 9 each 4.75" drill collars, XO, 7 stands of HWDP. RIH with multistring cutter to 1125'. Pressure up to 500 psi and move extended cutters downhole and locate casing collar recess at 1136' drill pipe measurement. PU 15' to 1121' and cut casing. Up wt. 60K, SO wt 60K. Begin cut at 40 rpm, 1 K tq to 1.5K tq. 200 gpm, 1 035 psi. I ncrease rate to 247 gpm, 1408 psi. and rotate from 20:35 to 20:40. Pressure drop from 1408 psi to 426 psi, 292 gpm. Saw casing jump. Cut completed. POH from 1121 '. LD multistring cutter BHA # 14. Knives in good shape. Cut rite and substrate scarred indicating good cut. Pull wear bushing and set test plug. Change out top rams from 3 1/2" X 6" to 7" and test door seals with chart to 3500 psi. Rig down test equipment and blow down lines. Split stack at tubing spool and casing head flange. Pull FMC 02:30 - 04:30 2.00 TIEBAC P OTHCMP 04:30 - 05:00 0.50 BOPSU OTHCMP 05:00 - 06:30 1.50 BOPSU OTHCMP 06:30 - 07:30 1.00 BOPSU OTHCMP 07:30 - 08:00 0.50 BOPSU OTHCMP 08:00 - 09:00 1.00 TIEBAC OTHCMP 09:00 - 11 :00 2.00 TIEBAC P OTHCMP 11 :00 - 12:00 1.00 TIEBAC P OTHCMP 12:00 - 15:30 3.50 TIEBAC P 15:30 - 16:00 0.50 TIEBAC P OTHCMP 16:00 - 18:00 2.00 TIEBAC P OTHCMP 18:00 - 18:30 0.50 TIEBAC P OTHCMP 18:30 - 20:00 1.50 TIEBAC N HMAN OTHCMP 20:00 - 20:30 0.50 TIEBAC N HMAN OTHCMP 20:30 - 20:45 0.25 TIEBAC N HMAN OTHCMP 20:45 - 21 :30 0.75 TIEBAC N HMAN OTHCMP 21 :30 - 22:00 0.50 TIEBAC N HMAN OTHCMP 22:00 - 22:30 0.50 TIEBAC HMAN OTHCMP 22:30 - 00:00 1.50 BOPSU HMAN OTHCMP 2/25/2006 00:00 - 02:00 HMAN OTHCMP Printed: 3/6/2006 12:52:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-01 P2-01 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 2/1 0/2006 Rig Release: 3/4/2006 Rig Number: 7ES Spud Date: End: 3/4/2006 7" packoff. Weld slip segments together and to 7" casing. Install pack off. 02:00 - 03:00 HMAN OTHCMP Nipple up BOP. 03:00 - 03:15 HMAN OTHCMP Test packoff and flange seal ring to 3500 for 5 minutes. OK. 03:15 - 03:30 HMAN OTHCMP Pull packoff. 03:30 - 04:00 HMAN OTHCMP Pick up spear BHA # 15 with pack off cup, XO 92681TCO spear 6.297", 7" spear extension, 8.125 spear stop sub, XOs, 1 jt. drill pipe. 04:00 - 04:30 0.50 TIEBAC N HMAN OTHCMP RIH to 7" casing top in well head and engage 7" with spear. Pick up and pull 7" fish to rotary table. 04:30 - 05:30 1.00 TIEBAC N HMAN OTHCMP RU casing running equipment and compensator for 7" TC-II casing. 05:30 - 05:45 0.25 TIEBAC N HMAN OTHCMP Pull 7" casing cut to floor. Brine wt. 9.8 ppg. 05:45 - 07:30 1.75 TIEBAC N HMAN OTHCMP Retrieve emergency slip body from 11" x 7" bowl. 07:30 - 1 0:30 3.00 TIEBAC N HMAN OTHCMP Pull 26 jts TC-II casing using compensator to lay down. Lay down TAM Port Collar screw in sub and XO with box down. Cut off stub, 26.39'. 10:30 - 11:30 1.00 TIEBAC N HMAN OTHCMP RD casing handling equipment and clear floor. 11 :30 - 12:00 0.50 TIEBAC N HMAN OTHCMP PU test jt. Install test plug. 12:00 - 13:30 1.50 TIEBAC N HMAN OTHCMP Change out rams fIT' to 3.5" x 6" variables and test door seals to 3500 psi w/chart. Function test rams. 13:30 - 14:00 0.50 TIEBAC N HMAN OTHCMP Rig down test equipment, pull test plug and install wear bushing. 14:00 - 15:00 1.00 TIEBAC N HMAN OTHCMP PU BHA #16 wlmill shoe, two 8.375" wash pipe extensions, 8.375" drive sub, XO, double pin sub, 7" boot basket, 9.625" casing scraper. bit sub, bumper sub, oil jars, nine 4.75" drill collars, XO, 7 stands HWDP. 15:00 - 16:30 1.50 TIEBAC N HMAN OTHCMP RIH slowly, pipe running in wet from large wash pipe aD. 16:30 - 17:00 0.50 TIEBAC N HMAN OTHCMP Wash down and tag 7" stub at 1121'. Swallow 15' to collar at 1136'. Up wt. 60K, SO wt. 60 K, 35 rpm, tq. 1-4K, 250 gpm, 275 psi. 17:00 - 17:30 0.50 TIEBAC N HMAN OTHCMP Circ. 328 bbls. at 250 gpm, 275 psi. 17:30 - 18:30 1.00 TIEBAC N HMAN OTHCMP POH wlcleanout BHA # 16. Brine wt. 9.8 ppg. 18:30 - 19:30 1.00 TIEBAC N HMAN OTHCMP LD BHA # 16 and clear floor. 19:30 - 21 :30 2.00 TIEBAC N HMAN OTHCMP PU casing backoff assembly BHA #17 with 9 drill collars and 21 HWDP. 21 :30 - 22:30 1.00 TIEBAC N HMAN OTHCMP RIH to 1414'. 22:30 - 00:00 1.50 TIEBAC N HMAN OTHCMP MU head pin and cement hose on single drill pipe joint, set BHA #17 wlupper slips at 1125' wltop of cutoff section 4' above at 1121'. Bottom slips below collar at 1136'. Pressure up and set slips. Pressure up to 3500 and observe pressure drop to 530 psi after 4 turns. Cycle tool per Baker representative. Back off 7" casing at 1136' 2/26/2006 00:00 - 02:00 2.00 TIEBAC N HMAN OTHCMP POH wlbackoff BHA # 17. Brine wt. 9.8 ppg. 02:00 - 02:30 0.50 TIEBAC N HMAN OTHCMP LD BHA # 17. 02:30 - 03:00 0.50 TIEBAC N HMAN OTHCMP PU Spear BHA # 18 wI bull nose, 9268 ITCO 6.22 spear, 8.125" spear stop sub, XOs, 21 jts HWDP. 03:00 - 04:00 1.00 TIEBAC N HMAN OTHCMP RIH to top of fish at 1121' and engage fish wlspear. 04:00 - 05:00 1.00 TIEBAC N HMAN OTHCMP POH wlspear BHA # 18. Lay down 14.54' cut off stub, with 7" BTC pin down. Brine wt. 9.8 ppg. 05:00 - 06:00 1.00 TIEBAC N HMAN OTHCMP RU and changeout top rams f/3.5" x 6" variable to 7". 06:00 - 06:30 0.50 TIEBAC N HMAN OTHCMP Test door seal to 250 psi low and 3500 psi high. RD test equipment. Printed: 3/6/2006 12:52:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-01 P2-01 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 2/10/2006 Rig Release: 3/4/2006 Rig Number: 7ES Spud Date: End: 3/4/2006 2/26/2006 06:30 - 08:00 1.50 TIEBAC N HMAN OTHCMP RU 7" casing running equipment and compensator. Change bails on topdrive. PJSM wlall hands, tourpusher and WSL for casing running. 08:00 - 10:00 2.00 TIEBAC N HMAN OTHCMP RIH wI?" BTC pup pin down, TAM Port Collar, and 28 jts of 7" 26 # L-80 TC-II casing. PU wt 55K, SO wt., 55K. 10:00 - 11 :00 1.00 TIEBAC N HMAN OTHCMP MU XO from 4" HT 40 drill pipe to 7" TC-II casing and wash down to collar at 1136' w/topdrive. Engage and makeup BTC thread into BTC-M collar at 1136'. Rotate slowly and see torque build. Work pipe up and down wltorque held in string until casing is torqued up to 9.3K. Pull test casing string to 200K. 11 :00 - 12:00 1.00 TIEBAC N HMAN OTHCMP ND BOP and install emergency slips in 11" X 7" bowl. 12:00 - 13:00 1.00 TIEBAC N HMAN OTHCMP Slack off 100K on slips. 13:00 - 14:00 1.00 TIEBAC N HMAN OTHCMP Cut casing off and dress cut. 14:00 - 14:30 0.50 TIEBAC N HMAN OTHCMP Install packoff and run in lock down screws. 14:30 - 17:00 2.50 TIEBAC N HMAN OTHCMP NU BOP stack and test pack off t/3500 psi f/10 min. 17:00 - 17:30 0.50 TIEBAC P OTHCMP Install wear ring, change out bails, clear floor. 17:30 - 18:00 0.50 TIEBAC P OTHCMP PU Halliburton Champ packer. 18:00 - 20:30 2.50 TIEBAC P OTHCMP RIH to 4740' wlcenter element of Champ packer and set w/20K down wt. 20:30 - 21 :00 0.50 TIEBAC P OTHCMP Test 7" casing to 3500 psi for 15 mins from Champ packer 4740' to surface at pipe rams. RD test equipment and blow down lines. 21 :00 - 23:30 2.50 TIEBAC P OTHCMP POH wlHalliburton Champ packer. 23:30 - 00:00 0.50 TIEBAC P OTHCMP PU Halliburton Fast Drill composite bridge plug and and RIH to 629'. 2/27/2006 00:00 - 02:00 2.00 TIEBAC P OTHCMP RIH wlHalliburton Fast Drill composite bridge plug and set at 4837' Rotate 45 turns to right and pick up 45K over string wt of 105K. Shear out at 150K. PU to 4825'. RI H and tag plug at 483?' and stack 20K on it. 02:00 - 04:00 2.00 TIEBAC P OTHCMP POH wlrunning tool for Fast Drill composite bridge plug. 04:00 - 06:30 2.50 TIESAC P OTHCMP PU and RIH w/Halliburton EZSV cement retainer and set at 4794'. Up wt. 103K, SO wt 103K. Set EZSV by rotating 25 turns to right to expose stinger. PU and pull 40K over string wt. of 103K to 143K. SO 20K on tool to verify setting depth. 06:30 - 09:00 2.50 TIEBAC P OTHCMP Break circulation pumping down drill pipe out casing cut at 4812' and taking returns up 7" x 9-5/8" annulus to surface. Pump 4 bbl/min at 2800 psi. 09:00 - 09:30 0.50 TIEBAC P OTHCMP Perform injectivity test by closing in 7" x 9-5/8" annulus. Pump down drill pipe and out through casing cut at 4812'. Closed annulus valve at surface directed fluid down 7" x 9-5/8" annulus toward 9-5/8" shoe at 5473'. Immediately pressured up to 1500 psi. No bleed off. Injectivity not established through 9-5/8" shoe. 09:30 - 11 :00 1.50 TIEBAC P OTHCMP RU Little Red Hot Oil Services to reverse circulate. 11 :00 - 13:30 2.50 TIEBAC P OTHCMP PJSM w/WSL, tool pusher, Hot Oil and all hands. Reverse circulate 158 bbls. of diesel down 7" x 9-5/8" annulus taking returns to pits. Pump 2 bpm, max psi. 1320. 13:30 - 15:00 1.50 TIEBAC P OTHCMP PJSM w/WSL, tool pusher, all hands, and Schlumberger. Rig up Schlumberger to pump 5 bbls fresh water to Tee on rig floor. Test lines to 4000 psi. Mix cement on the fly and displace freshwater out Tee on floor until cement at floor. Redirect valves down drill pipe. Pump 80.5 bbls. of 15.8 ppg class "G" Printed: 3/6/2006 12:52:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date P2-01 P2-01 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 2/10/2006 Rig Release: 3/4/2006 Rig Number: 7ES Spud Date: End: 3/4/2006 I 2/27/2006 13:30 - 15:00 1.501 TIEBAC P OTHCMP 1 st stage cement down drill pipe through EZSV cement I retainer at 4794', out casing cut in 7" at 4812' and up 7" x 9-5/8" annulus to depth of 2520'. Take returns out 7" x 9-5/8" I annulus valve to pits. Send sample to Schlumberger for UCA 1.00 I TIEBAC analysis. 15:00 - 16:00 P OTHCMP Displace w/total of 40 bbls, 5 bbls. w/Schlumberger and 35 I bbls. wlrig pumps. Underdisplace by 2 bbls. Sting out of I EZSV and pick up to 4667'. Continue purnping and saw cement contaminated brine at surface. Pump until fluid clean at surface. 16:00 - 17:30 1.50 TIEBAC P OTHCMP POH w/EZSV stinger f/4667' to 1340'. 17:30 - 18:30 1.00 TIEBAC P OTHCMP Circulate 50 bbls of diesel down drill pipe and up 4" drill pipe x 7" annulus w/Little Red Pumping Service at 2 bpm to fill 1200' of 7" casing wldiesel column. 18:30 - 19:00 0.50 TIEBAC P OTHCMP Allow diesel to U-tube from 4" drill pipe x 7" annulus. 19:00 - 19:30 0.50 TIEBAC P OTHCMP POH f/1340' to surface and LD EZSV stinger. 19:30 - 20:00 0.50 TIEBAC P OTHCMP PU TAM Port Collar Combo operating tool and RIH to 1130'. 20:00 - 21 :00 1.00 TIEBAC P OTHCMP Locate TAM Port Collar at 1130', RU lines and circulating TEE at surface. Pressure drill pipe to 1000 psi. to test cups on Combo cementing tool. 21 :00 - 21 :30 0.50 TIEBAC P OTHCMP PJSM with WSL, all hands, tourpusher, and Schlumberger. RU Schlumberger to pump freshwater to Tee and test lines to 4000 psi. Mix cement on the fly and displace freshwater out Tee on floor until cement at floor. Redirect valves down drill pipe. Pump 40 bbls. of 15.7 ppg. Arctic Set 1 cement (3 hrs thickening time at 40 deg F.) down drill pipe through TAM Port Collar and up 7" x 9-5/8" annulus. Pump 2.6 bblslmin at 260 psi. Approximately 5 bbls good cement returned to surface. Pump nine total bbls. displacement at 4 bblslmin at 660 psi. Schlumberger pumped 5 bbls of displacement and rig pumped 4 bbls. Underdisplace cement by 2 bbls. 21 :30 - 22:00 0.50 TIEBAC P OTHCMP PU and close TAM Port Collar. Rotate 1/4 turn to right and PU to pull out of port collar and pull to 1120'. Pressure up to 1800 psi and blow ball seat out on TAM Combo tool. Pressure test TAM Port Collar to 1000 psi. for 2 mins. down drill pipe. 22:00 - 22:30 0.50 TIEBAC P OTHCMP Circulate 95 bbls, 285 gpm. 1/2 bbl. green cement to surface at bottoms up. Circulate until brine clean. 22:30 - 23:30 1.00 TIEBAC P OTHCMP POH and LD TAM Port Collar Combo operating tool. 23:30 - 00:00 0.50 BOPSU P TIEB1 Pull wear bushing. Set test plug. 2/28/2006 00:00 - 00:30 0.50 BOPSU P TIEB1 Cont. RU for BOP test. 00:30 - 04:00 3.50 BOPSU P TIEB1 BOP test. NOTE: WSL called AOGCC rep. Lou Grimaldi at 22:30 to give required 2 hr. 2nd notice after 24 hr notice of impending BOP test. Left message. Call not returned. AOGCC not on location at 00:30. Started BOP test. BOP test witnessed by Lowell Anderson BP WSL and Chris Weaver Nabors Tourpusher. 04:00 - 05:30 1.50 CLEAN P CLEAN PU clean out BHA # 19 w/6-1/8" AT J4 bit, two boot baskets, bit sub, oil jars, 3.5" pump out sub, nine 4.75" drill collars, XO to 4" HT-40, 21 jts. HWDP. 05:30 - 08:00 2.50 CLEAN P CLEAN RIH wlcleanout BHA # 19. Tag top of cement at 4770' 08:00 - 09:00 1.00 CLEAN P CLEAN Rig up test equipment and test 7" casing to 3500 psi for 30 minutes. Rig down test equipment 09:00 - 19:00 10.00 CLEAN P CLEAN Install blower hose on top drive. Drill cement from 4770' to Printed: 3/6/2006 12:52:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-01 P2-01 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 2/10/2006 Rig Release: 3/4/2006 Rig Number: 7ES Spud Date: End: 3/4/2006 2/28/2006 09:00 - 19:00 10.00 CLEAN P CLEAN 4794'. Drill EZSV from 4794' to 4795'. Drill cement track and fastdrill plug at 4834'. Pushed fastdill to top of sand at 5630'. Pick up weight 120K, Slack off weight 100K, Rotating weight 110K, 60 rpm torque 4K, 300 gpm at 1000 psi Brine wt IN 9.8 ppg Out 9.8 ppg 19:00 - 20:30 1.50 CLEAN P CLEAN Rig up and attempt to test 7" casing while monitoring the OA for pressure. Pressure fell 500 psi in 5 minutes. Bleed pressure off. Check surface equipment. A second attempt to test casing I was made with the same results. Rig down and blow down I lines. 20:30 - 23:00 2.50 CLEAN P CLEAN Pull out of the hole from 5630' to 304' 23:00 - 23:30 0.50 CLEAN P CLEAN Lay down BHA. Recovered approx 10 Ibs of metal from boot baskets. 23:30 - 00:00 0.50 CLEAN P CLEAN Pick up BHA #20, Reverse circ junk basket. double pin sub, 2 4-3/4" boot baskets, bit sub, float sub, 94-3/4" drill collars, cross over sub, 21 joints 4" HW drill pipe. 3/1/2006 00:00 - 00:30 0.50 CLEAN P CLEAN Pick up BHA #20, Reverse circ junk basket. double pin sub, 2 4-3/4" boot baskets, bit sub, float sub, 94-3/4" drill collars, cross over sub, 21 joints 4" HW drill pipe. Function BOPE. 00:30 - 02:00 1.50 CLEAN P CLEAN Run in the hole with BHA #20 to 3245'. Filling pipe 125 pgm at 800 psi. 02:00 - 02:30 0.50 CLEAN P CLEAN Service top drive and crown. 02:30 - 03:30 1.00 CLEAN P CLEAN Run in the hole from 3245' to 5630'. 03:30 - 06:00 2.50 CLEAN P CLEAN Burn over remnants of EZSV and FasDrill, Utilizing reverse circulating junk basket. Wash down to within l' top of RBP at 5686'. Up weight 125K, Slack off weight 103K, Rotating weight 115K, 50 rpm, Torque 5K, 322 gpm at 2450 psi. Pumping high vis sweeps as needed to clean the hole. 06:00 - 07:00 1.00 CLEAN P CLEAN Pump a 25 bbl Hi-Vis sweep at 320 gpm 2430 psi, While reciprocating pipe, Brine weight in 9.8 ppg lOut 9.8 ppg. 07:00 - 09:30 2.50 CLEAN P CLEAN Blow down top driveand remove blower hose. Pull out of the hole. 09:30 - 10:30 1.00 CLEAN P CLEAN Lay down BHA #20. FasDrill recovered, found inside reverse circulating junk basket. Function BOPE. 10:30 - 11 :00 0.50 CLEAN P CLEAN Make up BHA #21. Over shot, 94-3/4" drill collars, cross over and 21 4" HW drill pipe. 11 :00 - 14:00 3.00 CLEAN P CLEAN Run in the hole with BHA # 21 to 5685'. Pick up a joint of 4' drill pipe and tag top of RBP at 5688'. Circulate 60 bbls at 126 gpm 250 psi prior to engauging RBP to ensure that there was no junk on or around the RBP. Up weight 135K, Slack off weight 100K 14:00 - 14:30 0.50 CLEAN P CLEAN Engauge RPB and pull free at 145K 10K over pull. 14:30 - 15:30 1.00 CLEAN P CLEAN Circulate 142 bbls at 126 gpm 250 psi, monitor well bore, static. 15:30 - 18:30 3.00 CLEAN P CLEAN Pull out of the hole and lay down BHA #21. Recovering RBP and a portion of cement retainer rubber. Both boot baskets were empty. 18:30 - 19:30 1.00 CLEAN P CLEAN Make up BHA #22. 6" dressing shoe, wash pipe extension, baskert catcher, bushing, reverse head, reverse circ top sub, double pin sub, 24-3/4" junk baskets, 7" casing scraper, bit Printed: 3/6/2006 12:52:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-01 P2-01 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 2/10/2006 Rig Release: 3/4/2006 Rig Number: 7ES Spud Date: End: 3/4/2006 3/1/2006 18:30 - 19:30 1.00 CLEAN P CLEAN sub, float sub, bumper jar, oil jar, pump out sub, 9 4-3/4" drill collars, cross over sub, 21 4" HW drill pipe 19:30 - 00:00 4.50 CLEAN P CLEAN Run in the hole with BHA #22 to 8502'. Filling drill pipe at 3819' and 7642' at 143 gpm 360 psi. 3/2/2006 00:00 - 01 :00 1.00 CLEAN P CLEAN Continue to run in the hole with BHA #22 from 8502' to 10099'. Install blower hose. 01 :00 - 03:00 2.00 CLEAN P CLEAN Wash down to 10169 tagging debris. Pump 50 bbl Hi-Vis sweep at 250 gpm 1800 psi. Rotation limited due to torque limtations on BHA. UP weight 215K, Slack off weight 133K, Rotary 165K. 40 RPM, Torque 11K. At bottoms up a 400% excess in returns was observed. Continue circulating adding 3 drums of Safe Lube to mud system. After Safe Lube was circulated around the rotary torque dropped to 1 OK at 40 RPM. 03:00 - 03:30 0.50 CLEAN P CLEAN Wash debirs from 10169' to 10171'. Dress 4-1/2" tubing stub from 10171' to 10177'. With 6" dressing mill, verified that mill had gone over tubing stub by a 50 psi increase in pump pressure. 03:30 - 05:00 1.50 CLEAN P CLEAN Pump a 25 bbl Hi-Vis sweep, at bottoms up 300% excess in returns was observed. Displace well bore out with clean 9.8 ppg brine. 05:00 - 07:30 2.50 CLEAN P CLEAN Blow down top drive and remove blower hose. Pull out of the hole standing back 54 stands of 4" HT-40 drill pipe in the derrick. 07:30 - 10:00 2.50 CLEAN P CLEAN Continue pulling out of the hole laying down 123 joints of 4" HT-40 drill pipe and 21 joints of 4" heavy weight drill pipe. 10:00 - 11 :00 1.00 CLEAN P CLEAN Lay down 9 3-1/2" drill collars and BHA #22. Clean and clear rig floor of unnecessary tools and equipment. 11 :00 - 12:00 1.00 CASE P TIEB1 Rig up torque turn equipment to run 4-1/2" 12.6# 13 Cr-80 NSCT scab liner. 12:00 - 00:00 12.00 CASE P TIEB1 Run 120 joints to 5350' of 4-1/2" 12.6# 13 Cr-80 NSCT scab liner with 6" Unique machine overshot. Placing one 4-1/2" x 5-11/16" free floating centralizer per joint. 3/312006 00:00 - 00:30 0.50 CASE P TIEB1 Ran a total of 134 joints of 4-1/2" 12.6# 13 Cr-80 NSCT scab liner class B to 5462' with 6" Unique machine overshot. Running a total of 1344-1/2" x 5-11/16" free floating centralizers. Make up torque for the 4-112" NSCT scab liner was 4192 foot pounds. 00:30 - 01 :00 0.50 CASE P TIEB1 Change out handling equipment and make up Bakers 7" x 5" C-2 ZXP liner top packer and hanger. 01 :00 - 01 :30 0.50 CASE P TIEB1 Rig down torque turn equipment, Remove long bails from top drive and install short bails. 01 :30 - 02:00 0.50 CASE P TIEB1 Run in the hole with one stand of 4" HT-40 drill pipe and circulate liner volume at 290 gpm 457 psi. Up weight 90K, Slack off weight 80K. 02:00 - 05:00 3.00 CASE P TIEB1 Run in the hole with liner on 4" HT-40 drll pipe. Filling drill pipe every 10 stands run. 05:00 - 06:00 1.00 CASE P TIEB1 MU cement head, cement line and wash up manifold. 06:00 - 07:00 1.00 CASE P TIEB1 Stab over tubing stub at 10177'. Confirm space out and pick up 1 foot. Up weight 180K, Slackoff weight 115K. 07:00 - 08:00 1.00 CEMT P TIEB1 PJSM with all personal involed. Pump 5 bbl fresh water. Printed: 3/6/2006 12:52:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-01 P2-01 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 2/10/2006 Rig Release: 3/4/2006 Rig Number: 7ES Spud Date: End: 3/4/2006 3/3/2006 07:00 - 08:00 1.00 CEMT P TIEB1 Pressure test lines to 4000 psi. Mix and pump 102 bbls 15.8 ppg class G cement. Wash up cement line. Drop dart displace with rig pumps, bumping plug to 4000 psi with 130 bbls 9.8 ppg KCL brine. CIP at 08:00 hours. 08:00 - 09:00 1.00 CEMT P TIEB1 Set packer with 3500 psi. Bleed off pressure and check floats. Release from liner hanger by rotating 10 turns to the right. Pressure up to 1000 psi and pick up to clear tie back receptacle once pressure began to fall circulated 40 bbls @ 6 BPM, slow pumps to 3 BPM. Pick up to expose rotating dog I sub, engage ZXP with 75K Ibs of down weight to set packer, rotated slowly and set down weight on packer to ensure good set. Top of 4-1/2" liner at 4733' Circ bottoms up, observed 4 bbls cement and contaminated brine. 09:00 - 09:30 0.50 CEMT P TIEB1 Rig down and blow down lines. Lay down cement head. 09:30 - 12:00 2.50 CEMT P TIEB1 Pull out of the hole with 4" HT-40 drill pipe. 12:00 - 12:30 0.50 CEMT P TIEB1 Lay down 12 joints of 4" HT-40 drill pipe and C-2 running tool. 12:30 - 13:00 0.50 RUNCO RUNCMP Pull wear ring and make a dummy run with hanger. 13:00 - 14:00 1.00 RUNCO RUNCMP Rig up torque turn equipment. 14:00 - 19:00 5.00 RUNCO RUNCMP Run in the hole with 4-1/2" 12.6# 13 Cr-80 Vam top tubing to 2137'. Make up Halliburtons SSSV. 19:00 - 21 :00 2.00 RUNCMP Rig up Halliburtons spooling unit. 21 :00 - 00:00 3.00 RUNCMP Continue to run in the hole with 4-1/2" 12.6# 13 Cr-80 Vam top tubing to 3504' 3/4/2006 00:00 - 02:00 2.00 RUNCMP Continue to run in the hole with 4-1/2" 12.6# 13 Cr-80 Vam top tubing. Tag top of 4-1/2" liner top, verifying tag up by setting 20K down. Inserting 10' into the top of the 4-1/2" liner top at 4742'. Space out tubing with WLEG 7 ft into liner top. Up weight 80K, Slack off weight 75K. Make up torque on the 4-1/2 Cr-80 Vam Top tubing was 4440 foot pounds. 02:00 - 03:30 1.50 RUNCO RUNCMP Pick up and make up Hanger and landing joint. Run control lines thru hanger and test to 5000 psi for 10 minutes. Land hanger and run in lock down screws. 03:30 - 04:30 1.00 CASE TIEB1 Test 4-1/2" liner top to 3500 psi for 30 minutes. OK 04:30 - 05:30 1.00 RUNCO RUNCMP Reverse circulate inhibited KCL fluid 05:30 - 07:00 1.50 RUNCO RUNCMP Drop 1-7/8" ball and rod with a 1-5/8" fishing neck, allow ball to seat on X nipple. Pressure tubing to 3500 psi to set Baker S 3 type packer, hold pressure for 30 minutes. Bleed tubing pressure down to 2000 psi. Pressure up annulus to 3500 psi for 30 min. Bleed off annulus pressure to 0, then bleed off tubing pressure to O. Pressure up annulus and shear DCK valve at 2500 psi, Continue to pump 2 bbls to verify DCK valve sheared. Pump 2 bbls down the annulus at 98 gpm 425 psi to verify DCK valve sheared 07:00 - 07:30 0.50 RUNCO RUNCMP Pull landing joint and rig down equipment, Dry rod TWC. 07:30 - 08:00 0.50 RUNCO RUNCMP Blow down top drive and kill line back to the mud pits. 08:00 - 11 :00 3.00 BOPSU P RUNCMP Nipple down BOP and double studded adapter flange. 11 :00 - 12:00 1.00 WHSUR P RUNCMP Open rear cellar doors and bring tree and adapter flange in. 12:00 - 14:00 2.00 WHSUR P RUNCMP Terminate control lines to tubing hanger. Nipple up adapter flange and test adapter flange to 5000 psi. 14:00 - 15:00 1.00 WHSUR P RUNCMP Nipple up Tree and test to 5000 psi. 15:00 - 16:00 1.00 WHSUR P RUNCMP Rig up DSM and pull TWC with lubircator. Printed: 3/612006 12:52:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-01 P2-01 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: 2/10/2006 Rig Release: 3/4/2006 Rig Number: 7ES Spud Date: End: 3/4/2006 1.00 WHSUR P 1.00 WHSUR P Rig up Little Red Hot Oil Services and freeze protect well with 70 bbls of diesel. RUNCMP . Allow freeze protect to U-Tube. RUNCMP Rig up DSM and install BPV with lubircator. Test from below to 1000 psi. Remove secondary annulus valve. Install gauges and secure tree. Rig released at 19:00 hours 3/4/06 Printed: 3/6/2006 12:52:05 PM e e Well: Field: API: Permit: P2-01 Rig Workover Prudhoe Bay Unit 50-029-22761-00-00 197 -073 Accept: Spud: Release: Ri: POST RIG WORK 03/12106 MIRU CTU. PERFORM BOP TEST. MU AND RIH WITH BOT 3.7" OD 3-BLADE OPTICUT JUNK MILL. SET DOWN AT 10018' CTMD. WASH DOWN TO 10108'. AT 10108' MOTOR APPEARED TO STOP WORKING. POOH TO INSPECT BHA #1. BHA HAD DISCONNECTED AT DISCONNECT. NOTHING FOUND ON SEAT. MU BHA #2 TO FISH TOOLS IN HOLE. 03/13/06 RIH W/BHA #2 (FISHING TOOLS). RECOVER DISCONNECT, MOTOR AND MILL FROM WELL. MU AND RBIH WITH BHA #3,3.70 3-BLADE MILL. APPEARED TO START MILLING CEMENT AT 10128' CTMD. MILLED TO 10195' AT -24 FPH BEFORE ENCOUNTERING NUMEROUS STALLS. TIME DRILLED TO 10212'. TIME DRILLED SLOWLY AT 10212' WITH 7 STALLS, 5 REQUIRING JAR HITS TO JAR OFF. ON LAST STALL, APPEARED TO DRAG UP HOLE WHILE TRYING TO JAR OFF TO 10190' CTMD. JARRED FREE AFTER 4 HITS, FREE SPIN PRESSURE DOWN 300 PSI, CANNOT STALL MOTOR. 03/14/06 STUCK WITH BHA AT 10190' CTMD. JARRED 4 TIMES BEFORE COMING FREE. LOST 300 PSI FROM FREE SPIN OF MOTOR, AND UNABLE TO INITIATE A STALL. POOH TO INSPECT TOOLS. ON INSPECTION, DISCONNECT WAS SHEARED. LEFT MILL, MOTOR, HALF OF DISCONNECT IN HOLE (16.5'). RIH WITH BHA #4 (FISHING STRING - 3" GS). SO AND LATCH AT 10158' CTMD. AFTER SEVERAL HARD DOWN LICKS, HIT AN UP LICK AND PULLED FREE. RBIH FREELY TO 10160'. POOH. AT SURFACE, ELE. COUNTER AT -45', MECH COUNTER AT -12'. (EXPLAINS WHY LATCH AT 10158'). RECOVERED ALL OF FISH. SEVERAL METAL SCARS ON SIDES OF MILL. LD TOOLS AND CUT 150' OF PIPE. MU AND RIH WITH BHA #5 (3 1/8" VENTURI JB). VACUUM FROM 10100' DOWN TO 10220' WITH 2 PASSES. ON WAY OUT OF HOLE, CT PIN HOLED AT -10160' FROM END OF COIL. 03/15/06 SPOOLING OUT OF HOLE AFTER VENTURI BASKET RUN. LOAD WELL WITH 60:40 METH DOWN BACKSIDE WHILE POOH. WELL FREEZE PROTECTED TO 2000'. AT SURFACE, JUNK BASKET RECOVERED APPROX 1 CUP OF STEEL AND CEMENT MATERIAL. BLOW DOWN CT WITH 20K SCF N2. RIG DOWN CTU AND RETURN TO SHOP TO SWAP CT STRING. 01/18/06 FINISH RIGGING UP AND DRIFT COIL WITH 1.25" BALL. RIH WITH BHA #6 3.125" BURN SHOE AND VENTURI BASKET. TAGGED DOWN AT 10182' WITH BHA. ATTEMPTED TO WORK PAST WITH VARIOUS METHODS WITH NO LUCK. 03/19/06 TAGGED UP AT 10182' CTM WITH BHA #6. UNABLE TO GET DEEPER. PUMPED 120 BBLS OF 1% XS KCL WITH 0.6% SAFELUBE TO COAT CHROME TUBULARS. POOH TO INSPECT TOOLS. RECOVERED ABOUT 8 LBS OF METAL PARTS AND A 2.5" X 7" TUBING DRIFT IN THE BASKET. RIH WITH SAME BHA. DRY TAG AT 10191' CTMD. WORK VENTURI AND BURN SHOE TO 10270' WITH VERY LITTLE MW. TT AT 10,245'. RECOVERED - 1 GALLON OF VARIOUS DEBRIS (METAUFASDRILURUBBER/SAND). LD VENTURI AND RIH WITH SAME BHA AND 3.7" TAPERED JUNK MILL. SET DOWN AT 10166' CTMD, AND 10280' CTMD. ROTATE TO GET DOWN. START FCO FROM 10270'. FIND HARD SAND TOP AT 10332'. CLEANOUT DOWN TO 10750' CTMD USING 1078 BBLS OF 1%XS KCL WITH 0.6% SAFELUBE AND 129 BBLS OF FLOPRO TAKING 12 X 50' BITES AND CHASING TO TUBING TAIL. GLR AT 1.5MM DURING CLEANOUT. CHASED OUT OF HOLE PULLING AT 50% OF PUMP RATE DUE TO CHROME TUBING. 03/20/06 POOH PUMPING 1% XS KCL CHASING SAND TO SURFACE. BULLHEAD 35 BBLS OF 60:40 MEOH TO FREEZE PROTECT WELL. FREEZE PROTECTED FLOWLINE ON WELL #4 WITH 70 BBLS OF 60:40 MEOH THROUGH ASRC TEST SEPERATOR. FREEZE PROTECTED WELL #1 FLOWLINE WITH 11 BBLS OF MEOH. NOTIFIED PAD OPERATOR THAT THE WELL IS TO BE LEFT SHUT IN. WELL TO BE LEFT SHUT-IN FOR 3 DAYS PRIOR TO STATIC SURVEY. NOTE: AREA AT UNIQUE OVERSHOT (10,170' ON SCHEMATIC) MAY NOT BE A SMOOTH TRANSITION. TREE = ? e .~AFETY NOTES: ***CHROME4-1/2" TBG, 4- WELLÞiEAD = CrN P2-01 1/2" SCAB LNR, & 7" CSG*** ACTUA TOR = BAKER C KB. ELEV = 47.15' ""'....... -- BF. ELEV = ¡ i H 1083' H7"TAMPORTCOLLAR I : :¡ KOP- ij! , 1-14-1/2" HES HXO SLV NIP, ID = 3.813" I Max Angle = 41 / 2119' Datum MD = 1046 . Datum TVD = 8800' SS' / ~ GAS LIFT MANDRELS ST MD TVD DEV ìYÆ VLV LA TCH PORT DATE IT' SCAB LNR, 26#, L-80 TCII, ID = 6.276" I 1089' r L 2 4276 4021 41 KBG-2 DCK DCK 0 02/20/06 1 4566 4245 38 KBG-2 DMY BK 0 02/20/06 Minimum ID = 3.725" @ 10231' -f 4630' 1-14-1/2" HES X NIP, ID - 3.813" I OTIS XN NIPPLE I I 1-1 T' x 4-1/2" BKR S-3 A<R, ID = 3.87" I .-I 4698' k2 ....... I -I 4721' H4-1/2" HES x NIP, 10 = 3.813" I I I 1---1 4727' I- T' x 5" BKR ZXP LNR TOP A<R, W / I ~ !i BKR FLEX-LOC LNR HNGR, ID = 4.430" 4-112" TBG, 12.6# 13CRSO VAM TOP, 1-1 4742' I H 4742' H4-1/2"WLEG, ID-3.958" I .0152 bpf, ID = 3.958" t-- 4754' H 5" x 4-1/2" XO, ID = 3.950" I ~ I 9-5/8" CSG, 40#, L-80, 10 = 8.835" H 5473' I ), 17" CSG, 26#, L-80, 10 = 6.276" I 10040' \ I 4-1/2" SCAB LNR, 12.6#. 13CR80 NSCT, 10098' I ~ .0152 bpf, ID = 3.958" ~ I 10149' '-14-1/2" BKR ÆRF PUP (CEMENTER) I R :) 4-1/2" SCAB LNR, 12.6#, L-80 BTC, 10149' I I 10160' I BK.R BALL & SSi\T SUB I .0152 bpf, ID = 3.958" 0 IBT v Ti-II XO, I" " " 92" R /', "~,/ ¡J '),0 10184' ELM HTBG STUB (02/10/06) I ~ --- ~ - 10179' H UNIQUE MACHINE OVERSHOT I 10189' 1-1T' X 4-1/2" BAKERS-3 A<R, 10- 3.875" I . · 10220' H4-1/2" OTIS x NIP, ID = 3.813" I · I 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf , ID = 3.958" I 10245' ~ . I 10231' 1-14-1/2" OTIS XN NIP, 10 - 3.725" I · ÆRFORA TION SUMMARY , 10245' 1-15" TUBING TAIL, WLEG, ID - 3.958" I REF LOG: R.A T EXP ON 05/02/97 [ I 10235' H ELMO TT LOGGED 05/13/97 I ANGLE AT TOP ÆRF: 35 @ 10392' Note: Refer to Production DB for historical perf data [ SIZE SPF INTERV AL Opn/Sqz DATE 2-1/2" 4 10392 - 10412 0 05/18/97 3-3/8" 6 10450 - 10480 0 08/12/97 [ 3-3/8" 6 10564 - 10584 0 08/12/97 3-3/8" 6 10605 - 10625 0 05/06/02 3-3/8" 6 10648 - 10708 0 08/12/97 [] 10750' CTM I-l TOP OF SAND (03/20/06) I I PBTD I 10879' I 7" CSG, 26#, 13-CR, ID = 6.276" I 10958' DATE REV BY COMMENTS DATE REV BY COMMENTS POINT MCINTYRE UNIT 05/06197 ORIGINAL COM PLETION WELL: P2-01 03/06/06 N7ES RWO ÆRMIT No: "1970730 03/20/06 JAF/TLH CMT/FASDRILL SAND REMOVAl API No: 50-029-22761-00 03/22/06 ???/TLH DRLG ORAFTCORRECTIONS SEC 11, T12N, R14E, 3918.04' FEL &3722.9' FNL BP Exploration (Alaska) Re: P2-01 scope change ) 1111' - 0 7 1., ) Subject: Re: P2-01 scope change From: WintonAubert <winton_aubert@admin~state.ak.us> Date: Tue, 31· Jan 2006 12:44:29 -0900 To:"Peltier,Bráhdon"<Brandon.Peltiar@bp.com> Brandon, AOGCC hereby approves changes to your approved P2-01 workover procedure (App. No. 306-027), described below. All other Sundry stipulations apply. Winton Aubert AOGCC 793-1231 5tANNE.It)) ~U\N ~ 1 2008 Peltier, Brandon wrote: Winton The P2-0 1 R WO program will have a scope change that involves cutting a pulling the 7" production casing above the OA down squeeze. New 7" casing will be run and cemented to surface. The remaining well plan and final well design will be unchanged. The original sundry request (306-027) has been approved. During the work-over planning phase for P2-0 I the IAxOA leak was overlooked, therefore a fix was not written into the SOR and resulting work-over operations plan. After the sundry had been submitted and approved, we became aware of the IAxOA leak and determined that the only solution was to replace the existing casing during the course of the work-over operation. The additional operations wil1 be as follows: 1. Run USIT log to evaluate 7" casing corrosion and TOC in OA. 2. Set and test RBP ~ 1000' below casing cut point. 3. Mechanical cut 7", 26 lblft, L-80 casing above OA TOC. Circulate out OA freeze protection with brine. 4. Spear 7" casing. POOH casing to cut. 5. RIH wI back-off tool and back-off 7" casing stub at nearest collar. 6. Run new 7", 26 lblft, L-80, TC-II casing (length TBD from USIT). 7. Install 7" emergency slips and primary pack-off. Land slips and NU stack. 8. Cement new 7" casing back to surface with and Arctic slurry (volume TBD). 9. Lift stack and cut 7" with Wachs cutter. Install new tubing spool and second pack-off. Test new spools and BOP's. 10. RIH with clean-out mill to ES cementer and drill cement. Pressure test 7" casing to 3500 psi for 30 minutes. POOH. 11. Fish RBP. Brandon Peltier BP Exploration (Alaska), Inc. Operations Drilling Engineer GPB Rotary Drilling (907) 564-5912 (Direct) (907) 748-7838 (Mobile) Brandon. Peltier@bp.com 1 of 1 1/31/2006 12:45 PM ) ) FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dave Wesley Senior Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 l q1-01Ó Re: Prudhoe Bay, P2-0 1 Sundry Number: 306-027 SCANNED ,JAN 2{ 5 2006 Dear Mr. Wesley: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, (~///~ :vy¿ Daniel T. Seamount Commissioner r<:.j DATED thi~3 day of January, 2006 Enc!. ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 2 0 2006 APPLICATION FOR SUNDRY APPROV Þdrska Oil & Gas Cons. Commission 20 AAC 25.280 Anchorage W41\- !J'l.:~' 2..o0{p RECE'VED 1. Type of Request: 0 Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Other a Alter Casing a Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Change Approved Program B Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: ./ 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number 197-073 /" 6. API Number: 50- 029-22761-00-00 '--' 99519-6612 47.15' 9. Well Name and Number: PBU P2-01 -- 8. Property Designation: ADL 034622 10. Field I Pool(s): Prudhoe Bay Field I Point Mcintyre Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 10334 /.. 8741 10334 MD TVD Burst Junk (measured): None Collapse 11. Total Depth MD (ft): 10975 Casing Structural Conductor Surface Intermediate Production Liner Total Depth TVD (ft): 9272 Length Size 110' 5438' 20" 9-5/8" 110' 5473' 110' 4957' 5750 3090 10924' 7" 10958' 9258' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): 10392' - 10708' /' 8788' - 9050' Packers and SSSV Type: 7" x 4-1/2" Baker 'S-3' packer Tubing Size: / 4-1/2", 12.6# Tubing Grade: 13Cr Packers and SSSV MD (ft): 10189' r" Tubing MD (ft): 10245' /' 12. Attachments: IBI Description Summary of Proposal o Detailed Operations Program 14. Estimated Date for Commencing Operations: o BOP Sketch 13. Well Class after proposed work: /' o Exploratory IBI Development 0 Service 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Brandon Peltier, 564-5912 Printed N~me. . ve W. esley . _ "1 Title Senior Drilling Engineer , . _ _ ,./ ~ ( / . L - Prepared By Name/Number: Signature ~.;ðy C:,(t?~~ ;:;::r-- Phone 564-5153 Date/¡2:d'/~" Terrie Hubble, 564-4628 Commission Use Only February 10, 2006 / Date: 15. Well Status after proposed work: IBI Oil 0 Gas o WAG 0 GINJ o Plugged DWINJ o Abandoned o WDSPL Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test 0 Mechanical Integrity Test 0 Location Clearance I Sundry Number: óO(g -0&7 Other: Tv; t B 0 f f to 3500 ¡Ok, RBDMS 8Ft .IAN 24 2006 Subsequent Form Required: l (!) - 40 4-. 0ItgInaI Signed By DAN SEAMOUNT Approved By: Form 10-403 Revised 07/2005 COMMISSIONER APPROVED BY THE COMMISSION Date I-;J-~ uP Submit In Duplicate ORIGINAL ) ) Well Status: P2-0 1 is a side well producer in the west -central water flood at Point McIntyre. The well is secured with a sand plug across the perforations and shut-it. The well has a production /' casing leak and a tubing x IA leak. Project: P2-01 is currently completed conventionally with 4-1/2" 13 Cr tubing inside 7" 13 Cr production casing. The tubing will be cut and pulled above the existing packer. A USIT log will be run to determine the extent of the external corrosion and to determine where the top of the scab liner should be located. A packer and plug will be run to that depth to confirm pressure integrity of the production casing above that point. A 4-1/2" scab liner will be stacked over the old packer and run up to a location determined by the US IT log. The liner will be cemented into place and a new 4-1/2" 13 Cr tubing string will be run back in the hole and tested. The plug will be removed from the well bore. The well will be placed on production and tested. Provide AOGCC field inspectors 24-hours notice as required to witness BOP tests. Pre-RWO 1. Check well head seals and lock down screws. 2. Remove SCSSSV and drift tubing. 3. Set plug in tubing tail just below packer. 4. Chemical cut 4-1/2" tubing above packer. 5. Circulate well clean and freeze protect with diesel. 6. Set BPV in tubing hanger 7. Remove well houses and flow lines. Prepare pad for rig. Note: Because of tubing x IA x production casing leak, the mechanical barriers down /. hole (tubing tail plug) cannot be proven. Barriers will consist of a BPV and kill weight fluid. /" RWO 1. MIRU work over rig. Install TWC and test. ND tree and tubing head adapter flange. 2. NU B¡6PE)nd test per BP and AOGCC regulations. Test the BOPE to 250 psi low and 3,3ì~'psi high. Test the annular to 250 psi low and 3500 psi high. Pull the TWC ,- with lubricator. 3. PU landing joint or spear and make-up into the tubing hanger. Pull and lay down the tubing hanger. 4. Pull and lay down the 4-Y2", 12.6Ib/ft, 13-Cr tubing down to the cut @ -10181 ft md. 5. PU wash shoe and 7" casing scraper on DP and Rill to the tubing stub. Reverse circulate hole clean wi seawater. 6. RU Schlumberger E-line and run USIT. The USIT log with be used to make a determination on the extent of external casing damage as well as help pick the proper length of the scab liner. .,/ ') ) 7. Run RTTS on DP. Set ~bove determined top of external casjag-daplage and confirm pressure integri~'1 production casing above damage. Tes4?I~And casing to 3500 psi for 30 minutes. ...,/ 8. Run 4-112", 12.6Ib/ft, 13-Cr scab liner (Length TBD). Run overshot on tubing stub. 9. Fully cement scab liner in place with 15.8 "G" cement (Volume TBD). /'" 10. Set liner hanger and packer. 11. Pressure test casing to 3500 psi for 30 charted minutes. /' 12. Drill out shoe-track. 13. Run 4-Y2", 12.6 #/ft, 13 Chrome Yam Top tubing. Stab tubing into scab liner tie- back. 14. Set the packer. Test the tubing to 3500 psi for 30 minutes. /' 15. ND BOPE and NU adapter flange and tree. Test to 5000 psi. FP IA to -2200'. 16. RDMO. Post-RWO 1. Pull ball and rod from RHC sleeve and pull RHC sleeve. 2. Install SCSSSV. 3. Tie-in flow lines, replace well house, and instrumentation. TREE = \VELLHEA"D = ACTUATOR = Kä.ËLEV = BF. ELEV = ROFt;······"'"'···-·'·.. . Max Angle; 'Datum"MD';; , ... ................,....""",,,,,,,,,......,,,,,,.,,,,...,,,,,. Datum TVD = ? crvv BAKER C ) P2 -01 ')AFETY NOTES: ***CHROME 4-1/2" TBG & I" CSG*** 2498' .""" ,,,,...,,,..,,,,,,,,,,,..,..,,,.,, ,4 ~ ~.~~g1' 10464' .. .,,, .""""....."..""""""",,'" 8800' SS' e 2199' 1- 4-1/2" CAMCO BAL-O SVLN, WRDP-2 (HPS-371), ID = 3.81" 9-5/8" CSG, 40#, L-80, ID = 8.835" l-i 5473' ~ ~ Minimum ID = 3.725" @ 10231' OTIS XN NIPPLE L GAS LIFT MANDRELS TYPE = KBG-2-LS (9CR) ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 4745 4388 38 SEE ABOVE DMY INT 0 10/08/04 2 6245 5550 40 SEE ABOVE DOME INT 16 07/27/05 3 7886 6820 40 SEE ABOVE SO INT 24 07/27/05 4 8534 7323 39 SEE ABOVE DMY INT 0 10/08/04 5 9761 8280 38 SEE ABOVE DMY INT 0 05/01/97 6 10161 8600 36 SEE A BOV E DMY INT 0 12/06/97 7" CSG, 26#, L-80, ID = 6.276" l-i 10040' I \,-~ 8: ~ 10189' l-i 7" x 4-1/2" BAKER S-3 PKR, ID = 3.875" 1 10220' l-i 4-1/2" OTIS X NIP, ID = 3.813" 1 10231' l-f 4-1/2" OTIS XN NIP, ID = 3.725" 1 10245' l-i 5" TUBING TAIL, WLEG, ID = 3.958" 1 10235' l-i ELMD TT LOGGED 05/13/97 I 10334' l-i TOP OF SAND 1 4-1/2" TBG, 12.6#, 13-CR, -i 10245' 1 .0152 bpf , ID = 3.958" PERFORA TION SUMMA RY REF LOG: PLAT EXP ON 05/02/97 ANGLE AT TOP PERF: 35 @ 10392' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-1/2" 4 10392 - 10412 0 05/18/97 3-3/8" 6 10450 - 10480 0 08/12/97 3-3/8" 6 10564 - 10584 0 08/12/97 3-3/8" 6 10605 - 10625 0 05/06/02 3-3/8" 6 10648 - 10708 0 08/12/97 A. 1 .I. I PBID l-i 10879' ~ I 7" CSG, 26#, 13-CR, ID = 6.276" l-i 10958' DATE 05/06/97 08/12/01 05/08/02 04/30/03 06/20/05 07/03/05 REV BY COMMENTS ORIGINAL COM PLErION RN/TP CORRECTIONS DDW/KK A DÆRFS DA V /KK PULL IBP & TIP IN XN SRB/PJC SA NDBA CK DTRlTLH GL V C/O DA TE REV BY COMMENTS 07/25/05 RPl-VPJC WArvrn. CANCB..LED 07/27/05 1WS/PJC GLV C/O 10/13/05 ITLH SA FETY & GL V CORRECTION POINT MCINTY RE UNIT WB..L: P2-01 PERMIT No: "1970730 API No: 50-029-22761-00 see 11, T12N, R14E. 3918.04' FEL & 3722.9' FNL BP Exploration (Alaska) TREE = ? f'" _ WELLHEAD = CrN ACTUATOR = BAKER C kS:ELEV"'; '" "" """47.'1§ BF. ELEV = KOP = ' m ""'''''''''''2'498; ,Max Angle = 41 @ 420f ÖalUrÏiMtf;' ,'., ," ''''0" ''''1Õ464ï .......".."......."..",,,,,,,,,,..,,...,,..,,,, """"" Datum lVD = 8800' SS' )P2-01 Proposed ) .......--' '" 9-5/8" CSG, 40#, L-80, ID = 8.835" l-i 5473' r.J Minimum IC = 3.725" @ 10231' OTIS XN NIPPLE Fully cemented 4.5", 12.6#/ft, 13Cr-80 scab liner with ZXP liner top packer -500' above 7" casing damage 7" CSG, 26#. L-80, ID = 6.276" l-i 10040' 1 4-1/2" TBG, 12.6#, 13-CR, -i 10245' 1 .0152 bpf , ID = 3.958" PERFORA TION SUMMARY REF LOG: PLAT EXP ON 05/02/97 A NGLE AT TOP ÆRF: 35 @ 10392' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-1/2" 4 10392 - 10412 0 05/18/97 3-3/8" 6 10450 - 10480 0 08/12/97 3-3/8" 6 10564 - 10584 0 08/12/97 3-3/8" 6 10605 - 10625 0 05/06/02 3-3/8" 6 10648 - 10708 0 08/12/97 I PBTD l-i 10879' 17" CSG, 26#, 13-CR, ID = 6.276" 1-1 10958' If) I -2100' 1- 4-1/2" HES HXO, ID = 3.813" .. GAS LIFT MANDRELS a ST MD TYÆ VLV 1 4.5" x 1" 90' DCK L 2 4.5" x 1" 90' DMY 3 4.5" x 1" 90' DMY 4 4.5" x 1" 90' DMY , ~ I H 7" X 4-1/2" BAKER 8-3 PKR, Ð ~ 3.875" J ~4.5.' 12.6#/ft, 13Cr-80 Tubing. 8-3 Packer will have "X" landing nipples on either side of it '. r 1 ' :g :8--- ~ t . 10189' 10220' 10231 ' 7" X 4-1/2" BAKER S-3 PKR, ID = 3.875" 4-1/2" OTIS X NIP, ID = 3.813" 1 4-1/2" OTIS XN NIP, ID = 3.725" 1 10245' l-i 5" TUBING TAIL, WLEG, ID = 3.958" 1 10235' l-i ELMD TT LOGGED 05/13/97 1 I I I ~ DA TE REV BY COMMENTS 07/25/05 RA-ilPJC WAIVER CANC8..LED 07/27/05 IWS/PJC GL V C/O 10/13/05 ITLH SAFE1Y & GLV CORRECTION POINT MCINTY RE UNIT W8..L: P2-01 PERMIT No: "1970730 API No: 50-029-22761-00 SEC 11, T12N, R14E, 3918.04' FEL & 3722.9' FNL DATE 05/06/97 08/12/01 05/08/02 04/30/03 06/20/05 07/03/05 REV BY COMMENTS ORIGINAL COM PLETION RNiTP CORRECTIONS DDW/KK ADÆRFS DA V /KK PULL IBP & TIP IN XN SRB/PJC SANDBACK DTR/TLH GL V C/O BP Exploration (Alaska) Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Z-01 Y-13 L2-14B Y -08A X-36 X-30 S-29A P2-01 tct1,01?> OS 12-08C D.S. 09-28A P2-34 Q-05A NK-09 NK-38A BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Job# 11087166 N/A 10670029 11047356 11075908 10662973 11087187 11072880 11087208 11094347 N/A 11087203 11062632 11075902 CiÎ'AMNE!r)· H\ N 2 () 2.006 ~~~V"\5'9~ "J_ t!~~ ~ir-!.l1 ,~, - Log Description LDL PRODUCTION LOG PROD PROFILE MEMORY/SENSA LDL MEMORY INJECTION PROFILE GLS INJECTION PROFILE LDL SBHP SURVEY LDL INJECTION PROFILE SBHP SURVEY PROD PROFILE WIDEFT MEMORY PROD PROFILE 01/04/06 NO. 3642 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne pt. Date BL Color CD 08/05/05 1 05/01/05 1 08/20/04 1 10/15/05 1 08/17/05 1 12/02/03 1 10/04/05 1 - 08/06/05 1 12/24/05 1 12/28/05 1 06/02/05 1 11/27/05 1 07/01/05 1 07/27/05 1 -~ -~ Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~rf'(~ Received l:;llðlt ~ 'KJV h P2-01 (PTD #1970730) Internal Waiver Cancellation ) ) Subject: P2-01 (PTD #1970730) Internal Waiver Cancellation From: "Dube, Anna T" <Anna.Dube@BP.com> Date: Sun, 24 Jul 2005 17:07:01 -0800 To: "AOGCC - Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us>. jim _regg@admin.state.ak.us CC: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>, "Holt, Ryan P (VECO)" <Ryan.Holt@BP.com> Winton and Jim, The internal BP waiver for IAxOA communication on well P2-01 (PTD #1970730) has been cancelled. The well has developed a production casing leak and is no longer operable on gas lift. It has been secured with a sand plug and is classified as a Trouble well. The well is currently being evaluated for ai/'" RWO. Please let me know if you have any questions. Thank you, }1.nna (})u6e Well Integrity Coordinator GPB Wells Group SC/\NNEK) AUG 0 9 2005 Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 :Sb(L ,IZ7/0Ç 1 of 1 7/27/2005 9:26 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _X ADD PERFS Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 5219' FNL, 4305' FEL, Sec. 11, T12N, R14E, UM At top of productive interval 3814' FNL, 3604' FEL, Sec. 10, T12N, R14E, UM At effective depth 3740' FNL, 3866' FEL, Sec. 10, T12N, R14E, UM At total depth 3722' FNL, 3918' FEL, Sec. 10, T12N, R14E, UM 5. Type of Well: Development _X Explorato~ Stratigraphic__ Service__ (asp's 681210, 5998633) ¢sp~ 676595, 599993~ (asp's 676331, 5999998) (asp's 676279, 6000012) 6. Datum elevation (DF or KB feet) RKB 47 feet 7. Unit or Property name Point Mclntyre Unit 8. Well number P2-01 9. Permitnumber/approvalnumber 197-073 10. APInumber 50-029-22761-00 11. Field / Pool Point Mclntyre Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 5439' Production 10924' 10975 feet Plugs (measured) 9272 feet 10879 feet Junk (measured) 9192 feet Size Cemented Measured Depth True Vertical Depth 20" Driven 114' 114' 9-5/8" 1590 sx Coldset III, 422 5473' 4957' sx Class 'G' 7" 294 sx Class 'G' 10958' 9258' Perforation depth: measured Open Perfs 10392'-10412', 10450'-10480', 10564'-10584', 10605'-10625', 10648'-10708' truevertical Open Peds 8788'-8805',8836'-8860',8930'-8946',8964'-8981',9000'-9050' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 4-1/2", 12.6#, 13-CR TBG @ 10235'. 7" x 4-1/2" Baker S-3 Packer @ 10189'. 4-1/2" Camco BaI-O @ 2199'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Well Shut-In Subsequent to operation 05/08/2002 OiI-Bbl Representative Daily Average Production or Iniection Data Gas-Mcf Water-Bbl 134 364 5398 Casing Pressure Tubing Pressure 892 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~'~t~~J~.''2 Title: Technical Assistant DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · Date May 09, 2002 Prepared by DeWa)/ne R. Schnorr 564-5174 SUBMIT IN DUPLICATE 04/24/2002 O5/O6/2OO2 P2-01 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PERFORATING: DRIFT/TAG PERFORATING: PERFORATING 04/24/02 05/O6/O2 EVENT SUMMARY PULL CAMCO WRDP-2 Cf HBS-773(NEEDLE VALVES BLOCKED IN @ THE TREE & PANEL. DRIFT W/3 3/8 DG TO 10,777' CORRECTED (HARD BOTTOM). NOTIFY PAD OP. OF WELL STATUS, LEFT WELL SHUT IN. RIH W/3.375 20' HSD 3406 PJ 6 SPF HMX PERF GUN. TIE INTO SLB PERF RECORD DATED 18-MAY-2002 AND PERF 10605-10625. GOOD SHOT INDICATION. POOH. NOTIFY PAD OPERATOR KNOW THAT WELL LEFT SHUT IN. WILL BE PUT INTO FLOWING STATUS ON NIGHT SHIFT. FLUIDS PUMPED BBLS 2 DIESEL FOR PRESSURE TESTING SURFACE PRESSURE CONTROL EQUIP 2 TOTAL 05/06/2002 ADD PERFS THE FOLLOWING INTERVAL WAS PERFORATED USING THE 3-3/8" POWER JET, LOADED 6 SPF, 60 DEGREES PHASING, RANDOM ORIENTATION. 10605'-10625' Page I oN OR BEFORE W C:LO~.~FILM.DOC STATE OF ALASKA ALASK,~'~:~IL AND GAS CONSERVATION COMMIE -)N REPOR, OF SUNDRY WELL OPERATI~JNS · Operations performed: Operation shutdown __ Stimulate _~ Plugging ~:~ Pull tubing __ Alter casing __ Repair well __ Perforate ~ Other __ Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 Location of well at surface "5219' FNL, 4305' FEL, Sec. 11, T12N, R14E" At top of production interval At effective depth At total depth "3722' FNL, 3918' FEL, Sec. 10, T12N, 1114E" 12. Present well condition summary Total Depth: measured: true vertical: Effective Depth: measured: true vertical: Casing Length Conductor 80' Surface 5473' Intermediate 10040' Liner Size 20" 9 5/8" 11 5. Type of Well: Development _~ Exploratory '__ Stratigraphic __ Service __ Datum elevation (DF or KB) 47.15 feet 7. Unit or Property name PQINT MCINTYRE UNIT 8. Well number P2-01 9. Permit number/approval number 10. APl number 500292276100 11. Field/Pool Point Mclntyre 10975 feet Plugs (measured) 9272 feet 10879 feet 9192 feet Cemented Driven Junk (measured) 1590 SX Coldset III & 422 sx Class G 294 sx Class G None. None. Measured depth True vertical depth 125' 125' 5473' 10040' 4946' Perforation depth: measured 10392-10412', 10450-10480', 10564-10584', 10648-10708' true vertical 8741-8757', 8788-8813', 8882-8899', 8952-9002' Tubing (size, grade, and measured depth) 4 1/2 in. 12.6# 13CR @ 0-10245' MD, Packers and SSSV (type and measured depth) 3 7/8 X 6 2/7 PKR @ 10189' MD, 3 4/5 x 4 1/2 SSSV @ 2199' MD 13. stimulation or cement squeeze summary Intervals treated (measured) Please refer to the attached Treatment description including volumes used and final pressure JUL 22 Alaska 0il & Gas Cu~;:~. ^nch0rage Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation n/a n/a n/a Subsequent to operation 4147 3908 361 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil~x Gas __Suspended Date Tubing Pressure n/a 9O8 17., here~ th~.~e f~.pg is true and correct to the best of my knowledge. S igned,~~'''/'"'~ Title Service Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE P2-01 Data Frac 6/29/97 1 RU and RU back side. Held pre-job safety meeting Placed 4360# of 13,640# pumped (32%). Average rate if 20 BPM at 5400 psi. Screened out w/8# 16/20 at perfs. Estimated sand top is at 9595' (817' Fill). 3 Fish" 1 treesaver cups (4"x 2') 4 RDMO P2-01 Perforate 8/11/97 1 RU service company. Held pre-job safety meeting. 2 RIH with CCL/20', 3.375" HSD Perf Gun 3 Tie into CET, 13-May-97. Shot gun at 10698-10708' MD. Good fire; POOH 4 RD for night 8/12/97 1 2 3 4 5 6 7 8 9 10 11 12 RU service company. Held pre-job safety meeting. RIH with CCL/20', 3.375" HSD Perf Gun Tie into CET, 13-May-97. Shot gun at 10668-10688' MD. Good fire; POOH RIH with CCL/20', 3.375" HSD Perf Gun Shot gun at 10648-10668. RIH with CCL/20', 3.375" Shot gun at 10564-10584' RIH with CCL/20', 3.375" Shot gun at 10460-10480' RIH with CCL/20', 3.375" Shot gun at 10450-10460' RDMO Good fire; POOH HSD Perf Gun MD. Good fire; POOH HSD Perf Gun MD. Good fire; POOH HSD Perf Gun MD. Good fire; POOH P2-01 OA Down Squeeze 10/11/98 I RU service company. Held pre-job safety meeting. 2 Pumped 31 bbls Arctic Set Cement, 15.7 ppg 1/4 PPB cellophane flakes; first 5 bbls with 20 PPB aggregate cement 3 Flushed with 110 bbls of Crude then 5 bbls Diesel. 4 Charged IA with a/I gas to 1500 psi. Bled to 750 psi, OA stable at 1250 psi 5 RD and released service company. AOGCC Individual Well Geological Materials Inventory PERMIT DATA T DATA PLUS RUN RECVD D -- Page: 1 Date: 05/24/99 97-072 97-072 97-072 97-072 MWD SRVY ~SPERRY 9998-11818 06/19/97 / NPG-TVD ,~"689-8701 FINAL 08/27/97 8088 ~_p.~S'PERRY GR/ROP 3 08/27/97 10-407 ~OMPLETION DATE DAZLY WELL OPS R @ .,. ~,Y @ 71 I¢1'17/ Are dry ditch samples required? yes ~.And received? yes.~'~"~ Was the well cored? yes ~¢-_~malysis & description received? year-no. Are well tests required? yes ~' Received? yem-~no~ ...... Well is in compliance COMMENTS Initial BOX PERMIT DATA 97-073 97-073 8041 97-073 BHC/SL 97-073 BHP 97-073 CN/LDT 97-073 AIT 97-073 SSTVD 97-073 DGR/MD 97-073 DGR-TVD 97-073 8055 97-073 CBL 97-073 CET 97-073 PROD-SPIN/TEM/ 97-073 MWD SRVY AOGCC Individual Well Geological Materials Inventory T DATA PLUS ..................... MWD SRVY 0~~.-10974. ~/~PERRY MPT/GR/ROP ~90-10926 A~'~599-10956 ~-g~99-10956 .~590-10974 ~9O-lO974 j~-s~541-10975 5011-9272 ~SCHLUM PEX/BHC ~'~0100-10842 ~0100-10842 ~F~PRES 10300-10750 ~SPERRY 0-10974. Page: 1 Date: 05/24/99 RUN RECVD o6/~z/97 4 07/30/97 FINAL 07/25/97 FINAL 07/25/97 FINAL 07/25/97 FINAL 07/25/97 FINAL 07/25/97 FINAL 08/06/97 FINAL 08/06/97 1 07/25/97 FINAL 08/22/97 FINAL 08/22/97 FINAL 11/05/97 08/28/97 10-407 m'C0MPLET¢ON DA?E ~¥~ /g~ Are dry ditch samples required? yes ~d received? Was the well cored? yes °m~_;~alysis & description received? Are well tests required? yes ~z~_~_Received? Well is in compliance COMMENTS Initial T D BOX Well-P2-01 ffKB 2199 - 2200 - 4745 - 4746 - 6245 - 6246 - 7886 - 7887 - SSSVLN -- OA SQUEEZE PKR -- NIP -- NIP -- Perf - Perf -- Perf - Perf -- GPMA WEB Date: 4/12/99 APl: 500292276100 SSSV Type: CAT I - SSSV Annular Fluid: DIESEL/C Reference Plat Exp Log: Last Tag: 10800 SLM-CORR Last Tag Date: 9/12/97 Well Type: PROD Orig Compltn: 5~6~97 Last W/O: Ref Log Date: 5~2~97 TD: 10974 ftKB Angle @ TS: deg @ Angle @ TD: 34 deg @ 10975 Rev Reason: RAN WRDP Last Update: 12/31/98 Max Hole 41 deg @ 4201 Anqle: Safe, Notes : : Date Note 5/5/97 Minimum ID: 3.725" OTIS XN NIPPLE @ 10231' MD GeneratNotes :r: :' Date Note 5/5/97 Tubing Hanger: 4 1/2" CIW @ 31' MD 5/5/97 Well Status: ACTIVE Top Of Fluid Depth @ 9250 Last Tag Depth (~ 10975 Other:(Plugs~ equiP,i etc~):- JEWELRY Depth TVD Type Description ID 2199 2197 SSSVLN 4-1/2" CAMCO BAL-O SVLN, ID=3.812"- (WRDP RAN 12/27/98) 3.812 10189 8623 PKR BAKER S-3, 7"X 4-1/2" PACKER, ID=3.875" 3.875 10220 8648 NIP OTIS X NIPPLE, ID=3.813" 3.813 10231 8657 NIP OTIS XN NIPPLE, ID=3.725" 3.725 10245 8668 TT TUBING TAIL, WLEG 10235' ELMD 4.000 casing Strings ~ AIl: : Size Weight Grade Top Btm Feet Description 9.625 40.00 L-80 0 5473 5473 SURFACE CASING 7.000 26.00 L-80 0 10040 10040 PROD. CASING 7.000 26.00 13CR 10040 10958 918 PROD. CASING :Tubing:Strings, All: Size Weight Grade Top Btm Feet Description 4.500 12.60 13CR 0 10245 10245 TUBING Gas: Lift MandrelsNalves Stn MD TVD Man Man VMfr VType Mfr Type 1 4745 4388 CAMCO KBG-2-LS CA GLV (9CR) 2 6245 5550 CAMCO KBG-2-LS CA GLV (9OR) 3 7886 6820 CAMCO KBG-2-LS CA DV (9CR) 4 8534 7323 CAMCO KBG-2-LS CA Odfice (9CR) 5 9761 8280 CAMCO KBG-2-LS CA DV (9CR) 6 10161 8600 CAMCO KBG-2-LS CA DV (9CR) P~rforati0h$ summa~: i: V OD Latch Port TRO Date VIv Run Comment 1.0 TEGR~0.250 0 11/6/98 GLM 1.0 TEGR~0.250 0 11/7/98 GLM 1.0 TEGR~0.000 0 5/1/97 GLM 1.0 TEGR~0.313 0 11/6/98 GLM 1.0 TEGR~0.000 0 5/1/97 GLM 1.0 TEGP~0.000 0 12/6/97 GLM Interval TVD 10392- 8788-8805 10412 10450- 8836-8860 10480 10564- 8930-8946 10584 10648- 9000-9050 10708 Zone Status FeetSPF Date Type Comment 20 4 5/18/97 IPERF 2-1/2" GUNS - ROPE perforated, Frac'd 6/29/97 30 6 8/12/97 APERF 3-3/8" GUNS - 6 SPF 20 6 8/12/97 APERF 3-3/8" GUNS - 6 SPF 60 6 8/12/97 APERF 3-3/8" GUNS - 6 SPF Stimulations &Treatments Interval Date Type 4473- 5473 10/11/98 OA DOWN-SQUEEZE Comment 5 BBL AGGREATE FOLLOWED BY 26 BBL NEAT GeoQuest 500 W. International Airport Road Anchorage, AK 99518-i199 ATTN: Sherrie NO. 11520 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Greater Point Mclntyre Area 1 1/3/97 Floppy Well Job # Log Description Date BL RF Sepia Disk P1-01' I~tC--- INJECTION PROFILE 970925 I 1 P1-01 ~t/ INJECTION PROFILE 97091 3 I 1 , , , P 1-6 · ~ (p, I~'"i PRODUCTION PROFILE 971 003 I 1 P1-11 · PRODUCTION PROFILE W/DEFT 971 01 2 1 1 P 1 - 12 ° PRODUCTION PROFILE W/DEFT 97081 1 I 1 P 1-14 I),. [ C~ INJECTION PROFILE 970926 I 1 P 1-21 I. AI ~ INJECTION PROFILE 97 092 6 I 1 P2-01 , c~"l' O"[~ PRODUCTION PROFILE 97091 4 I 1 P 2-16 L~ [(~ INJECTION PROFILE 97 0801 I 1 P 2-18 ~ PRODUCTION PROFILE W/DEFT 970 927 I 1 P2-19 . OI"J 'C)'-/~ PRODUCTION PROFILE DEFTIMAGES 971 004 I 1 P2-19 - '4,,' PRODUCTION PROFILE 971 004 I 1 P2-28 UtC- INJECTION PROFILE 971 01 0 1 1 ~P 2-31 · PRODUCTION LOG 970 804 I 1 P2-50, DEFT IMAGES 971 005 I 1 P 2- 50 · PRODUCTION PROFILE 971 005 I 1 P 2- 54, PRODUCTION PROFILE 97081 9 I 1 P 2- 57, PRODUCTION PROFILE 970911 I 1 P2'58' ( ~. PRODUCTION PROFILE W/DEFT 971010 I 1 3'053 1. 0'/3 s t.o'Sb ~o.oo~ DATE: ^" .. v. Nuv 5 !qq7 Alaska Oit & Gas C, ons. Anchorage SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 0 I::! I I--I-- I IM C1 SEI:I~/I C E S WEI,I, LOG TRANSM1TFAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - D.S. 18-15B, September 17, 1997 AK-MW-70146 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Ylm Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-21755-02. Note: This data is replacement data for well (18-1515) sent August 27, 1997. Only the Digital data needs replacing. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company u iNAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 97-73 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22761 4. Location of well at surface ......................... 9. Unit or Lease Name .... ~ ~.~: 0,,~ i . '_ Point Mclntyre 58' NSL, 4304' WEL, SEC. 11 T12N, R14E ~ "'~'~'~ -'~' ~'' At top of productive interval i.~/.~_ - .~.~_~.~.i .. , 10. Well Number 1417'NSL, 3516'WEL, SEC. 10, T12N, R14E i "~ ~ i~ P2-01 At total depth 11. Field and Pool 1533' NSL, 3894' WEL, SEC. 10, T12N, R14E i ~--_ ~ ................. Point Mclntyre 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and ~ Plan RTE = 45.4'I ADL 034622 12. Date Spudded4_23_97 I 13' Date T'D"~"Reached t 14' Date C°mp" Susp" °r Aband'll 5' Water depth' if °fish°re 116' N°' °f C°mpleti°ns5-2-97 5-6-97 N/A MSLI One 10975' 9272' FTI 10889' 9201' FTI []Yes I~No 2204' MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD,GR,Res,Den,Neut 23. OASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO-Iq-OM SIZE CEMENTING RECORD AMOUNT PULLED 20" 133# H40 Surf 110' 30" Driven 9-5/8" 40# L-80 35' 5473' 12-1/4" 1590 sx Coldset III, 422 sx 'G' 7" 26# L-80 34' 10040' 8-1/2" 305 sX Class 'G' 7" 29# 13CR 10040' 10958' 8-1/2" ,,. 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2 1/2" Gun Diameter, 4 spf 3 3/8" Gun Diameter, 6 spf 4 1/2" 12.6# 13 Cr 10245' 10193' MD TVD MD TVD 10392-10412 8789-8805 10450-10480 8836-8861 10564-10584 8930-8947 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10648-10708 9000-9050 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 160 bbls diesel -~; 27. '" .... PRODUCTION TEST Date First Production I Meth°d of Operation (Flowing, gas lift, etc.) 8/13/97I Gas Lift Date of Test Hours Tested PRODUCTION FOR IOIL-BBL GAS-MCF WATER-BBL CHOKE SiZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED iOIL-BBL ;GAS-MCF WATER-BBL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE I 28. CORE DATA Brief description of lithology, porosity, fraCtures, apparent dips and presence of oil, gas or water. Submit core chips. A.L]G 2 ~'? 1997 ~1-8~1.~ Cji & Gas Cons, ~chorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Zone UC3 10392 8789 Zone UC1 10450 8836 Zone UB1 10564 8930 Zone UA1 10648 9000 31. List of Attachments Summary of Daily Drilling Reports, Surveys, Leak Off Test Data 32. I hereby certify that th .~~r~s t(,~e~t to the best of my knowledgeSigned ~;;~/~_~'/.~ ~ Steve Shultz . Title Senior Drilling Engineer Date P2-01 97-73 Prepared By Name~Number: Kathy Carnnpoarnor, 564-5122 Well Number Permit No, / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM §.' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Performance Enquiry Report Operator ARCO Date 00:36, 28 Aug 97 Page 1 The analysis is from - 20:45, 27 Apr 97 - to - 20:45, 27 Apr 97 Programs in Result Table: P2-01 Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) P2-01 Event 20:45, 27 Apr 97 20:45, 27 Apr 97 0 hr 0 min Obtained leak off 13.500 Hole Size MDR 8-1/2 WELL LOG TRANSM~T~ To: State of Alaska August 27, 1997 Alaska Oil and Gas Conservation Comm. Atm.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs D.S. 18-15B, AK-MW-70146 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 D.S. 18-15B: 2" x 5" MD Gamma Ray Logs: 50-029-21755-02 2" x 5" TVD Gamma Ray Logs: 50-029-21755-02 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia RECEIVED AUG 2 7 1997 Aia~a 0il & Gas 0ohs. c.,ommi,~-~ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9¢7) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company Facility Date/Time 22 Apr 97 23 Apr 97 24 Apr 97 25 Apr 97 26 Apr 97 27 Apr 97 Pt Mac 2 Progress Report Well P2-01 Rig Doyon 14 13:30-15:00 15:00-15:30 15:30-18:00 18:00-19:30 19:30-20:30 20:30-23:00 23:00-23:30 23:30-00:30 00:30-06:00 06:00-23:30 23:30-00:00 00:00-01:30 01:30-03:30 03:30-04:30 04:30-06:00 06:00-06:00 06:00-14:30 14:30-15:30 15:30-18:15 18:15-21:00 21:00-22:30 22:30-01:00 01:00-02:00 02:00-02:30 02:30-03:00 03:00-04:00 04:00-04:15 04:15-06:00 06:00-11:00 11:00-12:30 12:30-12:45 12:45-14:30 14:30-15:30 15:30-17:30 17:30-18:30 18:30-19:00 19:00-20:30 20:30-22:00 22:00-02:00 02:00-06:00 06:00-06:30 06:30-08:30 08:30-09:00 09:00-10:00 10:00-12:30 12:30-14:00 14:00-15:00 15:00-15:30 15:30-16:00 16:00-18:30 18:30-19:15 19:15-20:45 20:45-21:00 21:00-22:00 Duration 1-1/2 hr 1/2 hr 2-1/2 hr 1-1/2 hr lhr 2-1/2 hr 1/2 hr lhr 5-1/2 hr 17-1/2 hr 1/2 hr 1-1/2 hr 2hr lhr 1-1/2 hr 24 hr 8-1/2 hr lhr 2-3/4 hr 2-3/4 hr 1-1/2 hr 2-1/2 hr lhr 1/2 hr 1/2 hr lhr 1/4 hr 1-3/4 hr 5hr 1-1/2 hr 1/4 hr 1-3/4 hr lhr 2hr lhr 1/2 hr 1-1/2 hr 1-1/2 hr 4hr 4hr 1/2 hr 2hr 1/2 hr lhr 2-1/2 hr 1-1/2 hr lhr 1/2 hr 1/2 hr 2-1/2 hr 3/4 hr 1-1/2 hr 1/4 hr lhr Activity Rig moved 100.00 % Rigged up Drillfloor / Derrick Rigged up Flowline Made up BHA no. 1 Held safety meeting Fill pits with Water based mud Washed to 85.00 ft Made up BHA no. 1 Drilled to 591.00 ft Drilled to 2452.00 ft Circulated at 2452.00 ft Pulled out of hole to 0.00 ft Downloaded MWD tool R.I.H. to 2452.00 ft Drilled to 2578.00 ft Drilled to 5041.00 ft Drilled to 5483.00 ft Circulated at 5483.00 ft Pulled out of hole to 1800.00 ft R.I.H. to 5483.00 fit Circulated at 5483.00 ft Pulled out of hole to 1084.00 ft Pulled BHA Downloaded MWD tool Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Casing to 1189.00 ft (9-5/8in OD) Ran Casing to 5473.00 ft (9-5/8in OD) Circulated at 5473.00 ft Held safety meeting Mixed and pumped slurry - 327.000 bbl Displaced slurry - 408.000 bbl Circulated at 2016.00 ft Mixed and pumped slurry - 376.000 bbl Displaced slurry - 153.000 bbl Rigged down Casing handling equipment Rigged down Annular preventor Rigged up BOP stack Tested BOP stack Installed Bore protector Made up BHA no. 2 R.I.H. to 2014.00 fit Serviced Block line Drilled installed equipment - DV collar R.I.H. to 5383.00 fit Circulated at 5383.00 ft Tested Casing - Via string Held drill (Kick (well kill)) Drilled cement to 5503.00 ft Circulated at 5503.00 ft Performed formation integrity test Drilled to 5541.00 ft Circulated at 5541.00 ft Page Date 1 27 August 97 Progress Report Facility Pt Mac 2 Well P2-0I Page 2 Rig Doyon 14 Date 27 August 97 Date/Time 22:00-00:00 28 Apr 97 00:00-00:30 00:30-01:00 01:00-02:00 02:00-04:30 04:30-06:00 06:00-06:00 29 Apr 97 06:00-06:30 06:30-07:00 07:00-08:00 08:00-09:00 09:00-06:00 30 Apr 97 06:00-22:30 22:30-23:30 23:30-00:00 01 May 97 00:00-00:15 00:15-01:00 01:00-06:00 06:00-19:30 19:30-20:30 20:30-22:00 22:00-22:30 22:30-00:00 02 May 97 00:00-00:15 00:15-00:30 00:30-04:30 04:30-06:00 06:00-06:15 06:15-06:30 06:30-09:00 09:00-12:00 12:00-12:30 12:30-14:00 14:00-15:00 15:00-16:30 16:30-19:00 19:00-22:00 22:00-22:15 22:15-06:00 03 May 97 06:00-06:30 06:30-07:30 07:30-07:45 07:45-09:00 09:00-23:00 23:00-00:30 04 May 97 00:30-00:45 00:45-01:15 01:15-01:30 01:30-02:00 02:00-02:30 02:30-03:00 03:00-03:45 03:45-04:00 04:00-05:30 Duration 2hr 1/2 hr 1/2hr lhr 2-1/2 hr 1-1/2 hr 24 hr 1/2hr 1/2 hr lhr lhr 21 hr 16-1/2 hr lhr 1/2 hr 1/4 hr 3/4 hr 5hr 13-1/2 hr lhr 1-1/2 hr 1/2hr 1-1/2 hr 1/4 hr 1/4 hr 4hr 1-1/2 hr 1/4 hr 1/4 hr 2-1/2 hr 3hr 1/2 hr 1-1/2 hr lhr 1-1/2 hr 2-1/2 hr 3hr 1/4 hr 7-3/4 hr 1/2 hr lhr 1/4 hr 1-1/4 hr 14hr 1-1/2 hr 1/4 hr 1/2 hr 1/4 hr 1/2 hr 1/2 hr 1/2 hr 3/4 hr 1/4 hr 1-1/2 hr Activity Pulled out of hole to 181.00 ft Pulled BHA Downloaded MWD tool Made up BHA no. 3 R.I.H. to 5541.00 ft Drilled to 5603.00 ft Drilled to 7446.00 ft Drilled to 7509.00 ft Circulated at 7509.00 ft Pulled out of hole to 5473.00 ft R.I.H. to 7509.00 ft Drilled to 8723.00 ft Drilled to 9858.00 ft Circulated at 9868.00 ft Rest hole at 9868.00 ft Held safety meeting Circulated at 9868.00 ft Drilled to 10225.00 ft Drilled to 10975.00 ft (cont...) Circulated at 10975.00 ft Pulled out of hole to 9150.00 ft R.I.H. to 10975.00 ft Circulated at 10975.00 ft Took EMS survey at 10975.00 ft Flow check Pulled out of hole to 210.00 ft Pulled BHA Retrieved B ore protector Installed Bore protector Rigged up sub-surface equipment - Downhole measurement tools Conducted electric cable operations Rigged down Logging/braided cable equipment Made up BHA no. 5 R.I.H. to 5380.00 ft Serviced Block line R.I.H. to 10977.00 ft Circulated at 10977.00 ft Flow check Laid down 10400.00 ft of 5in OD drill pipe Laid down 10600.00 ft of 5in OD drill pipe (cont...) Pulled BHA Retrieved Bore protector Installed Casing handling equipment Ran Casing to 10958.00 ft (7in OD) Circulated at 10958.00 ft Held safety meeting Pumped Brine spacers - volume 90.000 bbl Mixed and pumped slurry - 62.000 bbl Displaced slurry - 411.000 bbl Tested Casing ~E~EIV~¢ Rigged down Casing handling equipment Installed Seal assembly .~,~ [JG ~- 8 1997 Tested Seal assembly Rigged up Tubing handling equipment ~Ala$~a_ ,0ii .& Gas Cons~ !~o_[ni__!~l~ gn r_ait Facility Date/Time 05 May 97 Progress Report Pt Mac 2 Well P2-01 Page 3 Rig Doyon 14 Date 27 August 97 05:30-05:45 05:45-06:00 06:00-16:00 16:00-17:00 17:00-20:30 20:30-21:00 21:00-23:00 23:00-23:15 23:15-23:30 23:30-00:30 00:30-03:00 03:00-04:00 04:00 06:00-06:30 06:30-08:30 08:30-09:15 09:15-11:00 11:00-11:30 Duration 1/4 hr 1/4 hr 10hr lhr 3-1/2 hr 1/2 hr 2hr 1/4 hr 1/4 hr lhr 2-1/2 hr lhr 1/2 hr 2hr 3/4 hr 1-3/4 hr 1/2 hr Activity Held safety meeting Ran Tubing to 4-1/2in (100.00 ft OD) Ran Tubing to 8046.00 ft (4-1/2in OD) (cont...) Installed SCSSSV nipple assembly Ran Tubing to 10215.00 ft (4-1/2in OD) Installed Tubing hanger Reverse circulated at 10245.00 ft Retrieved Tubing landing string Installed Hanger plug Removed BOP stack Installed Xmas tree Removed Hanger plug Circulated at 10245.00 ft Circulated at 10245.00 ft (cont...) Set Production packer at 10189.00 ft with 4000.0 psi Tested Casing Freeze protect well - 160.000 bbl of Diesel Installed Hanger plug Sperry-Sun of Alaska Al)PM vl. 36A Apr/26/1997 ORIEHTATION DATA SHEET Well: P2-Oi Page: BRA ~ MD in MD out Bit ~ Size Make (ft) (ft) (in) 1 118.00 5483.00 1 12.250 SI~ITH Type Jets TFA Condition (in) (in2) m4AISL lX13D/2X16 0.543 4-3-BT-}{-E-1/16-ER-~) Pump Make Type Liner Stroke SPM ~ (in) (in) 1 E]4SCO FB-1600 6.000 12.000 70 2 E}{SCO FB-1600 6.000 12.000 80 D.D. supervisors: SCOTT CROSBY, JIM BROWN/S.CROSBY Flow rate...: 650.OOpm Magnetic declination: 28.67 P.pres. drlg: 2650 psi RWI) toolface offset.: 230.26 P.pres. circ: 2450 psi ~ depth correction: 50.00 f~ Tally: BIT I, }fir ST, }{TR AJ, SUB XO, STB S, MWDHOC, SUB OR, lO{DC, NMDC, H]4IX2, JAR, SUB XO, HWDP, DP G, KELLY Formations / TVD tops ~ill~: (ft) SV1 (T3) 4656.20 Orientation data: (Ali data on the current line refers to the depth interval: current bit depth - previous bit depth) Bit $vy Course Build Turn DLS TVD Orient Rotate Start End depth depth Inc Dir length rate rate ---interval--- rotate rotate (ft) (ft) (') (') (ft) ..... ('/lOOft) ...... (ft) (ft) (ft) (ft) (ft) 228.00 180.25 0.72 120.68 144.85 0.49 82.69 0.49 180.25 0.00 144.85 83.15 228.00 320.00 272.25 0.78 141.30 92.00 0.07 22.41 0.30 272.24 0.00 92.00 228.00 320.00 408.80 361.05 1.17 152.16 88.80 0.44 12.23 0.48 361.03 0.00 88.80 320.00 408.80 498.16 450.41 0.60 286.06 89.36 -0.64 149.84 1.84 450.38 61.00 28.36 469.80 498.16 587.39 539.64 0.87 286.06 89.23 0.30 0.00 0.30 539.60 I5.00 74.23 513.16 587.39 676.92 629.17 2.11 289.31 89.53 1.39 3.63 1.39 629.10 62.00 27.53 649.39 676.92 766.79 719.04 3.95 278.06 89.87 2.05 -12.52 2.14 718.84 45.00 44.87 721.92 766.79 859.68 809.08 4.36 277.34 92.89 0.46 -0.80 0.46 808.64 0.00 92.89 766.79 859.68 948.88 898.88 3.34 278.36 89220 -1.14 1.14 1.14 898.24 30.00 59.20 889.68 948.88 1038.13 988.13 3.56 280.34 89.25 0.25 2.22 0.28 987.33 0.00 89.25 948.88 1038.13 1128.38 1078.38 3.53 277.45 90.25 -0.03 -3.20 0.20 1077.41 0.00 90.25 1038.13 1128.38 1223.17 1173.17 3.67 278.83 94.79 0.15 1.46 0.17 1172.0i 0.00 94.79 1128.38 1223.i7 1317.01 1267.01 3.91 273.39 93.84 0.26 -5.80 0.46 1265.65 0.00 93.84 1223.i7 1317.01 1411.34 1361.34 3.81 278.13 94.33 -0.11 5.02 0.35 1359.77 0.00 94.33 1317.01 I411.34 1506.07 1456.07 2.73 274.43 94.73 -1.14 -3.91 1.16 1454.34 30.00 64.73 1411.34 1476.07 1600.58 1550.58 2.52 274.06 94.51 -0.22 -0.39 0.22 1548.75 0.00 94.51 1506.07 1600.58 1695.19 1645.19 1.99 280.78 94.61 -0.56 7.10 0.63 1643.29 20.00 74.61 1620.58 i695.19 1789.90 1739.80 0.96 228.39 94.71 -1.09 -55.37 1.69 1737.87 30.00 64.71 i725.19 I789.90 1884.85 I834.85 0.75 135.92 94.95 -0.22 -97.29 1.31 1832.91 20.00 74.95 i809.90 1884.85 1982.23 1932.23 0.79 129.95 97.38 0.04 -6.13 0.09 1930.28 0.00 97.38 1884.85 1982.23 2074.22 2024.22 0.95 i05.54 91.99 0.i7 -26.54 0.43 2022.26 0.00 91.99 i982.23 2074.22 2169.06 2119.06 1.47 300.25 94.84 0.55-174.28 2.53 2117.09 94.84 0.00 0.00 0.00 2262.81 2212.81 3.74 306.80 93.75 2.42 6.99 2.44 2210.74 62.00 31.75 2231.06 2262.81 2357.33 2307.33 5.85 302.36 94.52 2.23 -4.70 2.26 2304.92 62.00 32.52 2324.81 2357.33 2451.73 2401.73 9.02 301.92 94.40 3.36 -0.47 3.36 2398.51 62.00 32.40 2419.33 2451.73 2547.67 2497.67 10.65 300.18 95.94 1.70 -1.81 1.73 2493.04 31.00 64.94 2482.73 2547.67 2641.64 2591.64 12.96' 293.54 93.97 2.46 -7.07 2.85 2585.02 62.00 31.97 2609.67 2641.64 2736.81 2686.81 16.81 292.47 95.i7 4.05 -1.12 4.06 2676.98 62.00 33.17 2703.64 2736.81 2831.34 2781.34 '20.74 288.33 94.53 4.16 -4.38 4.39 2766.47 62.00 32.53 2798.81 2831.34 Toolface 330 RAG 280RAG 270 }{AG 260 RAG i10 }{AG i00 RAG 110 }{AG - 120mag 40RAG 260 RAG 270 RAG 270 RAG 305 20-80L/ROT 50-60L/ROT 20-30L/ROT 50-60L/ROT "~S-perr¥-Sun of Alaska ORIENTATION DATA SHEET Page: ADRM vl.36A Apr/26/1997 Well: P2-O1 BHA ~ MD in MD out Bit ~ Size Make Type Jets (ft) (ft) (in) (in) 1 118.00 5483.00 1 12.250 SMITH MA1SL lX13D/2X16 TFA Condition (in2) 0.543 4-3-BT-M-E-1/16-ER-TD Orientation data: (All data on %he current line refers to the depth interval: current bit Bit Svy Course Build Turn DLS TV]) Orient Rotate depth depth Inc Dir len~h rate rate ---interval--- (ft) (ft) (') (') (ft) ..... ('/lOOft) ...... (ft) (ft) (ft) 2926.54 2876.54 23.37 285.53 95.20 2.76 -2.94 2.97 2854.70 30.00 65.20 3021.70 2971.70 23.15 285.51 95.16 -0.23 -0.02 0.23 2942.13 0.00 95.16 3116.38 3066.38 24.02 288.44 94.68 0.92 3.09 1.54 3028.90 15.00 79.68 3211.49 3161.49 25.77 288.07 95.11 1.84 -0.39 1.85 3115.17 30.00 65.11 3305.29 3255.29 28.45 289.25 93.80 2.86 1.26 2.91 3198.66 45.00 ~8.80 3397.17 3347.17 30.70 289.14 91.88 2.45 -0.12 2.45 3278.56 45.00 46.88 3491.75 3441.75 30.77 285.58 94.58 0.07 -3.76 1.92 3359.86 45.00 49.58 3586.37 3536.37 32.95 283.71 94.62 2.30 -1.98 2.53 3440.22 45.00 49.62 3682.48 3632.48 36.70 283.06 96.11 3.90 -0.68 3.92 3519.10 45.00 51.11 3777.23 3727.23 37.71 285.34 94.75 1.07 2.41 1.80 3594.57 25.00 69.75 3872.99 3822.99 37.98 285.85 95.76 0.28 0.53 0.43 3670.19 20.00 75.76 3966.99 3916.99 37.97 287.05 94.00 -0.01 1.28 0.79 3744.29 20.00 74.00 4061.94 4011.94 37.43 287.54 94.95 -0.57 0.52 0.65 3819.42 32.00 62.95 4156.10 4106.10 40.59 289.34 94.16 3.36 1.91 3.56 3892.58 45.00 49.16 4250.94 4200.94 41.30 288.19 94.84 0.75 -1.21 1.09 3964.22 20.00 74.84 4346.03 4296.03 41.11 286.83 95.09 -0.20 -1.43 0.96 4035.76 20.00 75.09 4440.85 4390.85 39.48 286.88 94.82 -1.72 0.05 1.72 4108.08 0.00 94.82 4535.63 4485.63 38.59 286.43 94.78 -0.94 -0.47 0.99 4181.70 0.00 94.78 4630.34 4580.34 37.45 285.14 94.71 -1.20 -1.36 1.47 4256.31 0.00 94.71 4725.84 4675.84 36.64 286.31 95.50 -0.85 1.23 1.12 4332.53 45.00 50.50 4820.45 4770.45 37.99 285.30 94.61 1.43 -1.07 1.57 4407.77 40.00 54.61 4915.29 4865.29 39.31 287.50 94.84 1.39 2.32 2.01 4481.84 20.00 74.84 5010.24 4960.24 38.89 286.68 94.95 -0.44 -0.86 0.70 4555.53 0.00 94.95 5104.48 5054.48 38.70 288.92 94.24 -0.20 2.38 1.50 4628.98 25.00 69.24 5199.53 5149.53 37.83 289.62 95.05 -0.92 0.74 1.02 4703.61 0.00 95.05 5294.28 5244.28 38.69 288.13 94.75 0.91 -1.57 1.33 4778.01 40.00 54.75 5388.97 5338.97 38.46 289.35 94.69 -0.24 1.29 0.84 4852.04 20.00 74.69 depth - previous bit depth) Start End rotate rotate Toolface (ft) (ft) 2861.34 2926.54 50L/ROT 2926.54 3021.70 ROT 3021.70 3101.38 HS-2OL/ROT 3146.38 3211.49 30L/ROT 3256.49 3305.29 40-50L/ROT 3350.29 3397.17 50-60L/ROT 3442.17 3491.75 60-70L/ROT 3536.75 3586.37 IlS-IOn/ROT 3631.37 3682.48 IiS-iOR/ROT 3707.48 3777.23 40-60R/ROT 3797.23 3872.99 HS-2OR/ROT 3892.99 3966.99 ~S-iOR/ROT 3998.99 4061.94 iO-20L/ROT 4106.94 4156.10 IIS-iOL/RO~ 4176.10 4250.94 90L/ROT 4270.94 4346.03 100L/RO~ 4346.03 4440.85 ROT 4440.85 4535.63 ROT 4535.63 4630.34 ROT 4675.34 4725.84 t{S-iOR/RO~ 4765.84 4820.45 t[S-iOR/RO~ 4840.45 4915.29 ~S-iOR/ROT 4915.29 5010.24 ROT 5035.24 5104.48 ~S-iOR/ROT 5104.48 5199.53 ROT 5239.53 5294.28 30-40L/ROT 5314.28 5388.97 Remarks: THE ASSEMBLY WAS USED TO DRILL O~T ICE IN THE CONIMJCTOR, O-118'MD. THE ASSEMBLY WAS THEN USED TO DRILL THE 12.25" SURFACE MOLE SECTION FRACTIONkLLY, 118-5483'MD, ~ CASING POINT WAS REAC[[ED. THE ASSEMBLY WOULD GE~EPAT 7-10'/iOOFT DOG LEGS, IF FULL SETS WERE MADE. ORIENTATION DATA SHEET Page: ADPd4 vl.36A May/05/1997 Well: P2-O1 BRA { MD in MD out Bit # Size Make Type Jets (ft) (ft) (in) (in) 3 5541.00 10975.00 3 8.500 HYCALOG DSTOFGV 3x12's/3x13's TFA Condition (in2) 0.720 7-6-BT-N-X-1/4"-CT-TD Pump Make Type Liner Stroke Sm D.D. supervisors: JIM BROWN ~ (in) (in) 1 E){SCO FB-1600 6.000 12.000 65 Flow rate...: 600.OOpm 2 £~{SC0 [23-1600 6.000 12.000 75 P.pres. drlg: 3400 psi P.pres. circ: 3100 psi Magnetic declination: 28.67 ..~ toolface offset.: 36.I0 MWD depth correction: 46.00 ft Tally: BIT P, ~ PD, MTR BH, SUBNXO, ~dD GR, }54I) FE, SUB FS, FNI4I)C, STB S, FN]{DC, F~, JAR, HWDP, DP G, KELLY Formations / TVl) to~s drilled: (ft) SVl (T3) 4656.20 K-15 (UGNU) 5096.20 WEST SAK 6871.20 HRZ 8584.20 I~ALUBIK 8689.20 KUPARUK 8728.20 K-10 8399.20 Orientation data: (All data on the current line refers to the depth interval: ~rrent bit Bit Svy Course Build Turn DLS TV/) Orient Rotate depth depth Inc Dir length rate rate ---interval--- (ft) (ft) (') (') (ft) ..... ('/lOOft) ..... (ft) (ft) (ft) 5633.24 5587.24 40.16 288.19 92.70 2.66 -0.66 2.70 5046.57 32.00 60.70 5726.79 5680.79 40.15 287.71 93.55 -0.01 -0.51 0.33 5118.07 0.00 93.55 5819.50 5773.50 40.42 286.92 92.71 0.29 -0.85 0.62 5188.79 0.00 92.71 5913.34 5867.34 40.25 286.64 93.84 -0.18 -0.30 0.26 5260.32 0.00 93.84 6008.39 5962.39 40.03 285.27 95.05 -0.23 -1.44 0.96 5332.98 0.00 95~05 6101.17 6055.17 39.72 288.70 92.78 -0.33 3.70 2.39 5404.19 20.00 72.78 6195.94 6149.94 39.88 287.53 94.77 0.17 -1.23 0.81 5477.00 0.00 94.77 6289.28 6243.28 40.11 287.87 93.34 0.25 0.36 0.34 5548.51 0.00 93.34 6383.45 6337.45 39.67 287.65 94.17 -0.47 -0.23 0.49 5620.76 0.00 94.17 6476.81 6430.81 39.77 286.71 93.36 0.11 -1.01 0.65 5692.57 0.00 93.36 6572.94 6526.94 38.92 286.08 96.13 -0.88 -0.66 0.98 5766.91 0.00 96.13 6666.56 6620.56 39.28 284.99 93.62 0.38 -1.16 0.83 5839.56 0.00 93.62 6759.70 6713.70 38.80 287.89 93.14 -0.52 3.11 2.03 5911.91 20.00 73.14 6852.32 6806.32 38.37 289.02 92.62 -0.46 1.22 0.89 5984.31 0.00 92.62 6946.88 6900.88 38.34 288.82 94.56 -0.03 -0.21 0.14 6058.46 0.00 94.56 7040.66 6994.66 38.41 287.32 93.78 0.07 -1.60 1.00 6131.98 0.00 93.78 7135.22 7089.22 38.52 287.53 94.56 0.12 0.22 0.18 6206.02 0.00 94.56 7228.90 7182.90 38.95 286.89 93.68 0.46 -0.68 0.63 6279.10 0.00 93.68 7321.34 7275.34 39.16 286.84 92.44 0.23 -0.05 0.23 6350.88 0.00 92.44 7413.71 7367.71 39.33 285.71 92.37 0.18 -1.22 0.80 6422.42 0.00 92.37 7509.36 7463.36 40.07 286.89 95.65 0.77 1.23 1.10 6496.01 20.00 75.65 7600.00 7554.00 40.67 285.47 90.64 0.66 -1.57 1.21 6565.07 0.00 90.64 7693.33 7647.33 39.71 287.02 93.33 -1.03 1.66 1.49 6636.37 20.00 73.33 7788.24 7742.24 39.37 290.11 94.9i -0.36 3.26 2.10 6709.57 20.00 74.91 7880.15 7834.15 39.52 290.57 91.91 0.16 0.50 0.36 6780.55 0.00 91.91 7972.68 7926.68 40.35 290.36 92.53 0.90 -0.23 0.91 6851.50 0.00 92.53 8067.06 $021.06 39.04 289.18 94.38 -1.39 -1.25 1.60 6924.12 15.00 79.38 8158.73 8112.73 39.47 287.97 91.67 0.47 -1.32 0.96 6995.10 0.00 91.67 8252.15 8206.15 39.94 287.27 93.42 0.50 -0.75 0.69 7066.97 0.00 93.42 _ depth - previous bit depth) Start End rotate rotate Toolface (ft) (ft) 5572.54 5633.24 HS-IOL/ROT 5633.24 5726.79 ROT 5726.79 5819.50 ROT 5819.50 5913.34 ROT 5913.34 6008.39 ROT 6028.39 6101.17 80-90R/ROT 6101.17 6195.94 ROT 6195.94 6289.28 ROT 6289.28 6383.45 ROT 6383.45 6476.81 ROT 6476.81 6572.94 ROT 6572.94 6666.56 RfY~ 6666.56 6739.70 80-90R/ROT 6759.70 6852.32 ROT 6852.32 6946.88 ROT 6946.88 7040.66 ROT 7040.66 7135.22 ROT 7135.22 7228.90 ROT 7228.90 7321.34 ROT 7321.34 7413.71 ROT 7433.71 7509.36 90-100R/RT 7509.36 7600.00 ROT 7620.00 7693.33 125R/ROT 7693.33 7768.24 130R/ROT 7788.24 7880.15 ROT 7880.15 7972.68 ROT 7987.68 8067.06 170R/ROT 8067.06 8158.73 ROT 8158.73 8252..15 ROT' Sperry-Sun of Alaska ADRM vl. 36A ~{ay/05/1997 ORIENTATION DATA SHEET Well: P2-O1 Page: 3 MD in MD out Bit # Size Make Type Jets (ft) (ft) (i~l) (in) 5541.00 10975.00 3 8.500 HYCALOG DS7OFGV 3x12's/3x13's TFA Condi-tion (in2) 0.720 7-6-BT-N-X-1/4"-CT-TD Orientation data: (All data on the current line refers to the depth interval: current bit Bit Svy Course Build Turn DLS TVD Orient Rotate depth depth Inc Dir length rate rate ---interval--- (ft) (ft) (') (~) (ft) ..... (~/100ft) ...... (ft) (ft) (ft) 8346.66 8300.66 38.25 288.19 94.51 -1.79 0.97 1.89 7140.32 20.00 74.51 8442.21 8396.21 38.70 287.61 95.55 0.47 -0.61 0.60 7215.12 0.00 95.55 8533.97 8487.97 38.86 288.38 91.76 0.17 0.84 0.55 7286.65 0.00 91.76 8629.21 8583.21 38.80 287.79 95.24 -0.06 -0.62 0.39 7360.84 0.00 95.24 8722.66 8676.66 38.78 286.27 93.45 -0.02 -1.63 1.02 7433.68 0.00 93.45 8818.05 8772.05 38.59 285.00 95.39 -0.20 -1.33 0.86 7508.14 0.00 95.39 8909.84 8863.84 38.69 285.30 91.79 0.11 0.33 0.23 7579.84 0.00 91.79 9004.08 8958.08 39.94 285.32 94.24 1.33 0.02 1.33 7652.75 20.00 74.24 9097.91 9051.91 40.25 288.03 93.83 0.33 2.89 1.89 7724.53 20.00 73.83 9192.29 9146.29 40.62 288.87 94.38 0.39 0.89 0.70 7796.37 0.00 94.38 9284.86 9238.86 38.75 289.85 92.57 -2.02 1.06 2.13 7867.61 20.00 72.57 9377.79 9331.79 38.18 288.59 92.93 -0.61 -1.36 1.04 7940.37 0.00 92.93 9472.43 9426.43 37.62 287.15 94.64 -0.59 -1.52 1.11 8015.05 0.00 94.64 9567.32 9521.32 37.46 285.44 94.89 -0.17 -1.80 1.11 8090.29 0.00 94.89 9661.54 9615.54 37.07 285.79 94.22 -0.41 0.37 0.47 8165.27 0.00 94.22 9756.39 9710.15 38.04 285.36 94.85 1.03 -0.45 1.06 8240.27 20.00 74.85 9851.55 9805.55 37.58 286.32 95.16 -0.48 1.01 0.78 8315.64 0.00 95.16 9944.42 9898.42 37.41 283.74 92.87 -0.18 -2.78 1.70 8389.33 0.00 92.87 10038.57 9992.57 36.58 282.95 94.15 -0.88 -0.84 1.02 8464.53 0.00 94.15 10131.11 10085.11 36.37 285.90 92.54 -0.23 3.19 1.91 8538.95 20.00 72.54 10224.42 10178.42 36.07 283.80 93.31 -0.32 -2.25 1.37 8614.23 0.00 93.31 10319.67 10273.67 35.25 282.74 95.25 -0.86 -1.11 1.08 8691.62 0.00 95.25 10413.88 10367.88 35.24 284.59 94.21 -0.01 1.96 1.13 8768.56 20.00 74.21 10507.16 10461.16 35.17 285.13 93.28 -0.08 0.58 0.34 8844.78 0.00 93.28 10602.76 10556.76 33.69 286.11 95.60 -1.55 1.03 1.65 8923.63 0.00 95.60 10694.10 10648.10 33.40 286.88 91.34 -0.32 0.84 0.56 8999.76 0.00 91.34 10787.56 10741.56 33.30 285.48 93.46 -0.11 -1.50 0.83 9077.83 0.00 93.46 10881.01 10835.01 33.86 285.91 93.45 0.60 0.46 0.65 9155.68 0.00 93.45 10972.38 10926.38 34.i1 285.91 91.37 0.27 0.00 0.27 9231.44 0.00 91.37 depth - previous bit depth) Start End rotate' rotate Toolface (ft) (ft) 8272.15 8346.66 160R/ROT 8346.66 8442.21 ROT 8442.21 8533.97 ROT 8533.97 8629.21 ROT 8629.21 8722.66 ROT 8722.66 8818.05 ROT 8818.05 8909.84 ROT 8929.84 9004.08 30-40R/ROT 9024.08 9097.91 90R/ROT 9097.91 9192.29 ROT 9212.29 9284.86 160R/ROT 9284.86 9377.79 ROT 9377.79 9472.43 ROT 9472.43 9567.32 ~ 9567.32 9661.54 MOT 9681.54 9756.39 40-50R/ROT 9756.39 9851.55 ~ 9851.55 9944.42 MOT 9944.42 10038.57 MOT 10058.57 10131.11 50-70R/ROT 10131.11 10224.42 ROT 10224.42 10319.67 MOT 10339.67 10413.88 30-40R/ROT 10413.88 10507.16 MOT 10507.16 10602.76 MOT 10602.76 10694.10 ROT 10694.10 10787.56 MOT 10787.56 10881.01 MOT 10881.01 10972.38 MOT Remarks: THIS ASSEMBLY WAS FRACTIONALLY DRILLED THE 8.5" PRODUCTION SECTION, 5541-7510'MD, WHERE THE FIRST P[.,A.~ WIPER TRIP STATION WAS R~CHED. THE WIPER TRIP BACK TO THE CASING SHOE, AT 5473'~D, AND BACK IN TO BOTTO~ WAS W/O INCIDENTS. THE ASSERBLY CONTINUED TO BE FRACTIONALLY DRILLED AH~AD, 7510-9868'M1), WHERE THE WELL BORE WAS DISPLACED TO A 3% KCL-POL~ER RUD TYPE, W/2% MUD LUBE ADDED. THE DRILLING THEN CONTINUED, FRACTIONALLY PERFORMED, 9868-10975'~D, W~ICH WAS CALLED "T.D." FOR THE WELL BORE. THE ASSEMBLY WAS WIPER TRIPPED, 10975-9053'~D, AlqI) RAN BACK TO BOTTC~, W/O DIFFICULTIES. T]IE WELL BORE WAS CIRCULATED, AN ESS PROBE DROPPED, AND THE ASSEMBLY HOISTED. WELL LOG TRANSMITTAL To: State of Alaska August 27, 1997 Alaska Oil and Gas Conservation Comrn. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - D.S. 18-15B, AK-MW-70146 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~tG, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-21755-02. 5631 Silvemdo Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11256 Company: Field: 8/18/97 Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Greater Point Mclntyre Area West Niakuk (NK-27/NK-28/NK'-29) Well Job # Log Description Date BL RF Sepia P2-1 CEMENT EVALUATION LOG 97051 3 I 1 P2-1 CEMENT BOND LOG 97 0 51 3 I 1 ..... P 2- 5 9 INJECTION PROFILE 9 7 0 51 6 I 1 ,., ,, SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: CI I:t I I_1_1 IM G S E I~!~/Ir' ~:~ c: __ To: State of Alaska August 6, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs P2-01, AK-MM-70113 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Yum Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 P2-01: 2" x 5" MD Gamma Ray Logs: 50-029-22761-00 2" x 5" TVD Gamma Ray Logs: 50-029-22761-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company nl:! I I_1_1 N G S E I::IL/I C E S WELL LOG TRANSMITTAL _. To: State of Alaska July 30, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Drive. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - P2-01, AK-MM-70113 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22761-00 5631 Silverado Way, Suite G · Anchorage, ~aska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, inc. Company _ GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11179 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Greater Point Mclntyre Area All Pt. Mac wells excludes P1-09 7/24/97 Floppy Well Job # Log Description Date BL RF Sepia Disk P2-01 ~, ~ .~'~'~ 97278 PEX-AIT~CNL/LDT, BHC 970502 1 P2-01 97278 PEX-AIT 970502 1 1 , , P2-01 97278 PEX-CNL/LDT 970502 I 1 P2-01 97278 IBHC 970502 I 1 P2-01 97278 BOREHOLE PROFILE 970502 I 1 P2-01 97278 PEX-SSTVD 970502 I I Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: JUl_. 2 5 199-/ spenn -sur, CI i:! i I--I--I N G AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data P2-01 %'1. ol% June 9,1997 Dear Ms. Taylor: Enclosed are two hard copies of the above mentioned file(s). Well P2-01 MWD survey Tie-In point at 0.00', and a Projected survey at 10,974.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachments 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company C! I::! I I--I-- I N G AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data 18-15B June 10,1997 Dear Ms. Taylor: Enclosed are two hard copies of the above mentioned file(s). Well 18-15B MWD survey Tie-In point at 9,998.00', Window point at 10,110.00' and a Projected survey at 11,818.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachments 5631 Siiverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company SPF Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU / P2-01 500292276100 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/ 6/97 DATE OF SURVEY: 050297 MWD SURVEY JOB NUMBER: AK-MM-70113 KELLY BUSHING ELEV. = 47.15 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -47.15 34.30 34.3g -12.85 180.25 180.24 133.09 272.25 272.24 225.09 361.05 361.02 313.87 0 0 N .00 E .00 .00N .00E 0 0 N .00 E .00 .00N .00E 0 43 S 59.32 E .49 .475 .79E 0 46 S 38.70 E .30 1.255 1.68E 1 10 .S 27.84 E .48 2.525 2.48E .00 .00 -.89 -1.97 -3.10 450.41 450.37 403.22 539.64 539.59 492.44 629.17 629.09 581.94 719.04 718.82 671.67 809.08 808.62 761.47 0 36 N 73.94 W 1.84 3.205 2.46E 0 52 N 73.94 W .30 2.895 1.36E 2 6 N 70.69 W 1.39 2.155 .85W 3 57 N 81.94 W 2.14 1.175 5.48W 4 21 N 82.66 W .46 .305 11.94W -3.28 -2.13 .19 4.91 11.35 898.88 898.22 851.07 988.13 987.31 940.16 1078.38 1077.38 1030.23 1173.17 1171.99 11.24.84 1267.01 1265.62 1218.47 3 20 N 81.64 W 1.14 .52N 17.92W 3 33 N 79.66 W .28 1.39N 23.22W 3 31 N 82.55 W .20 2.26N 28.73W 3 40 N 81.17 W .17 3.10N 34.62W 3 54 N 86.61 W .46 3.75N 40.78W 17.30 22.63 28.15 34.04 40. 12 1361.34 1359.74 1312.59 1456.07 1454.31 1407.16 1550.58 1548.72 1501.57 1645.19 1643.25 1596.10 1739.80 1737.83 1690.68 3 48 N 81.87 W .35 4.38N 47.09W 2 43 N 85.57 W 1.16 5.00N 52.46W 2 31 N 85.94 W .22 5.32N 56.78W 1 59 N 79.22 W .63 5.78N 60.46W 0 57 S 48.39 W 1.69 5.56N 62.67W 46.35 51.67 55.89 59.55 61.60 1834.85 1832.87 1785.72 1932.23 1930.24 1883.09 2024.22 2022.22 1975.07 2119.06 2117.04 2069.89 2212.81 2210.67 2163.52 0 45 S 44.08 E 1.31 4.58N 62.83W 0 47 S 50.05 E .09 3.69N 61.87W 0 57 S 74.46 E .43 3.08N 60.65W 1 28 N 59.75 W 2.53 3.49N 60.95W 3 44 N 53.20 W 2.44 5.92N 64.43W 61.48 60.30 58.96 59.35 63.40 2307.33 2304.84 2257.69 2401.73 2398.44 2351.29 2497.67 2492.96 2445.81 2591.64 2584.94 2537.79 2686.81 2676.90 2629.75 5 50 N 57.64 W 2.26 10.35N 70.97W 9 1 N 58.08 W 3.36 16.84N 81.32W 10 38 N 59.82 W 1.73 25.27N 95.37W 12 57 N 66.46 W 2.85 33.85N 112.54W 16 48 N 67.53 W 4.06 43.37N 135.04W 70.93 82.71 98.60 117.51 141.82 2781.34 2766.39 2719.24 2876.54 2854.61 2807.46 2971.70 2942.04 2894.89 3066.38 3028.81 2981.66 3161.49 3115.07 3067.92 20 44 N 71.67 W 4.39 53.86N 163.58W 23 22 N 74.47 W 2.97 64.22N 197.78W 23 8 N 74.49 W .23 74.28N 233.99W 24 1 N 71.56 W 1.54 85.35N 270.20W 25 46 N 71.93 W 1.85 97.89N 308.22W 172.16 207.90 245.47 283.34 323.36 O G NAL JUN 11 199T Gl! & Gas Co.s. Oornmissio~ Anchorage SPF .... Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU / P2-01 500292276100 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/ 6/97 DATE OF SURVEY: 050297 MWD SURVEY JOB NUMBER: AK-MM-70113 KELLY BUSHING ELEV. = 47.15 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3255.29 3198.56 3151.41 3347.17 3278.45 3231.30 3441.75 3359.75 3312.60 3536.37 3440.10 3392.95 3632.48 3518.98 3471.83 28 27 30 42 30 46 32 57 36 42 N 70.75 W 2.91 111.58N 348.70W N 70.86 W 2.45 126.48N 391.52W N 74.42 W 1.92 140.90N 437.64W N 76,29 W 2.53 153.50N 485.95W N 76.94 W 3.92 166.19N 539.34W 366.07 411.37 459.68 509.58 564.35 3727.23 3594.44 3547.29 3822.99 3670.06 3622.91 3916.99 3744.16 3697.01 4011.94 3819.29 3772.14 4106.10 3892.45 3845.30 37 42 37 58 37 58 37 25 40 35 N 74.66 W 1.80 180.25N 594.86W N 74.15 W .43 196.05N 651.45W N 72.95 W .79 212.42N 706.92W N 72.46 W .65 229.68N 762.36W N 70.66 W 3.56 248.46N 818.56W 621.57 680.31 738.15 796.21 855.44 4200.94 3964.08 3916.93 4296.03 4035.62 3988.47 4390.85 4107.94 4060.79 4485.63 4181.56 4134.41 4580.34 4256.16 4209.01 41 17 41 6 39 28 38 35 37 27 N 71.81 W 1.09 268.44N 877.41W N 73.17 W .96 287.29N 937.14W N 73.12 W 1.72 305.07N 995.83W N 73.57 W .99 322.18N 1053.01W N 74.86 W 1.47 338.05N 1109.14W 917.55 980.18 1041.50 1101.19 1159.51 4675.84 4332.39 4285.24 4770.45 4407.63 4360.48 4865.29 4481.69 4434.54 4960.24 4555.37 4508.22 5054.48 4628.82 4581.67 36 38 37 59 39 18 38 53 38 42 N 73.69 W 1.12 353.64N 1164.51W N 74.70 W 1.57 369.25N 1219.69W N 72.50 W 2.01 385.99N 1276.50W N 73.32 W .70 403.59N 1333.74W N 71.08 W 1.50 421.63N 1389.94W 1217.03 1274.36 1333.58 1393.46 1452.48 5149 . 53 4703 . 45 4656 . 30 5244 . 28 4777 . 85 4730 . 70 5338.97 4851. 87 4804 . 72 5434 . 36 4926 . 78 4879 . 63 5494 . 55 4974 . 29 4927 . 14 37 49 38 41 38 27 38 2 37 41 N 70.38 W 1.02 441.05N 1445.51W N 71.87 W 1.33 460.02N 1501.02W N 70.65 W .84 478.99N 1556.93W N 70.81 W .44 498.48N 1612.68W N 71.20 W .72 510.51N 1647.62W 1511.29 1569.92 1628.92 1687.93 1724.85 5587.24 5046.39 4999.24 5680.79 5117.89 5070,74 5773.50 5188.61 5141,46 5867.34 5260.14 5212,99 5962.39 5332.81 5285,66 40 9 40 9 40 25 40 15 40 1 N 71.81 W 2.70 528.97N 1702.84W N 72.29 W .33 547.56N 1760.23W N 73,08 W .62 565.40N 1817.46W N 73.36 W .26 582.94N 1875.61W N 74,73 W .96 599.78N 1934.52W 1783.05 1843.36 1903.31 1964.04 2025.31 6055.17 5404.01 5356.86 6149.94 5476.82 5429.67 6243.28 5548.33 5501.18 6337.45 5620.58 5573.43 6430.81 5692.39 5645.24 39 43 39 52 4O 6 39 40 39 46 N 71,30 W 2.39 617.14N 1991.38W N 72.47 W .81 636.00N 2049.04W N 72.13 W .34 654.24N 2106.19W N 72,35 W .49 672.67N 2163.70W N 73,29 W .65 690.29N 2220.70W 2084.76 2145.41 2205.39 2265.77 2325.43 SPF ..... Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU / P2- 01 500292276100 NORTH SLOPE BOROUGH COMPUTATION DATE: 6 / 6/97 DATE OF SURVEY: 050297 MWD SURVEY JOB NUMBER: AK-MM-70113 KELLY BUSHING ELEV. = 47.15 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6525.94 5765.96 5718.81 6620.56 5839.39 5792.24 6713.70 5911.73 5864.58 6806.32 5984.13 5936.98 6900.88 6058.28 6011.13 38 55 N 73.92 W .99 707.31N 2278.55W 39 16 N 75.01 W .82 723.29N 2336.04W 38 47 N 72.11 W 2.03 739.88N 2392.30W 38 22 N 70.98 W .89 758.16N 2447.09W 38 20 N 71.18 W .14 777.19N 2502.59W 2385.74 2445.40 2504.04 2561.78 2620.42 6994.66 6131.80 6084.65 7089.22 6205.84 6158.69 7182.90 6278.91 6231.76 7275.34 6350.70 6303.55 7367.71 6422.23 6375.08 38 24 N 72.68 W 1.00 795.25N 2557.94W 38 31 N 72.47 W .18 812.86N 2614.06W 38 57 N 73.11 W .63 830.20N 2670.05W 39 9 N 73.16 W .23 847.10N 2725.79W 39 19 N 74.29 W .80 863.47N 2781.88W 2678.62 2737.43 2796.05 2854.29 2912.72 7463.36 6495.82 6448.67 7554.00 6564.88 6517.73 7647.33 6636.17 6589.02 7742.24 6709.36 6662.21 7834.15 6780.34 6733.19 40 4 N 73.11 W 1.10 880.63N 2840.52W 40 40 N 74.53 W 1.21 896.98N 2896.90W 39 42 N 72.98 W 1.49 913.82N 2954.72W 39 22 N 69.89 W 2.10 933.04N 3011.97W 39 31 N 69.43 W .36 953.34N 3066.73W 2973.81 3032.51 3092.73 3153.10 3211.38 7926.68 6851.29 6804.14 8021.06 6923.90 6876.75 8112.73 6994.89 6947.74 8206.15 7066.76 7019.61 8300.66 7140.10 7092.95 40 20 N 69.64 W .91 974.11N 3122.37W 39 2 N 70.82 W 1.60 994.50N 3179.09W 39 28 N 72.03 W .96 1012.98N 3234.07W 39 56 N 72.73 W .69 1031.04N 3290.95W 38 15 N 71.81 W 1.89 1049.18N 3347.71W 3270.66 3330.85 3388.82 3448.50 3508.08 8396.21 7214.90 7167.75 8487.97 7286.43 7239.28 8583.21 7360.63 7313.48 8676.66 7433.47 7386.32 8772.05 7507.93 7460.78 38 42 N 72.39 W .60 1067.45N 3404.28W 38 51 N 71.62 W .55 1085.20N 3458.94W 38 47 N 72.21 W .39 1103.74N 3515.71W 38 46 N 73.73 W 1.02 1120.88N 3571.68W 38 35 N 75.00 W .86 1136.95N 3629.09W 3567.51 3624.97 3684.67 3743.21 3802.82 8863.84 7579.62 7532.47 8958.08 7652.53 7605.38 9051.95 7724.34 7677.19 9146.29 7796.14 7748.99 9238.86 7867.37 7820.22 38 41 N 74.70 W .23 1151.93N 3684.42W 39 56 N 74.68 W 1.33 1167.70N 3742.00W 40 15 N 71.97 W 1.89 1185.04N 3799.90W 40 37 N 71.13 W .70 1204.41N 3857.94W 38 45 N 70.15 W 2.13 1223.99N 3913.71W 3860.11 3919.79 3980.24 4041.40 4100.44 9331.79 7940.13 7892.98 9426.43 8014.81 7967.66 9521.32 8090.05 8042.90 9615.54 8165.04 8117.89 9710.15 8240.04 8192.89 38 10 N 71.41 W 1.04 1243.03N 3968.28W 37 37 N 72.85 W 1.11 1260.87N 4023.61W 37 27 N 74.56 W 1.11 1277.09N 4079.10W 37 4 N 74.21 W .47 1292.45N 4134.04W 38 2 N 74.64 W 1.06 1307.93N 4189.59W 4158.19 4216.31 4274.12 4331.16 4388.81 SPE .... ~.~-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE SHARED SERVICES DRILLING PBU / P2- 01 500292276100 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/ 6/97 DATE OF SURVEY: 050297 MWD SURVEY JOB NUMBER: AK-MM-70113 KELLY BUSHING ELEV. = 47.15 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9805.55 8315.41 8268.26 37 34 N 73.68 W .78 1323.89N 4245.85W 9898.42 8389.09 8341.94 37 24 N 76.26 W 1.70 1338.54N 4300.43W 9992.57 8464.29 8417.14 36 34 N 77.05 W 1.02 1351.62N 4355.55W 10085.11 8538.70 8491.55 36 22 N 74.10 W 1.91 1365.32N 4408.81W 10178.42 8613.98 8566.83 36 4 N 76.20 W 1.37 1379.45N 4462.10W 4447.28 4503.77 4560.32 4615.27 4670.36 10273.67 8691.36 8644.21 35 15 N 77.26 W 1.08 1392.20N 4516.14W 10367.88 8768.30 8721.15 35 14 N 75.41 W 1.13 1405.04N 4568.96W 10461.16 8844.52 8797.37 35 10 N 74.87 W .34 1418.83N 4620.94W 10556.76 8923.37 8876.22 33 41 N 73.89 W 1.65 1433.38N 4672.99W 10648.10 8999.50 8952.35 33 24 N 73.12 W .56 1447.71N 4721.38W 4725.78 4780.06 4833.80 4887.83 4938.31 10741.56 9077.57 9030.42 33 17 N 74.52 W .83 1462.02N 4770.72W 10835.01 9155.42 9108.27 33 51 N 74.09 W .65 1476.01N 4820.48W 10926.38 9231.18 9184.03 34 6 N 74.09 W .27 1490.01N 4869.60W 10974.00 9270.61 9223.46 34 6 N 74.09 W .04 1497.33N 4895.28W 4989.68 5041.36 5092.42 5119.12 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5119.16 FEET AT NORTH 72 DEG. 59 MIN. WEST AT MD = 10974 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 286.80 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 10,974.00' MD SPF" ~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU / P2- 01 500292276100 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/ 6/97 DATE OF SURVEY: 050297 JOB NUMBER: AK-MM-70113 KELLY BUSHING ELEV. = 47.15 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -47.15 .00 N .00 E 1000.00 999.15 952.00 1.52 N 23.94 W 2000.00 1998.00 1950.85 3.19 N 61.04 W 3000.00 2968.06 2920.91 77.25 N 244.71 W 4000.00 3809.80 3762.65 227.50 N 755.44 W .00 .85 .85 2.00 1.15 31.94 29.94 190.20 158.26 5000.00 4586.32 4539.17 410.75 N 1357.65 W 6000.00 5361.60 5314.45 606.15 N 1957.85 W 7000.00 6135.98 6088.83 796.23 N 2561.11 W 8000.00 6907.55 6860.40 990.14 N 3166.56 W 9000.00 7684.67 7637.52 1174.81 N 3767.96 W 413.68 223.48 638.40 224.72 864.02 225.62 1092.45 228.44 1315.33 222.88 10000.00 8470.25 8423.10 1352.62 N 4359.87 W 10974.00 9270.61 9223.46 1497.33 N 4895.28 W 1529.75 214.42 1703.39 173.64 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SP~ "Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU / P2- 01 500292276100 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/ 6/97 DATE OF SURVEY: 050297 JOB NUMBER: AK-MM-70113 KELLY BUSHING ELEV. = 47.15 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -47.15 47.15 47.15 .00 147.15 147.15 100.00 247.16 247.15 200.00 347.17 347.15 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .26 S .43 E .00 .00 .98 S 1.46 E .01 .01 2.27 S 2.35 E .02 .01 447.19 447.15 400.00 547.20 547.15 500.00 647.24 647.15 600.00 747.44 747.15 700.00 847.72 847.15 800.00 3.21 S 2.49 E 2.85 S 1.24 E 1.93 S 1.48 W .90 S 7.42 W .07 N 14.82 W .04 .01 .05 .01 .09 .O5 .29 .19 .57 .28 947.90 947.15 900.00 1048.09 1047.15 1000.00 1148.28 1147.15 1100.00 1248.50 1247.15 1200.00 1348.73 1347.15 1300.00 .95 N 20.77 W 2.01 N 26.88 W 2.86 N 33.04 W 3.68 N 39.52 W 4.27 N 46.26 W .75 .18 .94 .19 1.13 .19 1.35 .21 1.58 .23 1448.90 1447.15 1400.00 1549.01 1547.15 1500.00 1649.09 1647.15 1600.00 1749.12 1747.15 1700.00 1849.13 1847.15 1800.00 4.98 N 52.12 W 5.32 N 56.71 W 5.80 N 60.60 W 5.46 N 62.79 W 4.45 N 62.70 W 1.75 .18 1.86 .11 1.94 .08 1.97 .03 1.98 .01 1949.14 1947.15 1900.00 2049.15 2047.15 2000.00 2149.18 2147.15 2100.00 2249.37 2247.15 2200.00 2349.92 2347.15 2300.00 3.55 N 61.70 W 2.97 N 60.26 W 3.87 N 61.61 W 7.35 N 66.34 W 12.96 N 75.12 W 1.99 .01 2.00 .01 2.03 .03 2.22 .18 2.77 .55 2451.08 2447.15 2400.00 2552.94 2547.15 2500.00 2655.84 2647.15 2600.00 2760.83 2747.15 2700.00 2868.43 2847.15 2800.00 20.98 N 88.04 W 30.35 N 104.97 W 40.06 N 127.10 W 51.58 N 156.84 W 63.36 N 194.71 W 3.93 1.16 5.79 1.86 8.69 2.90 13.68 4.99 21.28 7.59 2977.26 2947.15 2900.00 3086.46 3047.15 3000.00 3197.27 3147.15 3100.00 3310.78 3247.15 3200.00 3427.09 3347.15 3300.00 74.86 N 236.09 W 87.93 N 277.95 W 102.87 N 323.27 W 120.40 N 373.99 W 138.88 N 430.41 W 30.11 8.83 39.31 9.20 50.12 10.81 63.63 13.51 79.94 16.31 'f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 7 SHARED SERVICES DRILLING PBU / P2- 01 500292276100 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/ 6/97 DATE OF SURVEY: 050297 JOB NUMBER: AK-MM-70113 KELLY BUSHING ELEV. = 47.15 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3544.81 3447.15 3400.00 3667.61 3547.15 3500.00 3793.92 3647.15 3600.00 3920.78 3747.15 3700.00 4047.33 3847.15 3800.00 154.59 N 490.45 W 170.93 N 559.79 W 191.16 N 634.24 W 213.11 N 709.15 W 236.40 N 783.12 W 97.66 17.72 120.47 22.81 146.77 26.31 173.63 26.86 200.18 26.55 4178.41 3947.15 3900.00 4311.33 4047.15 4000.00 4441.61 4147.15 4100.00 4568.99 4247.15 4200.00 4694.24 4347.15 4300.00 263.80 N 863.28 W 290.20 N 946.77 W 314.41 N 1026.68 W 336.25 N 1102.47 W 356.72 N 1175.05 W 231.26 31.07 264.18 32.93 294.46 30.28 321.84 27.37 347.09 25.25 4820.65 4447.15 4400.00 4949.67 4547.15 4500.00 5077.96 4647.15 4600.00 5204.95 4747.15 4700.00 5332.94 4847.15 4800.00 377.48 N 1249.53 W 401.68 N 1327.38 W 426.39 N 1403.83 W 452.38 N 1477.66 W 477.75 N 1553.39 W 373.50 26.41 402.52 29.02 430.81 28.29 457.80 26.99 485.79 27.98 5460.23 4947.15 4900.00 5588.24 5047.15 5000.00 5719.07 5147.15 5100.00 5850.32 5247.15 5200.00 5981.12 5347.15 5300.00 503.72 N 1627.74 W 529.17 N 1703.45 W 555.07 N 1783.74 W 579.79 N 1865.07 W 602.96 N 1946.14 W 513.08 27.29 541.09 28.01 571.92 30.83 603.17 31.24 633.97 30.81 6111.28 5447.15 5400.00 6241.74 5547.15 5500.00 6371.97 5647.15 5600.00 6501.77 5747.15 5700.00 6630.59 5847.15 5800.00 628.53 N 2025.41 W 653.94 N 2105.24 W 679.35 N 2184.70 W 703.11 N 2263.96 W 724.93 N 2342.18 W 664.13 30.16 694.59 30.46 724.82 30.23 754.62 29.80 783.44 28.82 6759.15 5947.15 5900.00 6886.69 6047.15 6000.00 7014.25 6147.15 6100.00 7142.06 6247.15 6200.00 7270.77 6347.15 6300.00 748.63 N 2419.40 W 774.35 N 2494.26 W 798.87 N 2569.56 W 822.74 N 2645.48 W 846.26 N 2723.02 W 812.00 28.56 839.54 27.54 867.10 27.56 894.91 27.81 923.62 28.71 7399.92 6447.15 6400.00 7530.63 6547.15 6500.00 7661.60 6647.15 6600.00 7791.13 6747.15 6700.00 7921.25 6847.15 6800.00 869.00 N 2801.54 892.92 N 2882.22 916.49 N 2963.44 943.74 N 3041.10 972.88 N 3119.08 W 952.77 29.16 W 983.48 30.70 W 1014.45 30.98 W 1043.98 29.53 W 1074.10 30.12 Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU / P2-01 500292276100 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/ 6/97 DATE OF SURVEY: 050297 JOB NUMBER: AK-MM-70113 KELLY BUSHING ELEV. = 47.15 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8050.99 6947.15 6900.00 1000.69 N 3196.90 W 1103.84 29.74 8180.58 7047.15 7000.00 1026.16 N 3275.27 W 1133.43 29.59 8309.64 7147.15 7100.00 1050.91 N 3353.00 W 1162.49 29.06 8437.53 7247.15 7200.00 1075.26 N 3428.91 W 1190.38 27.89 8565.92 7347.15 7300.00 1100.43 N 3505.39 W 1218.77 28.39 8694.21 7447.15 7400.00 1123.96 N 3582.23 W 1247.06 28.30 8822.24 7547.15 7500.00 1145.07 N 3659.33 W 1275.09 28.03 8951.06 7647.15 7600.00 1166.51 N 3737.66 W 1303.91 28.83 9081.84 7747.15 7700.00 1191.02 N 3818.26 W 1334.69 30.78 9212.93 7847.15 7800.00 1218.48 N 3898.44 W 1365.78 31.09 9340.71 7947.15 7900.00 1244.78 N 3973.51 W 1393.56 27.79 9467.25 8047.15 8000.00 1268.18 N 4047.43 W 1420.10 26.54 9593.12 8147.15 8100.00 1288.77 N 4121.04 W 1445.97 25.87 9719.18 8247.15 8200.00 1309.40 N 4194.95 W 1472.03 26.06 9845.60 8347.15 8300.00 1330.69 N 4269.30 W 1498.45 26.42 9971.23 8447.15 8400.00 1348.77 N 4343.16 W 1524.08 25.63 10095.61 8547.15 8500.00 1367.03 N 4414.80 W 1548.46 24.38 10219.46 8647.15 8600.00 1385.22 N 4485.56 W 1572.31 23.85 10341.98 8747.15 8700.00 1401.28 N 4554.50 W 1594.83 22.52 10464.37 8847.15 8800.00 1419.32 N 4622.72 W 1617.22 22.39 10585.34 8947.15 8900.00 1437.78 N 4688.22 W 1638.19 20.97 10705.17 9047.15 9000.00 1456.69 N 4751.47 W 1658.02 19.83 10825.05 9147.15 9100.00 1474.49 N 4815.15 W 1677.90 19.88 10945.67 9247.15 9200.00 1492.97 N - 4880.00 W 1698.52 20.61 10974.00 9270.61 9223.46 1497.33 N 4895.28 W 1703.39 4.88 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 18, 1997 Steve Shultz Senior Drilling engineer ARCO Alaska Inc. P O Box 196612 Anchorage, AK 9951-6612 Re; Point McInB, re P2-01 ARCO Alaska Inc. Permit No: 97-73 Sur. Loc.: 58'NSL, 4304'WEL, Sec. 1 I, TI2N, R14E. UM Btmhole Loc: 1533'NSL. 3894'WEL. Sec. 10. T12N. RI4E, UM Dear Mr. Shultz: Enclosed is the approvcd application for permit to drill thc above referenced well. The permit to drill docs not exempt you from obtaining additional permits rcquircd by law from other govemmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations arc made. Your request for a variance from diverter regulation 20 AAC 25.035 7(b) is approved. Blowout prevention equipment (BOPE) must bc tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE tcst performed before drilling below the surface casing shoe must be given so that a representative of thc Commission max' witness the test. Notice mav be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman ~ ) BY ORDER OF THE ISSION dllTcnclosures Department of' Fish & (3amc. I labitat Section w, o cnci. Department of Envinomment Conservation w,o encl. STATE OF ALASKA ALASKA ¢ AND GAS CONSERVATION COM PERMIT TO DRILL 20 AAC 25.005 3SION [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RTE = 45.4' Point Mclntyre 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 034622 ~ 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 58' NSL, 4304' WEL, SEC. 11, T12N, R14E Point Mclntyre At top of productive interval 8. Well Number Number U-630610 1417' NSL, 3516' WEL, SEC. 10, T12N, R14E P2-01 At total depth 9. Approximate spud date Amount $200,000.00 1533' NSL, 3894' WEL, SEC. 10, T12N, R14E 04/21/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028297, 1533'I P2-03, 20' @ 500'-1000' MD 2560 10923' MD / 9225' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.O35 (e) (2)} Kick Off Depth 600' Maximum Hole Anqle 35.5° Maximum surface 3520 psig, At total depth (TVD) 8800' / 4400 psig 18. Casing Program' Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 133# H40 Btc 80' 45' 45' 125' 125' Driven 12-1/4" 9-5/8" 40# L-80 Btc-Mod 5412' 44' 44' 5456' 4946' 1590 sx Coldset III, 422 sx 'G' 8-1/2" 7" 26# L-80 Btcm/NSCC 9937' 43' 43' 9980' 8487' 294 sx Class 'G' 8-1/2" 7" 29# 13CR Btcm/NSCC 943' 9980' 8487' 10923' 9225' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate '~/~ ~i~F 7 Production '?~ ''~ ~ Liner ~'-; h_~ ~ ~ APR ]997 Perforation depth: measured0RI01 ,IAL4lasEaO'l.&GasCor~s.¢oramiss,o, true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Greg HobOs, 564-4191 Prepared By Name/Number: KathyCarnpoamor, 564-5122 ?' ' ' (i~ my knowledge 21.1 hereby certify that theatergoing is(tl}~( and rrect to the best of Signed .~-~..-- ~-~\ ~ .-~-'R---~ Steve ShCt~ /,.. '~k.A.'..~.;k.. <. % ¥¥-'-~..," ~ Title Senior Drilling Engineer Date "Commission Use Only Permit Number I APl Number Approval Date I See cover letter q7 -7 --%I 50- oA~l-lA7(~l ~--/~"'/~'-/t¢I for other requirements Conditions of Approval: Samples Required [] ,Yes ~ No Mud Log Required [] Yes,[~ No Hydrogen Sulfide Measures J~Yes [] No Directional Survey Required ,J~ Yes [] No [] [] [] [] [] Required Working Pressure for DOPE 2M; SM; ,K 5M; by o~l(~;of 15M !Approved By Other: 0rigJllal Si,~rh;c Commissioner the commission Date Form 10-401 Rev. 12-01-85 David W. J0hnstor. Submit STATE OF ALASKA · ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Dril~ [] Redrill I1 b. Type of well [] Exploratory [] Stral~i~raphic T~st [] Development Oil [] Re-Entry [] DeepenI []Service [] Dev.elopment Gas ..["iSincjle Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, [nc. Plan RTE -- 45.4' Point Mclntyre 3. Address :6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 034622 4~ Location of well' at surface " 7. Unit or'~roperty Name : 11. T'ype Bond (See 20 MC 25.02~) 58' NSL, 4304' WEL, SEC. 11, T12N, R14E Point Mclntyre At top of productive interval 81 Well Number Number U-630610 1417' NSL, 3516' WEL, SEC. 10, T12N, R14E P2-01 Attotal depth 9. ApProximate'spud date Amount $200,000.00 1533' NSL, 3894' WEL, SEC. 10, T12N, R14E 04/21/97 12~ Distance to nearest proi~rty line113. 'Distance t~'nearest well 4, N~mber of acres in property 15. Proposed depth (SO and TVD)' ADL028297, 1~i~3'I P2:03, 20' @ 5Q0'-1000' MD_ 2560 10923' MD / 9225' TVD 16. To be completed for deviated wells 17. Anticipated pressure I:s~ ~o ,~Ac 25.o~, (e)(2)) Kick Off Depth 600' Maximum Hole Anqle as.s°, Maximum surface 3520 psig, At total depth (TVD) 8800' / 4400 pslg 18. Casing Program Setting Depth Size Specifications Tol~ Bottom Quantity of Cement Hole Casing weigl~t Grade Coupling .Ler~gth MD TVI~ MD TVD (Include stage_d, ata) 30" 20" 133# H40 Btc 80' 4~i' 45' 125' 125' Driven 12-1/4" 9-5/8" 40# L-80 Btc-Mod' 5412' 44' 44' 545(j' 4946' 1590 Sx C~ldset III, 4'22 sx 'G~ 8~1/2" 7" 26# L-80 Btcm/NSCC 9937' 43' 43' 9980' 8487' ~94 sx Class 'G' 8-1/2" 7" 29# 13CR Btcm/NSCC 943' 9980~ 8487' 10923' 92-~5' ~. · Present well condition summary Total depth: measured feet Plugs (measured)8 99T true vertical feet Effective depth: measured feet Junk (measured) Ala$.~ Cj~ _& Gas .Carls, true vertical feet , ~rt.~o_~_8.[].~ '.~' ' Casing Length Size Cemented MD 'I'VD 'Structural Conductor Surface Intermediate Production Liner DU?! "CATE Perforation depth: measured true vertical -- , 20. Attachments [] Filing ~ee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Ddllfng Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Conta~i Engineer Name/Number: Grog H~bCls, 564-4191 Prepared l~y Name/Number: Kathy. Oampoamor, 564-5122 21' ' h;rebY certifYsigned v.s. thai the (f~r~g°ing¢~- is(t r~and l(i°rrect t° thex.,,~ ~..-~ best of rays -kn°Wledge'l - · ste ~llz ~/'t.. ~kJc. X.A,.'.<, ~ ~,,,~ X,__. Title enior uri~ lng h_ngineer Date '~. ~ Commission Use only f' / Permit Numbe~ ] APl Number I Approval.~t__e i See cover lottor O[ '7- -~ "~ 50- C) ~1, ~1 - p~., ~ '7 6 I _,~ ~'// ~;7 ~ for other requirements ..... i Condition~rr'A~roval: ~ Re~¢"~'~ [~] Y~_es ,~ No Mud Log Required [] Yes¢~ ,No ~' .~ydro -S~e'S'-% I~Y~s ID No Directional Survey Required ,j~ Yes [] iai -'-'---~....._.__~~~l}i~ure for~OPE 2~; ...... 3M; X 5M; by o~oO~;of 15M roved B ~--,. -.._ ' . the commission Date PP y Commissioner _ Form 10-401 Rev. 12-01-85 .......... ~ ., _ . __ ~ ~'.~_ _. _-- l-f_~ ~ .................. ~___ _~1_,_ ~-_~ ~. ~ ~, ............................................................ .................... ........................ ~ .................................... .......... ~ ........ ~ .... ~~ ....... ~ ....... ~~ . __~__~ .... ~'.~.~ .... ~ ~...~ .... ~...~.~ ........................................................................................................................................................................... ...... - .... ~._~, . . ~... ~_~.~ .... -. .~~ ...... _~_~ ...... x~ ......... ~~.~ ) ..................................... ......................................................................................................................................................... ........................................................................................................................... TONY KNOWLE$, GOVERNOR ~kLASKA OIL AND CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99§01-319Z PHONE: (907) 278-1433 FAX: (907) 276-7542 April 18, 1997 Steve Shultz Senior Drilling engineer ARCO Alaska Inc. P O Box 196612 Anchorage, AK 9951-6612 Re' Point McIntyre P2-01 ARCO Alaska Inc. Permit No: 97-73 Sur. Loc.: 58'NSL, 4304'WEL, Sec. 11, TI2N, R14E, UM BtmhoIe Loc: 1533'NSL, 3894'WEL, Sec. 10, T12N, RI4E, UM Dear Mr. Shultz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Your request for a variance from diverter regulation 20 AAC 25.035 7(b) is approved. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman ~...~ ) dlf/en¢losu~es cc: Department offish & Game, IIabitat Section w/o encl. Department of Enviuommeut Conservation w/o encl. I Well Name: I P2-01 Type of Well (producer or injector): [Producer Surface Location: 58' FSL, 4304' FEL, SEC 11, T12N, R14E Target Location: 1417' FSL, 3516' FEL, SEC 10, T12N, R14E Bottom Hole Location: 1533' FSL, 3894' FEL, SEC 10, T12N, R14E I AFE Number: ] 2B0206 ling: [DOYON 14 I Estimated Start Date: 15/21/97 I [Days to complete 116 ]MD: 110923' I I~VD= 19225' brt [ l RTE= 145.4 Well Design (conventional, slimhole, etc.): I Ultra-Slimhole 7" Longstring [ Formation Markers: Formation Tops MD TVD(rkb) Base of Permafrost 1783 1781 ~ SV1 (T3) 5085 4656 9 5/8" Casing Point 5456 4946 9-5/8" csg shoe below SV 1 & above K-15 K15 (Ugnu) 5647 5096 West Sak 7915 6871 9.5 ppg minimum mud weight required K-10 9868 8399 HRZ 10104 8584 K-5/HRZ same depth, 10.0 ppg Min EMW Kalubik 10238 8689 Kupamk 10288 8728 10.0 ppg Min EMW OWC 10783 9115 TD 10923 9225 7" casing shoe. 140' MD below OWC. Miluveach 9280 Hole ~ize C~g/Tb~ Wt/Ft Grade Conn Length Top Btm O.D. MD/TVD MD/TVD 30" 20" 133# H40 BTC 80' 45/45' 125 '/125' 12 1/4" 9 5/8" 40# L-80 BTC-Mod 5412' 44/44' 5456'/4946' 8 1/2" 7" 26# L-80/ BTCM / NSCC 9937' 43/43' 9980'/8487' 29# 13CR 943' 9980'/8487' 10923'/9225' Tubing 4 1/2" 12.6# 13CR80 NSCT 10146' 42'/42' 10188'/8650' Mud Program: Casing/Tubing Program: Surface Mud Properties: Spud Density (ppg) ~unnel Vis I Yield Point 8.7-9.5 ! 100-300I 30-70 ] 12 1/4" hole section I 10 sec gel 10 rain gel 20-60 40-80 pH I Fluid Loss 9-10 15 - 25cc Production Mud Properties: LSND [ 8 1/2" hole section Density (ppg) [Plastic Vis Yield Point 10 sec gel 10 rain gel 8.8-10.0 I 8-15 20-30 5-15 < 30 pH 9.0-9.5 Fluid Loss 6-12cc Production Mud Properties: 3 % KCL Denslty (ppg) I Plastic Vis ] Yield Point 10.0- 10.3 8-15 25-30 ] 8-1/2" hole section I lO sec gel 12-15 10 min gel I pH Fluid Loss < 30I 9.0-9.5 4-6cc Cement Data: Casing First Stage: Second Stage: Comments Sxs/Wt/Yield Sxs/Wt/Yield 9-5/8" surface Coldset III: 979/12.2/1.92 Two stage job: casing 611/12.2/1.92 (assumes 200% First stage Coldset III lead to 699(¢-~t~'6-~ excess in permafrost) from 2000'-4495' @ 50% ES cementer Class G: excess followed by Class G @ at .t800' 422/15.8/1.15 tail from shoe to 4495' (750' MD. '?~ o o o ° _ TVD) @ 50% excess + 80' ¢~ t (? :'~ , ~ shoe. Second stage Coldset III circulated to surface. Casing/Liner Lead:Sxs/Wt/Yield Tail: Sxs/Wt~ield Comments 7" none 294/15.8/1.14 Class "G". Volume based on cement to 1000' above the Kupamk with 50% excess + 80' shoe. Logging Program: I Open Hole Logs: 12 1/4" MWD Directional only 8 1/2" MWD DIR/GR to TD Openhole Wireline GR/RES/DEN/NEUT ICased Hole Logs: None Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics on file with AOGCC. Waiver for Diverter System requested from State (dated 4/14/97). Directional: KOP: 600' MD Maximum Hole Angle: Close Approach Wells: 38.50 degrees P2-03 (danger interval at 500-1000'MD) (20' from ellipses) Drilling and Completion Scope 1. Move rig to P2-01. NU riser, diverter, and flowlines, j , 3. 4. 5. 6. 7. 8. 9. Directionally drill 12 1/4" surface hole to -5470' MD. Run and cement 9 5/8" casing. Cement to surface. Drill 8-1/2" production hole with LWD DIR/GR to top of K-10 at 9868' MD. Change over mud system to 3 % KCL. Drill 8-1/2" production hole with MWD DIR/GR/RES/DEN/NEU to TD at 10923' MD. Run and cement 7" L-80/13CR casing. Run 4-1/2" 13CR production tubing with 7"x4-1/2" packer, 4-1/2" SSSV, and 4-1/2"xl" GLMs. Secure well, RDMO. Drilling Hazards/Contingencies · The original reservoir pressure is 4350 psi at 8800' ss. The expected reservoir pressure is 4400 psi at 8800' ss. · History indicates tight spots in the surface hole that have been worked through without much incident, but should be noted. · Tight hole has been experienced in the lower Sagavanirktok, below the surface casing shoe which were set into the SV4 sand. This has caused stuck pipe incidents and bit/BHA balling Gumbo problems. · Coal stringers in the lower Ugnu have caused stuck pipe. · No major instances of lost circulation problems have occured on Pt Mac 2 wells. · If formation problems occur above the Kupamk Interval, 7" casing will top-set the Kupamk, and the pay will be drilled out with 6" hole and completed with a 4.5" liner. · The Pad data sheet does not indicate significant problems in the area. Disposal · Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. '/ · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. In addition, haul all cuttings from drilling operations to CC-2A for disposal, except any metal cuttings which will be sent to the North Slope Borough. GH 4/11/97 BP EXPLOR.~iON 1o: B. Wondzell Date: April 14, 1997 From: G. Hobbs Subject: Dispensation for 20 AAC 25.035 (7)(b)(3) for the 1997 P2 Program Shared Services Drilling requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (7)(b)(3) "Secondary Well Control: Blowout Prevention Equipment (B OPE) Requirements" based upon experience on Point Mclntyre 1 and 2 drilling projects. None of the 19 wells drilled on pad 1 or the 36 wells (including current well P2-13) on pad 2 at Point Mclntyre have experienced any difficulty with shallow gas in intervals prior to placement of surface casing. This historical evidence indicates a minimal risk from shallow gas for future wells drilled at the pad 2 area. With this history, we have concluded that the remainder of the 1997/98 Point Mclntyre pad 2 drilling program will have similar surface hole section as those that have been drilled previously. Therefore, based on the above assumptions, a diverter system does not seem necessary and request your consideration of a waiver for it. Sincerely, SSD Engineer P2-01 [Wp3] Vertical Section RKB 287.03 46.20 MD Inc. Azi. TVDss TVDrkb 0.00 0.00 0.00 0.O0 0.00 0.00 1.00 2.00 3.00 4.00 4.00 4.00 4.00 4.00 4.00 3.00 2.00 1 .O0 0.17 0.00 0.00 0.00 0.00 0.00 2.50 5.00 7.50 10.00 12.50 15.00 17.50 20.00 22.50 25.00 27.50 30.00 32.50 35.00 37.50 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1783.07 1800.00 1900.00 2000.00 2100.00 2102.00 2202.00 2302.0O 2402.00 2502.00 2602.00 2702.00 2802.00 2902.00 3002.00 3102.00 3202.00 3302.00 3402.00 3502.OO 3602.00 270.00 270.00 270.00 270.00 270.00 270.00 270.00 270.00 270.00 270.00 270.00 270.00 270.00 270.00 270.00 270.00 270.00 270.00 270.00 270.00 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 -46.20 53.80 153.80 253.80 353.80 453.80 553.79 653.76 753.66 853.48 953.23 1052.99 1152.74 1252.50 1352.26 1452.07 1551.97 1651.94 1735.00 1751.93 1851.93 1951.93 2051.93 2053.93 2153.90 2253.68 2353,08 2451.90 2549.98 2647.10 2743.10 2837.78 2930.98 3022.50 3112.18 3199.85 3285.33 3368.47 3449.11 0.00 100.00 200.00 300.00 400.00 500.00 599.99 699.96 799.86 899.68 999.43 1099.19 1198.94 1298.70 1398.46 1498.27 1598.17 1698.14 1781.20 1798.13 1898.13 1998.13 2098.13 2100.13 2200.10 2299.88 2399.28 2498.10 2596.18 2693.30 2789.30 2883.98 2977.18 3068.70 3158.38 3246.05 3331.53 3414.67 3495.31 Rect. Coordinates No~hlng 0.00n 0.00n 0.00n 0.00n 0.00n 0.00n 0.00s 0.00s 0.00s 0.00s 0.00s 0.00s 0.00s 0.00s 0.00s 0.00s 0.00s 0.00s 0.00s 0.00s 0.00s 0.00s 0.00s 0.00s 0.64n 2.55n 5.74n 10.19n 15.91n 22.86n 31.06n 40.47n 51.08n 62.87n 75.82n 89.90n 105.09n 121.35n 138.67n Eastlng 0.00e 0.00e 0.00e 0.00e 0.00e 0.00e 0.87w 3.49w 7.85w 13.96w 20.93w 27.91w 34.88w 41.86w 48.84w 54.94w 59.30w 61.92w 62.77w 62.79w 62.79w 62.79w 62.79w 62.79w 64.88w 71.13w 81.54w 96.08w 114.74w 137.46w 164.22w 194.95w 229.60w 268.11w 310.40w 356.38w 405.98w 459.10w 515.64w Grid Coordinates Easting 681210.34 681210.34 681210.34 681210.34 681210.34 681210.34 681209.47 681206.85 681202.49 681196.39 681189.41 681182.44 681175.47 681168.49 681161.52 681155.42 681151.06 681148.44 681147.59 681147.57 681147.57 681147.57 681147.57 681147.57 681145.47 681139.17 681128.69 681114.05 681095.27 681072.39 681045.45 681014.51 680979.62 680940.85 680898.28 680851.98 680802.04 680748.56 680691.64 No~hlng 5998633.38 5998633.38 5998633.38 5998633.38 5998633.38 5998633.38 5998633.36 5998633.30 5998633.20 5998633.05 5998632.89 5998632,73 5998632.56 5998632.40 5998632.24 5998632.09 5998631.99 5998631.93 5998631.91 5998631.91 5998631.91 5998631.91 5998631.91 5998631.91 5998632.50 5998634.27 5998637.21 5998641.32 5998646.60 5998653.02 5998660.59 5998669.27 5998679.07 5998689.96 5998701.91 5998714.91 5998728.94 5998743.95 5998759.94 DLS deg/100ft 0.00 0.00 0.00 0.00 0.00 0.00 1.00 1.00 1.00 1.00 0.00 0.00 0.00 0.00 0.00 1.00 1.00 1.00 1.00 1.00 0.00 0.00 0.00 0.00 2.50 2.50 2.50 2.50 2.50 2.50 2.50 2.50 2.50 2.50 2.50 2.50 2.50 2.50 2.50 Ve~lcal Section Comment 0.00 0.00 0.00 0.00 0.00 0.00 0.83 3.34 7.51 13.35 20.02 26.69 33.36 40.03 46.70 52.53 56.70 59.21 60.02 Base Permafrost:1783'MD 60.04 60.04 60.04 60.04 60.04 62.22 68.76 79.65 94.86 114.37 138.13 166.11 198.25 234.50 274.77 318.99 367.09 418.96 474.51 533.64 4/8/97 10:44 AM Page 1 of 4 P2-01 [Wp3] Vertical Section RKB 287.03 46.20 MD Inc. Azi. TVDss TVDrkb 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 38.50 3641.97 3700.00 3800.00 3900.00 4000.00 4100.00 4200.00 4300.00 4400.00 4500.00 4600,00 4700.00 4800.00 4900.00 5000.00 5085.07 5100.00 5200.00 5300.00 5400.00 5455.62 5500.00 5600.00 5647.29 5700.00 5800.00 5900.00 6000.00 6100.00 6200.00 6300.00 6400.00 6500.00 6600.00 6700.00 6800.00 6900.00 7000.00 7100.00 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 287.03 3480.61 3526.02 3604.28 3682.55 3760.81 3839.07 3917,33 3995.59 4073.85 4152.12 4230.38 4308.64 4386.90 4465.16 4543.42 4610.00 4621.68 4699.95 4778.21 4856.47 4900.00 4934.73 5012.99 5050.00 5091.25 5169.52 5247.78 5326.04 5404.30 5482.56 5560.82 5639.09 5717.35 5795.61 5873.87 5952.13 6030.39 6108.65 6186.92 3526.81 3572.22 3650.48 3728.75 3807.01 3885.27 3963.53 4041,79 4120.05 4198.32 4276.58 4354.84 4433.10 4511.36 4589.62 4656.20 4667.88 4746.15 4824.41 4902.67 4946.20 4980.93 5059.19 5096.20 5137.45 5215.72 5293.98 5372.24 5450.50 5528.76 5607.02 5685.29 5763.55 5841.81 5920.07 5998.33 6076.59 6154.85 6233.12 Rect. Coordinates Northlng 145.87n 156.45n 174.67n 192.90n 211.13n 229.35n 247.58n 265.80n 284.03n 302.26n 320.48n 338.71n 356.94n 375.16n 393.39n 408.89n 411.62n 429.84n 448.07n 466.29n 476.43n 484.52n 502.75n 511.37n 520.97n 539.20n 557.43n 575.65n 593.88n 612.10n 630.33n 648.56n 666.78n 685.01n 703.24n 721.46n 739.69n 757.91n 776.14n Eastlng 539.17W 573.71W 633.23W 692.75W 752.27W 811.80W 871.32W 930.84W 990.36W 1049.89W 1109.41W 1168.93W 1228.45W 1287.98W 1347.50W 1398.13W 1407.02W 1466.54W 1526.07W 1585.59W 1618.70W 1645.11W 1704.63W 1732.78W 1764.16W 1823.68W 1883.20W 1942.72W 2002.25W 2061.77W 2121.29W 2180.81W 2240.34W 2299.86W 2359.38W 2418.90W 2478.43W 2537.95W 2597.47W Grid Coordinates Eastlng 680667.95 680633.17 680573.24 680513.31 680453.38 680393.46 680333.53 680273.60 680213.67 680153.74 680093.81 680033.88 679973.96 679914.03 679854.10 679803.12 679794.17 679734.24 679674.31 679614.39 679581.05 679554.46 679494.53 679466.19 679434.60 679374.67 679314.74 679254.81 679194.89 679134.96 679075.03 679015.10 678955.17 678895.24 678835.31 678775.39 678715.46 678655.53 678595.60 No~hlng 5998766.59 5998776.35 5998793.18 5998810.01 5998826.84 5998843.67 5998860.49 5998877.32 5998894.15 5998910.98 5998927.81 5998944.63 5998961.46 5998978.29 5998995.12 5999009.43 5999011.95 5999028.77 5999045.60 5999062.43 5999071.79 5999079.26 5999096.08 5999104.04 5999112.91 5999129.74 5999146.57 5999163.40 5999180.22 5999197.05 5999213.88 5999230.71 5999247.54 5999264.36 5999281.19 5999298.02 5999314.85 5999331.68 5999348.50 DLS deg/100ft 2.50 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Ve~ical Section 558.25 594.37 656.62 718.87 781.12 843.37 905.62 967.87 1030.12 1092.38 1154.63 1216.88 1279.13 1341.38 1403.63 1456.58 1465.88 1528.13 1590.38 1652.63 1687.25 1714.88 1777.13 1806.57 1839.38 1901.63 1963.88 2026.13 2088.38 2150.63 2212.88 2275.13 2337.38 2399.64 2461.89 2524.14 2586.39 2648.64 2710.89 Comment T-3 (SV1): 5085'MD 9 5/8" CASING K-15: 5647'MD 4/8/97 10:44 AM Page 2 of 4 P2-01 [Wp3] Vertical Section RKB 287.O3 46.20 MD Inc. Azi. TVDss TVDrkb Rect. Coordinates Northlng Easting 7200.00 38.50 287.03 6265.18 6311.38 794.37n 2656.99w 7300.00 38.50 287.03 6343.44 6389.64 812.59n 2716.52w 7400.00 38.50 287.03 6421.70 6467.90 830.82n 2776.04w 7500.00 38.50 287.03 6499.96 6546.16 849.05n 2835.56w 7600.00 38.50 287.03 6578.22 6624.42 867.27n 2895.08w 7700.00 38.50 287.03 6656.49 6702.69 885.50n 2954.61w 7800.00 38.50 287.03 6734.75 6780.95 903.73n 3014.13w 7900.00 38.50 287.03 6813.01 6859.21 921.95n 3073.65w 7915.32 38.50 287.03 6825.00 6871.20 924.74n 3082.77w 8000.00 38.50 287.03 6891.27 6937.47 940.18n 3133.17w 8100.00 38.50 287.03 6969.53 7015.73 958.40n 3192.70w 8200.00 38.50 287.03 7047.79 7093.99 976.63n 3252.22w 8300.00 38.50 287.03 7126.06 7172.26 994.86n 3311.74w 8400.00 38.50 287.03 7204.32 7250.52 1013.08n 3371.26w 8500.00 38.50 287.03 7282.58 7328.78 1031.31n 3430.79w 8600.00 38.50 287.03 7360.84 7407.04 1049.54n 3490.31w 8700.00 38.50 287.03 7439.10 7485.30 1067.76n 3549.83w 8800.00 38.50 287.03 7517.36 7563.56 1085.99n 3609.35w 8900.00 38.50 287.03 7595.63 7641.83 1104.21n 3668.88w 9000.00 38.50 287.03 7673.89 7720.09 1122.44n 3728.40w 9100.00 38.50 287.03 7752.15 7798.35 1140.67n 3787.92w 9200.00 38.50 287.03 7830.41 7876.61 1158.89n 3847.44w 9300.00 38.50 287.03 7908.67 7954.87 1177.12n 3906.97w 9400.00 38.50 287.03 7986.93 8033.13 1195.35n 3966.49w 9500.00 38.50 287.03 8065.19 8111.39 1213.57n 4026.01w 9600.00 38.50 287.03 8143.46 8189.66 1231.80n 4085.53w 9700.00 38.50 287.03 8221.72 8267.92 1250.03n 4145.06w 9800.00 38.50 287.03 8299.98 8346.18 1268.25n 4204.58w 9867.75 38.50 287.03 8353.00 8399.20 1280.60n 4244.90w 9900.00 38.50 287.03 8378.24 8424.44 1286.48n 4264.10w 10000.00 38.50 287.03 8456.50 8502.70 1304.70n 4323.62w 10100.00 38.50 287.03 8534.76 8580.96 1322.93n 4383.15w 10104.13 38.50 287.03 8538.00 8584.20 1323.68n 4385.61w 10200.00 38.50 287.03 8613.03 8659.23 1341.16n 4442.67w 10238.30 38.50 287.03 8643.00 8689.20 1348.14n 4465.46w 10288.13 38.50 287.03 8682.00 8728.20 1357.22n 4495.13w 10300.00 38.50 287.03 8691.29 8737.49 1359.38n 4502.19w 10400.00 38.50 287.03 8769.55 8815.75 1377.61n 4561.71w 10500.00 38.50 287.03 8847.81 8894.01 1395.84n 4621.24w Grid Coordinates Easting 678535.67 678475.74 678415.81 678355.89 678295.96 678236.03 678176.10 678116.17 678106.99 678056.24 677996.32 677936.39 677876.46 677816.53 677756.60 677696.67 677636.74 677576.82 677516.89 677456.96 677397.03 677337.10 677277.17 677217.24 677157.32 677097.39 677037.46 676977.53 676936.93 676917.60 676857.67 676797.75 676795.27 676737.82 676714.86 676685.00 676677.89 676617.96 676558.03 Northing 5999365.33 5999382.16 5999398.99 5999415.82 5999432.64 5999449.47 5999466.30 5999483.13 5999485.71 5999499.95 5999516.78 5999533.61 5999550.44 5999567.27 5999584.09 5999600.92 5999617.75 5999634.58 5999651.41 5999668.23 5999685.06 5999701.89 5999718.72 5999735.55 5999752.37 5999769.20 5999786.03 5999802.86 5999814.26 5999819.69 5999836.51 5999853.34 5999854.04 5999870.17 5999876.61 5999885.00 5999887.00 5999903.82 5999920.65 DLS deg/100ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0,00 0.00 0.00 0.00 0.00 0,00 0,00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Vertical Section 2773.14 2835.39 2897.64 2959.89 3022.14 3084.39 3146.64 3208.89 3218.43 3271.14 3333.39 3395.64 3457.89 3520.14 3582.39 3644.65 3706.90 3769.15 3831.40 3893.65 3955.90 4018.15 4080.40 4142.65 4204.90 4267.15 4329.40 4391.65 4433.82 4453.90 4516.15 4578.40 4580.98 4640.65 4664.50 4695.52 4702.90 4765.15 4827.40 Comment WEST SAK: 7915'MD K-10: 9868'MD HRZ: 10104'MD KALUBIK: 10238'MD KUPARUK, TARGET: 10288 4/8/97 10:44 AM Page 3 of 4 P2-01 [Wp3] Vertical Section 287.03 RKB 46.20 MD Inc. Azi. TVDss TVDrkb Rect. Coordinates Grid Coordinates DLS Vertical Northlng Eastlng Eastlng Northing deg/100ft Section Comment 10600.00 38.50 287.03 8926.07 8972.27 1414.06n 4680.76w 676498.10 5999937.48 0.00 4889.66 10700.00 38.50 287.03 9004.33 9050.53 1432.29n 4740.28w 676438.17 5999954.31 0.00 4951.91 10782.63 38.50 287.03 9069.00 9115.20 1447.35n 4789.46w 676388.66 5999968.21 0.00 5003.34 WOC: 10783'MD 10800.00 38.50 287.03 9082.60 9128.80 1450.51 n 4799.80w 676378.25 5999971.14 0.00 5014.16 10900.00 38.50 287.03 9160.86 9207.06 1468.74n 4859.33w 676318.32 5999987.96 0.00 5076.41 10922.63 38.50 287.03 9178.57 9224.77 1472.87n 4872.80w 676304.76 5999991.77 0.00 5090.49 TD 7" CASING: 10923'MD 4/8/97 10:44 AM Page 4 of 4 APR 18 ~97 03:BSPM BP EXPLORATIOM P,1 Shared Services Drilling1 [~-truclure; Pi Mae-2 Well: P2-Oi ~ Field: Point Ivlac I.o~atlon: Alaska i WELL PROFILE DATA T;,eon 0 O,Oa~70.00 O a ~LarlOlr l/l~ 1400 4.00~TO,no {o~D -o -49 o.oo ~A~o~ 1Boo 0,~0~TO.OD 179~ -0 -~3 ~ ~B 107~ ~B,~O~87,D3 9115 1t~7 -~8~ O:OD o , , u 800 (" 1600 rn 2,~oo (D 32oo >. 4000 ~ 4800 II -800 .............................................................. ! I I I P I [ 0 / ' ...... ~ ...... 4 .........4' ........ '* ........ I- ........ I I I L~ i ~.0, i ] i ........ ~ ........~ ........ I I I t I ..~___~ ....... q ........ q ........ + ........ ~ ........ V 56oo ........ ? ....... ~ 8400 - 7200 - 8O0O -800 0 800 1600 2400 3200 4000 4800 weflpoth --] e~.-Ol t'v~3l _~. WELL DATA p~.~B ~2-01 P2-01 Ancj~e inc. 2.~?,03 Azi, I Surface Location I x: 681210,54 I Y: 599863.3,38 L RKB: 46.2 6500 - ,, ~ 7000 - ~ 75oo ~ 8000 t- 8500 II v 9000 - 9500 3500 4000 4500 5000 5500 Shared Services Drillin Structure- PI k~ac 2 Well · P2-01 Field ' Po~nf Mac Location ' Alaska l WELL DATA -- svy/prop .... stat .... well p268 P2-O t P2--OI .... well pr.l Ih ---- P2--O! [WP.I] soo, · oo.oo E o s f - > TARGEI DATA 1028D 3B.55 21~7.03 ~:8 1.~,7 ~ 'r..l,,~O~l. mml 675605.01]. 5~tggSBS.EK] -5500 -5000 -4500 -4000 -3500 -3000 -2500 --2OD0 --1500 -1000 --500 0 500 1000 1500 o o A II -500 - -lO00- -- -. 1500 2500 1 . ~ I I 1. I I I i I ! I i ! t_ .I I L I I I ,I ! ~i __1 ,I I I 2500 / i i I I I I I I I I / I I I I ~ I 1 I I I -~ I I I I I & I i I I I I I i I I I ~ I I I I I / II ! I · ! I I I I ! I / I , i I i I i i I i i 2000 -* ...................... ~ ................. ~ ........................................................ k .............. 2000 I i t I I I t I I I I I I I I I I i I I J I I ~ I I ~ I I i I i I ~ I I I I I / i "-,-~z / i ._'~ I.~ - i I i I r , I d I / [ I I I [ I I I I I I I / I I ~ I~ ~'I I I I I i I I I I I I I I ~1 I I I I I i I j I I ) I ~ I ! t I I I I I I / , I I ; ~ I , , , .... . / I I I I I I ~ I I I I i 500 I I I I I I I ~ ,,~ I I I I I 1 ' I I I I I I I I I I t ~ I I I I I I I ~ , ......... ' .................................................... F ......~ ........ ' ...................... ' ....... ~ ........ i - -500 -- 1000 ,, -1500 -5500 -5000 -4500 -4000 -3500 -3000 -2500 --2000 -1500 -1000 -500 0 500 1000 1500 Scale I ' 500.00 East -> A 'Il Z 0 WELL PERMIT CHECKLISToo. Y ;% \% ¢ 0 PROGRAM: expD der ~ redrlD serv~ wellbore seg~ ann disp para req~ ADMINISTRATION 1. Permit fee attached ................... ~N 2. Lease number appropriate ............... ~.~N 3. Unique well name and number .............. ~N 4. Well located in a defined pool ............. .Y~,) N 5. Well located proper distance from drlg unit boundary..~ N 6. Well located proper distance from other wells ..... ~ N 7. Sufficient acreage available in drilling unit ..... ~ N 8. If deviated, is wellbore plat included ........ ~ N 9. Operator only affected party .............. ~ N 10. Operator has appropriate bond in force ......... ~ N 11. Permit can be issued without conservation order ..... ~ N 12. Permit can be issued without administrative approval..~ N 13. Can permit be approved before 15-day wait ....... ~ N ENGINEERING REMARKS APPR D~TE 14. Conductor string provided ............... ~Y~ N 15. Surface casing protects all known USDWs ........ .--~ N 16. CMT vol adequate to circulate on conductor & surf cng. N 17. CMT vol adequate to tie-in long string to surf cng . . . 18. CMT will cover all known productive horizons ...... ~ N N 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. ~/ N _~h 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed ......... .~ N ~~~,~ ~ ~~ ~/~~ 23. If diverter required, is it adequate .......... N · 24. Drilling fluid program schematic& equip list adequate 25. BOPEs adequate .............. _ ....... ~ N 26. BOPE press rating adequate; test to ~O~ psig.~ N 27. Choke manifold complies w/API RP-53 (Ma~ 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ -~V N GEOLOGY DATE 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis of shallow gas zones .......... Y 33. Seabed condition survey (if off-shore) ......... Y 34. Contact name/phone for weekly progress reports ..... Y [exploratory only] GEOLO~Y :._ ENGINEERING: COMMISSION: RPC~ ~//~ mcm~ Comments/Instructions: ..q Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Mon Jul 28 13:44:59 1997 Reel Header Service name ............. LISTPE Date ..................... 97/07/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 97/07/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER PT. McINTYRE MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 4 AK-MM-70113 T. MCGUIRE K. WHITE Date P2-01 500292276100 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 28-JUL-97 11 12N 14E 58 4304 47.10 45.80 11.70 RECEIVED JUL 30 1991 OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT'SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.625 5473.0 8.500 10975.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ANNULAR & CRITICAL VELOCITIES CALCULATED USING THE POWER LAW HYDRAULICS MODEL. 3. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 4. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR/SGRC) AND IS NOT PRESENTED DUE TO LOSS OF LOGGING DATA. 5. MWD RUN 4 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR/SGRC) . 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10,975'MD, 9272'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 5497.0 10935.0 ROP 5530.5 10967.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 5497.0 5511.5 9608.0 9622.5 9610.0 9623.5 9910.0 9921.0 9934.5 9947.0 9944.5 9956.0 9969.5 9980.5 10091.5 10111.0 10099.5 10114.5 10106.5 10118.0 EQUIVALENT UNSHIFTED DEPTH 10200.0 10211.0 10206.5 10217.5 10211.0 10222.5 10213.5 10224.0 10215.0 10225.5 10216.5 10227.0 10219 . 0 10229.5 10221.0 10231.5 10226.0 10236.5 10230.0 10241.0 10235.5 10246.5 10242.0 10252.5 10246.5 10256.0 10249 . 5 10260.0 10255.0 10266.0 10257.0 10268.5 10296.0 10307.5 10299.0 10310.0 10304.5 10316.0 10345.0 10355.0 10349.0 10359.5 10352.0 10361.0 10354.0 10364.5 10359.5 10368.5 10361.5 10371.0 10363.0 10373.0 10373.0 10382.0 10389.5 10397.0 10398.0 10406.0 10413.5 10421.5 10447.5 10454.5 10449.5 10457.0 10455.5 10463.5 10565.0 10573.0 10644.5 10650.5 10666.5 10674.5 10707.5 10715.0 10801.5 10807.5 10811.5 10816.5 10814.0 10820.0 10900.5 10908.5 10902.0 10910.0 10919.5 10927.0 10967.5 10975.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 4 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP 5541.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined MERGE BASE 10975.0 Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 5497 10967.5 8232.25 10942 5497 ROP 4.7489 697.113 137.548 10875 5530.5 GR 5.1723 346.233 74.7597 10877 5497 Last Reading 10967.5 10967.5 10935 First Reading For Entire File .......... 5497 Last Reading For Entire File ........... 10967.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE GR ROP $ START DEPTH STOP DEPTH 5511.5 10942.5 5545.0 10975.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 01-MAY-97 4.96 CIM 5.46 / DC 1.41 MEMORY 10975.0 5541.0 10975.0 33.3 40.7 TOOL NUMBER P0709CG6 8.500 8.5 KCL 9.60 46.0 9.0 1500 5.6 .000 .000 .000 .000 61.7 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 GR MWD 4 AAPI 4 1 68 ROP MWD 4 FT/H 4 1 68 Name Min Max Mean Nsam DEPT 5511.5 10975 8243.25 10928 GR 5.1723 346.233 74.7428 10863 ROP 4.7489 697.113 137.599 10861 First Reading 5511.5 5511.5 5545 Last Reading 10975 10942.5 10975 First Reading For Entire File .......... 5511.5 Last Reading For Entire File ........... 10975 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/07/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 97/07/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : P2 - O1 FIELD NAME : POINT MCINTYRE BOROUGH ' NORTH SLOPE STATE ' ALASKA API NUMBER : 50-029-22761-00 REFERENCE NO : 97278 RECEIVED JUL 2,5 1997' Oi~ & Gas Cons. Commission Anchorage M C OF LMED * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAM~ : ARCO ALASKA, INC. WELL NAME : P2-O1 FIELD NAME : POINT MCINTYRE BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22761-00 REFERENCE NO : 97278 LIS Tape Verification Listing Schlumberger ~laska C~mputing Center 18-JUL-1997 14:56 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/07/18 ORIGIN : FLIC REEL NA~E : 97278 CONTINUATION # : PREVIOUS REEL : CO~ENT : ARCO ALASKA INC, P2-O1, POINT MCINTYRE, API #50-029-22761-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/07/18 ORIGIN : FLIC TAPE NAME : 97278 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC, P2-O1, POINT MCINTYRE, API #50-029-22761-00 TAPE HEADER POINT MCINTYRE OPEN HOLE WIRELINE LOGS WELL NAME: API ~ER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB ~ER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION RUN 1 97278 KIRKBY K. WHITE SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING P2-O1 500292276100 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 18-JUL-97 RUN 2 RUN 3 .......... 11 12N 14E 58 4304 47.15 45.65 11.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 5473.0 LIS Tape Verification Listing Schlumberger Alaska C~mputing Center 18-JUL-1997 14:56 3RD STRING PRODUCTION STRING REMARKS: THIS IS PLATFORM EXPRESS/BHC DATA LOGGED 02-MAY-97. THE DATA IS JUST THE MAIN PASS DATA DUE TO DATA LOSS IN THE SURFACE INSTRUMENTATION. NO DEPTH SHIFTS HAVE BEEN MADE TO THIS DATA AS THIS HAS BEEN DETERMINED TO BE THE PDC LOG FOR THIS WELL. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE · 97/07/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLEMAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SU~9~ARY LDWG TOOL CODE AIT SDN BCS BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 10956.0 9702.0 10921.0 9602.0 10919.0 9592.0 BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: THIS IS THEMAIN PASS EDITED CLIPPED DATA AT .5' SAMPLE RATE. NO DEPTH SHIFTS HAVEBEENAPPLIED. $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... AIT SDN BCS RUN NO. PASS NO. ............... MERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-JUL-1997 14:56 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN * * NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 SP AIT MV O0 000 O0 0 1 1 1 4 68 0000000000 GR AIT GAPI O0 000 O0 0 1 1 1 4 68 0000000000 TENS AIT LB O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNT PU-S O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNT PU-S O0 000 O0 0 1 1 1 4 68 0000000000 DT BCS US/F O0 000 O0 0 1 1 1 4 68 0000000000 CALI SDN IN O0 000 O0 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN BN/E O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 AFiO AIT OH2V~l O0 000 O0 0 1 1 1 4 68 0000000000 AF20 AIT OHMM O0 000 O0 0 1 1 1 4 68 0000000000 AF30 AIT OH~M O0 000 O0 0 1 1 1 4 68 0000000000 AF60 AIT OH~ff4 O0 000 O0 0 1 1 1 4 68 0000000000 AF90 AIT OHF~I O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska C~mputing Center 18-JUL-1997 14:56 PAGE: DEPT. 10959.834 SP.AIT CNTC. CNT -999.250 CFTC. CNT DT. BCS -999.250 CALI. SDN RHOB.SDN -999.250 AFiO.AIT AF60.AIT -999.250 AF90.AIT DEPT. 10499.834 SP.AIT CNTC. CNT 2116.011 CFTC. CNT DT. BCS 89.019 CALI.SDN RHOB.SDN 2.262 AFiO.AIT AF60.AIT 33.473 AFgO.AIT DEPT. 9999.834 SP.AIT CNTC. CNT 2554.678 CFTC. CNT DT. BCS 84.740 CALI.SDN RHOB.SDN 2.424 AFIO.AIT AF60.AIT 5.776 AF90.AIT DEPT. 9590.334 SP.AIT CNTC. CNT -999.250 CFTC. CNT DT.BCS 94.915 CALI.SDN RHOB.SDN -999.250 AFiO.AIT AF60.AIT -999.250 AF90.AIT ** END OF DATA ** 50.875 GR.AIT -999.250 NPHI.CNT -999.250 DRHO.SDN -999.250 AF20.AIT -999.250 52.438 GR.AIT 788.436 NPHI.CNT 8.550 DRHO.SDN 24.093 AF20.AIT 34.018 34.313 GR.AIT 1011.204 NPHI.CNT 8.505 DRHO.SDN 6.115 AF20.AIT 5.324 -999.250 GR.AIT -999.250 NPHI.CNT -999.250 DRHO.SDN -999.250 AF20.AIT -999.250 -999.250 TENS.AIT -999.250 CPHI.CNT -999.250 PEF. SDN -999.250 AF30.AIT 54.714 TENS.AIT 27.093 CPHI.CNT 0.020 PEF. SDN 25.298 AF30.AIT 104.804 TENS.AIT 26.923 CPHI.CNT 0.018 PEF. SDN 5.809 AF30.AIT -999.250 TENS.AIT -999.250 CPHI.CNT -999.250 PEF. SDN -999.250 AF30.AIT 6547.400 -999.250 -999.250 -999.250 5333.500 0.311 4.291 26.563 5395.900 0.268 3.406 5.690 -999.250 -999.250 -999.250 -999.250 **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .002 SERVICE .FLIC VERSION .O01CO1 DATE : 97/07/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 2 RAW OPEN HOLEMAIN PASS LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-JUL-1997 14:56 PAGE: 5 Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE S07~VARY VENDOR TOOL CODE START DEPTH AIT 10956.0 PEX 10931.0 BHC 10919.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TI~E LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 9702.0 9602.0 9592.0 2-MAY-97 8C0-609 0 02-MAY-97 1030 02-MAY-97 10975.0 10974.0 9590.0 10974.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER AIT ARRAY INDUCTION AIT-H 122 PEX DENSITY SONDE HRMS 842 PEX NEUTRON SONDE HGNS 840 BHC SONIC SONDE SLA-WA 1498 BHC SONIC CARTRIDGE SDC-CB 83 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS _CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~4~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT) .. MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 8.500 5473.0 5472.0 KCL 10. O0 50.0 8.5 164.0 0.300 68.0 0.180 68.0 0.200 68.0 LIS Tape Verification Listing Schlumberger Alaska C~mputing Center 18-JUL-1997 14:56 PAGE: MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: AIT RUN IN COMPUTE MUD RESISTIVITY MODE TWO STANDOFFS RUN ON AITH HOLEFINDER RUN ON BOTTOM OF AITH LOGGED FROM TD TO 500' ABOVE KUPARUK MAX. DEVIATION 40 DEG BOWSPRING RUN ON CNL THIS DATA IS DECIMATED TO .5' SAMPLE RATE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN * * NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 SP AIT MV O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-JUL-1997 14:56 PAGE: 7 NAM~ SERV UNIT SERVICE API API API API FILE NUF~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) GR AIT GAPI O0 000 O0 0 2 1 1 4 68 0000000000 TENS AIT LB O0 000 O0 0 2 1 1 4 68 0000000000 CNTC PEX CPS O0 000 O0 0 2 1 1 4 68 0000000000 CFTC PEX CPS O0 000 O0 0 2 1 1 4 68 0000000000 NPHI PEX PU O0 000 O0 0 2 1 1 4 68 0000000000 NPOR PEX PU O0 000 O0 0 2 1 1 4 68 0000000000 DT BHC US/F O0 000 O0 0 2 1 1 4 68 0000000000 HCAL PEX IN O0 000 O0 0 2 1 1 4 68 0000000000 DPHZ PEX G/C3 O0 000 O0 0 2 1 1 4 68 0000000000 RHOZ PEX G/C3 O0 000 O0 0 2 1 1 4 68 0000000000 ~DRA PEX G/C3 O0 000 O0 0 2 1 1 4 68 0000000000 PEFZ PEX BN/E O0 000 O0 0 2 1 1 4 68 0000000000 AFiO AIT OH~ O0 000 O0 0 2 1 1 4 68 0000000000 AF20 AIT OH~4 O0 000 O0 0 2 1 1 4 68 0000000000 AF30 AIT OPiM~ O0 000 O0 0 2 1 1 4 68 0000000000 AF60 AIT OBk4~ O0 000 O0 0 2 1 1 4 68 0000000000 AF90 AIT OHI~4 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10975.834 SP.AIT 52.313 GR.AIT CNTC.PEX 2877.414 CFTC.PEX 1067.571 NPHI.PEX DT. BHC 77.546 HCAL.PEX 3.914 DPHZ.PEX HDRA.PEX 0.205 PEFZ.PEX 10.000 AFiO.AIT AF30.AIT 5.043 AF60.AIT 4.610 AF90.AIT 81 . 899 TENS.AIT 5198. 801 O. 344 NPOR. PEX 29. 773 29. 087 RHOZ. PEX 2.170 4. 639 AF20. AIT 5 . 296 4. 263 DEPT. 10499. 834 SP.AIT CNTC . PEX 2116. O11 CFTC. PEX DT. BHC 89. O19 HCAL. PEX HDRA . PEX O . 020 PEFZ . PEX AF30 .AIT 26. 563 AF60 .AIT 52.438 GR.AIT 54.714 TENS.AIT 5333.500 788.436 NPHI.PEX 0.311 NPOR.PEX 27.093 8.550 DPHZ.PEX 23.530 RHOZ.PEX 2.262 4.291 AFIO.AIT 24.093 AF20.AIT 25.298 33.473 AF90.AIT 34.018 DEPT. 9999.834 SP.AIT 34.313 GR.AIT CNTC.PEX 2554.678 CFTC. PEX 1011.204 NPHI.PEX DT. BHC 84.740 HCAL.PEX 8.505 DPHZ.PEX t{DRA.PEX 0.018 PEFZ.PEX 3.406 AFIO.AIT AF30.AIT 5.690 AF60.AIT 5.776 AF90.AIT 104.804 TENS.AIT 5395.900 0.268 NPOR.PEX 26.923 13.700 RHOZ.PEX 2.424 6.115 AF20.AIT 5.809 5.324 DEPT. 9590.334 SP.AIT -999.250 GR.AIT -999.250 TENS.AIT 5224.000 CNTC. PEX -999.250 CFTC. PEX -999.250 NPHI.PEX 0.307 NPOR.PEX -999.250 DT. BHC 94.915 HCAL.PEX 9.000 DPHZ.PEX -999.250 RHOZ.PEX -999.250 PiDRA.PEX 0.030 PEFZ.PEX -999.250 AFiO.AIT -999.250 AF20.AIT -999.250 AF30.AIT -999.250 AF60.AIT -999.250 AF90.AIT -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-JUL-1997 14:56 PAGE: **** FILE TRAILER **** FILE NAM~ : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE · 97/07/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NTrM~ER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.25 FILE SUA~LARY ~m%rDOR TOOL CODE START DEPTH STOP DEPTH 10956.0 9702.0 AIT $ LOG HEADER DATA DATE LOGGED: 2 -MAY- 97 SOFTWARE VERSION: 8C0 - 609 TIME CIRCULATION ENDED: 0 02-MAY-97 TIME LOGGER ON BOTTOM: 1030 02-MAY-97 TD DRILLER (FT) : 10975.0 TD LOGGER (FT) : 10974.0 TOP LOG INTERVAL (FT) : 9590.0 BOTTOM LOG INTERVAL (FT) : 10974.0 LOGGING SPEED (FPHR) : 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AIT ARRAY INDUCTION PEX DENSITY SONDE TOOL NUMBER AIT-H 122 HRMS 842 LIS Tape Verification Listing Schlumberger alaska Computing Center 18-JUL-1997 14:56 PAGE: PEX NEUTRON SONDE HGNS 840 BHC SONIC SONDE SLA-WA 1498 BHC SONIC CARTRIDGE SDC-CB 83 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 8.500 5473.0 5472.0 BOREHOLE CONDITIONS MUD TYPE: KCL MUD DENSITY (LB/G): 10. O0 MUD VISCOSITY (S) : 50.0 MUD PH: 8.5 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 164.0 RESISTIVITY (OPff4M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): O. 300 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 0.180 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 200 MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 REMARKS: AIT RUN IN COMPUTE MUD RESISTIVITY MODE TWO STANDOFFS RUN ON AITH HOLEFINDER RUN ON BOTTOM OF AITH LOGGED FROM TD TO 500' ABOVE KUPARUK MAX. DEVIATION 40 DEG BOWSPRING RUN ON CNL THIS DATA IS AIT CURVES AT . 25'SAMPLE RATE $ LIS FORMAT DATA 68.0 68.0 68.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Gomputing Center 18-JUL-1997 14:56 PAGE: 10 TYPE REPR CODE VALUE 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELaM CODE (HEX) DEPT FT O0 000 O0 0 3 1 1 4 68 0000000000 AFiO AIT OH~4~ O0 000 O0 0 3 1 1 4 68 0000000000 AF20 AIT OPH~ O0 000 O0 0 3 1 1 4 68 0000000000 AF30 AIT OH~4~ O0 000 O0 0 3 1 1 4 68 0000000000 AF60 AIT OFFS4 O0 000 O0 0 3 1 1 4 68 0000000000 AF90 AIT OH~M O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10976.000 AFIO.AIT 4.639 AF20.AIT AF60.AIT 4.610 AF90.AIT 4.263 5.295 AF30.AIT 5.043 DEPT. 10500.000 AFIO.AIT 24.294 AF20.AIT AF60.AIT 35.265 AF90.AIT 35.781 25.509 AF30.AIT 26.785 DEPT. 10000.000 AFIO.AIT 6.003 AF20.AIT AF60.AIT 5.517 AF90.AIT 5.105 5. 674 AF30 .AIT 5. 511 DEPT. 9590.500 AFiO.AIT -999.250 AF20.AIT -999.250 AF30.AIT -999.250 AF60.AIT -999.250 AF90.AIT -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger ~laska Cmmputing Center 18-JUL-1997 14:56 PAGE: 11 **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 97/07/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUM~ER 4 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NOT4~ER : 1 DEPTH INCREMENT: 0.1667 FILE SU~ff~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 10931.0 9602.0 PEX LOG HEADER DATA DATE LOGGED: 2-MAY-97 SOFTWARE VERSION: 8C0- 609 TItlE CIRCULATION ENDED: 0 02-MAY-97 TII~E LOGGER ON BOTTOM: 1030 02-MAY-97 TD DRILLER (FT) : 10975.0 TD LOGGER (FT) : 10974.0 TOP LOG INTERVAL (FT) : 9590.0 BOTTOM LOG INTERVAL (FT) : 10974.0 LOGGING SPEED (FPHR): 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... AIT ARRAY INDUCTION PEX DENSITY SONDE TOOL NUMBER AIT-H 122 HRMS 842 LIS Tape Verification Listing Schlumberger ~laska Computing Center 18-JUL-1997 14:56 PAGE: 12 PEX NEUTRON SONDE HGNS 840 BHC SONIC SONDE SLA-WA 1498 BHC SONIC CARTRIDGE SDC-CB 83 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 5473.0 5472.0 BOREHOLE CONDITIONS MUD TYPE: KCL MUD DENSITY (LB/G): 10. O0 MUD VISCOSITY (S) : 50.0 MUD PH: 8.5 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 164.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 0.300 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 0.180 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 200 MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 REMARKS: AIT RUN IN COMPUTE MUD RESISTIVITY MODE TWO STANDOFFS RUN ON AITH HOLEFINDER RUN ON BOTTOM OF AITH LOGGED FROM TD TO 500' ABOVE KUPARUK MAX. DEVIATION 40 DEG BOWSPRING RUN ON CNL THIS DATA IS AT . 1667 ' SAMPLE RATE $ LIS FORMAT DATA 68.0 68.0 68.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger ~laska Computing Center 18-JUL-1997 14:56 PAGE: 13 TYPE REPR CODE VALUE .............................. 3 73 4 66 5 66 6 73 7 65 8 68 O. 166 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 16 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 4 1 1 4 68 0000000000 RHOZ PEX G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 PEFZ PEX BN/E O0 000 O0 0 4 1 1 4 68 0000000000 DPHZ PEX PU O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10976.000 RHOZ.PEX 2.171 PEFZ. PEX 10.000 DPHZ.PEX DEPT. 10500.000 RHOZ.PEX 2.266 PEFZ.PEX 4.219 DPHZ.PEX DEPT. 10000.000 RHOZ.PEX 2.407 PEFZ.PEX 3.326 DPHZ.PEX DEPT. 9590.500 RHOZ.PEX -999.250 PEFZ. PEX -999.250 DPHZ.PEX 29. 005 23. 301 14.755 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger A!~ska Computing Center 18-JUL-1997 14:56 PAGE: 14 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/07/18 ORIGIN : FLIC TAPE NAME : 97278 CONTINUATION # : 1 PREVIOUS TAPE : COM~E2FT : ARCO ALASKA INC, P2-O1, POINT MCINTYRE, API #50-029-22761-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/07/18 ORIGIN : FLIC REEL NAME : 97278 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, P2-O1, POINT MCINTYRE, API #50-029-22761-00
