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197-033
By Anne Prysunka at 10:31 am, Nov 10, 2022 MGR12NOV2022 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:197-033 6.50-029-20415-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 15311 11458 8280 11431 , 11538 8198 , 8270 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 36 - 116 36 - 116 1530 520 Surface 2695 13-3/8" 36 - 2731 36 - 2731 5380 2670 Intermediate 11796 9-5/8" 34 - 11830 34 - 8535 6870 4760 Production 737 7" 11550 - 12287 8345 - 8839 8160 7020 Perforation Depth: Measured depth: 12130 - 15278 feet True vertical depth:8731 - 8980 feet Tubing (size, grade, measured and true vertical depth)5-1/2" 17# x 4-1/2" 12.6# L-80 x N-80 33 - 11591 11431 , 11538 8198 , 8270Packers and SSSV (type, measured and true vertical depth) 5-1/2" HBBP-T / 4-1/2" Baker FHL Liner 3752 3-1/2" x 2-7/8" 11563 - 15311 8351 - 8980 10160 / 10570 10530 / 11160 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Torin Roschinger Torin.Roschinger@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564-4887 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9005 Sundry Number or N/A if C.O. Exempt: 5-1/2" BTDP-1 SSV 2155 2155 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Kinley tubing punch Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028328 PBU 03-16A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 321-044 12280 , 12400 , 13190 , 13600 12325 ,12540 ,15161 Convert to Producer 5 5 & 321-211 14100 , 14750 feet 101 31 440 2703 1977 1962 256 2666114 55 By Samantha Carlisle at 3:15 pm, May 26, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.05.26 14:24:18 -08'00' Bo York RBDMS HEW 6/9/2021 DSR-5/26/21 SFD 6/16/2021MGR30JUL2021 ACTIVITYDATE SUMMARY 12/5/2020 T/I/O=0/0/0 Temp = SI MIT IA to 2500 psi (Injection Conversion) MIT IA PASSED to 2481 psi Pumped 9.56 bbls DSL down IA to achieve test pressure of 2500 psi. 15 min loss of 21 psi, 30 min loss of 8 psi, for total loss of 29 psi in 30 mins. Bleed IAP to 0 psi. Bled back ~6 bbls. Tags hung on IA/WV DSO/WSL notified FWHP=0/0/0 12/6/2020 ***WELL SI ON ARRIVAL*** PULLED 5.5" XXN PLUG @ 11458' RKB. DRIFT TBG TO TAG @ 12210' SLM w/ 10' x 2.16" DMY GUN & SAMPLE BAILER, RECOVERED HARD DRY INJECTION RESIDUE IN BAILER. ***JOB COMPLETE, DSO NOTIFIED OF WELL STATUS*** 12/7/2020 T/I/O = 1100/90/0. Temp = SI. TBG FL @ 320' ( 7.4 bbls) (OE). Well is blinded at WV and MI companion valve. 12:30 12/11/2020 T/I/O = 40/50/0. Temp = SI. Stack out TBG w/AL gas from 03-15. TBG FL @ near surface. RU jumper hose from 03-15 IA to 03-16 TBG. Stack out TP from 40 psi to 1750 psi in 4 hrs. TBG FL pushed down to 830'. ***Continued on WSR dated 12/12/20.*** 12/12/2020 ***Continued from WSR dated 12/11/20.*** T/I/O = 1750/110/0. Temp = SI. Stack out TP w/AL gas from 03-15. TBG FL @ 830' (19 bbls) Coninued with AL down TBG. Maintained 1780 psi on TBG for 3 hrs. Could not depress TBG FL below 850'. Final WHPs = 1780/110/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:00 12/25/2020 T/I/O= 24/56/0. Temp= SI. LRS Unit 72 SBG Treatment and Injectivity test (SCHMOO-B-GONE). Pumped 2 bbls of 60/40 Meoh and 100 bbls of SBG into the TBG. Pumped 50 bbls of 1% KCL into the TBG at 0.93 bpm and SD pump. TBG lost 708 psi in 10 minutes. Pumped 50 bbls of 1% KCL into the TBG at 1.25 bpm and SD pump. TBG lost 546 psi in 10 minutes. Pumped 50 bbls of 1% KCL into the TBG at 1.80 bpm and SD pump. TBG lost 557 psi in 10 minutes. Pumped 50 bbls of 1% KCL into the TBG at 3.41 bpm and SD pump. TBG lost 522 psi in 10 minutes. Pumped 70 bbls of 1% KCL into the TBG at 4.35 bpm and SD pump. TBG lost 640 psi in 10 minutes. Pumped 2 bbls of 60/40 Meoh into the TBG and SD pump for 3 hours. Complete Injectivity test. FP TBG with 58bbls of DSL. Hang tags, finish paperwor, Notify DSO upon departure. 12/26/2020 T/I/O = Vac/290/5. Temp = SI. TBG-FL @ 1085' (25.2 bbls) (APE request). Well is blinded @ WV and MI companion valve. SV, WV, SSV = C. MV = O. IA, OA = OTG. 10:00 12/27/2020 T/I/O = Vac/25/0. Temp = SI. T FL @ 3336'' (77 bbls) (APE request). Well is blinded at WV and MI companion valve. IAP decreased 265 psi to 25 psi, OAP decreased to 0+ psi. SV, WV, SSV = C. MV = O. IA & OA = OTG. 08:30 12/30/2020 T/I/O = VAC/30/VAC. Temp = SI. T & IA FL (Ops). Well is blinded at both WVs. T FL inconclusive. IA FL @ near surface. SV, WV, SSV = C. MV = O. IA & OA = OTG. 20:30 12/31/2020 T/I/O = Vac/30/Vac. Temp = SI. TBG FL (OE request). TBG FL @ 3660' (85 bbls). SV, WV, SSV = C. MV = O. IA, OA = OTG. 07:20 Daily Report of Well Operations PBU 03-16A Daily Report of Well Operations PBU 03-16A 2/20/2021 ***WELL S/I ON ARRIVAL*** (Injection conversion) MISU POLLARD UNIT 57 TO RUN 5-1/2" KINLEY PUNCHER. ***JOB IN PROGRESS, CONTINUED ON 2/21/21 WSR*** 2/21/2021 ***CONTINUED FROM 2/20/21 WSR*** (Injection conversion) RAN 5-1/2" BRUSH, 3.80" G-RING TO 11,450' SLM (No issues). BRUSHED CA. SVLN, KINLEY PUNCH DEPTH (~4,787' & 4,800' md), & XN NIPPLE. DRIFT TO 5,000' SLM W/ 4.43" x 68" DRIFT (Target = 4,800' md). SET 5-1/2" CAT STANDING VALVE IN XN NIPPLE AT 11,431' SLM / 11,458' MD. ***LDFN, WELL S/I & SECURED, CONTINUED ON 2/22/21 WSR*** 2/22/2021 T/I/O= 132/3/0 Temp=SI Assist Sline as directed Pumped 2 bbls 60/40 followed by 28 bbls DSL down tbg to load and bring tbg pressure up to 500 psi . Sline in control of well upon depature. DSO notified of well status. CV's= OTG FWHP's= 510/4/0 2/22/2021 ***CONTINUED FROM 2/21/21 WSR*** (Injection conversion) TAG 5-1/2" SVLN W/ 4.70" G-RING AT 2,131' SLM / 2,158' MD (24' Correction). SET 5-1/2" SLIP STOP CATCHER SUB AT 4,802' MD (Piston for check insert 2' from kinley btm). RAN 5-1/2" KINLEY PUNCHER & SET 16/64" CHECK INSERT AT 4,800' MD. MOVE 5-1/2" SLIP STOP CATCHER SUB FROM 4,802' TO 4,789' MD. RAN 5-1/2" KINLEY PUNCHER & SET 16/64" CHECK INSERT AT 4,787' MD. ***LDFN, WELL S/I & SECURED, CONTINUED ON 2/23/21 WSR*** 2/23/2021 LRS Temporary Hardline. Begin WSR 2/23/21, Begin Rigging Up Temporary Hardline. Inlet Well 03-16, Outlet Well 03-15. Job in Progress, Continued on WSR 2/24/21 2/23/2021 ***CONTINUED FROM 2/22/21 WSR*** (Injection conversion) PULL EMPTY 5-1/2" SLIP STOP CATCHER SUB FROM 4,767' SLM. PULL 5-1/2" CAT STANDING VALVE FROM 11,431' SLM / 11,458' MD. ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** 2/24/2021 LRS Temporary Hardline. Continued from WSR 2/23/21. Complete Rigging Up Temporary Hardline, PT'd to 4000 psi. Inlet Well 03-16, Outlet Well 03-15. Job in Progress, Continued on WSR 2/25/21 2/28/2021 LRS Temporary Hardline DS3-16. 2/24/21 through 2/28/21. 5 Days. Begin WSR on 2/24/21. Hardline Rigged Up. Continue WSR on 3/1/21. 3/1/2021 T/I/O = 640/1480/0+. Temp = SI. T & IA FL (Ops request). Temporary AL online. T FL @ 720' (4080 above btm Kinley punch). IA FL @ 4800' (btm Kinley punch). SV, WV, SSV = C. MV = O. IA, OA = OTG. 22:00 3/31/2021 LRS Temporary Hardline DS3-16. 3/1/21 through 3/31/21. 31 Days. Continue WSR from 2/28/21. Continue flowback. Continue WSR on 4/1/21. 4/1/2021 ***WSR CONTINUED FROM 31-MAR-2021*** LRS Temporary Hardline DS03-16. Continue flowback 04/01/21 - 04/30/21. ***WSR CONTINUED ON 01-MAY-2021*** 5/1/2021 ***WSR CONTINUED FROM 30-APR-2021*** LRS Temporary Hardline DS13-16. Continue flowback. 5/15/2021 LRS Well Test Unit 6. Temporary Hardline Inspection. Begin WSR 5/15/21, Mobilize Equipment to Location, BDRD Harfdline, Inspect Hardline Gaskets, Reassemble Hardline. Inlet Well 03-16, Outlet Well 03-15. Job in Progress, Continued on WSR 5/16/21. Daily Report of Well Operations PBU 03-16A 5/16/2021 T/I/O = 430/1380/785. Temp = 90*. PPPOT-IC (PASS), (eval IAxOA). AL online from well 03-15 (1440 psi, no companion valve). 03-16 flowing to 03-15 FL. PPPOT-IC: Stung into IC test port (200 psi), bled void to 0 psi. Monitor for 10 min, no change in pressure. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. SV, SSV, MV = O. WV, CWV = C. IA & OA = OTG. 16:45. 5/16/2021 LRS Well Test Unit 6. Temporary Hardline Inspection. Continued from WSR 5/15/21. Complete Reassembling Hardline, PT. Inlet Well 03-16, Outlet Well 03-15. Job Complete/ End WSR Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:197-033 6.API Number:50-029-20415-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028328 Property Designation (Lease Number):10. 8. PBU 03-16A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown convert to producer Op Shutdown GAS GSTOR WAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5Stratigraphic Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 15311 Effective Depth MD: L-80 x N-80 11. Commission Representative: 15. Suspended Contact Name: Torin Roschinger Contact Email: Torin.Roschinger@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: no SSSV Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9005 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 11431,11538 8198, 8270 Date: Liner 3752 3-1/2" x 2-7/8" 11563 - 15311 8351 - 8980 10160 / 10570 10530 / 11160 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 36 - 2731 36 - 2731 14. Estimated Date for Commencing Operations: BOP Sketch 36 - 116 Structural 6870 Proposal Summary 13. Well Class after proposed work: 5-1/2" HBBP-T / 4-1/2" Baker FHL 12130 - 15278 8731 - 8980 5-1/2" 17# x 4-1/2" 12.6#33 - 11591 Liner 12280 8530 12325,12540,15161 36 - 116 520 13-3/8" 9-5/8" Contact Phone:(907) 564-4887 Date:4-23-21 4760 80 153020"Conductor 2670 GINJ Post Initial Injection MIT Req'd? Yes No Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2695 5380 Intermediate 11796 34 - 11830 34 - 8535 737 7"11550 - 12287 8345 - 8839 8160 7020 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 3609 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. 55 5555 5/1/2021 12280,12400,13190, 13600 By Samantha Carlisle at 11:24 am, Apr 26, 2021 321-211 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.04.26 09:53:43 -08'00' Bo York Mel Rixse - Sr. Petr Engr. 10-404 MGR29APR21 DLB04/26/2021 X 30-APR-2021 DSR-4/26/21 Yes on Required? Comm. 5/3/21 dts 5/3/2021 JLC 5/3/2021 RBDMS HEW 5/3/2021 Injector to Producer Conversion Well: 03-16A PTD: 197033 Well Name:03-16A API Number: 50-029-20415-01 Current Status:Operable PWI Pad:FL2, DRILLSITE 03 Estimated Start Date:May 1, 2021 Rig:NA Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Carrie Janowski Permit to Drill Number:197033 First Call Engineer:Torin Roschinger (907) 564-4887 (O) (406) 570-9630 (M) Last Bottom Hole Pressure:3,609 psi @ 8,599’ TVD SBHP survey (10/15/14)8.10 PPG Maximum Expected BHP:3609 psi MPSP:2750 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 96° @ 13,400’ MD Max Dogleg:59.6°/100ft @ 12,328’ MD Brief Well Summary: 03-16A was sidetracked as a WAG injector in 1997, all MI cycles were completed in 2004, when it was returned to PW injection. It has been LTSI well since December 2015 due to PWI flowline corrosion. PWI and MI lines were blinded in 2016. The PWI line would require full replacement to reinstate injection and the sees no current value to reinstating injection in this pattern. This well is located in a lucrative area of the reservoir, with great performance from offset producers. In March 2021, the well was temporarily converted from and injector to a producer to evaluate the economics of doing a full conversion to a producer. Since POP’d in March, the well has consistently flowed with a 2-4% WC, ~2100bfpd, 2mmscfd and ~60-100bopd. Objective: The objective of this procedure is to convert the injector to a producer full time. Attachments: 1. Current Schematic Injector to Producer Conversion Well: 03-16A PTD: 197033 Attachment 1: Current Schematic Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:197-033 6.API Number:50-029-20415-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028328 Property Designation (Lease Number):10. 8. PBU 03-16A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Kinley tubing punch Op Shutdown GAS 5 GSTOR WAG SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 15311 Effective Depth MD: L-80 x N-80 11. Commission Representative: 15. Suspended Contact Name: Torin Roschinger Contact Email: Torin.Roschinger@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: no SSSV Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8980 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 11431,11538 / 8198, 8270 no SSSV Date: Liner 3752 3-1/2" x 2-7/8" 11563 - 15311 8351 - 8980 10160 / 10570 10530 / 11160 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 36 - 2731 36 - 2731 14. Estimated Date for Commencing Operations: BOP Sketch 36 - 116 Structural 6870 Proposal Summary 13. Well Class after proposed work: 5-1/2" HBBP-T / 4-1/2" Baker FHL 12130 - 15278 8731 - 8980 5-1/2" 17# x 4-1/2" 12.6#33 - 11591 Liner 12280 8530 12325,12540,15161 36 - 116 520 13-3/8" 9-5/8" Contact Phone:(907) 564-4887 Date: 1/20/2021 4760 80 153020"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2695 5380 Intermediate 11796 34 - 11830 34 - 8535 737 7"11550 - 12287 8345 - 8839 8160 7020 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 3609 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. 12280,12400,13190,13600 2-1-2021 By Samantha Carlisle at 3:42 pm, Jan 22, 2021 321-044 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.01.22 12:26:26 -09'00' Bo York SFD 1/29/20219005 10-404 SFD 1/29/2021MGR25JAN2021 DSR-1/22/21 convert to producer Yesn Required? Comm 2/8/21 dts 2/8/2021 JLC 2/8/2021 RBDMS HEW 2/8/2021 PWI to PAL Test Well: 03-16 Date: 01-08-21 Well Name: 03-16A API Number: 50-029-20415-01 Current Status: Operable PWI Pad: FL2, DRILLSITE 03 Estimated Start Date: February 1, 2021 Rig: NA Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Carrie Janowski Permit to Drill Number: 197-033 First Call Engineer: Torin Roschinger (907) 564-4887 (O) (406) 570-9630 (M) Second Call Engineer: John Condio (907) 564-4696 (O) (602) 373-0659 (M) AFE Number: Well EZ Entries Required ??? Last Bottom Hole Pressure: 3,609 psi @ 8,599’ TVD SBHP survey (10/15/14) 8.10 PPG Maximum Expected BHP: 3609 psi MPSP: 2750 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 96° @ 13,400’ MD Max Dogleg: 59.6°/100ft @ 12,328’ MD Brief Well Summary: 03-16A was sidetracked as a WAG injector in 1997, all MI cycles were completed in 2004, when it was returned to PW injection. It has been LTSI well since December 2015 due to PWI flowline corrosion. PWI and MI lines were blinded in 2016. The PWI line would require full replacement to reinstate injection. The team sees no current value to reinstating injection in this pattern. This well is located in a lucrative area of the reservoir, with great performance from offset producers. We believe there is potential that an oil column has resaturated the area in the 5 years this well has been SI. Conversion to production could bring value to the field from an otherwise idle well. Initial attempts to flow and test 03-16’s production were unsuccessful without gas lift. The following actions were performed: x 12/05/2020: MIT-IA to 2500 psi – passed x 12/06/2020: Pulled TTP, drift and tag at 12,210’ SLM, recovered sample of dry injection residue x 12/11/2020: Stacked out tubing with AL gas from well 03-15, well locked up; could not depress tubing fluid level below 850’. Attempted to flow to open top tanks. No flow established. x Team decided likely injection schmoo preventing perforations from flowing. x 12/25/2020: Performed Schmoo-B-Gone treatment. Successfully established injectivity. Freeze protected tubing. Objective: x Install 2x 16/64” Kinley Tubing Punch, check valve inserts in 5-1/2” tubing at ~ 4800’ MD. Sundry Procedure (Approval Required to Proceed) 1. RU hot oil and PT lines to 3000 psi. 2. Bullhead 85 bbls of crude to tubing (TxIA differential pressure should be less than 1000 psi, per Kinley Perforator Manual, last WHP= Vac, T FL at 3660’, IA FL at surface. 3. RU Slickline unit and drift tubing to ~ 5000’ for Kinley High Power Perforator (HPP), max tool OD=4.275” 4. Tag Bal-O nipple at 2155’ with G-Ring for depth correction 5. Set tubing stop in collar nearest 4800’ (Tubing stop to be set below tubing punches.) (No pressure noted on tubing, i.e. competent tubing to top of packer.) Note: Attempted to bring well on again after schmoo be gone treatment, without success. ) PWI to PAL Test Well: 03-16 Date: 01-08-21 6. RU Kinley High Power Perforator (HPP), PT lubricator and surface equipment per Kinley recommended practice. 7. Run Kinley HPP (2 runs), install two 16/64” check inserts at ~4800’ and 4787’ MD, use tubing stop to space out and avoid punching tubing in a connection. 8. Pull tubing stop. 9. POP well for temporary 60 day test to evaluate conversion from PWI to PAL. Attachments: 1. Current Schematic 2. Proposed Schematic 3. Tubing Tally PWI to PAL Test Well: 03-16 Date: 01-08-21 Attachment 1: Current Schematic PWI to PAL Test Well: 03-16 Date: 01-08-21 Attachment 2: Proposed Schematic PWI to PAL Test Well: 03-16 Date: 01-08-21 Attachment 3: Tubing Details Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Wednesday, December 9, 2020 4:37 PM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Bo York; Aras Worthington; Oliver Sternicki; John Condio - (C) Subject: OPERABLE: Injector 03-16 (PTD #1970330) Temporary flowback Mr. Wallace, Injector 03-16 (PTD #1970330) was made not operable on 11/09/19 as it lapsed a required 4 year AOGCC MIT -IA. The well passed an MIT -IA on 12/05/20 which verifies two well barriers. At this time the well is classified as OPERABLE and will require an AOGCC 4 year MIT -IA when thermally stable if placed back on injection. Plan Forward: 1. Operations: Install low pressure pilot and conduct AOGCC performance test of SVS within 5 days of well start/ stabilized production 2. Operations: Temporary flowback 3. Operations Engineer: Submit 10-404 / 10-407 if flowback exceeds 30 days Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity /Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 �om: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday, November 9, 2019 4:07 PM To: 'ch ris.wallace@alaska.gov' <chris.waIlace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS2 DS Ops Lead <AKOPSFS2DSOpsLead@bp.com>; Ak, OPS FS2 Facility PTL <AKOPSFS2FacilityPTL@bp.com>; Ak, OPS FS2 Field PTL <AKOPSFS2Field PTL@bp.com>; AK, OPS FS2 OSM <AKOPSFS20SM1@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; G GPB FS2 Drillsites <ggpbfs2drillsites@BP.com>; Rupert, C. Ryan <Ryan.Rupert@BP.com>; Summers, Matthew <Matthew.Summers@bp.com> Cc: 'Begg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCProjectsWelllntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempseyl@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis. Montgomery@ bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smithl@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras 1 <Aras.Worthington@bp.com> Subject: NOT OPERABLE: Injector 03-16 (PTD #1970330) will lapse on 4 -year AOGCC MIT -IA • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,November 19,2015 TO: JimRegg1113UIIc SUBJECT: Mechanical Integrity Tests .I. PSupervisor 1 l l BP EXPLORATION(ALASKA)INC. 03-16A FROM: Chuck Scheve PRUDHOE BAY UNIT 03-16A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 03-16A API Well Number 50-029-20415-01-00 Inspector Name: Chuck Scheve Permit Number: 197-033-0 Inspection Date: 11/14/2015 Insp Num: mitCS151115073813 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 03-16A Type Inj W TVD 8257 - Tubing 1862 1876 - 1866 1860 - PTD 1970330 " Type Test SPT Test psi 2064 IA 582 2505 - 2486 ' 2486 Interval 4YRTST - P/F P `/ OA 37 66 - 66 66 ' Notes: 44, Oke ' (l) T---W ?R S51-ve S pla f Cz) SCANNED SEP 1 5 2016; Thursday,November 19,2015 Page 1 of 1 nn ot) 0 • . INA N o VI - - _ t.i) ..8 cr..:ASSA c..) .) - .., 31 ''. 4 f.r ze -• 4 L. I_ t., -4) . .., . •-i- I'; 1!.... S $ ...-. ... •:, t..! , . ' . i . . :- TREE= , FRAC GEN 1 SANOTES: VVEIL ANGLE>70°@ 12530'"'1t2S [WELLHEAD FMC 03-1 6A +`-• =SAV GE 125 ppm WHEN ON MI-SSSV ACTUATOR= AXSSON RJTQ II•X WHEN ON Mt ""FFL/TMV HBBP PKRS HAVE KB.ELEV= 64' REDUCED TEST PRESSURE LIMITS IN SOME CASES- ' BF.ELEV= CONTACT ACE x5102 PRIOR TO PRESSURE IhSTNG"" KOP=__m-" -3000' Max Angle= 96' 13400' Datum MD= 12287' 0 r 2155' H5-1/2" 5-1/2"CAMEO BAL-0 SSSV NP,0=4.56" Datum TVD= 8800 SS 13-3/8"CSG,72#,L-80,D=12.347" H 2725' A k z 11424' —{9-5/8'X 5-1/2"T1W HBBP-T PKR I I 11458' —15-1/2"HES XN NIP,D=4.55" 5-1/2"TBG, 17#,L-80,.0232 bpf,D=4.892" { 11480' I 1 11489' H5-1/2"UNIQUE OVERSHOT i 11514' —5-1/2"BAKER PBR ASSY 5-1/2"TBG, 174,N-80,.0232 bpf,0=4.892" — 11523' Ill / 11523' —5-1/2"X 4-1/2"XO,D=1958" Minimum ID =2.441 @ 11563' > 11533' —{9-5/8"x 4-1/2"BKR EFL PKR 3-112" X 2-7/8" CROSSOVER TOP OF 7"LNR —I 11550' J 0 11559' —4-1/2"G SEAL SUB TOP OF 2-78"LNR — 11563' ` / 11563' —13-1/2"X 2-7/8"XO,D=2.441' 11584' —14-1/2"OTIS X NP,ID=3.81" 4-1/2"TBG, 12.6#,N-80„0152 bpf,D=3.958" — 11586' j f 11586' 1—4-1/2"WLEG(BEHIND LNR) 11591' —E3M0 TT LOGGED 05/03/85 9-518"CSG,47#,L-80,D=8.681" —I 11830' , 7"LNR,294,L-80,.0371 bpf,ID=6.184" — 12280' i ) 7'MLLOUT WINDOW(03-16A) 12280' 1 PERFORATION SUMMARY REF LOG:NGP ON 04/12/97 I-- 12280' ELM —2.875"BKR OBP(10/06/14) 12400' H2-7I8'CuP ANGLE AT TOP FERE:47°@ 12130' Note:Refer to Production DB for historical perf data pl. pp 12540' —IASI+1,315'OD X 24'BRASS PRONG 01/18/04) v♦♦ N. SIZE SPF INTERVAL Opn/Sqz SHOT SQZ N♦ 4�. ..• ♦ 13190' H2-7/8"CUP(01/26/02) r 6 12130-12140 0 05/31/10 i♦.f♦� 2' 6 12150- 12160 0 05/31/10 �•••*•• ���1 k7110. 13600' 2-7/8'CEP(11/23/00) 0••• r 6 12195-12220 0 08/08/12 •••• 0� 14100' —12-7/8"C8P(01/28/00)*1.4 1 � r 6 12245 12270 0 08/08/12I••�•�•�• -.1111/411/40..2' 6 12300-12360 C 01/25/04 $• ••;• 14750' —12-1/2"CUP(03!02/98) r 6 12850- 12890 C 01/28/02 �i+iaiari *i t4i r 6 12920-12940 C 01/28/02, 15161' —FISH-2-1/8-GUNS 2' 6 13360-13410 C 01/26/02 118 FEED 4 13825-13900 C 01/29/00 FISH-2-7/8"CEP, MLLED ® �1, 1-11/16" 4 14470- 14550 C 04/02/98 &PUSHED BTM(08/07/12) 2-1/8" 4 15050- 15090 C 06/23/97 'IP r 2-1/8' 4 15178- 15278 C 04/15/97 PBTD — 15300' 2-7/8"LNR,6.5#,L-80,.0058 bpf,D=2.441" H 15311' DATE REV BY COMtiETfTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/08/85 ORIGINAL COMPLETION 08/13/12 DMS/PJC MLL FISH ADPTIRF(817/12) WELL: 03-16A 03/11/98 WORKOVER 10/06/14 RFD/PJC'SET C 3P FERMI No:y1970330 05/30/06 PRI/PJC PERU CORRECTIONS AR No: 50-029-20415-01 06/02/10 MV/PJC CIBP/ADFERFS(05/31/10) SEC 10,T10N,R15E, 1637'FEL&2205'FM_ 02/11/11 M8/JMD ADT»SSSV SAFETY NOTE 01/10/12 TMN/JMD ADDED H2S SARI Y NOTE BP Exploration(Alaska) Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Saturday, November 9, 2019 4:07 PM To: Wallace, Chris D (CED); AK, OPS EOC Specialists; AK, OPS FS2 DS Ops Lead; Ak, OPS FS2 Facility PTL; Ak, OPS FS2 Field PTL; AK, OPS FS2 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL, G GPB FS2 Drillsites; Rupert, C. Ryan; Summers, Matthew Cc: Regg, James B (CED); AK, GWO Completions Well Integrity, AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: NOT OPERABLE: Injector 03-16 (PTD #1970330) will lapse on 4 -year AOGCC MIT -IA 0 03-16 (PTD # 1970330) is a mechanically sound Injector that is due for its AOGCC required 4 -year MIT -IA by the end of November. The well is currently shut in and there are no plans to put on injection. The well will now be classified as NOT OPERABLE for tracking purposes. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization -Alaska Office: 907-659-8110 . '. ""18" "'1181" Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning pr~ject. They are available in the original file and viewable by direct inspection. /77' 0 33 File Number otWell History File PAGES TO DELETE Complete RESCAN [J Color items - Pages: [J GraY,scale, halftones, pictures, graphs, charts - Pages: Poor Quality Original' - Pages: Other - Pàges: [J [J DIGITAL DATA [J Diskettes, No. e Other, NoIType 'OVERS IZED e Logs of various kinds e Other COMMENTS: 7 (p ? ~ ". Scanned by: Beverty Mlldred.D.r.ø.~1 D8~:.3/1 ( Ial ~ c TO RE-SCAN Notes: Re-Scanned by: Beverty MIldred Daretha Nathan Lowell Date: 1sJ" • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, January 09, 2012 TO: Jim Regg P.I. Supervisor 3Qi :( i v SUBJECT: Mechanical Integrity Tests ll BP EXPLORATION (ALASKA) INC 03 -16A FROM: Chuck Scheve PRUDHOE BAY UNIT 03 -16A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 03 - 16A API Well Number: 50 Inspector Name: Chuck Scheve Insp Num: mitCS111216074606 Permit Number: 197 - 033 - Inspection Date: 12/15/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 03 -16A ' Type Inj. W ' TVD 8257 ' IA 527 2510 - 2491 2489 P.T.D 1970330 TypeTest SPT Test psi 2064.25 ' OA 38 205 200 197 Interval 4YRTST P/1i P Tubing 1744 1756 1768 1772 Notes: S!,,ANNIEDFFB 6 2012 Monday, January 09, 2012 Page 1 of 1 STATE OF ALASKA 4. ALASKA AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate0 Other ^ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate 0 Re-ente uspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Drill Number: Name: Development ^ Exploratory ^ 197-0330 3. Address: P.O. Box 196612 Stratigraphic^ Service Q .API Number: Anchorage, AK 99519-6612 50-029-20415-01-00 8. Property Designation (Lease Number) : 9. Well Name and Number ADLO-028328 \ PBU 03-16A 10. Field/Pool(s): HOE BAY POOL PRUDHO E BAY FIELD / PRUD 11. Present Well Condition Summary: 13190,13600 Total Depth measured 15311 feet Plugs (measured) 12210, 12399 feet 14100, 14750 true vertical 8979.52 feet Junk (measured) 12540, 15161 feet t Effective Depth measured 12339 feet Packer (measured) 2155 11424 11533 true vertical 8902 feet (true vertical) 2155 8257 8331 Casing Length Size MD TVD Burst Collapse Structural Conductor 73 20" 94# H-40 30 - 103 30 - 103 1530 520 Surface 2696 13-3/8" 72# L-80 29 - 2725 29 - 2725 4930 2670 Production 11802 9-5/8"47# L-80 28 - 11830 28 - 8554 6870 4760 Liner 730 7"29# L-80 11550 - 12280 8365 - 8860 8160 7020 Liner 4 3-1/2"9.3# L-80 11559 - 11563 8371 - 8374 10106 10530 Liner 3748 2-7/8"6.5# L-80 11563 - 15311 8374 - 9005 10570 11160 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 5-1/2" 17# L-80 26 - 11523 26 - 8324 4-1 /2"12.6# L-80 26-8324 8324-8367 Packers and SSSV (type, measured and true vertical depth) 5-1/2" BTDP-1 SSV 2155 2155 5-1/2" HBBP-T Packer 14 4 ~~ 8257 4-1 /2" Baker FHL Packer 11533 `, ~ ~ i 12. Stimulation or cement squeeze summary: ~-~ ~,. ~ Intervals treated (measured): ~;~ ~, _ '~ ~~~- j~S1fl~ Treatment descriptions including volumes used and final pressure (~9~ ~f.,etC y~ ~~~~a ~ ~ ~ ~ 13.,E Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 6843 1145 Subsequent to operation: 1614 1963 14. Attachments: 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: W 310-131 Contact Gary Preble Printed Name Gary Pr Title Data Management Engineer Signature Phone 564-4944 Date 7/7/2010 ~~,,,, ,~-~~.. ~~„~u „~~~~ RBDMS JUL 08 Z010~ 7- 3-ta ..__.........~..._. _..., ~ ~ ~~~ 03-16A 197-033 D~DC ATTA!_1-111A~AIT • • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 03-16A 4/15/97 PER 15,178. 15,278. 8,982.79 8,979.67 03-16A 6/23/97 APF 15,050. 15,090. 8,987.35 8,985.86 03-16A 3/2/98 BPS 14,750. 15,278. 9,002.54 8,979.67 03-16A 4/2/98 APF 14,470. 14,550. 9,019.34 9,016.16 03-16A 1/28/00 BPS 14,100. 14,550. 9,023.56 9,016.16 03-16A 1/29/00 APF 13,825. 13,900. 9,017.77 9,018.82 03-16A 11/23/00 BPS 13,600. 13,610. 9,019.14 9,019.08 03-16A 12/1 /00 APF 13,360. 13,410. 9,032.85 9,028.02 03-16A 1/26/02 BPS 13,190. 13,200. 9,043.76 9,043.13 03-16A 1/27/02 APF 12,870. 12,890. 9,039.81 9,043.79 03-16A 1/27/02 APF 12,920. 12,940. 9,048.44 9,050.63 03-16A 1/28/02 APF 12,850. 12,870. 9,035.22 9,039.81 03-16A 1/24/04 APF 12,330. 12,360. 8,865.76 8,882.08 03-16A 1/24/04 BPS 12,399. 13,190. 8,901.65 9,043.76 03-16A 1/25/04 APF 12,300. 12,330. 8,847.66 8,865.76 03-16A 5/30/10 BPS 12,210. 12,850. 8,847.66 9,035.22 03-16A 5/31/10 APF 12,130. 12,140. 8,731.3 8,738.1 03-16A 5/31/10 APF 12,150. 12,160. 8,744.93 8,751.77 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 • • 03-16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY ' 5/30/2010'"*"WELL SHUT-IN ON ARRIVAL***(E-LINE PLUG AND PERF) ~ INITIAL T/IA/OA = 0 / 0 / 0 I ;SET BAKER 2-7/8" CIBP AT 12210'. j ~ LRS MIT-T TO 3000 PSI FOR 30 MIN. TEST PASSED. , 5/30/2010 5/30/2010 """JOB CONTINUED ON 31 MAY 201 T/I/O = 50/0/0. Temp=S1 SLB has control) of well. TBG FL (E-line call-in). TBG FL @ 900', 25 bbls. ~T/I/0= 0/0/0 (Assist E-line MIT TBG Passed to 3000 psi) (profile mod.) Pump 24 [bbls diesel down tbg to achieve test pressure. TBG lost 95 Psi in 1st 15 Min then 30 i Psi in2nd 15 Min for a total loss of 130 Psi in 30 Min. Bled TBG Press to 0 Psi. E-Line Ion well @ departure. IA and OA open to gauges. FWHP= 0/0/0 Operator Notified. 5/31/2010*"*JOB CONTINUED FROM 30 MAY 2010.*** I RIH WITH TS: HEAD/ERS/ 2-1.69 IN WB/ CCL/ FIRING HEAD/ 10 FT 2006 HSD PJ GUN, 2" DIAMETER, 6 SPF, FULLY LOADED. FIRST ATTEMPT MISRUN. RIH WITH SAME TOOLSTRING WITHDIFFERENT ..DETONATOR DATE SHIFT CODE. .CONDUCT EMERGENCY RESPONSE DRILL WITH PE. PERFORATE INTERVAL OF 12150-12160 FT. 2" 2006 HSD PJ, 6 SPF, 60 DEG PHASING. $ PERFORATE INTERVAL OF 12130-12140 FT. 2" 2006 HSD PJ, 6 SPF, 60 DEG PHASING. CONFIRMED ALL SHOTS FIRED. WELL LEFT SHUT IN, SSV CLOSED, TREE CAP ON AND TESTED. FINAL T/I/O = 20/0/0. ~__ _ ~*""JOB COMPLETE*'''' U 6/12/2010 T/I/0=2100/0/160 temp=100" Perform injectivity test [Profile mod] Rigged up to :tubing and pumped 5 bbls neat meth, 50 bbls diesel to load. Pumped additional 52 ; bbls diesel to capture injection rates of .7 BPM @ 1400 psi, .95 BPM @ 1700 psi, 1.45 BPM @ 2000 psi. Return well to injection **Swab- closed, Wing,SSV, Master, I IA, OA valves open on departure"* FWHP's= 500/0/60 7/3/20101 T/I/0=1720/140/120 Temp=145" IA FL for fullbore. IA FL is at surface. On water injection. SV=C WV, SSV, MV=O IA, OA=OTG NOVP 7/5/2010 T/I/O = 1900/200/50 -Bullhead Mud Acid Stimulation: Spear in w/ 5 bbls of I Methanol. Perform injectivity test. Pump: 100 bbls of 1 %KCI, 25 bbls of 3% NH4CL + ~ 10% U67 + 0.2% F103, 30 bbls of 12% HCI, 30 bbls of 9% HCI-1 % HF, 100 bbls of NH4CI. Displace with 300 bbls of 1 %KCI. Turn well over to Pad Op to return to injection. Titrations= HCL- 12.7%, and HCL 9.2% w/ HF 1.1 %. 7/5/2010'. T/I/0= 1900/200/100. Temp= 100*. Assist Fullbore, using triplex, pressure up IA to 1000 psi with methanol (acid stimulation). Increased IAP from 200 psi to 1000 psi in 8 minutes. OAP decreased to 50 psi. Maintained pressure during SLB acid stimulation. Bled IAP from 860 psi to 100 psi in 15 minutes. 30 minute monitor. IAP increased 50 psi. Final WHP's= 360/150/10. **Job complete** SLB has control of valves. FLUIDS PUMPED BBLS 12 METHANOL 100 1%KCI 25 3% NH4CL + 10% U67 + 0.2% F103 30 12% HCI 30 9% HCI-1 % HF 100 3% NH4CL 104 DIESEL 280 1 %KCI 681 TOTAL i rat = rivet, ~r~v ~ WELLF~EAD= FMC ACTUATOR = AXELSON KB. ELEV = 64' BF. ELEV = KOP = 3000' Max Angle = 96 @ 13400' Datum MD = 12287' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" 2725' 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" (~ 11480' 5-112" TBG, 17#, N-80, .0232 bpf, ID = 4.892" ~ 11523' Minimum ID = 2.441 @ 11563' 3-1i2" X 2-718" CROSSOVER TOP OF 7" LNR -I 11550' SAFETY N : FHLtTIW HBBP PKRS HAVE -16A REDUCED T PRESSURE LIMITS IN SOME CASES - CONTACT ACE x5102 PRIOR TO PRESSURE TESTING. HORIZONTAL WELL - 70° @ 12530' AND 90° @ 12988' 2155' 5-112" CAMCO BAL-O SSSV NIP, ID = 4.56" 11424' 11458' 11489' 11514' 11523' 11533' 19-5/8" X 5-1/2" TNV HBBP-T PKR 5-112" HES XN NIP, ID = 4.55" 5-1/2" UNIOUEOVERSHOT' 5-1/2" BAKER PBR ASSY 5-1/2" X 4-1/2" XO, ID = 3.958"~ 9-518" X 4-112" BKR FHL PKR 11559' -(4-112" G SE4L SUB " ' 11563' 112" X 2 7/8" XO ID = 2 441" 3 TOP OF 2-7/8 LNR 11563 - - , . 1 ' X NIP / " OT ID 1 584 , 4-1 2 IS = 3.81 1/2" TBG N-80 12 6# 0152 b f ID = 3 958" 11586' 11586' 4-1/2" WLEG (BEHIND LNRj , . , , . , p . 11591' ELMD TT LOGGED 05/03185 9-5/8" CSG, 47#, L-80, ID = 8.681" 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I-I 12280' PERFORATION SUMMARY REF LOG: NGP ON 04/12/97 ANGLE AT TOP PERF: 47° @ 12130' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 12130 - 12140 O 05/31/10 2" 6 12150 - 12160 O 05/31/10 2" 6 12300 - 12360 O 01/25/04 2" 6 12850 - 12890 C 01/28/02 2" 6 12920 - 12940 C 01/28/02 2" 6 13360 - 13410 C 01/26/02 2" 4 13825 - 13900 C 01!29/00 1-11/16" 4 14470 - 14550 C 04/02/98 2-1/8" 4 15050- 15090 C 06(23!97 2-118" 4 15178 - 15278 C 04(15/97 12210' 2-718" CIBP (05!31110) 7" MILLOUT WINDOW 12280' 12400' 2-718" CIBP 12540' FISH-1.315"OD X 24" BRASS PRONG 01/18/04) 13190' 2-718° CIBP (ov2s/o2~ 13600' 2-7/8"CIBP (11/23100} 14100' 2a/s" ciBP(ov28/OO{ 14750' 2-1/2" CIBP(03/02/98} 15161' FISH -2-1/8" GUNS - 118' FIRED PBTD -~ 15300' ~' 2-7/8" LNR, 6.5#, L-80, .0058 bpf, ID = 2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS 04/08/85 ORIGINAL COMPLETION 05/30106 PPJ/PJC PERF CORRECTIONS 03/11/98 WORKOVER 06/02110 MV/PJC CIBP/ ADPERFS (05!31/10) 06!24/02 BHC/TLH PERF INFO CORRECTION 07(01/02 BHC/KK PERF INFO CORRECTION 01/19/04 JBM~TLH FISH 01/25/04 CAO/TLP PERFS, CIBP, PERFANGLE PRUDHOE BAY UNIT WELL: 03-16A PERMIT No: 1970330 API No: 50-029-20415-01 SEC 10, T10N, R15E, 1637.6' FEL & 2205.8' FNL BP Exploration (Alaska) • ~~Q~C~ 0~ Q~Q~~{Q /~...~..~o~.~. Whitney King ~ n ~~ Petroleum Engineer ~~~;-, ~~'t? ~a ~~ ~~;~ m BP Exploration (Alaska), Inc. ~ ~ ' F/ P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU 03-16A Sundry Number: 310-131 Dear Mr. King: 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 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, Daniel T. Seamount, Jr. Chair DATED this ~ day of April, 2010. Encl. ' ' STATE OF ALASKA ~~~~1~~-~~ CIO `~ f`f~'~~ ALASI~IL AND GAS CONSERVATION COMMISSI~ ,,~~~~~/~ ,~c~ °~ APPLI ATI N F R NDRY APPR VALS APR 15'~111ll ~1,i C O O SU O 20 AAC 25.280 ~.. _a._ ~ a ~?.... Panne 1. Type of Request: Abandon ^ Plug for Redrill ^ Pertorate New Pool ^ Repair Well ^ e rogram ^ Suspend ^ Plug Perforations V[~~•i$ P Perforate0 - Pull Tubing ^ Time Extension ^ Operation Shutdown ^ Re-enter Susp. Well ^ Stmulate^~ _ Alter Casing ^ ^ Y /L Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 197-0330- 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ _ 6. API Number: Anchorage, AK 99519-6612 50-029-20415-01-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ^~ ^ PBU 03-16A - Spacing Exception Required? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): _ ADLO-028328 - Prudhoe Bay Field / Prudhoe Bay Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 14750 Junk (measured): 15311 _ 8979.52 12339 8901.65 12399 13190 13600 14100 12540' 15161' Casing Length Size MD TVD Burst Collapse Conductor 73 20"94# H-40 1530 103 30 103 1530 520 Surface 2696 13-3/8" 72# L-80 29 2725 29 2725 4930 2670 Production 11802 9-5/8" 47# L-80 28 11830 28 8554 6870 4760 Liner 730 7"29# L-80 11550 12280 8365 8860 8160 7020 Liner 4 3-1/2" 9.3# L-80 11559 11563 8371 8374 10106 10530 Liner 3748 2-7/8" 6.5# L-80 11563 15311 8374 9005 10570 11160 Perforation Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 5-1/2" 17# L-80 26 11523 - - 4-1/2" 12.6# N-80 11523 11586 Packers and SSSV Tvoe: 5-1/2" BTDP-1 SSV Packers and SSSV MD and TVD (ftl: 2155 2155 5-1/2" HBBP-T Packer 11424 8257 4-1/2" Baker FHL Packer 11533 8331 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposedwork: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/21/2010 Oil ^ Gas ^ WDSPL ^ Plugged ^ 16. Verbal Approval: Date: WINJ Q - GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Whitney King Printed Name Whitne Kin Title P E Signature ~ Phone Date - 564-4840 4/14/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: /~ ~ -' l Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~ Q , ~~ Subsequent Form Required: APPROVED BY ~ /~ ~ ~ I O Approved by: COMMISSIONER THE COMMISSION Date: I BDMS PR 2 0 ZO f ~Y•!G •/o Form 10-403 Revised 12/2009 f \ ~ ~ ~ ~ H ~ ~ ~ f~/~ Submit in Duplicate 03-16A 197-033 PERF OTTOrHMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 03-16A 4/15/97 PER 15,178. 15,278. 8,982.79 8,979.67 03-16A 6/23/97 APF 15,050. 15,090. 8,987.35 8,985.86 03-16A 3/2/98 BPS 14,750. 15,278. 9,002.54 8,979.67 03-16A 4/2/98 APF 14,470. 14,550. 9,019.34 9,016.16 03-16A 1/28/00 BPS 14,100. 14,550. 9,023.56 9,016.16 03-16A 1/29/00 APF 13,825. 13,900. 9,017.77 9,018.82 03-16A 11/23/00 BPS 13,600. 13,610. 9,019.14 9,019.08 03-16A 12/1/00 APF 13,360. 13,410. 9,032.85 9,028.02 03-16A 1/26/02 BPS 13,190. 13,200. 9,043.76 9,043.13 03-16A 1/27/02 APF 12,870. 12,890. 9,039.81 9,043.79 03-16A 1/27/02 APF 12,920. 12,940. 9,048.44 9,050.63 03-16A 1/28/02 APF 12,850. 12,870. 9,035.22 9,039.81 03-16A 1/24/04 APF 12,330. 12,360. 8,865.76 8,882.08 03-16A 1/24/04 BPS 12,399. 13,190. 8,901.65 9,043.76 03-16A 1/25/04 APF 12,300. 12,330. 8,847.66 8,865.76 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 To: Jerry Bixby /Clark Olsen Date GPB Well Ops Team Leaders #: APBD03WL16 Whitney King DS 03 Pad Engineer From: Josiah Igwe Wells Engineer AFE: Est. Cost: Subject: 03-16A Set CIBP / Adperf 20' IOR: Please perform the following well work on DS 03-16A April 13, 2010 PBD03WL16-C $150, 000 100 1 F SBG 2 S Drift and to TD w/dumm erf un w/sand bailer. 3 E Set CIBP & Ad erf 20' 4 FP Formation Break down 5 FP Acid Stimulation Current Status: Operable Injector Last Test: 03/30/2010 1413 W H I P and 13669 bwpd Max Deviation: 96° @ 13400' MD (47° @ 12150' MD) Minimum ID: 2.441" @ 11,563'MD at 3-1/2" x 2-7/8" XO Last Downhole ops: S/Line logged w/ gyrodata tool to 12400' on 01/24/2009 Last Tag SL tag sticky bottom at 12,286' SLM on 02/08/2008 Latest H2S Value: N/A SBHP/SBHT 12/15/2003: 3664 psi @ 8674' SS / 151 deg F Well Detail Objectives: The objective of this procedure is to change injectivity in well 03-16 by adding perfs into the 45P and 46P. The CIBP will be set to isolate the new perfs from the old ones and maintain injectivity into just the 45 and 46P. A pert breakdown will most likely needed to establish injection into the new sets of perfs. A pending acid step is included in case there is low injectivity into the new perforation interval. This adperf should also increase pressure support for near by wells (03-23, 03-02). Well History Well 03-16 is an operable MIST injector at the end of its cycle. The well was originally completed in April of 1985 and sidetracked in April of 1997. The well has 5-1/2" x 4-1/2" tubing with a 2-7/8" liner.. Injections rates have been falling in this well. Infectivity had little increase following a recent SBG. r ',. DS 03-16A: Set IBP/AdPerf~ ~#: APBD03WL16 > 03/27/98: Attempted Adperf. Stuck gun was fished. > 04/13/98: and 12/23/98: Acid Stim > 10/27/99: FCO > 01 /28/00 and 01 /29/00: CT Adperf > 02/15/00: Perf wash (DAD Acid) > 11/22/00 - 12/02/00: CT attempted FCO, set CIBP, adperf, acid stim > 01/26/02 - 01/28/02: CT Set CIBP, adperf, acid stim > 01/24/05 - 01/25/04: E/L Set CIBP, adperf > 05/02/04: Acidize perfs > 01 /23/09: SL reached 12341' SLM > 01/24/09: E/L reached 12322' ELMD Risks/Discussion: Previous wireline drifts have been unable to reach 12400' where CIBP has been set even though the deviation between 12300' - 12400' is only 50 - 60 degrees. There have been problems with schmoo and FCOs in this well. Possible schmoo build up. Note: unable to reach 12400' with wireline. Contacts: Whitney King Production Engineer Off/Cell: 564-4840/310-989-7674 Josiah Igwe Wells Engineer Off/Cell: 564-4753/590-0610 Attachments• o Perforating procedure -page 6 o Tie-in Log: SLB Perforating Record Dated: 01/24/2004 Page 7 o Wellbore Schematic page 8 o Penetration Diagrams pages 9 & 10 Fullbore: 1. Record injection pressure and rate for 03-16i 2. SI well 3. RU to 03-16i tubing and pump 5 bbls of 60/40 methanol 4. Pump 280 bbls of Schmoo-B-Gone mix. (48 bbls of concentrate in 232 bbls of at 160°F water) followed by 5 bbls of 60/40 methanol. o Do not exceed a WHIP of 2,000 psi. 5. Wait for three hours. 6. Notify Pad operator to put well on injection (target 10,000 bwpd). 2 ' ~ " . DS 03-16A: Set IBP/AdPerf~ ~#: APBD03WL16 7. RDMO. S-Line Procedure 1. Drift and tag TD with dummy pert gun and TEL. E-Line Perforation Procedure 1. MIRU SWS. 2. MU tool string with 2-7/8" CIBP/GR/CCL 3. Log up hole to correlate depths and set CIBP at 12,200' o Note Max. OD of HES 2-7/8" CIBP is 2.18" 4. Carefully slack off weight and pressure test plug to 3,000 psi to ensure a good set. 5. MU and RIH Gun #1 SLB 10' gun 2006 PowerJet HMX, 6 SPF 60 deg phasing. o Note Max. diameter of gun in liquid/gas after shot is 2.16'%2.21': (Make sure there is enough fluid at the shooting depths) 6. Perforate interval (12,150' - 12,160') o Note any tubing pressure change in the AWGRS summary 7. At surface, makeup BHA #2 SLB 10' gun 2006 Powerjet, 6 SPF 60 degree phasing 8. RIH and correct to top shot depth w/CCL 9. Perforate interval (12,130' - 12,140') 10. POOH, RD E-Line and handover well back to operator to POI @ 10,000 bwpd. • Break down formation step will proceed if the injection rate is less than 10,000 bwpd 3 . DS 03-16A: Set IBP/AdPerf~ ~#: APBD03WL16 Pend inq Fullbore Perfs Breakdown: 1. MIRU LRS 2. Pump down tubing with 5 bbls of 60/40 meth, then 50 bbls of diesel to establish injection rate 3. Capture injection rates at 1,400 psi, 1,700 psi and 2,000 psi for 15 minutes each 4. Bleed pressures to normal 5. If injection rate is less than 10,000 bwpd please proceed with the stimulation below. Stimulation target Note: The stimulation target is the pert interval 12,130' to 12,140' and 12,150' to 12,160' ELM and will be done with full bore. Pending Fullbore- Bullhead Mud Acid Stimulation Note: Before starting operation please ensure the followings; ^ Close wing valve ^ Freeze protect injection line as necessary. ^ Ensure all safety measures required for acid treatment are in place before proceeding with this job ^ Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location ^ Trap 1000 psi on the IA and monitor every 30 minutes during treatment and note on WRS ^ Ensure that well is ready to be POI immediately after acid treatment is pumped away ^ Pump acid within 24 hours of mixing - if job is delayed call SLB to add fresh corrosion inhibitor, this is because of the shelf life of corrosion inhibitor ^ Ensure triplex pump is tied into the IA to maintain 1000 psi through out this operation 1. MIRU SLB pump 2. Shut in well and trap 1000 psi in the IA. 3. Hold a detailed PJSM discussing acid handling and PPEs • Ensure acid shower trailer is at location and inspected 4 .~ DS 03-16A: Set IBP/AdPerf~ ~#: APBD03WL16 • Ensure that current MSDS sheets are onsite and acid safe handling procedures are followed 4. PT treatment lines are tested to 4,500 psi 5. Mix/Circulate acid in the vac truck to ensure homogenous solution at pump time. 6. Pump 5 bbls of 60/40 meth ahead and perform injection test starting form 0.5 bpm followed with 0.5 bpm increments not exceeding 1500 psi 7. Bullhead acid treatment as follows; • Record rate, well head pressure, annulus pressure in the WRS through out this job. a) 100 bbls of 1 % kcl b) 25 bbls of 3% NH4CL + 10% U67 + 0.2% F103 c) 30 bbls of 12% HCI d) 30 bbls of 9% HCI-1 % HF e) 100 bbls of 3% NH4C1 f) Displace to perfs (approximately 420 bbls) with 1 % kcl and freeze protect Acid Additives /concentrations Corrosion Inhibitor 0.5% A261, 8 t A153, 4 t A179 Surfactant 0.2% F103 Iron Reducin A ent 20 t L58 Nonemulsifier 0.5% W54 Antislud e A ent 0.5% W60 Fe + concentration <300 m Acceptable acid concentrations is +/- 1 % HCL and +/- 0.25% for for HF. 8. RDMO. 9. Notify Pad Operator to return well on injection +/-10,000 BWPD. 5 ,~ DS 03-16A: Set IBP/AdPerf~ ~#: APBD03WL16 6 - ' ~~-~. DS 03-16A: Set IBP/AdPerf~ 'Ul1LHFAD = FMC \CTUATOR= AXELSON :B. ELEV = 64' 3F. ELEV = -- :OP = __ 3000' Aax_A_ngle = 96 @_1_3400' Tatum MO = _ 12287 )alum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.34 I 2725' I 5-1/2" TBG, 17#, L-80, .0232 bpf, O = 4.892" ~ 11480' TOP OF 5-112" 78G 114$0' 5-1/2" TBG, 17#, N-80, .0232 bpf, 1D = 4.892" 11523' TOP OF 4-1/2" TBG 11523' Minimum ID = 2.441 @ 11563' 3-112" X 2-718" CROSSOVER TOP OF 7" LNR 11550' TOP OF 2-718" LNR {- j 11563' 112" TBG, 12.6#, N-80, .0152 bpf, ID = 3.958" I-I 11586' 9-5/8" CSG, 47#, L-80, ID = 8.681" I 11830' 7" LNR, 29#, L-80, .0371 bpf, O = 6.184" 12280' PERFORATION SUMMARY REF LOG: NGP ON 04112/97 ANGLE AT TOP PERF: 50 @ 12300' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2" 6 12300 - 12360 O 01 /25!04 2" 6 12850- 12890 C 01/28!02 2" 6 12920. 12940 C 01/28/02 2" 6 13360-13410 C 01(26/02 2" 4 13825- 13900 C 01/29/00 1-11(16" 4 14470 - 14550 L' 04/02198 2-118" 4 15050 - 15090 C 06/23/97 2-118" 4 15178 - 15278 C 04/15/97 #: APBD03WL16 u'+rci ~ ~w~ca. n-au nrr noor rrvto nnvc O ~ -16A REDUCED TEST PRESSURE LIMITS IN SOME CASES • CONTACT ACE x5102 PRIOR TO PRESSURE TESTING. HORIZONTAL WELL - 70° @ 12530' AND ~ 90° @ 12988' 21.55' ~ 5-1/2" CAMCO BAL-O SSSV NIP. ID = 4.5f 11424' -j 9-518" X 5-112" TNV HBBRT f 11458' 5-1/2" HES XN NIP, ID = 4.55" 1/2" UNIQUEOVERSHOT 11489' --~5 - 11514' 5-1/2" BAKER PBR ASSY 11523' 5-112"X4-112"X01 11533' 9-5/8" X 4-1/Z" BKR FHL PKF -~ 11559' ~--) 4-112" G SEAL SUB I 11563' 3-1/2" x 2-7la" xo, to = 2.aar' 115$4' 4-1f2" OTIS X LANDING NIP, ID = 3.81" 11586' 4-1/2" TUBING TAIL W/ WLEG (BEHIND LNR) 11591' F1M0 T7 LOGGED 05/03/85 7" MILLOUT WINDOW 12280' 12400' 2als° cIBP 12540 FISH (1.315"OD X 24" BRASS PRONG 01/18!04) iJ-I 2-7/8" CIBP SET 01/26/02 13600' gals" CIBPSET 11/23/00 14100' z-71a°c~PSErovzs/o0 14750' -{ 2-1lZ" CIBP SET 03/02/98 15161' 2-1/8" GUNS - 118' FIRED 15311' za/B" FL4S TM FLT/GD SHOE I 15300' f f 2-718" LNR, 6.5#, L-80, .0058 bpf, 10 = 2.441" ~- j 15311' I DATE REV BY COMMENTS DATE REV BY COMMENTS FRUDHOE BAY UNIT 04/08/65 -......"... ORIGINAL COMPLETION 05!30!06 PPJIPJC PF}2F CORRECTIONS WELL: 03-16A 03N1198 WORKOVER PERMfTNo: 1970330 06124102 BHGTLH PERT WFO CORRECTION API No: 50-029-204}5-Ot 07/01/02 BHGKK PERF ~1F0 CORRECTION SEC 10, T10N, R15E, 1637.6' fEL & 2205.8' FNL 01/19104 JBM/TLH FISH n1/7fi/nd f:A llffl P PFRFR (:IRP PFRF ANf;I F RP Fvntnraflnn /Atae 4al 7 gyrodafa Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 SURVEY REPORT BP Drill Site #DS03-16A Wellhead Prudhoe Bay, AK AK0109G_107 24 Jan 2009 Serving the Worldwide Energy Industry with Precision Survey Instrumentation --~ ~~,,u..~. ~ cam-- ~! ~ ~ 97 - ~3 3 gyrodafa Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 February 23, 2009 State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: Drill Site, Well #DS03-16A Prudhoe Bay, Alaska Enclosed, please find two (2) copies, and one (1) disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, ~~~~ Rob Shoup r North American Regional Manager RS:tf Serving the Worldwide Energy Industry with Precision Survey Instrumentation A Gyrodata Directional Survey for BP EXPLORATION (ALASKA) Lease: Drill Site Well: DS03-16A, Location: Wellhead, Prudhoe Bay, Alaska Job Number: AK0109G 107 Run Date: 24 Jan 2009 Surveyor: Jamie McCrimmon Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.231656 deg. N Longitude: 148.278969 deg. W Azimuth Correction: Gyro: Bearings are Relative to True North Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location s • Horizontal Coordinates Calculated from Well Head Location BP Exploration (Alaska) Lease: DriII Site Well: DS03-16A Location: Wellhead, Prudhoe Bay, Alaska Job Number: AK0109G 107 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. A Gyrodata Directional Survey BORE HOLE BEARING deg. min. DOGLEG SEVERITY deg./ 25 ft. VERTICAL CLOSURE DEPTH DIST. AZIMUTH feet feet deg. 0.00 0.00 0.00 N 0 0 E 0.00 0.00 0.0 0.0 0 - 12325 FT. RATE GYROSCOPIC MULTISHOT SURVEY ALL MEASURED DEPTHS AND COORDINATES REFERENCED TO ORIGINAL R.K.B. OF 64 FT. AMSL 100.00 0.18 140.00 S 40 0 E 0.04 100.00 200.00 O.SO 275.75 N 84 1S W 0.16 200.00 300.00 0.39 194.32 S 14 19 W 0.15 300.00 400.00 0.64 200.06 S 20 4 W 0.06 399.99 500.00 0.40 235.68 S SS 41 W 0.10 499.99 600.00 0.23 222.88 S 42 53 W 0.05 599.99 700.00 0.65 180.79 S 0 47 W 0.13 699.98. 800.00 0.54 153.24 S 26 46 E 0.08. 799.98 900.00 0.19 237.46 S S7 '27 W 0'.14 899.98 1000.00 0.25 ` 292.20 N 67 48 W 0.0.5 999.98 1100.00 0.34 272..71 N 87 17 W 0.03 1099.98 1200.00 O.SO 98.90 S 81 6 E 0.21 1199.97 1300.00 0.48 96.30 S 83 42 E 0.01 1299.97 1400.00 O.SZ 134.64 S 4S 21 E 0.08 1399.97 1500.00 0.28 231.57 S S 1 34 W 0.15 1499.97 1600.00 0.33 90.69 S 89 19 E 0.14 1599.96 1700.00 O.SO 202.39 S 22 23 W 0.17 1699.96 1800.00 0.64 131.05 S 48 S7 E 0.17 1799.96 1900.00 0.83 163.91 S 16 S E 0.11 1899.95 2000.00 0.51 108.92 S 71 S E 0.17 1999.95 HORIZONTAL COORDINATES feet 0.00 N 0.00 E ------------------------------- 0.2 140.0 0.12 S 0.3 230.8 0.19 S 0.9 237.4 0.48 S 1.7 217.6 1.34 S 2.6 216.2 2.06 S 3.1 218.8 2.40 S 3.7 213.7 3.11 S 4.5 204.5 4.10 S 4.9 201.4•: 4.61 S S.1 204:9 4.62 S 5.2 210.4.... 4.52 S 5:2 208.8 4.57 S S.0 199.5 4.69 S S.1 190.3 S.OS S S.6 188.1 5.52 S S.7 186.9 5.68 S 6.1 185.4 6.08 S 6.9 182.6 6.84 S 7.9 177.8 7.91 S 8.8 173.9 8.76 S 0.10 E 0.24 W 0.75 W 1.03 W 1.51 W 1.93 W 2.08 W 1.87 W 1.80 W 2.1SW 2.65 W 2.51 W 1.66 W 0.92 W 0.79 W 0.69 W 0.57 W 0.31 W 0.31 E 0.94 E • 2 BP Exploration (Alaska) Lease: Drill Site Well: DS03-16A Location: Wellhead, Prudhoe Bay, Alaska Job Number: AK0109G 107 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. A Gyrodata Directional Survey BORE HOLE BEARING deg. min. DOGLEG SEVERITY deg./ 25 ft. VERTICAL CLOSURE HORIZONTAL DEPTH DIST. AZIMUTH COORDINATES feet feet deg. feet 2100.00 1.12 90.37 S 89 38 E 0.16 2099.93 9.2 165.3 8.91 S 2.34 E 2200.00 1.00 90.82 S 89 11 E 0.03 2199.92 9.9 154.8 8.93 S 4.19 E 2300.00 0.89 94.39 S 85 36 E 0.03 2299.90 10.7 147.0 9.00 S 5.84 E 2400.00 0.72 120.68 S 59 19 E 0..10 2399.89 11.8 142.7 9.38 S 7.15 E 2500.00 0.74 142.65 S 37 21 E 0.07 2499.89 13.0 141.6 10.21 S 8.08 E 2600.00 0.73 160.14 S 19 51 E 0.06 2599.88 14.3 142.5 11.32 S 8.69 E 2700.00 0.85 158.20 S 21 48 E 0.03 2699.87 15.6 143.9 12.61 S 9.18 E 2800.00 0.84 203.90 S 23 54 W 0.16 2799.86 16.7 146.8 13.98 S 9.16 E 2900.00 6.22 297.85 N 62 9 W 1.58 2899.66 12.8 161.4 12.11 S 4.07 E 3000.00 11.04 292.74 N 67 16 W 1.22 2998.50 11.2 238.4 5.88 S 9.56W 3100.00 13.23 283.37 N 76 38 W 0.73 3096.27 29.5 270.9 0.47 N 29.53 W 3150.00 14.64 282.20 N 77 48 W 0.72. 3144.80 41.4 274.3 3.13 N 41.27 W 3175.00 15.11 .:.281.20 N 78 48 W 0.53 3168.96 47.8 275.3 4.43 N 47.55 W 3200.00 15.74 279.2'7 N 80 44 W 0.82 3193.06 54.4 275.9 5.61 N 54.10 W 3225.00 16.06 277.73 N 82 16 W 0.53 3217.10 61.2 276.2 6.62 N 60.87 W 3250.00 16.37 274.98 N 85 " 1 W 0.83 3241.'1 l 68.2 276.2 7.39 N 67.81 W 3275.00 16.48 272.31 N 87 41 W 0.76 3265.09 75.3 276.0 7.84 N 74.87 W 3300.00 16.43 270.18 N 89 49 W 0.61 3289.06 82.3 275.6 7.99 N 81.94 W 3325.00 16.13 266.66 S 86 40 W 1.03 3313.06 89.3 275.0 7.80 N 88.95 W 3350.00 16.10 264.63 S 84 38 W 0.56 3337.08 96.1 274.3 7.28 N 95.86 W 3375.00 15.96 261.85 S 81 51 W 0.78 3361.11 102.9 273.6 6.46 N 102.72 W 3400.00 16.09 259.45 S 79 27 W 0.68 3385.14 109.7 272.8 5.34 N 109.53 W 3425.00 16.32 258.36 S 78 22 W 0.38 3409.14 116.4 272.0 4.00 N 116.37 W 3450.00 16.56 257.91 S 77 55 W 0.26 3433.12 123.3 271.2 2.55 N 123.30 W 3 A Gyrodata Directional Survey BP Exploration (Alaska) Lease: Drill Site Well: DS03- 16A Location: Wellhead, Prudhoe Bay, Alaska Job Number: AK0109G 107 MEASURED I N C L AZIMUTH BORE HOLE DOGLEG VERTICAL CLOS URE HORIZON TAL DEPTH BEARING SEVERITY DEPTH DIST. AZIMUTH COORDINATES feet deg. deg. deg. min. deg./ feet feet deg. feet 25 ft. 3475.00 16.95 257.68 S 77 41 W 0.40 3457.06 130.3 270.4 1.02 N 130.34 W 3500.00 17.29 257.55 S 77 33 W 0.35 3480.95 137.5 269.8 0.56 S 137.53 W 3525.00 17.97 257.68 S 77 41 W 0.68 3504.78 144.9 269.1 2.18 S 144.92 W 3550.00 18.41 257.87 S 77 52 W 0.45 3528.53 152.6 268.6 3.83 S 152.55 W 3575.00 19.09 258.20 S 78 12 W 0.68 3552.20 160.5 268.0 5.50 S 160.41 W 3600.00 19.80 258.69 S 78 41 W 0.73 3575.78 168.7 267.6 7.16 S 168.57 W 3625.00 20.47 259.15 S 79 9 W 0.68 3599.25 177.2 267.1 8.82 S 177.01 W 3650.00 21.33 259.72 S 79 43 W 0.88 3622.60 186.1 266.8 10.45 S 185.78 W 3675.00 22.22 260.16 S 80 10 W 0.91 3645:82 195.3 266.5 12.07 S 194.91 W 3700.00 23.10 260.46 S 80 28 W 0.88 3668.89 204.9 266.2 13.69 S 204.40 W 3725.00 23.98 260.86 ' S 80 51 W 0.90 3691.81 214.8 265:9 15.31 S 214.25 W 3750.00 24.82 261.07 S` 81 4 W 0.84. 37.14.58 225..1 265.7 16.93 S 224.45 W 3775.00 25.82 261.37 S 81 22 W 1.02 3737.17 235.8. 265.5 18.56 S 235.02 W 3800.00 26.78 261.82 S 81 49 W 0.98 .~ 3759.59 246.8 265.3 20.18 S 245.98 W 3825.00 27.60 262.07 S 82 4 W 0.83 3781.82 258.2 265.2 21.78 S 257.29 W 3850.00 28.36 262.40....... S 82 ,24 W 0.77... -.....3803..90. 269.9. ....265,0 23.37 S 268.91 W 3875.00 29.22 262.62 S 82 37 W 0.87 3825.81 282.0 264.9 24.94 S 280.85 W • 3900.00 29.91 262.89 S 82 54 W 0.70 3847.56 294.3 264.8 26.49 S 293.08 W 3925.00 30.80 263.10 S 83 6 W 0.90 3869.13 306.9 264.8 28.03 S 305.62 W 3950.00 31.46 263.38 S 83 23 W 0.68 3890.53 319.8 264.7 29.55 S 318.46 W 3975.00 32.23 263.57 S 83 34 W 0.78 3911.76 333.0 264.6 31.05 S 331.57 W 4000.00 33.13 263.65 S 83 39 W 0.89 3932.81 346.5 264.6 32.55 S 344.98 W 4025.00 33.93 263.77 S 83 46 W 0.81 3953.65 360.3 264.6 34.06 S 358.71 W 4050.00 34.91 263.99 S 83 59 W 0.99 3974.27 374.5 264.5 35.57 S 372.76 W 4 BP Exploration (Alaska) Lease: Drill Site Well: DS03-16A Location: Wellhead, Prudhoe Bay, Alaska Job Number: AK0109G 107 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. 4075.00 35.72 264.06 4100.00 36.54 264.14 4125.00 37.54 264.29 4150.00 38.26 264.25 4175.00 38.89 264.21 4200.00 39.63 264.16 4225.00 40.41 264.17 4250.00 41.28 264.14 4275.00 42.07 264.28 4300.00 42.82 264..38 4325.00 43.66 264.50 4350.00 44.25 264.67 4375.00 44.97 264.62` 4400.00 45.76 264.72 4425.00 46.45 264.70 4450.00 47.01 ..264.75 4475.00 47.52 264.59 4500.00 47.99 264.43 4525.00 48.33 264.14 4550.00 48.90 264.10 4575.00 49.53 264.09 4600.00 50.23 264.09 4625.00 50.91 264.04 4650.00 51.58 264.09 A Gyrodata Directional Survey B ORE HOLE DOGLEG VERTICAL CLOS URE HORIZON TAL BEARING SEVERITY DEPTH DIST. AZIMUTH COORDINATES deg, min. deg./ feet feet deg. feet 25 ft. S 84 4 W 0.81 3994.67 388.9 264.5 37.08 S 387.13 W S 84 8 W 0.82 4014.86 403.6 264.5 38.59 S 401.79 W S 84 17 W 1.00 4034.81 418.7 264.5 40.11 S 416.78 W S 84 15 W 0.72 4054.54 434.1 264.5 41.64 S 432.06 W S 84 13 W 0.63 4074.09 449.6 264.5 43.21 S 447.57 W S 84 10 W 0.74 4093.44 465.5 264.5 44.81 S 463.31 W S 84 10 W 0.78 4112.59 481.5 264.5 46.44 S 479.30 W S 84 9 W 0.87 4131.50 497.9 264.5 48.11 S 495.56 W S 84 17 W 0.79 4150.17 514.5. .264.4 49.78 S 512.10 W S 84 23 W 0.76 4168.62 531.4 264.4 51.45 S 528.89 W S 84 30 W 0.84 4186.83 548.5 264.4 53.11 S 545.94 W S 84 40 W 0.61 4204.83 565.9 264.4. 54.75 S 563.21 W S 84 37 W 0.72 4222.63 583.4 .264:5 56.39 S 580.69 W -S 84 43 W 0.79 4240.19 601.2 264.5 58.04 S 598.41 W 3 84 42 W 0.69 4257.53 619.2 264.5 59.70 S 616.34 W S 84 45 W 0.56 4274.66 .637.4 264.5 - 61.37 S 634.47 W S 84 35 W 0.53 4291.63 655.8 264.5 63.08 S 652.75 W S 84 26 W 0.48 4308.43 674.3 264.5 64.85 S 671.17 W S 84 9 W 0.40 4325.11 692.9 264.5 66.71 S 689.71 W S 84 6 W 0.58 4341.64 711.7 264.5 68.63 S 708.37 W S 84 6 W 0.62 4357.97 730.6 264.5 70.58 S 727.19 W S 84 6 W 0.70 4374.08 749.7 264.4 72.54 S 746.21 W S 84 2 W 0.68 4389.96 769.0 264.4 74.54 S 765.42 W S 84 5 W 0.67 4405.61 788.5 264.4 76.55 S 784.81 W 5 • A Gyrodata Directional Survey BP Exploration (Alaska) Lease: Drill Site Well: DS03-16A Location: Wellhead, Prudhoe Bay, Alaska Job Number: AK0109G 107 MEASURED I N C L AZIMUTH BORE HOLE DOGLEG VERTICAL CLOSURE HORIZONTAL DEPTH BEARING SEVERITY DEPTH DIST. AZIMUTH COORDINATES feet deg. deg. deg. min. deg./ feet feet deg. feet 25 ft. 4675.00 52.27 264.01 S 84 1 W 0.69 4421.02 808.2 264.4 78.59 S 804.38 W 4700.00 53.11 264.14 S 84 8 W 0.85' 4436.18 828.1 264.4 80.65 S 824.16 W 4725.00 53.70 264.19 S 84 12 W 0.59 4451.08 848.2 264.4 82.69 S 844.12 W 4750.00 54.40 264.18 S 84 11 W 0.70 4465.76 868.4 264.4 84.74 S 864.26 W 4775.00 54.69 264.28 S 84 17 W 0.31 4480.26 .888.8 264.4 86.78 S 884.52 W 4800.00 54.43 264.32 S 84 19 W 0.26 4494.76 909.1 264.4 88.81 S 904.79 W 4825.00 54.36 264.34 S 84 21 W 0.07 4509.31 929.5 264.4 90.81 S 925.02 W 4850.00 54.35 264.27 S 84 16 W 0.06 4523.88 949.8 264.4 92.83 S 945.23 W 4875.00 54.36 264.35 S 84 21 W 0.06 4538.45 970.1 264.4 94.84 S 965.45 W 4900.00 54.37 264.29 S 84 17 W 0.05 4553.01 990.4 264.4 96.86 S 985.67 W 4925.00 54.20 264.24 S 84' 14 W 0.18 4567.61 1010.7 264.4 98.88 S 1005.86 W 4950.00 54.26 264.22. S 84 13 W 0.06 4582.22 1031:0 264.4 100.92 S 1026.04 W 4975.00 53.86 264.20 S 84 12 W 0.40.. 4596.89 1051.2 264.4 102.97 S 1046.18 W 5000.00 54.11 264.24 S 84 15 W 0.26 4611.59 1071.5 264.4 105.00 S 1066.30 W 5025.00 54.21 264.24 S 84 14 W 0.09 4626.23 1091.7 264.4 107.04 S 1086.47 W 5050.00 54.20 264.24. S 84 15 W 0.00. 4640.85 1112.0 ..264.4 109.07 S 1106.64 W 5075.00 54.14 264.26 S 84 15 W 0:06 4655.49 1132.3 264.4 111.10 S 1126.81 W S 100.00 54.28 264.32 S 84 19 W 0.15 4670.11 1152.6 264.4 113.12 S 1146.99 W 5125.00 54.04 264.38 S 84 23 W 0.25 4684.74 1172.8 264.4 115.12 S 1167.16 W 5150.00 54.47 264.40 S 84 24 W 0.43 4699.35 1193.1 264.4 117.10 S 1187.35 W S 175.00 54.49 264.44 S 84 27 W 0.04 4713.87 1213.5 264.4 119.08 S 1207.60 W 5200.00 54.09 264.58 S 84 35 W 0.42 4728.46 1233.8 264.4 121.02 S 1227.81 W 5225.00 54.41 264.62 S 84 37 W 0.33 4743.07 1254.0 264.4 122.93 S 1248.01 W 5250.00 54.33 264.55 S 84 33 W 0.10 4757.64 1274.4 264.4 124.85 S 1268.24 W 6 u U BP Exploration (Alaska) Lease: Drill Site Well: DS03-16A Location: Wellhead, Prudhoe Bay, Alaska Job Number: AK0109G 107 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. A Gyrodata Directional Survey BORE HOLE DOGLEG VERTICAL CLOSURE BEARING SEVERITY DEPTH DIST. AZIMUTH deg. min. deg./ feet feet deg. 25 ft. 5275.00 54.23 264.63 S 84 38 W 5300.00 54.26 264.65 S 84 39 W 5325.00 54.48 264.63 S 84 38 W 5350.00 54.47 264.85 S 84 51 W 5375.00 54.74 264.91 S 84 54 W 5400.00 54.97 265.00 S 85 0 W 5425.00 55.24 264.96 S 84 57 W 5450.00 55.30 264.90 S 84 54 W 5475.00 55.66 265.14 S 85 8 W 5500.00 55.40 265.24 S 85 14 W 5525.00 55.55 265.32 S 85- 19 W 5550.00 55.75 265.30 S 85' 18 W 5575.00 55.48 265.33 'S 85 20' W 5600.00 55.69 265.40 S 85 24 W 5625.00 55.85 265.47 S 85 28 W 5650.00 55.98 _ .:265.62 . S.: 85 37 W 5675.00 56.19 265.75 " S 85 45 W 5700.00 55.78 265.84 S 85 51 W 5725.00 55.89 265.96 S 85 58 W 5750.00 56.08 265.97 S 85 58 W 5775.00 55.88 265.91 S 85 55 W 5800.00 56.00 265.91 S 85 55 W 5825.00 55.75 265.89 S 85 54 W 5850.00 55.98 265.92 S 85 55 W HORIZONTAL COORDINATES feet 0.12 4772.23 1294.7 264.4 126.76 S 1288.44 W 0.03 4786.84 1315.0 264.4 128.66 S 1308.64 W 0.22 4801.40 1335.3 264.4 130.55 S 1328.87 W 0.18 4815.93 1355.6 264.4 132.42 S 1349.13 W 0.27 4830.41 1376.0 264.4 134.24 S 1369.43 W 0.24 4844.80 1396.4 264.4 136.04 S 1389.79 W 0.27 4859.10 1416.9 264.4 137.83 S 1410.22 W 0.08 4873.34 1437.5 264.4 139.65 S 1430.69 W 0.41 4887.51 1458.1 264.4 141.44 S 1451.21 W 0.27 4901.66 1478.7 264.4 143.17 S 1471.74 W 0.16 4915.83 1499.3 264.5 144.86 S 1492.27 W 0.20 4929.94 1519.9 264.5 146.55 S 1512.84 W 0.27 4944.06 1540.6 264:5 148.23 S 1533.40 W 0.22 4958.19 1561.2 264.5 149.90 S 1553.96 W 0.17 4972.25 1581.8 264.5 151.54 S 1574.56 W 0. I8 49.8.6.26 1..602.5 ... ..264.5 153.15 S 1595.21 W 0:24 SII00.21 1623.3 264.5 154.72 S 1615.89 W 0.41 5014.20 1644.0 264.5 156.23 S 1636.56 W 0.15 5028.24 1664.7 264.6 157.71 S 1657.19 W 0.19 5042.22 1685.4 264.6 159.17 S 1677.86 W 0.21 5056.21 1706.1 264.6 160.63 S 1698.53 W 0.12 5070.21 1726.8 264.6 162.11 S 1719.19 W 0.25 5084.24 1747.5 264.6 163.59 S 1739.83 W 0.23 5098.27 1768.2 264.6 165.07 S 1760.47 W 7 i • A Gyrodata Directional Survey BP Exploration (Alaska) Lease: Drill Site Well: DS03- 16A Location: Wellhead, Prudhoe Bay, Alaska Job Number: AK0109G 107 MEASURED I N C L AZIMUTH B ORE HOLE DOGLEG VERTICAL CLOS URE HORIZONTAL DEPTH BEARING SEVERITY DEPTH DIST. AZIMUTH COORDIN ATES feet deg. deg. deg. min. deg./ feet feet deg. feet 25 ft. 5875.00 56.10 265.96 S 85 57 W 0.12 5112.23 1788.9 264.7 166.54 S 1781.16 W 5900.00 55.80 265.94 S 85 57 W 0.29 5126.23 1809.6 264.7 168.00 S 1801.82 W 5925.00 55.83 265.85 S 85 51 W 0.08 5140.28 1830.3 264.7 169.48 S 1822.45 W • 5950.00 55.92 265.90 S 85 54 W 0.10 5154.30 1851.0 264.7 170.97 S 1843.09 W 5975.00 55.72 265.85 S 85 51 W 0.20 5168.35 1871.7 264.7 172.46 S 1863.71 W 6000.00 55.81 265.78 S 85 47 W 0.11 5182.41 1892.3 264.7 173.96 S 1884.33 W 6025.00 55.86 265.82 S 85 49 W 0.06 5196.45 1913.0 264.7 175.48 S 1904.96 W 6050.00 55.59 265.83 S 85 50 W 0.27 5210.53 1933.7 264.7 176.98 S 1925.56 W 6075.00 55.83 265.76 S 85 46 W 0.25 5224.61 1954.3 264.8 178.50 S 1946.16 W 6100.00 55.76 265.90 S 85 54 W 0.14 5238.67 1975.0 264.8 180.00 S 1966.78 W 6125.00 55.40 265.98 S 85 59 W 036 5252.80. 1995.6 264.8 181.46 S 1987.36 W 6150.00 55.58 266.00 S 86 0 W 0.18 5266.96 2016.2 264.8 182.90 S 2007.91 W 6175.00 55.70 266.08 S 86 5 W 0.14 5281.07 2036:9 264.8 184.33 S 2028.49 W 6200.00 55.53 266.02 S 86 1 W 0.18 5295.19 2057.5 264.8 185.75 S 2049.07 W 6225.00 55.44 266.00 S 86 0 W 0.09 5309.36 2078.1 264.8 187.18 S 2069.62 W 6250.00 55.45 266.10 S 86 6 R' 0.09 5323..54 209..8.7 ..264.8 ........188.60 S 2090.16 W 6275.00 55.61 266.01 S 86 1 W 0.17 5337:69 2119.3 264.9 190.02 S 2110.73 W 6300.00 55.38 266.05 S 86 3 W 0.23 5351.85 2139.9 264.9 191.44 S • 2131.28 W 6325.00 55.26 266.10 S 86 6 W 0.13 5366.08 2160.4 264.9 192.85 S 2151.79 W 6350.00 55.32 266.05 S 86 3 W 0.07 5380.31 2181.0 264.9 194.26 S 2172.29 W 6375.00 55.30 266.08 S 86 5 W 0.03 5394.54 2201.5 264.9 195.67 S 2192.80 W 6400.00 55.08 266.09 S 86 6 W 0.22 5408.81 2222.0 264.9 197.07 S 2213.28 W 6425.00 54.76 266.12 S 86 7 W 0.32 5423.18 2242.5 264.9 198.46 S 2233.69 W 6450.00 55.07 266.12 S 86 7 W 0.31 5437.55 2262.9 264.9 199.84 S 2254.10 W 6475.00 55.31 266.15 S 86 9 W 0.25 5451.82 2283.5 264.9 201.22 S 2274.58 W 8 BP Exploration (Alaska) Lease: Drill Site Well: DS03-16A Location: Wellhead, Prudhoe Bay, Alaska Job Number: AK0109G 107 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. A Gyrodata Directional Survey BORE HOLE BEARING deg. min. DOGLEG SEVERITY deg./ 25 ft. VERTICAL CLOSURE HORIZONTAL DEPTH DIST. AZIMUTH COORDINATES feet feet deg. feet 6500.00 55.06 266.20 S 86 12 W 0.26 5466.10 2304.0 265.0 202.59 S 2295.06 W 6525.00 55.47 266.17 S 86 10 W 0.41 5480.34 2324.5 265.0 203.96 S 2315.56 W 6550.00 55.42 266.33 S 86 20 W 0.14 5494.52 2345.1 265.0 205.31 S 2336.10 W 6575.00 55.34 266.34 S 86 20 W 0.08 5508.72 2365.7 265.0 206.63 S 2356.63 W 6600.00 55.41 266.23 S 86 14 W 0.11 5522.93 2386.2 265.0 207.96 S 2377.16 W 6625.00 55.26 266.26 S 86 16 W 0.14 5537.15 2406.8 265.0 209.30 S 2397.68 W 6650.00 54.89 266.23 S 86 14 W 0.37 5551.46 2427.3 265.0 210.65 S 2418.13 W 6675.00 54.89 266.28 S 86 17 W 0.04 5565.84 2447.7 265.0 211.98 S 2438.54 W 6700.00 55.25 266.29 S 86 18 W 0.36 5580.15 2468.2 265.0 213.31 S 2458.99 W 6725.00 55.39 266.40. S 86 24 W 0.16 5594.38 2488.8 265.1 214.62 S 2479.51 W 6750.00 55.41 266.32 S 86 19 W 0.07 5608.57 2509.4 265.1 215.93 S 2500.05 W 6775.00 55.21 266.38. S 86 23 W 0.21 5622.80 2529:9 265.1 217.23 S 2520.56 W 6800.00 55.58 266.33 S 86 20 W 0.37 5637:00` 2550.5 265.1 218.54 S 2541.10 W 6825.00 55.28 266.40 S 86 24 W 0.3-1 5651.19 2571.1 265.1 219.85 S 2561.64 W 6850.00 55.47 266.48 S 86 29 W 0.21 5665.39 2591.6 265.1 221.13 S 2582.17 W 6875.00 55.29 266.55 S 86 33 W 0.19 5679.60 2612.2 265.1 '222.38 S 2602.71 W 6900.00 55.55 266.61 S 86 37 W 0:26 5693.78 2632.8 265.1 223.61 S 2623.26 W 6925.00 55.66 266.71 S 86 43 W 0.14 5707.91 2653.4 265.1 224,81 S 2643.85 W 6950.00 55.63 266.72 S 86 43 W 0.03 5722.01 2674.0 265.2 225.99 S 2664.46 W 6975.00 55.69 266.66 S 86 40 W 0.07 5736.12 2694.7 265.2 227.18 S 2685.06 W 7000.00 55.97 266.79 S 86 47 W 0.29 5750.16 2715.3 265.2 228.36 S 2705.71 W 7025.00 56.14 266.86 S 86 52 W 0.18 5764.12 2736.1 265.2 229.51 S 2726.42 W 7050.00 56.28 266.81 S 86 49 W 0.15 5778.02 2756.8 265.2 230.66 S 2747.17 W 7075.00 56.41 267.00 S 87 0 W 0.20 5791.88 2777.6 265.2 231.78 S 2767.95 W n U 9 A Gyrodata Directional Survey BP Exploration (Alaska) Lease: Drill Site Well: DS03- 16A Location: Wellhead, Prudhoe Bay, Alaska Job Number: AK0109G 107 MEASURED I N C L AZIMUTH BORE HOLE DOGLEG VERTICAL CLOS URE HORIZONTAL DEPTH BEARING SEVERITY DEPTH DIST. AZIMUTH COORDIN ATES feet deg. deg. deg. min. deg./ feet feet deg. feet 25 ft. 7100.00 56.12 266.94 S 86 56 W 0.29 5805.76 2798.4 265.2 232.88 S 2788.71 W 7125.00 56.36 266.94 S 86 56 W 0.25 5819.65 2819.2 265.2 233.99 S 2809.46 W • 7150.00 56.31 266.96 S 86 58 W 0.06 5833.51 2840.0 265.3 235.10 S 2830.24 W 7175.00 56.04 266.93 S 86 56 W 0.27 5847.43 2860.7 265.3 236.20 S 2850.98 W 7200.00 56.18 266.87 S 86 52 W 0.15 5861.37 2881.5 265.3 237.32 S 2871.70 W 7225.00 55.89 266.85 S 86 51 W 0.29 5875.34 2902.2 265.3 238.46 S 2892.40 W 7250.00 55.76 266.80 S 86 48 W 0.13 5889.38 2922.9 265.3 239.60 S 2913.06 W 7275.00 55.66 266.80 S 86 48 W 0.10 5903.46 2943.5 265.3 240.76 S 2933.68 W 7300.00 55.57 266.76 S 86 46 W 0.09 5917.58 2964.2 265.3 241.92 S 2954.28 W 7325.00 55.72 266.82 S 86 49 W 0.16 5931.69 2984.8 265.3 243.07 S 2974.89 W 7350.00 55.56 266.8`I S 86 49 W 0.16 5945.79 3005.4 265.3 244.22 S 2995.49 W 7375.00 55.43 266.84, S 86 50 W 0.13 5959.96 3026.0 265.3 245.36 S 3016.06 W 7400.00 55.69 266.88 S 86 53 W 0:26 5974.09 3046.6 265.4 246.49 S 3036.65 W 7425.00 55.33 266.87 S 86 52 W 0.3..6 5988.25 3067.2 265.4 247.61 S 3057.23 W 7450.00 55.47 266:97 S 86 58 W 0.17 6002.45 3087.8 265.4 248.72 S 3077.77 W 7475.00 55.56 266.96 ,, S 86 57 W .- 0.09_,,: 60.1.6.60- 3.10..8.4..... ... 265.4........ 249.81 S 3098.35 W 7500 00 i . 55.27 266.97 S 86 58 W 0.29 6030.79 3129.0 265.4 250.90 S 3118.91 W 7525.00 55.32 266.99 S 86 59 W 0.04 6045.03 3149,5 265.4 251.99 S 3139.43 W 7550.00 55.00 266.96 S 86 57 W 0.31 6059.31 3170.0 265.4 253.07 S 3159.92 W 7575.00 54.97 266.92 S 86 55 W 0.05 6073.65 3190.5 265.4 254.16 S 3180.37 W 7600.00 55.12 266.97 S 86 58 W 0.16 6087.98 3211.0 265.4 255.26 S 3200.83 W 7625.00 54.88 267.00 S 87 0 W 0.24 6102.32 3231.5 265.5 256.33 S 3221.27 W 7650.00 54.82 266.97 S 86 58 W 0.06 6116.71 3251.9 265.5 257.41 S 3241.69 W 7675.00 54.79 267.01 S 87 0 W 0.04 6131.12 3272.3 265.5 258.48 S 3262.09 W 10 A Gyrodata Directional Survey BP Exploration (Alaska) Lease: Drill Site Well: DS03- 16A Location: Wellhead, Prudhoe Bay, Alaska Job Number: AK0109G 107 MEASURED I N C L AZIMUTH B ORE HOLE DOGLEG VERTICAL CLOSURE HORIZONTAL DEPTH BEARING SEVERITY DEPTH DIST. AZIMUTH COORDIN ATES feet deg. deg. deg. min. deg./ feet feet deg. feet 25 ft. 7700.00 54.60 267.06 S 87 4 W 0.20 6145.57 3292.7 265.5 259.53 S 3282.47 W 7725.00 54.70 267.00 S 87 0 W 0.12 6160.03 3313.1 265.5 260.59 S 3302.83 W 7750 00 54 41 26 2 • . . 7.0 S 87 1 W 0.29 6174.53 3333.5 265.5 261.66 S 3323.17 W 7775.00 54.46 267.12 ~ S 87 7 W 0.10 6189.07 3353.8 265.5 262.70 S 3343.48 W 7800.00 54.49 266.93 S 86 56 W 0.16 6203.59 3374.1 265.5 263.75 S 3363.80 W 7825.00 54.10 266.98 S 86 59 W 0.40 6218.18 3394.4 265.5 264.83 S 3384.07 W 7850.00 54.10 266.88 S 86 53 W 0.08 6232.84 3414.7 265.5 265.91 S 3404.30 W 7875.00 53.98 266.91 S 86 54 W 0.12 6247.52 3434.9 265.5 267.01 S 3424.50 W 7900.00 53.85 266.93 S 86 56 W 0.13 6262.25 3455.1 265.5 268.10 S 3444.68 W 7925.00 53.82 266.86 S 86 52 W 0.06 6277:.00 3475.3 265.6 269.19 S 3464.83 W 7950.00 53.46 266.88 S 86 53 W 0.37 6291:82 3495.4 265.6 270.29 S 3484.93 W 7975.00 53.39 266.82 S 86 49 W 0.09 6306.72 3515.5 265.6 271.39 S 3504.98 W 8000.00 53.29 266.81 S 86 49 W 0.10 6321.64 3535.5 265.6 272.50 S 3525.00 W 8025.00 53.52 266.73 S 86 44 W 0.24 6336.55 3555.6 265.6 273.63 S 3545.04 W 8050.00 53.72 266.68 S 86 41 W 0.21 6351.38 3575.7 265.6 274.79 S 3565.13 W 8075.00 53.97 266.62 S 86 37 W 0.25........ 6366.13 :3595,9 265.6,.. 275.97 S 3585.29 W 8100.00 54.52 266.58' S 86 35 W 0.56 6380.73 3616.2 265.6 277.17 S 3605.54 W 8125.00 54.61 266.51 S 86 31 W 0.11 6395.23 3636.5 265.6 278.40 S 3625.87 W 8150.00 54.65 266.42 S 86 25 W 0.08 6409.70 3656.9 265.6 279.66 S 3646.22 W 8175.00 55.47 266.55 S 86 33 W 0.83 6424.02 3677.4 265.6 280.91 S 3666.67 W 8200.00 55.80 266.56 S 86 34 W 0.33 6438.13 3698.1 265.6 282.15 S 3687.27 W 8225.00 56.08 266.60 S 86 36 W 0.29 6452.13 3718.8 265.6 283.39 S 3707.95 W 8250.00 56.33 266.55 S 86 33 W 0.25 6466.04 3739.5 265.6 284.63 S 3728.69 W 8275.00 56.38 266.50 S 86 30 W 0.07 6479.89 3760.3 265.6 285.89 S 3749.46 W 11 A Gyrodata Directional Survey BP Exploration (Alaska) Lease: Drill Site Well: DS03- 16A Location: Wellhead, Prudhoe Bay, Alaska Job Number: AK0109G 107 MEASURED I N C L AZIMUTH B ORE HOLE DOGLEG VERTICAL CLOSURE HORIZONTAL DEPTH BEARING SEVERITY DEPTH DIST. AZIMUTH COORDIN ATES feet deg. deg. deg. min. deg./ feet feet deg.. feet 25 ft. 8300.00 56.78 266.58 S 86 35 W 0.40 6493.66 3781.2 265.6 287.15 S 3770.29 W 8325.00 56.72 266.42 S 86 25 W 0.15 6507.36 3802.1 265.6 288.43 S 3791.16 W 8350.00 57.09 266.49 S 86 29 W 0.38 6521.01 3823.1 265.7 289.72 S 3812.06 W 8375.00 58.04 266.61 S 86 37 W 0.95 6534.42 3844.2 265.7 290.99 S 3833.12 W 8400.00 57.75 266.70 S 86 42 W 0.29 6547.71 3865.3 265.7 292.23 S 3854.26 W 8425.00 58.24 266.82 S 86 49 W 0.51 6560.96 3886.5 265.7 293.43 S 3875.43 W 8450.00 58.36 266.63 S 86 38 W 0.20 6574.10 3907.8 265.7 294.64 S 3896.66 W 8475.00 58.51 266.58 S 86 35 W 0.15 6587.18 3929.1 265.7 295.90 S 3917.93 W 8500.00 58.52 266.68 S 86 41 W 0.08 6600.24 3950.4 265.7 297.15 S 3939.21 W 8525.00 58.53 266.49. S 86 30 W 0.16 6613:29 3971.7 265.7 298.42 S 3960.49 W 8550.00 58.73 266.56 S 86 34 W 0.21 6626:31 3:993`:1 265.7 299.72 S 3981.80 W 8575.00 58.77 266.3$ S 86 23 ' W 0. I6 6639.28 4014:4 265.7 301.03 S 4003.13 W 8600.00 58.76 266.46 S 86 28 W 0.07 6652.24: 403:5:8' 265.7 302.37 S 4024.47 W 8625.00 58.97 266.21 S 86 13 W 0.3.0 6665.17 4057.2 265.7 303.73 S 4045.82 W 8650.00 58.82 266.30 S 86 18 W 0.17 6678.08 4078.6 265.7 305.13 S 4067.18 W 8675.00 59.06 266.19 S 86 I 1 W 0.26 6690.98 4100.0: ...265.7. _ 306.54 S 4088.55 W 8700.00 59.40 266.16 S 86 10 W 0.34' ' 6703:77 ~ 4121.5 265:7 307.97 S 4109.98 W 8725.00 59.29 266.11 S 86 7 W 0.12 6716.52 4143.0 265.7 309.42 S 4131.44 W 8750.00 59.15 266.01 S 86 0 W 0.17 6729.31 4164.5 265.7 310.89 S 4152.87 W 8775.00 59.40 266.09 S 86 6 W 0.26 6742.09 4186.0 265.7 312.37 S 4174.31 W 8800.00 59.36 266.04 S 86 2 W 0.07 6754.82 4207.5 265.7 313.85 S 4195.77 W 8825.00 59.92 265.93 S 85 56 W 0.57 6767.46 4229.1 265.7 315.36 S 4217.29 W 8850.00 59.73 266.02 S 86 1 W 0.21 6780.02 4250.7 265.7 316.88 S 4238.85 W 8875.00 59.45 266.15 S 86 9 W 0.30 6792.68 4272.2 265.7 318.35 S 4260.36 W 12 A Gyrodata Directional Survey BP Exploration ( Alaska) Lease: Drill Site Well: DS03- 16A Location: Wellhead, Prudhoe Bay, Alaska Job Number: AK0109G 107 MEASURED I N C L AZIMUTH B ORE HOLE DOGLEG VERTICAL CLOSURE HORIZONTAL DEPTH BEARING SEVERITY DEPTH DIST. AZIMUTH COORDIN ATES feet deg. deg. deg. min. deg./ feet feet deg. feet 25 ft. 8900.00 60.37 265.97 S 85 58 W 0.93 6805.21 4293.9 265.7 319.84 S 4281.94 W 8925.00 60.48 265.98 S 85 59 W 0.11 6817.55 4315.6 265.7 321.37 S 4303.63 W 8950.00 60.12 265.99 S 85 59 W 0.36 6829.94 4337.3 265.7 322.89 S 4325.29 W . 8975.00 60.04 265.97 S 85 58 W 0.08 6842.41 4359.0 265.7 324.41 S 4346.90 W 9000.00 60.14 265.93 S 85 56 W 0.10. 6854.87 4380.7 265.7 325.94 S 4368.52 W 9025.00 60.42 266.01 S 86 1 W 0.29 6867.27 4402.4 265.7 327.46 S 4390.18 W 9050.00 60.36 265.91 S 85 54 W 0.11 6879.62 4424.1 265.7 328.99 S 4411.86 W 9075.00 60.29 265.94 S 85 57 W 0.08 6892.00 4445.8 265.7 330.54 S 4433.52 W 9100.00 59.49 266.02 S 86 1 W 0.81 6904.54 4467.5 265.7 332.06 S 4455.10 W 9125.00 59.86 265.92 S 85 55 W 0.38 6917.16 4489.0 265.7 333.57 S 4476.62 W 9150.00 59.49 265.96 S $$ 57 W 0.37 6929.78 4510.6 265.7 335.10 S 4498.15 W 9175.00 59.33 265.84. S 85 51 W 0.1$ 6942.51 4532.1 265.7 336.64 S 4519.61 W 9200.00 59.18 265.76 S 85 46 W 0.17 6955.29 4553.6 265.7 338.21 S 4541.04 W 9225.00 59.04 265.79 S 85 47 W 0.14 6968.12 4575.1 265.7 339.79 S 4562.44 W 9250.00 58.84 265.67 S 85 40 W 0.22 6981.02 4596.5 265.7 341.39 S 4583.80 W 9275.00 58.54 265.89 S 85 - 53 W 0.36...._ 6994.01 -. 46.17.9 -.,265.7 , -,342.96 S 4605.10 W 9300.00 58.41 266.03` S 86` 2 W 0.17 7007:08 4639.2 265.7 344.46 S 4626.35 W 9325.00 58.31 266.02 S 86 1 W 0.10 7020.20 4660.4 265.7 345.94 S 4647.59 W 9350.00 58.26 265.96 S 85 58 W 0.07 7033.34 4681.7 265.7 347.43 S 4668.80 W 9375.00 58.11 266.05 S 86 3 W 0.17 7046.52 4703.0 265.7 348.91 S 4689.99 W 9400.00 57.99 265.90 S 85 54 W 0.17 7059.75 4724.2 265.7 350.39 S 4711.16 W 9425.00 57.84 266.07 S 86 4 W 0.21 7073.02 4745.3 265.7 351.88 S 4732.29 W 9450.00 57.53 266.20 S 86 12 W 0.33 7086.39 4766.5 265.7 353.30 S 4753.37 W 9475.00 57.60 265.85 S 85 51 W 0.31 7099.79 4787.6 265.8 354.76 S 4774.42 W 13 A Gyrodata Directional Survey BP Exploration (Alaska) Lease: Drill Site Well: DS03- 16A Location: Wellhead, Prudhoe Bay, Alaska Job Number: AK0109G 107 MEASURED I N C L AZIMUTH BORE HOLE DOGLEG VERTICAL CLOS URE HORIZONTAL DEPTH BEARING SEVERITY DEPTH DIST. AZIMUTH COORDIN ATES feet deg. deg. deg. min. deg./ feet feet deg. feet 25 ft. 9500.00 57.32 266.39 S 86 23 W 0.54 7113.24 4808.7 265.8 356.19 S 4795.44 W 9525.00 57.13 266.47 S 86 28 W 0.20 7126.78 4829.7 265.8 357.50 S 4816.42 W 9550.00 57.09 266.14 S 86 8 W 0.28 7140.35 4850.7 265.8 358.85 S 4837.37 W 9575.00 57.24 266.12 S 86 7 W 0.15 7153.91 4871.7 265.8 360.27 S 4858.33 W 9600.00 56.96 266.23 S 86 14 W 0.29 7167.49 4892.7 265.8 361.67 S 4879.27 W 9625.00 57.29 266.12 S 86 7 W 0.35 7181.06 4913.7 265.8 363.07 S 4900.22 W 9650.00 56.96 266.01 S 86 1 W 0.34 7194.63 4934.7 265.8 364.51 S 4921.17 W 9675.00 56.40 266.10 S 86 6 W 0.57 7208.36 4955.5 265.8 365.95 S 4942.01 W 9700.00 56.60 266.07 S 86 4 W 0.21 7222.16 4976.4 265.8 367.37 S 4962.81 W 9725.00 56.64 266.08 S 86 S W 0.04 7235.91 4997.3 265.8 368.80 S 4983.64 W 9750.00 56.74 265;86 S 8S 52 W 0.21 7249.64 5018.2 265.8 370.27 S 5004.48 W 9775.00 56.56 265.95 S 8S S7 W 0.19 7263.39 5039.0 265.8 371.76 S 5025.31 W 9800.00 56.31 266.47 S 86 28 W 0.50. 7277.21 5059.9 265.8 373.13 S 5046.09 W 9825.00 56.13 266.01 S 86 1 W 0.43 7291.11 5080.6 265.8 374.49 S 5066.83 W 9850.00 55.91 :266.00 S 86 0 W 0.22 7305.08 5101.4 265.8 375.94 S 5087.51 W 9875.00 56.14 :...266.43. S 86,..... .26 W - 0.42 7319.05 - 5122.1 265.8 377.31 S 5108.20 W 9900.00 55.70 266.01 S 86 0" W 0.56 7333.06 5142:8 265:8 378.67 S 5128.86W • 9925.00 55.73 265.46 S 8S 28 W 0.45 7347.14 5163.5 265.8 380.21 S 5149.46 W 9950.00 55.65 266.11 S 86 7 W 0.54 7361.23 5184.1 265.8 381.72 S 5170.05 W 9975.00 55.48 266.21 S 86 13 W 0.18 7375.37 5204.7 265.8 383.10 S 5190.62 W 10000.00 55.30 265.58 S 85 35 W 0.55 7389.57 5225.3 265.8 384.58 S 5211.15 W 10025.00 55.23 265.73 S 85 44 W 0.15 7403.81 5245.9 265.8 386.14 S 5231.63 W 10050.00 55.14 265.90 S 85 54 W 0.17 7418.09 5266.4 265.8 387.63 S 5252.10 W 10075.00 54.97 265.64 S 8S 38 W 0.27 7432.41 5286.9 265.8 389.15 S 5272.54 W 10100.00 54.78 265.66 S 85 40 W 0.19 7446.79 5307.3 265.8 390.70 S 5292.93 W 14 BP Exploration (Alaska) Lease: Drill Site Well: DS03-16A Location: Wellhead, Prudhoe Bay, Alaska Job Number: AK0109G 107 MEASURED I N C L AZIMUTH DEPTH feet deg, deg. A Gyrodata Directional Survey BORE HOLE BEARING deg. min. DOGLEG SEVERITY deg./ 25 ft. VERTICAL CLOSURE HORIZONTAL DEPTH DIST. AZIMUTH COORDINATES feet feet deg. feet 10125.00 54.71 265.62 S 85 37 W 0.08 7461.22 5327.7 265.8 392.25 S 5313.28 W 10150.00 54.75 265.59 S 85 36 W 0.05 7475.66 5348.2 265.8 393.81 S 5333.63 W 10175.00 54.67 265.56 S 85 34 W 0.0$ 7490.10 5368.6 265.8 395.39 S 5353.98 W 10200.00 54.43 265.56 S 85 33 W 0.25 7504.60 5388.9 265.8 396.96 S 5374.29 W 10225.00 54.57 265.47 S 85 28 W 0.16 7519.11 5409.3 265.8 398.56 S 5394.58 W 10250.00 54.40 265.80 S 85 48 W 0.32 7533.64 5429.6 265.8 400.11 S 5414.87 W 10275.00 54.54 265.41 S 8S 25 W 0.34 7548.17 5450.0 265.8 401.67 S 5435.15 W 10300.00 54.32 265.32 S 85 19 W 0.23 7562.71 5470.3 265.8 403.31 S 5455.42 W 10325.00 54.44 265.52 S 85 31 W 0.20 7577.27 5490.6 265.8 404.93 S 5475.68 W 10350.00 54.45 265.37. S 85 22 W 0.12 7591.81 5511.0 265.8 406.55 S 5495.95 W 10375.00 54.38 265.52 S 85 31 W 0.14 7606.35 5531.3 265.8 408.16 S 5516.22 W 10400.00 54.47 265.27 S 85 16 VJ 0.22.. 7620.90 5551.6 265.8 409.80 S 5536.49 W 10425.00 54.51 265.27 S 85 16 'W 0.05 7635.42 5572,0 265.8 411.47 S 5556.77W 10450.00 54.67 265.33 S 85 20 W 0.16 7649.90 5592.4 265.8 413.14 S 5577.08 W 10475.00 54.34 265.25 S 85 15 W 0.33 7664.42 5612.7 265.8 414.81 S 5597.36 W 10500.00 54.40 265.37 S 85 22 W 0.11 7678.98 5633.0" 265.8 416.47 S 5617.61 W 10525.00 54.66 265.73 S 85 44 W 0.39 7693.49 5653.4 265.8 418.05 S 5637.91 W 10550.00 54.46 265.17 S 85 10 W 0.49 7707.99 5673.8 265.8 419.67 S 5658.22 W 10575.00 54.60 264,86 S 84 S2 W 0.29 7722.49 5694.1 265.8 421.44 S 5678.50 W 10600.00 54.54 265.51 S 85 31 W 0.53 7736.99 5714.5 265.8 423.15 S 5698.80 W 10625.00 54.55 265.43 S 85 26 W 0.07 7751.49 5734.8 265.8 424.76 S 5719.10 W 10650.00 54.50 264.66 S 84 40 W 0.63 7766.00 5755.2 265.7 426.51 S 5739.38 W 10675.00 54.05 265.53 S 85 32 W 0.84 7780.60 5775.5 265.7 428.25 S 5759.60 W 10700.00 54.19 265.17 S 85 10 W 0.32 7795.25 5795.8 265.7 429.89 S 5779.79 W 15 i A Gyrodata Directional Survey BP Exploration (Alaska) Lease: Drill Site Well: DS03-16A Location: Wellhead, Prudhoe Bay, Alaska Job Number: AK0109G 107 MEASURED I N C L AZIMUTH BORE HOLE DOGLEG VERTICAL CLOSURE HORIZONTAL DEPTH BEARING SEVERITY DEPTH DIST. AZIMUTH COORDINATES feet deg. deg. deg. min. deg./ feet feet deg. feet 25 ft. 10725.00 53.95 265.33 S 85 20 W 0.27 7809.92 5816.0 265.7 431.57 S 5799.96 W 10750.00 53.71 265.53 S 85 32 W 0.28 7824.68 5836.2 265.7 433.18 S 5820.08 W 10775.00 53.92 264.85 S 84 51 W 0.59 7839.44 5856.4 265.7 434.87 S 5840.19 W 10800.00 53.55 265.94 S 85 56 W 0.95 7854.22 5876.5 265.7 436.49 S 5860.28 W 10825.00 52.66 265.57 S 85 34 W 0.94 7869.23 5896.5 265.7 437.97 S 5880.22 W 10850.00 53.05 264.99 S 85 0 W 0.61 7884.33 5916.4 265.7 439.61 S 5900.08 W 10875.00 52.77 265.66 S 85 40 W 0.61 7899.40 5936.4 265.7 441.24 S 5919.95 W 10900.00 52.56 266.10 S 86 6 W 0.40 7914.57 5956.3 265.7 442.67 S 5939.78 W 10925.00 52.51 265.33 S 85 20 W 0.61 7929.77 5976.1 265.7 444.15 S 5959.57 W 10950.00 52.66 265.36 S 85 22 W 0.15 7944.96 5995.9 265.7 445.76 S 5979.36 W 10975.00 52.18 266.47 S 86 28 W 1.00 7960.21 6015.8 265.7 447.17 S 5999.12 W 11000.00 51.06 266.92 S 86 55 W 1.17 7975..73 6035.4 265.7 .448.30 S 6018.6$ W 11025.00 50.63 265.77 S 85 , 47 W 0.99 7991.52. 6054.7 265.7 449.54 S 6038.03 W 11050.00 50.95 266.14 S 86 8 W 0.43 8007.32 6074.1 265.7 450.90 S 6057.35 W 11075.00 49.86 266:78 S 86 47 W 1.20 8023.26 6093.4 265.7 452.09 S 6076.58 W 11100.00 49.08 266.96 ; . S 86 58 W 0_79 803.9.50 _ 61:.:12.4 ....:265.7 453.13 S 6095.55 W 11125.00 49.08 267.83 S 87 50 W 0.65 8055.88 6131.3 265.8 453.99 S 6114.42 W 11150.00 48.89 267.20 S 87 12 W 0.51 8072.29 6150.1 265.8 454.80 S 6133.27 W 11175.00 49.26 267.25 S 87 15 W 0.37 8088.66 6169.0 265.8 455.72 S 6152.13 W 11200.00 48.54 267.80 S 87 48 W 0.83 8105.10 6187.8 265.8 456.53 S 6170.95 W 11225.00 47.43 267.65 S 87 39 W 1.12 8121.83 6206.4 265.8 457.27 S 6189.51 W 11250.00 47.62 268.30 S 88 18 W 0.51 8138.71 6224.8 265.8 457.92 S 6207.94 W 11275.00 47.53 268.14 S 88 8 W 0.15 8155.58 6243.2 265.8 458.50 S 6226.39 W 11300.00 47.57 268.74 S 88 44 W 0.44 8172.45 6261.7 265.8 459.00 S 6244.83 W 16 A Gyrodata Directional Survey BP Exploration (Alaska) Lease: Drill Site Well: DS03- 16A Location: Wellhead, Prudhoe Bay, Alaska Job Number: AK0109G 107 MEASURED I N C L AZIMUTH B ORE HOLE DOGLEG VERTICAL CLOS URE HORIZONTAL DEPTH BEA RING SEVERITY DEPTH DIST. AZIMUTH COORDIN ATES feet deg. deg. deg. min. deg./ feet feet deg. feet 25 ft.. 11325.00 46.72 269.13 S 89 8 W 0.90 8189.45 6280.0 265.8 459.34 S 6263.15 W 11350.00 47.00 269.61 S 89 37 W 0.45 8206.55 6298.2 265.8 459.54 S 6281.39 W 11375 00 47 01 . . 268.89 S 88 53 W 0.53 8223.60 6316.4 265.8 459.78 S 6299.67 W 11400.00 47.32 269.56 S 89 33 W 0.58 8240.60 6334.7 265.8 460.03 S 6318.00 W 11425.00 46.99 270.03 N 89 58 W 0.48 8257.60 6353.0 265.8 460.10 S 6336.33 W 11450.00 46.88 270.08 N 89 55 W 0.12 8274.67 6371.2 265.9 460.08 S 6354.60 W 11475.00 47.27 270.21 N 89 47 W 0.41 8291.69 6389.5 265.9 460.03 S 6372.90 W 11500.00 47.14 270.48 N 89 31 W 0.24 8308.68 6407.8 265.9 459.92 S 6391.25 W 11525.00 47.66 270.66 N 89 21 W 0.54 8325.60 6426.1 265.9 459.74 S 6409.65 W 11550.00 47.29 270.97 N 89 2 W 0.44 8342.50 6444.5 265.9 459.48 S 6428.07 W 11575.00 47.62 271.27 N 88 44 W 0.39 8359.40 6462.8 265.9 459.12 S 6446.49 W 11600.00 47.51 271.83 N 88 lA W 0.43 8376.27 6481.2 2659 458.62 S 6464.93 W 11625.00 47.65 271.85 N 88 9 W 0.13 8393.13 6499:5 266.0 458.03 S 6483.38 W 11650.00 47.77 272.23 N 87 46 W 0.3:1 8409.96 6517.9 266.0 457.37 S 6501.86 W 11675.00 47.82 272.49 N 87 30 W 0.20 8426.75 6536.3 266.0 456.60 S 6520.36 W 11700.00 47.89 272.74 ,;, N 87 „_15 W - 0.20.... 8443...53 - 6554.7- ,266.0 455.76 S 6538.88 W 11725.00 47.84 272.99 N 87" " 1 W' 0.19 8460:30 6573.1 266.0 454.83 S 6557.39 W 11750.00 48.00 273.35 N 86 39 W 0.31 8477.05 6591.6 266.1 453.80 S 6575.92 W 11775.00 47.83 273.26 N 86 45 W 0.19 8493.81 6610.0 266.1 452.73 S 6594.44 W 11800.00 48.14 273.70 N 86 18 W 0.45 8510.54 6628.4 266.1 451.61 S 6612.98 W 11825.00 48.14 274.59 N 85 24 W 0.66 8527.22 6646.8 266.1 450.26 S 6631.55 W 11850.00 48.00 274.84 N 85 9 W 0.23 8543.93 6665.2 266.1 448.73 S 6650.09 W 11875.00 47.11 275.16 N 84 50 W 0.92 8560.80 6683.4 266.2 447.12 S 6668.47 W 11900.00 47.73 275.87 N 84 8 W 0.81 8577.72 6701.6 266.2 445.35 S 6686.79 W 17 A Gyrodata Directional Survey BP Exploration (Alaska) Lease: Drill Site Well: DS03-16A Location: Wellhead, Prudhoe Bay, Alaska Job Number: AK0109G 107 MEASURED I N C L AZIMUTH BORE HOLE DOGLEG VERTICAL DEPTH BEARING SEVERITY DEPTH feet deg. deg. deg. min. deg./ feet 25 ft. 11925.00 48.30 276.01 N 83 59 W 0.58 8594.44 11950.00 48.66 276.22 N 83 47 W 0.39 8611.02 11975.00 49.04 276.39 N 83 36 W 0.41 8627.47 12000.00 49.02 276.63 N 83 22 W 0.18 8643.86 12025.00 48.09 277.03 N 82 58 W 0.98 8660.41 12050.00 47.45 277.00 N 83 0 W 0.63 8677.21 12075.00 47.58 277.17 N 82 50 W 0.18 8694.09 12100.00 47.47 276.86 N 83 8 W 0.26 8710.98 12125.00 47.27 276.88 N 83 7 W 0.20 8727.91 12150.00 46.87 276.83. N 83 10 W 0.40 8744.93 12175.00 46.73 276.55 N 83 27 W 0:25 8762.05 12200.00 46.36 ..276.75. N 83 15 W 0.40 8779.24 12225.00 46.36 276.47 N 83 32 W 021.. 8796.49 12250.00 46.13 276.75 N 83 15 W 0.31 8813.78 12275.00 46.26 276:82 N 83 11 W 0.14 8831.09 12300.00 50.71 283.24 N 76 , 45 W b.55 8847.66. 12325.00 54.14 285.01` N 74 59 W 3:70 8862:90 Final Station Closure: Distance: 7010.65 ft Az: 266.69 deg. CLOSURE HORIZONTAL DIST. AZIMUTH COORDINATES feet deg. feet 6719.9 266.2 443.43 S 6705.27 W 6738.4 266.2 441.44 S 6723.88 W 6756.9 266.3 439.37 S 6742.59 W 6775.5 266.3 437.23 S 6761.35 W 6793.9 266.3 435.00 S 6779.95 W 6812.1 266.4 432.74 S 6798.33 W 6830.2 266.4 430.47 S 6816.62 W 6848.3 266.4 428.21 S 6834.92 W 6866.4 266.4 426.01 S 6853.19 W 6884.4 266.5 423.83 S 6871.36 W 6902.4 266.5 421.71 S 6889.46 W 6920:2 ~ 266.5 419.60 S 6907.49 W 6938.0 266.5 417.52 S 6925.46 W 6955.8 266,6 415.44 S 6943.40 W 6973.6 266,6 413.31 S 6961.32 W 6991.8._ ._266.6- _- 410.02 S 6979.72 W 70T0.6 266.7 405.18 S 6998.93 W 18 • BP Exploration (Alaska) Well: Drill Site DS03-16A Location: Wellhead, Prudhoe Bay, Alaska Interp Inrun Gyrodata AK0109G_107 DEFINITIVE 0 -50 -100 -150 ~ -200 C7 z ~ -250 z -300 -350 OTTOM HOLE OCATED D: 12325.00 -400 -450 -7000 -6000 -5000 -4000 -3000 -2000 -1000 0 FASTING (ft) BP Exploration (Alaska) Well: Drill Site DS03-16A Location: Wellhead, Prudhoe Bay, Alaska lU Interp Inrun Gyrodata AK0109G_107 DEFINITIVE BOTTOM HOL MD: 12325.0 0 2000 4000 6000 8000 10000 12000 14000 MEASURED DEPTH (ft) N N '~ a.i r-~ W W w J 4 0 0 i BP Exploration (Alaska) Well: Drill Site DS03-16A Location: Wellhead. Prudhoe Bav. Alaska Interp Inrun Gyrodata AK0109G_107 DEFINITIVE 60 55 50 45 40 z O 35 z v 30 z 25 20 15 10 5 0 LOCATE D MD: 12325.0 u ~uuu 4000 6000 8000 10000 12000 14000 MEASURED DEPTH (ft) BP Exploration (Alaska) Well: Drill Site DS03-16A Location: Wellhead, Prudhoe Bay, Alaska 300 280 260 240 220 200 N Q 180 160 140 120 100 80 Interp Inrun Gyrodata AK0109G_107 DEFINITIVE BOTTOM HC LOCATED MD: 12325. u ~uuu 4uvu 6000 8000 10000 12000 14000 MEASURED DEPTH (ft) Survey QC - RGS-CT Specification Sheet ~y/'~(,~~a ~~ SURVEY QUALITY CONTROL -SPECIFICATION DATA INITYALISATION Gyro Compass Reading /Station Raw Inclination Raw Azimuth Ab5 (ERNeas ERrneo) 32 14.59 282.16 0.1180 33 14.59 282.26 0.1572 34 14.59 282.26 0.1477 35 14.59 282.32 0.1678 36 14.59 282.27 0.1878 37 14.59 282.24 0.1943 38 14.59 282.22 0.2041 39 14.59 282.18 0.2137 40 14.59 282.23 0.1950 41 14.59 282.23 0.1957 Average 14.59 282.24 0.1781 Tolerance on Average* 0.0829 Standard Deviation 0.00 0.04 0.0282 Tolerance on St. Dev.** 0.1~ 0.20 0.0374 Advanced Initialisation Azimuth Advanced Initialisation Standard Deviation Tolerance = TBA * Tolerance on Average of earth horizontal rate difference is given by (1/cosI) * v[(CosA*SinI*0.1)z+nnt;2~/hr ** Tole2nce on Standard Deviation of earth horizontal rate difference tolerance is given by (1/cosI) *J[(COSA*SinI*0.1)Z+(O.OSZ/(n-1))] ~/hr DRIFT TUNES Drift Tune Number Ending Time Ending Depth Ending Inclination Ending Azimuth Residual Gx Bias Residual Gy Bias Start End Start End 1 1415.67 5096.10 54.38 264.29 0.001 0.002 0.001 -0.001 2 1376.61 7196.76 56.34 266.88 0.001 0.002 0.002 -0.002 3 1371.61 9298.82 58.61 266.02 -0.001 0.003 0.002 -0.001 4 1341.25 11299.73 47.92 268.60 0.001 0.002 0.001 -0.001 5 1133.97 12372.32 54.95 284.77 0.002 -0.004 0.000 -0.000 6 329.38 12322.38 54.14 285.02 0.004 -0.003 0.003 -0.003 7 993.48 11299.49 47.48 268.62 0.001 0.002 0.001 0.000 8 1325.78 9297.94 58.36 266.05 0.001 0.002 0.001 -0.000 9 1321.06 7196.38 56.14 266.92 0.004 -0.002 0.005 -0.005 10 1336.31 5097.20 54.17 264.42 0.001 0.001 0.002 -0.002 11 1270.28 3145.45 14.69 281.06 0.001 -0.000 0.001 0.002 Average 0.001 0.000 0.002 -0.001 Standard Deviation 0.001 0.002 0.001 0.002 Tolerance for both the Average and the Standard Deviation 0.033/hr 0.033/hr 0.033/hr 0.033°/hr SURV-Qi67 (OPS SUR-MA-003) 19`" Nov 03 /Rev 15 Page 1 of 11 AK01096_107 Survey QC - RGS-CTS ecification Sheet /'~ INCLINATION AND AZIMUTH INRUN AND OUTRUN COMPARISON Depth Corrected Inclination Corrected Azimuth Inrun * Outrun * Difference Inrun * Outrun * Difference 100.00 0.18 0.03 0.15 140.00 353.97 146.03 200.00 0.50 0.06 0.44 275.75 347.95 -72.20 300.00 0.39 0.09 0.31 194.32 341.92 -147.60 400.00 0.64 0.11 0.52 200.06 335.89 -135.83 500.00 0.40 0.14 0.26 235.68 329.87 -94.19 600.00 0.23 0.17 0.06 222.88 323.84 -100.95 700.00 0.65 0.20 0.45 180.79 317.81 -137.03 800.00 0.54 0.23 0.31 153.24 311.78 -158.55 900.00 0.19 0.26 -0.07 237.46 305.76 -68.30 1000.00 0.25 0.29 -0.04 292.20 299.73 -7.53 1100.00 0.34 0.35 -0.00 272.71 282.92 -10.21 1200.00 0.50 0.41 0.10 98.90 265.00 -166.10 1300.00 0.48 0.47 0.01 96.30 247.07 -150.77 1400.00 0.52 0.53 -0.01 134.64 229.14 -94.50 1500.00 0.28 0.60 -0.32 231.57 211.22 20.35 1600.00 0.33 0.66 -0.33 90.69 193.29 -102.60 1700.00 0.50 0.72 -0.23 202.39 175.37 27.02 1800.00 0.64 0.78 -0.14 131.05 157.44 -26.39 1900.00 0.83 0.85 -0.01 163.91 139.51 24.40 2000.00 0.51 0.91 -0.39 108.92 121.59 -12.67 2100.00 1.12 1.49 -0.37 90.37 137.12 -46.76 2200.00 1.00 1.10 -0.10 90.82 91.25 -0.42 2300.00 0.89 0.90 -0.02 94.39 94.77 -0.37 2400.00 0.72 0.75 -0.04 120.68 120.82 -0.14 2500.00 0.74 0.75 -0.01 142.65 142.60 0.05 2600.00 0.73 0.76 -0.03 160.14 160.12 0.03 2700.00 0.85 0.92 -0.07 158.20 158.14 0.06 2800.00 0.84 1.07 -0.23 203.90 204.06 -0.16 2900.00 6.22 6.69 -0.47 297.85 293.30 4.55 3000.00 11.04 10.75 0.28 292.74 286.14 6.60 3100.00 13.23 13.40 -0.17 283.37 282.70 0.67 3150.00 14.64 14.64 0.00 282.20 281.29 0.90 3175.00 15.11 15.06 0.05 281.20 280.65 0.55 3200.00 15.74 15.73 0.02 279.27 278.71 0.55 3225.00 16.06 16.05 0.02 277.73 277.02 0.70 3250.00 16.37 16.39 -0.01 274.98 274.31 0.67 3275.00 16.48 16.51 -0.03 272.31 271.65 0.66 3300.00 16.43 16.45 -0.02 270.18 269.54 0.64 3325.00 16.13 16.16 -0.02 266.66 265.89 0.77 3350.00 16.10 16.12 -0.02 264.63 263.97 0.66 SURV-Q167 (OPS SUR-MA-003) 19`" Nov 03 /Rev 15 Page 2 of 11 AK0109G-107 Survey QC - RGS-CTS ecification Sheet /tiD+~t 3375.00 15.96 15.97 -0.01 261.85 261.08 0.77 3400.00 16.09 16.10 -0.01 259.45 259.04 0.41 3425.00 16.32 16.39 -0.07 25$.36 258.52 -0.17 3450.00 16.56 16.62 -0.06 257.91 257.98 -0.07 3475.00 16.95 16.99 -0.05 257.68 257.71 -0.03 3500.00 17.29 17.33 -0.04 257.55 257.56 -0.01 3525.00 17.97 18.02 -0.05 257.68 257.90 -0.22 3550.00 18.41 18.46 -0.05 257.87 258.06 -0.18 3575.00 19.09 19.14 -0.05 258.20 258.54 -0.34 3600.00 19.80 19.88 -0.07 258.69 259.03 -0.34 3625.00 20.47 20.51 -0.04 259.15 259.45 -0.30 3650.00 21.33 21.38 -0.05 259.72 260.05 -0.34 3675.00 22.22 22.26 -0.04 260.16 260.48 -0.31 3700.00 23.10 23.14 -0.04 260.46 260.73 -0.27 3725.00 23.98 24.02 -0.04 260.86 261.11 -0.26 3750.00 24.82 24.86 -0.04 261.07 261.36 -0.29 3775.00 25.82 25.86 -0.04 261.37 261.64 -0.27 3800.00 26.78 26.82 -0.04 261.82 262.07 -0.26 3825.00 27.60 27.65 -0.05 262.07 262.31 -0.24 3850.00 28.36 28.43 -0.07 262.40 262.64 -0.23 3875.00 29.22 29.26 -0.04 262.62 262.83 -0.21 3900.00 29.91 29.96 -0.05 262.89 263.13 -0.23 3925.00 30.80 30.84 -0.04 263.10 263.32 -0.22 3950.00 31.46 31.52 -0.05 263.38 263.61 -0.23 3975.00 32.23 32.31 -0.08 263.57 263.79 -0.22 4000.00 33.13 33.16 -0.04 263.65 263.86 -0.20 4025.00 33.93 34.00 -0.06 263.77 264.00 -0.23 4050.00 34.91 34.96 -0.05 263.99 264.21 -0.22 4075.00 35.72 35.75 -0.03 264.06 264.29 -0.23 4100.00 36.54 36.57 -0.03 264.14 264.37 -0.23 4125.00 37.54 37.57 -0.03 264.29 264.51 -0.22 4150.00 38.26 38.30 -0.04 264.25 264.47 -0.22 4175.00 38.89 38.93 -0.04 264.21 264.43 -0.22 4200.00 39.63 39.66 -0.03 264.16 264.36 -0.20 4225.00 40.41 40.44 -0.03 264.17 264.37 -0.20 4250.00 41.28 41.31 -0.03 264.14 264.34 -0.20 4275.00 42.07 42.10 -0.03 264.28 264.46 -0.18 4300.00 42.82 42.85 -0.03 264.38 264.55 -0.17 4325.00 43.66 43.70 -0.04 264.50 264.71 -0.20 4350.00 44.25 44.28 -0.03 264.67 264.85 -0.19 4375.00 44.97 45.00 -0.02 264.62 264.80 -0.18 4400.00 45.76 45.82 -0.06 264.72 264.88 -0.16 4425.00 46.45 46.51 -0.06 264.70 264.88 -0.17 4450.00 47.01 47.03 -0.02 264.75 264.91 -0.16 4475.00 47.52 47.55 -0.02 264.59 264.75 -0.16 SURV-Q167 (OPS SUR-MA-003) 19~" Nov 03 /Rev 15 Vage 3 of 11 AKO1O9G_1O7 Survey QC - RGS-CTS ecification Sheet ~~ 4500.00 47.99 48.01 -0.02 264.43 264.60 -0.18 4525.00 48.33 48.38 -0.05 264.14 264.31 -0.17 4550.00 48.90 48.94 -0.04 264.10 264.24 -0.15 4575.00 49.53 49.54 -0.02 264.09 264.24 -0.15 4600.00 50.23 50.22 0.01 264.09 264.25 -0.15 4625.00 50.91 50.91 -0.00 264.04 264.19 -0.15 4650.00 51.58 51.63 -0.05 264.09 264.24 -0.15 4675.00 52.27 52.30 -0.03 264.01 264.17 -0.16 4700.00 53.11 53.10 0.01 264.14 264.28 -0.14 4725.00 53.70 53.71 -0.01 264.19 264.33 -0.13 4750.00 54.40 54.41 -0.01 264.18 264.28 -0.10 4775.00 54.69 54.71 -0.01 264.28 264.36 -0.08 4800.00 54.43 54.47 -0.04 264.32 264.46 -0.13 4825.00 54.36 54.40 -0.03 264.34 264.47 -0.13 4850.00 54.35 54.38 -0.03 264.27 264.40 -0.12 4875.00 54.36 54.36 -0.01 264.35 264.47 -0.12 4900.00 54.37 54.40 -0.03 264.29 264.41 -0.12 4925.00 54.20 54.22 -0.02 264.24 264.35 -0.11 4950.00 54.26 54.28 -0.02 264.22 264.32 -0.10 4975.00 53.86 53.88 -0.02 264.20 264.33 -0.13 5000.00 54.11 54.12 -0.00 264.24 264.36 -0.12 5025.00 54.21 54.23 -0.02 264.24 264.35 -0.12 5050.00 54.20 54.20 0.00 264.24 264.35 -0.11 5075.00 .54.14 54.15 -0.01 264.26 264.37 -0.12 5100.00 54.28 54.27 0.02 264.32 264.42 -0.10 5125.00 54.04 54.02 0.02 264.38 264.48 -0.10 5150.00 54.47 54.47 -0.00 264.40 264.49 -0.09 5175.00 54.49 54.49 0.00 264.44 264.55 -0.10 5200.00 54.09 54.07 0.01 264.58 264.70 -0.12 5225.00 54.41 54.40 0.01 264.62 264.71 -0.09 5250.00 54.33 54.33 0.00 264.55 264.66 -0.12 5275.00 54.23 54.24 -0.01 264.63 264.73 -0.11 5300.00 54.26 54.24 0.02 264.65 264.73 -0.09 5325.00 54.48 54.48 -0.00 264.63 264.75 -0.12 5350.00 54.47 54.46 0.01 264.85 264.97 -0.11 5375.00 54.74 54.73 0.01 264.91 265.00 -0.09 5400.00 54.97 54.95 0.02 265.00 265.08 -0.09 5425.00 55.24 55.23 0.01 264.96 265.06 -0.10 5450.00 55.30 55.29 0.01 264.90 265.01 -0.11 5475.00 55.66 55.65 0.01 265.14 265.25 -0.11 5500.00 55.40 55.41 -0.00 265.24 265.33 -0.09 5525.00 55.55 55.54 0.01 265.32 265.42 -0.10 5550.00 55.75 55.75 -0.00 265.30 265.40 -0.10 5575.00 55.48 55.48 0.00 265.33 265.45 -0.12 5600.00 55.69 55.69 0.00 265.40 265.51 -0.11 SURV-Qi67 (OPS SUR-Mb-003) 19`" Nov 03 /Rev 15 Page 4 of 11 AK0109G_107 Survey QC - RGS-CTS ecification Sheet 5625.00 55.85 55.84 0.00 265.47 265.56 -0.10 5650.00 55.98 55.97 0.00 265.62 265.71 -0.09 5675.00 56.19 56.19 -0.00 265.75 265.84 -0.09 5700.00 55.78 55.78 0.00 265.84 265.96 -0.12 5725.00 55.89 55.89 0.00 265.96 266.06 -0.09 5750.00 56.08 56.07 0.01 265.97 266.07 -0.10 5775.00 55.88 55.88 -0.00 265.91 266.00 -0.09 5800.00 56.00 55.98 0.02 265.91 266.00 -0.09 5825.00 55.75 55.75 -0.00 265.89 265.98 -0.09 5850.00 55.98 55.98 0.00 265.92 266.02 -0.11 5875.00 56.10 56.09 0.01 265.96 266.04 -0.09 5900.00 55.80 55.79 0.01 265.94 266.05 -0.10 5925.00 55.83 55.82 0.01 265.85 265.96 -0.11 5950.00 55.92 55.92 0.00 265.90 265.99 -0.09 5975.00 55.72 55.72 -0.00 265.85 265.95 -0.09 6000.00 55.81 55.82 -0.01 265.78 265.89 -0.11 6025.00 55.86 55.87 -0.01 265.82 265.93 -0.10 6050.00 55.59 55.59 -0.00 265.83 265.91 -0.08 6075.00 55.83 55.84 -0.00 265.76 265.84 -0.08 6100.00 55.76 55.76 -0.00 265.90 265.98 -0.08 6125.00 55.40 55.40 0.00 265.98 266.04 -0.07 6150.00 55.58 55.58 -0.01 266.00 266.08 -0.08 6175.00 55.70 55.70 -0.01 266.08 266.18 -0.10 6200.00 55.53 55.53 -0.01 266.02 266.11 -0.09 6225.00 55.44 55.45 -0.01 266.00 266.08 -0.08 6250.00 55.45 55.46 -0.01 266.10 266.18 -0.09 6275.00 55.61 55.62 -0.01 266.01 266.09 -0.08 6300.00 55.38 55.38 -0.00 266.05 266.14 -0.09 6325.00 55.26 55.26 -0.01 266.10 266.18 -0.09 6350.00 55.32 55.32 -0.00 266.05 266.14 -0.09 6375.00 55.30 55.30 -0.00 266.08 266.16 -0.08 6400.00 55.08 55.08 -0.00 266.09 266.18 -0.09 6425.00 54.76 54.77 -0.00 266.12 266.20 -0.08 6450.00 55.07 55.07 -0.00 266.12 266.21 -0.09 6475.00 55.31 55.32 -0.01 266.15 266.23 -0.08 6500.00 55.06 55.06 -0.01 266.20 266.28 -0.08 6525.00 55.47 55.48 -0.01 266.17 266.25 -0.08 6550.00 55.42 55.43 -0.01 266.33 266.42 -0.09 6575.00 55.34 55.35 -0.01 266.34 266.43 -0.09 6600.00 55.41 55.42 -0.02 266.23 266.30 -0.07 6625.00 55.26 55.26 -0.00 266.26 266.34 -0.08 6650.00 54.89 54.90 -0.00 266.23 266.30 -0.07 6675.00 54.89 54.91 -0.02 266.28 266.36 -0.08 6700.00 55.25 55.26 -0.01 266.29 266.36 -0.07 6725.00 55.39 55.39 0.00 266.40 266.47 -0.07 SURV-Q367 (OPS SUR-MA-003) 19~" Nov 03 /Rev 15 Page S of it AK0109G_307 Survey QC - RGS-CTS ecification Sheet j~ 6750.00 55.41 55.41 -0.01 266.32 266.40 -0.08 6775.00 55.21 55.21 -0.01 266.38 266.44 -0.06 6800.00 55.58 55.58 0.00 266.33 266.39 -0.06 6825.00 55.28 55.28 -0.00 266.40 266.47 -0.07 6850.00 55.47 55.48 -0.01 266.48 266.54 -0.06 6875.00 55.29 55.30 -0.01 266.55 266.61 -0.06 6900.00 55.55 55.56 -0.01 266.61 266.68 -0.07 6925.00 55.66 55.66 -0.00 266.71 266.77 -0.06 6950.00 55.63 55.64 -0.01 266.72 266.77 -0.05 6975.00 55.69 55.69 0.00 266.66 266.73 -0.07 7000.00 55.97 55.98 -0.01 266.79 266.86 -0.08 7025.00 56.14 56.14 0.00 266.86 266.94 -0.08 7050.00 56.28 56.27 0.01 266.81 266.90 -0.09 7075.00 56.41 56.41 -0.00 267.00 267.07 -0.07 7100.00 56.12 56.13 -0.01 266.94 267.01 -0.07 7125.00 56.36 56.37 -0.01 266.94 267.02 -0.08 7150.00 56.31 56.32 -0.01 266.96 267.02 -0.06 7175.00 56.04 56.04 -0.00 266.93 266.97 -0.04 7200.00 56.18 56.18 -0.00 266.87 266.92 -0.05 725.00 55.89 55.88 0.01 266.85 266.91 -0.05 7250.00 55.76 55.76 0.01 266.80 266.86 -0.06 7275.00 55.66 55.65 0.01 266.80 266.86 -0.06 7300.00 55.57 55.56 0.02 266.76 266.81 -0.05 7325.00 55.72 55.72 0.00 266.82 266.88 -0.07 7350.00 55.56 55.55 0.01 266.81 266.87 -0.06 7375.00 55.43 55.43 0.00 266.84 266.90 -0.06 7400.00 55.69 55.69 -0.00 266.88 266.94 -0.06 7425.00 55.33 55.32 0.01 266.87 266.93 -0.07 7450.00 55.47 55.48 -0.01 266.97 267.03 -0.06 7475.00 55.56 55.55 0.01 266.96 267.02 -0.06 7500.00 55.27 55.26 0.02 266.97 267.03 -0.06 7525.00 55.32 55.31 0.00 266.99 267.06 -0.08 7550.00 55.00 55.00 0.00 266.96 267.01 -0.05 7575.00 54.97 54.97 -0.00 266.92 266.99 -0.07 7600.00 55.12 55.11 0.01 266.97 267.03 -0.06 7625.00 54.88 54.87 0.01 267.00 267.07 -0.07 7650.00 54.82 54.82 0.01 266.97 267.02 -0.05 7675.00 54.79 54.79 0.00 267.01 267.07 -0.06 7700.00 54.60 54.60 0.00 267.06 267.10 -0.04 7725.00 54.70 54.71 -0.00 267.00 267.07 -0.07 7750.00 54.41 54.41 0.00 267.02 267.08 -0.07 7775.00 54.46 54.46 -0.00 267.12 267:17 -0.05 7800.00 54.49 54.48 0.01 266.93 266.98 -0.05 7825.00 54.10 54.08 0.01 266.98 .267.03 -0.04 7850.00 54.10 54.09 0.01 266.88 266.94 -0.06 SURV-Q167 (OPS SUR-MA-003) 19`h Nov 03 /Rev 15 Page 6 of 11 AKO1O9G_lO7 Survey QC - RGS-CTS ecification Sheet ~Ij"~ 7875.00 53.98 53.97 0.01 266.91 266.97 -0.07 7900.00 53.85 53.83 0.02 266.93 266.98 -0.05 7925.00 53.82 53.82 0.00 266.86 266.93 -0.06 7950.00 53.46 53.45 0.00 266.88 266.94 -0.06 7975.00 53.39 53.39 0.00 266.82 266.87 -0.05 8000.00 53.29 53.28 0.01 266.81 266.87 -0.06 8025.00 53.52 53.51 0.01 266.73 266.78 -0.05 8050.00 53.72 53.72 -0.00 266.68 266.74 -0.06 8075.00 53.97 53.96 0.01 266.62 266.67 -0.06 8100.00 54.52 54.51 0.01 266.58 266.66 -0.08 8125.00 54.61 54.62 -0.00 266.51 266.56 -0.06 8150.00 54.65 54.64 0.01 266.42 266.50 -0.07 8175.00 55.47 55.45 0.02 266.55 266.60 -0.05 8200.00 55.80 55.79 0.01 266.56 266.63 -0.07 8225.00 56.08 56.08 0.00 266.60 266.63 -0.03 8250.00 56.33 56.34 -0.01 266.55 266.60 -0.05 8275.00 56.38 56.38 0.00 266.50 266.54 -0.04 8300.00 56.78 56.78 -0.00 266.58 266.62 -0.04 8325.00 56.72 56.73 -0.01 266.42 266.46 -0.04 8350.00 57.09 57.10 -0.01 266.49 266.55 -0.06 8375.00 58.04 58.05 -0.01 266.61 266.67 -0.05 8400.00 57.75 57.76 -0.00 266.70 266.75 -0.06 8425.00 58.24 58.26 -0.01 266.82 266.85 -0.03 8450.00 58.36 58.37 -0.01 266.63 266.65 -0.03 8475.00 58.51 58.52 -0.01 266.58 266.63 -0.04 8500.00 58.52 58.54 -0.02 266.68 266.72 -0.04 8525.00 58.53 58.54 -0.01 266.49 266.53 -0.03 8550.00 58.73 58.75 -0.01 266.56 266.58 -0.01 8575.00 58.77 58.78 -0.01 266.38 266.41 -0.03 8600.00 58.76 58.77 -0.01 266.46 266.49 -0.03 8625.00 58.97 58.98 -0.01 266.21 266.28 -0.07 8650.00 58.82 58.82 -0.00 266.30 266.33 -0.03 8675.00 59.06 59.07 -0.01 266.19 266.23 -0.05 8700.00 59.40 59.42 -0.02 266.16 266.19 -0.03 8725.00 59.29 59.30 -0.02 266.11 266.14 -0.03 8750.00 59.15 59.17 -0.02 266.01 266.03 -0.03 8775.00 59.40 59.42 -0.02 266.09 266.13 -0.03 8800.00 59.36 59.36 -0.00 266.04 266.07 -0.03 8825.00 59.92 59.93 -0.01 265.93 265.97 -0.04 8850.00 59.73 59.75 -0.01 266.02 266.04 -0.02 8875.00 59.45 59.45 -0.00 266.15 266.18 -0.03 8900.00 60.37 60.38 -0.01 265.97 266.01 -0.03 8925.00 60.48 60.49 -0.01 265.98 265.99 -0.01 8950.00 60.12 60.13 -0.01 265.99 266.02 -0.04 8975.00 60.04 60.05 -0.01 265.97 265.99 -0.02 SURV-Q167 (OPS SUR-MA-003) 19`" Nov 03 /Rev 15 Page 7 of 11 AK0109G_107 Survey QC - RGS-CTS cification Sheet gY~ ~® 9000.00 60.14 60.14 -0.00 265.93 265.97 -0.05 9025.00 60.42 60.44 -0.03 266.01 266.06 -0.04 9050.00 60.36 60.38 -0.02 265.91 265.93 -0.03 9075.00 60.29 60.32 -0.02 265.94 265.96 -0.02 9100.00 59.49 59.50 -0.01 266.02 266.02 -0.01 9125.00 59.86 59.85 0.01 265.92 265.94 -0.02 9150.00 59.49 59.49 -0.00 265.96 265.96 -0.01 9175.00 59.33 59.34 -0.00 265.84 265.87 -0.02 9200.00 59.18 59.18 0.00 265.76 265.82 -0.06 9225.00 59.04 59.05 -0.01 265.79 265.78 0.00 9250.00 58.84 58.85 -0.00 265.67 265.70 -0.03 9275.00 58.54 58.53 0.00 265.89 265.91 -0.02 9300.00 58.41 58.42 -0.01 266.03 266.05 -0.02 9325.00 58.31 58.30 0.01 266.02 266.04 -0.02 9350.00 58.26 58.25 0.01 265.96 265.98 -0.02 9375.00 58.11 58.09 0.02 266.05 266.06 -0.01 9400.00 57.99 57.99 0.01 265.90 265.90 -0.00 9425.00 57.84 57.83 0.01 266.07 266.07 -0.00 9450.00 57.53 57.52 0.01 266.20 266.20 0.00 9475.00 57.60 57.57 0.03 265.85 265.86 -0.01 9500.00 57.32 57.32 -0.00 266.39 266.41 -0.02 9525.00 57.13 57.12 0.01 266.47 266.48 -0.00 9550.00 57.09 57.09 0.00 266.14 266.13 0.01 9575,00 57.24 57.22 0.02 266.12 266.15 -0.03 9600.00 56.96 56.95 0.01 266.23 266.23 -0.00 9625.00 57.29 57.29 0.01 266.12 266.13 -0.01 9650.00 56.96 56.95 0.01 266.01 266.02 -0.01 9675.00 56.40 56.40 -0.01 266.10 266.11 -0.01 9700.00 56.60 56.59 0.01 266.07 266.08 -0.01 9725.00 56.64 56.63 0.01 266.08 266.07 0.01 9750.00 56.74 56.73 0.01 265.86 265.88 -0.02 9775.00 56.56 56.55 0.01 265.95 265.98 -0.02 9800.00 56.31 56.29 0.02 266.47 266.49 -0.01 9825.00 56.13 56.12 0.01 266.01 266.02 -0.01 9850.00 55.91 55.91 0.00 266.00 266.04 -0.04 9875.00 56.14 56.12 0.02 266.43 266.42 0.01 9900.00 55.70 55.69 0.01 266.01 265.99 0.02 9925.00 55.73 55.70 0.03 265.46 265.48 -0.02 9950.00 55.65 55.67 -0.01 266.11 266.14 -0.02 9975.00 55.48 55.46 0.03 266.21 266.19 0.02 10000.00 55.30 55.32 -0.02 265.58 265.56 0.02 10025.00 55.23 55.23 -0.00 265.73 265.74 -0.01 10050.00 55.14 55.14 0.00 265.90 265.87 0.03 10075.00 54.97 54.97 -0.00 265.64 265.64 -0.00 10100.00 54.78 54.77 0.01 265.66 265.68 -0.01 SURV-Q167 (OPS SUR-MA-003) 19`" Nov 03 /Rev 15 Page 8 of 11 AKO1O9G_lO7 Survey QC - RGS-CTS cification Sheet ,~~°'rp 10125.00 54.71 54.71 0.00 265.62 265.63 -0.01 10150.00 54.75 54.76 -0.01 265.59 265.60 -0.01 10175.00 54.67 54.68 -0.00 265.56 265.56 -0.00 10200.00 54.43 54.43 -0.01 265.56 265.55 0.01 10225.00 54.57 54.58 -0.01 265.47 265.45 0.02 10250.00 54.40 54.40 0.00 265.80 265.77 0.02 10275.00 54.54 54.55 -0.02 265.41 265.40 0.01 10300.00 54.32 54.33 -0.01 265.32 265.34 -0.02 10325.00 54.44 54.44 -0.00 265.52 265.50 0.02 10350.00 54.45 54.46 -0.01 265.37 265.36 0.01 10375.00 54.38 54.39 -0.00 265.52 265.51 0.01 10400.00 54.47 54.48 -0.01 265.27 265.26 0.01 10425.00 54.51 54.52 -0.00 265.27 265.27 0.00 10450.00 54.67 54.67 -0.00 265.33 265.32 0.01 10475.00 54.34 54.36 -0.01 265.25 265.27 -0.01 10500.00 54.40 54.38 0.02 265.37 265.35 0.02 10525.00 54.66 54.67 -0.01 265.73 265.72 0.01 10550.00 54.46 54.46 -0.00 265.17 265.18 -0.01 10575.00 54.60 54.61 -0.01 264.86 264.83 0.03 10600.00 54.54 54.57 -0.03 265.51 265.48 0.03 10625.00 54.55 54.55 -0.00 265.43 265.41 0.02 10650.00 54.50 54.49 0.01 264.66 264.64 0.02 10675.00 54.05 54.06 -0.00 265.53 265.53 0.00 10700.00 54.19 54.20 -0.01 265.17 265.16 0.01 10725.00 53.95 53.95 -0.01 265.33 265.33 -0.01 10750.00 53.71 53.72 -0.01 265.53 265.53 -0.00 10775.00 53.92 53.92 -0.00 264.85 264.84 0.00 10800.00 53.55 53.57 -0.02 265.94 265.97 -0.03 10825.00 52.66 52.64 0.01 265.57 265.56 0.01 10850.00 53.05 53.04 0.01 264.99 264.96 0.03 10875.00 52.77 52.80 -0.03 265.66 265.65 0.02 10900.00 52.56 52.56 0.00 266.10 266.10 0.00 10925.00 52.51 52.52 -0.01 265.33 265.30 0.03 10950.00 52.66 52.67 -0.01 265.36 265.37 -0.01 10975.00 52.18 52.20 -0.02 266.47 266.45 0.02 11000.00 51.06 51.06 0.00 266.92 266.90 0.02 11025.00 50.63 50.61 0.02 265.77 265.75 0.02 11050.00 50.95 50.96 -0.01 266.14 266.13 0.01 11075.00 49.86 49.89 -0.03 266.78 266.74 0.04 11100.00 49.08 49.09 -0.01 266.96 266.89 0.07 11125.00 49.08 49.09 -0.01 267.83 267.82 0.00 11150.00 48.89 48.90 -0.01 267.20 267.21 -0.01 11175.00 49.26 49.26 -0.00 267.25 267.19 0.05 11200.00 48.54 48.53 0.01 267.80 267.74 0.06 11225.00 47.43 47.45 -0.02 267.65 267.60 0.06 SURV-Q167 (OPS SUR-MA-003) 19`" Nov 03 /Rev 15 Page 9 of 11 AK0109G_307 Survey QC - RGS-CTS ecification Sheet t~ o~ 11250.00 47.62 47.63 -0.01 268.30 268.26 0.04 11275.00 47.53 47.51 0.02 268.14 268.12 0.02 11300.00 47.57 47.51 0.06 268.74 268.62 0.11 11325.00 46.72 46.71 0.01 269.13 269.03 0.10 11350.00 47.00 46.96 0.04 269.61 269.56 0.05 11375.00 47.01 46.97 0.03 268.89 268.79 0.10 11400.00 47.32 47.27 0.05 269.56 269.41 0.15 11425.00 46.99 46.95 0.04 270.03 269.98 0.05 11450.00 46.88 46.81 0.07 270.08 269.98 0.10 11475.00 47.27 47.22 0.05 270.21 270.12 0.09 11500.00 47.14 47.07 0.07 270.48 270.33 0.15 11525.00 47.66 47.61 0.06 270.66 270.50 0.16 11550.00 47.29 47.16 0.13 270.97 270.78 0.19 11575.00 47.62 47.55 0.07 271.27 271.07 0.20 11600.00 47.51 47.44 0.08 271.83 271.62 0.21 11625.00 47,65 47.56 0.08 271.85 271.63 0.22 11650.00 47.77 47.69 0.09 272.23 272.05 0.18 11675.00 47.82 47.73 0.09 272.49 272.28 0.21 11700.00 47.89 47.79 0.10 272.74 272.55 0.19 11725.00 47.84 47.74 0.10 272.99 272.79 0.20 11750.00 48.00 47.90 0.10 273.35 273.17 0.18 11775.00 47.83 47.71 0.12 273.26 273.08 0.18 11800.00 48.14 48.03 0.11 273.70 273.52 0.18 11825.00 48.14 48.01 0.13 274.59 274.44 0.15 11850.00 48.00 47.87 0.12 274.84 274.69 0.15 11875.00 47.11 46.95 0.16 275.16 274.99 0.17 11900.00 47.73 47.55 0.18 275.87 275.73 0.14 11925.00 48.30 48.11 0.19 276.01 275.92 0.09 11950.00 48.66 48.47 0.19 276.22 276.15 0.07 11975.00 49.04 48.89 0.16 276.39 276.36 0.04 12000.00 49.02 48.87 0.14 276.63 276.58 0.05 12025.00 48.09 47.92 0.17 277.03 276.99 0.04 12050.00 47.45 47.27 0.18 277.00 276.91 0.08 12075.00 47.58 47.38 0.20 277.17 277.08 0.09 12100.00 47.47 47.27 0.20 276.86 276.81 0.05 12125.00 47.27 47.06 0.20 276.88 276.83 0.06 12150.00 46.87 46.70 0.17 276.83 276.77 0.06 12175.00 46.73 46.54 0.20 276.55 276.47 0.08 12200.00 46.36 46.18 0.18 276.75 276.68 0.08 12225.00 46.36 46.17 0.19 276.47 276.40 0.06 12250.00 46.13 45.94 0.20 276.75 276.69 0.06 12275.00 -46.26 45.95 0.31 276.82 276.67 0.15 12300.00 50.71 50.29 0.43 283.24 283.08 0.16 12325.00 54.14 55.06 -0.92 285.01 284.76 0.25 SURY-Q 167 (OPS SUR-MA-003) 19"' Nov 03 /Rev 15 Page 10 of it AKO1O9G_1O7 Survey QC - RGS-CTS cification Sheet o® Average 0.0044 -0.0311 Standard Deviation 0.0990 0.1488 Tolerance for both the Average and the Standard Deviation Casing 0.3~ Drill i e 0.3~ Casing 0.5~ Drill i e 0.75 * Inclination and Azimuth interpolated to same depths as shown. SURV-Q367 (OPS SUR-MA-003) 19~" Nov 03 /Rev 15 Page I7 of 11 AK0109G_107 Survey QC - RGS-CT Analysis Sheet ~Y~ SURVEY QUALITY CONTROL -DATA ANALYSIS REFERFNCF SVCTFMC Grid S stem Grid Correction 0.00 Azimuth reference: Grid True North TRUE NORTH Vertical reference: RKB MSL Other RKB If other ive details TIE ON DATA De th 0.00 Inclination 0.00 Azimuth 0.00 TVD 0.00 Northin s 0.00 Eastin s 0.00 Latitude 70.2317 Az. Ref: Grid rue True Grid Corrected Y N? N Descri tion CALIBRATION Tool Number 6051 Calibration Date 29 Mar 2008 OPERATING TEMPERATURE Calibration ran a From 49.93 To 119.89 Gyro operating range From 79.11 To 88.91 Soec' -Within calibration ranoe FTFI D RAI l TFCT Mnlu valiri nn fiva(I cfn~rtnroe 1A/hcn nnf r ofhln inn~if roll toot ~i~to nog-Fn~mo.i ~f+o~ ~o*~~... r., ~,~~e~ Cal value Pre ~ob offset ost ~ob offset Abs dif.cal. ost Abs dif. re. ost Sec' Accel Scale 0.000000 0.000000 N A Cal Post - 0.00015 Mass Unbalance 0.00 0.00 N A Pre Post - 0.4° hr TNTTTAI TSATTCIN De th A rox 3145.36 No of stns 10 Sec' -Min No. - 6 Azimuth Mean 282.24 Std deviation 0.04 Sec' - Azi SD 0.2° Inclination Mean 14.59 Std deviation 0.00 Sec' -Inc SD 0.1° Earth Horizontal Rate Mean Abs mess-theor 0.18 Std deviation 0.03 Sec' -See 167 DRIFT TUNE Residual x ro bias Mean 0.000 Std dev' 0.002 Sec's -Mean and SD - 0.333 hr Residual ro bias Mean -0.001 Std dev' 0.002 Sec's -Mean and SD - 0.333° hr TOOLFACE RATE Maximum toolface rate 37.62 Sec' - 400° sec TN /AIIT CAMPARTCAN /A7T' N /A TF TNN ti C°1 Inclination Difference Mean 0.00 Std dev' 0.10 Sec's -Casin 0.3° Drill i e 0.3° Azimuth Difference Mean -0.03 Std dev' 0.15 Sec's -Casin 0.5° Drill i e 0.75° Lateral Diver ence 1000 0.49 Sec - 5.0 1000 Vertical Diver ence/1000 0.07 Sec' - 2.0/1000 DEPTH CONTROL Wireline Com an Schlumber er Line a 15 32 Encoder SF Schlumber er Max De th TD 12325 CCL Corrected Yes Zero De th Ri u Casin Flan a Rezero De th -12.4 Given u ~oint de th 11414.41 Measured P] 11422.87 Strech cor. At TD divided b TD 1000 1.1789 Sec' - 1.5/1000 Dif. Between ri u and rezero de the divided b TD 1000 1.0081 Sec' - 2.0 1000 Dif. Between iven and meas de th divided b mess 1000 .6878 Sec' - 2.0 1000 SURV-Q365 (OPS SUR-MA-010) 22ntl )an 2004 /Revision 20 Page 1 of 1 AK0109G-107 Survey QC - RGS-CT Acceptance Sheet ~~~ FIELD AND SURVEY INFORMATION Operator BP Exploration (Alaska) Field /Platform Wellhead Well Number Drill Site DS03-16A Survey section From 3145.00 ft. to 12372.00 ft. Date 21 Jan 2009 Gyrodata Job No AK0109G-107 Gyrodata Surveyors Jamie McCrimmon Job Objective High Accuracy Gyro Survey SURVEY PERFORMANCE In Spec' QC Parameter Yes/No/NA Possible Actions Contact Duty Engineer to discuss options: Operational temperature within Yes 1. Recalibrate tool to higher temperature specification 2. Resurvey with backup tool 3. Resurvey 'Hot' section at higher speed Roll test data within specification Contact Duty Engineer to discuss options: Only valid on land/fixed installations Yes 1. Recalibrate tool and reprocess survey 2. Resurve with backu tool Continuous initialisation within Take new initialisation, after three failures: specification Yes 1. Contact Duty Engineer or, 2. Resurve with backu tool. Contact Duty Engineer to discuss options: Toolface rate within specification Yes Resurvey section from previous bias check Investi ate and comment if effects are ne li ible Contact Duty Engineer to discuss options: Drift tunes within specification Yes 1. Reprocess with different software settings 2. Resurve with backu tool Inrun/Outrun comparison within Contact Duty Engineer to discuss options. specification Yes Resurvey is usually not required if either inrun or outrun meet all other C arameters Depth control within specification Yes Contact Duty Engineer to discuss options. Action taken: Note: Provided satisfactory action has been taken, parameters out with specification will not necessarily fail a survey. SURVEY ACCEPTED Gyrodata Representative Client's Representative SURV-Q366 (OPS SUR-MA-003) 13`" Nov 03 /Revision 12 Page 1 of 1 AK0109G_107 MEMORANDUM . TO: Jim Regg ~ ,; ;1 P.I. Supervisor L I FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 26, 2007 SliBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) PVC 03-16A PRUDHOE BAY' LNIT 03-16A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I.Suprv~i~~~ '" Comm WeII Name: PRUDHOE BAY UNIT 03-16A Insp Num: mitCS07 1 22 1 092943 Rel Insp Num: API Well Number: 50-029-204 1 5-0 1-00 Permit Number: t97-033-0 Inspector Name: Chuck Scheve Inspection Date: 12/19/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! 03-16A ~~TYPe Inj. W ~ TVD _ 8279 IA ~ _ 80~ i 2310 2280 2280 ' ~ ! I P.T ' 1970330 ~TypeTeSt I SPT ~~ TCSt pSt '~I _ 2069.75 ' ~I QA ~ 60 100 ~ 100 100 ~ InterVal 4YRTST P~F P TUbing ~'i -- 1060 1060 ' - - 1060 1060 NOteS: Pre-test pressures observed and found stable. ~~~~~~~ JA1~ ~ 200 Wednesday, December 26, 2007 Pale I of I 11'-"'.:11, ~ f 11 ¡..vv T STATE OF ALASKA RÉéfE,'HVE" /01- ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROV ALAPR - 92004 20 AAC 25.280 ! .~ 1, Type of Request: Abandon 0 Suspend 0 Alter Casinç 0 Repair Well 0 Change Approved Program I!J / Pull Tubing 0 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7, KB Elevation (ft): 64.00 KB 8. Property Designation: ADL-0028328 11. Total Depth MD (ft): 15311 Casing .ength Size Conductor 73 Liner 730 Liner 4 Liner 3748 Production 11802 Surface 2696 Perforation Depth MD (ft): I 12850 . 12890 12870 . 12940 12920 . 12870 Packers and SSSV Type: 4-1/2" Baker FHL Packer 5-1/2" BTDP-1 SSV 5-1/2" HBBP-T Packer 12, Attachments: Description Summary of Proposal Œ Detailed Operations Program Œ BOP Sketch D 14, Estimated. Date for . A rilLJ. 004 Commencing Operatlor p ev:¿1 16, Verbal Approval: Date: Commission Representative: 20" 94# H-40 7" 29# L-80 3-1/2" 9.3# L-80 2-7/8" 6.5# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 Perforation Depth TVD (ft): 9065. 9069.2 9074 - 9076.1 9061. 9065.3 Operation Shutdown D Pluç Perforations 0 Perforate New Pool D 4. Current Well Class: Development D MD top bottom top 30 103 30.0 11550 12280 8364.9 11559 11563 8371.0 11563 15311 8373.8 28 11830 28.0 29 2725 29.0 Tubing Size: 5.5 " 4.5 " Alaska Oil & Gas Cons. Commission PerforateD variance~choRm~lar DisposalD StimulateD Time ExtensionD OtherD Re-enter Suspended Well 0 5. Permit to Drill Number: 197-0330 Exploratory D . liD bottom 103.0 8859.6 8373.8 9005.0 8554.1 2724.9 Tubing Grade: 17 # 12.6 # Packers and SSSV MD (ft): 6, API Number 50-029-20415-01-00 Plugs (md): 13190 13600 14100 14750 Burst L-80 L-80 1530 8160 10160 10570 6870 4930 Tubing MD (ft): 26 11523 StratigraphicD Service ŒI 9, Well Name and Number: 03-16A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 9005.0 15279 8941.2 11533 2155 11424 13, Well Class after proposed work: ExploratoryD DevelopmentD 15. Well Status after proposed work: Oil D GasD WAG D GINJD 17, I hereby certify that the foregoing is true and correct to the best of my knowledge, Printed Name Signature Brian Carlson ~7f-C;~ Commission Use Only Plug Integrity D Conditions of approval: Notify Commission so that a representative may witness Mechanciallntegrity Test D Other: Subsequent 0 ORIGINAL Title Phone ServiceŒ Junk (md): None Collapse 520 7020 10530 11160 4760 2670 11523 11586 PluggedD AbandonedD WINJŒ / WDSPLD Perpared by Garry Catron 564-4657, Contact Brian Carlson Petroleum Engineer 564-5046 Location Clearance D 3/22/04 I Sundry Number: 30'1 -/1 ~ J 393 a77 ':Fr;- RBDMS BFL API 2 0 200\ BY ORDER OF '~t <tf1~f THE COMMISSION Date: #f/ /..;) ð SUBMIT! IN DU ICA ...- bp To: Doug Cismoski/J ohn Smart GPB Well Ops Team Leaders Date: 3/22/04 From: Brian Carlson DS 3/9/14 Production Engineer Subject: DS 03-16A Acid Stimulation PBD03WL16-C Capacity Sustainment Est. Cost: $80M lOR: 400 Please replace the fullbore acid stimulation procedure on the WBL with the updated coil tubing acid /" stimulation. Type lOR PR N DS-WL AFE JOB DESCRIPTION PRIORITY COMMENTS/OTHER c 400 4 03-16 A PBD03WL16-CAcidStim Max Deviation: Min. ill: Last TD tag: Last Downhole Ops: Latest H2S value: Tie-in Log: 96 deg @ l3,400'MD 2.441" @ 11,563' MD, 3-1/2"x2-7/8" crossover 12,400 1/24/04 set CIBP; 13190 'MD on 1/26/02 Adperf 1/25/04 No Data MWD Sperry GR 4/4/97 Well3-l6A was a MIST injector in Zone 3. All ofthe MI bulbs are complete. To provide injection support to the offset Zone 4 producers, 3-16A was plugged back and perforated in Zone 4. The injection rates are very low, so an acid procedure is needed to clean up the perforation interval. Contact Brian Carlson at x5046, 349-6592 (home), or 350-8427 (cell) with any questions or comments. cc: w/a: 03-16A Well File Brian Carlson ~ ~~ 03-16Ai Acid Stimulation Program Prepared By: Brian Carlson Phone#: 564-5046(w),350-8427(c) JOB PLANNING DETAILS: Perfs: 12300' - 12360' (new perfs) 12850' - 12890' (isolated by plug) 12920' - 12940' (isolated by plug) 13360' - 13410' (isolated by plug) 13825' - 13900' (isolated by plug) 14470' - 14550' (isolated by plug) 15050' - 15090' (isolated by plug) 15178' - 15278' (isolated by plug) ISSSV: Out 1/18/04. 5 Yz" BTDP-1 @ 2155' MD. TD Tag History: 12,400 MD 1/24/04. cmp setting Displacement bbls: 272 bbls (tubing = 268, 2-7/8"liner to top perf = 4) Coil String Weight: 16K# @ 12500' CTM, 1/28/02 Static: -3300 psi, 188°F; (3460 psi @8800'SS 2/13/98) NOTE: cmp set at 12,400' (1/24/04) cmp set at 13,190' (1/26/02). Beware of potential H2S in any returns taken at surface. CT OPERATIONS: 6. RU CT. Trap 1000 psi on the IA. 7. Make multiple passes across the perfs and pump the following at a maximum rate with a recommended maximum WHP of 2000 psi (*). Don't POOH until the entire overflush has been pumped behind pipe in order to reduce the chance of stirring up schmoo. 25 bbls 3% NH4CI with 10% U-66 and 0.2% F1O3 100 bbls 7.5% HCI 50 bbls 9% - 1 % HCI-HF 100 bbls 3% NH4Cl overflush with 10% U-66 and 0.2% F1O3 * Go to 3000 psi if necessary to establish injection. Once acid is at the perfs the maximum treating pressure should be 2000 psi. All fluids should be filtered to 3 microns. Please note the initial and final injectivity in the WSR. Please note the vitals in the WSR when each ^.. .' ,~ ..., stage hits the perfs. Please run a cable so that the pump truck can record back side WHP on the treating report. Please e-mail the treating report to the program author. Treatment Design: 4200 gal 7.5% HCI 0.5% A26I 0.5% A20I 20 ppt L58 0.2% F1O3 0.5% W54 0.5% W60 2100 gal 9:1 HCI:HF 0.5% A26I 0.5% A20I 0.2% F1O3 20 ppt L58 0.5% W54 0.5% W60 -125 bbIs 3% NH4CI water with 10% U-66 and 0.2% F1O3 Please note the acid titrations and iron ppm on the WSR. 8. POOH. Bleed lAP. RDMO. Put on PWI injection. L- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1, Operations Performed: AbandonD Alter Casing 0 Change Approved Program 0 2, Operator SuspendD Repair Well 0 Pull TubingD Operation Shutdown D Plug PerforationsŒ] Perforate New Pool D 4. Current Well Class: Perforate 00 WaiverD Stimulate 0 Time ExtensionD Re-enter Suspended Well 0 5, Permit to Drill Number: 197-0330 OtherD Name: BP Exploration (Alaska), Inc. Development D Stratigraphic 0 9, Well Name and Number: 03-16A 10. FieldlPool(s): Prudhoe Bay Field / Prudhoe Oil Pool ExploratoryD ServiceŒ 6, API Number 50-029-20415-01-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7, KB Elevation (ft): 64.00 8. Property Designation: ADL-0028328 11. Present Well Condition Summary: Total Depth measured 15311 feet true vertical 9005.0 feet Plugs (measured) 12399,13190,13600,14100,14750 Effective Depth measured 12399 feet Junk (measured) 12540 true vertical 8927.1 feet Casing Length Size MD TVD Burst Collapse Conductor 73 20" 94# H-40 30 103 30.0 - 103.0 1530 520 Liner 730 7" 29# L-aO 11550 - 12280 8364.9 - 8859.6 8160 7020 Liner 4 3-1/2" 9.3# L-80 11559 - 11563 8371.0 - 8373.8 10160 10530 Liner 3748 2-7/8" 6.5# L-80 11563 - 15311 8373.8 - 9005.0 10570 11160 Production 11802 9-5/8" 47# L-80 28 - 11830 28.0 - 8554.1 6870 4760 Surface 2696 13-3/8" 72# L-80 29 - 2725 29.0 - 2724.9 4930 2670 Perforation depth: Measured depth: 12300 - 12330, 12330 -12360 True vertical depth: 8873.07 - 8891.18,8891.18 - 8891.18 RECEIVED Tubing ( size, grade, and measured depth): Packers & SSSV (type & measured depth): 5-1/2" 17# L-80 4-1/2" 12.6# L-80 4-1/2" Baker FHL Packer 5-1/2" BTDP-1 SSV 5-1/2" HBBP-T Packer @ 26 @ 11523 @ 11533 @ 2155 @ 11424 11523 11586 MAK 3 0 2004 Alaska Oil & Gas Cons. Commi88ion Anchor8ge 12, Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Averaae Production or Iniection Data Gas-Met Water-Bbl Casing Pressure 0 4145 0 Rll)MS at &.. MAR 31- luU't 13 Prior to well operation: Subsequent to operation: Oil-Bbl 0 0 0 1628 0 Tubing Pressure 1722 1762 14, Attachments: 15, Well Class after proposed work: ExploratoryD Development 0 ServiceŒ Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown 0 OilD Gas 0 WAG D GINJD WINJŒ WDSPLD Prepared by Garry Catron (907) 564-4657, SUndry Number or N/A if C,O, Exempt: 303-377 Daily Report of Well Operations. ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, Contact Garry Catron Printed Name Garry Catron ß~C~ Form 10-404 Revised 12/2003 Title Production Technical Assistant Signature . Phçme : 5~.4-4657 Date 3/25/04 > < ' - 03-16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 01/18/04 --WELL INJ WATER ON ARRIVAL-- (PRE ADPERF) DRIFT 4,5" GAUGE RING TO SSSV @ 2130' SLM PULLED 51/2" SSSV (BTDP-1 SER# HVS-1058) *** LOST BRASS PRONG OFF OF PULLING TOOL 24" OAL 1.315 OD *** MADE 2 ATTEMPTS W/2" DUMMY GUN & 2.33 OVERSHOT WI 1.31 GRAPPLE TO TRY RETRIEVE BRASS PRONG DRIFTED WI 2" DUMMY GUN, 2.25 CENT & SAMPLE BAILER STOPPED DUE TO DEVIATION @ 12,540' SLM' *** FISH LEFT IN HOLE BRASS PRONG 24" OAL 1,315 OD*** *** PUT WELL BACK ON INJECTION *** 01/24/04 TIIIO 0/0/0. ASSIST E-LINE. PRESSURE TEST BRIDGE PLUG, PUMPED 22.3 BBLS METH DOWN TBG. HELD 3000 PSI FOR 15 MINS.TP HELD @ 3000 PSI FOR 15 MIN TEST. BLEED TBG PRESSURE DOWN. RDMOL FINAL WHP'S 0/0/0. 01124/04 SET CIBP @ 12399' 01/24/04 Perforate 12330'-12360' 6 SPF 01/25/04 Perforate 12300'-12330' 6 SPF FLUIDS PUMPED BBLS 45 4 49 Methonal Diesel TOTAL Page 1 >. ,. ,- TREE = WELLHEAD = ACTU4. TOR = 1<8, 8..EV = BF, 8..EV~ KOP= llfax Angle = Datum M) = DatumTVO= FWC GEN 1 FWC . AXELSON 64' 3000' 96 @1~400' 12287' 8áoo' SS 113-3/8" CSG, 72#, L-80, 10 = 12,347' H 2725' 15-1/2" 1BG,17#, L-80, .0232 bpf, 10= 4.892" H 11480' I TOP OF 5-1/2" TBG H 11480' 15-1/2" TBG, 17#, No80. .0232 bpf, 10= 4.892" H 11523' TOPOF 4-1/2" TBG H 11523' Minimum ID = 2.441 @ 11563' 3-112" X 2-7/8" CROSSOVER ITOPOFT' LI'R H 11550' I TOPOF2-7/8"LI'RH 11563' I 4-1/2"ìBG,12.6#,N-80,.0152bpf,10=3.958" Ii- 11586' I I 9-5/8" CSG. 47#, L-80, 10= 8,681" H 11830' I I T' LNR, 29#, L-80, .0371 bpf, 10 = 6.184" H 12280' I ÆRFORA TlON SUMI'v\A.RY REF LOG: NGPON04/12/97 ANGLE AT TOP PERF: 50 @ 12300' Note: Refer to Production œ for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 2" 6 12300-12360 0 01/25/04 2" 6 12850 - 12890 0 01/28/02 2" 6 12920 - 12940 0 01/28/02 2" 6 13360-13410 C 01/26/02 2" 4 13825-13900 C 01/29/00 1-11/16" 4 14470 -14550 C 04/02/98 2-118" 4 15050-15090 C 06/23/97 2-118" 4 15178-15278 C 04/15/97 03-16A . - r.4I:g &~ SAÆTYNOTES: FHLmW HBBP PKRS HAVE REDUCED TEST PRESSURE UMITS IN SOME CASES - CONTACT ACEx51 02 PRIOR TO PRESSURE TESTING. HORIZONTAL WELL - 70° @ 12530' AND 90° @ 12988' 2155' H 5-1/2"CAMCOBAL-O SSSV NP.10=4.56" hl Z ~ ... I I 11424' H 9-5I8"X5-1/2"TWI-BBP-TPKR I I 11458' H 5-1/2" HES XN NP, 10 = 4.55" I 11489' H 5-1/2" UNQUEOVERSHOT I 11514' H 5-1/2" BAKER PBR ASSY I 11523' H 5-1/2" X 4-1/2" XO I 11533' H 9-518" X 4-1/2" BKR FHL PKR .. I 11559' H 4-1/2"G SEAL SUB I 11563' H 3-1/2"X2-7/8"XO,10=2.441" I 11584' H 4-1/2"OT6 XLANONGNIP, 10= 3,81" I I 11586' H4-1/2" TLBING TAIL W/WLEG (BB-IIt'Ð LNR) I 11591' HELMOTTLOGGED05/03/85 I 7" MILLOur WINDOW 12280' H , ... I 12400' H 2-7/8" clap I I 12540' H FISH(1,315"ODX24"BRASSffiONG01/18/04) 2-7/8" clap SET 01/26/02 I 13600' H 2-7/8" CIBP SET 11/23/00 I 14100' H 2-7/8" OBPSET01/28100 I 14750' H 2-1/2" OBPSET03l02l98 I 15161' H 2-1/8"GUNS-118'AREO I 15311' H 2-7/8" FL4S TIW I I R. T/GD SHOE IFBTDH 15300' I 2-718" LNR. 6.5#, L-80, .0058 bpf. 10= 2.441" H 15311' I RBI BY DA TE REV BY COMM;NTS 01/19/04 JBMffiH FISH 01/25/04 CAOITLP PERFS, asP, PERF ANGLE PRUDHOE BAY lA'IlT WELL: O3-16A PERMrr I\b: 1970330 AR I\b: 50-029-20415-01 SEe 10, T10N, R15E, 1637.6' F8.. & 2205.8' FNL DATE 04/08/85 03/11198 OU)51O1 02102102 06/24102 07101102 COMlll8\lTS ORIGINAL COMPLErION WORKOVER SIS-Ivo FINAL RNIlP CORREeTONS BHe/lLH PERF I!\FO CORRECTION BHe/KK PERF I!\FO CORRECTION BP Exploration (Alas ka) MEMORANDUM TO: Jim Regg P.I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission ~ ~'~,,; i /6/otr ~1 SUBJECT: Mechanical Integrity Test BPX OS 3 3-16A PBU DATE: January 4, 2004 FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL Well 3-16A Type Inj, P.TD. 197-033 Type test Notes: Well P,TD, Notes: Well P.T.D. Notes: Well P,TD. Notes: Well P.TD, Notes: Type INJ, Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Inj. Type test Type Inj. Type test Type Inj, Type test Type Inj. Type test s P Packer Depth TV,D, 8278 Test psi 2070 Pretest Tubing 1660 Casing 520 Initial 1660 2200 15 Min, 30 Min, 1660 1660 Interval 2170 2170 P/F 4 P TV.D. Tubing Test psi Casing TV,D, Tubing Test psi Casing TV,D, Tubing Test psi Casing TV,D. Tubing Test psi Casing Interval P/F Interval P/F Interval P/F Interval P/F Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details I traveled to BPXs DS 3 in the Prudhoe Bay Field and witnessed the routine 4 year MIT on well 3-16A. The pretest tubing and casing pressures were observed and found to be stable. The pressure test was then perfonned with the well demonstrating good mechanical integrity. M.LT.'s performed: 1 Attachments: II. n f\ f\~! ~. :;. <dLðù. "" Anr/{ Zt"',dc¡j' MIT report form 5/12/00 L.G. Number of Failures: Q Total Time during tests: 1 hour cc: MIT PBU 3-16A 1-4-04 CS.xls 1/6/2004 ~ 11../ 1'1 JWO'~ ( STATE OF ALASKA ( Of7S R/ (?(:z ALASIÒ-. .JIL AND GAS CONSERVATION CO~...,SSION /"'--Á1 1 j J APPLICATION FOR SUNDRY APPROVAL Vlj I v( Ir 20 AAC 25.280 1 . Type of Request: D Suspend D Abandon Alter CasinQ D Repair Well D Change Approved Program 0 Pull Tubing 0 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 64.00 KB 8. Property Designation: ADL-0028328 11. Total Depth MD (ft): 15311 Casing _ength Size Conductor 73 Un~ no Uner 4 Liner 3748 Production 11802 Surface 2696 Perforation Depth MD (ft): I 12850 - 12890 12870 - 12940 12920 - 12870 Packers and SSSV Type: 4-1/2" Baker FHL Packer 5-1/2" BTDP-1 SSV 5-1/2" HBBP-T Packer 12. Attachments: Description Summary of Proposal ŒI 20" 94# H-40 7" 29# L-80 3-1/2" 9.3# L-80 2-7/8" 6.5# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 Perforation Depth TVD (ft): 9065 - 9069.2 9074 - 9076.1 9061 - 9065.3 Detailed Operations Program ŒI BOP Sketch D Operation Shutdown D PluQ Perforations IX] Perforate New Pool D 4. Current Well Class: Perforate [!] Variance D Stimulate IX) Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 197-0330 / Development D MD top bottom top 30 103 30.0 11550 12280 8364.9 11559 11563 8371.0 11563 15311 8373.8 28 11830 28.0 29 2725 29.0 Tubing Size: 5.5 " 4.5 " Packers and SSSV MD (ft): Exploratory D 6. API Number / 50-029-20415-01-00 ¡VD Plugs (md): # 13190 # # 13600 # # 14100 # # 14750 # Burst Stratigraphic D Service ŒJ 9. Well Name and Number: 03-16A / 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 9005.0 15279 8941.2 17 # 12.6 # bottom 103.0 8859.6 8373.8 9005.0 8554.1 2724.9 Tubing Grade: L-80 L-80 1530 8160 10160 10570 6870 4930 Tubing MD (ft): 26 11523 11533 2155 11424 ExploratoryD 13, Well Class after proposed work: ServiceŒl 14. Estimated Date for January 1,2004 / Commencing Operatior 16. Verbal Approval: Date: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Other: Subsequent Form Required: j (:) .- "D if Approved by: angina' Sign~ By !-orm , U-4U::i HeVlsea :¿/:¿(I¡&lJ.,;!\ rat!" DevelopmentD 15. Well Status after proposed work: Oil D Gas 0 Plugged 0 WAG D GINJD WINJŒ) Title Phone Annular Disposal D OtherD Junk (md): None Collapse 520 7020 10530 11160 4760 2670 11523 11586 Abandoned D WDSPLD Perpared by Garry Catron 564-4657. Contact Brian Carlson Brian Carlson 71~ ~ ~~ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I Sundry Numb~È 'ð t¡ p Plug Integrity 0 BOP Test 0 nd.pc< tion aørsce c::R. E C t:: \ . ~l, 1 Ó" 0 Eel 7 2.003 \ . BY ORDER o~'aska Oil & Gas con~CT~~--< 0 ~ !&~+.... jt H: $ 1 20¡ijH E COMM I SSION D~~~~~~~ol"';l ¿, I (I f/ ~ Petroleum Engineer 564-5046 Mechanciallntegrity Test D RBDMS Bf L 1218/03 bp '... ,\It.",. ........~ ~..... ~4!:- -:...-- ...~ -F""~ .'I'~~I\~ ". \ \ To: Doug Cismoski/John Smart GPB Well Ops Team Leaders Date: 12/3/03 From: Brian Carlson DS 3/9/14/16 Production Engineer Subject: DS 03-16A CIBP" Perf" and Acid Stimulation PBLDO03016 Capacity Sustainment Est. Cost: $120M lOR: 350 Please perform the following steps to convert 03-16A into a Z4 only injector. Type lOR PR N DS-WL AFE JOB DESCRIPTION PRIORITY COMMENTS/OTHER 0 350 S 350 E 350 C 350 1 2 03-16 A PBLDO03016 SBG 03-16 A PBLDO03016 PulllSSSV, Drift 3 4 03-16 A PBLDO03016 Set CIBP and Adperf 03-16 A PBLDO03016 Acid Stirn Procedure: 1. 0 2. S 3. E 4. C SBG. Pull ISSSV. Drift as deep as possible. . Set CffiP at 12,400'MD. Perforate 12300-12360'MD (see attached procedure). /' Perform acid stimulation (see attached procedure). Max Deviation: 96 deg @ 13,400'MD Proposed Plug Deviation: 61 deg Proposed Adperf Deviation: 50 deg Min. ill: 2.441" @ 11,563' MD, 3-1/2"x2-7/8" crossover Last TD tag: 13190 'MD on 1/26/02 Last Downhole Ops: Adperf 1/28/02 Latest H2S value: No Data Tie-in Log: MWD Sperry GR 4/4/97 i We1l3-16A was a MIST injector in Zone 3. All of the MI bulbs are complete. To provide injection / support to the offset Zone 4 producers, 3-16A should be plugged back and perforated in Zone 4. All of the previous bulbs required an acid job, so an acid stimulation procedure is attached to provide injectivity. Contact Brian Carlson at x5046, 349-6592 (home), or 350-8427 (cell) with any questions or comments. cc: w/a: 03-16A Well File Brian Carlson 03-16Ai Recompletion Program Prepared By: Brian Carlson Phone#: 564-5046(w),350-8427(c) JOB PLANNING DETAILS: Perfs: 12300' - 12360' (new perfs-see attached procedure) 12850' - 12890' (to be isolated by plug) 12920' - 12940' (to be isolated by plug) 13360' - 13410' (isolated by plug) 13825' - 13900' (isolated by plug) 14470' - 14550' (isolated by plug) 15050' - 15090' (isolated by plug) 15178' - 15278' (isolated by plug) ProposedPlug Deviation: 61 deg Proposed Perf Deviation: 50 deg ISSSV: In. 5 Yz" BTDP-l @ 2155' MD. TD Tag History: 13,190' MD 1/26/02. CIBP setting Displacement bbls: 276 bbls (tubing = 268, 2-7/8"liner to top perf = 8) Coil String Weight: 16K# @ 12500' CTM, 1/28/02 Static: ....3300 psi, 188°P; (3460 psi @8800'SS 2/13/98) NOTE: CIBP to be set at 12,400' MD CIBP set at 13,190' (1/26/02). Beware of potential H2S in any returns taken at surface. PREP WORK: 1. Pump SBG as per SOP. 2. Pull ISSSV. Drift as deep as possible. E-LINE OPERATIONS: 3. SI Injection. RU E-Line 4. RIH with 2-7/8" CIBP and set at 12,400'MD. Pressure test the CIBP to 3000 psi. 5. Perforate with 2" powerjets, 6 spp from 12,300-12,360'MD. See attached procedure. RDMO { ~ CT OPERATIONS: 6. RU CT. Trap 1000 psi on the IA. 7. Make multiple passes across the perfs and pump the following at a maximum rate with a recommended maximum WHP of 2000 psi (*). Don't POOH until the entire overflush has been pumped behind pipe in order to reduce the chance of stirring up schmoo. 25 bbls 3% NH4Cl with 10% U-66 and 0.2% FI03 / 100 bbls 7.5% HCl 50 bbls 9% - 1 % HCl-HF 100 bbls 3% NH4Cl overflush with 10% U-66 and 0.2% FI03 * Go to 3000 psi if necessary to establish injection. Once acid is at the perfs the maximum treating pressure should be 2000 psi. All fluids should be filtered to 3 microns. Please note the initial and final injectivity in the WSR. Please note the vitals in the WSR when each stage hits the perfs. Please run a cable so that the pump truck can record back side WHP on the treating report. Please e-mail the treating report to the program author. Treatment Design: 4200 gal 7.5% HCl 0.5% A261 0.5% A201 20 ppt L58 0.2% FI03 0.5% W54 0.5% W60 2100 gal 9: 1 HCl:HF 0.5% A261 0.5% A201 0.2% FI03 20 ppt L58 0.5% W54 0.5% W60 -125 bbls 3% NH4Cl water with 10% U-66 and 0.2% FI03 Please note the acid titrations and iron ppm on the WSR. 8. POOH. Bleed lAP. RDMO. Put on PWI injection. TREE = WELLHEA D = ' ACTCLA. TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = . . , Datum rvD = Datum TVD = { FIVC GEN 1 FIVC AXELSON 64' 3000' 96~ 13400' 12287' 8800' SS 113-318" CSG, 72#, L-80, D = 12,347' H 272r1 1 5-1 f2" lBG, 17#, L-80, 0.0232 bpf, D = 4,892" H 11480' I TOPOF 5-1/2" TBG H 11480' 5-1f2"lBG, 17#, N80, 0.0232 bpf ,ID=4.892 H 11523' ITOPOF 4-112" lBG H 11523' Minimum ID = 2.441 @ 11563' 3-11288 X 2-7/888 CROSSOVER 03-16A e ~ :8: :&~ I ~ 1 ' Z ~ ITOPOF7"LNRI-1 11550' h 1 TOP OF 2-7/8" LNR 1-1 11563' 1 1 4-1f2"lBG, 12,6#,N-80,0.0152bpf,ID=3.958" 1-1 11586' 1 I H' j l 1 9-518" CSG, 47#, L-80, ID= 8,681" 1-1 11830' ~ 1 7" LNR, 29#, L-80, ~0371 bpf, ID = 6,184" 1-1 12280' PffiFORA TION SUMMARY REF LOG: NGP ON 04/12/97 ANGLE AT TOP ÆRF: 76 @ 12850' Note: Refer to Production DB for historcal perf data SIZE SFF NTffiVAL Opn/Sqz DATE 2" 6 12850 - 12890 0 01/28/02 2" 6 12920 - 12940 0 01/28/02 2" 6 13360 - 13410 C 01/26/02 2" 4 13825 - 13900 C 01/29/00 1-11/16" 4 14470 - 14550 C 04/02/98 2-1/8" 4 15050 - 15090 C 06/23/97 2-1/8" 4 15178 - 15278 C 04/15/97 \ SAFETY NOTES: FHUTIW I-BBP PKRS HAV E REDUCED TEST PRESSLRE LIMITS IN SOMECASES - CONTACT ACEx5102 PRIOR TO PRESSURE TESTII\G. HORIZONTAL Wa.L - 7(1> @ 12530' AN) 9O0@ 12988' 2155' H 5-1/2" CAMCO BAL-O SSSV NP, ID=4,56" 1 1 11424' H 9-518" X 5-1/2" TW I-BBP- T PKR I 1 11458' H 5-1/2" HES XN NP, ID = 4,55" 1 11489' H 5-1/2" UNQUEOVERSH)T 1 1 11514' H 5-1/2" BAKER PBR ASSY 1 1 11523' 1-1 5-1/2" X 4-1/2" XO 1 11533' H 9-5/8" X 4-1/2" BKR FHL PKR 1 11559' 1-1 4-1/2" G SEAL SUB 1 1 11563' 1-1 3-1/2"X2-7/8"XO,ID=2.441"1 1 11584' 1-1 4-1/2"OT6XLANDNGNIP,ID=3,81" 1 1 11586' H4-1/2" TLBING TAIL W/WLEG (BB-HND LNR) 1 1 11591' HELMDTTLOGGBJ 05/03/85 .. 7" MILLOur WINDOW 12280' 13190' 1-1 2-7/8"CIBPSET01/26/02 1 13600' H 2-7/8" CIBP SET 11f23/00 1 14100' 1-1 2-7/8" OBPSET01/28/00 1 1 14750' H 2-1/2" OBPSET03/02l98 1 1-1 2-1/8" GU\JS - 118' ARED 1 2- 7/8" FL4S llW FLT/GD SHOE 1 2-718"LNR,6,5#,L-80"O058bpf,ID=2.441" 1-1 15311' 1 REV BY DA TE REV BY COMrvENTS 06/24/02 BHCltlh PffiF NFO CORRECllON 07/01/02 BI-C/KK PffiF NFO CORRECllON DATE 04/08/85 03/11/98 12/26/00 01/05/01 02/02/02 OOMMß\JTS ORIGINAL OOrvPLETION WORKOV ffi SIS-QAA OOIW ffiTED TO CA IW AS SIS-MD ANAL RI\VTP OORRECTIONS FRUDHOE BA Y UNIT WELL: 03-16A PERMIT No: 197-0330 API No: 50-029-20415-01 SEC10 T10N R15E 1637,6 FEL 2205,8 FNL BP Exploration (Alas ka) " Effective depth: Casing Conductor Surface Intermediate Liner Sidetrack Liner Perforation depth: .,./'--. -. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation shutdown- Pull tubing - Stimulate _X Alter casing - 5. Type of Well: 1, Operations performed: SaG/Clap/Add Perfs 2. Name of Operator BP Exploration (Alaska), Inc. 3, Address P. O. Box 196612 Anchorage, AK 99519-6612 4, Location of well at surface 4027' FNL, 76' FEL, Sec. 010, T10N, R15E, UM At top of productive interval 4926' FNL, 1596' FEL, Sec. 09, T10N, R15E, UM At effective depth 4207' FNL, 1896' FEL, Sec. 09, T10N, R15E, UM At total depth 2206'FNL, 1638'FEL, Sec. 09, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical Development - Exploratory- Stratigraphic- Service_X (asp's 713185, 5937286) (asp's 706416, 5936204) (asp's 706095, 5936913) (asp's 706293, 5938919) 15311 feet 9005 feet Plugs (measured) measured true vertical 131 90 feet 9069 feet Junk (measured) Length 73' 2661' 11766' 730' 3752' Plugging - Perforate _X Repair well - Other _X clap 6, Datum elevation (DF or KB feet) RKB 64 feet 7, Unit or Property name Prudhoe Bay Unit 8, Well number 03-16A 9. Permit number / approval number 1.97 -o33t:~ 10.AP(number ' 50-029-20415-01 11. Field / Pool Prudhoe Bay Oil Pool CIBP set @ 13190' (01/27/2002) CIBP set @ 14100' (01/28/2000) CIBP set @ 14750' (03/02/1998) Size Cemented Measured Depth True Vertical Depth 20" 383 sx AS 137' 137' 13-3/8" 2100 sx Fondu 2725' 2725' 9-5/8" 500 sx Class 'G' 11830' 8554' 7" 548 sx Class 'G' 11550' - 12280' 8365' - 8860' 2-7/8" 26 bbls Class 'G' 11559' - 15311' 8371' - 9005' measured Open Perfs 12850'-12890',12920'-12940', Isolated Below CIBP's 13825'-13900', Isolated Below CIBP's - continued 14470'-14550',15050'-15090',15178'-15278' true vertical Open Perfs 9061'-9069', 9074'-9076', Isolated Below CIBP's 9043'-9044', Isolated Below CIBP's - continued 9045'-9042', 9013'-9011', 9008'-9005' Tubing (size, grade, and measured depth) 5-1/2",17#, L-80 TBG @ 11523'. 5-1/2" X 4-1/2" XO @ 11523'. 4-1/2", 12.6#TT @ 11591'. Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" TIW HBBP-T Packer @ 11424', 9-5/8" X 4-1/2" BKR FHL PKR @ 11533'. 5-1/2" Camco BAL-O SSSV Landing Nipple @ 2155'. 13, Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14, Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Prior to well operation 01/17/2002 Subsequent to operation 02/09/2002 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations - Oil - Gas - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~~~~ CasinQ Pressure TubinQ Pressure 1822 3218 2510 25826 16. Status of well classification as: Title: Technical Assistant Form 10-404 Rev 06/15/88 . .'-, ¡ ¡ \.j i lJ 1 t\J ~\ L- Suspended - Service WAG Injector RECEiVi[~ruary 15, 2002 Prepared by DeWayne R, Schnorr 564.5174 FEB .1 5 2002 ~ \ Alaska Oil & Gas Cons. Commission Anchoraqe SUBMIT IN DUPLICATE ~ 03-16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 01/07/2002 PERF(ADD-PERF): PUMP SCHMOO-B-GONE 01/08/2002 PERF(ADD-PERF): SCHMOO-B-GONE TREATMENT (PRE ADPERF - ACID 01/09/2002 PERF(ADD-PERF): PULL SSSV - DfT (PRE-CTU PERF) 01/22/2002 PERF(ADD-PERF): CAST IRON BRIDGE PLUG 01/23/2002 PERF(ADD-PERF): CAST IRON BRIDGE PLUG 01/24/2002 PERF(ADD-PERF): CAST IRON BRIDGE PLUG; PERFORATING 01/26/2002 PERF(ADD-PERF): CAST IRON BRIDGE PLUG 01/27/2002 PERF(ADD-PERF): PERFORATING 01/30/2002 PERF(ADD-PERF): INJECTION PROFILE 01/31/2002 PERF(ADD-PERF): INJECTION PROFILE 01/07/02 01/08/02 01/09/02 01/22/02 01/23/02 01/24/02 01/26/02 01/27/02 01/30/02 EVENT SUMMARY SCHMOO-B-GONE TUBING TREATMENT. 280 BBLS SCHMOO-B-GONE PUMPED, SWAP TO NEAT MEOH TO FREEZE PROTECT SURFACE LINES, PUMP 2 BBLS, SO. STANDBY FOR SBG TO SOAK. SCHMOO-B-GONE TREATMENT, FLUSH WITH SEAWATER. DRIFTED TO TOP OF SSSV W/4.511 GAUGE RING, PULL 5-1/2" BTDP-1 SSSV (# HVS-596) DRIFT TUBING INTO LINER WITH A 211 DUMMY GUN, 2.2511 CENTRALIZER AND SAMPLE BAILER TO 122251 SLM - ALL CLEAR. POOH. NO SAMPLE. RDMO. RELEASED FOR INJECTION @ 16:50 MIRU CTU #1. WELL SI UPON ARRIVAL, PAD OPERATOR FRZ PROTECTED FLOWLINE AND TBG. MU 1-11/16" PDS MEM LOGGING TOOLS, RIH. LOG DOWN FROM 129001 TO 134011 (PBTD) AT 30 FPM. FLAG PIPE AT 131501 CTD. POOH. SECURE WELL. GO ON WEATHER DELAY. MU BAKER 2-7/811 CIBP. BACK ON WEATHER DELAY. (1/25/02 - 24HRS WEATHER DELAY) (1/25/02 WEATHER) STAB BACK ON WELL, PT, RIH W/ BAKER 2-7/811 CIBP. SET AT 131901 MD. POOH. RIH W/GUN #1 (211 POWERJETS, 6 SPF). RIH W/GUN #1 (211 POWERJETS - 20l SHOOT 129201 - 129401. POOH. ALL SHOTS FIRED. SECURE WELL. STAND-BY ON WEATHER (-40 DEGF). BOP TEST, MU BAKER BHA & GUN #2 (201 2" PJ, 6 SPF), RIH. SHOOT 128701 - 128901, POOH. RIH W/GUN #3 (SAME CONFIGURATION AS GUN #2). RUNNING IN HOLE AT 9000. CTM AT END OF REPORT. DRIFT TO SSSV NIPPLE W/ 5 1/2 BRUSH AND 4.55 GAUGE RING. Page 1 01/31/02 BBLS 2 2 5 167 280 210 1351 ~. 03-16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS SET 5 1/2 BTDP-1 ( SER. HVS-1058 BALANCE OPERATED) @ 21351 SLM, ( ZERO TBG. PRESSURE) BALANCE LINE HOLDS 5000 PSI, AND Z-6 SPRING IN SET POSITION. RDMO / LEFT WELL SHUT-IN. FLUIDS PUMPED PRESSURE TEST LUBRICATOR W/ 1 BBL OF DIESEL (TWO TESTS). NEAT METHANOL WATER METHANOL WATER 60/40 METHANOL WATER SCHMOO-B-GONE SEAWATER TOTAL ADD PERFS 01/27 - 28/2002 THE FOLLOWING INTERVALS WERE PERFORATED USING THE 2" PJ 6SPF, 60 DEG PHASING, RANDOM ORIENTATION. 12850' - 12890. 12920' - 12940' Page 2 ~, ,..! _.j STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS .. 1. Operations performed: Operation shutdown - Pull tubing - Stimulate _X Alter casing - 5, Type of Well: 2, Name of Operator BP Exploration (Alaska), Inc. 3, Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Development- Exploratory - Stratigraph ic- Service_X 4027' FNL, 76' FEL, Sec. 10, T1 ON, R15E, UM At top of productive interval 4926' FNL, 1596' FEL, SEC. 09, T10N, R15E, UM At effective depth (asp's 713185, 5937286) (asp's 706416, 5936204) At total depth 2206' FNL, 1638' FEL, Sec. 9, T1 ON, R15E, UM 12. Present well condition summar Total depth: measured true vertical (asp's 706293, 5938919) 15311 feet 9005 feet Plugs (measured) Effective depth: Casing Conductor Surface Production Liner Liner Perforation depth: measu red 13360' - 13410'; (Isolated under CIBP's 13825' - 13900'; 14470' - 14550'; 15050' - 15090'; 15178' - 15278') true vertical Plugging - Pert orate _X Repair well- Other ~X (CIBP) 6, Datum elevation (DF or KB feet) RKB 64 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number RtltfVtLJ DEe 07 2000 03-16Ai AI~~ka Oil f{ r,~~ Gons. CommÍ!::!=:illn 9, Permit number / approval number Anchorage 197-033/300-271 (signed October 26,2000) 10, API number 50-029-20415-01 11, Field / Pool Prudhoe Bay Oil Pool CIBP set @ 13600' MD (11/23/2000) clap set @ 14100' MO (1/28/2000) clap set @ 14750' MO (3/0211998) True vertical Depth 73' 2725' 8554' 8860' 9005' 9058' - 9054'; (Isolated under CIBP's9043' - 9044'; 9045' - 9042'; 9013' - 9011'; 9008' - 9005') measured 13600 feet Junk (measured) true vertical 9045 feet Length Size Cemented Measured Depth 73' 20" 383 Sx AS 73' 2661' 13-3/8" 2100 Sx Fondu 2725' 11766' 9-5/8" 500 Sx Class G 11 830' 730' 7" 548 Sx Class G 12280' 3752' 2-7/8" 26 bbls Class G 15311' Tubing (size, grade, & measured depth) Packers and SSSV (type & measured depth) 5-1/2",17#, L-80Tbg @ 11489' MD; 5-1/2",17#, N-80Tbg @ 11523' MD; 4-1/2",12.6#, N-80, Tbg @ 11586' MD, 9-5/8" X 4-1/2" BAKER FHL PACKER @ 11533' MD; 9-518" X 5-1/2" TIW HBBP-T PACKER @ 11424' MD. 5-1/2" CAMCO BAL-O SSSV @ 2155' MD, 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Representative Daily Averaqe Production or Injection Data Gas-Mcf Water-Bbl 1076 3246 Oi -Bbl Subsequent to operation 15, Attachments Copies of Logs and Surveys run - Daily Report of Well Operations --.2( Oil - Gas - Suspended - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ ~ Title, OS 3 Surveillance Engineer Danlelle Ohms 16, Status of well classification as: Form 10-404 Rev 06/15/88. 0_\ rt~\) i¡.Î (~' r f\ I /\ ¡ ,,'I ¡ I" \. r~-.' , ~¿¡ ~¡ \L.~ Casing Pressure Tubing Pressure 1907 1896 Service WAG Date /¿- ¡; - 00 Prepared by Paul Raul 564-5799 '. ~ SUBMIT IN DUPLlCAT~ .,~,. . - ,.. ... - 03-16Ai DESCRIPTION OF WORK COMPLETED IMPLEMENTATION OF 4TH MI BULB SET CIBP / ADD PERFORATION / ACID STIMULATION TREATMENT Date Event Summary 11/07/2000: RIH & drifted to 12590' SLM (HAW). Pulled SSSV. 11/22/2000: MIRU CTU. PT'd equip to 4000 psi. RIH w/ CT & tagged PBTD @ 13876' MD. FCO'd to 14100' & POOH w/ CT. FP'd well. LDFN. 11/23/2000: RIH w/ Halliburton 2-7/8" CIBP. Set CIBP @ 13600' MD to isolate the open perforations located @: 13825' - 13900' MD (Zone 2B) Reference Log: MWD GR 4/1997. Note: 14470' - 14550', 15050' - 15090', & 15178' - 15278' perfs are isolated by previously installed Clap's @ 14100' & 14750'. Confirmed set. PT'd CIBP to 3000 psi -held. POOH. FP'd well. RD CTU. 11/30/2000 - MIRU CTU. BOPE tested. RIH w/ CT conveyed perforating guns & tagged CIBP. 12/01/2000: 13360' - 13410' M D (2B / 2C) Used 2" carriers and all shots @ 6 SPF, 60°/ phasing, random orientation, & underbalanced pressure. POOH w/ guns - ASF (except for gun #2 interval 13370' -13390' which had only half of the shots fired). LDFN. 12/02/2000: An CT Mud Acid Stimulation Treatment was performed as follows: PT'd stack. RIH w/ CT & pumped / reciprocated across the open perforations (listed above) the following fluids schedule: (a) 25 bbls filtered 3% 100°F NH4CL / Water @ 0.4 - 0.6 bpm, followed by (b) 102 bbls 7.5% HCI @ 0.3- 1.6 bpm, followed by (c) 53 bbls 9% HCI - 1 % HF @ 1.9 - 2 bpm, followed by (d) 150 bbls filtered 3% 100°F NH4CL / Water @ 1.7 bpm, followed by (e) shutdown. Performed injectivity test: 2 bpm @ 600 psi, 2.5 bpm @ 680 psi, 3.5 bpm @ 1600 psi, & 5 bpm @ 1700 psi. POOH w/ CT. FP'd well. RD CTU. 12/03/2000: Placed well BOL & began injecting produced water. Obtained representative injection data. RECEIVED DEC 07 2000 Alaska Oil & Gas Cons. Commissiolì Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1, Operations performed: Operation shutdown - Pull tubing - 2, Name of Operator ARCO Alaska, Inc. 3, Address P. O. Box 100360 Anchorage, AK 99510-0360 4, Location of well at surface 4027' FNL, 76' FEL, SEC. 10, T1 ON, R15E, UM At top of productive interval 4926' FNL, 1596' FEL, SEC. 09, T10N, R15E, UM At effective depth At total depth 2206' FNL, 1638' FEL, SEC. 09, T10N, R15E, UM 12, Present well condition summar Total depth: measured true vertical Effective depth: measured true vertical Length Size 73' 20" 2661' 13-3/8" 11766' 9-5/8" 730' 7' 3752' 2- 7/8" Casing Conductor Surface Production Liner Liner Perforation depth: Stimulate _X Alter casing - 5, Type of Well: Development- Exploratory- Stratigraphic- Service_X (asp's 713185, 5937286) (asp's 706416, 5936204) (asp's 706299, 5938910) 15311 feet 9005 feet Plugs (measured) Plugging - Perforate _X Repair well - Other _X (CIBP) 6. Datum elevation (OF or KB feet) RKB 64 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 03-16Ai 9. Permit number / approval number 1 97-033 10. API number 50-029-20415-01 11, Field / Pool Prudhoe Bay Oil Pool CIBP set @ 14750' MD (3/02/98) CIBP set @ 14100' MD (1/28/2000) OR\G\NAL Measured Depth 73' 2725' 11 830' 12280' 15311 ' True vertical Depth 73' 2725' 8554' 8860' 9005' 141 00 feet 9049 feet Junk (measured) measured 13825' - 13900'; (Isolated under CIBP's 14470' - 14550'; 15050' - 15090'; 15178' - 15278') Cemented 383 Sx AS 2100 Sx Fondu 500 Sx Class G 548 Sx Class G 26 bbls Class G true vertical 9043' - 9044'; (Isolated under CIBP's 9045' - 9042'; 9013' - 9011'; 9008' - 9005') Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 5,1/2' 17# L-80 Tbg@ 11489' MO; 5-1/2' 17# N-80 Tbg@ 11523' MO; 4-1/2' 12,6#, N-80 Tbg @ 11586' MOD TIW H BBP- T Packe' @ 11424' M D; Baker FH L Packe, @ 11533' M D; Cameo Ba~~t;; lXF. . , C~ 0 0 2000 Alaska Oil & Gas Cons. Commiaeion Anchor~e Representative Daily Averaqe Production or Injection Data Gas-Mcf Water-Bbl 7500 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Oil-Bbl Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations J Oil - Gas - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed -1~ Erin Oba r/7 ~ tr( 7\./' Form 10-404 Rev 06/15/88. 32000 16. Status of well classification as: Casing Pressure Tubing Pressure 1925 1831 Suspended - Service WAG Date ~..- f ~ Z ùOê) ¡...-- Title Arco Engineering Supervisor Prepared by Paul Rauf 263-4990 SUBMIT IN DUPLICATE Date 10/27/1999: 1/28/2000 - 1/29/2000: 2/14/2000: 2/15/2000: 2/29/2000: 3/02/2000: 03-16Ai DESCRIPTION OF WORK COMPLETED SET CIBP / ADD PERFORATION / MUD ACID STIMULATION TREATMENT Event Summary RIH wi CT & performed a FCO to 14525' MD. Pumped Schmoo-Be-Gone treatment. Injectivity 2 bpm @ 1200 psi. MIRU CTU & PT'd equip. Killed well. RIH & drifted to 14200' MD. Set 2-7/8" Cast Iron Bridge Plug @ 14100' to isolate the open perforations @: 14470' -14550' MD Note: 15050' - 15090' & 15178' - 15278' perfs isolated by clap @ 14750' MD. POOH wi setting tool. RIH wi perf guns & shot 75' of Add Perforations @: 13825' -13900' MD (Zone 2B) Reference Log: MWD GR on 4/2-13/1997. Used 211 carriers & all shots @ 4 SPF, random orientation, 1800 phasing. Injectivity test - 0.9 bpm @ 1800 psi WHP. POOH wi guns. ASF. RD. Attempted a FB Mud Acid Stimulation Treatment to increase injectivity as follows: MIRU. PT'd equip to 3600 psi. Pumped the treatment fluids fullbore through the open perforation interval listed above as follows: (a) 100 bbls 20/0 1 OO°F NH4CL I Water @ 2 bpm, followed by (b) 50 bbls Diesel I Xylene @ 0.7 - 0.9 bpm, followed by (c) 150 bbls 12% HCL wi 10% Xylene & 3% Acetic Acid @ 0.7- 1.15 bpm, followed by (d) 50 bbls 90/0 HCL - 1 % HF - 30/0 Acetic Acid @ 1.0 - 1.2 bpm, followed by (e) 23 bbls 12% HCL wi 100/0 Xylene & 3% Acetic Acid @ 0.6 bpm. WHP rose to 2300 psi when Diesel/Xylene hit perfs @ 23 bbls of DAD Acid away. Pumped 9 bbls of 60/40 MEOH Water, before well finally pressured up @ 4500 psi. RD pumping equipment & 81 well. Called out CTU. MIRU CTU & PT equip. RIH w/CT & circulated fluids from tubing and injected fluids down well 3-17i. RIH w/CT & circulated 200 bbls of 20/0 NH4CI Water down to the CIBP at 14100' MD. Jetted 31 bbls of 12% HCL -10% Xylene - 30/0 Acetic Acid across perfs, followed by 33 bbls of 2% NH4CI Water, followed by 60/40 MEOH Water. WHP broke back to below 1000 psi during fluids injection. POOH w/Cr. RD. MITOA to 2000 psi - passed. MITIA to 2500 psi - passed. Returned well to WAG injection & gathered representative injection data. Well is currently injecting MI. ,~~ , -- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown - Pull tubing - 2. Name of Operator ARGO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4027' FNL, 76' FEL, SEC. 10, T1 ON, R15E, UM At top of productive interval 353' FSL, 1596' FEL, SEC. 09, T1 ON, R15E, UM At effective depth At total depth 2206' FNL, 1638' FEL, SEC. 09, T10N, R15E, UM 12. Present well condition summar Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Production Uner Uner Length 73' 2661' 11766' 730' 3752' 7' 2-7/8H Size 20u 13-3/8" 9-5/8u Stimulate - Alter casing - 5. Type of Well: Development- Exploratory- Stratigraphic- Service_X 15311 feet 9005 feet Plugs (measured) Plugging - Perforate - Repair well - Other _X 6. Datum elevation (DF or KB feet) RKB 64 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 03-1 6Ai 9. Permit number / approval number 97 -033 10. API number 50-029-20415-01 11. Field / Pool Prudhoe Bay Oil Pool CIBP set @ 14750' MD (3/02/98) DUPLICATE Measured Depth 73' 2725' 11 830' 12280' 15311 ' True vertical Depth 73' 2725' 8554' 8860' 9005' 14750 feet 9028 feet Junk (measured) Perforation depth: measured 9608' - 9640', (open perfs isolated below CIBP: 15050' - 15090'; 15178' - 15278') Cemented 383 Sx AS 2100 Sx Fondu 500 Sx Class G 548 Sx Class G 26 bbls Class G true vertical 9045' - 9042'. (open perfs isolated below CIBP: 9013' - 9011'; 9008' - 9005') ',,~;"'i..:: .' .. '! Tubing (size, grade, and measured depth) 5-1/2' 17# L-80 Tbg@ 11489' MD; 5-1/2" 17# N-80 Tbg@ 11523' MD; 4-1/2' 12.6#, N-80 Tbg @'¡t~15å6r'MD. Packers & SSSV (type & measured depth) TIW HBBP-T Packer @ 11424' MD; Baker FHL Packer @ 11533' MD; Camco Bal-O SSSV @ 2155' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 2652 2042 14. Oil-Bbl Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations J Oil - Gas - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Þ- Erin Dba rv... ~ Form 10-404 Rev 06/15/88. Casing Pressure Tubing Pressure 1785 1831 16. Status of well classification as: Suspended - Service X Date 3-31-1' Title Arca Engineering Supervisor Prepared by Paul Rauf 263.4990 SUBMIT IN DUPLICATE ~. 03-16Ai DESCRIPTION OF WORK COMPLETED ACID STIMULATION TREATMENT Date Event Summary 12/23/1998: Performed a CT Acid Stimulation Treatment to increase injectivity as follows: MIRU CTU. PT'd BOPE. RIH wI CT to 14400' MD & pumped the following fluids schedule: (a) 20 bbls 12% HCL wI 100/0 Xylene, followed by (b) 10 bbls 9% HCL -1 % HF, followed by (c) 20 bbls 12% HCL wI 100/0 Xylene, followed by (d) 30 bbls 20/0 NH4CL water displacement, followed by (e) 35 bbls 60/40 MEOH Water. POOH wI CT & RDMOL. Returned well to WAG injection. -, ~ AOGCC Individual Well Geological Materials Inventory Ib /f)\l PERMIT DATA T DATA PLUS --------- ---------------- - ------------------------- 97-033 ~ERRY 12200-15311 MWD SRVY 97-033 ~ERRY 12200.-12900. MWD SRVY 97-033 Y8796-8941 ~12280-15311 /SPERRY GR/ROP ~PLETION DATE @ c-!¡/~ /17/ TO t1¡ lý f( 1 / NGP-TVD 97-033 NGP-MD 97-033 8070 10-407 DAILY WELL OPS R @ J /)c) /q 7 / Page: 1 Date: 04/07/99 T / RUN RECVD D BOX ----- -------- 05/14/97 OS/23/97 FINAL 08/13/97 FINAL 08/13/97 2-13 08/13/97 g r/Æ!:.!f7 / 9 )7,¿J/o/7/ Are dry ditch samples required? yes ~ Ar!~t received? ~fJ no -- c...? Was the well cored? yes ~alysis & description received? - yc~.-no- Are well tests required? }/yes Well is in compliance ~ Initial - ~R.@.ceived? ~S'-no COMMENTS --~ -.--.- ~ '" , -~ STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown - Pull tubing - 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 1249' FSL, 78' FEL, Sec 10, T10N, R15E, UM. At top of productive intelVal: 353' FSL, 1596' FEL, Sec 9, T10N, R15E, UM. At effective depth: At total depth: 2206' FNL, 1638' FEL, Sec 9, T10N, R15E, UM. 12. Present well condition summary Total Depth: measured 15311 feet true vertical 9005 feet Effective Depth: measured 14750 feet true vertical 9028 feet Casing Length Size Conductor 73' 20" Surface 2661' 13-3/8" Production 11766' 9-5/8" Liner 730' 7" Liner 3752' 2-718" Perforation Depth StimulateJ Alter casing - 5. Type of Well: Development - Exploratory - Stratagrapic - Service _X Plugs (measured) Junk (measured) Plugging - Perforate _X Repair well- Other - 6. Datum of elavation (OF or KB feet): 64' RKB 7. Unit or Property: Prudhoe Bay Unit 8. Well number: 3-16A 9. Permit number/approval number: 97 -033 10. API number: 50-029-20415-01 11. Field/Pool: Prudhoe Bay Oil Pool CIBP Set @ 14750' MD (312198). l'->~" , "-,, 1 ì\ l' ,\ f ¡ , j I 'ì , . \ Lj - ¡ ~1 I ;, ¡ ! ' . \ " ; 1 \. - ll~í<);~"Jr\.,-- Cemented Measured depth True vertical depth 383 Sx Arcticset 73' 73' 2100 Sx Fondu 2725' 2725' 500 Sx Class G 11830' 8554' 548 Sx Class G 12280' 8860' 26 bbls Class G 15311' 9005' measured 14470 -14550' [Open Perfs Isolated Below CIBP: 15050 -15090'; 15178 -15278'] true vertical 9045 - 9042' [Open Perfs Isolated Below CIBP: 9013 - 9011 '; 9008 - 9005'] Tubing (size, grade, and measured depth) 5-1/2",17#, L-80, Tbg @ 11489' MD; 5-1/2",17#, N-80, Tbg @ 11523' MD; 4-1/2",12.6#, N-80, Tbg @ 11586' MD. Packers and SSSV (type and measured depth) TIW HBBP-T Packer @ 11424' MD; Baker FHL Packer @ 11533' MD; Cameo Bal-O SSSV @ 2155' MD 13. Stimulation or cement squeeze summary IntelVals treated (measured) see attached IntelVals treated (measured) 14. REC[ IV ED JUL 24 1998 A1aska Oil ~" G::I~ eons. ClJIl\roj!;sion Oil-Bbl Representitive Daily Average Production or-Injection Data Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and SulVeys run - Daily Report of Well Operations _X Oil- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ 1'n ~ f.J.e7?\./ Title: Engineering Supervisor Form 10-404 Rev 06/15/88 Gas-Mcf Water-Bbl Casing Pressure 21373 16. Status of well classification as: 2586 Gas- Suspended - SelVice _X Date 7- 20 - '1)( SUBMIT IN DUPLICATE ~ 3-16A DESCRIPTION OF WORK COMPLETED ClBP INSTALLATION, CTU ADD PERFORATIONS, & ACID STIMULATION TREATMENT 3/2/98: MIRU CTU & PT equipment. perforation intervals at: RIH w/CIBP & set plug in the 2-7/8" liner at 14750' MD, to isolate the open 15050 - 15090' MD 15178- 15278' MD PT tubing to 3000 psi. Well failed MIT of Tbg & IA. RD. 3/3/98: RIH w/chemical cutter & cut the 5-1/2" tubing at 11480' MD. 3/6/98 - 3/12/98: Performed Rig Workover to pull & replace the tubing string above the tubing cut. (A separate 10-404 Report of Sundry of 4/15/98 reported these RWO operations). 4/2/98: MIRU CTU & PT equipment. Made runs w/CTC perforating guns & shot Add Perforations at: 14470- 14550' MD Used 1-11/16" carriers & shot all perfs at 4 spf at 0 degree phasing at balanced pressures. POOH w/guns & noted all but 3 shots fired on the gun runs. RD. 4/13/98: Performed a Fullbore Acid Stimulation Treatment to increase injectivity as follows: MIRU CTU & PT equipment. Loaded wellbore w/2% NH4CI Water, then RIH w/CT to CIBP. PU & reciprocated treatment fluids across the open perforation interval (above). Pumped: a) 50 bbls 50% Diesel - 50% Xylene @ 3.7 - 5 bpm, followed by b) 50 bbls 12% HCl w/10% Xylene, followed by c) 15 bbls Benzoic Acid Flakes Diverter Stage 1, followed by d) 50 bbls 12% HCl w/10% Xylene, followed by e) 18 bbls Benzoic Acid Flakes Diverter Stage 2, followed by f) 50 bbls 12% HCl w/10% Xylene, followed by g) 50 bbls 9% HCl- 1% HF @ 5.5 bpm, followed by h) 60 bbls 12% HCl w/10% Xylene, followed by i) 413 bbls 2% NH4Cl Water displacement, followed by j) Shutdown. Saw good injectivity response during treatment. POOH w/CT. RD. Placed well on miscible gas injection & obtained a valid injection rate. ...... STATE OF ALASKA ALASKA _IL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown []Stimulate [] Plugging [] Perforate I--]Pull Tubing [--]Alter Casing [~ Repair Well ~lOther 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1249' NSL, 78' WEL, SEC. 10, T10N, R15E, UM At top of productive interval 353' NSL, 1596' WEL, SEC. 09, T10N, R15E, UM At effective depth At total depth 2206' SNL, 1638' WEL, SEC. 09, T1 ON, R15E, UM t5. Type of well: [] Development [] Exploratory [] Stratigraphic [~ Service 6. Datum Elevation (DF or KB) 64' RKB 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 03-16Ai 9. Permit Number / Approval No. 97-033 398-048 10. APl Number 50-029-20415-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 15311 feet true vertical 9005 feet Effective depth: measured 15279 feet true vertical 9005 feet Casing Length Structural Conductor 73' Surface 2661' Intermediate Production 11766' Liner 730' Liner 3752' Plugs (measured) Junk (measured) ©?<iGiiIAL Size Cemented MD TVD 20" 383 sx Arcticset 73' 73' 13-3/8" 2100 sx Fondu 2725' 2725' 9-5/8" 500 sx Class 'G' 11830' 8554' 7" 548 sx Class 'G' 11550' - 12280' 8328' - 8860' 2-7/8" 127 sx Class 'G' 11559' - 15311' 8334' - 9005' Perforation depth: measured true vertical Sqzd: 12000'-12040', 12164'-12204', 12218'-12234', 12250'-12260', 12266'-12276' (Bridge Plug) Isolated: 15050'-15090', 15178'-15278' Sqzd: 8669'-8695', 8779'-8807', 8817'-8828', 8839'-8846', 8850'-8857' (Bridge Plug) lsol~ed: 9013'-9011',9008'-9005' Tubing(size, grade, and measured depth) 5-1/2",17#,L-80to 11489'; 5-1/2",17#, N-80 11480'-11523'; 4-1/2",12.6#, N-80 11523'-11586' Packers and SSSV (type and measured depth) TIW HBBP-T packer at 11424'; Baker FHL packer at 11533'; Camco BAL-O SSSV Nipple at 2155' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations I16. Status of well classifications as: [] Oil [] Gas [] Suspended Service Gas Injection 117. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed pa, Stone ~'- ~ ,~'~ Title Engineerin9 Supervisor Prepared By Name/Number: Date ~[IStR~ Terrie Hubble, 564-4628 ,~ ~ ~ ~)uplicate ~ Form 10-404 Rev. 06/15/88 STATE OF ALASKA ALASKA _ ,L AND GAS CONSERVATION COIv, MISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 t5. Type of well: [] Development [] Exploratory [] Stratigraphic [~:~] Service 4. Location of well at surface 1249' NSL, 78' WEL, SEC. 10, T10N, R15E, UM At top of productive interval 353' NSL, 1596' WEL, SEC. 09, T10N, R15E, UM At effective depth At total depth 2206' SNL, 1638' WEL, SEC. 09, T10N, R15E, UM 6. Datum Elevation (DF or KB) 64' RKB 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 03-16A 9. Permit Number 97 -033 10. APl Number 50-029-20415-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 15311 feet true vertical 9005 feet Effective depth: measured 15279 feet true vertical 9005 feet Casing Length Structural Conductor 73' Surface 2661' Intermediate Production 11766' Liner 730' Liner 3752' Plugs (measured) Junk (measured) ORIGINAL Size Cemented MD TVD 20" 383 sx Arcticset 73' 73' 13-3/8" 2100 sx Fondu 2725' 2725' 9-5/8" 500 sx Class 'G' 11830' 8554' 7" 548 sx Class 'G' 11550' - 12280' 8328' - 8860' 2-7/8" 127 sx Class 'G' 11559' - 15311' 8334' - 9005' Perforation depth: measured true vertical 12000'-12040', 12164'-12204', 12218'-12234', 12250'-12260', 12266'-12276', 15050'-15090', 15178'-15278' 8669'-8695', 8779'-8807', 8817'-8828', 8839'-8846', 8850'-8857', 9013'-9011', 9008'-9005' Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80 at 11523'; 4-1/2", 12.6#, N-80 at 11586' Packers and SSSV (type and measured depth) Baker FHL packer at 11533'; Otis RQM SSSV at 2179' 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch .... ~'" 14. Estimated date for commencing operation March 2, 1998 16. If proposal was verbally approved Name of approver Contact Engineer Name/Number: Winton Aubert, 564-4825 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Gas Injection Date approved Chris Brown, 564-5582 Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify tha~the foregoing is t~ue and correct to the best of my knowledge Signed ! " JamesSmithl/'~ ~'~ Title Engineering Supervisor // Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity_ Approved Cop~. Mechanical Integrity Test__ Returned pprOvea py el(der of the Commission Form 10-403 Rev. 06/15/88 I Approval N o.~',~.- BOP Test ,,"" Location clearance __ Subsequent form required 10- Original Sigr~,.~ _.~ David W_ Johnston Commissioner Date c)/~t¢/~ ~ Submlft In ~iplicate.,~:~ Db 3-16A RWO SUMMARY Objective This operation's objective is to cut and fish tubing above existing packer, test 9-5/8" casing to confirm integrity, and run new 5-1/2" tubing with custom overshot and stacked packer. Pre-Rig Procedure 1. RU slickline and pull SSSV. RD slickline. 2. RU WL unit with CCL and chemical cutter for 5-1/2", 17 #/ft tubing. 3. RIH and chemical cut 5-1/2" tubing @ 11,490' MD, in first full joint of 5-1/2" above PBR. POH, RD WL. 4. Have well head services test 9-5/8" packoff to 5000 psi. 5. If packoff tests to 5000 psi, perform CMIT on tubing and annulus to 4000 psi for 30 minutes. This test is required by the state for injection wells. 6. Release pressure on tubing and all annuli. Circulate clean sea water. Freeze protect well to 2200'. 0 psi is required on tubing and all annuli. 7. Set BPV. Remove wellhouse and flow lines, level pad, dig out cellar if necessary. Drilling Rig Procedure 1. MIRU Nabors 2ES. Obtain production handover form. Take on SW. 2. Circulate SW around tubing cut. Pull BPV. Install TWC. 3. ND tree and tubing head adapter. Send tree and hanger to DSM as soon as pos- sible for inspection and reuse (if timing permits). NU BOPE and test to 250 / 5000 psi. Test annular to 250 / 2500 psi. Pull TWC. Monitor well and ensure stability. Pull and LD tubing hanger and 5-1/2" tubing from above cut @ 11,490' MD. If necessary, replace 9-5/8" packoff and test to 5000 psi. If casing was not tested during pre-rig, PU RTTS. RIH to cut tubing depth and test 9-5/8" casing to 4000 psi for 30 minutes. POH, LD RTTS. Run 5-1/2" L-80 completion with Unique Machine custom overshot and 5-1/2" x 9- 5/8" packer. Make WL drift run through custom overshot to ensure access to perforations. . o , , , Well: 03-16A Spud_. Date: 02-24-80 Original RKBE: 64' Pop of Formation: 12152' Annular Fluid: Diesel/9.6 NaCl Reference Log: BHCS ARCr '~a~k.a., Inc. - Px%tdhoe Bay API %:50-029-20415-01 Completion:04-17-97 Hanger Type:FMC Max Hole Angle:59° @ MD: 9000' Date:03-24-80 Tie In:CNL Type:INJECTOR Status:Sidetrack Hanger:27' Angle @ TS:46° Angle @ TD:46° Date: 04-20-80 ALL DEPTHS ARE RKB DRILLING MD TO TOP OF EQUIPMENT EXCEPT WHERE NOTED. Jewelry ~pth. i 2179' 3 11~23 ' J-1 4 11533' 5 11559' 6 11563' 7 11584' 8 11585' 9 11586' 15311' t}490' 12 (,?) ._ __ Description 5-1/2' Otis RQM SSSV Nipple ID=4.562Z 5-1/2" Baker PBR Assembly Crossover. 5-1/2" x 4-1/2" 9-5/8, x 4-1/2' Baker FHL Packer 4-1/2" G Seal Sub ID=3' Crossover 3-1/2" x 2-7/8" ID=2.441" 4-1/2" Otis X Lauding Nipple (Be__h~n8 Liner) ID=-3.813' 4-1/2' W/L Re-entry Guide (Behind Liner) 4-1/2' Tubing Tail (Behind Liner) EI~ Tubing Tail (Logged 05/03/85) (Behind Liner) 2-7/8" TIW Float/Guide Shoe FISH: 118' Fired 2-1/8" Guns (Lost 04/15/97) J-2 Min ID: F~L/TIW CaSeS. J-3 ., J-5,6 J-7 J-8,9 .... :'" 2 C-2 3 P-1 Crossover 3-1/2" x 2-?/8" 1D=2.441" ' HBBP pkrs have reduced test pressure limits in some Contact ACE (x5102) prior to pressure testing. Casing and Tubing (C) Size' Weight Grade 13-3/8" 72% L-80 9-5/8" 47~ L-80 7" 29# L-80 7" Window @ 12280' 4 2-7/8' 6.5% L-80 5-1/2" 17# N-80 '4-1/2" 12.6# N-80 Top Bottom Description ';(:'~ .0'~'-:"-'2725'..~.- Casing 0' 11830' Casing 11550' 12280'. Liner 11563' 15311' Liner 0' 11523' Tubing-PC 11523'~ 11586' Tubing-PC C,~ 7' Window @ 1~';80' Perforation Data Interval Zone 12000-12040 SAG 12164-12204 4 12214-12218 4 12218-12234 4 12250-12260 4 12266-12276 4 15050-15090 2 15178-15278 2 FT SPF 40 6 ~ 40 0 1/2 4 0 16 0 1/4 10 4 1/2 10 2 1/2 40 4 100 4 ]~te -07-29-94'RPEI~FAPE~'l 's z 09-19-91 06-23-97 'APERF 04-15-97 J-11~12 0-4 Datum 8700' SS=12141, MD 8800' SS=12286' MD PBTD=15311' TD=-15311' Revision Date: 06-30-97 by ENH · Reason: APERF Previous Reason: 05-31-97 Well 03-16A CT Liner Set 04/17/97 ARCO Alaska Inc. Poat Office Box 10-0360 Anchorage, Aleska 99510-0360 Telephon~ (907) 276-1215 August 28, 1997 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3301 Porcupine Drive Anchorage, Alaska 99501-3192 Re' Recent MITIA on well 03-16i Deal' Mr. Wondzell' The attact~ed MIT document is provided for your review. This test was done following a changeoout of the SSSV, which appears to have repaired the limit.cd communication float was reported on 8/18/97. Per my couversation with Lou Gramaldi this well is now back on MI injection. If you require additional information m' clarification, please feel free to contact either Richard Ortiz or myself at (907) 659-5102. Very Truly Yours, D. D. Smith Problem Well Specialist STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical ~nt~jrity Test FELD ! UNIT ! PAD: DATE: 8/25/9 3.I6 COMMENTS: COMMENTS: COMMENTS: COMMENTS: 11~533 ,, CASIlt~ SlZE f WT I GRAD~ 9 [ I [s.s' 1 ~o~ PIqETT~T TBG CSG PRESS 480 2,5O0 15 MIN TIUE TBG CSG PRESS 4~ 2, 4~0 4~ 2,475 I i I 'l COMMENTS: 03-10 M~'T/'A completed t I J F TBG. INJ. FLUID CODES FRESH WATER INJ. GAS INJ. SALT WATER I NJ. NOT INJECTING c- Datal3~e c- Trip R'pl I=~z TEST'TYPE: M = ANNULUS MONFI"ORING P = STD AN NULU,S PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = 'I'ENIPERATL, JRE A~¥ TEST D = DIFFER ENTIAL TEMPERATURE TEST NewA~ MIT Form ANNULAR FLUID: P.P.G. Grad. I O. O0 DIESEL GLYCOL I o. oD SALT WATER L O, O0 DRILLING MUD i 0.00 OTHER i O. OO WELL TEST: Initial 4 - Year W~r~over Of:her AC)GCC REP S1GNATURF_: n ~! I Ll_l rtl G S~l~/IC~ s To,' __ WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. _ Anchorage, Alaska 99501 MWD Formation Evaluation Logs - D.S. 03-16A, August 13, 1997 AK-MW-70090 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#: 50-029-20415-01. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company OF:llL. I--ING SEI~IL~I C E S WELL LOG TRANSMITTAL To: State of Alaska - August 13, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs DS 03-16A, AK-MW-70090 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Yah Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS 03-16A: 2"x 5"MD Gamma Ray Logs: 50-029-20415-01 2" x 5" TVD Gamma Ray Logs: 50-029-20415-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 ° (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company STATE OF ALASKA AL,.,$KA OIL AND GAS CONSERVATION COMMISSION' REPORT OF SUNDRY WELL OPERATIONS , 1. Operations performed: Operation Shutdown _ Stimulate X Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other 2. Name of Operator: 5. Type of Well: 6. Datum of elevation (DF or KB feet): ARCO Alaska, Inc. Development_ 64' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic Anchorage, AK 99510-0360 Service _x Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 1249' FSL, 78' FEL, Sec 10, T10N, R15E, UM. 3-16A At top of productive interval: 9. Permit number/approval number: 353' FSL, 1596' FEL, Sec 9, T10N, R15E, UM. 97-033 At effective depth: 10. APl number: 50-029-20415-01 At total depth: 11. Field/Pool: 2206' FNL, 1638' FEL, Sec 9, T10N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 15311 feet Plugs (measured) true vertical 9005 feet ORIGINAL Effective Depth: measured 15279 feet Junk (measured) true vertical 9005 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 73' 2¢ 383 Sx Arcticset 73' 73' Surface 2661' 13-3/8" 2100 Sx Fondu 2725' 2725' Production 11766' 9-5/8" 500 Sx Class G 11830' 8554' Liner 730' 7" 548 Sx Class G 12280' 8860' Liner 3752' 2-7/8" 26 bbls Class G 15311' 9005' Perforation Depth measured 12000 - 12040'; 12164 - 12204'; 12218- 12234'; 12250- 12260'; 12266 - 12276'; 15050- 15090'; 15178- 15278' true vertical 8669 - 8695'; 8779 - 8807'; 8817 - 8828'; 8839 - 8846'; 8850 - 8857'; 9013 - 9011 '; Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80, PCT @ 11523' MD; 4-1/2", 12.6#, N-80, PCT @ 11586' MD. -~,.,.~k:', ()il & Gas C~r~s. "-"" "' Packers and SSSV (type and measured depth) Baker FHL Packer @ 11533' MD; Otis RQM SSSV @ 2179' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached Intervals treated (measured) 4. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 18313 - 2912 Subsequent to operation 26790 - 2639 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ X Oil_ Gas _ Suspended Service X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~.,~..__. "~ · ~ Title: Engineering Supervisor Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICAte.,, 3-16A DESCRIPTION OF WORK COMPLETED CTU ADD PERFORATIONS & ACID STIMULATION TREATMENT 6/23~97: MIRU CTU & PT equipment. MU & RIH w/CT mounted perforation guns & added 40' of perforations at: 15050- 15090' MD (Z2) Used 2-1/8" carriers & shot the perfs at 4 spf at zero degree phasing. POOH w/guns. Noted ASF. RD. 713197: Performed a Fullbore Acid Stimulation Treatment as follows: MIRU & PT equipment to 5000 psi. Pumped stimulation fluid sequence fullbore to treat the open perforation intervals located at: 12000 - 12040' MD (Sag) 12164- 12204' MD (Z4) 12218- 12234' MD (Z4) 12250- 12260' MD (Z4) 12266- 12276' MD (Z4) 15050- 15090' MD (Z2) 15178- 15278' MD (Z2) Pumped: a) 100 bbls 2% NH4CI Water @ 5.5 bpm, followed by b) 50 bbls 12% HCI w/10% Xylene @ 5.5 bpm, followed by c) 10 bbls Benzoic Acid Flake Diverter stage 1, followed by d) 50 bbls 12% HCI w/10% Xylene @ 5.5 bpm, followed by e) 10 bbls Benzoic Acid Flake Diverter stage 2, followed by f) 50 bbls 12% HCI w/10% Xylene @ 5.2 bpm, followed by g) 50 bbls 9% HCI - 1% HF @ 5.8 bpm, followed by h) 50 bbls 12% HCI w/10% Xylene @ 5.8 bpm, followed by i) 450 bbls 2% NH4CI Water displacement, followed by j) 10 bbls Methanol, followed by k) Shutdown. RDMO. Placed the well on miscible injection & obtained a valid injection rate. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well Oil ~ Gas Suspended Abandoned__ Service_X Injector 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 97-033 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-20415-01 4 Location of well at surface ~ ...... "" ,. ~ '' ~ ...... J . .-:'r:..,; ! ~ 9 Unit or Lease Name At Top Producing interval ~!") 10 Well Number 3-16A At T ota1353'DepthFSL' 1596' FEL, Sec 9, T10N, R15E, UM. ~ ~~.~.V!~!F[~;) ..... !i 2206' FNL, 1638' FEL, Sec 9, T10N, R15E, UM'?~ ....... ' .... .~ ...... ; '"-- ~ ...- ..... PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. 64' RKB ADL 28328 PRUDHOE BAY OIL POOL ~12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp., or Aband. 15 Water Depth, if offshore 16 No. of Completions 4/1/97 4/12/97 4/16/97 N/A 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 D_epth where SSSV set 21 Thickness of Permafrost 15311' MD / 9005' TVD 15279' MD / 9005' TVD YES_X NO__ 2179' feet MD 1900' feet (approx) 22 Type Electric or Other Logs Run MWD, GR. 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMT PULLED 20" 94# H-40 Surf 73' 30" 383 Sx Arctic Set 13-3/8" 72# L-80 Surf 2725' 17.5" 2100 Sx Fondu 9-5/8" 47# L-80/S-95 Surf 11830' 12.25" 500 Sx Class G 7" 29# L-80 11550' 12280' 8.5" 548 Sx Class G 2-7/8" 6.5# FL4S 11559' 15311' 3.75" 26 bbls Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and ' 125 TUBING RECORD interval, size and number) SIZE DEPTH SET MD PACKER MD 5-1/2" Tbg 11523' 11533' 15178 - 15278' MD; 9008- 9005' TVD; at 4 spf. 4-1/2" Tbg 11586' - 4-1/2" Tbg 12340 - 12356' - 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMT & KIND MATERIAL USED 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 4/22/97 (On Injection) Miscible Gas Injection Date of Test Hours Tested INJECTION FOR OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE I GOR I 4/24/97 (Injection Rate) TEST PERIOD_24 hrs 27259 Flow Tubing Press Casing Pressure CALCULATED OIL - BBL GAS - MCF WATER - BBL OIL GRAVITY - APl (con') 24 HOUR RATE __ - ' 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water. Submit core chips. * This 10-407 submitted as directed per the 10-401 form approved 3/14/97 (issued Permit # 97-033). ?-- 5 1997 ORIGINAL '- Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, and fluids recovered and gravity, MEAS DEPTH TRUE VERT DEPTH GOR, and time of each phase. Top Sadlerochit 12151' 8769' N/A 31 LIST OF ATTACHMENTS Summary of 3-16A Coil Tubing Sidetrack Drilling Operations. 321 hereby cedify that the foregoing is true and correct to the best of my knowledge Signed _~'~._, '~'1- ~ Engineering Supervisor Date ~-- Z,~ _ ~ 7 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases. 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 5: 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 Facility PB DS 03 Progress Report Well 03-16A Rig Nabors 2ES Page Date 1 15 April 98 Date/Time 05 Mar 98 06 Mar 98 07 Mar 98 08 Mar 98 09 Mar 98 06:00-12:00 12:00-12:30 12:30-17:00 17:00-19:30 19:30-20:00 20:00-00:00 00:00-00:30 00:30-02:00 02:00-04:30 04:30-06:00 06:00-07:30 07:30-10:00 10:00-10:30 10:30-11:30 11:30-14:30 14:30-15:30 15:30-17:00 17:00-18:00 18:00-19:00 19:00-21:00 21:00-22:00 22:00-23:00 23:00-00:00 00:00-00:30 00:30-03:30 03:30-04:00 04:00-06:00 06:00-11:00 11:00-12:00 12:00-12:30 12:30-13:00 13:00-17:30 17:30-19:00 19:00-21:30 21:30-21:45 21:45-00:00 00:00-00:30 00:30-01:30 01:30-03:00 03:00-05:30 05:30-06:00 06:00-06:30 06:30-10:30 10:30-11:00 11:00-11:30 11:30-12:00 12:00-12:30 12:30-15:30 15:30-18:00 18:00-21:30 21:30-21:45 21:45-22:00 22:00-03:30 03:30-04:00 Duration 6hr 1/2hr 4-1/2 hr 2-1/2 hr 1/2 hr 4hr 1/2hr 1-1/2 hr 2-1/2 hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 1/2 hr lhr 3hr lhr 1-1/2 hr lhr lhr 2hr lhr lhr lhr 1/2 hr 3hr 1/2 hr 2hr 5hr lhr 1/2 hr 1/2 hr 4-1/2 hr 1-1/2 hr 2-1/2 hr 1/4 hr 2-1/4 hr 1/2 hr lhr 1-1/2 hr 2-1/2 hr 1/2hr 1/2 hr 4hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 3hr 2-1/2 hr 3-1/2 hr 1/4 hr 1/4 hr 5-1/2 hr 1/2 hr Activity Rig moved 90.00 % Held safety meeting Rig moved 100.00 % Fill pits with Brine Held safety meeting Circulated at 11480.0 ft Held safety meeting Circulated at 11480.0 ft Removed Surface tree Installed BOP stack Installed BOP stack (cont...) Tested BOP stack Held safety meeting Tested Kelly/top drive hose Tested BOP stack Made up BHA no. 1 Fished at 25.0 ft Circulated at 11480.0 ft Pulled BHA Installed BOP test plug assembly Tested Pipe ram Retrieved BOP test plug assembly Laid down 400.0 ft of Tubing Held safety meeting Laid down 1600.0 ft of Tubing Installed Tubing handling equipment Laid down Tubing of 2000.0 ft Laid down 9500.0 ft of Tubing (cont...) Rigged up Drillstring handling equipment Held safety meeting Made up BHA no. 2 Singled in drill pipe to 5000.0 ft Tested Casing - Via annulus and string Singled in drill pipe to 11480.0 ft Held drill (Kick while tripping) Singled in drill pipe to 11000.0 ft Held safety meeting Singled in drill pipe to 11460.0 ft Tested Casing - Via annulus and string Circulated at 11460.0 ft Serviced Block line Serviced Block line (cont...) Pulled out of hole to 0.0 ft Pulled BI--IA Made up BHA no. 3 R.I.H. to 500.0 ft Held safety meeting R.I.H. to 11460.0 ft Circulated at 11460.0 ft Laid down 3400.0 ft of 3-1/2in OD drill pipe Held drill (Kick while tripping) Worked toolstring at 8050.0 ft Pulled out of hole to 100.0 ft Pulled BHA Facility PB DS 03 Progress Report Well 03-16A Page 2 Rig Nabors 2ES Date 15 April 98 Date/Time 10 Mar 98 11 Mar 98 04:00-05:30 05:30-06:00 06:00-12:00 12:00-12:30 12:30-17:30 17:30-18:00 18:00-22:30 22:30-00:00 00:00-00:30 00:30-03:30 03:30-05:30 05:30-06:00 06:00-08:30 08:30-10:30 10:30-12:00 12:00-12:30 12:30-13:30 13:30-15:30 15:30-18:30 18:30-21:00 21:00-22:00 22:00-00:00 00:00-00:30 00:30-02:00 02:00-03:00 03:00-05:00 05:00-06:00 06:00-06:30 06:30-08:30 08:30-11:00 11:00-12:00 12:00-12:30 12:30-14:00 14:00-16:30 16:30-17:30 17:30-21:00 Duration 1-1/2 hr 1/2 hr 6hr 1/2 hr 5hr 1/2 hr 4-1/2 hr 1-1/2 hr 1/2 hr 3hr 2hr 1/2hr 2-1/2 hr 2hr 1-1/2 hr 1/2 hr lhr 2hr 3hr 2-1/2 hr lhr 2hr 1/2 hr 1-1/2 hr lhr 2hr lhr 1/2 hr 2hr 2-1/2 hr lhr 1/2 hr 1-1/2 hr 2-1/2 hr lhr 3-1/2 hr Activity Rigged up Tubing handling equipment Held safety meeting Ran Tubing to 4100.0 ft (5-1/2in OD) Held safety meeting Ran Tubing to 9335.0 ft (5-1/2in OD) Installed SCSSSV Ran Tubing to 11400.0 ft (5-1/2in OD) Space out tubulars Held safety meeting Installed SCSSSV control line Installed Emergency hang off assembly Removed Seal assembly Removed Seal assembly (cont...) Installed Seal assembly Removed Emergency hang off assembly Held safety meeting Installed SCSSSV control line Installed Tubing hanger Ran Tubing to 11489.0 ft (5-1/2in OD) Reverse circulated at 11489.0 ft unit operations on Slickline equipment - Tool run Rigged up Slickline Conducted slickline Held safety meeting Conducted slickline Conducted slickline Conducted slickline Conducted slickline operations on Slickline equipment - Setting run operations on Slickline equipment - Retrival run operations on Slickline equipment - Setting run operations on Slickline equipment - Setting run Conducted slickline operations on Slickline equipment - Setting run (con Freeze protect well - 147.000 bbl of Diesel Set packer at 11424.0 ft with 4000.0 psi Removed BOP stack Held safety meeting Rigged down BOP stack Rigged up Surface tree Tested Surface tree Rig moved 10.00 % ...) 3-16A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING 3/30/97: RIH w/drilling BHA & tagged cement top at approximately 11600' MD, then drilled pilot hole to 11783' MD. 3/31/97: Continued drilling pilot hole to 12247' MD. POOH w/BHA. RIH w/drilling BHA. then continued drilling pilot hole to 12280' MD. POOH w/BHA. Swapped well to water, 4/1/97: RIH w/window milling BHA. Milled window from 12280' to 12284' MD, then continued drilling formation to 12290' MD. Backreamed window & POOH w/BHA. 4/2/97: RIH w/drilling BHA & displaced well to FIo Pro. Performed formation leakoff test w/350 psi on mud column; held w/no loss. Drilled 3.75" build section to 12564' MD. POOH w/BHA. 4/3/97: RI H w/drilling BHA. Drilled conglomerates to 12707' MD. drilling build to 12740' MD. POOH w/BHA. RIH w/drilling BHA & resumed 4/4/97: Completed drilling build section to 13000' MD. POOH w/BHA. Performed rig maintenance & PT BOPS. 4/5/97: RIH w/drilling BHA. Drilled horizontally from 13000' to 13350' MD. new FIo Pro. RIH & drilled to 13543' MD. Made sweep to window. Swept hole to 12300' & swapped in 4/6/97: RIH & drilled to 13825' MD. POOH w/BHA. RIH w/drilling BHA & resumed drilling to 13965' MD. 4/'7/97: Drilled to 14076' MD. POOH w/BHA. RIH w/drilling BHA. Drilled 14241' MD. POOH w/BHA. 4/8/97: Drilled to 14430' MD. 4/9/97: Drilled to 14506' MD. POOH w/BHA. POOH w/BHA. RIH w/drilling BHA. RIH w/drilling BHA. Drilled to 14603' MD. 4/10~97: Drilled to 14638' MD. RIH w/drilling BHA. POOH w/BHA. RIH w/drilling BHA. Drilled to 14660' MD. POOH w/BHA. 4/11/97: Drilled to 14789' MD. Circulated in new FIo Pro & continued drilling to 15140' MD. Swept to window. 4/12/97: Drilled to TD at 15311' MD. Spotted lubetex pill from TD to window & POOH w/BHA. MU liner assembly. 4/13/97: RIH w/2-7/8" blank liner assembly & landed liner on bottom at 15311' MD. Mixed cement. 3-16A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING 4/14/97: Pumped 26 bbls of Class G cement to set the 2-7/8" liner from 11559' to 15311' MD. Water from 11000' to surface. Washed through liner w/KCl Water, then POOH. PT BOPS. 4/15/97: MU & RIH w/perforation guns. Shot initial perforations at: 15178 - 15278' MD Used a 2-1/8" carrier & shot the perfs at 4 spf. 4/16/97: RIH & FP top 2000' w/Meth Water. Set BPV. Displaced well w/KCI Guns stuck on bottom. Disconnected from guns. POOH. ND BOPS. NU & PT tree. RD & released CTU. Placed the well on miscible injection & obtained a valid injection rate. SI RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. PBU / 3-16A 500292041501 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 9/97 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 12200.00 8804.30 8740.30 12280.00 8859.72 8795.72 12282.00 8861.11 8797.11 12327.80 8890.04 8826.04 12384.12 8919.88 8855.88 COURS INCLN DG MN 46 30 45 47 46 10 55 35 60 31 DATE OF SURVEY: 041397 MWD SURVEY JOB NUMBER: AK-MW-70090 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. N 87.80 W .00 N 87.20 W 1.03 N 86.60 W 28.43 N 74.00 W 29.59 N 63.72 W 17.78 894.00S 6833.50W 891.49S 6891.14W 891.41S 6892.57W 885.19S 6927.39W 867.89S 6971.82W 6377.05 6433.41 6434.82 6470.07 6517.45 12407.37 8931.25 8867.25 12435.97 8944.64 8880.64 12470.37 8959.44 8895.44 12500.07 8970.87 8906.87 12529.62 8981.11 8917.11 6O 54 63 18 65 44 68 59 70 29 N 61.67 W 7.86 N 55.88 W 19.76 N 52.71 W 10.91 N 47.96 W 18.37 N 44.97 W 10.76 858.59S 6989.84W 845.48S 7011.43W 827.35S 7036.64W 809.85S 7057.72W 790.76S 7077.81W 6537.25 6561.48 6590.48 6615.34 6639.65 12572.13 8994.63 8930.63 12591.38 9000.18 8936.18 12625.08 9008.70 8944.70 12649.78 9014.17 8950.17 12680.26 9020.60 8956.60 72 30 74 0 76 43 77 41 77 57 N 33.55 W 25.91 N 29.86 W 19.92 N 25.11 W 15.86 N 19.84 W 21.17 N 15.09 W 15.26 759.59S 7103.25W 743.91S 7112.94W 714.99S 7127.97W 692.74S 7137.17W 664.33S 7146.11W 6672.22 6685.60 6707.53 6722.12 6738.03 12714.89 9028.13 8964.13 12741.17 9034.13 8970.13 12799.32 9048.13 8984.13 12830.32 9055.93 8991.93 12858.37 9062.73 8998.73 76 54 76 43 75 24 75 30 76 27 N 14.74 W 3.22 N 11.40 W 12.39 N 7.53 W 6.85 N .15 W 23.04 N 1.78 E 7.50 631.67S 7154.81W 606.75S 7160.60W 551.09S 7169.88W 521.18S 7171.89W 493.97S 7171.50W 6754.80 6766.78 6790.00 6799.59 6806.18 12894.02 9070.03 9006.03 12921.32 9074.13 9010.13 12949.84 9076.98 9012.98 12988.12 9078.36 9014.36 13009.07 9078.10 9014.10 79 53 N 6.00 E 15.06 82 50 N 10.59 E 19.84 85 41 N 9.17 E 11.12 90 10 N 10.40 E 12.16 91 13 N 14.26 E 19.09 459.17S 7169.13W 432.48S 7165.23W 404.52S 7160.36W 366.83S 7153.86W 346.37S 7149.39W 6812.79 6815.86 6818.31 6821.67 6822.58 13045.72 9076.95 9012.95 13076.92 9075.44 9011.44 13103.77 9074.03 9010.03 13128.12 9072.79 9008.79 13190.72 9069.24 9005.24 92 22 N 15.14 E 3.93 93 9 N 15.67 E 3.05 92 54 N 15.32 E 1.62 92 54 N 16.90 E 6.48 93 35 N 20.94 E 6.54 310.94S 7140.09W 280.90S 7131.82W 255.06S 7124.65W 231.70S 7117.91W 172.59S 7097.65W 6822.67 6822.35 6822.04 6821.50 6817.04 13225.09 9067.06 9003.06 13255.09 9065.19 9001.19 13283.79 9063.39 8999.39 13311.22 9061.62 8997.62 13349.67 9059.12 8995.12 93 41 N 21.65 E 2.08 93 25 N 21.82 E 1.03 93 46 N 23.06 E 4.48 93 35 N 23.76 E 2.63 93 52 N 25.87 E 5.52 140.63S 7085.19W 112.82S 7074.10W 86.35S 7063.17W 61.23S 7052.29W 26.41S 7036.19W 6813.18 6809.58 6805.79 6801.71 6795.05 ARCO ALASKA INC. PBU / 3-16A 500292041501 NORTH SLOPE BOROUGH COMPUTATION DATE: 5 SP' -IY-SUN DRILLING SERVICES ANCHORAGE ALASKA / 9/97 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN 13387.32 9055.98 8991.98 95 42 13399.64 9054.68 8990.68 96 19 13429.47 9051.42 8987.42 96 14 13472.69 9047.44 8983.44 94 18 13497.62 9045.90 8981.90 92 48 13522.44 9045.15 8981.15 90 37 13563.02 9044.84 8980.84 90 15 13593.54 9044.70 8980.70 90 15 13625.97 9044.45 8980.45 90 37 13661.29 9043.91 8979.91 91 8 13701.54 9043.51 8979.51 90 0 13733.82 9043.71 8979.71 89 18 13770.14 9043.90 8979.90 90 5 13797.62 9043.65 8979.65 90 58 13839.52 9043.20 8979.20 90 15 13858.37 9043.27 8979.27 89 19 13879.14 9043.69 8979.69 88 19 13920.22 9045.08 8981.08 87 48 13949.27 9046.13 8982.13 88 4 13980.52 9046.84 8982.84 89 18 14025.32 9047.54 8983.54 88 55 14038.42 9047.85 8983.85 88 19 14062.29 9048.38 8984.38 89 7 14097.82 9049.04 8985.04 88 46 14134.57 9050.31 8986.31 87 16 PAGE 14165.47 9051.82 8987.82 87 5 14186.89 9052.82 8988.82 87 33 14226.97 9054.17 8990.17 88 35 14259.09 9054.83 8990.83 89 1 14286.29 9055.00 8991.00 90 15 DATE OF SURVEY: 041397 MWD SURVEY JOB NUMBER: AK-MW-70090 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC 14318.42 9054.17 8990.17 92 43 14340.84 9052.91 8988.91 93 41 14369.04 9051.27 8987.27 92 59 14399.52 9049.45 8985.45 93 52 14428.67 9047.41 8983.41 94 7 COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. N 25.87 E 4.89 7.35N 7019.82W 6787.87 N 26.04 E 5.22 18.36N 7014.46W 6785.51 N 23.06 E 9.93 45.33N 7002.14W 6780.50 N 25.52 E 7.22 84.55N 6984.44W 6773.43 N 25.16 E 6.19 107.04N 6973.79W 6768.89 N 24.28 E 9.51 129.57N 6963.42W 6764.63 N 26.22 E 4.86 166.26N 6946.11W 6757.29 N 24.64 E 5.18 193.82N 6933.01W 6751.68 N 23.93 E 2.45 223.38N 6919.67W 6746.35 N 24.11 E 1.56 255.64N 6905.30W 6740.71 N 24.46 E 2.96 292.33N 6888.75W 6734.10 N 23.41 E 3.91 321.83N 6875.65W 6728.99 N 23.93 E 2.60 355.09N 6861.07W 6723.41 N 25.52 E 6.61 380.05N 6849.58W 6718.69 N 26.22 E 2.38 417.74N 6831.30W 6710.67 N 24.68 E 9.57 434.76N 6823.20W 6707.19 N 23.79 E 6.41 453.70N 6814.67W 6703.80 N 22.70 E 2.95 491.42N 6798.47W 6697.79 N 21.65 E 3.73 518.30N 6787.51W 6694.08 N 21.47 E 3.98 547.35N 6776.03W 6690.42 N 17.40 E 9.12 589.59N 6761.13W 6686.82 N 16.90 E 5.90 602.10N 6757.27W 6686.29 N 16.55 E 3.62 624.96N 6750.40W 6685.50 N 16.02 E 1.79 659.05N 6740.44W 6684.60 N 13.21 E 8.65 694.59N 6731.18W 6684.74 N 10.75 E 7.97 724.77N 6724.77W 6686.27 N 14.52 E 17.71 745.65N 6720.09W 6687.09 N 14.79 E 2.66 784.40N 6709.96W 6687.21 N 13.56 E 4.07 815.53N 6702.09W 6687.58 N 11.98 E 7.36 842.06N 6696.08W 6688.56 N 12.86 E 8.13 873.42N 6689.18W 6689.91 N 11.28 E 8.26 895.31N 6684.50W 6690.99 N 10.22 E 4.50 922.96N 6679.25W 6692.99 N 8.11 E 7.49 952.99N 6674.40W 6695.99 N 7.41 E 2.56 981.81N 6670.47W 6699.57 St- ~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA INC. PBU / 3-16A 500292041501 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 9/97 DATE OF SURVEY: 041397 MWD SURVEY JOB NUMBER: AK-MW-70090 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 14465.39 9045.10 8981.10 93 4 14487.59 9044.07 8980.07 92 16 14528.54 9042.46 8978.46 92 11 14558.79 9041.39 8977.39 91 51 14589.77 9040.06 8976.06 93 3 N 4.60 E 8.15 1018.25N 6666.64W N 4.07 E 4.32 1040.36N 6664.96W N 2.31 E 4.30 1081.21N 6662.69W N 1.88 E 1.81 1111.42N 6661.58W N 1.22 E 4.42 1142.36N 6660.75W 6705.19 6709.23 6717.49 6724.15 6731.26 14615.59 9038.54 8974.54 93 41 14641.57 9036.93 8972.93 93 25 14665.87 9035.22 8971.22 94 39 14705.04 9031.61 8967.61 95 53 14735.29 9029.06 8965.06 93 46 N .15 W 5.83 1168.13N 6660.50W N .91 E 4.19 1194.06N 6660.33W N .38 E 5.51 1218.30N 6660.06W N 5.07 W 14.21 1257.25N 6661.65W N 6.83 W 9.07 1287.23N 6664.78W 6737.63 6744.10 6750.04 6761.55 6772.24 14773.92 9026.31 8962.31 94 23 14800.57 9024.72 8960.72 92 27 14826.39 9023.87 8959.87 91 19 14859.39 9022.78 8958.78 92 27 14883.59 9021.44 8957.44 93 52 N 5.95 W 2.77 1325.52N 6669.07W N 6.48 W 7.51 1351.96N 6671.95W N 10.17 W 14.95 1377.49N 6675.68W N 10.34 W 3.49 1409.94N 6681.55W N 9.29 W 7.26 1433.75N 6685.67W 6786.19 6795.74 6805.88 6819.87 6829.94 14918.22 9019.34 8955.34 93 4 N 12.63 W 9.89 1467.68N 6692.24W 14944.69 9017.96 8953.96 92 54 N 12.28 W 1.49 1493.49N 6697.94W 14976.29 9016.36 8952.36 92 54 N 15.27 W 9.45 1524.14N 6705.46W 14999.22 9015.22 8951.22 92 48 N 16.14 W 3.81 1546.19N 6711.66W 15026.42 9013.91 8949.91 92 43 N 18.08 W 7.13 1572.15N 6719.65W 6844.98 6857.10 6872.20 6883.84 6898.21 15059.32 9012.52 8948.52 92 6 N 18.25 W 1.92 1603.38N 6729.90W 15087.47 9011.48 8947.48 92 7 N 20.59 W 8.31 1629.91N 6739.25W 15136.52 9009.56 8945.56 92 22 N 22.65 W 4.23 1675.46N 6757.30W 15150.49 9009.09 8945.09 91 24 N 25.99 W 24.86 1688.18N 6763.05W 15184.77 9008.10 8944.10 91 55 N 27.04 W 3.42 1718.84N 6778.35W 6916.11 6931.94 6961.05 6969.87 6992.50 15217.59 9007.09 8943.09 91 34 N 29.15 W 6.51 1747.78N 6793.79W 15239.87 9006.39 8942.39 92 1 N 33.72 W 20.60 1766.77N 6805.41W 15272.12 9005.35 8941.35 91 40 N 31.26 W 7.70 1793.96N 6822.72W 15290.37 9005.00 8941.00 90 31 N 32.84 W 10.67 1809.42N 6832.40W 15311.00 9005.04 8941.04 89 14 N 34.50 W 10.19 1826.59N 6843.83W 7014.84 7030.92 7054.61 7067.93 7083.38 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 7083.39 FEET AT NORTH 75 DEG. 3 MIN. WEST AT MD = 15311 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 284.83 DEG. TIE-IN SURVEY AT 12,200.00' MD WINDOW POINT AT 12,282.00' MD PROJECTED SURVEY AT 15,311.00' MD St RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. PBU / 3-16A 500292041501 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 9/97 DATE OF SURVEY: 041397 JOB NUMBER: AK-MW-70090 KELLY BUSHING ELEV. = 64.00 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 12200.00 8804.30 8740.30 894.00 S 6833.50 W 3395.70 13200.00 9068.66 9004.66 163.94 S 7094.33 W 4131.34 735.64 14200.00 9053.38 8989.38 758.33 N 6716.81 W 5146.62 1015.28 15200.00 9007.58 8943.58 1732.40 N 6785.27 W 6192.42 1045.79 15311.00 9005.04 8941.04 1826.59 N 6843.83 W 6305.96 113.54 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. S! '.RY-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE ARCO ALASKA INC. PBU / 3-16A 500292041501 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 9/97 DATE OF SURVEY: 041397 JOB NUMBER: AK-MW-70090 KELLY BUSHING ELEV. = 64.00 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 12200.00 8804.30 8740.30 894.00 S 6833.50 W 3395.70 12286.36 8864.00 8800.00 891.00 S 6895.82 W 3422.36 26.66 12481.82 8964.00 8900.00 820.82 S 7044.86 W 3517.82 95.46 12864.16 9064.00 9000.00 488.33 S 7171.22 W 3800.16 282.33 12900.00 9071.05 9007.05 453.32 S 7168.46 W 3828.95 28.79 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS May 12, 1997 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data 3-16A Dear Ms. Taylor: Enclosed are two hard copies of the above mentioned file(s). Well 3-16A MWD survey Tie-In point at 12,200.00', Window point at 12,282.00' and a Projected survey at 15,311.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 14, 1997 Erin Oba Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re; Prudhoe Bay Unit 3-16A ARCO Alaska, Inc. Permit No. 97-033 Sur. Loc 1249'FSL, 78'FEL, Sec. 10, T10N, RISE, UM Btmhole Loc. 2639'FNL, 1944'FEL, Sec. 9, T10N, R15E, UM Dear Ms. Oba: 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. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical inte~ity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and 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 tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Commissioner BY ORDER OF THE COMMiSSION dlf/Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 i la. Type of Work Drill __ Redrill X I lb. Type of Well Exploratory__ Stratigraphic Test _ Development Oil _ Re-Entry__ Deepen --I Service X~ Development Gas __ Single Zone ~ Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 64' 3. Address 6. Property Designation P. O. Box 100360, Anchora~le, AK 99510-0360 ADL 28328 ~" Prudhoe Ba¥/Prudhoe Bay Oil 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1249' FSL, 78' FEL, Sec 10, T10N, R15E, UM. Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 353' FSL, 1596' FEL, Sec 9, T10N, R15E, UM. 3-16A #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 2639' FN/, 1944' FEL, Sec 9, T10N, R15E, UM. March 14, 1997 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line No Close Approach 15350' MD / 9024' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 12300' MD Maximum hole angle 91° Maximum surface 3000 psig At total depth (TVD) 3500 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD 'rVD (include stage data) 3-3/4" 2-7/8" 6.4 L-80 FL4S 3770' 11580' 8387' 15350' 9024' 25 Bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: true measured vertical 9413 13070 feet feet Plugs(measured) Effective depth: measured 12326 feet Junk (measured) true vertical 8853 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 73' 20" 383 Sx Arcticset 73' 73' Surface 2661 ' 13-3/8" 2100 Sx Fondu 2775' 2725' Production 11766' 9-5/8" 500SxCIG 11830' 8553' 24 1997 Liner 1515' 7" 548 SxCI G 13065' 9410' Perforation depth: measured 12000 - 12040'; 12164 - 12204'; 12218- 12234' AJaska0jJ&GasC0ns. C0mrrlissi0n true vertical 8629 - 8656'; 8741 - 8769'; 6778 - 8789' ~0rage 20. Attachments Filing fee x Property plat __ BOP Sketch _~x Diverter Sketch _ Drilling program x__. Drilling fluid program__ Time vs depth plot_ Refraction analysis _ Seabed report _20 AAC 25.050 requirements _ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge.,~;:~ e~'.;o~-~ ,~ ~, 5 ~ ~ ~,Jo, ~.-~ Signed ~¢=,,~ ~. ~ Titlle Engineering Supervisor Date ,,~-,7,/../L - ~' 7 Commission Use Only Permit Number I AP, number I Ap p roval~..~ e_.//,~_7~_ ~ ..~ I See cover letter for ~'~- 0~..~ 50- O~¢{ - ~ 0 I~J,~...OI other requirements Conditions of approval Samples required .~Y e s ~ N o Mud log required~ Y e s ~ N o Hydrogen sulfide measures ~ Y e s N o Directional survey required .~ Yes__ N o Required working pressure for BOPE 2M; __ 3M; ~ 5M' __ 1 0M~ __ 1 5M /~ 3500 psi for CTU Other: -Ongma Mary C. Marshbum byorder of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplica DS 3-16A CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore. Directionally drill a horizontal well from the existing wellbore. Complete with 2-7/8" cemented liner. Intended Procedure: Cement squeeze the current perforations and plugback the existing completion to N 12270' md. Mill window in 7" casing at-12300' md. Drill 10' of formation and perform Leak off test to 0.5 ppg above the highest anticipated mud weight. Build angle to ~92°. Directionally drill 3-3/4" x 3000' horizontal well to access Victor reserves. · Run and cement 2-7/8" liner to TD. · Perforate selected intervals. · Place well on MI. February 20, 1997 DS 3-16A Proposed CT Sidetrack Horizontal 5-1/2" Tubing Packer 11533' 7" Liner Top 11550' X Nipple 11584' Tbg Tail 11586' 9-5/8" Casing shoe @11830' Top of 2-7/8" Liner in 4-1/2" Tbg. tail. Initial Perfs~ 200' 3-1/2" scab liner top @ 12348' Pkr @ 12340' ELM XN Nipple 12354' Tbg Tail 12356' Sand Top 12528' cutin 7"at ~12300-12305' 3-3/4" Open hole 2-7/8" liner TD @ ~ 15000' Current perforations cement squeezed i 3-i6APL.xis 3-i6 A DiRECTiONAL SIDETRACK PLAN 2/19/97 5:09 PM ! ARCO 3-16 A SIDETRACK PLAN PREPARED FOR S. WARD FEB. 19, 1997 359.39° REL. TOGRID NORTH I -64' ! I I N/S & E?W REL. TO GRiD NORTH / ASP COORD. ARE REL. TO ?RID NORTH 5937286.3 28.72"i J VERTICAL SECTION USED RKB NOTE SURFACE LOC. MAG. DEC. TO TRUE N. Comments TIP MD Inc. Dir SS DEPTHJ VSJ ftI deg I (leg I ltl 12,200.00 46.45i 270.581 8,740.301-1,014.50 i t221000 4637 270.65 8747~01-1.014.301 12,240.001 4e.131 270.861 8,768.00!-1,013.80i 1.,122~0~j~445c68~ ~771,~20~1 88L8~988~0 NI-S E/-WI BuildI Turn] Dogleg ftI ft deg/100 deg/100i deg/100i -1,086.90 .6,805.40 0.00 o.ool 0.00I -1,086.80 ~ -6,812.70, -0.80 0.70 0.90! -1,086.50 X: 713185.2 ASP Y ASP X ft ft 5,936,199.5 706,379.8 5,936,199.5 5,936,200.0 706,372.5 706,350.8 2. KOP 19 DL HIGHStDE 3. DL 19.6 90 TF 112,330.001 51.35i 271.28 271.28 12,420.00 12,450.00i ..... 12,480.00i I 12,510.00i 12,54o.ooI 8,895,40i !2,6~.00l -1,008.701 ! 12,600.00 67.73{ 322.10j 81964.20i , , ! I 70.241 327.621 8,975.001 .-8_9! -984.101 -914.101 -1,086.10 -1,085.70 -1,085.20 -1,082.60 -1,077.60 -1,069.60[-6,: -1,058.801 -7,021.70 -i,045.20' -1,029.10 -1,010.50 -989.70 ORIENT 0.36 DL 90 12,660.001 72.911 332.97 8,984.50 -866.20 12,690.00! 75.72 338.16 8,992.601 .839.80 12,72000, 78.64 343.22! 8.999.201 -8t2. t0! 12,750.001 81.64l 348.171 9,004.40! -783.40 I 12,810.00 87.801 357.88 9,009.90 12,840.00 90.91 2.69 9,010.30 ~53.9~{ -724.10 -694.10 12,842.90i 9" 21' 3.151 9,010.20J -691.20{ 12,870.001 91.21 3.25 9,009.601 -664.201 t2,900.00i 9i.2i 3.35i 9,009.00 -634.20i ~ 12,930.00 91.21 3.46i 9,008.401 -604.30 12 960 00 91 20 3 -~7 9 007 701 --~74 40! j 5- - ~ · I '~ ~ ! ' ~ ~' * . ~ .................. 12~990.00T- -9i:201 3.68[-9,00~;'1bI-':544.501 ' i 13,020.00j 91.20 3.781 9,006.501 -514.60l - -942.00 -915.80 -888.20 -859.50 -830.20 -800.30 -770.30 -767.501 -7,168.70 -740.40 -710.40 -680.50 -650.60 ~620~60 -590.70 I 13,050.001 91.201 3.891 9,005.80 -484.70 I 13,080.001 91.201 4.001 9,005.20 -454.80 i 13,110.00i 91.20i 4.11i 9,004.60 -424.90 13,140 O0i 91.20 4.22] 9,004.00 -395.00 13,170.001 91.19 4.321 9,003.30, -365.10 9 002 70 13,200.00i 91.191 4.431 , . , -335.20 I 13,230.001 91.19] 4.541 9,002.10! -305.40i i 13,260.001 91.191 4.651 9,00t.501 -275.501 , i 13,290.001 91.191 4.761 9,000.801 -245.60i t3,320 . O0 , 91 ._19 4 .86 9 ,000.20!, -215.80{ -560.801-7,156.00 -530.90 -7,153.90 -500.90 -7,151.80 -471.00 -7,149.60 -441.10! -7,147.40 411 20 714510 ~381;30 ~7:142;80 -351.40 -7,140.40 -321.50 -7,137.90 -291.60 -7,135.40 o.oo{ 19.oo{ 5,936,200.0 706,329.3 5,936,200.5 706,307.8 5,936,201.0 5,936,201.5 706,285.3 706,261.8 5,936,204.0 706,235.9 5,936,209.0 706,211.1 5,936,217.0 706,186.9 5,936,227.5 706,163.5 21.1oi 7.701 19.00 19.10 5,936,241.0 706,141.1 5,936,257.5 706,120.1 5,936,276.0 706,100.4 19.10t 5,936,296.5I 706,082.5 5,936,319.5 706,066.4 5,936,344.5 706,052.3 5,936,370.5 706,040.4 5,936,398.0 706,030.7 5,936,427.0 706,023.4 5,936,456.0 706,018.6 5,936,486.0 706,016.2 5,936,516.0 706,016.3 5,936,519.0 706,016.5 5,936,546.0 706,018.0 0.00 0.40 0.40 0.00 0.40 0.40J J O.OOj 0.40 0.40j 0.00 0.40 0.40] 0.00 0.40 0.40J 0.00 0.40' 0.40 0.00 0.40l 0.40l 0.00 0.4o 0.40 0.001 0.40 0.40 0.00, 0.40 040l 5,936,576.0 706,019.8 5,936,606.0 706,021.5 5,936,636.0 706,023.4 5,936,665.5 706,025.3 5,936,695.5 706,027.2 5,936,725.5 706,029.2 5,936,755.5 706,031.3 5,936,785.5 706,033.4 5,936,815.5 706,035.6 5,936,845.0 706,037.8 5,936,875.0 706,040.1 5,936,905.0 706,042.4 5,936,935.0 706,044.8 5,936,965.0 706,047.3 5,936,994.5 706,049.8 5,937,024.5 706,052.4 5,937,054.5 706,055.0 5,937,084.5 706,057.7 5,937,114.0 706,060.4 5,937,144.0 706,063.3 13,350.001 13,380.00 13,410.00 13,440.001 91.19 4.97 8,999.60 91 181 5.051 8,~9.00 91.18i 5.191 8,998.40 91.18i 5.30J 8,997.70] 0.00 0.40 -185.90 -261.70J -7,132.80 -!56.10 -231.90 -7,130.20 0.00 0.40 -126.201 -202.00J-7,127.50 0.00 0.40 -96.40j -172.101 -7,124.80 0.00 0.40 -66.60i -142.30 -7,122.00 0.00 0.40: -112.40 -7,119.10 0.001 0.40 .82.601 -7,116.201 0.00 0.40 -52.70 -7,113.2ol o.oo o.4oJ -22.90 -7,110.20J O.OOJ 0.40 t3,470.001 91.18i 5.40j 8,997.10i ~ J J 13 500.OOJ 91.18 5.51J 8,996.50J ~6.70J 13,530.00 91.181 5.62i 8,995.901 .6.90 13,560.001 91.18 5.73J 8,995.30 22.90 13,590.00j 91.17J 5.83j 8,994.70J 52.70] 13,620.00J 91.171 5.94j 8,994.001 82.50j 0.40 0.40 0.40 0.40 0.40 0.40 0.40I 0.40 0.40 7.00 -7,107.10 0.00 0.40 0.40 5,937,174.0 706,066.1 5,937,204.0 706,069.0 5,937,233.5 706,072.0 5,937,263.5 706,075.0 5,937,293.5 706,078.1 2 3-16APL.xls 3-16A DIRECTIONAL SIDETRACK PLAN 2/19/97 5:09 PM Comments MD Inc. Dir SS DEPT~t V~t NI-S E/-W Build Turn Dogleg A SP~ A SPX [ ffi deg deg ftI ftI degllO0 degl'lO0 degllO0ft ft 113,650.00l 91.17J 6.05J 8,993.40J 112.30 36.801 -7,104.00J 0.00 o.40J o.4oI 5,937,323.0 706,081.2 I 13,680.00 91.17j 6.16J 8,992.80J 142.10 66.60 -7,100.801 0.00 0.401 0.40J 5,937,353.0 706,084.4 13,710.00 9i.17 6.27i 8,992.20i 171.90 96.40-7,097.60i 0.00 0.40i O.40i 5,937,383.0 706,087.6 I13,740.00 91.17 6.37 8,991.60 201.60 126.30 -7,094.30/ 0.00 0.401 0.401 5,937,412.5 706,090.9 13,770.00 91.17J 6.48 8,991.00 231.40 156.10-7,090.90J 0.00 0.40! O~OJ 5,937,442.5 706,094.3 j ] '6.59' ' I 0.00 0.40 i ' J 13,800.00 91.16j 8,990.40 261.20j 185.90 -7,087.50 0.00 0.40 5,937,472.0 706,097.8 13,830.00J 91.16J 6.70 8,989.80 290.90i 215.60 -7,084.00 0.40 0.40 5,937,502.0 706,101.2 I t3,860.00j 91.16 6.81J 8,989.20j 320.70 245.40J -7,080.50 0.00 0.40 0.40 5,937,532.0 706,104.8 I 13,890.00j 91.16- 6.91j 8,988.50J 350.40 275.20 -7,076.90 0.00 0.40 0.40 5,937,561.5 706,108.3 J 13,920.001 91.t6! 7.021 8,987.901 380.10 305.00 -7,073.30 0.00 0.40 0.40 5,937,591.5 706,111.9 13,950.00 7.13 8987 30 91.16J . 409.90 334.70 -7,069.60 0.00 0.40 0.40 5,937,621.0 706,115.6 j 13,980.00 91.15j 7.24 8'986'701 439.60 364.50 -7,065.80 0.00 0.40 0.40 5,937,651.0 706,119.4 114,010.00 91.151 7.35 81986;10 469.30 394.30 -7,062.00 706,123.2 0.40 5,937,680.5 0.00 0.40 7.45t 8,985.50 424.00 -7,058.20 0.00 0.40 0.40 5,937,710.5 706,127.1 14,040.001 9t.151 499.00 14,070.O0 91.15i 7.56i 8,984.90 528.70 453.70 -7,054.20 0.00 0.40 0.40 5,937,740.0 706,131.0 I 14,100.00J 91.15J 7.67J 8,984.30 558.40 483.50-7,050.30J 0.00 0.40 0.40 5,937,770.0 706,135.0 I 14,130.001 91.15i 7.78i 8,983.70 588.10 513.20'-7,046.20 0.00 0.40 0.40 5,937,799.5 706,139.0 / 14,160.00 91.15 7.88J 8,983.10 617.70 542.90-7,042.20 0.00 0.40 0.40 5,937,829.0 706,143.1 J 14,190.00 91.14 7.99j 8,982.50 647.40 572.60 -7,038.00J 0.00 0.40 0.40 5,937,859.0 706,147.3 J 14,220.00j 91.14! 8.101 8,981. -7,033.80 j 0.40' 0.46 5,937,888.5 706,151.4 14.250.00 I 8.21 ~l -7,029.60 677.OO 602.30 0.00 91.14J 8,981. 706.70 632.00 0.00 0.40 0.40 5,937,918.5 706,155.7 t4 280.00J 91.14 8.32 8,980.70 736.30 661.70 -7,025.20 0.00 0.40 0.40 5,937,948.0 706,160.0 14,310.001 91.141 8.42 8,980.10 765.90 691.40 -7,020.90 0.00 0.40 0.40 5,937,977.5 706,164.4 i !4,340.00 91.14{ 8.53 8,979.50 795.60 721.00 -7,016.50 0.00 0.40 0.40: 5,938,007.5 706,168.8 14,370.00 91.13i 8.641 8,978.90 825.20 750.70 -7,012.00 0.00 0.40 0.40 5,938,037.0 706,173.3 14,400.001 91.131 8.75 8,978.30 854.801 780.30 -7,007.401 0.00 0.40 0.40 5,938,066.5 706,177.8 8.861 8,977.80 J !4,430.001 91.131 884.401 810.00 -7,002.90[ 0.00 0.40[ 0.40 5,938,096.5 706,182.4 9.07 8,977.20{ 913.90 839.60 -6,998.20 0.40 [14,460.00[ 91.13[ 8.96 943.50 -6,993.50 0.00 0.40 0.40 5,938,126.0 706,187.1 14,490.00i 9t.131 8,976.60 869.20 0.00 0.40 5,938,155.5 706,191.8 14,520.00 91.131 9.18 8,976.00 973.10 898.80 -6,988.80 0.00 0.40 0.40 5,938,185.0 706,196.6 14,550.001 91.121 9.29 8,975.40 1,002.60 928.50 -6,983.90 0.00 0.4O 0.4(~ 5,938,2~5.0 706,201.4 14,580.001 91.12 9.39 8,974.80 1,032.20 958.00 -6,979.10 0.00 0.40 0.40 5,938,244.5 706,206.3 , t4,610.00[ 91.12, 9.50! 8,974.20 1,061.70 987.60.-6,974.20 0.00 0.40 0.40 5,938,274.0 706,211.1 I 14,640.00 91.12 9.61i 8,973.60 1,091.20 1,017.20 -6,969.20 0.00 0.40 0.40 5,938,303.5 706,216.1 14,670.00 91.12 9.72i 8,973.00 1,t20.70 1,046.80-6,964.10 0.00 0.40 0.40 5,938,333.0 706,221.2 t4,700.00 91.12[ 9.83! 8,972.50 1,150.20! t,076.30 -6,959.00 0.00 0.40 0.40 5,938,363.5 706,226.3 i 14,730.00J 91.12 9.93J 8,971.90 1,179.70 1,105.90 -6,953.90 0.00 0.40 0.40 5,938,392.0 706,231.4 14,760.00' 91.11 10.041 8,971.30 1,209.20 1,135.401 -6,948.70~ 0.00 0.40 0.40 5,938,422.0 706,236.6 14,790.00 91.11 10.151 8,970.70 1,238.70! 1,165.00 -6,943.4o 0.00 0.40 o.4o 5,938,451.5 706,241.9 , t4,820.00 91.11, 10.26i 8,970.10 1,268.20! 1,194.50 -6,938.10 0.00 0.40 0.40 5,938,481.0 706,247.2 J J i8,969.50 '1,224.00 0.40 14,850.00 91.11 i 10.37 ~ 1,297.601 -6,932.80~ 0.00 0.40 5,938,510.5 706,252.6 114,88o.ool 9t.11! 10.471 8,959.00[ 1,327.001 1,253.50-6,927.301 0.00 0.40! 0.40 5,938,540.0 706,258.0 14,910.00 91.11} 10.58 8,968.40J 1,356.50J 1,283.001 -6,921.90 O.OOJ 0.40 0.40 5,938,569.5 706,263.5 14,940.00 91.10j 10.69 8,967.80 1,385.90 1,312.50 -6,916.30 0.00; 0.40 0.40 5,938,599.0 706,269.1 J 14,970.00j 91.10J 10.80J 8,967.20 1,415.30 1,341.90 -6,910.70 0.001 0.40 0.40 5,938,628.0 706,274.6 15,000.00 j 91.101 10.91 8,966.70 1,444.70 J 1,371.40 -6,905.10 0.00 0.40 0.40 5,938,657.5 706,280.3 15,030.00 91.!0j 11.01 8,966.10 J 1,474.10 1,400.801 -6,899.40 0.00 0.40 0.40: 5,938,687.0 706,286.0 i 15,060.00 91.101 11.t2 8,955.501 1,503.50 1,430.30 0.00 0.40 0.40 5,938,716.5 706,291.8 -6,893.60 , 15,090.00 91.10! 11.23 8,964.9o, 1,532.80J 1,459.70,-6,887.80 0.00 0.40 0.40 5,938,746.0 706,297.6 ] 15,120.00 91.09i 11.34 8,964.40 1,562.20i 1,489.10i -6,881.90 0.00~ 0.40 0.40 5,938,775.5 706,303.4 i15,150.00j 91.09 11.44 8,963.80 1,591.50J 1,518.50J-6,876.00 0.00 0.40 0.40 5,938,805.0 706,309.4 15,180.00i 91.09i 11.55 8,963.?_0' 1,62.0.80i t,547.90i-6,870.00 0.00 0.40 0.401 5,938,834.0: 706,315.4 15,210.00 91.09j 11.66 8,962.50 1,650.201 1,577.301-6,864.00 0.00 0.40 0.40 5,938,863.5, 706,321.4 !15,240.00 91.09} 11.77 8,962.10 1,679.50t 1,606.70J-6,857.90 0.001 O.4O 0.40 5,938,893.0 706,327.5 , 15,270.00, 91.08, 11.88 8,961.50 1,708.80, 1,636.001 -6,851.80 0.00 0.40 0.40 5,938,922.5 706,333.6 / ~ 15,300.001 91.08! 11.98 8,960.901 1,738.00 1,665.40 -6,845.60 0.00 0.40 0.40 5,938,951.5 706,339.9 / 15,330.00 91.08i 12.09 8,960.40 1,767.30 1,694.701 -6,839.30 0.00 0.40 0.40 5,938,981.0 I 706,346.1 6. TD FOOTAGE: 3049.~' J 15,349.50 91.08j 12.16 8,960.00 1,786.30 1,713.70J -6,835.20 0.00 0.40 0.40 5,939,000.0J 706,350.2 · I I II IIIIUIII II I Iii]1 IIII II I IIIIIII IIII ARCO ALASKA INC. ~-t~6 A DIRECI'IOHAL Sll~TRACK PI~UOHCIt~ ~L~v ii ii i iiiiiiii N~RTH REF. TO GRID N. True t-1 .~2) Mag (+27 09~ 8600 -- 8900 -"" 9200 I TIP 12200 IVlD 2DI lg~/100 TT0° KOP 3 D! t9.1°/100 TT 90° 4 DI .36°/1 D0 Tf 90.7;3' 316ASTOG 31EORGR A ARCO ALASKA INC. 6 ~--2000 -- -- -- -- 3---1000 -- 0 2000 E/W & NIS Scale I Inch · 1000 tt Vertical Section Scale 1 inch: 300 ft PLANE OF VERTICAL SECTION, 359.39° RELATIVE TO GRID NORTH FILE N&ME ' C:~ARGOALK~3-1GA~,3-16A~,.DW2 DR&~N BY ' Sll~O HAD!PbTRO DATE FEB lg. 1957 III Illl .__ II IIII IIIIII III III IIIII III C T Drilling Wellhead Detail ~ CT Injector Head Methanol Injection Offs 7' WLA Quick Connect Alignment Guide Flange-- 7-1/16", 5M Ram Type Dual /1 Gate BOPE HCR Flanged Fire Resistant Manual Valve Kelly Hose To Dual \ ChokeManifold X ~~~_~~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure -- 7 R~ser i I 5,000 psi working pressure I ,; 2" Cutters or Combination Cutter/Blinds 2" Slip/Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Ram Type Dual Gate BOPE Manual over Hydraulic 7-1/16" ID with Pipe/Slip Rams o.458' ($.$") Manual Master Valve 2" Pump-In ~Tubing Hanger 9-5/8" Annulus 13-3/8" Annulus Fire Resistant Kelly Hose to Flange by Hammer Up 1/4 Turn Valve on DS Hardline 10' from Tree 60~40 Trplx Shop Fuel Water Boilers Mud Pump Room Pipe rack Ext. Dowell Drilling Equipment Trailer Ext. Preferred Major Equipment Layout for CT Drilling in DS 3-16A WELL PERMIT CHECKLISTco~.¥ FIELD ,~ POOL ~ ~ Oil" IN~T CLASS ~ ~ ~ ~ ~ ~ --' t~ ~ PROGRAM: exp[] dev [] redrl~serv~wellbore segF] ann disp para req[] GEO., ~A-~-~ O UN~T# / l ~ Y 0 ON/OFF SHORE (~ ~/ '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 ............. ~ N 5. Well located proper distance from drlg unit boundary. . N 6. Well located proper distance from other wells ...... O 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 REMARKS ENGINEERING 15. Surface casing protects all known USDWs ......... Y 16. CMT vol adequate to circulate on conductor & surf csg. . Y 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. .Y N 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~j~ N 26. BOPE press rating adequate; test to ~ psig. Y~ N 27. Choke manifold complies w/~LPI RIP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ Q~ N GEOLOGY AP~ DATE 30. Permit can be issued w/o hydrogen~. .Y N 31 Data presented on pot~T%-ssure zones ..... Y N 32 Seismic a~allow gas zones .......... Y N 33 ~l~dition survey (if off-shore) ......... Y N 34 Contact name/phone for weekly progress reports ..... Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: ~o~ ~1~ mom -~X~. 2 ~'--~" Comments/Instructions: HOW/dlf- A:\FORMS\cheklist rev 01/97 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 Tue Aug 05 16:30:07 1997 Reel Header Service na/~e ............. LISTPE Date ..................... 97/08/05 ~..' Origin ................... STS Reel Name ................ LrNKNOWN i,~,. Continuation Number ...... 01 ~4'~ Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientl~ Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/08/05 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNO~ Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW-70090 A. WORTHINGT BASS/KARA AUG 1997 AI~a Oi! & Gas Cons. Commission ~chorage 03-16A 500292041501 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 05 -AUG- 97 MWD RUN 3 AK-MW-70090 A. WORTHINGT BASS/KARA MWD RUN 4 AK-MW-70090 A. WORTHINGT GOODRICH/KAR JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 AK-MW-70090 A. WORTHINGT GOODRICH/KAR MWD RUN 6 AK-MW-70090 A. WORTHINGT GOODRICH/KAR MWD RUN 7 AK-MW-70090 A. WORTHINGT GOODRICH/KAR JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 8 AK-MW-70090 GOODRICH/KAR MWD RUN 9 AK-MW-70090 W. JACKSON GOODRICH/KAR MWD RUN 10 AK-MW-70090 W. JACKSON GOODRICH/MOO 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 11 AK-MW-70090 W. JACKSON GOODRICH/MOO 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: File Header MWD RUN 12 AK-MW-70090 W. JACKSON GOODRICH/MOO 10 i0N 15E MWD RUN 13 AK-MW-70090 W. JACKSON GOODRICH/MOO 1249 78 64.00 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.375 2725.0 9.625 11830.0 7.000 12280.0 3.750 15311.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL GAMMA RAY DATA (SGRD) IS DOWNHOLE RECORDED. 3. MWD RUN 1 IS DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). THIS RUN CONTAINS NO VALID DATA AND IS NOT PRESENTED. 4. MWD RUNS 2 THROUGH 13 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP) . 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ALI TURKER OF SPERRY-SUN DRILLING SERVICES AND DOUG KNOCK OF ARCO ALASKA, INC. ON JULY 24, 1997. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15311'MD, 8941'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/05 Maximum Physical Record..65525 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 GR 12257.0 ROP 12280.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 15284.0 15310.5 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE MWD 2 12280 MWD 3 12290 MWD 4 12564 MWD 5 12707 MWD 6 13000 MWD 7 13843 MWD 8 14082 MWD 9 14241 MWD 10 14433 MWD 11 14508. MWD 12 14637. MWD 13 14662. $ REMARKS: MERGED MAIN pass. $ TOP MERGE 0 12290 0 12564 0 12707 0 13000 0 13843 0 14082 0 14241 0 14433 0 14508 0 14637 0 14662 0 15311 # 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 BASE 0 0 0 0 0 0 0 0 0 0 0 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12257 15310.5 13783.8 6108 12257 GR 16.99 122.15 29.1832 6055 12257 ROP 1.87 2988 99.5945 6062 12280 Last Reading 15310.5 15284 15310.5 First Reading For Entire File .......... 12257 Last Reading For Entire File ........... 15310.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/05 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 ....... 97/08/05 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12257.0 12267.5 ROP 12280.0 12289.5 $ LOG HEADER DATA DATE LOGGED: 01-APR-97 SOFTWARE SURFACE SOFTWARE VERSION: MSC V. 1.32 DOWNHOLE SOFTWARE VERSION: NGP; SPC V. 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 12290.0 TOP LOG INTERVAL (FT) : 12280.0 BOTTOM LOG INTERVAL (FT) : 12290.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 45.8 MAXIMUM ANGLE: 47.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP $ NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER NGP 214 3.800 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 (OHl~4) 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 3.8 Sea-Water .00 .0 .0 0 .0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 75.0 First Name Min Max Mean Nsam Reading DEPT 12257 12289.5 12273.2 66 12257 GR 33.07 58.12 43.4627 22 12257 ROP 1.87 467.63 121.943 20 12280 Last Reading 12289.5 12267.5 12289.5 First Reading For Entire File .......... 12257 Last Reading For Entire File ........... 12289.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/05 Maximum Physical Record..65535 File Type ................ LO Previous File.Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12266 . 0 12538 . 5 ROP 12289 . 0 12564 . 0 $ LOG HEADER DATA DATE LOGGED: 03 -APR- 97 SOFTWARE SURFACE SOFTWARE VERSION: DOWlqHOLE 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: 55.6 MAXIMUM ANGLE: 7 0.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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: MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 12564.0 12290.0 12564.0 TOOL NUMBER NGP 292 3.750 3.8 FLO-PRO 8.80 .0 9.8 MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) 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 .0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 63 .3 First Name Min Max Mean Nsam Reading DEPT 12266 12564 12415 597 12266 GR 21.49 122.15 40.5365 546 12266 ROP 6.86 362.4 60.4433 551 12289 Last Reading 12564 12538.5 12564 First Reading For Entire File .......... 12266 Last Reading For Entire File ........... 12564 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 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 START DEPTH STOP DEPTH GR 12538 . 0 12680 . 0 ROP 12562 . 0 12706 . 5 $ LOG HEADER DATA DATE LOGGED: 03-APR-97 SOFTWARE SURFACE SOFTWARE VERSION: MSC V. 1.32 DOWNHOLE SOFTWARE VERSION: NGP; SPC V. 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 12707.0 TOP LOG INTERVAL (FT) : 12564.0 BOTTOM LOG INTERVAL (FT) : 12707.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 72.5 MAXIMUM ANGLE: 78,0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE NGP 292 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT) : 3.8 BOREHOLE CONDITIONS MUD TYPE: FLO-PRO MUD DENSITY (LB/G): 8.90 MUD VISCOSITY (S) : .0 MUD PH: 9.2 MUD CHLORIDES (PPM) : FLUID LOSS (C3) : 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 63.3 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 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 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12538 12706.5 12622.2 338 12538 GR 20.79 37.83 25.5932 285 12538 ROP 12.82 163.64 24.4669 290 12562 Last Reading 12706.5 12680 12706.5 First Reading For Entire File .......... 12538 Last Reading For Entire File ........... 12706.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMI~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12679.0 12973.0 ROP 12705.0 12999.5 $ LOG HEADER DATA DATE LOGGED: 04-APR-97 SOFTWARE SURFACE SOFTWARE VERSION: MSC V. 1.32 DOWNHOLE SOFTWARE VERSION: NGP; SPC V. 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 13000.0 TOP LOG INTERVAL (FT): 12707.0 BOTTOM LOG INTERVAL (FT) : 13000.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 75.4 MAXIMUM ANGLE: 85.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 292 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 3.8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 8.90 .0 9.5 .0 .000 .000 .000 .000 63.3 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): .3 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 AAPI 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12679 12999.5 12839.2 642 12679 GR 17.38 71.87 29.4775 589 12679 ROP 24.82 575.6 93.6026 590 12705 Last Reading 12999.5 12973 12999.5 First Reading For Entire File .......... 12679 Last Reading For Entire File ........... 12999.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12973.0 ROP 13000.0 $ 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 NGP NATURAL GAMMA PROBE $ 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 (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: STOP DEPTH 13816.5 13843.0 06-APR-97 MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 13843.0 13000.0 13843.0 89.3 96.3 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL NUMBER NGP 214 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : 3.750 3.8 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 FLO-PRO 8.90 .0 9.5 .0 .000 .000 .000 .000 60.9 .3 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 AAPI 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12973 13843 13408 1741 12973 GR 16.99 104.27 26.5567 1688 12973 ROP 37.78 1691.63 127.879 1687 13000 Last Reading 13843 13816.5 13843 First Reading For Entire File .......... 12973 Last Reading For Entire File ........... 13843 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13816.0 ROP 13842.0 $ 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 NGP $ 14055.5 14081.5 NATURAL GAMMA PROBE 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 (OHMM) 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 07 -APR- 97 MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 14082.0 13843.0 14082.0 87.8 90.3 TOOL NUMBER NGP 214 3.750 3.8 FLO-PRO 8.80 .0 9.4 .0 .000 .000 .000 .000 65.6 .3 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 7 FT/H 4 1 68 4 2 GR MWD 7 AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 13816 14081.5 13948.8 532 13816 ROP 27.46 1531.28 129.124 480 13842 GR 18.03 75.7 30.2364 480 13816 Last Reading 14081.5 14081.5 14055.5 First Reading For Entire File .......... 13816 Last Reading For Entire File ........... 14081.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NIIMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NI/MBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH STOP DEPTH 14054.0 14214.0 14080.0 14240.5 07 -APR- 97 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 NGP NATURAL GAMMA PROBE $ 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 (OHMM) 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 MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 14241.0 14082.0 14241.0 87.1 89.1 TOOL NUMBER NGP 156 3.750 3.8 FLO-PRO 8.80 .0 9.4 .0 .000 .000 .000 .000 68.0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 8 AAPI 4 1 68 4 2 ROP MWD 8 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 14054 14240.5 14147.2 374 GR 20.23 46.47 27.348 321 ROP 28.52 129 85.266 322 First Reading 14054 14054 14080 Last Reading 14240.5 14214 14240.5 First Reading For Entire File .......... 14054 Last Reading For Entire File ........... 14240.5 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... 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BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY %rENDOR TOOL CODE START DEPTH STOP DEPTH GR 14213 . 0 14406 . 0 ROP 14241.0 14432 . 5 $ LOG HEADER DATA DATE LOGGED: 08-APR- 97 SOFTWARE SURFACE SOFTWARE VERSION: MSC V. 1.32 DOWNHOLE SOFTWARE VERSION: NGP; SPC V. 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 14433.0 TOP LOG INTERVAL (FT) : 14241.0 BOTTOM LOG INTERVAL (FT) : 14433.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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 (OHMM) 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 88.6 93 .9 TOOL NUMBER NGP 257 3.750 3.8 FLO-PRO 8.90 .0 9.2 6.0 .000 .000 .000 .000 70.3 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 9 AAPI 4 1 68 4 2 ROP MWD 9 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 14213 14432.5 14322.8 440 14213 GR 21.8 39.88 27.5474 387 14213 Last Reading 14432.5 14406 R0P 13.24 344.7 46.5457 384 14241 14432.5 First Reading For Entire File .......... 14213 Last Reading For Entire File ........... 14432.5 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/05 Maximum Physical Record..65535 File Type LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE AIUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 14405 . 0 14481 . 5 ROP 14431.0 14507 . 5 $ LOG HEADER DATA DATE LOGGED: 09-APR- 97 SOFTWARE SURFACE SOFTWARE VERSION: MSC V. 1.32 DOWNHOLE SOFTWARE VERSION: NGP; SPC V. 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 14508.0 TOP LOG INTERVAL (FT) : 14433.0 BOTTOM LOG INTERVAL (FT) : 14508.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMI/M ANGLE: 92 . 3 MAXIMUM ANGLE: 94.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE TOOL NUMBER NGP 257 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 (OHMM) 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 3.750 3.8 FLO-PRO 8.80 .0 9.1 .0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 10 AAPI 4 1 68 4 2 ROP MWD 10 FT/H 4 1 68 8 3 68.0 First Name Min Max Mean Nsam Reading DEPT 14405 14507.5 14456.2 206 14405 GR 25.67 35.86 29.135 154 14405 ROP 11.78 217.84 29.1717 154 14431 Last Reading 14507.5 14481.5 14507.5 First Reading For Entire File .......... 14405 Last Reading For Entire File ........... 14507.5 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF File Header Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 14481.0 14611.0 ROP 14507 . 0 14636 . 5 $ LOG HEADER DATA DATE LOGGED: 10-APR-97 SOFTWARE SURFACE ~OFTWARE VERSION: MSC V. 1.32 DOWNHOLE SOFTWARE VERSION: NGP; SPC V. 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 14637.0 TOP LOG INTERVAL (FT): 14508.0 BOTTOM LOG INTERVAL (FT): 14637.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 91.9 MAXIMUM ANGLE: 93.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAP/MA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS TOOL NLTMBER NGP 257 3.750 3.8 MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHI~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 FLO-PRO 8.90 .0 9.1 .0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 11 AAPI 4 1 68 4 2 ROP MWD 11 FT/H 4 1 68 8 3 70.3 First Name Min Max Mean Nsam Reading DEPT 14481 14636.5 14558.8 312 14481 GR 22.38 34.38 26.2388 261 14481 ROP 19.67 2988 127.276 260 14507 Last Reading 14636.5 14611 14636.5 First Reading For Entire File .......... 14481 Last Reading For Entire File ........... 14636.5 File Trailer Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.012 Physical EOF File Header Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.011 Comment Record FILE HEADER FILE NUMBER: 12 RAW MWD Curves and log header data for each bit run in separate files. BIT RIINAIUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 14611.0 ROP 1463 6.0 $ 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: STOP DEPTH 14635.5 14661.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMYiA PROBE $ 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 (OHMM) AT TEMPERATURE (DEGF) 10-APR-97 MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 14662.0 14637.0 14662.0 ~93 ,4 93 .4 TOOL NUMBER NGP 79 3.750 3.8 FLO-PRO 8.90 .0 9.1 ,0 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 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 12 AAPI 4 1 68 4 2 ROP MWD 12 FT/H 4 1 68 8 3 70.3 First Name Min Max Mean Nsam Reading DEPT 14611 14661.5 14636.2 102 14611 GR 24.6 31.01 27.3047 50 14611 ROP 11.01 131.14 61.7925 52 14636 Last Reading 14661.5 14635.5 14661.5 First Reading For Entire File .......... 14611 Last Reading For Entire File ........... 14661.5 File Trailer Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.013 Physical EOF File Header Service name ...... ~ ...... STSLIB.013 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.012 Cormnent Record FILE HEADER FILE NI/MBER: 13 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 14635 . 0 15248 . 0 ROP 14661 . 0 15310 . 5 $ LOG HEADER DATA DATE LOGGED: 12-APR- 97 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: 89 . 2 MAXIMUM ANGLE: 94.4 MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 15311.0 14662.0 15311.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 257 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 3.8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT F~AX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 8.90 .0 9.1 .0 .000 .000 .000 .000 72.6 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 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 13 AAPI 4 1 68 4 2 ROP MWD 13 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 14635 15310.5 14972.8 1352 14635 GR 19.77 75.54 29.4374 1299 14635 ROP 11.01 2297.24 116.617 1300 14661 Last Reading 15310.5 15284 15310.5 First Reading For Entire File .......... 14635 Last Reading For Entire File ........... 15310.5 File Trailer Service name ............. STSLIB.013 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.014 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/08/05 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/08/05 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Scientific Physical EOF Physical EOF End Of LIS File
