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Home My WebLink About176-073STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: OA WeIlLock Squeeze 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development m Exploratory C] 5. Permit to Drill Number 176-073 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6' API Number 50-029-20231-00-00 7 Property Designation (Lease Number): ADL 028327, 028328 & 028331 8. Well Name and Number: PBU 03-08 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools:RIECEIVEF PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Q 5 NOVY tl Total Depth: measured 10370 feet Plugs measured None feet true vertical 9339 feet Junk measured 9829, 9851, 10225 feet Effective Depth: measured 10225 feet Packer measured 8821, 9298 feet AOGC C true vertical 9217 feet Packer true vertical 8053, 8442 feet Casing: Length: Size: MD: TVD: Buret: Collapse: Structural Conductor 80 20" 34-114 34-114 1530 520 Surface 2675 13-3/8" 33-2708 33-2707 5380 2670 Intermediate Production 10306 9-5/8" 31 -10337 31-9311 6870 4760 Liner Perforation Depth: Measured depth: 9604-9980 feet True vertical depth: 8697-9012 feet Tubing (size, grade, measured and true vertical depth) 4-112" 12.6# x 5-1/2" 17#, 13Cr80 / L-80 29-9423 29-8546 4-1/2" Baker S-3 Perm Packer 8821 8053 Packers and SSSV (type, measured and 5-1/2" Baker S-3 Packer 9298 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): OA Cemented to Surface Treatment descriptions including volumes used and final pressure: Used 2.2 gallons WeIlLock to fill stand pipes and squeeze OAP to 2500 psi. Monitor OAP and WH Temp until WeIlLock is fully cured. Wellock sample is solid and pliable and able to press into it. Final Pressures: OA = 184 psi, IA = 1862 psi, TBG = 256 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas- Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 188 106 6657 1791 236 Subsequent to operation: 176 0 5855 1862 256 14. Attachments: (required per 20 MC 25.070.25.071, a 25.2es) 15. Well Class after work: Daily Report of Well Operations 21 Exploratory ❑ Development 0 Service ❑ Stratigrephic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 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: 319-350 Authorized Name: Lastufka, JoseiaL N Contact Name: Smith, Travis T Authorized Title: Spe st Contact Email: travis.smithl@bp.com Authorized Signature: Date: N y + Contact Phone: +1 9075645412 Form 10-404 Revised 04/2017 W (0 �✓✓,, I -f -"NOV 0 6 20i� Submit Onginal Ony l !!�'/ �,.R,�6�r9 `�BDMS- Daily Report of Well Operations PBU 03-08 4CTI V ITV r1GTF m uuA w ev T/I/O = SSV/300/700. (Pre Wellock). N/D OA working 3" CIW valve and OA companion 3" tapped blind flange. N/U Intergal flanges w/ block valves on OA, working and companion. See Log. *** Job Complete*** Final WHPs - T/I/O = SSV/300/0. Note: Valve and blind flange left in corner of wellhose and Viton HiTemp gaskets installed in intergal flanges, low temp gaskets installed in block 9/24/2019 valves. T/I/O=SSV/1100/0 (Pre Wellock) Replace Arctic Gaskets with Viton HiTemp gaskets on OA Block 9/26/2019 Valves.***Job Complete*** Final WHPs=SSV/1100/0 COA=C WOA=OTG T/1/0 = SSV/1230/0. Temp = SI. Bleed IAP & OAP to 0 psi (Pre Wellock). ALP = 1860 psi, SI @ CV. IA FL @ 3190' (171 bbls). SI AL lateral. Serviced AL CV. IA bleed in progress. 10/13/2019 ***Continued on 10/14/19*** ***Continued from 10/13/19*** T/I/O = 1700/460/0. Temp = SI. Bleed IAP & OAP to 0 psi (Pre Wellock). Bled ALP to 200 psi, SI @ CV & lateral. Continue to bleed IAP to OT from 460 psi to 1 psi in 5 hrs (gas). Did not monitor. Installed heater in wellhouse and bled treecap void to 0 psi (gas), left 1 door open. Final WHPs = 1700/1/0. 10/14/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 05:45. T/I/O = SSV/70/500. Temp = SI. WeIlLock OA (Eval OA Repressurization). ALP = 1010 psi, SI @ CV & LV. OA cemented to surface. Bled OAP to 500 psi to 0 psi in <1 min (all gas). Monitor OAP for 1 hr for no observable flow. Remove 1502 block valves & caps, install target 90 & cap on OA companion and install sweeping 90 and stand pipe on OA. Used 2.2 gallons WeIlLock to fill stand pipes and squeeze OAP to 2500 psi. Monitor OAP and WH Temp for next 24 hrs. 10/15/2019 ***WSR continued on 10/16/2019*** **Job in progress** Continued from 10/15/19 AWGRS. T/I/O = SSV/0/1560. Temp = SI. Monitor 24 hrs (Post WeIlLock Squeeze). ALP = 1010 psi, SI @ CV & LV. OA cemented to surface. Continue to monitor OAP and wellhead temp. Bled OA working and companion side to 900 psi. Heater in Well house working and well head @ 72*. 10/16/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 13:20 T/I/O = SSV/190/880. Temp = SI. WHPs (Post wellock treatment). AL SI @ casing valve (1000 psi). Working side OA = 880 psi. Companion side OA = 700 psi. Casing temp @ 9 o'clock position = 1000, Casing temp @ 3 o'clock position = 60° (Windy day, casing is taking as much heat as possible). Added second heater hose to 3 o'clock position. Wellock sample is the consistency of warm honey. 10/17/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 20:20 T/l/O = SSV/190/1160. Temp = SI. WHPs (Post Wellock). AL SI @ casing valve (1000 psi). Working side OA= 1160 psi. Companion side OA =1020 psi. Bled the working side OA to 780 psi (Hyd oil & gas, —1 teaspoon). Bled the companion side OA to 980 psi (wellock, —1 teaspoon). Casing temp @ 9 o'clock position = 95*. Casing temp @ 3 o'clock position = 100* (adjusted heaters). Wellock sample is the consistency of warm honey. FWPs = SSV/190/780. 10/18/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 10:00 T/I/O = SSV/270/620. Temp = SI. WHPs (post Wellock). ALP = 1920 psi, SI @ CV. Wellhead temp = 94*. Wellock has the consistency of warm honey. 10/19/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 20:30 T/I/O = SSV/310/820. Temp = SI. WHPs (Post Wellock). ALP = 1890 psi, SI @ CV. OAP at the 12 o'clock = 1040 psi. OAP at the 6 o'clock = 820 psi. Wellhead temp on both sides of casing = 110*. Adjusted heaters away from wellhead. Wellock sample is unchanged. 10/20/2019 SV, WV, SSV = C. MV=O. IA, OA = OTG. 14:20 T/I/O = SSV/350/520 (12:00), 540 (6:00). Temp = SI. WHPs (Post Wellock). ALP = 2000 psi, SI @ CV. Wellhead temp= 70° (9:00), 80° (3:00). Wellock sample is firm, but not solid. 10/21/2019 SV, WV, SSV = C. MV=O. IA, OA = OTG. 16:40 T/I/O = SSV/330/540 (12:00), 580 (06:00). Temp = SI. WHPs & Wellock Description (Post Wellock). Wellhead Temp= 60° (9:00), 74° (3:00). Wellock sample is beginning to harden but is still fluid. Adjust heaters. 10/21/2019 SV, WV, SSV = C. MV=O. IA, OA = OTG. 02:00. Daily Report of Well Operations PBU 03-08 TWO = SSV/360/580. Temp = SI. WHPs (post Wellock). ALP = 2000 psi, SI @ CV. Wellhead temp = 74° @ 9 o'clock, 84° @ 3 o'clock. Wellock sample thick but still moves in jar. Still sticky to the touch. 10/22/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 13:30 T/I/O = SSV/380/660 (12:00), 660 (6:00). Temp = SI. WHPs (Post Wellock). ALP = 2000 psi, SI @ CV. Wellhead temp = 500 (9:00), 55° (3:00). Wellock sample is firm and tacky. Adjust heater trunks. 10/23/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 00:40. T/I/O = SSV/450/840 (12:00), 760 (6:00). Temp = SI. WHPs (Post Wellock). ALP = 1980 psi, SI @ CV. Wellhead temp @ 3 o'clock = 92° and 90° @ 9 o'clock. Wellock sample is firm but not set up hard. 10/24/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 14:50 T/I/O = SSV/470/600 (12:00), 600 (6:00). Temp = SI. WHPs (Post Wellock). ALP = 1980 psi, SI @ CV. Wellhead temp @ 3 o'clock = 62° and 780 @ 9 o'clock. Wellock sample is firm and tacky. 10/25/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 01:00. TWO = SSV/520/620 (12:00), 640 (6:00). Temp = SI. WHPs (Post Wellock). ALP = 2040 psi, SI @ CV. Wellhead temp @ 3 o'clock = 78° and 68° @ 9 o'clock. Wellock sample is solid and dry. 10/26/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 17:00. TWO = SSV/520/680 (12:00), 640 (6:00). Temp = SI. WHPs (Post Wellock). ALP = 2020 psi, SI @ CV. Wellhead temp @ 3 o'clock = 92° and 820 @ 9 o'clock. Wellock sample is solid and pliable and able to press into it. Heaters in good working condition. 10/27/2019 ISV, WV, SSV = C. MV = 0. IA, OA = OTG. 15:00 1 /1/0=300/500/0. Post welll lock job. RD hardline. RU 3" Cameron valve and 3" 5000 Blind flange. 10/28/2019 Tor ued to API spec. Job Complete. See log. Final WHP's 300/500/0. I/A 0/A= OTG. TREE = 4-118" CIW FLS V413LHEAD= FMC ACTUATOR= BAKER OKB. ELEV = 61' BF. ELB/ _ 3-318" KOP= 320U Max Angle = 36' @ 8800 Datum M7= 9800' Datum ND = 8800' SS &5/8" CSG, 47#, L-80, T0.1, D = 8.681" 2267' 13-3/8" CSG 72#. MN -80. D = 12.347" --27flFP Minimum ID = 2.79" @ 9214' 5-1/2" ALPHA TBG PATCH 4-12" TBG 12.6# 13CR-80, VAM TOP, .0152 bp f, D= 3.958" TOC DONUT, D = 2.79" (TAGGED 01/04/99) 5-12" TBG -PC 17#. L-80..0232 bof. D = 4.892' PERFORATION SUuMRY FIEF LOG: BRCS ON 11/06/76 ANGLEATTOP PHF:33 @ 9604' Note: Refer t0 R0duction DB for h'storical pert data SIZE SIT= NT92VAL Opn/Sqz SHOT SOZ 3-318" 6 9604-9636 O 11/02/87 16 33/8" 4 9732-9772 O 01/10/85 DOME RK 33/8" 4 9774-9788 O 01/10/85 33 MMG DOME RK 4 9774-9788 S 03/11/8201/04/85 8987 33/8" 4 9789-9793 O 11/02/87 8719 3318" 4 9804-9829 O 01/10185 4 9804-9829 S 05/14177 OIAW85 33/8" 4 9831- 9842 O 01/10/8.5 4 9831-9842 S 03/11/82 01/04185 33/8" 4 9850-9860 O 01/10/85 4 9850-9860 S 05/18/7701/04/85 33/8" 4 9870-9875 O 01/10/85 4 9870-9875 S 05/14177 01/04/85 2" 6 9910-9930 O 03/13101 4 9911-9946 S 05/14/77 01/04/85 33/8" 1 9914-9920 O 11/02/87 4 9960-9980 S 05/14/77 01/04/85 9-5/8" CSG 47#, MN -80, ID= 03-08 3_OQv SAFETY NOTES: 14-1/2"CHROME TUBING 2088' 4-12" FES X NP, ID = 3.813" -,F--224-8--7—W7518- HES ES CEMWTER 1 2326' 1 FOC CZAR I FTUAMnDMIe ST MD TVD DEV TWE VLV LATCH PORT DATE 5 2991 2990 5 MMG DOME RK 16 04/07/19 4 4908 4776 29 MMG DOME RK 16 04/07/19 3 63fi2 6021 33 MMG DOME RK 16 04/07/19 2 7524 8987 35 MMG SO RK 32 04/07/19 1 8719 7970 35 MMG DMY RK 0 02/17/07 = 3.813" 1' 1 -i9 -5/8x VILEG, D= ST MD I TVD DEV TYPE VLV LATCH PORT I DATE 8 8916 8129 36 MMG SO RI( 28 0223/01 9 9071 8256 36 MMG DMY RK 0 11113176 10 9229 8385 35 MMG "DCR RKP 0 08/17/89 VI IU LV LUVt - btH"U IUG PA IL:H 9214' - 9236' 5-1/2"X 21' ALPHA TBG PATCH D=2.79"(0205199) 15-12" OTIS XN NP, ID = 4.455' 1 1 9422' ��5-12'BKR SFEAROUi SUB 9423' S-1/2"Y♦2EG, D=4.892' 9414' aMD Ti LOGG®11!02/87 - BP FISH -2 l" DATE REV BY COMMENTS DATE REV BY COMMENTS 11113!76 ORIGINAL COMPLETION 0122/18 DGVJMD SET PX PLUG (01115/18) 11M2186 RWO 0123118 DG/JMD GLVC/O(O1/16/18) Li 02118N7 N4E5 RWO 0322/18 JMG/JMD GLV & PULLED PX PLUG 03/30/07 GJB/PJC DRLG DRAFT CORRECTIONS 04/14/19 PK(JMDa GLV C/O (04107/19 1120114 PJC PERFORATION UPDATES 0229/16 JPK/JMD GLV C/O (02r23116) PRUDHOE BAY UNIT WELL 03-08 PERMIT NO: 81760730 API NO: 50-029-20231-00 , T10N, R15E,1199' FSL 8 837' FWL BP Exploration (Alaska) THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Travis Smith Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 03-08 Permit to Drill Number: 176-073 Sundry Number: 319-350 Dear Mr. Smith: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a ogc c. a losk a.go v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, JnlClifownski�-' Commissioner DATED this '36 day of July, 2019. RBDWS JjUL 3 12019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 26.280 J ORIGINAL Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. 19 flV-60-2 X'7.46�& Submit Form and Attachments in Duplicate 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 - Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ CAange Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Aller Casing ❑ Other OA WellLock Squeeze RI 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0 5. Permit to Drill Number. 176-073 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ e. API Number: 50-029-20231-00-00' 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? S. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No El PBU 03-08 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028327. 028328 & 028331 PRUDHOE BAY. PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (6): Total Depth TVD(ft) : Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10370 9339 10225 9217 None 9829,9851,10225 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 34-114 34-114 1530 520 Surface 2675 13-3/8" 33-2708 33-2707 5380 2670 Intermediate Production 10306 9-5/8'. 31-10337 31-9311 6870 4760 Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 1 9604- 9930 8897 - 8970 JM -1 /2" 12.6# x 5-1/2" 17# 13Cr80 / L-80 29-9423 Packers and SSSV Type: 4-1/2" Baker S-3 Perm Packer Packers and SSSV MD (ft) and TVD (ft): 8821/8053 5-1/2" Baker S-3 Pecker 9298/8442 12. Attachments: Proposal Summary 0 Wellbore Schematic a 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development m Service ❑ 14. Estimated Date for Commencing Operations: August 10, 2019 15. Well Status after proposed work: Oil @ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Smith, Travis T be deviated from without prior written approval. Contact Email: Travis.Smithl@bp.com Authorized Name: Smith, Travis T Contact Phone: +1 907 564 5412 Authorized Title: En Authorized Signature: Date: / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: {J` O Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RB®NIS _W-'A1JUL 3 11019 Post Initial Injection MIT Req'tl? Yes 11No ❑ —/ Spacing Exception Required? Yes ❑ No lrI Subsequent Form Required: /0 _ y© y `/' APPROVEDBYTHE Approved by: Ix COMMISSIONER COMMISSION Date: 3� 1 J ORIGINAL Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. 19 flV-60-2 X'7.46�& Submit Form and Attachments in Duplicate by Z Well: 03-08 03-08 OA WeIlLock Proposal Engineers: Intervention: Travis Smith, 907-564-5412 Production: Matt Summers, 907-564-5066 History: Well 03-08 is a gas -lifted producer that has recently exhibited OA pressurization. This well has a fully - cemented OA, and has previously been treated with WeIlLock in 2015 and 2018. The well currently exhibits OA pressurization at a rate that is unmanageable by bleed. A PPPOT-IC passed on June 26, 2019. The proposed work in this Sundry would squeeze the OA with WeIlLock to mitigate the re -pressurization of the OA and return the well to service. Scope of Work: Squeeze the OA with WeIlLock to mitigate OA pressurization. Procedural Steps 1. ND OA gate valves, NU OA integrals. 2. Bleed annuli: bleed IA as low as possible. 3. Pump WeIlLock OA top job squeeze to 2500 psi per RP "WeIlLock Treatment for Cemented OAs". 4. After 1 week of cure time, ND OA integrals, NU OA gate valves. Current Schematic 03-08 SAFETY NOTES: —412' CHROME TIRING DATE REV BY COMMENTS REV BY COMMENTS 11/13778 ORM`�NALCCMPLETNN7 8 DGUMD SETPXPLUG 1H5/18 1122196 RYYO 8 DG/JMD GLVC/0(0jMSIB) O2MBST N4ES RVW #DATE 8JMC w GLVMaPULEDPXPL 1031J007 GJB/PJC DRLG DRAFT CORRECTIONS 9 PX/JMD GLVC/0 1120/14 PJC PERFORATION UPDATES 022&16 JPR/JMD GLV GO 022318 GATE 00N]H9 OOAT/19 04W 00/W/l 9 ovnmT DATE 0223/01 11n3ns 08/1711]. PRUDHOE BAY UNI WELL 03M PERMR No: 17W730 API No: 5002&20231-00 SEC 11, T10N, R/SE,1199' FSL 8 MT FAL SP Eapb918un (Ahab) Rixse, Melvin G (CED) From: Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com> Sent: Friday, July 26, 2019 8:55 AM To: Rixse, Melvin G (CED) Subject: RE: PTD 176-073, Sundry 319-350, PBVU 03-08 OA well lock squeeze 03-08 passed a CMIT-TxIA on 1/15/2018 to 2500 psi As far as the OA and IA being related, the recent pressure trends do not look as though the two equalize. Typically the OA has been lower than IA pressure, but when the OA has had pressure spikes they have been to higher pressures than the IA. Travis From: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Sent: Thursday, July 25, 2019 3:24 PM To: Smith, Travis T (CONOCOPHILLIPS) <travis.smithl@bp.com> Subject: PTD 176-073, Sundry 319-350, PBVU 03-08 OA well lock squeeze Travis, When was the last MIT performed on the IA? How do you know the well lock squeeze is not a single barrier to IA pressure? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231) or (Melvin.Rixse(�alaska.eov). • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday,April 4, 2018 2:52 PM To: Regg,James B (DOA);AK, OPS EOC Specialists;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OIL;AK, OPS FS2 Field OTL;AK, OPS FS2 OSM;AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL;G GPB FS2 Drillsites; Nottingham, Derek; Summers, Matthew Cc: Wallace, Chris D (DOA);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; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J Subject: OPERABLE: Producer 03-08 (PTD#1760730)Well Lock squeeze fixed OA repressurization external-email: 0 SCANNED ° All, Producer 03-08 (PTD#1760730)was placed Under Evaluation on 03/28/18 to put on production and thermal cycle the well to evaluate a Well Lock repair on the outer annulus. Operations brought the well online on 03/29/18.The well was subsequently thermal cycled on 04/02/18 and 04/03/18.The OA showed no pressure response during the cool down cycle.The lack of pressure response on the OA indicates the Well Lock squeeze successfully repaired the repressurization.The well is now classified as OPERABLE. Work Completed: 1. Special Projects: Pump well lock squeeze- DONE 2. Operations: Put on Production- DONE 3. DHD: Monitor- DONE 4. Operations:Shut in when requested by optimization engineer- DONE 5. DHD: Monitor for repressurization during cooling cycle—DONE Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 From: A , • Well Integrity Engineer Sent: Wednesday, 8, 2018 10:50 AM To: 'Regg, James B (DOA) (ji . -••@alaska.gov)'; AK, OPS EOC Specialists; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; 'PS FS2 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; G GPB FS2 Drillsites, • ingham, Derek; Summers, Matthew Cc: 'chris.wallace@alaska.gov'; AK, GWO Completion ell Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO We - rity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, Davi. , ' ckerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis 3; Munk, Corey; Obrigewitch, Beau; O'connor, - ine; Romo, Louis A; Sternicki, Oliver R; 1 11=1;t1 STATE OF ALASKA , 0 MAR 2 8 2018 ALASKA OIL AND GAS CONSERVATION C SIGN REPORT OF SUNDRY WELL OPE ONS — 1. Operations Performed �� Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 OperatiorPs sht7tffo C ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Repair Well II Re-enter Susp Well 0 Other:OA Welllock Squeeze El 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 176-073 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20231-00-00 7. Property Designation(Lease Number): ADL 028327,028328,028331 8. Well Name and Number: PBU 03-08 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 10370 feet Plugs measured None feet true vertical 9339 feet Junk measured 9829,9851,10225 feet Effective Depth: measured 10225 feet Packer measured 8821,9298 feet true vertical 9217 feet Packer true vertical 8053.8442 feet Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20" 34-114 34-114 1530 520 Surface 2675 13-3/8" 33-2708 33-2707 5380 2670 Intermediate Production 10306 9-5/8" 31-10337 31-9311 6870 4760 Liner Perforation Depth: Measured depth: 9604-9920 feet t True vertical depth: 8697-8962 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#x 5-1/2"17#13Cr80/L-80 29-9423 29-8545 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Packer 8821 8053 true vertical depth) 5-1/2"Baker S-3 Packer 9298 8442 12.Stimulation or cement squeeze summary: Intervals treated(measured): OA Cemented to surface. OA down sqz performed with HES WeIlLock.Continued process at 30 min intervals until hardening time of 10.5 hours. Well sample is the consistency of cold maple syrup after 7 days of monitoring(03/15/2018). Treatment descriptions including volumes used and final pressure: Pumped 2.5 gallons of WeIlLock into OA.Final Pressure=540 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 155 705 6055 1386 247 Subsequent to operation: No Test Available 540 0 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory 0 Development QI Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 318-011 Authorized Name: Summers,Matthew Contact Name: Summers,Matthew Authorized Title: Production Engineer Contact Email: Matthew.Summers@bp.com Authorized Signature: '— d 222 /)p Date: ,3/ '?//� Contact Phone: +1 9075645066 Form 10-404 Revised 04/2017 l� i /�/ RBDMS IAR 2 9 2018 Submit Original Only 410 • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report Of Sundry Well Operations (10-404) March 28, 2018 To Whom it May Concern: Attached please find the Report Of Sundry Well Operations for Repair Well (OA Welllock Squeeze), covered under Approved Sundry #318-011 for Well PBU 03-08, PTD #176-073. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 * S Daily Report of Well Operations PBU 03-08 ACTIVITYDATE SUMMARY T/I/O= SSV/630/340. Temp= SI. Bleed IAP &OAP to 0 psi. (pre WeIlLock). ALP = 1350 psi,AL SI @ casing valve. IA FL near surface. OA cemented to surface. Bled IAP from 630 psi to 0 psi to BT in 15 minutes. (gas/fluid). Bled OAP from 340 psi to 0 psi in <1 minute to BT, held open bleed on OA for 30 minutes. During 30 minute monitor, IAP increased 3 psi and OAP increased 6 psi. Heater in wellhouse upon departure. Bled treecap to 0 psi. Final WHPs = SSV/3/6. 3/5/2018 SV, WV, SSV= C. MV= O. IA, OA= OTG. 11:00 T/I/O = SSV/110/0. Temp Well S/I. OA spool temp=68° Job Scope: OA down sqz w/HES WeIlLock. Pumped 0.5 gallons of WeIlLock into OA before seeing returns from opposing casing port. Installed hydraulic filled manifold with Ascroft gauge on return side for monitoring pressure on OA. 1.5 gallons into annular space before pressure began rising. Once at recommended squeeze pressure monitored at 15 min intervals over 3 hours period. Continued process at 30 min intervals until hardening time of 10.5 hours. Bled down to 1000 psi, re-pressured to 1800 psi and left pressure on OA. Daily monitors will be conducted by DHD getting pressures and temp on spool piece for seven days. Well secured and DSO notified of well condition. Note: Caution tags hung on both sides of OA stating Viton seals in 1502 connections temp rating of 20 deg F thru 400 deg. F. Post WeIlLock Treatment. ***Activity complete*** 3/6/2018 T/I/O = SSV/110/0. Temp Well S/I. OA spool temp=68° Job Scope: OA down sqz w/HES WeIlLock. Pumped 0,5 gallons of WeIlLock into OA before seeing returns from apposing casing port. Installed hydraulic filled manifold with Ascroft gauge on return side for monitoring pressure on OA. 1.5 gallons into annular space before pressure began rising. Once at recommended squeeze pressure monitored at 15 min intervals over 3 hours period. Continued process at 30 min intervals until harding time of 10.5 hours. Bled down to 1000 psi and left pressure on OA. Daily monitors will be conducted by DHD getting pressures and temp on spool piece for seven days. Well secured and DSO notified of well condition. Note: Caution tags hung on both sides of OA stating Viton seals in 1502 connections temp rating of• 20 deg F thru 400 deg. F. Post WeIlLock Treatment. ***Activity complete*** 3/6/2018 T/I/O = SSV/250/1320. Temp= SI. WHPs (Post Wellock squeeze). ALP = 1040 psi, SI @ CV. Heater in wellhouse working properly, wellhouse door is open —16". Wellock sample is still liquid. Temp from thermomotor on wellhead at the 11 o'clock position reading 50*. 3/7/2018 SV, WV, SSV= C. MV= O. IA, OA= OTG. 09:30 T/I/O = SSV/400/300. Temp= SI. WHPs (Post Wellock squeeze). ALP= 750 psi, SI @ CV. Heater in wellhouse working properly. Lower wellhouse door was fully open on arrival. Closed and wired door open —16". Wellock sample has the consistancy of soft caramel. Temperature from thermometer on wellhead at the 11 o'clock position reading 10°. IAP increased 150 psi, OAP decreased 1020 psi from 3/7/18. 3/9/2018 SV, WV, SSV= C. MV= O. IA, OA= OTG. 01:00 T/I/O= SSV/500/300. Temp= SI. WHPs(Post Wellock squeeze). ALP =650 psi, SI @ CV. Heater in wellhouse is working properly. OA spool temp= 34°. Adjusted heater hose. Door wired partially open. Wellock sample is soft but not runny IAP increased 100 psi overnight. 3/10/2018 SV, WV, SSV= C. MV= O. IA, OA= OTG. 15:00 hrs. T/I/O = SSV/500/1300. Temp= SI. WHPs(Post wellock). AL SI @ casing valve (500 psi). Heater working properly. Casing spool temp = 55*. Adjusted door and heater. Sample is semi hard. 3/11/2018 SV, WV, SSV= C. MV= O. IA, OA= OTG. 1530 hrs. 4 • • Daily Report of Well Operations PBU 03-08 T/I/O= SSV/540/520. Temp= SI. WHPs (Post wellock). AL SI @ casing valve (540 psi). Heater working properly. Casing spool temp=45*. Adjusted door and heater. WeIlLock sample Semi- hard at this time. 3/12/2018 SV, WV, SSV= C. MV= O. IA, OA=OTG. 08:30. T/I/O= SSV/1770/580. Temp = SI. WHPs(Post Wellock). ALP =620 psi, SI @ CV. Heater working properly. Casing spool temp= 90*. Wellock sample is tacky and viscous. IAP increased 40 psi, OAP increased 1250 psi overnight. 3/13/2018 SV, WV, SSV= C. MV= O. IA, OA= OTG. 15:40 T/I/O = SSV/540/950. Temp = SI. WHPs(Post Wellock). AL SI @ casing valve(620 psi). Casing spool temp= 85*. Well sample is viscous like cold honey. The OAP increased 370 psi overnight. 3/14/2018 SV, WV, SSV= C. MV= O. IA, OA= OTG. 1645 hrs. T/I/O= SSV/550/460. Temp= SI. WHPs (Post Wellock). AL SI @ casing valve (620 psi). Casing spool temp= 78*. Well sample the consistency of cold maple syrup(sample temp @ 42*on arrival, moved to bottom lip of spool). The OAP decreased 490 psi overnight. 3/15/2018 SV, WV, SSV=V. MV= O. IA, OA=OTG. 0945 hrs. T/I/O=SSV/650/0. Post Wellock. N/D integrals and block valves from OA and N/U 3" CIW FL and 3" tapped blind. PT to 500 psi. Pass. ***Job Complete***See log. Final WHP's SSV/650/0. Note: NO 3/18/2018 VR PLUG IN PIT SIDE OA PROFILE. ***WELL S/I ON ARRIVAL***(cement squeeze) SET 4-1/2" WHIDDON ON PLUG @ 8,835' MD PULLED RK-DGLV'S FROM ST#4 @(4,908' MD) &ST#5 @ (2,991' MD) SET RK-LGLV'S IN ST#4 @ (4,908' MD) &ST#5 @ (2,991' MD) PULLED EMPTY WHIDDON FROM 8835' MD PULL PX PLUG FROM X-NIPPLE @ 8,835' MD 3/19/2018 ***WELL S/I ON DEPARTURE*** Fluids Summary Bbls Type 2.5 WeIlLock Resin 1 Diesel ,TREE 41/$" • a3-os �► WELLHEAD_ FMC: • FETY NOTES: ""4-112'GF#tOM E TUBING,"" ACTUATOR= BAKER C OKB.ELEV= 61' � Bim' 1 • ►� 2088' H4-1/2"FES XKIP,D=3.813" KOP= 3200 Max Angle= 36"©8800' As 2248' H9-5/8"HES ES CATER 4110 Datum MD= 9800' -tieTVD 8800'SS y� 2326' {95/8"FOC 9-5/8"CSG,47#,L-80,TC-N,in=8.681"H 2257' 2451' —I9 5/$"FOC GAS LFT MASS ST MD TVD DEV TYPE VLV LATCH FORT DATE 13-3/8"CSG 72#,MN-80,1:1=12.347" --j 2708' 5 2991 2990 5 MMG DOME RK 16 03/19/18 4 4908 4776 29 MMG DOME RK 16 03/19/18 Illn 3 6362 6021 33 MMG SO RK 28 02/23/16 2 7524 6987 35 MMG DMY FK 0 09/02/10 Minimum ID =2.79" @ 9214' 1 8719 7970 35 MMG DM( FE 0 02/17/07 5-1/2" ALPHA TBG PATCH 1 8790' H4-1/2"HES XNIP,D=3.813" �� ( 8811' —j9-5/8 x 4-1/2'BKR S-3 PKR D=3.870" I 8836' —{4-1/2'HES X MP,D=3.813" 5.1/2"TBG STUB,D=4.892 — 8864' 4-1/2"TBG 12.6#13CR-80, H 8883' - 8883' —14-1/2'WLEG,D=3.958" VAM TOP, .0152 bpf,D=3.958' ST MD ND DEV TYPE VLV LATCH PORT DATE TOC DONUT,D=2.79"(TAGGED 01/04/99) —{ 9115' 8 8916 8129 36 WAG SO RK 28 02/23/01 �,� "`: 9 9071 8256 36 WAG OMY !�( 0 11/13/76 �+► 1.�I 10 9229 8385 35 MMG *OCR RKP 0 08117/89 II 5-1/2"TBG-PC 17#,L-80,.0232 bpf,D=4.892' i 9423' x► ,I ORIGNVAL WELLBORE-'BEI-00 TBG PATCH l`I, 1.♦ II V' 1,♦ PERFORATION �. ISI § • 9214'-9236' —5-1/2"X 21'ALPHA TBG PATCH REF LOG:BRCS ON 11/06/76 I`1,C• mircle e," D=2.79"(02/25/99) /I ANGLE AT TOP TEFF:33 @ 9604' ISI ��I ( 9298• — 95/8"X 5-1/2"BKR S-3 PKR D=6.000" ►�� y►�/ Pie:Refer to Production 06 for historical perf data 1 SIZE SPF N1BR'/AL Opn/Sgz SHOT SQZ y 3-3/8" 6 9604-9636 0 11/02/87 - 9408' H 5-1/2'OTIS XN P.1'D=4.455' 3-3/8" 4 9732-9772 0 01/10185 3-3/8" 4 9774-9788 0 01/10/85 4 9774-9788 S 03/11/82 01/04/85 - 9422' —5-1/2"BKR SFEAROUT STUB 3-3/8" 4 9789-9793 0 11/02187 3-3/8" 4 9804-9829 0 01/10/85 9423' -15-1/2"WLEG,D=4.892" 4 9804-9829 S 05/14/77 01/04/85 9414' --{ELMD TT LOGGED 11/02/87 3-3/8" 4 9831-9842 0 01/10/85 I 4 9831-9842 S 03/11/82 01/04/85 3-3/8" 4 9850-9860 0 01/10/85 4 9850-9860 S 05118(77 01104/85 v I 9829• H FSH-5116"RKP(11/02/91) 3-3/8' 4 9870-9875 0 01/10/85 4 9870 9875 S 05/14/77 01/04/85 9851' -FISH-BPRUBBE'2ELBNB/T(01/18/99) 2" 6 9910-9930 0 03/13/01 ' 4 9911-9946 S 05/14/77 01/04/85 3-3/8' 1 9914-9920 0 11/02/87 4 9960-9980 S 05/14/77 01/04/85 10225' —FISH-2 CA-FTT-RK's(08/17/89) •IF I f I`I in IIIIII�II �►AI+IoI�INioloo e e e 10225' -I PBTD e eee 11.111 ►NNA%% 10370' --I TD 9-5/8"CSG 47#,MN-80,D=8.681" — 10332 DATE REV BY OOMMDITS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/13/76 ORIGINAL COMPLETION 0122/18 OG/JVD SET PX RUG(01/15/18) WELL: 03-08 11/12186 FANO 01/23/18 DG/JMD GLV C/O(01/16/18) PERMIT No:9760730 02/18107 N4BS FANO 03/22/18 JMG/JMD GLV C/0&FULLED PX PLUG AR No: 50-029-20231-00 03/30/07 GJBIPJC DRLG DRAFT CORFECTIOT4S SEC 11,T1ON,R15E,1199'FSL&837'E1ML 11/20/14 PJC FERFORAT1ON LRAMS 02/29/16 JRVJMD GLV C70(02/23/16) BP Exploration(Alaska) • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, March 28, 2018 10:50 AM To: Regg,James B (DOA);AK, OPS EOC Specialists;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL;AK, OPS FS2 Field OTL;AK, OPS FS2 OSM;AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL;G GPB FS2 Drillsites; Nottingham, Derek;Summers, Matthew Cc: Wallace, Chris D (DOA);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; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J Subject: UNDER EVALUATION: Producer 03-08 (PTD#1760730) POP to evaluate OA well lock squeeze. external-email: 0 All, Producer 03-08 (PTD#1760730) has an outer annulus that is cemented to surface.The well was made Not Operable on 01/10/18 for having outer annulus repressurization by an external source that is not manageable by bleeds. On 03/06/18 special projects performed an OA squeeze with well lock in accordance with approved Sundry#318-011.The well lock has had time to cure and the well is now ready to be put on production to monitor the success of the squeeze. Because the OA repressurization would take place during a cooling cycle,the well will need to undergo a thermal cycle during the evaluation period.The well is now reclassified as Under Evaluation and is on the 28 day clock for monitoring. Plan forward/Work Completed: 1. Special Projects: Pump well lock squeeze- DONE 2. Operations: Put on Production 3. DHD: Monitor 4. Operations:Shut in when requested by optimization engineer 5. DHD: Monitor for repressurization during cooling cycle Please respond if in conflict. SCOSej Andrew Ogg Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 From: AK, GWO Well -- Engineer Sent: Sunday, January 07, 20 •42 PM To: 'Regg,James B (DOA) (jim.regg@a - •ov)'; AK, OPS EOC Specialists; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS F 64• AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Chamansingh, Ann Marie; G GPB 'rillsites; Nottingham, Derek; Ohms, Danielle H; Stechauner, Bernhard; Richards, Meredyth Cc: 'chris.wallace@alaska.gov'; AK, GWO Completions Well Integrity; AK, G 711_F-®D Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Informatio a OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski— , rrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R; Te- Joshua; 1 • tiOF 7.4 0,I//j��s,, THE STATE Alaska Oil and Gas F '�►'�-�► � of jLAj TA Conservation Commission 333 West Seventh Avenue 117 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 \T" O Q+ Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Travis Montgomery Interventions and Integrity Engineer same FEB. J 6,2 0 a BP Exploration(Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-08 Permit to Drill Number: 176-073 Sundry Number: 318-011 Dear Mr. Montgomery: Enclosed is the approved application for sundry approval relating.to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French 4 Chair DATED this�`� day of January, 2018. RE3DI i3 L - 1 2C18 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI ON APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 . Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other OA r ement�Squeeze 0 ' 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number. 176-073 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory El Development D 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20231-00-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 PBU 03-08 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028327.028328&028331 PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10370 • 9339 • 10225 9217 None 9829,9851,10225 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 34-114 34-114 1530 520 Surface 2675 13-3/8" 33-2708 33-2707 5380 2670 Intermediate Production 10306 9-5/8" 31-10337 31-9311 6870 4760 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9604-9930 8697-8970 #4-1/2"12.6#x 5-1/2"17# 13Cr80/L-80 29-9423 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and TVD(ft): 8821/8053 5-1/2"Baker S-3 Packer 9298/8442 12.Attachments: Proposal Summary RI Wellbore Schematic p 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development RI Service 0 14.Estimated Date for Commencing Operations: February 1,2018 15. Well Status after proposed work: Oil 0 • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Montgomery,Travis J be deviated from without prior written approval. Contact Email: Travis.Montgomery@bp.com Authorized Name: Montgomery,Travis J Contact Phone: +1 907 564 4127 Authorized Title: Interventions&Integrity Engineer/� AA Authorized Signature: / /�„ s Date. 8(�C/� 1>�� V COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 6 NEDOther: Post Initial Injection MIT Req'd? Yes 0 No ImoJANrc 10 2018 Spacing Exception Required? Yes 0 No I3'/ Subsequent Form Required: /b— 40 /J 0 , r I l•Nc, I �� APPROVED BYTHE AOGCC Approved by: COMMISSIONER COMMISSION Date: 1 /fin!Iej v-rt //az,f/ JRIGINAL �� Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. //rt��/ Attachments in Duplicate/ r (O ., -1,/z:lt., • • .44 00 Well: 03-08 03-08 OA Cement &WeIlLock Squeeze Well Interventions Engineer: Travis Montgomery (918) 281-9663 Pad Engineer: Matt Summers (907) 952-1682 History Well 03-08 is a gas-lifted Zone 4 producer. The well's fully-cemented OA was treated with WeIlLock on 5/4/15 to mitigate the unmanageable OA repressurization that was seen when the well was on production. The well currently exhibits unmanageable OA repressurization when shut-in. The source of the repressurization appears to be external. IA & OA gas compositions do not match. A cold PPPOT-IC Passed on 12/31/17. OAP exceeds IAP. Current Status The well is classified as "Not Operable" by BP due to the OA pressurization. The well is therefore currently shut-in until the leak is fixed. Objective Squeeze the OA with WeIlLock to mitigate OA pressurization. , Procedural steps Special Projects — OA WeIlLock Squeeze 1. ND OA Gate Valves, NU OA Integrals. 2. Bleed annuli (bleed IA as low as possible). 3. Prep OA, WeIlLock OA top job squeeze to 2500 psi per RP "WeIlLock Treatment for Cemented OAs." 4. After 1 week cure, ND OA Integrals, NU OA gate valves. TREE= 4-1/9"CNV FLS 0 • V*111-FAD.. FMC 0 3-0 8 , ... . SAFET Y NO TES_ 4-1(2 CHROME TUBING"" ACTUAlUit= BAKER C 0103.BEV= 61' :.,‘ BE REV -- - '#_, . j 2088' ---4-1/2"FES X P4F,10 3.813- i • KOP= 3207 = IA3z Angle= 36";Z*8800 4' ....,,-. 2248' i-9-5/8"FES ES CUAENTER 1 Datum W= 98017 .i* Datum IVO= 8800'SS tie...4 23-iffl _He-5/8'FOC mm-.1 2451' -9-5/8FOC I 9 519'(S(i,41N,I -80,TC-11,n)-81931"- 2257' I GAS LFT MANDRELS ST WI IVO OW TYPE VI V IA ECA-1 PORT (ATT- 13318-CSG 720,MN-80,F; 17-)4c ' 2 7087-1 5 2991 299U 5 WAG 00Ik RK 16 09102110 4 4908 4776 29 16/G DOME RK 16 09/02/10 Lill 3 6362 6021 33 MAC SO Plc 28 02/23116 2 7524 5987 35 AVG DLIV RK 0 09/02/10 Minimum ID = 2.79" f; 9214" I 1 8719 7970 35 WAG [LW RK 0 02/17/07 5-1/2" ALPHA TBG PATCH ... 8790' -4-1/2"FES X NP,13=3.813" ; 1 i 1 <" >"‹. 8811' --19-578 x 4-172'BKR S-3 P(R,CI=3 813" ; 1 1 8896' -4 1/2"FE.S X NIP,1() 3(113" [-&----177 TBG S7113,10-4 892 --i, 8884' ........„„.... . _._ 4-10"THG 1284113CR•130, 1 ;;8Y , 8:;3±1-14-1/2"AtE0,ID=3_050- I VA M TOP, ;0152 bor.ID=3.958 S I 1 P.40-7-wl) DEV TYPE V LV LATCH PORT DATE i roc DONUT ID-2 79"(TAGGED 01104/99) alCaC - 88616 817"), 36 ; A/IMG SO RF( 28 02/23/01 I orNi rAr 9 9071 ;8256 36 ; MMG DIAY RK 0 11/13/78 e 1 % e 10 L 9229;83051 35 1 WAG 'OCR RKP 0 08/17/88 5-1/2'TBG-PC 170,L-80,..0232 Opt 13=4.;,-:r - 114.23' 0%,.. — #40 ORKiINALYYLL LBORE-'BE t)TOG PATCH ;if *IP IP it-To FETT-CRATIONSLIWARY 4 4%, 9214'-9236' --5-112"X 21'ALPHA 113G FTC11 flo ir-I +1- ID=2 79'(02/25/99)LOG Ell-CS ON 11/06/76 •111 im).A. dir 1 ., ANGLE AT TOP HEW 331'9604' JP C. /../ 9298' -19-5/8"x 5-1/2"BKR S-3 FKR,U---6 000' An. 1 We:Refer to Production[B for historical ped data k a.. SIZE SFF tITERVAL 0pn/Sqz SWT SQZ t i e 1 _ 3-3/8' 6 9604-9636 0 11/02/8784or 5-1/2"OTIS XN NIP,13=4 455- 3-3/8" 4 9732-9772 0 01/10/85i \ I 1 3-3/8' 4 9774-9788 0 01/10185 \ 4 9774-9788 S 03/11/82 01/04/85 \ 9422 -1 5-1/2"BKR SI-IEAROUT Sill 3-3/8' 4 97;-;:-9793 0 11102/87 / \ -15-1f2'%MEG,10-4:•-:2" 3-308' 4 9804-982'9 0 01/10/85 4 9804-9829 S 05/14/77 01/04/85 9414' 1--ELMO TT LOGGI)11/02/87 33/8' 4 9831-9842 0 01/10/85 4 9831-9842 S 03/11)82 01/04/85 3-3/8" 4 1.;50-9660 0 01110985 4 9650-9060 S 05/18/77 01/04/85 461r 9929' -FISH-5716" 6CP(11102/91) 3-3/8' 4 'A;70-9875 0 01/10185 At' I 9661' F184-I E3P14080-FR Fi WEN!(OM; . ) 4 9870-9875 S 05/14/7 01/04/85 7. 6 9910-9930 0 03/13/01 4 9911-9948 S U5/141/1 U1/04/ti5 11 3-3(8" 1 9914-9920 0 11/02837 I 4 9960-9980 S 05/14/77 01/01/85 10226' H FISH-2 CA-RD-RX's(08/17/84) 10225' STD I ; _ .... _ 4.- r 1 ;•s;Aj 1037C/ - TD ,- 19-518"CSG 47#,ht4-80,13-8_681" I- 10337' DA TE REV BY CON&ENTS DATE I REV BY CO\oRENTS FIM]-IOE BAY UNIT , i 11113/76 ORIGINAL COM PLET1ON 11/20/14; RIC PERFORATION JEIDA 1R, WELL 03-08 11/12186 RINO .02/29/18f1PK/JIAD GLV C/O(02/22./16) .P146.41;Nix'1760/30 ,02/18107 NOES IWO , AR No: 50-029-20231-00 03i05/07 7/MINS'CRLG DRAFT C7JRRECT1' ONS ' SEC 11,T1011,R15E,11917 FSi &837"FW I r03/21/07 JOM/T11-1 RH.BP/GIN GO(03/19/07) 03130107 GJB/F0C DRLG DRAFT CORRECTIONS , -; BP Exploration (Alaska) 2 • S Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday,January 7, 2018 12:42 PM To: Regg,James B (DOA);AK, OPS EOC Specialists;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL;AK, OPS FS2 Field OTL;AK,OPS FS2 OSM;AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL;Chamansingh,Ann Marie; G GPB FS2 Drillsites; Nottingham, Derek;Ohms, Danielle H; Stechauner, Bernhard; Richards, Meredyth Cc: Wallace, Chris D (DOA);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; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J Subject: NOT OPERABLE: Producer 03-08 (PTD#1760730) anomalous OA repressurization not manageable - All, Producer 03-08(PTD#1760730) was put Under Evaluation on 12/10/17 to evaluate outer annulus repressurization after being shut in.The well was subjected to thermal cycles and DHD monitored the pressure build up rate of the outer annuls after being shut in.The monitors have proved that the pressure build up rate exceeds the maximum allowable to keep the well operable.The well will remain shut in and reclassified to NOT OPERABLE. Plan Forward: 1. Anchorage Engineer: Evaluate for Well lock squeeze. 2. Slickline (Pending):Secure well if Well lock job not possible. Please respond if in conflict. Andrew Ogg u Well Integrity Engineer SCANNED ` ' `` BP Global Wells Organization-Alaska Office:907-659-8110 Cell:307-399-3816 From: AK, GWO Well Integr seineer Sent: Sunday, December 10, 2017 •.! AM To: AK, OPS EOC Specialists; AK, OPS FS2 6 ••s Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS FS2 OSM; AK, RES GPB East Wells Opt Engr; AK, RES °. est Wells Opt Engr; AKOpsProdEOCTL; Chamansingh, Ann Marie; AK, OPS FS2 Field OTL; Allderdice,Ted; Barndt, James M; =. ' in, Ryan G; Byers, Gary F; Elvsaas, Peter; Gandee, Thomas; Holm, Brian D; Howe, Blake M; Lorenz, Tracy M; Matthe onnie T; Maxon, Edward L; Mcclung, Steven R.; Mcqueen, Josh M; Morin, Justin J; Petersen, Frank; Phillips,Timothy; Pre - Sean; Reimer, Brian T; Shepard, Nathan; Smith, William D (CH2M HILL); Stahl, Randy; Weys, Michael (CH2M HILL); Whi -, tonald A; Williams, Wister 3; Wilson, Van R; Witt, Jenna; Nottingham, Derek Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects 1,z Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIM = •• User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; b. Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: UNDER EVALUATION: Producer 03-08 (PTD #1760730) anomalous OA repressurization All, 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday,January 2, 2018 1:19 PM To: Regg,James B (DOA) Cc: Wallace, Chris D (DOA);AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information Subject: NOT OPERABLE: Producer 03-08 (PTD#1760730) anomalous OA repressurization over NOL when shut in Mr Regg, Producer 03-08 (PTD#1760730) has an outer annulus that is cemented to surface.The well was placed under evaluation on 12/10/17 to address anomalous outer annulus repressurization (did not break NOL when discovered).The well shows rapid outer annulus repressurization for a short period as it goes through a cooling cycle after being shut in. During the diagnostic phase,the well was shut in on 12/30/17 to recreate the anomalous pressure event and on 12/31/17 the outer annulus pressure was reported above NOL with a pressure of 1,180 psi. Plan forward: 1. Town Engineer—Evaluate for well lock job to seal micro annulus in cement created during cooling cycle. Please respond if in conflict. Andrew Ogg c �1 , SCAN Well Integrity Engineer �Ert ° L, ;- BP Global Wells Organization-Alaska Office:907-659-8110 Cell:307-399-3816 From: , WO Well Integrity Engineer Sent: Sunday, •- -tuber 10, 2017 9:04 AM To: AK, OPS EOC Spe ists; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS FS2 OSM; AK, RES GPB East - Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Chamansingh, Ann Marie; AK, OPS FS2 Field OTL; Allderdic-, ed; Barndt, James M; Bowlin, Ryan G; Byers, Gary F; Elvsaas, Peter; Gandee, Thomas; Holm, Brian D; Howe, Blake ' , orenz,Tracy M; Matthews, Lonnie T; Maxon, Edward L; Mcclung, Steven R.; Mcqueen, Josh M; Morin,Justin J; Petersen, - _ k; Phillips,Timothy; Presley, Sean; Reimer, Brian T; Shepard, Nathan; Smith, William D (CH2M HILL); Stahl, Randy; Wey ichael (CH2M HILL); White, Ronald A; Williams, Wister 3; Wilson, Van R; Witt, Jenna; Nottingham, Derek Cc: AK, GWO Completions Well Integrity; AK, GWO DHD We itegrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, .: de; Montgomery,Travis 3; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua, orthington, Aras J Subject: UNDER EVALUATION: Producer 03-08 (PTD #1760730) anomalous 0 -•ressurization All, Producer 03-08(PTD#1760730) is exhibiting anomalous outer annulus repressurization when shut i The outer annulus is cemented to surface.The well was recently shut in on 12/03/17 and subsequently on 12/04/17 the 0 -quired three bleeds to keep from exceeding NOL.At this time the well will placed Under Evaluation and is on the 28 day c • for diagnostics.The plan forward is to subject the well to thermal cycles and have DHD monitor the OA to better un• tand the extent of repressurization. 1 • • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Tuesday, May 24, 2016 10:30 AM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL;AK, OPS FS2 Field OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Shrider, James; Regg, James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator; McVey, Adrienne; Wallace, Chris D (DOA) Subject: NOT OPERABLE: Producer 03-08 (PTD#1760730) Sustained OA Casing Pressure Above MOASP Attachments: Producer 03-08 (PTD #1760730) TIO Plot 2016-05-24.docx All, Producer 03-08 (PTD#1760730) was shut in on 05/20/16, and was reported to have sustained OA casing pressure above MOASP on 05/23/16. Pressures were confirmed to be TBG/IA/OA= Shut In/1900/1580 psi. Due to surface constraints, there are no plans to bring the well online in the near future.The well is reclassified as Not Operable. Plan Forward: 1. Downhole Diagnostics: Bleed IA and OA pressures—IN PROGRESS 2. Downhole Diagnostics: Monitor—IN PROGRESS 3. Operations: Leave well shut in A T/I/O plot is attached for reference. Please reply if in conflict with proposed plan. Thanks, SCANNED JUL 1 1 2Q16 Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C: (907)943-0296 H: 2376 Email: AKDCWeIllntegrityCoordinator(a)BP.com From. A D&C Well Integrity Coordinator Sent: Satur.. A ugust 08, 2015 9:42 AM To: AK, OPS FS2 OS ; - , •'S FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS PCC EOC TL; Cismoski, Doug A; Daniel, Rya ' • D&C Wireline Operations Superintendent; AK, D&C WL Completions Superintendent; AK, RES GPB East Wells Op - • AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Sinnok, Ralph; 'chris.wallace@alaska.gov Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Int g rdinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sayers, Jessica; Pettus, Whitney; 'jim.re laska.gov' Subject: OPERABLE: Producer 03-08 (PTD #1760730) Well-lock Treatment CompI to 1 `� Producer 03-08(PTD#1760730) TIO Plot 05/24/16 Well o3-ce —s-- -A— +cu 00A +000A On Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, August 08, 2015 9:42 AM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS PCC EOC TL; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent;AK, D&C WL Completions Superintendent; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Sinnok, Ralph;Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sayers, Jessica; Pettus, Whitney; Regg, James B (DOA) Subject: OPERABLE: Producer 03-08 (PTD#1760730) Well-lock Treatment Complete Attachments: Producer 03-08 (PTD 1760730) TIO Plot.docx All, Producer 03-08 (PTD#1760730) outer annulus was treated with Well-lock product on May 04, 2015 to mitigate high outer annulus pressure that was previously found to be unmanageable by bleeds. The well was placed on production July 25, 2015 and monitored over the last two weeks. The outer annulus pressure has been found to be manageable by bleeds with minimal indication of buildup rate. The well is reclassified as Operable and may remain in service. A copy of the TIO plot is included for reference. Please call with any questions or concerns. Thank you, Whitney Pettus SCANNED AUG 1 02015 (Alternate: Kevin Parks) BP Alaska -Well Integrity Coordinator G WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: D&C Well Integrity Coordinator Sent: Saturda , 25, 2015 12:25 PM To: AK, OPS FS2 OSM;, SPS S DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team • KK D&C Well Services Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, C Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Sinnok, Ralph; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coors . or; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sayers, Jessica; Morrison, Spencer; 'jim.regg s - ka.gov' Subject: UNDER EVALUATION: Producer 03-08 (PTD #1760730) Ready to be place o . •suction All, 1 Producer 03-08 (PTD 1760730) TIO Plot August 08, 2015 • • i �a Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, July 25, 2015 12:25 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OIL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Sinnok, Ralph; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sayers, Jessica; Morrison, Spencer; Regg, James B (DOA) Subject: UNDER EVALUATION: Producer 03-08 (PTD #1760730) Ready to be place on production All, Producer 03-08 (PTD# 1760730) was treated with Well-lock product on May 04, 2015 to repair outer annulus repressurization that was previously found to be unmanageable by bleeds. The surface piping issue has been corrected and the well is ready to be put on production.The well has been reclassified as Under Evaluation to determine if the treatment was successful. The outer annulus pressure may exceed MOASP (1,000 psi) while determining the stabilization trend. Should the outer annulus pressure approach 2,000 psi, it will be bled off and a new approach developed. Please use caution when bringing the well online as the annuli are fluid packed. Plan forward: 1. Operations: Bring well online 2. DHD: Monitor outer annulus for stabilization pressure Please call with any questions or concerns, Thank you, SCANNED JUL 2 72015 Kevin Parks (fllterncite Whitney Pett:'• BP Alaska-Well Integrity Coordinator C l/VGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, D&C Tv- • -•rity Coordinator Sent: Saturday, July 04, 201 i. 0 'M To: AK, OPS FS2 OSM; AK, OPS FS2 DS •. ead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS PCC EOC IL; AK, D&C Wireline Operations Team Lead; A , .t Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS EOC 9- .lists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Sinnok, Ralph; 'chris.wallace@alaska.gov' 1 C r4.n„ V D STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMM. )N ��L 1 4 Z015 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed �-9 Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 �oTi5"sROtdn ❑ Suspend ❑ Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other Wellock Treament 121 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5 Permit to Drill Number 176-073 3. Address: P.O.Box 196612 Anchorage, Development ® Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20231-00-00 7. Property Designation(Lease Number): ADL 0028331 8. Well Name and Number: PBU 03-08 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 10370 feet Plugs measured None feet true vertical 9339 feet Junk measured See Attachment feet Effective Depth: measured 10225 feet Packer measured See Attachment feet true vertical 9217 feet Packer true vertical See Attachment feet Casing: Length. Size: MD: TVD: Burst: Collapse: Structural Conductor Surface See Attachment Intermediate Production Liner Perforation Depth: Measured depth: See Attachment feet p True vertical depth: See Attachment feet e3t?�78 0 Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 31'-2273' Treatment descriptions including volumes used and final pressure: 22 GALS WELLOCK 13. Representative Daily Average Production or Injection Data 011-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 150 0 5662 1584 274 Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 AAC 25 070 25 071,a 25 2831 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ® Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16 Well Status after work• Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C.O.Exempt: 315-179 Contact Summerhays,Nita (WIPRO Technologi..) Email Nita.Summerhays@bp.com Printed Name ummerha -, it M(WIPRO Technol..ies) Title Petrotechnical Data Manager / !//�� I., �'// Phone +1 907 564-4035 Date 07/14/2015 Form 10-404 Revised 5/2015 VTL 472 `2/ R8Dmi ��(glnal(�r�y 1 2015 Daily Report of Well Operations PBU 03-08 ACTIVITYDATE SUMMARY Road to location, RU to IA. Continued on 05-03-15 5/2/2015 T/I/O =SSV/30/0. Temp=SI. Wellock treatment(prep). heater in well house. Bled from SSV up to 0 psi, door left open. Removed—10 gallons of fluid from OA. Straped cement @ 80". SV, WV, SSV=C. MV=0. IA, OA= OTG. 17:00 5/2/2015 T/I/O =SSV/30/0. Temp=SI. Move heater to warm well conductor(SP). Installed heater in well house. Tree cap bled to 0 psi, door left open. 5/2/2015 SV, WV, SSV=C. MV=0. IA, OA=OTG. 02:45. T/I/O =XXXX. Temp= SI. Pump Wellock. 5/3/2015 Continued from 05-02-14 WSR , ***Performed Safety drill*** Pumped a 5 bbls meth spear and 670 bbls of 180*crude down the IA taking returns up the tubing to flowline thru SO at 6362'to warm the OA for OA Welllock treatment. Over Displacement of TxIA volume served as flowline freeze protect. Pressured flowline to 1500 psi. Bled back— bbls to Final WHP-0/0/0 Tags hung. AFE 5/3/2015 sign hung. T/I/O = SSV/0/0. Temp=SI. Wellock treatment. Began mixing wellock at 20:00. Assist Halliburton 5/3/2015 w/pumping of Wellock into OA. ***Continued on 5/4/15 AWGRS*** ***Job Continued from 5/3/15 WSR*** Assist Halliburton pumping Wellock, Musol &pressuring up cemented OA w/N2 (22 gals Wellock pumped into OA). Monitored WHPs during thermal chemical reaction. Bleed as needed. No bleed needed.Temp=81°. Final WHPs=SSV/Vac/600. 5/4/2015 SV, WV, SSV=C. MV=O. IA&OA=OTG. NOVP. 1355. T/I/O= SSVNAC/490. Temp= SI. WHPs(post wellock). Heater installed @ 9 o'clock. Temp @ 9 o'clock 83°. Temp @ 3 o'clock 63°. OAP decreased 110 psi overnight. 5/5/2015 SV, WV, SSV=C. MV= 0. IA, OA=OTG. 1230. T/I/O= SSVNac/510. Temp= SI. WHPs. (Well Lock). ALP= 1960 psi, AL SI @ casing valve. Heater installed @ 9 o'clock position. Temp @ 6 o'clock=83°. Temp @ 3 o'clock= 86°. OAP increased 20 psi over 7 hr period. Depressured SSV&tree cap void. 5/5/2015 SV, WV, SSV= C. MV=0. IA&OA=OTG. 19:40 T/I/O= SSVNAC/510. Temp= SI. WHP's(Wellock). Heater installed in wellhouse @ 9 o'clock position. WH Temp @ 3 o'clock position = 72°. OAP increased 20 psi overnight. 5/6/2015 SV, WV, SSV=C. MV=0. IA, OA= OTG. 1245. T/I/O= SSVNAC/500. Temp= SI. WHPs(post wellock). Heater installed in well house,working properly. Temp @ 9 o'clock 78°. Temp @ 3 o'clock 81°. OAP decreased 10 psi since 00:15. SV, WV, SSV=C. MV=0. IA, OA= OTG. 0700. 5/7/2015 T/I/O= SSVNAC/490. Temp= SI. WHPs(post wellock). Heater installed in well house,working properly. Temp @ 9 o'clock 115°. Temp @ 3 o'clock 86°. OAP decreased 20 psi overnight. SV, WV, SSV= C. MV=0. IA, OA= OTG. 19:55. 5/7/2015 T/I/O= SSVNAC/510. Temp= SI. WHPs (post wellock). Heater installed in well house,working properly. Temp @ 9 o'clock 115°. Temp @ 3 o'clock 86°. OAP increased 20 psi overnight. SV, WV, SSV=C. MV= 0. IA, OA= OTG. 00:15.. 5/7/2015 • Daily Report of Well Operations PBU 03-08 T/I/0 =SSVNAC/500. Temp= SI. WHPs(post wellock). Heater installed in well house, working properly. Temp @ 9 o'clock 110°. Temp @ 3 o'clock 90°. OAP unchanged. SV, WV, SSV=C. MV=0. IA, OA=OTG. 19:45. 5/8/2015 T/I/0= SSVNAC/440. Temp= SI. WHPs(Wellock). AL SI @ casing valve (1960 psi). Heater burner out, reset burners. Temp @ both 3 o'clock and 9 o'clock 52°. 5/9/2015 SV, WV, SSV= C. MV= 0. IA, OA=OTG. 1600. T/I/O=SSVNav/440. Temp= SI. WHP's (Wellock). AL SI W casing valve(1960 psi). Temp @ 3 o'clock position = 90*. Temp @ 9 o'clock position = 102*. 5/10/2015 SV, WV, SSV= C. MV= 0. IA, OA=OTG. 1650 hrs. T/I/0= SSVNAC/480. Temp= SI. Remove Heater from wellhouse- Release equipment. Pulled heater trunk from wellhouse&released heater. 5/13/2015 SV, WV, SSV= C. MV= 0. IA, OA=OTG. 1630 hrs. ***WELL S/I ON ARRIVAL***(new technology project) RIGGING UP SWCP DC-5 6/22/2015 ***CONT'D ON 06/23/15 WSR*** ***CONT'D FROM 06/22/15 WSR***(new technology project) PULLED RK-OGLV FROM ST#3 @ 6,362' MD.(check stuck open) SET RK-OGLV(28/64" ports) IN ST#3 @ 6,362' MD. PERFORMED PASSING MIT-T TO 2500psi. EQUALIZED&PULLED 4-1/2"XX PLUG IN X-NIPPLE @ 8,835' MD. 6/23/2015 ***WELL S/I UPON DEPARTURE, DSO NOTIFIED*** Fluids Summary BBLS Type 5 METH 670 CRUDE 1 DIESEL 676 Total Fluids Summary GALS Type 22 WELLOCK 22 Total Perforation Attachment PBU 03-08 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base 03-08 11/19/2014 BPS 9604 9636 8696.59 8723.39 03-08 • 11/19/2014 BPS 9732 9772 8803.92 8837.47 03-08 11/19/2014 - BPS 9774 9788 8839.15 8850 88 03-08 11/19/2014 BPS 9789 9793 8851.72 8855.07 03-08 11/19/2014 BPS 9804 9824 8864.29 8881.06 03-08 11/19/2014 BPS 9824 9829 _ 8881.06 8885.25 03-08 • 11/19/2014 BPS 9831 9842 8886.93 8896.16 03-08 ▪ 11/19/2014 BPS 9850 9860 8902.87 8911.27 03-08 11/19/2014 BPS 9870 9875 8919.66 8923.86 03-08 11/19/2014 BPS 9910 9911 8953.28 8954.12 03-08 11/19/2014 BPS 9911 9914 8954.12 8956.64 03-08 11/19/2014 BPS 9914 9920 8956.64 8961.69 03-08 11/19/2014 BPS 9920 9930 8961.69 8970.09 03-08 • 11/19/2014 BPS 9930 9946 8970.09 8983.54 03-08 11/19/2014 BPS 9960 9977 8995 32 9009 61 03-08 11/19/2014 BPS 9977 9980 9009.61 9012.13 AB ABANDONED MIR ISOLATED REMOVED APF ADD PERF MIS ISOLATED BPP PULLED MLK MECHANICAL LEAK BPS SET OH OPEN HOLE STRADDLE PACK, FCO FILL CLEAN OUT STC CLOSED STRADDLE PACK, FIL FILL STO OPEN SQUEEZE SQF FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER SAND PLUG PER PERF SPR REMOVED RPF REPERF Packers and SSV's Attachment PBU 03-08 SW Name Type MD TVD Depscription 03-08 PACKER 8820.67 _ 8052.41 4-1/2" Baker S-3 Perm Packer 03-08 PACKER 9298.27 8442 7-5/8" Baker SB-3 Packer as Q,o00000 Cp N IC CN- N-O CO 0ND O CDto N dNrCO N V 4i c) C) ON- O� v M • O) co 00 N - m r- CO CO I,- co CA N CO N O) N CO CO I� CO COCO CD — 0) 0) CO CON c7 CD N CD 0 N co co N - N 0) CO V m Q• OI S co C'r) CO r N 0) 8) M Ch Cc) NCOCON N CO C 0 • CO W F— a00 0 000000 O i CSD OD CO O En Z Z • CO• N U co Occ)L-6 NCV NI- P.- CON Cf) C<i O N CO0N CO Nt 0 D J a O _O O C F- w H H R 00 D < D D O O O O u_ O O Z Z Z r O O mODCLCLDD UcAaO- F 03-08 PBU 03-08 Junk Attachment SW Name MD Date Comments 03-08 9829 11/02/1991 5/16" RKP 03-08 _ 9851 01/18/1999 IBP Rubber Element 03-08 10225 08/17/1989 2 CA RD RK's TREE WB L= = 4-1/8'CAN RAC 03-08 I TY NOTES_ M 4-12'CHROM E TUBING-- • ACTUATOR= BAKER C OKB.R.B/= 61' �N �.BEV= —' _^ ` 'I` 2088' H4-112 HES X NP,ID=3.813' KOP= 3200' I, Max Angle=� 36' t, 8800' 2248' H9-5/8"HES ES CEME�rrER i Dahsn M)= 9800' ,` Datura TVD= 8800'SS 2326' -19-5/8-FOC 9-5/8"CSG,478,L-80,TC-1,ID=8.681'-I 225T 2461' H9-5/8'95/8'FOC GAS LFT MANDRELS ST IC TVD DE/ TYPE VLV LATCH PORT DATE 13-3/8"CSG 728,MN-80,13=12.347" -1 2708" 5 2991 2990 5 M14; DO16E RK 16 09/02/10 4 4908 4776 29 MG DOME RK 16 09/02/10 E 3 6362 6021 33 MAG SO FE 28 06/28/15 2 7524 6987 35 1W DIN FE 0 09/02/10 Minimum ID =2.79" la 9214' 1 8719 7970 35 MAG DIY RK 0 02/17107 5-1/2" ALPHA TBG PATCH 8790' H4-12'HES X142,D=3.813" 'NMI 8811' H9-5/8 x 4-1/2"BKR S-3 PKR,D=3.813" ' 8835' H4-12"FTS X NP,13=3.813' 5-1/2"TBG STUB,ID=4.892 H 8864 4-1/2"TBG 12.8#1308.110, (•--� 8883' 8883' H4-12'V11LEG,D=3.958' VAMTOP, .0152 bpf,D=3.958 !I ST MD ND DEV TYPE VLV LATCH PORT DATE (TOC DONUT,D=2.79'(TAGGED 01/04/99) H 9115' i 8 8916 8129 36 WAG SO RK 28 02/23101 -,i •�� 9 9071 8256 36 PAM DMY RK 0 11/13/76 �%'i \III 10 9229 8385 35 MMG 'OCR RKP 0 08/17/89 5-12"TBGPC 178,L-80,.0232 bpf,D=4.892' H 9423' a do ii.% ORIGINAL W LBORE BEND TBG PATCH _. I.I,y 11I1I PERFORAl1ON SUINARY .11.'1. II I 11 SI 9214'-9236' 5-1/2"X 21'ALPHA TBG PATCH D=2.79' 0225/99 REF LOG:BHCS ON 11/06/76 i i`■ mit% ( ) ANGLE AT TOP PERF:33 0 9604' I_I. I►�4 9298' 9-5/8"X 5-12'BKR S-3 PKR,D=6.000" Nob:Refer b RRoduction DB for hisbrical pert data SIZE SPF BR1/AL Cpn/S�t SHOT SQ,Z i 1 M 3-318' 6 9604-9636 0 11102/87 9408' H5-1/2"OTIS XN NP,D=4.455' 3-3/8" 4 9732-9772 0 01/1085 3-3/8" 4 9774-9788 0 01/10/85 4 9774-9788 S 03/1182 01104/85 9422 H5-12-BKR Sf-EAROUT SUB 3-3/8' 4 9789-9793 0 11/02/87 3-3/8" 4 9804-9829 O 01/10185 9423' -15-12'MEG,D=4.892' 4 9804-9829 S 05/14/77 01/04/85 9414' H ELMD TT LOGGED 11/02/87 3-3/8" 4 9631-9642 0 01/10/85 4 9831-9842 S 03/11/82 01/04/85 I 3-3/8" 4 9850-9860 0 01/10/85 4 9650-9660 S 05/18/17 01/04/85 - I 9829' H FISH-5/16'RKP(11/02/91) 3-3/8" 4 9870-9875 0 01/10185 4 9870-9875 S 05/14/77 01/04/85 9851' H FISH-BP RUBBER ELMENT(01/18/99) 2" 6 9910-9930 0 03/13/01 ' 4 9611-9946 S 05/14/77 01/04/85 3-3/W 1 9914-9920 0 11/02/87 4 9060-9980 S 05/14/77 01/04/85 10226' H FISH-2 CA-RD-RICs(08/17/89) . ....... Illlllll� I.I.II�III+I4, 10225' PBTD ..,‘,N.N,N,,N,teeeeee10370' -I 713 19-5/8"CSG 478,144-80,D=8.681" H 10337 DATE REV BY COMMENTS DATE RE/BY C01.0.1ENTS A D-IOE BAY UNT 11/13/76_ ORIGINAL COMPLETION 03/27/12 ?/PJC GLV CORRECTION WE L: 03-08 11/12/86 MO 08/22/14 DIYJAD TREE CIO(08/05/14) PERT Ha:9760730 02/18/07 ME RINO 11/18/14 LEC"PJC SET XX RUG AR No: 50-029-20231-00 03/05/07 ?/MWS DPW DRAFT CORRECTIONS 11/20/14 PJC PERFORATION URATES SEC 11,T1ON,R15E,1199'FSL&837'FWL 0321/07 JCIWTLH RLL BP/GLV CIO(03/19/07) 07/09/15 JAMJAD PULLED XX PLUG/GLV 00(0623/15) 03/30107'GJBIPJC DRLG DRAFT CORRECTIONS BP Exploration(Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWeIlIntegrityCoordinator@bp.com> Sent: Saturday, July 04, 2015 10:40 AM To: AK, OPS FS2 OSM;AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Sinnok, Ralph; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sayers, Jessica; Morrison, Spencer; Regg, James B (DOA) Subject: NOT OPERABLE: Producer 03-08 (PTD #1760730) Surface Piping Issues Attachments: image001.png All, Producer 03-08 (PTD#1760730) will not be placed on production within the 28 day Under Evaluation Clock to evaluate inner x outer annulus communication post well lock treatment due to surface piping issues. The well is reclassified as Not Operable until surface piping issues are resolved. Please call with any questions. Thank you, Kevin Parks (Alternate Whitney Pete • BP Alaska-Well Integrity Coordinator SCANNED JUL 0 6 2015 GWGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com Fro D&C Well Integrity Coordinator Sent: FridayJu 26, 2015 10:30 AM To: AK, OPS FS2 Or.OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Sinnok, Ralph; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sayers, Jessica; 'jim.regg@alaska.gov'; Morrison, Spencer Subject: UNDER EVALUATION: Producer 03-08 (PTD #1760730) Well-lock Treatment Complete All, Producer 03-08 (PTD# 1760730) was treated with Well-lock product on May 04, 2015 to repair outer annulus repressurization that was previously found to be unmanageable by bleeds.The well has been reclassified as Under Evaluation to determine if the treatment was successful. 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, June 26, 2015 10:30 AM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Sinnok, Ralph; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sayers,Jessica; Regg, James B (DOA); Morrison, Spencer Subject: UNDER EVALUATION: Producer 03-08 (PTD#1760730) Well-lock Treatment Complete Attachments: image001.png All, Producer 03-08 (PTD# 1760730) was treated with Well-lock product on May 04, 2015 to repair outer annulus repressurization that was previously found to be unmanageable by bleeds.The well has been reclassified as Under Evaluation to determine if the treatment was successful. The outer annulus pressure may exceed MOASP (1,000 psi) while determining the stabilization trend. Should the outer annulus pressure approach 2,000 psi, it will be bled off and a new approach developed. Please use caution when bringing the well online as the annuli are fluid packed. Plan forward: 1. Operations: Bring well online 2. DHD: Monitor outer annulus for stabilization pressure Please call with any questions or concerns, Thank you, SCANNED JUL 0 12015 Kevin Parks (Alter nate: Whitney Pettu,. BP Alaska-Well Integrity Coordinator I A I Global Wells V V Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Wednesday, November 19, 2014 3:19 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; chris.wallace@alaska.gov, G GPB FS2 Drillsites; Vohra, Prachi; AK, OPS FS2 Field OTL Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; 'jim.regg@alaska.gov'; AK, OPS FF Well Ops Comp Rep Subject: NOT OPERABLE: Producer 03-08 (PTD #1760730) Outer Annulus Repressurization-Secured 1 All, Producer 03-08 (PTD# 1760730) has been secured with a tested tubing tail plug.The well has been reclassified as Not Operable. Plan forward: 1. APE to evaluate methods of managing Outer Annulus repressurization. Thank you, Kevin Parks (Alternate Laurie Climer) BP Alaska-Well Integrity Coordinator GM A/ Global Wells �/�/ Organization Office: 907.659.5102 WIC Email:AKDCWelilntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Sunday, November 02, 2014 3:21 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; 'chris.wallace©alaska.gov'; G GPB FS2 Drillsites Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; 'jim.regg©alaska.gov'; AK, OPS FF Well Ops Comp Rep Subject: UNDER EVALUATION: Producer 03-08 (PTD #1760730) Sustained Outer Annulus Casing Pressure Above MOASP All, Producer 03-08 (PTD#1760730) was reported to have sustained outer annulus casing pressure above MOASP on 11/02/2014. The pressures were reported to be tubing/inner annulus/outer annulus of 235/1600/1200 psi. The outer annulus pressure build up rate is unmanageable by bleeds. The well is reclassified as Under Evaluation and placed on a 28 day clock. Plan forward: 1. Slickline: Set tubing tail plug for secure A copy of the TIO plot is included for reference. Thank you, Jack Disbrow (Altera,- 1r17,;-; : BP Alaska -Well Integrity Coordinator G{/�/ Global Wells �/ Organization Office: 907.659.5102 WIC Email:AKDCWelllntegrityCoordinator@bp.com 2 • OF Tkn , �w\,\\��jy�s� THE STATE Alaska Oil and Gas � •� of Conservation Commission i - = ALASI�:A • t s re=_' 333 West Seventh Avenue ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF Main: 907 279.1433 ALAS e. Fax 907.276.7542 www.aogcc.alaska.gov 1 Jessica Sayers Engineering Team Leader BP Exploration(Alaska), Inc. 1-7(p-(3--1 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-08 Sundry Number: 315-179 Dear Ms. Sayers: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4 /°;?-4 (.1--- Cat y P Foerster Chair DATED this 2i� of April, 2015 Encl. ` RECEIVED ` STATE OF ALASKA MA \ LSU.; ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS, 20 AAC 25-280 ,_(� 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair WeltE Change Approved Program Suspend❑ Plug Perforations❑ Perforate El Pull Tubing❑ Time Extension❑ ph micro 4.�y�k�� Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other Well Lock�eegnelegy LI ' 2 Operator Name. 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development 0 • 176-073-0 • 3 Address: Stratigraphic ❑ Service ❑ 6.API Number P.O.Box 196612,Anchorage,AK 99519-6612 50-029-20231-00-00 • 7 If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? PBU 03-08 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number). 10.Field/Pool(s): ADL0028331 • PRUDHOE BAY, PRUDHOE OIL• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10369 • 9338 • 8835 8064 8835 See Attachment Casing Length Size MD TVD Burst Collapse Structural Conductor 81 20"94#H-40 33 05-113.8 33.05-113 8 Surface 2677 13-3/8"72#N-80 32.55-2709.55 32.55-2708.95 4930 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner None None None None None None Perforation Depth MD(ft): Perforation Depth TVD(ft). Tubing Size. Tubing Grade. Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13 Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 4/7/15 Commencing Operations: Oil 0• Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval. Date: WINJ ❑ 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 Jessica Sayers Email Jessica.Sayers@BP.Com Printed Name Jessica Sayers Title Well Intervetions Engineer Signature . 564-4281 Date 3 O�/ Prepared by Garry Catron 564-4424 I •I COMMISSION USE ONLY Conditions of approval. Notify Commission so that a representative - witness Sundry Number. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No V Subsequent Form Required: /C — q c q_ APPROVED BY Approved by. p9COMIvy�SIbE�t G I �TACpMMISSION Date. 4 —Z —1 S v'r1- 3/ 3 //5 U lRJ I I\'1 L M ,116 Form 10-403 Revised 10/2012 Approved application is valid for 12 months from the date of proval. Submit Form and Attachments in Duplicate RBDMSAPR - 6 2015 Ai , - JUNK SUMMARY ADLO312828 SW_NAME MEAS_DEPTH MEAS_METHOD_CODE RUN DATE COMMENTS 03-08 9829 JUNK 11/2/1991 5/16" RKP 03-08 9851 JUNK 1/18/1999 IBP Rubber Element 03-08 10225 JUNK 8/17/1989 2 CA RD RK's Perforation Attachment ADL0028331 Well Date Perf Code MD Top MD Base TVD Top TVD Base 03-08 11/18/14 BPS 9604 9636 8697 8723 03-08 11/18/14 BPS 9732 9772 8804 8837 03-08 11/18/14 BPS 9774 9788 8839 8851 03-08 11/18/14 BPS 9789 9793 8852 8855 03-08 11/18/14 BPS 9804 9824 8864 8881 03-08 11/18/14 BPS 9824 9829 8881 8885 03-08 11/18/14 BPS 9831 9842 8887 8896 03-08 11/18/14 BPS 9850 9860 8903 8911 03-08 11/18/14 BPS 9870 9875 8920 8924 03-08 11/18/14 BPS 9910 9911 8953 8954 03-08 11/18/14 BPS 9911 9914 8954 8957 03-08 11/18/14 BPS 9914 9920 8957 8962 03-08 11/18/14 BPS 9920 9930 8962 8970 03-08 11/18/14' BPS 9930 9946 8970 8984 03-08 11/18/14 BPS 9960 9977 8995 9010 03-08 11/18/14 BPS 9977 9980 9010 9012 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0028331 Well Facility Type MD Top Description TVD Top 03-08 PACKER 8821 4-1/2" Baker S-3 Perm Packer 8052 03-08 PACKER 9298 7-5/8" Baker SB-3 Packer 8442 by • 0 To: Ken Bulloch / Scott Bundy; AK, D&C Special Projects Tyler Norene / Len Seymour; AK, D&C Well Services Team Lead Date: 03-16-2015 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: 03-08 WellLock MicroOA Treatment Objective This program is for treating the micro-annular leaking in the fully cemented OA. This well exhibits OA repressurization when on production and is not manageable by bleeds. The liquid leak rate has been established at 0.05 gallons per minute at 3000 psi. WeIlLock is a Newtonian resin that sets with temperature as an inert, hard, plastic-like material. The viscosity has been tested at 60 cP. The objective is to use the small diaphragm, suitcase, pump to squeeze the WellLock into the micro-annulus with high pressure and low volume. Once pressure fall off dissipates, Musol A followed by diesel, should be flushed across the OA valves to keep WeIlLock from setting up. Well Detail Current Status: Not Operable — PAL Previous Test: 11-18-14 CMIT-IA passed to 2500 psi Integrity Issues: Fully cemented OA, OA breaks MOASP, unmanageable by bleeds when on-line (all gas), highest observable pressure 1250 psi; Well Operation Detail Fluid Density: WeIlLock: 9.1-9.3 ppg (keep WellLock at or above 85°F) Musol A: 7.5 ppg 2% KCI: 8.3-8.5 ppg Diesel: 6.8 ppg Equipment: See rig-up diagram Temperature: Maintain 75°-80° F throughout the entire job Relevant History: > 09/13/06: RWO completed cement OA to surface Well Program: 1 D Pump 870 bbls hot, 180° F, crude down IA to heat up the OA. 2 D Over flush diesel out of OA void with several gallons of 2% KCI, 120° F, using the triplex. Purge void with nitrogen, displacing as much KCI as possible. 3 D *** Switch to diaphragm pump. Pump 1.5 gallon WellLock pill. Take returns 1:1 in grounded bucket. 4 D Maintain 3,000 psi for two hours by pumping KCI at signs of pressure fall off. This is to squeeze the WellLock into the microannulus. Record pressure and temperature readings on casing every hour. Do not exceed 3,500 psi. 5 D Swap to Musol A in suitcase pump, crack needle valve on returns line to grounded bucket. Maintain 3,000 psi on returns line. Pump 1 gallon of Musol A through pump, across valves to returns. 6 D Shut-in suitcase pump and returns. 7 D Swap to Musol A through triplex. Pump 1 bbl of Musol A across well to returns to durms, maintaining 3,000 psi. Swap to neat meth in triplex. Overflush Musol A with neat meth, maintaining 3,000 psi. 8 D Shut down triplex with 3,000 psi on well for one week. 9 D Leave crystal gauge on well and take pressure and temperature readings on casing, twice daily. Record in AWGS. 10 D After seven days, MIT-OA *** Collect approximately one cup sample of WellLock in disposable container. Place sample in representative condition and monitor viscosity throughout job. 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The well has been reclassified as Not Operable. Plan forward: 1. APE to evaluate methods of managing Outer Annulus repressurization. Thank you, Kevin Parks !,'lternote: Laurie Chmit BP Alaska - Well Integrity Coordinator GWGlobal Wells Organization Office: 907.659.5102 WIC Email: AKDCWelllntegritVCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Sunday, November 02, 2014 3:21 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; 'chris.wallace@alaska.gov'; G GPB FS2 Drillsites Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; 'jim.regg@alaska.gov'; AK, OPS FF Well Ops Comp Rep Subject: UNDER EVALUATION: Producer 03-08 (PTD #1760730) Sustained Outer Annulus Casing Pressure Above MOASP All, Producer 03-08 (PTD #1760730) was reported to have sustained outer annulus casing pressure above MOASP on 11/02/2014. The pressures were reported to be tubing/inner annulus/outer annulus of 235/1600/1200 psi. The outer annulus pressure build up rate is unmanageable by bleeds. The well is reclassified as Under Evaluation and placed on a 28 day clock. Plan forward: 1. Slickline: Set tubing tail plug for secure A copy of the TIO plot is included for reference. Thank you, Jack Disbrow (Alternate: Laurie Climer) BP Alaska - Well Integrity Coordinator GGlobal� /� / Wells Y Y Organization Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@bp.com 4.000 3.000 2000. Im Producer 03-08 (PTD #1760730) TIO Plot Wc11:03-08 0 Tbg f W —�— OA OOA �— OOOA On Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, November 02, 2014 3:21 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; Wallace, Chris D (DOA); G GPB FS2 Drillsites Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; Regg, James B (DOA); AK, OPS FF Well Ops Comp Rep Subject: UNDER EVALUATION: Producer 03-08 (PTD #1760730) Sustained Outer Annulus Casing Pressure Above MOASP Attachments: image001.png; Producer 03-08 (PTD #1760730) TIO Plot.docx 0 Producer 03-08 (PTD #1760730) was reported to have sustained outer annulus casing pressure above MOASP on 11/02/2014. The pressures were reported to be tubing/inner annulus/outer annulus of 235/1600/1200 psi. The outer annulus pressure build up rate is unmanageable by bleeds. The well is reclassified as Under Evaluation and placed on a 28 day clock. Plan forward: 1. Slickline: Set tubing tail plug for secure A copy of the TIO plot is included for reference. Thank you, Jack Disbrow BP Alaska - Well Integrity Coordinator GWGlobal Wells Organization Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@bp.com 1 SCOW NOVO 4 2014 3i 2,i M Producer 03-08 (PTD #1760730) TIO Plot Well: 034 —� Tbq —� - IA �OA OOA t 00 OA On Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, August 11, 2014 10:37 AM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; Wallace, Chris D (DOA); Dos Santos, Higino W; G GPB FS2 Drillsites Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; Regg, James B (DOA); AK, OPS FF Well Ops Comp Rep Subject: OPERABLE: Producer 03-08 (PTD #1760730) Zero Outer Annulus Pressure Build Up Attachments: image001.png; Producer 03-08 (PTD #1760730) TIO Plot.docx All, Producer 03-08 (PTD #1760730) has been bled and is showing no buildup of outer annulus pressure. The well is reclassified as Operable. A copy of the TIO plot is included for reference. Thank you, Jack Disbrow BP Alaska - Well Integrity Coordinator GW Global Wells SCO OCT Organization Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Saturday, July 19, 2014 4:06 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; 'chris.wallace@alaska.gov'; Dos Santos, Higino W; G GPB FS2 Drillsites Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; 'jim.regg@alaska.gov'; AK, OPS FF Well Ops Comp Rep Subject: UNDER EVALUATION: Producer 03-08 (PTD #1760730) Sustained Outer Annulus Casing Pressure Above MOASP Producer 03-08 (PTD #1760730) was reported to have sustained outer annulus casing pressure above MOASP on 07/16/2014. The pressures were reported to be tubing/inner annulus/outer annulus of 1400/1400/1050. The well is reclassified as Under Evaluation and placed on a 28 day clock. Plan forward: 1. DHD: Hold open bleed on outer annulus until repressurization is manageable. A copy of the TIO plot is included for reference. Thank you, Jack Disbrow BP Alaska - Well Integrity Coordinator GGlobal� /► J Wells V' Y Organization Office: 907.659.5102 WIC Email: AKDCWellintegrityCoordinator@bp.com 4.000 3.000 2.000 1,000 Producer 03-08 (PTD #1760730) TIO Plot W.M-03-M 05'77:74 0&24114 05/35;14 0607;14 06:4=14 0621114 0571&'14 07.'05/14 07112.14 071914 072614 0&0214 08109714 t ng tIA —+— OA GOA t OOOA On , Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, July 19, 2014 4:06 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; Wallace, Chris D (DOA); Dos Santos, Higino W; G GPB FS2 Drillsites Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; Regg, James B (DOA); AK, OPS FF Well Ops Comp Rep Subject: UNDER EVALUATION: Producer 03-08 (PTD #1760730) Sustained Outer Annulus Casing Pressure Above MOASP Attachments: image001.png; Producer 03-08 (PTD #1760730) TIO Plot.docx Producer 03-08 (PTD #1760730) was reported to have sustained outer annulus casing pressure above MOASP on 07/16/2014. The pressures were reported to be tubing/inner annulus/outer annulus of 1400/1400/1050. The well is reclassified as Under Evaluation and placed on a 28 day clock. Plan forward: 1. DHD: Hold open bleed on outer annulus until repressurization is manageable. A copy of the TIO plot is included for reference. Thank you, Jack Disbrow SCANHE'U OCT 0 9 241 A BP Alaska - Well Integrity Coordinator GWGlobal Wells Organization Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@bp.com 0 4.000 4.000 2000 1.000 04f Producer 03-08 (PTD #1760730) TIO Plot .20 t rey t w —OA OOA �— OOOA pn Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Tuesday, February 11, 2014 9:19 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; chris.wallace@alaska.gov; Higino.Dos@bp.com Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer Subject: OPERABLE: Producer 03-08 (PTD #1760730) Sustained Outer Annulus Casing Pressure Above MOASP All, Producer 03-08 (PTD #1760730) was found to have sustained outer annulus pressure above MOASP on January 21, 2014. A passing pack -off test on the IC hanger passed on February 03, 2014, and the OA pressure buildup rate was -140 psi / day. The well has been reclassified as Operable with known IAxOA communication manageable by periodic bleeds. Please call with any questions. Thank you, Laurie Climer fernute: Jack Disbrow) BP Alaska - Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWeIIlntegrityCoordinator@BP.com SIMI ID .�.W w.,-.�_.,_,....�.,.—�.,...... From: A &C Well Integrity Coordinator Sent: Friday, ary 24, 2014 5:38 PM To: AK, OPS FS2 0 K, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D&C Wirelirie-Of2erations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; , PS EOC Specialists; Daniel, Ryan; AK, RES GPB,West Wells Opt Engr; 'chris.wallace@alaska.gov'; 'Dos Santos, Higino W' Cc: AK, D&C DHD Well Integrity Engineer; AK, C Well Integrity Coordinator; AK, D&C Pobjects Well Integrity Engineer; 'jim.regg@alaska.gov' Subject: UNDER EVALUATION: Producer 03-08 (PTD #1760730) Sustained Outer Annulus Casing Pressure Above MOASP All, \ Producer 03-08 (PTD #1760730) was found to have sustained outer annulus casing pressult"bove MOASP on 01/21/2014. The pressures were found to be tubing/inner annulus/outer annulus of 275/1500/1150 psi. The well is reclassified as Under Evaluation and is placed on a 28 day clock to facilitate evaluation. Plan forward: 1. DHD: Perform OART 2. Wellhead: PPPOT-IC A copy of the TIO plot and wellbore schematic are included for reference. Please call with any questions. Thank you, Jack Disbrow (Altera; BP Alaska - Well Integrity Coordinator W Global Wells GOrganization Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@bp.com V1 Wallace, Chris D (DOA From: AK, D&C Well Integrity Coordinator [AKDCWelllntegrityCoordinator@bp.com] Sent: Friday, January 24, 2014 5:38 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; Wallace, Chris D (DOA); Dos Santos, Higino W Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; Regg, James B (DOA) Subject: UNDER EVALUATION: Producer 03-08 (PTD #1760730) Sustained Outer Annulus Casing Pressure Above MOASP Attachments: Producer 03-08 (PTD #1760730) TIO Plot.docx; Producer 03-08 (PTD #1760730) Wellbore Schematic.docx.pdf All, Producer 03-08 (PTD #1760730) was found to have sustained outer annulus casing pressure above MOASP on 01/21/2014. The pressures were found to be tubing/inner annulus/outer annulus of 275/1500/1150 psi. The well is reclassified as Under Evaluation and is placed on a 28 day clock to facilitate evaluation. Plan forward: 1. DHD: Perform DART 2. Wellhead: PPPOT-IC A copy of the TIO plot and wellbore schematic are included for reference. Please call with any questions. Thank you, Jack Disbrow BP Alaska - Well Integrity Coordinator GWGlobal Wells Organization Office: 907.659.5102 WIC Email: AKDCWellintesritvCoordinator@bp.com SCANNED OCT Q 9 2014, r 4.000 3,000 2.000 1.000 Y 10!1613 11613 11M 1M Producer 03-08 (PTD #1760730) TIO Plot Welt: 03M 11(2313 IIrM13 12'07/13 1211N13 12121/13 1228113 GIAW14 01111/14 �— Tbg t W — OA GOA —�-- GOOA On TREE = FMC WELLHEAD = FMC ACTUATOR= AXELSON KB. �E/ = 61' BF ELLV = TVD KOP = 3200' Max Angle = 36 @ 8800' Dlatum MD = 9800' Datum TVD = 8800' SS 9-5J8" CSG, 47#, L-80, TC -11, ID = 8.681" 2257' 13-3/8" CSG 72#, MN -80, D = 12.347" 14 2708' IMinimum ID = 2.79" @ 9214' 5-112" TUBING PATCH I5 112" TBG STUB, D = 4.892 I 8864' 4-1/2" TBG 12.6# 13CR-80, 8883' VAM TOP, .0152 bpf, ID = 3.958" 15-112' TBG -PC 17#, L-80, 9423' .0232 bpf, ID = 4.892" PERFORATION SULWIARY RE= LOG: BHCS ON 11/06/76 ANGLE AT TOP PERF: 33@9604' Note: Refer to Production DB for historical perf data SIZE I SPF I INTERVAL I Opn/Sgz I DATE SEE PG 2 FOR PERFORATION DATA PBTD 10255' 9-518" CSG 47#, MN -80, D = 8.681"10337' 1 1 r 03-08 3_p8 ( NOTES: '"" 4-112" CHROME TUBING 2248' 9-518" HES ES CEiJENTH2 2326' 9-518" FOC 2451' 9-518" FOCGAS LET MANDRELS L 8790' —14-112" HES X NIP, D = 3813- -1 813" 9-5/8 x 4-1/2" BKR S-3 PKR, D = 3.813" 8883' —{4-112" WLEG, � = 3.958" ST MD TVD DEV TYPE ST MD TVD DEV TYPE I VLV LATCH PORT DATE 28 02/23101 9 9071 8256 36 MMG 5 2991 2990 5 MMG DOME RK 16 09/02/10 0 08/17/89 4 4908 4776 29 MMC DOME RK 16 09/02/10 3 6362 6022 33 MMU SO RK 28 09/02/10 2 7524 6987 35 MMU DMY RK 0 09/02/10 1 18719 179701 35 Mu1U DMY RK 1 0 02/17/07 L 8790' —14-112" HES X NIP, D = 3813- -1 813" 9-5/8 x 4-1/2" BKR S-3 PKR, D = 3.813" 8883' —{4-112" WLEG, � = 3.958" ST MD TVD DEV TYPE VLV LATCH PORT DATE 8 8916 8129 36 MMG SO RK 28 02/23101 9 9071 8256 36 MMG DMY RK 0 11/13/76 10 9229 18385 35 MMG 'DCR RKP 0 08/17/89 UHJUINAL VVELLBUKt-' k3blM IbU NA IGH 9115' TOP OF CEMENT DONUT, D = 2.79" (TAGGED 01/04/99) 9214' - 9236' S 1/2" X 21' ALPHA TBG PATCH (02125/99) 11411999?'? 9298' 9-5/8" X 5-1/2" BKR S-3 PKR D = 6.000" 5-1/2" OTIS XN NP, D = 4.455" 9422' S-112" BKR SHEAROUT SUB 9423' 5-1/2" TUBNG TAL 9414'—FB-MD TT LOGGED 11/02/87 9$29' FISH- 5/16" RKP(11/02191) 9851' FISH - BP RUBBER ELEMENT (01/18/99) 10225' H FISH - 2 CA-RD-RK's (08/17189) PRUDHOE BAY UNIT WELL: 03-08 PERMIT No: '1760730 API No: 50-029-20231-00 SEC 11, T10N, R15E, 1395.51' FEL 8 1608.76' FNL DATE REV BY COMvBINITS DATE REV BY COMMENTS 11/13/76 ORIGINAL COMPLETION 07/19/07 SWCIPJC GLV GO (07/09/07) 11/12/86 RWO 07/20/07 SWCIPJC PATCH, CMT, GLV CORRECMI 02/18107 NOES RWO 05/30/09 JCMTLH PX PLUG SET (05/15/09) 1 03/05/07 ?/ MWS DRLG DRAFT CORRECTIONS 09/04/10 BSE/SV PULL PX / GLV CIO (09/02/10) 03/21/07 1 JH I PULL BP/GLV CIO (03119/07 03/27/12 ?/ PJC GLV CORRECTION BP Exploration (Alaska) 03/30/07 GJB/PJC DRLG DRAFT CORRECTIONS PERFORATION SUMMARY REF LOG: BHCS ON 11/06!16 ANGLE AT TOP PERF: 33 @ 9604' Note: Refer to Production DB for historical pert data SIZE SPF MB2VAL Opn/Sgz DATE 3-3/8" 6 9604-9636 O 11/02/87 3-3/8" 4 9732-9772 O 01/10/85 3-3/8" 4 9774- 9788 O 01/10/85 3-3/8" ? 9789-9793 O 11/02/87 3-3/8" 4 9804-9829 O 01/10/85 3-3/8" 4 9831-9842 O 01/10/85 3-3/8" 4 9850-9860 O 01/10/85 3-3/8" 4 9870-9875 O 01/10/85 3-3/8" ? 9915-9918 O 11/02/87 4 9909-9944 S 01/01/85 2" 6 9910-9930 O 03/13/01 2" 4 9957- 9977 S 01/01/85 03-08 PRUDHOE BAY LWT WELL 03-08 PERMIT No. '1760730 AR No: 50-029-20231-00 SEC 11, T10N, R15E, 1395.51' FEL & 1608.76' FNL DATE REV BY COMVIEWS DATE REV BY COMMENTS 11/13/76 ORIGINAL COMPLETION 07/19/07 SWCIPJC GLV CIO (07/09/07) 11/12/86 RWO 07120/07 SWC/PJC PATCF1, CMT, GLV CORF;ECTIOf 02/18/07 NOES RWO 05/30/09 JCMTLH PX PLUG SET (05/15/09) 03/05/07 ?/ MWS DRLG DRAFT CORRECTIONS 09/04/10 BSE/SV PULL PX / GLV C1O (09/02/10) 03/21/07 1 JCWTLH i RJLL BP/GLV CIO (03119/0103/27/12 ?/ PJC GLV CORRECTION BP Exploration (Alaska) 03/30/07 GJB/PJC I DR -G DRAFT CORROCTIONS11 I I d • P6i.{ 0 • ?tf f7' 0730 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] P ib`j.1 g Z Sent: Monday, October 15, 2012 4:24 PM To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS2 DS; Dos Santos, Higino W Cc: AK, D &C DHD Well Integrity Engineer Subject: OPERABLE: Producer 03 -08 (PTD #1760730) OA BUR Manageable By Bleeds Attachments: 03 -08 TIO Plot 10- 15- 12.docx All, i Producer 03 -08 (PTD # 1760730) exhibited an OA build up rate of 114 psi /day during an OA Repressurization Test performed from 10/1 -10/5 making the well manageable by bleeds. At this time the well is reclassified as Operable. «03 -08 TIO Plot 10- 15- 12.docx» Thank you, NEB APR 1 2D�3 Mehreen Vazir BPXA Well Integrity Coordinator From: AK, D &C Well Integrity Coordinator Sent: Saturday, September 29, 2012 4:30 PM To: 'Schwartz, Guy L (DOA)'; 'Regg, James B (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt - 6r; G GPB FS2 DS; Dos Santos, Higino W Cc: AK, D &C DHD Well Integrity Engineer; AK, D &C Well Integrity Coordinator; Wills, Shane ; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: UNDER EVALUATION: Producer 03 -08 (PTD #1760730) Sustained OA Press e Above MOASP All, Producer 03 -08 (PTD #1760730) had broken MOASP on the OA in oly of 2011, as noted in the e -mail chain below. During the diagnostics, repairs to the artificial lift line -re required which halted the process and the well was made not operable. Repairs have been complete. •nd the well is prepared to return to production. The well is reclassified as Under Evaluation to continue ••.gnostics of the well. Plan forward: 1. Operations: Put the well on productio 2. DHD: Outer Annulus Repressuri :tion test (OART) 3. WIE: Evaluate for Seal-Tit- reatment pending results of the OART 1 i PBU 03 -08 PTD #1760730 10/15/2012 TIO Pressures Plot j Welt 03.06 .1,000 - 0 j j s.0C0 - i I — ibg -f— IA A B OA Z,iM'A ' O0A — ..— 0000 .■■On 1 LOS - . • I C r 1 •_•• • _•_ • •._••••••.•••••_•_ •••• •• • • ••••.•.••_ ,.'21,'t2 0728/12 02402 . °_.'t v12 0 &1 &'ti • QSrZ512 09. 09'0 &12 09,15 +12 •. 09 0429112 1iC6'12 10,1212 PG a. . • 1-1100730 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] ' l (OHO,/ Sent: Saturday, September 29, 2012 4:30 PM To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS2 DS; Dos Santos, Higino W Cc: AK, D &C DHD Well Integrity Engineer; AK, D &C Well Integrity Coordinator; Wills, Shane M; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: UNDER EVALUATION: Producer 03 -08 (PTD #1760730) Sustained OA Pressure Above MOASP All, Producer 03 -08 (PTD #1760730) had broken MOASP on the OA in July of 2011, as noted in the e -mail chain below. During the diagnostics, repairs to the artificial lift line were required which halted the process and the well was made not operable. Repairs have been completed and the well is prepared to return to production. The well is reclassified as Under Evaluation to continue diagnostics of the well. Plan forward: 1. Operations: Put the well on production 2. DHD: Outer Annulus Repressurization test (OART) 3. WIE: Evaluate for Seal -Tite treatment pending results of the OART Please call if you have any questions. Thank you, Gerald Murphy SEWED �;R 2D� BP Alaska - Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Tuesday, August 23, 2011 5:23 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, G 1 L (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; • , OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cis • *ski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; Huebel, Ross Cc: King, Whitney; Arend, Jon (NORTHERN SOLUTIONS ) Subject: NOT OPERABLE: Producer 03 -08 (PTD #176e 30) Sustained OA Pressure Above MOASP All, 1 NOT OPERABLE: Producer 03 -08 E D #1760730) Sustained OA Pressure lime MOASP Page 1 0 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIllntegrityCoordinator ©bp.com] � 1�� Sent: Tuesday, August 23, 2011 5:23 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; Huebel, Ross Cc: King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: NOT OPERABLE: Producer 03 -08 (PTD #1760730) Sustained OA Pressure Above MOASP All, Due to ongoing repairs on the AL line, Producer 03 -08 (PTD #1760730) has remained shut in since it was placed Under Evaluation and diagnostics have not been completed. The well is reclassified as Not Operable until the repairs are complete. Please notify Well Integrity when the well is ready to bring back online and it will be reclassified as Under Evaluation to POP so diagnostics can be completed. The plan forward is: 1. Wellhead: PPPOT -IC - PASSED 2. WIC: Reclassify to Under Evaluation 3. Operations: POP 2. DHD: OART with well on production Thank you, • :v. a DAP l r P Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIllntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Saturday, July 30, 2011 2:46 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy L (D• '; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, ►. C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB Eas ells Opt Engr; AK, RES GPB West Wells Opt Engr; Huebel, Ross Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Are +, Jon (NORTHERN SOLUTIONS LLC) Subject: UNDER EVALUATION: Producer 03 -08 (PT ° 1760730) Sustained OA Pressure Above MOASP All, Producer 03 -08 (PTD #1760731 has confirmed sustained OA pressure above MOASP. The wellhead pressures were tubing /IA/O A -qual to 224/1880/1820 on 07/28/2011. The well is reclassified as Under Evaluation. Plan forward: 1. Wellhead: PPPOT-IC 2. DHD: OAR 8/30/2011 UNDER EVALUATION: Producer 03 -(PTD #1760730) Sustained OA Press,Above MOA... Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] V `t 'Id" Sent: Saturday, July 30, 2011 2:46 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Huebel, Ross Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: UNDER EVALUATION: Producer 03 -08 (PTD #1760730) Sustained OA Pressure Above MOASP Attachments: Producer 03 -08 (PTD #1760730) TIO Plot.doc; 03 -08 (PTD #1760730) wellbore schematic.pdf All, Producer 03 -08 (PTD #1760730) has confirmed sustained OA pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 224/1880/1820 on 07/28/2011. The well is reclassified as Under Evaluation. 5CP - 2 ?. 4 ( tt) oaf it-ELL(f) Plan forward: 1. Wellhead: PPPOT -IC � . � , 2. DHD: OART 3. WIE: Evaluate for Seal -Tite treatment depending on previous tests t/16kce o� A TIO plot and wellbore schematic are included for reference. «Producer 03 -08 (PTD #1760730) TIO Plot.doc» «03 -08 (PTD #1760730) wellbore schematic.pdf» Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator ' AU 6 3 2U1 Office (907) 659 -5102 " � Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 8/1/2011 TREE= FMC WELLHEAD = FMC • 03 -0 8 SAFETY•ES: "4 CHROME TUBING** ACTUATOR= AXELSON KB. ELEV = — 61' i. BF. ELEV = I i 'A 6i. 0 1 , 2088' H 4- 1 /2" HES X NIP, ID = 3.813" KOP = 3200' 1 Max Angle = 36 @ 8800' rA I 4 2248' H 9-5/8" HES ES CEMENTER 1 Datum MD = 9800' ' .1F t 0 Datum TVD = 8800' SS ... 2326' H 9-5/8" FOCI 9-5/8" CSG, 47#, L-80, TC-II, ID = 8.6811 2451' I-19-5/8" FOCI -1 2257' GAS LIFT MANDRELS AL-41 ..„ 03x 125; ST MD TVD DEV TYPE VLV LATCH PORT DATE 113-3/8" C72#, MN-80, ID = 12.347" I 2708' 5 2991 2990 5 MMG DOME RK 16 07/09/07 vt p , 5 6o DI 4 4908 4776 29 MMG DOME RK 16 07/09/07 3 6362 6022 33 MMG DOME RK 16 07/09/07 2 7524 6987 35 MMG SO RK 28 07/09/07 1 8719 7970 35 MMG DMY RK 0 02/17/07 • • 8790' 1---I 4-1/2" HES X NIP, ID = 3.813" Minimum ID = 219" @ 9214' 5-1/2" TUBING PATCH OMI 8811' _1-19-5/8 x 4-1/2" BKR S-3 PKR, ID = 3.813" I ii IIII 8835' H 4- 1 /2" HES X NIP, ID = 3.813" I 8883' J-14-1/2" WLEG, ID = 3.958" I 5-1/2" TBG STUB, ID = 4.892 H 8864' 1 ---- PRODUCTION MANDRELS 4-1/2" TBG 12.6# 13CR — I 8883' 1 ST MD TVD DEV TYPE VLV LATCH PORT DATE 8 8916 8129 36 MMG SO RK 28 02/23/01 VAM TOP, .0152 bpf, ID = 3.958" 9 9071 8256 36 MMG DMY RK 0 11/13/76 10 9229 8385 35 MMG *DCR RKP 0 08/17/89 ORIGINAL WELLBORE -" BEHIND TBG PATCH 9115' 11 TOP OF CEMENT DONUT, ID = 2.79" (TAGGED 01/04/99) v.vII . we *0 k WA •4■ 9214' - 9236' 1-15-1/2" X 21' ALPHA TBG PATCH (02/25/99) I 0 I VA 0 14* AAA OA `qel C 1 9298' 1-19-5/8" X 5-1/2" BKR S-3 PKR, ID = 6.000" 1 0 I. 4 I 9408' H 5-1/2" OTIS XN NIP, ID = 4.455" I 9422' J-15-1/2" BKR SHEAROUT SUB 5-1/2" TBG-PC 17#, L-80, -I 9423' I-- .0232 bpf, , ID = 4.892" 9423' 1--15-1/2" TUBING TAIL I I I 9414' 1-I ELMD TT LOGGED 11/02/87 I PERFORATION SUMMARY REF LOG: BHCS ON 11/06/76 .4 1 4 , I — T8W - 1 — tFISH - 5/16" RKP (11/02/91)1 ANGLE AT TOP PERF: 33 @ 9604' Ave I 9851' I-I FISH - IBP RUBBER ELEMENT (01/18/99) I Note: Refer to Production DB for historical perf data SIZE I SPF 1 INTERVAL I Opn/Sqz 1 DATE SEE PG 2 FOR PERFORATION DATA I I I 1 I I , 1 1 7 PBTD H 10255' 11111111 -44-4v4r*"*-Ivir4 10225' 1-IFISH - 2 CA-RD-RK's (08/17/89) 1 • • • . • . ••• •••• 4 1 9-5/8" CSG 47#, MN-80, D = 8.681" H 10337' .* • • • • • * • * 0 ■ .... *- ••4 ,lkit1'12-2. 6 l p I TO I-1 10370' DATE REV BY COMMENTS II DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/13/76 ORIGINAL COMPLETION 1107/19/O7SWC/PJC GLV C/O (07/09/07) WELL: 03-08 11/12/86 RWO 07/20/07 SWC/PJC PATCH, CMT, GLV CORRECTIONS PERMIT No: r 1760730 02/18/07 N4ES RWO 05/30/09 JCM/TLH PX PLUG SET (05/15/09) API No: 50-029-20231-00 03/05/07 ?/ MWS DRLG DRAFT CORRECTIONS 09/04/10 BSE/SV PX PLUG PULLED (09/02/10) SEC 11, Ti ON, R1 5E 1395.51' FEL & 1608.76' FNL 03/21/07 JCM/TLH IBP PULLED & GLV C/O (03/19/07) 03/30/07 GJB/PJC DRLG DRAFT CORRECTIONS 1 BP Exploration (Alaska) • _ • • t,, o o. ► !4 IIP I PERFORATION SUMMARY '01 F 4 1 1 IN REF LOG: BRCS ON 11/06/76 : I '∎ + ■ ANGLE AT TOP PERF: 33 @ 9604' t 4 111, Note: Refer to Production DB for historical perf data MI/ � 1�t SIZE SPE INTERVAL Opn /Sqz DATE 1 1 3 -3/8" 6 9604 - 9636 0 11/02/87 A 1 3 -3/8" 4 9732 - 9772 0 01/10/85 3 -3/8" 4 9774 - 9788 0 01/10/85 3 -3/8" ? 9789 - 9793 0 11/02/87 3 -3/8" 4 9804 - 9829 0 01/10/85 3 -3/8" 4 9831 - 9842 0 01/10/85 3 -3/8" 4 9850 - 9860 0 01/10/85 3 -3/8" 4 9870 - 9875 0 01/10/85 3 -3/8" ? 9915 - 9918 0 11/02/87 4111v. I ? 4 9909 - 9944 S 01/01/85 2" 6 9910 - 9930 0 03/13/01 2" 4 9957 - 9977 S 01/01/85 I • I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11113/76 ORIGINAL COMPLETION 07/19/07 SWC/PJC GLV C/O (07/09/07) WELL: 03 -08 11/12/86 RWO 07/20/07 SWC/PJC PATCH, GMT, GLV CORRECTIONS PERMIT No: 1760730 02/18/07 N4ES RWO 05/30/09 JCM/TLH PX PLUG SET (05/15/09) API No: 50- 029 - 20231 -00 03/05/07 ?/ MWS DRLG DRAFT CORRECTIONS 09/04/10 BSE/SV PX PLUG PULLED (09/02/10) SEC 11, T10N, R15E, 1395.51' FEL & 1608.76' FNL 03/21/07 JCM/TLH IBP PULLED & GLV C/O (03/19/07) 03/30/07 GJB /PJC DRLG DRAFT CORRECTIONS H BP Exploration (Alaska) PBU 03 -08 PTD #1760730 7/30/2011 TIO Pressures Plot Well: 03 -08 4,000 - • 3 - -#- T bg —M— IA 2 :000 - —OA OOA I .•• • •:.s'■'�. 000A _t y 0 1:000 - Tri • eir 05/07/11 05/21/11 06/64/11 006/18/11 07/02/11 07/16111 07/30/11 Producers with sustained casing pression IA and OA due to proration Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Wednesday, January 12, 2011 10:42 PM --1! till It To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: King, Whitney; Cismoski, Doug A; Engel, Harry R; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead Subject: Producers with sustained casing pressure on IA and OA due to proration Jim/Tom /Guy, The following producers were found to have sustained casing pressure on the IA during the proration January 10 -12. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 03 -28 (PTD #1840720) 12 -15 (PTD #1830320) 12 -36 (PTD #1951580) 514 x`' (1 S -33 (PTD #1921020) Z -30A (PTD #2032190) The following producers was found to have sustained casing pressure on the OA during the proration January 10 -12. The immediate action is to perform an OA repressurization test and evaluate if the IAxOA pressure is manageable by bleeds. If the IAxOA communication is unmanageable, a follow up email will be sent to the AOGCC notifying you of the remedial plan. 03 -08 (PTD #1760730) f 03 -28 (PTD #1840720) Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 1/13/2011 OPERABLE: Producer 03-08 (PTD# 1730) OA pressure manageable • Page 1 of 1 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator@bp.com] _ Sent: Monday, October 25, 2010 10:07 AM- To: AK, D&C Well Integrity Coordinator; Regg, James B (DOA); Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, OPS FS2 Ops Lead; Cismoski, Doug A; Engel, Harry R; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL Cc: Sinyangwe, Nathan; King, Whitney; Quy, Tiffany Subject: OPERABLE: Producer 03-08 (PTD# 1760730) OA pressure manageable Attachments: 03-08 TIO Plot 10-25-10.doc All, Producer 03-08 (PTD #1760730) was placed on production to quantify the OA pressure build -up -rate prior to a Seal-Tite treatment. The well has been on production for over two weeks without anv si ns of OA repressu�riz_ation. The well has been reclassified as Operable and may continue on production. Please notify well integrity if the OA pressure begins to increase. «03-08 TIO Plot 10-25-10.doc>> Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: AK, D&C Well Integrity Coordinator Sent: Friday, October 08, 2010 5:55 AM U7 To: 'Regg, James B (DOA)'; 'Schwartz, Guy (DOA)'; 'Maunder, Thomas E (DOA)'; 'Brooks, Phoebe L (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, OPS FS2 Ops Lead; Cismoski, Doug A; Engel, Harry R; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB East Production Optimization Engineer; AK, OPS PCC EOC TL Cc: AK, D&C Well Integrity Coordinator; Sinyangwe, Nathan; Janowski, Carrie; Vazir, Mehreen Subject: UNDER EVALUATION: Producer 03-08 (PTD# 1760730) POP to evaluate OA build -up -rate and pump Seal -rite treatment All, Producer 03-08 (PTD #1760730) has a history of hydrates forming in the OA resulting in sustained casing pressure while online. In attempt to mitigate the high OA pressure a Seal-Tite treatment will be performed. The well has been reclassified as Under Evaluation so that it can be placed on production for further diagnostics and the Seal-Tite treatment. Please call Well Integrity prior to placing the well on production as DHD will need to be on location to monitor and bleed the OA pressure as necessary. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 10/25/2010 l —*— Tbg f— IA �— OA OOA —� — OOOA On C -I 2 WED ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Nathan Sinyangwe Production Engineer BP Exploration (Alaska), Inc. -10 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 03-08 Sundry Number: 310-339 Dear Mr. Sinyangwe: 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 reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel -T:. Seamount, Jr. Chair DATED this Llday of October, 2010. Encl. V� STATE OF ALASKA /('0ALASAIL AND GAS CONSERVATION COMMISSO f 0-11 X b APPLICATION FOR SUNDRY APPROVALS IQ•t�"� 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool[-_] Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re-enter Susp. Well ❑ Stimulate❑ Alter Casing ❑ 0 Other: SEALTIE 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ Stratigraphic ❑ Service ❑ 176-0730 3. Address: P.O. Box 196612 6. API Number: Anchorage, AK 99519-6612 50-029-20231-00-00 - 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: Spacing Exception Required? Yes ❑ No ❑ PBU 03-08 , 9. Property Designation (Lease Number): _ 10. Field/Pool(s): ADLO-028331/ADL0028327 PRUDHOE BAY Field / PRUDHOE OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10369 - 9337.88 - 10255 9297 8835'5/16/09 9829 9851 10225 Casing Length Size MD TVD Burst Collapse Structural Conductor 73 20" 94# H-40 SURFACE 101 SURFACE 101 1530 520 Surface 2677 13-3/8" 72# MN -80 SURFACE 2708 SURFACE 2707 5380 2670 Intermediate 10307 9-5/8" 47# MN -80 SURFACE 10337 SURFACE 9311 6870 4760 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4-1/21112.6+# 13CR80 URFACI 8833 - - 5-1/2" 17# L-80 8864 9423 Packers and SSSV TVDe: 9-5/8"x4-1/2" BKR S-3 Packers and SSSV MD and TVD (ft): 8811 8045 9-5/8"X5-1/2" BKR 8-3 PKR 9298 8442 12. Attachments: Description Summary of Proposal ❑- 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑✓ Service ❑ - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/15/2010 Oil [rte Gas ❑ WINJ ❑ GINJ ❑ WDSPL ❑ Suspen WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: I'D -fI vld Commission Representative: S(1co.l t— GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoind is true and correct to the best of my knowledge. Contact Nathan Sinyangwe Printed Name Nathin Sinyangwe Title Production Engineer Signature Phone Date 564-5062 10/8/2010 Prepared by Gary Prebie 564-4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: j 0 ✓ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: i} CI jf.FT I 1 Alaus Oil &Gas C9RS. C0"'tdejV Subsequent Form Required: /0- ��0 ri APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: / � ip1 SOCT Form 10-403 Re dD 2010 �� 12 n D I G I N A' �r/�Iplicate 03-08 176-073 PERF ATTACHMENT Sw Name Pert Operation Code Operation Date Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 03-08 PER 5/14/77 9,804. 9,829. 8,864.29 8,885.25 03-08 PER 5/14/77 9,870. 9,875. 8,919.66 8,923.86 03-08 PER 5/14/77 9,911. 9,946. 8,954.12 8,983.54 03-08 PER 5/14/77 9,960. 9,980. 8,995.32 9,012.13 03-08 PER 5/17/77 9,850. 9,860. 8,902.87 8,911.27 03-08 PER 5/18/77 9,850. 9,860. 8,902.87 8,911.27 03-08 BPS 1/24/81 9,878. 9,906. 8,926.38 8,949.91 03-08 APF 3/11/82 9,774. 9,788. 8,839.15 8,850.88 03-08 APF 3/11/82 9,831. 9,842. 8,886.93 8,896.16 03-08 SQZ 1/4/85 9,500. 9,977. 8,609.64 9,009.61 03-08 APF 1/10/85 9,732. 9,772. 8,803.92 8,837.47 03-08 RPF 1/10/85 9,774. 9,788. 8,839.15 8,850.88 03-08 RPF 1/10/85 9,804. 9,824. 8,864.29 8,881.06 03-08 RPF 1/10/85 9,824. 9,829. 8,881.06 8,885.25 03-08 RPF 1/10/85 9,831. 9,842. 8,886.93 8,896.16 03-08 RPF 1/10/85 9,850. 9,860. 8,902.87 8,911.27 03-08 RPF 1/10/85 9,870. 9,875. 8,919.66 8,923.86 03-08 APF 11/2/87 9,604. 9,636. 8,696.59 8,723.39 03-08 APF 11/2/87 9,789. 9,793. 8,851.72 8,855.07 03-08 APF 11/2/87 9,914. 9,920. 8,956.64 8,961.69 03-08 MLK 10/27/98 9,213.5 9,214.5 8,372.03 8,372.86 03-08 FIL 12/30/98 9,851. 9,977. 8,903.71 9,009.61 03-08 BPS 12/31/98 9,380. 9,390. 8,509.74 8,518.04 03-08 SPS 1/4/99 9,300. 9,380. 8,443.43 8,509.74 03-08 SQZ 1/4/99 9,115. 9,300. 8,291.24 8,443.43 03-08 SPR 1/14/99 9,300. 9,380. 8,443.43 8,509.74 03-08 BPP 1/17/99 9,380. 9,390. 8,509.74 8,518.04 03-08 FCO 6/16/00 9,851. 9,961. 8,903.71 8,996.16 03-08 FCO 6/25/00 9,944. 9,985. 8,981.86 9,016.33 03-08 FIL 6/26/00 9,914. 9,977. 8,956.64 9,009.61 03-08 FCO 3/13/01 9,914. 9,965. 8,956.64 8,999.52 03-08 APF 3/14/01 9,910. 9,930. 8,953.28 8,970.09 03-08 BPS 5/16/09 8,835. 9,980. 8,064.01 9,012.13 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED 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 Date: To: October 7, 2010 Jerry Bixby/Rob Liddelow, AK, D&C Wireline Operations Team Lead Clark Olsen/Tyler Norene, AK, D&C Well Services Team Lead From: Tiffany Quy/Mehreen Vazir, Projects Well Integrity Engineers 659-5098, Harm #2418 Chris Colbert, ACT Petrophysicist Subject: 03-08 Mitigate OA Gas Repressurization Est. Cost: AFE: APBD03WL08 IOR: 270 Step Type Procedure 1 D Load OA with brine 2 WP Treat OA with Seal-Tite Objective: Mitigate gas repress u rization in cemented outer annulus. Well Stats: Well Status: Not Operable, PAL, SI for OA repressurization above MOASP Last well test: 278 bopd, 5708 bwpd, 545 mscfpd form gas, 4.0 mmscfpd AL, 95% WC — 263 psi FTP, 157 deg F Max Deviation: 360 @ 8800' Min ID: 2.79" @ 9214' patch in tubing tail for this program: 3.813 X -nipple @ 8835' Last SBHPS: 05/15/09 — 3247 psi & 189°F @ 8800' SSSV: NO Last H2S: 06/23/08 — 32 ppm Well Events Summary: Well 03-08 was completed with 4.5" Chrome Tubing stacker packer completion in a RWO 02/2007. The 9-5/8" PC was cut and pull at ±2326', replaced and cemented to surface to repair IAxOA communication. About a year after the RWO, the well began experiencing high / OAP that became unmanageable by bleeds. It is now classified as Not Operable due to the high OA pressure. IA & OA gas samples show the gases have different compositions indicating the OA gas is not AL gas. An MIT -OA failed 09/15/2008 (-2 mos after SI) with a LLR of 0.63 gpm at 2000 psi indicating a Microannulus in the OA cement allowing fluid movement. Another MIT -OA 09/05/09 found a LLR of 0.017 gpm to hydraulic fluid and 0.15 gpm to diesel both at 2000 psi. A Tecwel LDL was attempted 7/13/08 with no success in finding a leak. The well was secured 05/15/09 and a Tecwel LDL was again attempted 6/8/09 with still no success in identifying a leak site. /An MIT -IA to 3000 psi passed on 9/2/10. A live gas lift valve design was set and the TTP was pulled. The OA was strapped and TOC was tagged at 28". Please call Tiffany Quy/Mehreen Vazir at 907-659-5098, Harm #2418 with any questions or concerns regarding this program. Cc: Well File AK, D&C Well Integrity Engineer • Mechanical Considerations: • The OA is 13 3/8" 72 Ib/ft L-80 with a burst of 5380 psi. • The IA is 9 5/8" 47 Ib/ft L-80 with a collapse of 4750 psi. • The lower of the two gives a pressure rating of 3800 psi. The max injection pressure used for this treatment will be 2500 psi - derated for the age of the surface casing pipe. • The limiting pressure rating is the IA collapse with a rating of 80% = 3808 psi. The IA will not see close to this differential at the SC shoe as the pipe is cemented externally and on-line with AL gas at 1600+ psi internally. The IA pipe from ±2326' up is from the RWO in 2007. • The OA has a rating of 80% = 4304 psi and 2500 psi would derate the pipe to 58% , of burst. The external reservoir pressure accounts for possible hydrostatic column in the cemented annulus. The OA pipe is from the original completion done in 1976. An MIT -OA to 2500 psi will be done as part of the Seal-Tite program. • The well has a sealed conductor so the surface casing will be inaccessible for performing a UT scan to assess wall loss. • Casing pressure diagnostics have shown a characteristic rapid bleed off pressure (from as high as 2180 psi to 0 psi in 1 min, gas, 7/5/08) followed by a buildup of as ' much as 920 psi in 30 min (on-line). The OA buildup rate is much higher when the well is on line and hot. Extended periods of open bleed on the OA result in a reduced OA buildup rate both when the well is on or off production. • The OA bleed gas has been sampled and confirmed to have a different composition than lift gas from the IA indicating feed in from an external reservoir source. From drilling logs in other parts of Prudhoe, it is possible that the source is a gas reservoir somewhere between 2700' - 4500' TVD. However there has been no log confirmation of a high gas reservoir in the EWF area, so the actual depth is unknown. A WAF LDL was attempted 7/13/08 and then again on 6/8/09 with no success in finding the OA leak site. • OA FL's have consistently been at or near surface (within 50'). Drilling records indicate cement at surface through the OA valve on completion. The first attempt to inject fluids into the OA 9/15/08 required 4.8 bbls to pressure up from 0 to 2000 psi / indicating the TOC —70'. It is reasonable to assume there is some combination of r/ cement fall back and cracks/voids in the cement to some unknown depth. Below that depth the microannulus aspect takes over as evidenced by the slow gas feed -in rate (OA BUR) after extended draw -downs (bleeds). • An OA-LLR was found at 0.63 gpm at 2000 psi for 30 minutes 9/15/08 using a triplex with diesel. Another OA-LLR was performed 9/5/09 and found 0.15 gpm at 2000 psi to diesel with a triplex and 0.02 gpm at 2000 psi to hydraulic fluid with a hand pump. The well was SI for OA repressurization 07/2008, so all leak rate tests were performed cold. • Given the higher build rate evidenced when the well is on production, this procedure calls for an extended flow period accompanied by OA bleeds to maximize the flow area of the Microannulus crack. 2 0 Sealant Considerations/Design: 0 • The sealant volume design is based on filling a microannulus with diameter of 0.0075 inches, from the top of cement to at least 500 feet below the top of cement (estimated 3.5 liters per 100'). This will provide sufficient sealant to ensure isolation of the pressure source from the surface once the casing has been cut below the surface and the well abandoned. • Given the above discussion of an uncertain TOC and a possible large cement channel, the sealant injection technique will be to inject a given volume of time activated sealant and water-based pressure activated sealant into a diesel -filled annulus. The majority of that sealant will be displaced then an additional volume of water-based sealant injected and allowed to fall for 1 hour before displacement. • Seal-Tite will provide the 16 ppg brine required for treatment. This weight is not easily available from Ml. It will likely be a Zinc Bromide solution. • Gly -Flo 1 M will be blended to approx. 14 ppg, freeze point is -60F. • Micro -Seal is mixed about 8.8 ppg. It has a liquid FP -10°F. It is a A&B copolymer which yields a exothermic reaction. Therefore it will heat up and solidify when mixed. The cure time to solid is -72 hours. • STI contacts: Office (985) 875-1292. Jon Arend, Field Tech (907) 240-4383. Neil Cary, Design Engineer (985) 264-3335. Barry Ellis, (985) 630-3636. 3 F_ L � Procedure: This procedure employs the following major steps: - POP Under Evaluation and monitor OA buildup. - Attempt to displace annulus with brine to kill the OAP. If unsuccessful, plan to move onto Seal-Tite steps below. - Perform multiple OA bleeds to achieve maximum void capacity in the OA. - Displace and activate the sealant. Depending on data observed during the build up and bleeds, it is anticipated that a combination of time activated and pressure activated sealants will be used. - Allow the sealant to cure under pressure for several days. - Cycle the pressure at the surface to finalize the seal. Downhole Diagnostics: POP & displace OA with brine NOTE: Will require the following rig -up. • Hard line and AP tank rigged up to OA in advance. Call 659-5182 to order RU. Coordinate with DHD WIE on which AP tank to use (DHD tank #030 or 019). • Lincoln grease pump for brine (DHD equipment). • 2- Heaters (Non mobile @ 659-5642) 10.8 ppg CaC12 brine will be ordered from MI. 10.8 ppg has a freeze point of -51 degrees F. It is recommended to transport this tote in the special projects trailer. Coordinate w/ DHD foreman on transporting tote (659-5521). 1. Perform PJSM & record in AWGRS log. 2. RU to OA via hard line to a DHD arctic pack tank. Install heater trunk in cellar. 3. Assist Ops with POP. Note that IA is liquid packed. Follow PE Guidelines to avoid damaging GLVs when unloading. 4. Every 30 min record the following in the AWGRS log entry: time, well temp, WHPs. 5. Allow OAP to stabilize. This was done with the well on line May 2008 and the OAP stabilized 1500 psi for 2 weeks. 6. Once the OAP is stable (stops building pressure for 4 hrs), bleed OAP to slop trailer. a. Record the time it takes to bleed (in seconds), fluid bled back (gas/liquid amt). b. SI the bleed once the OA is at 0 psi. c. Record the OA pressure every 5 min for the first 30 min after the bleed. Then record the OAP every 30 min until it reaches 1000 psi. d. Once the OAP reaches 1000 psi, open OA bleed and repeat the above steps. e. Continue burping the OA for one shift or until there is no liquid returned in at least 4 -dumps. f. Maintain an open bleed for 48-hrs to help mitigate OAP BUR for pumping. 7. RU a manifold to the OA to Lincoln grease pump and bleed trailer. Grease pump will be used to pump 10.8 ppg brine down the OA. Transfer brine to a 5 - gal bucket pre -marked to accurately measure small volumes into the OA. 8. Lube and bleed brine into the OA in an attempt to mitigate high OAP with a maximum treatment pressure of 2000 psi. a. Use attached L&B spreadsheet. b. L&B until either the gas no longer swaps out and there are only fluid returns at surface or until at least 2-bbls of brine are pumped into the OA. c. Diligently record all fluids pumped in and out of the OA. Record all straps and bleed backs. 0 9. Once L&B is complete, monitor OA BUR for 7 days. Track 30 min WHPs and temperature. 10. If brine is unsuccessful in mitigating the high OAP: a. MIT -OA to 2500 psi with diesel pre-Seal-Tite. b. The sealant used for this work is water-based and will dilute readily into the existing brine cap, therefore it must be displaced with diesel. Establish injection into the OA with diesel and continue injecting at 2000 to 2500 psi until a minimum of 40 gallons has been injected. Allow the well to stabilize for 24 hours. c. Burp OA of as much fluid as possible (as in the above steps pre -brine). Be sure to record all fluids bled back, times, and pressures as above and record 5 -min OAP's post bleed. d. Leave open bleed on the OA for 48 hrs. e. Move on to Seal-Tite steps below. f. Leave hard-line rigged up to AP tank, heater hose in the cellar, and DHD monitor if needed due to high OAP. Wellhead Pending: Pump Seal-Tite down OA to mitigate OA repressurization NOTE: Will require the following rig -up • OA bleed (there should be an AP tank rigged up to the OA from the previous steps). If not, a bleed trailer can be used for this part of the program. • Heater (Non mobile @ 659-5642) • Seal-Tite pump and product. This should be a small rig -up easily contained within the wellhouse. • Assure well has been on line a min of 7 -days and has had at least 2 -days of open bleeds prior to the Seal-Tite treatment. 11. Perform PJSM and record in AWGRS. 12. On arrival, bleed the OA for 3 hours if an open bleed has not been done throughout night shift. Keep heater hose rigged up to the wellhead. 13. R/U Seal-Tite injection equipment to OA casing valve. Test all equipment to 200 psi low and 3000 psi high. 14. RU Crystal Engineering nVision (or similar) digital pressure recorder to the OA to store all pressure treatment data for further analysis. 15. From previous diagnostics and drilling records the TOC is uncertain but is most likely between 10'-30'. A large cement crack may also exist which travels down to the micro -annulus. The brine will be injected, allowed to fall through the diesel in the OA to the TOC, and then displaced into the cracks with diesel. 16. Shut in bleed and immediately pump 16 ppg brine. Continue pumping until the OA pressure is 2000 psi or 7 gallons have been injected. Shut down 30 minutes and allow brine to fall. a. 16 ppg brine will be provided by Seal-Tite. 17. Bleed the OA to zero and lubricate in an additional 5 gallons of 16 ppg brine. 18. Increase OA pressure with diesel to establish stable injection rates for 5 minutes at 1000 psi, 1500 psi, 2000 psi, and 2200 psi. a. The lowest injection pressure that provides a 0.1 gpm leak rate will be used as the minimum injection pressure. b. If very high injection rates are seen (although not anticipated based on previous LLR data), the step rate test may have to be increased. A maximum injection pressure of 2500 psi will be allowed (see mechanical considerations discussion above). 5 1'9. Continue diesel injection to push the brine into annulus at minimum injection pressure as identified from step rate test above. Continue injection until 80% of the brine volume pumped is displaced with diesel. a. 80% of the anticipated 12 gals brine to be pumped = 9.6 gal diesel @ min injection pressure. Injecting Sealant - Maintain minimum injection pressure determined previously during sealant injection in the next steps. 20. Bleed OA to 500 psi. Immediately inject 3 gallons of pressure -activated sealant Gly -Flo 1 M. Shut down 60 minutes and allow GF 1 M to fall to bottom. 21. Inject the Gly -Flo 1 M into the micro -annulus crack with 2.5 gallons of diesel. 22. Bleed OA to 500 psi. Immediately inject 3 gallons of pressure -activated sealant Gly -Flo 3M. Shut down 60 minutes and allow GF 1 M to fall to bottom. 23. Push the Gly -Flo 3M into the micro -annulus crack with 2.5 gallons of diesel. a. Contact Seal-Tite office and review well performance to determine whether additional pressure -activated sealant will be injected or move to time -activated sealant below. b. Do not bleed before contacting STI office. Pending the injection pressure trends, there may be more pressure -activated sealant pumped into the OA before bleeding. It is undesirable to have significant flow -back until as much sealant as possible is injected into the crack(s). 24. Bleed OA to 500 psi. Immediately inject 5 gallons of time -activated sealant Micro -Seal 1300. Perform separate lub/bleeds if required. Shut down 60 minutes and allow MS 1300 to fall to bottom. 25. Begin injecting diesel to push MS 1300 into the cement micro -annulus. Overdisplace by 2 gallons (total 7 gallons of diesel). Lock in pressure on OA, shut down and allow sealant to cure for minimum 5 days. a. Lock in 2500 psi OAP. This is -300 psi over the maximum observed SI pressure of 2180 psi. b. The pressure should decrease as the sealant cures. c. If the OA builds up, bleed OA back down to 2500 psi. 26. Once sealant is cured for 5 days, MIT -OA with diesel to 2000 psi. Obtain a LLR if fails. a. Contact STI with these results to determine if more pressure -activated sealant injection is required. 27.Assuming LLR is negligible and passing MIT -OA, slowly begin bleeding back pressure from OA. Once OA pressure reaches 1500 psi, stop and allow to cure for 4 hours. 28. Continue bleeding OA to a pressure of 1000 psi. Stop and allow to cure for 4 hours. 29. Continue bleeding OA to a pressure of 500 psi. Stop and allow to cure for 3 days while maintaining well on production. Monitor OA for pressure buildup. 30. Shut OA bleed in and monitor overnight buildup to ensure pressure is within operable limits. 31. If buildup occurs beyond operational limits, re-establish diesel/sealant injection per steps provided by STI office. Pressure cycles may be required (slowly increase pressure to 2000 psi and then rapidly bleed the OA pressure to 500 psi. 32. If OA BUR is manageable, rig down all equipment. Secure well, and clean work location. Turn well over to operator. 0 TREE = f 19-518" CSG, 47#, L-80, TC -I, ID = 8.681- 113-318" CSG 72#, MN -80, ID = 12.347" Minimum ID = 2.79" (& 9214" 5-1/2" TUBING PATCH It)-UZ- It$U51tks,Iu=4.aa. •1/2" TBG 12.6# 13CR-80, AM TOP, .0152 bpf, ID = 3,958- - OA - 13 3/8" 72 Ib/ft L-80 with a burst of 5380 psi — 0.0581 bpf - IA - 9 5/8" 47 Ib/ft L-80 with a collapse of 4750 psi — 0.0535 bpf 5-112" TBG -PC 17#, L-80, .0232 bpf, ID = 4.892" PERFORATION SMVIARY REF LOG: BHCS ON 11106176 ANGLE AT TOP PERF; 33 @ 9604" Nate: Refer to Production DB for historical perf data '.. 101K T61=1 ZOItT`Irou1ITT 1 1 PBTD 1025T 9-518" CSG 47#, W+80, D = 6.681" 1033T M� %SAFETY NOTES: **4-1/2" CHROM ETUBING- mcr. ►ISO,1 o- �3ti��®gym DATE REV BY COMMENTS DATE REV BY COMMENTS 11113176 ORIGINAL COM PLETION 07119/07 SWCIPJC GLV C/O (07/09107) 11/12/86 RWO 07/20/07 SWCIPJC PATCH, CMT, GLV CORRECTIONS 02/18107 N4ES RWO 05/30/09 JCMITLH PX PLUG SET (05/15/09) 03105/07 ?/ MWS DRLG DRAFT CORRECTIONS N�VNIIKIVA..! 03130107 GJB/PJC DRLG DRAPE' CORRECTIONS I •i 19-518" CSG, 47#, L-80, TC -I, ID = 8.681- 113-318" CSG 72#, MN -80, ID = 12.347" Minimum ID = 2.79" (& 9214" 5-1/2" TUBING PATCH It)-UZ- It$U51tks,Iu=4.aa. •1/2" TBG 12.6# 13CR-80, AM TOP, .0152 bpf, ID = 3,958- - OA - 13 3/8" 72 Ib/ft L-80 with a burst of 5380 psi — 0.0581 bpf - IA - 9 5/8" 47 Ib/ft L-80 with a collapse of 4750 psi — 0.0535 bpf 5-112" TBG -PC 17#, L-80, .0232 bpf, ID = 4.892" PERFORATION SMVIARY REF LOG: BHCS ON 11106176 ANGLE AT TOP PERF; 33 @ 9604" Nate: Refer to Production DB for historical perf data '.. 101K T61=1 ZOItT`Irou1ITT 1 1 PBTD 1025T 9-518" CSG 47#, W+80, D = 6.681" 1033T M� %SAFETY NOTES: **4-1/2" CHROM ETUBING- mcr. ►ISO,1 o- UK]UNAL VVt1Lt5VKt: t"tr114L7 IOU ril lUrl X115' TOP OF CEMENT DONUT, ID = 2.79" (TAGGED 01104199) 9214" - 9236* 5-112" X 21' ALPHA TBG PATCH 9408' —15-112" OTIS XN NIP, ID = 4.455" 9422" 5-1f2" BKR SHEARCUT SUB 9423* 5-112"TUBING TAIL 9414" EMD TT LOGGED 11102187 9829" FISH - 5/1$" RKP (111Q2191 } 9851* HPISH- IBP RUBBER ELEMENT (01 �3ti��®gym DATE REV BY COMMENTS DATE REV BY COMMENTS 11113176 ORIGINAL COM PLETION 07119/07 SWCIPJC GLV C/O (07/09107) 11/12/86 RWO 07/20/07 SWCIPJC PATCH, CMT, GLV CORRECTIONS 02/18107 N4ES RWO 05/30/09 JCMITLH PX PLUG SET (05/15/09) 03105/07 ?/ MWS DRLG DRAFT CORRECTIONS 03/21/07 1 J LH I IBP FULLED & GLV C/O (03/19107) BP Exploration (Alaska) 03130107 GJB/PJC DRLG DRAPE' CORRECTIONS I •i Immsmomm, !' NNE • '...im N-1 His EM ♦ .,r• i:r, �.r:�. UK]UNAL VVt1Lt5VKt: t"tr114L7 IOU ril lUrl X115' TOP OF CEMENT DONUT, ID = 2.79" (TAGGED 01104199) 9214" - 9236* 5-112" X 21' ALPHA TBG PATCH 9408' —15-112" OTIS XN NIP, ID = 4.455" 9422" 5-1f2" BKR SHEARCUT SUB 9423* 5-112"TUBING TAIL 9414" EMD TT LOGGED 11102187 9829" FISH - 5/1$" RKP (111Q2191 } 9851* HPISH- IBP RUBBER ELEMENT (01 PRUD 40E BAY UNIT WELL: 03-08 PERMIT No: 1760730 API No: 50-029-20231-00 SEC 11, TION, R15E, 1395,51' FEL & 1608.76 FNL DATE REV BY COMMENTS DATE REV BY COMMENTS 11113176 ORIGINAL COM PLETION 07119/07 SWCIPJC GLV C/O (07/09107) 11/12/86 RWO 07/20/07 SWCIPJC PATCH, CMT, GLV CORRECTIONS 02/18107 N4ES RWO 05/30/09 JCMITLH PX PLUG SET (05/15/09) 03105/07 ?/ MWS DRLG DRAFT CORRECTIONS 03/21/07 1 J LH I IBP FULLED & GLV C/O (03/19107) BP Exploration (Alaska) 03130107 GJB/PJC DRLG DRAPE' CORRECTIONS I Immsmomm, NNE UK]UNAL VVt1Lt5VKt: t"tr114L7 IOU ril lUrl X115' TOP OF CEMENT DONUT, ID = 2.79" (TAGGED 01104199) 9214" - 9236* 5-112" X 21' ALPHA TBG PATCH 9408' —15-112" OTIS XN NIP, ID = 4.455" 9422" 5-1f2" BKR SHEARCUT SUB 9423* 5-112"TUBING TAIL 9414" EMD TT LOGGED 11102187 9829" FISH - 5/1$" RKP (111Q2191 } 9851* HPISH- IBP RUBBER ELEMENT (01 7 PRUD 40E BAY UNIT WELL: 03-08 PERMIT No: 1760730 API No: 50-029-20231-00 SEC 11, TION, R15E, 1395,51' FEL & 1608.76 FNL DATE REV BY COMMENTS DATE REV BY COMMENTS 11113176 ORIGINAL COM PLETION 07119/07 SWCIPJC GLV C/O (07/09107) 11/12/86 RWO 07/20/07 SWCIPJC PATCH, CMT, GLV CORRECTIONS 02/18107 N4ES RWO 05/30/09 JCMITLH PX PLUG SET (05/15/09) 03105/07 ?/ MWS DRLG DRAFT CORRECTIONS 03/21/07 1 J LH I IBP FULLED & GLV C/O (03/19107) BP Exploration (Alaska) 03130107 GJB/PJC DRLG DRAPE' CORRECTIONS I 7 0 r 10-404 03-08 (176-073) Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, October 11, 2010 2:24 PM To: 'Preble, Gary B (SAIC)' Cc: Sinyangwe, Nathan Subject: RE: 10-404 03-08 (176-073) Gary, You have verbal approval to proceed with the Sealtite treatment of the OA as written on well DS 3-08. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Preble, Gary B (SAIL) [mailto:Gary.Preble@bp.com] Sent: Monday, October 11, 2010 8:46 AM To: Schwartz, Guy L (DOA) Cc: Sinyangwe, Nathan Subject: RE: 10-404 03-08 (176-073) S r al would be greatly appreciated. Thanks From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, October 11, 2010 8:20 AM To: Preble, Gary B (SAIL) Subject: RE: 10-404 03-08 (176-073) Ok... how soon. Do you just want to get a verbal? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Preble, Gary B (SAIC) [mailto: Gary. Preble@bp.com] Sent: Monday, October 11, 2010 7:59 AM To: Schwartz, Guy L (DOA) Cc: Sinyangwe, Nathan Subject: 10-404 03-08 (176-073) Guy, I am submitting a 10403 for 03-08 (176-073) this morning. It is a Sealtite job and there is a scheduling problem that causes BP to ask you to expedite approval on it. Thanks in advance. 10/11/2010 1b-404 03-08 (176-073) Gary Preble Petrotechnical Data Team Coordinator Science Applications International Corporation Office 907.564.4944 Mobile 907.350.6879 preblegb@bp.com 10/11/2010 Page 2 of 2 UNDER EVALUATION: Producer 0.9 (PTD# 1760730) POP to evaluate O uild-up-rate an... Page 1 of 1 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator@bp.com]�� (094 o Sent: Friday, October 08, 2010 5:55 AM To: Regg, James B (DOA); Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, OPS FS2 Ops Lead; Cismoski, Doug A; Engel, Harry R; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB East Production Optimization Engineer; AK, OPS PCC EOC TL Cc: AK, D&C Well Integrity Coordinator; Sinyangwe, Nathan; Janowski, Carrie; Vazir, Mehreen Subject: UNDER EVALUATION: Producer 03-08 (PTD# 1760730) POP to evaluate OA build -up -rate and pump Seal- Tite treatment All, Producer 03-08 (PTD #1760730) has a history of_ydrates forming in the OA resulting in sustained casing pressure while online. In attempt to mitigate the high OA pressure a Seal-Tite treatment will be performed. The well has been reclassified as Under Evaluation so that it can be placed on production for further diagnostics and the Seal-Tite treatment. Please call Well Integrity prior to placing the well on production as DHD will need to be on location to monitor and bleed the OA pressure as necessary. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 10/8/2010 WAMW OCT I I N10 J ~/~~.~. ~ To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 [907j 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing lnspection(Caliper / MTV The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Date Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, lnc. Attn: Robert A. Richey 130 West International Airport Road ~~j~A ~~~ f ~~ n,,~ J ~~d` Suite C Anchorage, AK 99518 Fax: (907j 245-8952 1) Leak Detection - WAF 08,Jun-09 03-08 Color Log / EDE 50-029-20231-00 2j ~~. JUN 1 ~ 20u9 Signed Print Name: Date iii G~ ~. ~rr~missiAe~ AnGh~ra~a PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : pdsanchoraae(~memoryloa.com WESSITE : www.memorvloa.com C:\Documents and Settings\Owner\Desktop\T,ansmit BP.docx ALASSA ®~ AI1TD GA5 COlY5ER~ATIOI~I CO1rII-II55IO1~T i SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chris Colbert BP Exploration (Alaska), Inc=,r, PO Box 196612 Anchorage, AK 99519 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-08 Sundry Number: 308-383 ~~ ~~ 1 Dear Mr. Colbert: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~y/~.~- Cathy P. Foerster Commissioner DATED this 7i day of October, 2008 Encl. ,, ~~'~~~ • STATE OF ALASKA (~'~ ALASKA OIL AND GAS CONSERVATION COMMISSION~~ ACT `~ ~ ZQ~J~ APPLICATION FOR SUNDRY APPROV ~`ti 20 AAC 25.280 5~8 ~4I gx ~~ ~~7~1:~~ ~~0~~~31~S1C~'+ 1. Type of Request: Abandon Suspend Operational shutdown Perforate Wa ; Othe Alter casing ^ Repair well ^~ ~ Plug Perforations^ Stimulate ^ Time Extension ^ SEALTITE ~ Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development], Exploratory ^ 176-0730 - 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-20231-00-00 - 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 03-08 Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ~dL~~3a~ ADLO-028331- 61 KB- PRUDHOE BAY Field / PRUDHOE OIL Pool 11 • PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10369 - 9337.88 - 10255 9242 9297' 9829' 9851' 10225' Casing Length Size MD TVD Burst Collapse Conductor 73' 20" Surface 101' Surface 101' 1530 520 Surface 2677' 13-3/8" 72# mn-80 Surface 2708' Surface 2707' 5380 2670 Production 10307' 9-5/8" 47# MN-80 Surface 10337' Surface 9311' 6870 4760 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4-1/2" 12.6# 13CR80 SURFACE - 8883' - - 5-1/2" 17# L-80 8864' - 9423' Packers and SSSV Type: 9-5/8"X4-1/2" BKR S-3 Packers and SSSV MD (ft): 8811' 9-5/8"X5-1/2" BKR S-3 PKR 9298' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/5/2008 OIL ^~ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Colbert Printed Name Chris Colbert Title PE Signature ~ Phone 564-5135 Date 10/22/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ ~- ~ tt r1`_~ '~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ W~~\ ~ ,T ~~3 Oth ~~~ er: Subsequent Form Required: ~f1y ~,\ ~~fJ APPROVED BY Approved by: COMMIS IONER THE IQfV Date: ~ ~ ~d Form 10-403 evised 06/2006 ~ ~ ti_ ~``' '' '~- : ' ~5i~it in Duplicate 03-08 176-073 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 03-08 5/14/77 PER 9,804. 9,829. 8,864.29 8,885.25 03-08 5/14/77 PER 9,870. 9,875. 8,919.66 8,923.86 03-08 5/14/77 PER 9,911. 9,946. 8,954.12 8,983.54 03-08 5/14/77 PER 9,960. 9,980. 8,995.32 9,012.13 03-08 5/17/77 PER 9,850. 9,860. 8,902.87 8,911.27 03-08 5/18/77 PER 9,850. 9,860. 8,902.87 8,911.27 03-08 1/24/81 BPS 9,878. 9,906. 8,926.38 8,949.91 03-08 3/11/82 APF 9,774. 9,788. 8,839.15 8,850.88 03-08 3/11/82 APF 9,831. 9,842. 8,886.93 8,896.16 03-08 1/4/85 SQZ 9,500. 9,977. 8,609.64 9,009.61 03-08 1/10/85 APF 9,732. 9,772. 8,803.92 8,837.47 03-08 1/10/85 RPF 9,774. 9,788. 8,839.15 8,850.88 03-08 1/10/85 RPF 9,804. 9,824. 8,864.29 8,881.06 03-08 1/10/85 RPF 9,824. 9,829. 8,881.06 8,885.25 03-08 1/10/85 RPF 9,831. 9,842. 8,886.93 8,896.16 03-08 1/10/85 RPF 9,850. 9,860. 8,902.87 8,911.27 03-08 1/10/85 RPF 9,870. 9,875. 8,919.66 8,923.86 03-08 11/2/87 APF 9,604. 9,636. 8,696.59 8,723.39 03-08 11/2/87 APF 9,789. 9,793. 8,851.72 8,855.07 03-08 11/2/87 APF 9,914. 9,920. 8,956.64 8,961.69 03-08 10/27/98 MLK 9,213.5 9,214.5 8,372.03 8,372.86 03-08 12/30/98 FIL 9,851. 9,977. 8,903.71 9,009.61 03-08 12/31/98 BPS 9,380. 9,390. 8,509.74 8,518.04 03-08 1/4/99 SPS 9,300. 9,380. 8,443.43 8,509.74 03-08 1/4/99 SQZ 9,115. 9,300. 8,291.24 8,443.43 03-08 1/14/99 SPR 9,300. 9,380. 8,443.43 8,509.74 03-08 1/17/99 BPP 9,380. 9,390. 8,509.74 8,518.04 03-08 6/16/00 FCO 9,851. 9,961. 8,903.71 8,996.16 03-08 6/25/00 FCO 9,944. 9,985. 8,981.86 9,016.33 03-08 6/26/00 FIL 9,914. 9,977. 8,956.64 9,009.61 03-08 3/13/01 FCO 9,914. 9,965. 8,956.64 8,999.52 03-08 3/14/01 APF 9,910. 9,930. 8,953.28 8,970.09 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 • by To: J. Bixby/C. Olsen October 21, 2008 GPB Well Ops Team Leaders From: Chris Colbert DS 03&17 Production Engineer Subject: DS 03-08 Sealtite Treatment Est. Cost: $75M PBD03WL08-N IOR: 270 BOPD Please perform the following procedure(s): 1. I O I Pump Sealtite Treatment per attached procedure ~ Status: GL producer, not operable do to high OAP Last Test 278 BOPD, 5708 BWPD, 545 MCFPD Form. Gas, and 3,977 MCPD GL Max Deviation: 36° @ 8800'MD Min ID: 2.79"@ 9214' MD, 5'/z" Tubg Patch Last TD Tag: 9904' MD 05/17/2008 Last Downhole Ops: Ran TecWel WAF log 7/13/2008 to 3500' MD Latest H2S value: 32 ppm 06/23/2008 Purpose: The purpose of this program is to repair an apparent micro-annulus in the fully cemented OA of well 03-08. History: Well 03-08 has been SI and classified as not operable due to high OA pressure (>1000psi). This well had a RWO in the spring of 2007 and then about a year later began experiencing high OAP that became unmanageable by bleeds. During the RWO the OA was cemented to surface. Gas sam les taken from the IA and OA show the apses have different compositions. Because o t is Gas Lift pas. An MIT-OA failed to 2000 psi on 9/15/2008 a LLR was established at 0.63 gal/min showing there is micro-annulus present allowing gas to flow around the cement. Contact Chris Colbert at x5135 or 970-759-9715 (cell) or Jennifer Jullian 564- 5663 (w) or 240-8037 (c) with any questions or comments. cc: w/a: 03-12 Well File Chris Colbert Seal-Tite International Advanced Sealant Technology • Proposed Procedure BP Alaska, 03-08 Microannulus Leak Repair October 21, 2008 Seal-rite International 500 Deer Cross Drive Madisonville, LA 70447 Telephone:985-875-1292 Facsimile: 985-875-0687 http://www. seal-tite.net Objectives Repair a microannulus cement leak in the OA in order to restore OA integrity Mechanical Considerations The 03-08 well has a history of IA/OA communication. To attempt a repair the 9 5/8" casing was cut at +- 2326' and pulled, then replaced and cemented to surface. However the OA pressure continues to build due to a suspected microannulus channel in the OA cement. Casing pressure diagnostics have shown a characteristic rapid bleed off of pressure (660 psi bled to 0 psi in 60 seconds, all gas) followed by a buildup to 23 psi in 30 minutes. The OA buildup rate has increased significantly in the past several months and has become unmanageable by routine bleeds. The OA builds to as much as 2100 psi in +-48 hours. The OA bleed gas has been sampled and confirmed to be different than gas lift gas, indicating feed in from an external reservoir source. The depth of the source is unknown, but could be as high as the 2700' or as deep as 4500' TVD. Additional diagnostics recently performed verified the ability to inject fluids into the annulus. Diesel was injected into the OA and increased to 2000 psi with 4.8 bbls, indicating a probable cement top of about 70'. Continued injection resulted in a sustained diesel injection rate of 0.63 gal/min at 2000 psi for 30 minutes. This is considered sufficient to allow sealant injection. A review of cementing records has indicated a TOC at the surface in contrast to the 70' TOC by the above diesel displacement. Therefore it is reasonable to assume that there is some combination of a cement slump and a very large crack into the cement to some unknown depth. Below that depth the microannulus aspect takes over as evidenced by the slow gas feed-in rate. • • Intended Repair Procedure This procedure employs the following major steps: - Displacing and activating the sealant - Allowing the sealant to cure under pressure for a period of several days - Cycling the pressure at the surface to finalize the seal The sealant volume design will be based on filling a microannulus with diameter of 0.0075 inches, from the top of cement to at least 500 feet below the top of cement (estimated 3.5 liters per 100').. This will provide sufficient sealant to ensure isolation of the pressure source from the surface once the casing has been cut below the surface and the well abandoned. Given the above discussion of an uncertain TOC and a possible large cement channel, the sealant injection technique will be to inject a given volume of water- based sealant into adiesel-filled annulus. The majority of that sealant will be displaced, then an additional volume of water-based sealant injected and allowed to fall for 1 hour before displacement. The outer casing is 13 3/8" 72 Ib/ft L-80 with a burst of 5380 psi. The inner casing is 9 5/8" 47 Ib/ft L-80 with a collapse of 4750 psi. Using 80% of the lower pressure provides a maximum injection pressure of 3800 psi; however, the well has only had previous MIT-OA pressure tests up to 2400 psi. For the purposes of this procedure we will use a maximum pressure of 2400 psi. 1. Perform Job Safety Analysis with all concerned personnel. 2. Take pressure readings as follows: - Tubing Pressure - 9 5/8" casing (IA) - 13 3/8" casing (OA) 3. R/U Seal-Tite injection equipment to OA casing valve. Test all equipment to 200 psi low and 3500 psi high. 4. Install a chart recorder on the OA casing with a 2400 psi spring and 24 hour clock. Calibrate chart recorder against test gauge. (Or substitute with similar pressure measurement /recording device) 5. From previous diagnostics and drilling records the TOC is uncertain but is most likely between 10'-30'. A large cement crack may also exist which travels down to the microannulus. Accordingly the brine will be injected and , f• allowed to fall to the cement. In order to gain a void in the OA to inject brine, the OA should be allowed to build and maintained at 1500-2000 psi. Given the previous diesel injection rate of 0.63 gal/min @ 2000 psi and a target displacement volume of 4.8 bbls, the pressure should be held for a minimum of 24 hours. This will push fluid into the cement microannulus. As an alternative, nitrogen can be used just prior to the next step to push the fluid level down. 6. Once the fluid level has been pushed down as above, bleed the OA to zero, record effluent and time to bleed. 7. Fill OA with 100 liters of 11.8 ppg brine. Continue with injection of diesel until the OA is full.. Record volume required to fill up. Allow 60 minutes for brine to fall before the next step. 8. Increase OA pressure with diesel to establish stable injection rates for 5 minutes at 1000 psi, 1500 psi, 2000 psi, and 2200 psi.. 9. Continue diesel injection to push the brine into annulus at 2000 - 2200 psi. Continue injection until a total of 90 liters has been injected. 10. Inject 15 liters of water-based sealant (Gly-Flo 1 M) into OA. This should raise the OA pressure to 800-900 psi. Shut down 60 minutes and let the sealant fall to TOC. 11. Using diesel, push 12 liters of sealant into the cement at 1400 psi. 12. Repeat steps 10 and 11 using Gly-Flo 3M into OA at 1400 psi. 13. Repeat steps 10, and 11 using Gly-Flo 5M into OA at 1400 psi 14. Repeat steps 10, and 11 using Gly-Flo 7M into OA at 1400 psi 15. Repeat steps 10, and 11 using Gly-Flo 9M into OA at 1400 psi 16. Repeat step 10 using Gly-Flo 9MV into OA at 1400 psi until 3 liters has been injected. 17. Increase injection pressure to 2000 psi. Continue with Gly-Flo 9MV until an additional 3 liters has been injected. 18. Increase injection pressure to 2200 psi. Continue with Gly-Flo 9MV until an additional 3 liters has been injected. 19. Increase injection pressure to 2400 psi (maximum allowable pressure). Continue with Gly-Flo 9MV until an additional 3 liters has been injected. • • 20. Bleed pressure to zero -measure returns. Allow to bleed for 3 minutes, then increase injection pressure to 2400 psi. 21. Repeat the above pressure cycling sequence an additional 10 times - monitoring returns each time. Once flowback begins to reduce, increase flowback times but do not allow more than 3 liters of returns. 22. Allow sealant to cure overnight. 23. Repeat the above pressure cycling sequence an additional 10 times - monitoring returns each time. Continue to increase flowback times as flowrate reduces until flow is reduced to zero. 24. Shut OA in and monitor for buildup overnight to ensure buildup is within allowable limits. 25. Rig down all equipment. Secure well and clean work location. Turn well over to operator. 26. End of procedure. DNC 10/21/08 NOT OPERABLE- 03-08 (PTD #1760730) Unmanageable OA repressation Page 1 of 3 • Regg, James B (DOA) __ `~` From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~ ` ~;~/~~ Sent: Wednesday, July 16, 2008 12:55 PM ~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng Cc: Winslow, Jack L.; Colbert, Chris M; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE- 03-08 (PTD #1760730) Unmanageable OA repressurization ~ All, After two weeks of bleeding the OA pressure on well 03-08 {PTD #1760730), the build up rate is still unma, naaeable. At this point, we have no plans forward for the well, but are awaiting the outcome of a peer review scheduled for early August. In the interim, the well wil! be classified as Not Operable. Operations: Please ensure the weH is shut-in as soon as possible. Please call with any questions or concerns. Thank you, Andrea Hughes ~~~~ S~~' ~ ~ ~~~~ From: NSU, ADW Well Integrity Engineer Sent: Wednesday, July 02, 2008 7:53 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng Cc: Roschinger, Torin T.; NSU, ADW Well Integrity Engineer; Colbert, Chris M Subject: UNDER EVALUATION- 03-08 (PTD #1760730) Sustained casing pressure on the OA All, Weil 03-08 {PTD #1760730) has been confirmed to again have sustained casing pressure above 1000 psi. The wellhead pressures were tubing/IAtOA equal to 24811640/1700 on 06/30/08. The well has been reclassified as Under Evaluation to further evaluate the source of the high OA pressure. Although initial gas samples were taken and showed two different gas compositions between the IA and OA, gas samples will again be taken and the OA pressure allowed to increase up to 2000 psi to evaluate the potential for IAxOA communication. A TIO plot and wellbore schematic have been included far reference. Please cal( with any questions. Thank you, ,,Znna tDu6e, t'. E. Well Integrity Coordinator GPB Wells Group 8/29!2008 NOT OPERABLE- 03-08 (PTD #1760730) Unmanageable OA repressurization Page 2 of 3 • Phone: {907j 659-5102 Pager: {907j 659-5100 x1154 From: NSU, ADW WeII Integrity Engineer Sent: Saturday, May 24, 2008 9:38 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; Deckert, Steven L; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: OPERABLE- 03-08 (PTD #1760730) OA pressure manageable by bleeds AI I, As a follow-up to the note below on well 03-08 {PTD #1760730j, the OA pressure was allowed to build until 05/18/08 when the TIOs were 300/1670/1440 psi. An open bleed was conducted on 05!18108 and 05120108, and then the well was monitored for another three days to evaluate the build up rate. On 05/23/08 the TIOs were 25011620/190 psi with a build up rate of -60 psi/day. The well has been reclassified as Operable. It is permissible to maintain the OA pressure under the standard MAASP of 1,000 psi with occasional bleeding. Please notify the Well Integrity Engineer if the OA pressure exceeds MAASP or becomes unmanageable by bleeds. Please call with any questions or concerns. Thank you, Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Monday, April 28, 2008 9:02 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FSi/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; Deckert, Steven L; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng Cc: Dahlem, Jason E; NSU, ADW Well Integrity Engineer Subject: 03-08 (PTD #1760730) Planned Action -Under Evaluation with Sustained Casing Pressure on the OA Jim and Tom, WeII 03-08 {PTD #1760730) has been found with sustained casing pressure on the OA. The TIOs on 04127108 were 450/170011480 psi. As seen in the email below, our plan is to evaluate the source of OA repressurization by first allowing the pressure to stabilize, and then by maintaining an span bieed for several days. At that point, it will be determined if an internal dispensation will be needed for continued operation with an OA pressure greater than 1,000 psi. The OA of 03-08 was cemented to surface on 02118/07 during a rig workover. The surface casing is 13-3/8°', 72#, L-80 with a burst value of 5,380 psi. The OA pressure will not be allowed to build over 45°l0 of burst, A TIO plot and wellbore schematic have been included for reference. 8/29/2008 NOT OPERABLE- 03-08 (PTD #1760730) Unmanageable OA repressurization Page 3 of 3 • • Please call with any questions or concerns. Thank you, Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Wednesday, April 23, 2008 9:37 AM To: GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, F52 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; Deckert, Steven L; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: 03-OZ and 03-08 Reclassified as Under Evaluation All, Wells 03-02 and 03-08 have been reclassified as Under Evaluation to diagnose the source of the building OA pressure. Gas sampling of the OA and IA gas verified that the wells do not have IAxOA communication. An attempt to quantify the gas inflow into the OA with a gas meter was unsuccessful, as the rate was too small. The plan forward for these wells is as follows: 1. WIE: Monitor OAP until stabile with well online (this is most likely a pressure above MAASP. Please DO NOT bleed the OAP.) 2. DHD: Once the maximum obtainable pressure has been established, maintain an open bleed on the OA in an attempt to deplete the gas source. 3. WIC: Eval for dispensation for continued operation with OAP above currently set MAASP. Operations: Please do not bleed the OA pressure of these wells until all of the diagnostics are complete. I will follow up with an additional email once this is the case. Please do not hesitate to call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 8/29/2008 PBU 03-08 PTD 176-073 ,000 -' `' hAAASP 1 -N~ 0 4201008 4M 7!2008 Sr1C1008 SM 7200$ 6M I2008 6M 6E2008 7~1r1008 ~~ss~~~, ~lee~ 7M 7!2008 -~- Tbg -rE- IA -~ OA -- ODA ~- OOOA • TREE = FMC WELLHEAD = FMC ACTUATOR= AXELSON KB._EZEV - 61 BF. ELEV = KOP = 3200' Max Angle = 36 @ 8800' Datum MD = 9800' Datum TVD = 8800' SS 9-518" CSG, 47#, L-80, TGII, ID = 8.681 13-318" CSG 72#, MN-80, ID = 12.347" '3 ~O $ NOTES: **4-1/Z" CHROMETUBING** 208$' 4-1l2" HES X NIP, ID = 3.813" 2248' 9-518" HES ES CEMENT 2326' 9-5/8" FOC ' 2451' 9-518" Foc 2257 GAS LIFT MANDRELS ~ ST MD TVD DEV TYPE VLV LATCH PORT DATE 270$' S 2991 2990 5 MMG DOME RK 16 07109/07 4 4908 4776 29 MMG DOME RK 16 07!09/07 3 6362 6022 33 MMG DOME RK 16 07!09107 2 7524 6987 35 MMG SO RK 28 fl7109107 1 8719 7970 35 MMG DMY RK 0 02/17/07 Minimum ID = 2.79" @ 9214' 5-1/2" TUBING PATCH f 5-112" TBG STUB, ID = 4.892 ( $$64' 4-112" TBG 12.6# 13CR-80: 8$83' VAM TOP, .0152 bpf, ID = 3.958" 5-1/2" TBG-PC 17#, L-8o, 9423' .0232 bpf, ID = 4.892" PERFORATION SUMMARY REF LOG: BRCS ON 11/06/76 ANGLE AT TOP PERF: 33 @ 9fi04' Note: Refer to Production DB for historical perf data SIZE 15PF g INTERVAL ~ OpnlSgz 0 DATE ~ SEE PG 2 FOR PERFORATION DATA PBTD 10255' 9-518" CSG 47#, MN-80, ID = 8.681" 10337° TD 10370' L $790' --~4-112" HES X NIP, ID = 3.813" 8811' 9-518 x 4-1(2" BKR S-3 PKR, ID = 3.813" $$35' lam'-ill" HES X N1P, ID = 3.813" 8883' 4-112" WLEG, 1D = 3.95$" PRODUCTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 8 8916 8129 36 MMG SO RK 28 02123101 9 9071 8256 36 MMG DMY RK 0 11113176 10 9229 8385 35 MMG *DCR RKP 0 08/17189 Ut{ItilNHL W t:LLkiUhfC = tiCFifNU I ti(~ f-'H 1 C.:H 9115' TOP OF CEMENT DONUT, ID = 2.79" {TAGGED 01104199) 9214' - 9236' S-112" X 21' ALPHA TBG PATCH (02125/99) 929$' 9-518" X 5-1/2" BKR S-3 PKR, ID = 6.000" 9408' S-112"' OT1S XN NIP, ID = 4.455" 9422' S-1/2" BKR SHEAROUT SUB 9423` 5-112" TUBING TAIL 9414' ELMD TT LOGGED 11!02/87 9$29' - F-SH - 5116" RKP { 11 /02/91) 9$51' FISH - IBP RUBBER ELEMENT (01118!99) 10225' I-~ FISH - 2 CA-RD-RK's {08117189) DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDNOE BAY UNIT 11/13/76 ORIGINAL COMPLETION 07(19(07 SWGPJC GLV GO (07/09/07} WELL: 03-08 11(12186 RWO 07120/07 SWGPJC PATCH, CMT, GLV CORRECTK3N -~~~~~~~~~~~~~~~~~ S PERMIT No: °1760730 fl2P18(07 N4ES RWO API No: 50-029-20231-00 03105/07 ?/ MWS DRLG DRAFT CORRECTIONS SEC 11, T10N, R15E, 1395.51' FEL & 1608.76' FNL 03/21/07 JCM(itH tBP PULLED &GLV CIO {03119107} 03/30/07 GJB(PJC DRLG DRAFT CORRECTIONS 8P Exploration {Alaska] • 03-08 PERFORATION SUMMARY REF LOG: BRCS ON 11!06!76 ANGLE AT TOP PERF: 33 @ 9604' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 3-318" 6 9604 - 9636 O 11!02187 3-318" 4 9732 - 9772 O 01/10185 3-318" 4 9774 - 9788 O 41/10185 3-318" ? 9789 - 9793 O 11!02!87 3-3/8" 4 9804 - 9829 O 01/10/85 3-318" 4 9831 - 9842 O 01/10185 3-3/8" 4 9850 - 9860 O 41/10/85 3-318" 4 9870 - 9875 O 01110!85 3-318" ? 9915 - 9918 O 11!02/87 ? 4 9909 - 9944 S 41/01/85 2" 6 9910 - 9930 O 03/13101 2" 4 9957 - 9977 5 01101(85 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE $AY UNIT 11113/76 QRIGINAL COMPLETION 07119107 SWCIPJC GLV GO (07109107} WELL: 03-08 111121$6 RWO 07120!07 SWC/PJC PATCH, CMT, GLV CORRECTION S PERMIT No: '1760730 02118/07 N4ES RWO API No: 50-029-20231-00 03,'05107 ?/ MWS DRLG DRAFT CORRECTIONS SEC 11, T10N, R15E, 1395.51' FEL & 1608.76' FNL 03121107 JCMlTLH IBP PULLED ~ GLV GO (03/19!07) 03/30107 GJBIPJC DRLG DRAFT CORRECTIONS BP Exploration {ABaska} Yf/~~~ ~OV ____ ,! }''~ ~°.. ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Catiper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP E~loration (Alaska), Inc. Petratechnical Data Center Attn: Joe Lastufka LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services,, lnc. Attn: Robert. A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~c (907 245-8952 D5 03-08 1 BL / EDE 1) Leak Detection - WAF 12zJUF08 2) Signed Print Name: 1~-(0-03 V ~~a PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT Im SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)2458952 E-MAIL .:^ai~:.~n:_^.3~~&°e'1 ~.2(.~nu'~.E'~'Huf'.i~~d_d m'~~ WEBSITE.?tU~.htN.'? 3"''a^A6°~.3',~C^~.a:ye.~~ Date . C:\Documents and Se[tinge\Owner\Desktop\Tmnsmit_BP.doc OPERABLE- 03-08 (PTD #1760730) OA pressure manageable by bleeds • • Page 1 of 2 Regg, James B (DOA) From Sent: To: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Saturday, May 24, 2008 9:38 AM Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; Deckert, Steven L; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng ~Y~ ~1410~ Cc: Townsend, S. Eliot; NSU, ADW W~Integrity Engineer Subject: OPERABLE- 03-08 (PTD #1760730) OA pressure manageable by bleeds All, As a follow-up to the note below an well 03-08 {PTD #1760730}, the OA pressure was allowed to build until 05/18/08 when the TIOs were 300/1670/1440 psi. An open bleed was conducted on 05/18008 and 05/20108, and then the well was manitored for another three days to evaluate the build up rate. On 05023/08 the TIOs were 250116201190 psi with a build up rate of -60 psi/day. The well has been reclassified as Operable. ft is permissible to maintain the OA ~res~i,rP ender the standard MAASP of 1 000 psi with occasional bleeding. Please notify the Well Integrity Engineer if the OA pressure exceeds MAASP or becomes unmanageable by bleeds. . Please call with any questions or concerns. Thank you, ~~~~®J U N ~. ;~ 200 Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Monday, April 28, 2008 9:02 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; Deckert, Steven L; NSU, ADW WeII Operations Supervisor; GPB, Wells Opt Eng Cc: Dahlem, Jason E; NSU, ADW Well Integrity Engineer Subject: 03-08 (PTD #1760730) Planned Action -Under Evaluation with Sustained Casing Pressure on the OA Jim and TOm, Well 03-08 {PTD #1760730) has been found with sustained casing pressure on the OA. The TIOs on 04/27!08 were 450/1700!1480 psi. As seen in the email below, our plan is to evaluate the source of OA repressurization by first allowing the pressure to stabilize, and then by maintaining an open bleed for several days. At that point, it will be determined if an internal dispensation will be needed for continued operation with an OA pressure greater than 1,000 psi. The OA of 03-08 was cemented to surface on 02/18107 during a rig workover. The surface casing is 13-3/8°', 72#, L-80 with a burst value of 5,380 psi. The OA pressure will not be allowed to build over 45°l~ of burst. A TIO plot and weilbore schematic have been included for reference. Please call with any questions or concerns. 6/4/2008 OPERABLE- 03-08 (PTD #1760730) OA pressure manageable by bleeds Page 2 of 2 • Thank you, Andrea Hughes From: NSU, ADW WeII Integrity Engineer Sent: Wednesday, April 23, 2008 9:37 AM To: GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, F52 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; Deckert, Steven L; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: 03-02 and 03-08 Reclassified as Under Evaluation AI I, Wells 03-02 and 03-08 have been reclassified as Under Evaluation to diagnose the source of the building OA pressure. Gas sampling of the OA and IA gas verified that the wells do not have IAxOA communication. An attempt to quantify the gas inflow into the OA with a gas meter was unsuccessful, as the rate was too small. The plan forward for these wells is as follows: 1. WIE: Monitor OAP until stabile with well online (this is most likely a pressure above MAASP. Please DO NOT bleed the OAP.) 2. DHD: Once the maximum obtainable pressure has been established, maintain an open bleed on the OA in an attempt to deplete the gas source. 3. WIC: Eval for dispensation for continued operation with OAP above currently set MAASP. Operations: Please do not bleed the OA pressure of these wells until all of the diagnostics are complete. I will follow up with an additional email once this is the case. Please do not hesitate to call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907} 659-5102 Pager: (907) 659-5100 x1154 6/4/2008 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, April 28, 2008 9:02 PM ~ ~ ~I~~ ~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; Deckert, Steven L; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng Cc: Dahlem, Jason E; NSU, ADW Well Integrity Engineer ,/ Subject: 03-08 (PTD #1760730) Planned Action -Under Evaluation with Sustained Casing Pressure on the OA i ~ ~ Pt~dc~cer- _ ~. tJ ~ L Attachments: 03-08.pdf; 03-08 TIO PIot.BMP \ Jim and Tom, Well 03-08 (PTD #1760730} has been found with sustained casing pressure on the OA. The TIOs on 04127/08 ~ were 450/1700/1480 psi. As seen in the email below, our plan is to evaluate the source of OA repressurization by first allowing the pressure to stabilize, and then by maintaining an apen bleed for several days. At that point, it will be determined if an internal dispensation will be needed for continued operation with an OA pressure greater than 1,000 psi. The OA of 03-08 was cemented to surface on 02118J07 during a rig workover. The surface casing is 13-318", 72#, L-80 with a burst value of 5,380 psi. The OA pressure wiil not be allowed to build over 45% of burst. A TIO plot and welibare schematic have been included for reference. `~ Zll ZI psi «03-08.pdf» «03-08 TIO PIot.BMP» ! Please call with any questions or concerns. Thank you, Andrea Hughes ~~~N MAY 2 1 200 From: NSU, ADW Well Integrity Engineer Sent: Wednesday, April 23, 2008 9:37 AM To: GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; Deckert, Steven L; NSU, ADW Well-Operations Supervisor; GPB, Wells Opt Eng Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: 03-02 and 03-08 Reclassified as Under Evaluation All, ,. Wells 03-02 and 03-08 have been reclassified as Under Evaluation to diagnose the source of the building OA pressure. Gas sampling of the OA and IA gas verified that the wells do not have IAxOA communication. An attempt to quantify the gas inflow into the OA with a gas meter was unsuccessful, as the rate was too small. The plan forward for these wells is as follows: 1. WIE: Monitor OAP until stabile with well online (this is most likely a pressure above MAASP. Please DO NOT bleed the OAP.) 5/20/2008 vv-vv ~a a i rr a i vv r .. v~ a...a as a...a a :...,..... v.......~ ~.........,............~ .. ..~... »....»~.`~.,...~ ~...... ~b ~...,.,»... a ...b.... .,~ .... ~" ~./, 2. DHD: Once the maximum obtainable pressure has been established, maintain an open bleed on the OA in an attempt to deplete the gas source. 3. WIC: Eval for dispensation for continued operation with OAP above currently set MAASP. Operations: Please do not bleed the OA pressure of these wells until all of the diagnostics are complete. I will follow up with an additional email once this is the case. Please do not hesitate to call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 5/20/2008 • ai .~ H ~n r O I ..~ r ~ ~~ ~J r~~ °"- O ^ oc~ 0 .~ w 0 a w .~ n. 0 00 ~v r- 0 a s~+ ca sv r~ 0 a G C7 t0 ~ ~~ ~ ~ '~ .~ °a_ °o_ °a_ °o_ ~ to tea r T`~ L Q k t6 ~~ TRFF = FMC WELLHEAD = FMC ACTUATOR = AXELSON KB. EL.EV - 61' BF. ELEV = KOP = 3200' _,~ Max Angle = -_. 36 @-8800' Datum MD = 9800' -Datum TVD = 8800' SS I9-518" CSG, 47#, L-80, TGII, ID = 8.681 13-3/8" CSG 72#, MN-80, ID = 12.347" `,~, I 2708' I 3 s SA 'NOTES: ""4-1(2" CNROMETUBING"* --C2O$$' 4-1/2" HES X NIP, ID~ 3.813" 2248' 9-518" HES E5 CEMENTER 2326' 9-518^ FOG 2451' 9-518" FOC , GAS LIFT MANDRELS ~` ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 2991 2990 5 MMG DOME RK 16 07109(07 4 4908 4776 29 MMG DOME RK 16 07(09107 3 6362 6022 33 MMG DOME RK 16 07/09!07 2 7524 6987 35 MMG SO RK 28 07/09/07 1 8719 7970 35 MMG DMY RK 0 02!17/07 879~~--14-1/2" HES X NIP, ID = 3.813" Minimum ID = 2.79" @ 9214' 5-112" TUBING PATCH 5-112" 7BG STUB, ID = 4.892 ~ $864' 4-112" TBG 12.6# 13CR-80, ~ 8883' VAM TOP, .0152 bpf, ID = 3.958" 5-112" TBG-PC 17#, L-80, .0232 bpf, ID = 4.892" PERFORATION SUMMARY REF LOG: BRCS ON 11/06/76 ANGLE AT TOP PERF: 33 @ 9604' Note: Refer to Production DB for historical perf data SIZE I SPF I INTERVAL { Opn/Sqz I DATE ~ SEE PG 2 FOR PERFORATION DATA PBTD 10255' 9-5/8" CSG 47#, MN-80, ID = 8.681" 1033T TD 10370' $$11' 9-5t8 x 4-112" BKR S-3 PKR, ID = 3.813"' $835' --~ 4-1 t2" HES X N1P, ID = 3.813" 88$3' 4-1/2" WLEG, ID = 3.958' PRODUCTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 8 8916 8129 36 MMG SO RK 28 02/23/01 9 9071 8256 36 MMG DMY RK 0 11113(76 10 9229 8385 35 MMG 'DCR RKP 0 08117/89 v€~i~iNHL vvt=LLtturc~ -° escnnvu i ese~ rh ~ ~n 9115' TOP OF CEMENT DONUT: ID = 2.79" {TAGGED 01104199} 9214' - 9236' 5-1/2" X 21' ALPHA TBG PATCH (02!25!99} 9298' 9-518" X 5-112" BKR S-3 PKR, 1D = 6,000" g4O$' 5-112" OTIS XN NIP, ED = 4,455" 9422' S-112" BKR SHEAROUT SUB 9423° 5-112" TUBING TAIL 9414° --~MD TT LOGGED 11(021$7 g$2g' FISH - 5116" RKP { 11!02!91 } 9$51' FISH -IBP RUBBER ELEMENT {01(18!99) FISH - 2 CA-RD-RK's (08117/89) DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11!13!76 ORIGINAL COMPLETION 07/19/07 SWCIPJC GLV CIO (07109!07} WELL: 03-08 11/12/86 RWO 07(20107 SWCIPJC CMT, GLV CORRECTION PATGH,_,,..,_,.~_....,,...~ S PERMIT No: 1760730 02/18/O7 N4ES RWO AP( No: 50-029-20231-00 03(05107 ?/ MWS DRLG DRAFT CORRECTIONS SEC 11, T10N, R15E, 1395.51' FEL & 1608.76' FNL 03/21/07 JCM/TLH IBP PULLED &GLV C/U (03119!07) 03/30/07 GJB/PJC DRLG DRAFT CORRECTIONS BP Exploratian {Alaska) PERFORATION SUMNtARY REF LOG: BHCS ON 11/06/76 ANGLE AT TOP PERF: 33 @ 9604' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 3-318" 6 9604 - 9636 O 11/02/87 3-318" 4 9732 - 9772 O 01110/85 3-3/8" 4 9774 - 9788 O 01/10/85 3-3/8" ? 9789 - 9793 O 11/02/87 3-3/8" 4 9804 - 9829 O 01/10(85 3-318" 4 9831 - 9842 O 01/10/85 3-3/8" 4 9850 - 9860 O 01/10/85 3-318" 4 9870 - 9875 O 01/10/85 3-318" ? 9915 - 9918 O 11(02187 ? 4 9909 - 9944 S 01 /01 /85 2" 6 9910 - 9930 O 03/13/01 2" 4 9957 - 9977 S 01!01185 DATE REV BY COMMENTS DATE REV BY GOMMENTS PRUDHOE BAY UNIT 11!13/76 ORIGINAL COMPLETION 07/19/07 SWClPJC GLV C/O (07!09(07} WELL: 03-08 ' 11!12!86 RWO 07/20/07 SWC/PJC PATCH, CMT, GLV CORRECTION S 1760730 PERMff No: 02/18107 N4ES RWO API No' S0-029-20231-00 03/05!07 ?/ MWS DRLG DRAFT CORRECTIONS SEC 11, T10N, R15E, 1395.51' FEL & 160$.76' FNL 03(21/07 JCIWTLH IBP PULLED &GLV C1O (03119/07) 03/30/07 GJB/PJC DRLG DRAFT CORRECTIONS BP Exploration {Alaska} 03-08 (PTD #1760730) Reclassi~as Not Operable -Hydrates in OA • Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well integrity Engineer [NSUADWWe111ntegrityEngineer@BP.com] ~~ ~j ~I ~~ Sent: Saturday, March 08, 2008 1:53 PM I To: Regg, James B (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FSZ/COTU OTL; GPB, FS2 DS Ops Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor; Colbert, Chris M Cc: NSU, ADW Well Integrity Engineer; Roschinger, Torin T. Subject: 03-08 (PTD #1760730) Reclassified as Not Operable -Hydrates in OA All, Well 03-08 has been found to have sustained casing pressure in the OA. The TIOs on 03/07!08 were 280/1670/1040 psi. A comparative analysis of the IA gas to the OA gas confirms that there are hydrates pre~nt in the OA. Because Operations is unable to maintain the OAP below MAASP with several bleeds, the well has been shut-in and reclassified ~' as Not Operable. Please contact Well Integrity if the OA bleed frequency does not slow as the well cools. Call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~h5 APR ~ ~ 200 3/19/2008 ell ob 011 Description ate olor Z-20 11686722 PRESS/TEMP SURVEY 02/26/07 1 P2-35 11657107 PRODUCTION PROFILE 02/19/07 1 L5-28A 11661127 MEMORY STP 01/30/07 1 NK-43 11686716 PRODUCTION PROFILE 02/17/07 1 C-06B N/A MEM PROD PROFILE 02/25/07 1 05-31A 11686719 SCMT 02/19/07 1 03-02 . 11626072 USIT CORROSION EVALUATION 02/22/07 1 03-02 11626072 USIT CEMENT EVALUATION 02/22/07 1 2-54/Q-12 11626376 USIT 02/22/07 1 - 4-18/S-30 11638613 USIT 02/12/07 1 DS 03-08 11630455 USIT 02/07/07 1 DS 16-20 11666863 PRODUCTION PROFILE 01/26/07 1 14-24 . 11549359 RST 12/26/06 1 1 U-06BPB1 40011873 OH EDIT MWD/LWD 05/01/05 2 1 U-06B 40011873 OH EDIT MWD/LWD 05/08/05 2 1 Schlumberger Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2836 ATTN: Beth W 03/15/2007 NO. 4184 1"1-0-07-3 Company: State of Alaska Alaska Oil & Gas Cons Gomm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay J # L D BL C CD . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. 3 '>001 Petrotechnical Data Center LR2-1 SCANNED APR 0 . f.. 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: /4 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 'I Received by: u._ rJÞJ;~ 'I ~ I;,¡ '(nOT ~~ . STATE OF ALASKA .f "0°1.. RECEIVED ALA Oil AND GAS CONSERVATION COM~ON 1l¡'~ MAR 0 2 Z007 REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commission 1. Operations Performed: Anchorage o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 176-073 - 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20231-00-00 ~ 7. KB Elevation (ft): 61' 9. Well Name and Number: PBU 03-08 / 8. Property Designation: 10. Field / Pool(s): ADL 029331 Prudhoe Bay Field / Prudhoe Bay Pool ..- 11. Present well condition summary Total depth: measured 10370 feet true vertical 9338 feet Plugs (measured) 9297 Effective depth: measured 10255 feet Junk (measured) None true vertical 9242 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 73' 20" 101' 101' 1530 520 Surface 2677' 13-3/8" 2707' ~ .....-.. 5380 2670 2708' Intermediate Production 10307' 9-5/8" 10337' 9311' 6870 4760 Liner 6CAHNED MAR 1 , 2007 Perforation Depth MD (ft): 9604' - 9930' Perforation Depth TVD (ft): 8697' - 8970' 4-1/2",12.6# 13Cr80 9423' Tubing Size (size, grade, and measured depth): & !;-1/," 17# & I-RO 9-5/8" x 4-1/2" Bãker~~j' þãêkêr'; . ··"c..,.,·...· 8811'; Packers and SSSV (type and measured depth): 9-5/8" Baker 'SB-3' packer 9298' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut & pull tubing from -8880'. Cut & pull 9-5/8" casing from -2257'. Run new 9-5/8" tieback to surface. Cement w/ 151 Bbls Class 'G' (848 cu ft / 731 sx).Run new Chrome tubinQ. 13. Representative Dailv AveraQe Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil o Gas o WAG OGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 307 -003 Printed Name Terrie Hubble Title Technical Assistant Signature/'fÓJ¡1\.ÌL 6i, I ~ Date 0 "'(z.,ek 7 Prepared By Name/Number: Phone 564-4628 Terrie Hubble, 564-4628 Fonn10-404 _;"'04I2OÖ R \ GINA L RBDMS Bfl MAR ] z lOOí Submit Original Only Digital Wellfile , W~II Events for SurfaceWell - 03- 8 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS2 -> 03 -> 03-08 Date Range: 10/Dec/2006 to 02/Feb/2007 Data Source(s): AWGRS Events Source Well AWGRS 03-08 Date 02/02/2007 AwG8S 03-08 01/26/2007 AwGRS 03-08 01/25/2007 AWGRS 03-08 AWGRS 03-08 AWGB5 03-08 AWGRS 03-08 01/24/2007 01/24/2007 01/22/2007 01/09/2007 AWGRS 03-08 01/08/2007 AWGRS 03-08 01/07/2007 AWGRS 03-08 01/06/2007 AWGRS 03-08 01/05/2007 A~G8~ 03-08 01/04/2007 AWGRS 03-08 01/03/2007 AWGRS 03-08 12/30/2006 AWG8S 03-08 12/24/2006 AWGRS 03-08 12/17/2006 AWGRS 03-08 12/16/2006 AWGRS 03-08 12/10/2006 Page 1 of 1 . Description T/I/O = BPV/Vac/90. Temp = S/I. AL and Flowline removed. Bleed WHPs to 0 psi. Bled OAP to tank from 90 psi to 0+ psi in 30 miniutes. Post 30 minute monitor OAP increased 5 psi. Bled OAP from 5 psi to 0 psi in 20 minutes. Post 30 minute monitor OAP increased to 0+. FWHPs = BPV/VAC/O+. T/I/O = 220/Vac/20. SI. AL spool disconnected. Companion valve with integral. BPV in the hole. WHPs post-bleed (pre-Rig, 01/29). OAP increased 15 psi, no change in TBG or lAP since yesterday. T/I/0220/vac/130. SI. Bleed OAP to 0 psi (pre-Rig, 01/29). Flow line pressure=220 psi. OA FL @ 84'. BPV in tubing. Bled OAP from 130 psi to 0 psi in 2.5 hours. Bled TBG from 220 psi to 0 psi in 2 minutes. Monitored 1 hour. TBG pressure increased 220 psi & OAP increased 5 psi. Final WHP's=220/vac/5. SET BPV THRU TREE PRE RIG WORK API VALVE SHOP set bpv/ pre rig T/I/O= SSV/VAC/120. Temp= SI. AL disconnected. WHP's (eval OAP, pre-RWO). T/I/O= 0+/VAC/60. Temp= SI. AL= Spool Dropped. WHP's (pre RWO). OAP increased 60 psi overnight. Integral on the companion valve. Bolts not fully threaded on WH = 3 0' Clock on the TBG head adapter & 3, 5, 6, 11 O'Clock on the bottom side of the master valve. T/I/O = 0/Vac/160. SI. Companion valve, AL spool dropped. Bleed OAP to 0 psi (pre RWO). OA FL @ 60'. Bleed OAP to bleed trailer to 0 psi (lhr 40 min) all gas. Monitor 30 min. Final WHPs = O/Vac/O. T/I/O= 0/0/150. Temp= SI. AL= Spool Dropped. WHP's (pre PPPOT). OAP increased 150 psi overnight. T/I/O=O/O/O, Pre-Rig PPPOT-T (PASS), PPPOT-IC (FAIL). PPPOT-T, sting into TBG hanger test port with bleeder tool, 0 psi. Pumped through void untill dead fluid was achieved. Pressured void to 5000 psi for 30 min, lost 50 psi in first 15 min, 0 psi in second 15 min. Functioned LDS, all pins moved freely. PPPOT-IC, sting into test port with bleeder tool, 0 psi. Pressured void to 3000 psi, pressure dropped to 1000 psi, functioned LDSjgland nuts, all pins moved freely. Pressured void to 3000 psi, pressure decreased to 1000 psi. ***Continued from 1-4-07 WSR*** Circ-Out (PRE RWO) Pumped 5 bbls neat, 939 bbls 1% kcl down the tubing, up the IA taking returns down the flowline to production. Freeze protect TBG x IA w/150 bbls diesel. Freeze protect flowline w/ 7 bbls neat meth, 60 bbls crude & 23 bbls diesel. Attempt CMIT TxIAxOA 2000 psi as per procedure, unable to get OA to track TxIA. (see log) MIT OA 2000 psi ***PASSED*** Loaded & pressured up OA to 2000 psi w/16 bbls diesel. OA passed w/loss of 40 psi in 15 min. & 20 psi in 2nd 15 min. CMIT TxIA 2000 psi ***PASSED*** Pressured up TxIA to 2000 psi w/5 bbls diesel. T/IA lost 40/0 in 15 min. & 20/0 in 2nd 15 min. Bled all pressures. Final WHP's=O/O/O T/I/O= 650/820/400 Temp= S/I Circ-Out (PRE RWO) ***Continue on 1-5-07 WSR*** ****** Rig up to well at - 36 temp fell to - 42 Standby for temp to warm up****** -------- Job postponed do to weather--------- T/I/O= 520/920/400. Temp= SI. OA FL (OA FL Survey). OA FL @ 228'. WELL SHUT IN ON ARRIVAL. SHOT 4.15" SCP POWER CUTTER AT 8880', DEPTH IS MIDDLE OF FIRST FULL JOINT ABOVE GLM AT 8912' TUBING TALLY DEPTH. JOB TURNED OVER TO DSO. *****JOB COMPLETE***** *** WELL SHUT IN ON ARRIVAL *** (PRE RWO) Drifted w/4.50" centralizer. SD @ 9212' SLM DUE TO TBG PATCH, TARGET DEPTH 8890' MD *** WELL S/I ON DEPARTURE, NOTIFIED DSO *** IBP MONTHLY RENTAL FOR 11/01/06 - 0/01/07. MOs 2 & 3. NOTE IBP SET 10/01/06 1/31/07: WATCH FOR RIG PULLING OF PLUG DURING UPCOMING RWO (PLUG ORIGINALLY SET TO SECURE) SLIM CEMENT MAPPING TOOL TAGGED PLUG AT 9311'. LOGGED FROM PLUG TO 8400'. FOUND TOP OF CEMENT AT 8906'. TOOK PULL AT 5310' WHILE POOH. T/I/O 500/850/1100 *****JOB COMPLETE***** http://digitalwellfile.bpweb.bp .com/W ellEvents/Home/Default.aspx 2/28/2007 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-08 03-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/2/2007 Rig Release: 2/18/2007 Rig Number: Spud Date: 10/21/1976 End: 2/2/2007 21 :00 - 00:00 3.00 RIGD P POST Scope and lower Derrick. Disconnect and rig down Sub Base, Pits and Pipe Shed Modules. 2/3/2007 00:00 - 03:00 3.00 RIGD P POST Continue RD of Rig and Modules. 03:00 - 09:30 6.50 MOB P PRE Move Rig and components to DS 03 from DS 11. 09:30 - 15:00 5.50 RIGU P PRE Arrive at DS3. Spot rig over well and tie-in pit module and pipe shed. Spot Camp and connect to Rig power. Raise and scope Derrick. 15:00 - 17:30 2.50 RIGU P PRE Connect lines to Tiger Tank. Begin taking on hot 1 % KCL into Pits. Connect lines to Tree. Accepted Rig at 15:00 hrs on 2/3/2007. 17:30 - 18:30 1.00 WHSUR P DECOMP RU Lubricator with Drill Site Maintenance Techs. Pull BPV and no pressure observed on the well. RD Lubricator. Pre-tour safety meeting with pre-kill operation/procedure discussed. Service Rig including Derrick inspection and PVT Alarms check - OK. 18:30 - 22:00 3.50 KILL N RREP DECOMP Service Flange to Flange connection on Mud Valve on discharge line from Mud Pump in the Pits. New API Ring installed. The connection was found to be leaking during a Packer test on previous well (11-24A). Tested the connection to 3,500 psi - OK. 22:00 - 00:00 2.00 KILL P DECOMP Pre-kill safety meeting with all employees. Open up well and note pressures: Tbg = 0 psi, IA = 0 psi, OA = 0 psi. Break circulation down the Tubing and up the IA through the Micromotion at 3 bpm / 20 psi and continue to walk up to 5 bpm / 30 psi. Started getting returns after 34 bbls pumped. Pump pressure = 460 psi, IA pressure = 190 psi with diesel returns. Increase pump pressure to 5.5 bpm / 620 psi with IA = 330 psi. 2/4/2007 00:00 - 00:30 0.50 KILL P DECOMP Continue circulating well at a rate of 5.5 bpm / 600 psi on the Tubing and 310 psi on the IA. Pumped a total of 655 bbls of hot 1 % KCL. Shut down and monitor well dead - OK. Both the Tubing and IA are 0 psi and static. 00:30 - 02:00 1.50 KILL P DECOMP Pressure test the well against the IBP @ 9,308' to 1,000 psi for 10 mins. The test lost 200 psi in 10 mins. The OA pressure increased from 0 psi to 100 psi. Bump back up and it lost 250 psi in 15 mins. The OA pressure remained at 100 psi. Try a third time and lost 200 psi in 10 mins. The OA pressure increased to 125 psi. Discuss with Anchorage Engineering and the IBP is considered a competent barrier because it is holding a column of kill weight fluid above it. Bleed test pressure off of well. Blow down lines. 02:00 - 02:30 0.50 WHSUR P DECOMP PU T-bar and set BPV with FMC reps. Test from below to 1,000 psi for 10 mins. The test pressure lost 300 psi but no fluid seen above the BPV and it remained in the profile - OK. The swab valve was slightly opened to verify that no fluid was coming up past the BPV - OK. 02:30 - 03:00 0.50 WHSUR P DECOMP PJSM with Nabors and FMC personnel on ND Tree. 03:00 - 05:00 2.00 WHSUR P DECOMP ND 7 1/16" Cameron Tree and Adapter Flange. Inspect Hanger threads - OK. Screw on Blanking Plug with no problems. 05:00 - 08:00 3.00 BOPSU P DECOMP PJSM. NU 13 5/8" BOPE. 08:00 - 18:30 10.50 BOPSU P DECOMP Test BOPE per BP/AOGCC regulations, 200 psi low pressure test/3500 psi high pressure test. All tests witnessed by Nabors toolpusher (Steve Bounds) and BP WSL (Dave Reem). Tests Printed: 2/19/2007 1 :06:48 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-08 03-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/2/2007 Rig Release: 2/18/2007 Rig Number: Spud Date: 10/21/1976 End: charted. 3" x 6" VBRs tested OK on the 3.5" test joint, failed completely on the 5-1/2" test joint. Round up set of 5-1/2" pipe rams and install same. Re-test with 5-1/2" test joint (OK). Continue with BOPE test. 18:30 - 20:00 1.50 WHSUR P DECOMP PU Landing Joint and pull Blanking Plug with FMC reps. RU Lubricator and pull BPV with Drill Site Maintenance Techs. RD Lubricator. 20:00 - 21 :00 1.00 PULL P DECOMP MU Landing Joint to Hanger. BOLDS with FMC reps. Pull on Hanger and came free at 200K. Pull Hanger to the Floor with an UW = 150K. Set Slips and cut Control Line with SWS rep. 21 :00 - 21 :30 0.50 PULL P DECOMP Break down and lay down Tubing Hanger Assembly. LD Landing Joint. The pin end on the Pup Joint below the Hanger was corroded and had holes in it. 21 :30 - 22:30 1.00 PULL P DECOMP RU Spooling Unit with SWS rep. Change out elevator from 3 1/2" to 51/2". MU Headpin and fill up well with 16 bbls of 1% KCL. Monitor well dead - OK. Blow down and break off Headpin. 22:30 - 00:00 1.50 PULL P DECOMP POOH with existing 51/2",17#, L-80, LTC AB Modified Tubing laying down 1 x 1 in the Pipe Shed. Spooling up dual control line with SWS rep. The Joints of Tubing do not appear to be in too bad of shape. 2/5/2007 00:00 - 06:00 6.00 PULL P DECOMP Continue POOH with existing 5 1/2" Tubing spooling up dual control line. After 53 Joints laid down, RD Spooling Unit. Recovered a total of 30 out of 32 Stainless Steel Bands. Continue POOH. Encountered a hole in Joint #127 (8 Joints down from GLM #2). Continue POOH maintaining well full of 1 % KCL. 06:00 - 11 :00 5.00 PULL P DECOMP POOH with 5-1/2" completion down to the cut. Cut was flared out with two minor splits. No additional holes were observed other than the one found in #127. 11 :00 - 12:30 1.50 CLEAN P DECOMP Clear and clean rig floor. RD 5-1/2" handling equipment, RU 3-1/2" drill pipe handling equipment. Drill pipe is loaded in the shed and strapped. 12:30 - 14:45 2.25 BOPSU P DECOMP Set and PT test plug. Drain stack. Remove 5-1/2" pipe rams, install 3" x 6" VBRs. Attempt to test VBRs. Tubing spool gland nuts at balance and control line ports starting to scope out of tbg spool and leak. SD test operations and hot-shot FMC tech to remove these gland nuts and install blanking plugs in these ports. 14:45 - 15:30 0.75 BOPSU P DECOMP Waitng on FMC tech. 15:30 - 16:00 0.50 BOPSU P DECOMP Install blanking plugs in tbg spool. Test VBRs to 250 psi/3500 psi per BP/ AOGCC regs. Good test. LD test jt, pull test plug, install wear ring. 16:00 - 18:00 2.00 CLEAN P DECOMP M/U BHA #1: 4-1/2" mule-shoe 20' pup jt, XO, XO, 9-5/8" scraper, 2 boot bskts, bit sub, bumper sub, jar, XO, 96-1/2" collars, XO to drill pipe. BHA OAL = 337.05'. 18:00 - 18:30 0.50 CLEAN P DECOMP Pre-tour safety meeting and service Rig. Derrick inspected and PVT checked - OK. 18:30 - 00:00 5.50 CLEAN P DECOMP TIH with BHA #1 on 3 1/2" DP from the Pipe Shed 1 x 1. A tight spot was encountered at approximately 2,325'. Worked the Scraper Assembly a couple of times up and down through it until no weight bobbles seen anymore. Continue TIH. 2/6/2007 00:00 - 04:00 4.00 CLEAN P DECOMP Continue TIH with BHA #1 while picking up DP 1 x 1 from the Printed: 2/19/2007 1 :06:48 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-08 03-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/2/2007 Rig Release: 2/18/2007 Rig Number: Spud Date: 10/21/1976 End: 2/6/2007 00:00 - 04:00 4.00 CLEAN P DECOMP Pipe Shed. 04:00 - 05:00 1.00 CLEAN P DECOMP In with 269 Joints of DP. PU and MU Kelly. UW = 150K , DW = 130K. Break circulation at a rate of 3 bpm 1330 psi. Tag top of 5 1/2" Tubing Stump 16' in on the Kelly = 8,868'. PU and rotate to try and slide inside the 5 1/2" Tubing. Re-try several times until finally got inside. Continue RIH inside of the 5 1/2" Tubing to 36' in on the Kelly = 8,888'. Observed pump pressure increase of 20 psi. Total swallow inside 51/2" Tubing = 20'. POOH to approximately 10' above Tubing Stump. 05:00 - 08:00 3.00 CLEAN P DECOMP Line up to reverse circulate. Close Annular. Reverse circulate the well bore clean at a rate of 5 bpm 11,100 psi utilizing a 20-bbl Hi-Vis Sweep. 08:00 - 12:30 4.50 CLEAN P DECOMP POH standaing back DP and DC. UD BHA #1. Call out Halliburton for the RBP. Conduct BOP drill in middle of trip out. 12:30 - 13:30 1.00 CLEAN P DECOMP Clear and Clean rig floor. 13:30 - 15:00 1.50 CLEAN P DECOMP PUMU Halco 9-5/8" RBP. RIH to 60'. Set RBP. Release RBP. 15:00 - 19:00 4.00 CLEAN P DECOMP RIH w/RBP. In with 279 Joints of DP. UW = 129K , DW = 114K. Set 9 5/8" RBP @ 8,831' Center of Element. The top of the RBP is @ 8,826'. Slack off to 100K down weight (14K down) to verify set - OK. 19:00 - 20:30 1.50 CLEAN P DECOMP POH 1 stand of Drill Pipe and MU Headpin. RU Test Equipment. Pressure test the 9 5/8" RBP to 3,500 psi for 30 mins charted. It took 8.5 bbls to reach test pressure. Test #1: The 9 5/8" lost 300 psi in 15 mins. The OA pressure increased to 1,000 psi. Test #2: Bump the 9 5/8" back to 3,600 psi and lost 100 psi in 30 mins. It lost 80 psi in the first 15 mins and 20 psi in the second 15 mins. The OA increased to 1,200 psi in increments of 100 psi each 15 mins. Consult with Anchorage Engineering and the test is considered good. Bleed down pressure on the well. 20:30 - 00:00 3.50 CLEAN P DECOMP TOH with RBP Running Tool Assembly standing back DP in the Derrick. 2/7/2007 00:00 - 00:30 0.50 CLEAN DECOMP Break down and lay down RBP Running Tool Assembly with Halliburton rep. 00:30 - 02:30 2.00 EV AL DECOMP PJSM. ND Flow Riser. NU Shooting Flange. 02:30 - 04:30 2.00 EV AL DECOMP PJSM with E-line. RU E-line to Shooting Flange. MU US IT Logging Tool Assembly. 04:30 - 06:00 1.50 EVAL DECOMP RIH with USIT Logging Tool. 06:00 - 12:00 6.00 EVAL DECOMP Run USIT log in cement/corrosion mode from 8820' to surface. RBIH wllogging tools to run Hi-Res corrosion logs from 4,710'-4,830',4,990'-5,080',5,150'-5,350' and 7,125'-7,210'. TOC @ 2,525' with stringers up to 2,340'. 12:00 - 13:00 1.00 EVAL DECOMP UD USIT logging tool string. 13:00 - 13:30 0.50 EVAL DECOMP PJSM - All crew. Review string shot procedures with rig crew and SWS E-line personnel. 13:30 - 16:00 2.50 EVAL DECOMP PUMU RIH wlString Shot tool string. PIT packoff to 100-psi. Correlate String Shot depth to CCL log. Fired String Shot across casing collar @ 2251' WLM. Top of shot @ 2246' WLM. 16:00 - 19:00 3.00 CLEAN DECOMP POH UD String Shot tool string. RDMO E-line equipment. ND shooting flange. NU flow riser and Drip Pan. Move 6 3/4" Drill Collars to adjacent rack on Derrick now that E-line is out of the Printed: 2/19/2007 1 :06:48 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-08 03-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/2/2007 Rig Release: 2/18/2007 Rig Number: Spud Date: 10/21/1976 End: 2/712007 16:00 - 19:00 3.00 CLEAN DECOMP way. 19:00 - 19:30 0.50 DHB TIEB1 PU and MU 9 5/8" RBP with Halliburton rep. 19:30 - 21 :30 2.00 DHB TIEB1 TIH with 9 5/8" RBP on 3 1/2" DP from the Derrick. In with 37 stands of DP (111 Joints). UW = 59K , DW = 59K. Set 9 5/8" RBP @ 3,525' COE with the top of the Plug @ 3,520'. 21 :30 - 00:00 2.50 DHB TIEB1 Pressure test against the RBP to 1,000 psi for 15 mins , charted - OK. Performed 3 different 15 min tests to show signs of stabilization since test pressure was being lost to the OA. The last 15 mins the test pressure went from 1,100 psi to 1,000 psi in 15 mins. Consulted with Anchorage Engineering and given OK to proceed. Dump 2,200 Ibs of 20/40 mesh sand on top of RBP. 2/8/2007 00:00 - 01 :00 1.00 EVAL P TIEB1 Continue dumping 20/40 sand on top of 9 518" RBP @ 3,525'. 01 :00 - 02:00 1.00 EVAL P TIEB1 Flush out DP to ensure all sand on top of RBP. RIH and tag sand @ 3,469' (51' of sand). 02:00 - 03:30 1.50 EVAL P TIEB1 TOH with RBP Setting Tool Assembly standing back DP in the Derrick. 03:30 - 04:00 0.50 CASE P TIEB1 On surface with RBP Setting Tool Assembly. Lay down with Halliburton rep. PU and MU BHA #2 as follows with Baker rep: Multi-String Cutter, XO, Stabilizer, XO. OAL = 12.38'. 04:00 - 06:00 2.00 CASE P TIEB1 TIH with BHA #2 on 3 1/2" DP from the Derrick. In with 70 Joints of DP. Kelly up. 06:00 - 06:30 0.50 FISH P TIEB1 Mechanically locate casing collar @ 2,239' which is deeper by 9' than E-line CCL log. Mechanically locate 1 st casing collar 43' above connection to be backed off @ 2,219'. Position MS Cutter @ 2,239' and establish cutting parameters. PUW = 48K, SOW = 45K, 4.0-BPM @ 650-psi., 11 O-Amps free torque @ 72-RPM. 06:30 - 07:15 0.75 FISH P TIEB1 Commence cutting operations @ 06:35-hrs. Finish cut @ 2,239' @ 06:50-hrs. SID pump. S/I annular preventer and open OA to open top tank. Establish circulation through OA to open top tank @ 4.0.-BPM @ 900-psi. Crude oil returns to open top tank from OA. Pumped 3.0-Bbls. to clear IA of possible contamination from OA. SID rig pump. 07:15 - 09:30 2.25 FISH P TIEB1 Open annular preventer and line up well to circulate heated 120F seawater through DP taking returns from IA to rig pits to warm up wellbore. 09:30 - 12:00 2.50 FISH P TIEB1 Displace DP and IA to spot 100F Diesel at cut at 2,239'. Close annular preventer and displace 130-Bbls. heated Diesel to OA @ 4.0-BPM @ 1080-psi decreasing to 650-psi. while takiing returns to open top tank. Crude oil and Diesel returns noted. Did not see any Arctic Pac in returns. SID pumping once Diesel spotted and displace 3-1/2" x 9-5/8" annulus with 137-Bbls. 9.8-ppg NaCI brine. Close annular preventer and displace diesel from OA to open top tank with 9.8-ppg NaCI brine. At 58-Bbls. brine pumped, started taking 9.8-ppg NaCI brine in returns. SID pumping and let well stabilize. 12:00 - 12:30 0.50 FISH P TIEB1 Wait for well to stablize. 12:30 - 14:45 2.25 FISH P TIEB1 Set Kelly back in rathole. POH UD BHA #2. 14:45 - 16:30 1.75 WHSUR P TIEB1 PUMU pulling tool for 9-5/8" casing packoff. Sting into packoff and attempt to rotate 1 full turn to left. NO rotation possible. BOLDS and pull mandrel packing to floor. with 50K overpull. UD packoff pulling tool. Printed: 2/19/2007 1 :06:48 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-08 03-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/2/2007 Rig Release: 2/18/2007 Rig Number: Spud Date: 10/21/1976 End: 2/8/2007 16:30 - 17:30 1.00 FISH P TIEB1 PUMU BHA #3 - 9-5/8" ITCO spear w/8.681" grapple on one joint 3-1/2" DP. 17:30 - 18:00 0.50 FISH P TIEB1 Engage the Spear in the 9 5/8" and pull. It came free at 120K and came to the Rig Floor with 117K. Break out and lay down Spear. 18:00 - 19:00 1.00 FISH P TIEB1 RU 9 5/8" Handling Equipment. MU Headpin. 19:00 - 21 :00 2.00 FISH P TIEB1 Break circulation down the 9 5/8" and up the OA. Getting gassy Arctic Pack back to surface. The 9 5/8" is coated on the outside with Arctic Pack. Line up returns to the open top Tank. Break circulation at a rate of 4 bpm I 300 psi with 160 psi on the OA. Reciprocate the 9 5/8" while pumping to aid in Arctic Pack removal. The returns would alternate from clean brineldiesel returns to thick Arctic Pack throughout the process. Pumped a total of 180 bbls and shut down to wait for more brine. 21 :00 - 23:00 2.00 FISH P TIEB1 Wait on vac truck to arrive on location with more 9.8 ppg brine. Hold safety discussion with crew about safety culture on the Rig and how to improve it - mini Stand Down. 23:00 - 00:00 1.00 FISH P TIEB1 Take on heated 9.8 ppg brine into the Pits. 2/9/2007 00:00 - 01 :00 1.00 FISH P TIEB1 Resume circulating down the 9 5/8" and up the OA taking returns to the open top tank. Break circulation at a rate of 4 bpm 1200 psi with 70 psi on the OA. Increase rate to 4.5 bpm I 320 psi with 180 psi on the OA. Pumped a total of 180 bbls. Never saw any significant amount of Arctic Pack in the returns. 01 :00 - 02:00 1.00 FISH P TIEB1 Blow down lines and break down Headpin. Open up Annular. Monitor well. The fluid is breaking out gas and falling as the gas breaks out of it. 02:00 - 15:30 13.50 FISH P TIEB1 POOH with existing 9 5/8",47#, MN-80 BTC Casing. Having a difficult time breaking out the connections. Having to hammer each Collar and utilize the 9 5/8" Rig Tongs to get the connection to break out prior to using the Power Tongs. Each Joint of Casing is completely coated in Arctic Pack. Circulated two times while POH. Very small amount of Arctic Pac in returns both times. Torque required to break out connections varying from 45K ft-Ibs. to 60K ft-Ibs. Joint #34 OOH at 1045-hrs. Laid down 57 full joints and a cut joint. Cut joint length = 22.39' . Cut looks uniform and is very slightly flared out. Recovered 8 bow spring centralizers. 15:30 - 18:00 2.50 FISH P TIEB1 C & C rig floor. Rig down casing handling tools. Prep to run scraperlwashpipe BHA. 18:00 - 19:00 1.00 FISH P TIEB1 PU Spear and break out from 9 518". Lay down the Spear. 19:00 - 20:30 1.50 FISH P TIEB1 PU and MU BHA #4 as follows: 12 118" Washpipe Shoe, 11 3/4" Washpipe, Junk Basket, XO, 133/8" Scraper, Bit Sub, Bumper Sub, Oil Jar, XO, Float Sub, (9) 6 3/8" Drill Collars, XO. OAL = 347.62'. 20:30 - 00:00 3.50 FISH P TIEB1 TIH with BHA #4 on 31/2" DP from the Derrick. Stop every 5 stands of DP to circulate out the Arctic Pack to surface. Circulating at a rate of 6 bpm taking returns into the Pits to monitor Arctic Pack returns. 2/10/2007 00:00 - 01 :30 1.50 FISH P TIEB1 Continue TIH with BHA #4 stopping every 5 stands to circulate out Arctic Pack. 01 :30 - 02:30 1.00 FISH P TIEB1 Tag 9 5/8" Stump @ 2,239. PU and MU Kelly. UW = 62K , DW =62K. RIH over Stump down to Collar @ 2,259'. Had to rotate Printed: 2/19/2007 1 :06:48 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-08 03-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/2/2007 Rig Release: 2/18/2007 Rig Number: Spud Date: 10/21/1976 End: 2/10/2007 01 :30 - 02:30 1.00 FISH P TIEB1 (50 RPM) on a Centralizer until it fell. Continue RIH to final depth of 2,274'. PU off of Stump and break circulation at a rate of 5 bpm I 350 psi. RIH washing over same spot with no rotation - no problems, did not see the Centralizer. PU off of Stump and RIH over 9 5/8" Stump without circulation - OK. 02:30 - 03:30 1.00 FISH P TIEB1 Circulate bottoms up at a rate of 6 bpm I 400 psi to finish cleaning out well bore of any Arctic Pack. Saw gassy returns to surface. Pumped a total of 445 bbls with small amounts of Arctic Pack back to surface. 03:30 - 05:00 1.50 FISH P TIEB1 Blow down and set back Kelly. TOH with BHA #4 standing back DP in the Derrick. 05:00 - 06:00 1.00 FISH P TIEB1 On surface with BHA #4. Break down and lay down BHA components. 06:00 - 07:30 1.50 FISH P TIEB1 BOLD BHA #4. 07:30 - 09:30 2.00 FISH P TIEB1 C&C rig floor. Prep to PUMU BHA #5. 09:30 - 11 :30 2.00 FISH P TIEB1 PUMU BHA #5 - 9-5/8" Casing back-off assembly. Gave AOGCC, Chuck Sheve, 24 hr. notice of impending BOPE test as well as explanation of possibility of going 2-3 hrs. past 1-week requirement between tests. 11 :30 - 13:45 2.25 FISH P TIEB1 RIH w/BHA #5 to top of stump. Filled DP wlfresh water while tripping in hole to obtain differential across backoff tool. 13:45 - 14:15 0.50 FISH P TIEB1 Obtain backoff parameters. PUW = 63K, SOW = 57K. Space out backoff tool across casing collar at 2259'. Pressure up DP to 11 OO-psi and set lower anchor. Set 20K downweight on lower anchor plus additional 3" of downstroke. Bleed off pressure to zero. Pressure up DP to 1200-psi and set upper anchor. Slack off total DP weight. 14:15 - 15:30 1.25 FISH P TIEB1 Backoff Casing collar at 2259'. Breakout torque = 40K ft-Ibs. Back out stump 6-1/2 turns. Pick up DP and release backoff tool. Drop pumpout sub dart. Wait 5 minutes for dart to drop. Pressure up DP to 2500-psi 5 to shear open pump-out sub. No shear. 15:30 - 17:00 1.50 FISH P TIEB1 POH w/BHA #5. 17:00 - 18:00 1.00 FISH P TIEB1 Break down and lay down BHA #5 components with Baker rep. 18:00 - 18:30 0.50 FISH P TIEB1 Pre-tour safety meeting, check PVT, Derrick Inspection - OK. Clear and clean Rig Floor. 18:30 - 19:00 0.50 FISH P TIEB1 PU and MU BHA #6 as follows: Bullnose, Spear (8.681" Grapple), Spear Extension, Stop Sub, Bumper Sub, XO. OAL = 20.11'. 19:00 - 20:30 1.50 FISH P TIEB1 TIH with BHA #6 on 3 1/2" DP from the Derrick. 20:30 - 21:00 0.50 FISH P TIEB1 In with 70 Joints of DP. See the top of the 9 5/8" Stump 3' in on Joint #71 = 2,239'. Continue swallowing the Spear until it bottomed out at 10' in on Joint #71 = 2,246' (7' of swallow). PU and overpull 3K to verify the Spear is engaged - OK. Set Slips and begin turning to left with Rotary Table. Attempt to pull - No Joy. Repeat several times and finally backed out completely. Turned a total of 13 times. (Total turns at connection including Backoff Assembly is 19 turns). 21 :00 - 23:00 2.00 FISH P TIEB1 TOH with BHA #6 and 9 5/8" Fish standing back DP in the Derrick. 23:00 - 00:00 1.00 FISH P TIEB1 On surface with 9 5/8" Fish. Cut Joint length = 19.43'. Lay down in Pipe Shed. RD 3 1/2" Handling Equipment. 2/11/2007 00:00 - 01 :30 1.50 CASE P TIEB1 Clear and clean Rig Floor. Printed: 2/1912007 1 :06:48 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-08 03-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/2/2007 Rig Release: 2/18/2007 Rig Number: Spud Date: 10/21/1976 End: 2/11/2007 01 :30 - 03:00 1.50 CASE P TIEB1 RU 95/8" Handling Equipment. RU Nabors Casing (Torque Turn). 03:00 - 03:30 0.50 CASE P TIEB1 PJSM with BP, Nabors, Nabors Casing and Halliburton personnel. 03:30 - 05:00 1.50 CASE P TIEB1 PU and MU Triple Connect Assembly to ES Cementer and Bakerlok the connection. PU and MU the 9 5/8" BTC x TC-II Crossover Joint to the ES Cementer and Bakerlok the connection. 05:00 - 05:30 0.50 CASE P TIEB1 RIH with 9 5/8", 47#, L-80, TC-II Casing. Utilizing Jet Lube Seal Guard on each connection. Filling pipe every 5 joints with 9.8 ppg brine. Utilizing one free-floating Centralizer per Joint. Torque-turning each connection to 17,500 ft-Ibs. 05:30 - 07:45 2.25 CASE P TIEB1 Wait for hydraulic power unit to arrive. Unable to attain adequate torque for TC-II casing connections with rig hydraulic system. Rig up hydraulic power unit to casings tongs. 07:45 - 13:30 5.75 CASE P TIEB1 RIH with 9 5/8",47#, L-80, TC-II Casing. Utilizing Jet Lube Seal Guard on each connection. Filling pipe every 5 joints with 9.8 ppg brine. Utilizing one free-floating Centralizer per Joint. Torque-turning each connection to 17,500 ft-Ibs. 13:30 - 14:45 1.25 CASE P TIEB1 Attempt to screw into 9-5/8" stump @ 2259' with Baker triple connector. Unable to attain screw-in connection. Called and discussed issues with Frank Roach. Decision to POH UD 9-5/8" Casing. 14:45 - 17:00 2.25 CASE C TIEB1 C&C rig floor and rig up to lay down 9-5/8" Casing. Shear open ES cementer to prevent wet trip. ES cementer shear open pressure = 2700-psi. 17:00 - 21 :30 4.50 CASE C TIEB1 POOH with 9 5/8" Casing. 21 :30 - 23:00 1.50 CASE C TIEB1 On surface with HES ES Cementer, Baffle Plate and Triple Connect Assembly. Inspect the Overshot and there are no indications of it having been damaged or bottomed out. There are no rnarkings or paint missing on the bottom. Break out the 11 3/4" Shoe and inspect inside of it. We recovered the Ring from the Centralizer. It was wedged inside of the Shoe and prevented any damage to the BTC Pin end on the Assembly. PU a BTC Collar and MU to the Pin to ensure it is undamaged - OK. Will clean Assembly and ship to Baker Fishing Shop to have the ES Cementer bucked off and a new ES Cementer bucked on. 23:00 - 00:00 1.00 CASE C TIEB1 Clear and clean Rig Floor due to Arctic Pack. 2/12/2007 00:00 - 01 :00 1.00 CASE C TIEB1 Continue clearing and cleaning the Rig Floor. RU to run Drill Collars and Drill Pipe. 01 :00 - 01 :30 0.50 CASE P TIEB1 PU and MU 13 3/8" Storm Packer with Halliburton rep. 01 :30 - 02:30 1.00 CASE P TIEB1 TIH with Drill Collars and Drill Pipe. Set 133/8" Storm Packer @ 107' Center of Element, 100' top of Packer. Release Packer and stand back 1 stand of DP. Pressure test the Storm Packer to 1,000 psi for 15 mins , charted - OK. Drain BOP Stack. 02:30 - 04:00 1.50 BOPSU P TIEB1 Set bottom Test Plug and RILDS. Attempt to fill BOP Stack and fluid running past the Test Plug. Call FMC rep and discuss. They will be sending us a new Test Plug. 04:00 - 05:00 1.00 BOPSU TIEB1 Wait on new Test Plug to arrive on location. RU to test BOPE. 05:00 - 06:00 1.00 BOPSU TIEB1 Tool Service on location. PU and set new Test Plug. Change out sensor for Recording Chart. 06:00 - 13:15 7.25 BOPSU TIEB1 Perform weekly BOPE test perAOGCC/BP requirements. Printed: 2/19/2007 1 :06:48 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-08 03-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/2/2007 Rig Release: 2/18/2007 Rig Number: Spud Date: 10/21/1976 End: AOGCC - Chuck Sheve waived withness test. lay down Test Plug. 13:15 - 14:00 0.75 TIEB1 POH UD 13-3/8" HES Storm Packer. 14:00 - 15:00 1.00 TIEB1 POH SIB 6-1/4" Drill Collars. 15:00 - 16:00 1.00 TIEB1 Rig up Casing handling tools and prepare rig floor to RIH w/9-5/8" Casing. 16:00 - 16:30 0.50 CASE P TIEB1 PJSM - All crew. RIH w/9-5/8" Casing. 16:30 - 22:30 6.00 CASE P TIEB1 RIH wI 9-5/8" 47# TC-II Casing 1x1 from pipe shed. Torqueing connections to 17,500 ft.-Ibs. Filling pipe every 5 jts. w 19.8 #/gal NaCI Brine. Utilizing one free floating Centralizer per Joint of Casing. Ran a total of 53 Centralizers. 22:30 - 00:00 1.50 CASE P TIEB1 In with 54 Joints of Casing to space out on Rig Floor. UW = 105K, DW = 105. MU TC-II to BTC XO and MU BTC Landing Joint. RIH and lightly tag the 9 5/8" Collar @ 2,258'. Begin to screw in with Baker rep. Achieved a total of 8 turns and maximum torque applied was 12K ft-Ibs. Work 9 5/8" up and down several times to ensure the connection was fully made up - OK. Pull test the Casing to 250K - OK. Lay down Landing Joint and MU Headpin. RU test Equipment. 2/13/2007 00:00 - 00:30 0.50 CASE P TIEB1 Pressure test the 9 5/8" Casing to 2,000 psi for 30 mins , charted - OK. 00:30 - 02:00 1.50 CASE P TIEB1 Blow down lines. RD Test Equipment. Break off Headpin. Clear and clean Rig Floor. 02:00 - 04:30 2.50 BOPSU P TIEB1 PJSM. ND BOP Stack. Clean Arctic Pack off of 9 5/8". Set FMC Emergency Slips and engage with 125K. 04:30 - 06:00 1.50 BOPSU P TIEB1 NU BOP Stack. 06:00 - 06:30 0.50 CASE P TIEB1 Finish rigging up lines for cement job. 06:30 - 08:45 2.25 CASE P TIEB1 PIT lines to 3000-psi. Shear open ES Cementer @ 2600-psi. Break circulation at 0645-hrs. @ 5.0-BPM to warm wellbore to 80F. Initial circulating temperature = 60F. Temp. @ 0745-hrs. =70F. 08:45 - 09:15 0.50 CASE P TIEB1 PJSM - All rig crew, Schlumberger Cement crew, Veco Vac Truck drivers & HES Cementers. 09:15 - 10:15 1.00 CASE P TIEB1 Prime up SLB cementers and prepare to pump cement. Repair SLB cementers cement van. 10:15 - 10:30 0.25 CASE P TIEB1 Pump 8-Bbls. Fresh Water to warm and PIT lines. PIT lines to 1400-psi low/5000-psi high. 10:30 - 12:30 2.00 CASE P TIEB1 Btach mix and pump 151-Bbls. cement @ 5.0-BPM with a max. psi of 581-psi taking returns to rig pits. Drop wiper plug and follow with 5-Bbls. cement at 5.0-BPM. Held 110-psi to 400-psi backpressure on annulus during pumping. Displace cement to 9-5/8" annulus with 9.8-ppg NaCI Brine. At 100-Bbls. Brine away, divert returns to open top tank. At 145-Bbls. away, reduce rate to 2.0-BPM. Bump plug @ 870-psi @ 163-Bbls away. Increase pressure to 2133-psi and close ES Cementer. Bled pressure to O-psi. Floats holding. Recovered -1 O-Bbls. neat cement in returns to surface. 12:30 - 13:30 1.00 CASE P TIEB1 RDMO SLB cementers. Vac out open top tank and release vac trucks. Vac out 9-5/8" Casing stump and prepare to ND BOPE, cut Casing and changeout Tubing spool and casing packoff. 13:30 - 16:00 2.50 CASE P TIEB1 ND BOPE and lift stack. Rig up Wachs Cutter. Cut Cut Casing. Cut off jt. length = 22.08'. 16:00 - 23:00 7.00 WHSUR P TIEB1 NU new Tubing Spool and install Casing packoff. Pack off junk Printed: 2/1912007 1 :06:48 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-08 03-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/2/2007 Rig Release: 2/18/2007 Rig Number: Spud Date: 10/21/1976 End: rings were rolled. Had to redress pack off. Changed out check valve on casing spool & installed new check valve in tbg spool. Pressure up & tested pack off to 3400 psi for 30 min. Tested good. 23:00 - 00:00 1.00 TIEB1 NIU BOPE. 2/14/2007 00:00 - 01 :30 1.50 TIEB1 Finish NIU BOPE. Install 2nd annulus valve on tbg spool. 01 :30 - 02:00 0.50 TIEB1 Install test plug. RILDS. Fill stack. RlU test equip. 02:00 - 03:00 1.00 TIEB1 Pressure test BOP body & breaks. LP 250 psi. HP 3500 psi. Charted same. Cement UCA reported +1000-psi compressive strength @ 0300-hrs. 03:00 - 04:00 1.00 TIEB1 RID test equip. Pull & UD test plug. Drain stack. 04:00 - 06:00 2.00 TIEB1 P/U & M/U BHA #7 as follows: 8 1/2" Bit, 2 - Boot Baskets, 95 18" scraper, BS, Bumper sub, Jars, XO, 9 * 6 1/4" DCs, XO. TL = 313.91'. RIH wI same. 06:00 - 07:00 1.00 FISH P TIEB1 RIH wlBHA #7. Tag TOC @ 2133. 07:00 - 14:00 7.00 DRILL P TIEB1 Kelly up. Break circulation and obtain drilling parameters - PUW = 60K, SOW = 60K, 5.5-BPM @ 400-psi & 80-RPM. Commence drilling out cement w/5-6K WOB. Drill out cement to baffle plate @ 2256' and circulate 30-Bbl. hi-vis sweep to clean out hole before drilling out baffle plate. Drill out baffle plate and ream from 2240' to 2260' 14:00 - 15:00 1.00 DRILL P TIEB1 RIH to 3449'. 15:00 - 15:45 0.75 DRILL P TIEB1 Rig up headpin and prepare to reverse circulate hole and swap to seawater. 15:45 - 17:00 1.25 DRILL P TIEB1 Reverse circulate out 9.8# Brine and swap hole to Seawater @ 5.0-BPM @ 300-psi. 17:00 - 18:30 1.50 EVAL P TIEB1 PIT 9-5/8" Casing to 3500-psi. No test, fluids aired up. Circulate well. 98 SPM @ 600 psi. Pumped 250 bbls. 18:30 - 20:00 1.50 EVAL P TIEB1 Attempt to test casing. Could not get satisfactory test. Fluid temperature 110 degrees. Pressure bled off 100 psi in 10 min. No leaks detected. RID test equip. 20:00 - 22:00 2.00 DRILL P TIEB1 POOH & stand back 33 satands of 31/2" DP. 22:00 - 23:00 1.00 DHB P TIEB1 Set back 3 stands of DCs. Break out & UD BHA. Empty junk baskets. (1/2 full wI cmt). M/U BHA #8 as follows: RCJB, BS, LBS, Jars, XO, 9*6 1/4" DCs, XO. TL = 308.82'. 23:00 - 00:00 1.00 EVAL P TIEB1 RlU test equip. Close blind rams & begin testing casing. 2/15/2007 00:00 - 00:30 0.50 EVAL P TIEB1 Finish testing 9 5/8" casing to 3500 psi. Lost 100 psi in 45 min. Could not find any leaks @ surface or in annulus. RID test equip. Clear floor. 00:30 - 01 :00 0.50 FISH P TIEB1 RIH wI BHA #8 & DCs. 01 :00 - 02:30 1.50 FISH P TIEB1 RIH wI 33 stand of 31/2" DP to 3444'. 02:30 - 04:30 2.00 FISH P TIEB1 Cut & slip 84' of drilling line. Adjust brakes. 04:30 - 05:00 0.50 FISH P TIEB1 P/U kelly & break circulation. Tagged fill @ 3469'. Work RCJB from 3469 to 3459'. Wash from 3469 to 3480'. Pump 85 SPM @ 2000 psi. P/U Wt =78K, SIO wt =76k, Rot Wt = 76K. 60 RPMs. Torq. = 1-1.5K. 05:00 - 07:00 2.00 FISH P TIEB1 Circulate bottoms up. Pumped 5 BPM @ 2000 psi. 07:00 - 08:30 1.50 FISH P TIEB1 POH w/BHA #8. Break out RCJB. Recovered parts of baffle plate and cement ring. 08:30 - 10:30 2.00 FISH P TIEB1 RIH wlBHA #8 and tag at 3480'. Kelly up and break circulation. 10:30 - 12:15 1.75 FISH P TIEB1 Cleanout sand to 3510' leaving 10' of sand on top of RBP fishing neck at 3520'. Circulate bottoms up @ 5.0-BPM @ Printed: 2/19/2007 1 :06:48 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-08 03-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/2/2007 Rig Release: 2/18/2007 Rig Number: Spud Date: 10/21/1976 End: 2/15/2007 10:30 - 12:15 1.75 FISH P TIEB1 2000-psi. 12:15 - 14:30 2.25 FISH P TIEB1 POH BOLD JRCJB. Recovered one small piece of cement ring from top of baffle plate. 14:30 - 15:00 0.50 FISH P TIEB1 Clear and clean rig floor. PUMU Halco 9-5/8" RBP OIS 15:00 - 16:30 1.50 FISH P TIEB1 RIH w/RBP OIS to top of sand @ 3510'. 16:30 - 18:00 1.50 FISH P TIEB1 P/U kelly. Close bag & reverse circulate down to top of RBP @ 3525'. Reverse out excess sand. Engage & unset RBP. Allow rubbers to relax. 18:00 - 19:00 1.00 FISH P TIEB1 Circulate bottoms up. Pump 5.4 BPM @ 550 psi. No gas to surface. Pumped total of 225 bbls. 19:00 - 20:30 1.50 FISH P TIEB1 POOH & stand back 31/2" DP. Break out & UD RBP & setting tool. 20:30 - 22:00 1.50 FISH P TIEB1 M/U RBP retrieving O/S. RIH wI 9 . 6 1/4" DCs. 22:00 - 00:00 2.00 FISH P TIEB1 RIH wI Retrieving tool assy on 3 1/2" DP. 2/16/2007 00:00 - 02:00 2.00 FISH P TIEB1 Con't to RIH wI 90 stands of 3 1/2" DP. 02:00 - 02:30 0.50 FISH P TIEB1 P/U kelly. Break circulation 3 BPM @ 670 psi. Circulate down & engage RBP @ 8828'. Put 1 1/2 RH turns in DP & work torq to bottom. Released RBP wI 175K. Allow rubbers to relax. Stroke pipe above & below setting depth & insure plug free & moving. P/U Wt 146K, SIO Wt = 122K. 02:30 - 05:00 2.50 FISH P TIEB1 Circulate bottoms up. Pumped 5.7 BPM @ 1400 psi. Had gas to surface, slowed pump to 3.5 BPM & circulated out gas. Pumped total of 735 bbls. No gain or loss recorded after circulation. 05:00 - 06:00 1.00 FISH P TIEB1 Monitor well. DP flowing -1.0-BPH. Mix 15-Bbl. dry job to 8.6-ppg heavy and pump long way @ 4.0-BPM. Monitor well. No flow. 06:00 - 13:30 7.50 FISH P TIEB1 RIU & POOH. LDDP 1 x1 through pipe shed. 90 jts. OOH @ 0830-hrs. 255 jts. OOH @ 1300-hrs. 13:30 - 14:30 1.00 FISH P TIEB1 POH UD 6-1/4" DC's, RBP OIS and 9-5/8" Halco RBP. Pull wear ring. 14:30 - 18:00 3.50 RUNCMP C&C rig floor. Prepare to RIH w/4-1/2" 12.6#/ft., 13Cr, Vam Top completion. 18:00 - 18:30 0.50 RUNCMP level up rig so blocks clear stabbing guide when @ full extension. 18:30 - 19:00 0.50 RUNCMP Check PVT alarms & inspect derrick. 19:00 - 19:30 0.50 RUNCMP Hold PJSM & review tubing completion running order wI all hands. 19:30 - 20:00 0.50 RUNCMP P/U & M/U tail pipe assys. Baker Lok all connections below packer. 20:00 - 00:00 4.00 RUNCMP RIH w/4 1/2" 12.6#, 13Cr Vam Top completion. Torq Turn all connections to 4440 ft-Ibs using Jet Lube seal Guard lubricant. Ran 60 jts in hole. 2/17/2007 00:00 - 09:15 RUNCMP Con't to RIH w/4 1/2" 12.6#, 13Cr Vam Top completion. Torq turn all connections to 4440 ft-Ibs using Jet Lube Seal Guard lubricant. Ran 165 jts in the hole @ 06:00-hrs.. 205 Jt.s RIH @ 09:15-hrs. 09:15 - 09:45 RUNCMP PU jt. 206. RIH and tag top of 5-1/2" Tubing stump with Fluted Collar @ 8864'. Set 5K downweight on stump. POH UD jts. #205 and #206. PUMU RIH w/2' spaceout pup and Jt. #205. 09:45 - 10:30 RUNCMP PJSM. PUMU 3-1/2" DP landing joint and XO with floor valve and circulating lines and makeup to Tubing Hanger. Makeup tubing hanger to top of Jt. #205 hanging in slips. Printed: 2/19/2007 1 :06:48 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-08 03-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/2/2007 Rig Release: 2/18/2007 Rig Number: Spud Date: 10/21/1976 End: Rig down torque turn equipment and 4-1/2" Tubing running tools. 11 :30 - 15:00 3.50 RUNCMP Reverse circulate 150-Bbls. 120F seawater @ 3.0-BPM @ 200-psi from pits taking returns from Tubing to pits. Reverse circulate 480-Bbls. EC-1124A corrosion inhibitor treated 120F seawater @ 3.0-BPM @ 200-psi taking returns from Tubing to Tiger Tank. Clear and clean rig floor and prepare to RDMO. 15:00 - 15:30 RUNCMP Break off landing joint and drop ball & rod. MU landing joint and land Tubing Hanger. RILDS. UD landing joint. Close Blind rams. 15:30 - 17:00 RUNCMP Pressure up Tubing to 3500-psi to set packer and test Tubing for 30 charted minutes. Bled off Tubing to 1500-psi. Pressure up and test Casing to 3500-psi for 30 charted minutes. Bled off tubing and sheared DCR-1 valve. Verified circulation both ways through DCR-1 valve. 17:00 - 18:00 1.00 RUNCMP Rig up LRS to freeze protect well. 18:00 - 20:00 2.00 RUNCMP Hold PJSM. Pressure test lines to 3500 psi, Ok. Pump 150 bbls of 70 degree diesel down annulus to freeze protect well. Pumped 2 BPM, pressure increased from 700 to 850 psi. SID & suck lines down. 20:00 - 21 :30 RUNCMP RIU to U-tube well. U-tube & allow well to equalize the tbg I annulus. 21 :30 - 22:00 0.50 WHSUR P RUNCMP P/U Tee-bar & install TWC in tbg hanger. UD Tee-bar. 22:00 - 23:00 1.00 WHSUR P RUNCMP Pressure test TWC from top to 1000 psi for 10 min. Test TWC from bottom to 1000 psi for 10 min. Tested good. Charted tests. 23:00 - 00:00 1.00 BOPSU P RUNCMP Begin N/D BOPE. 2/18/2007 00:00 - 01 :30 1.50 BOPSU P RUNCMP N/D BOPE. N/D DSA. 01 :30 - 04:00 2.50 WHSUR P RUNCMP N/U adapter flange. Test tubing hanger void to 5000 psi. for 30 min,OK. 04:00 - 05:00 1.00 WHSUR P RUNCMP N/U tree. Full & test to 5000 psi. Tested Ok. 05:00 - 07:00 2.00 WHSUR P RUNCMP P/U lubricator & pull TWC. Install BPV UD lubricator. 07:00 - 07:30 0.50 WHSUR P RUNCMP PIT BPV to 1000-psi from below. Good test. 07:30 - 08:00 0.50 WHSUR P RUNCMP Trim out Tree w/all required valves. guages, etc. Secure Tree and cellar. DSO - Joseph Thomas inspected and accepted Tree as built. Release rig @ 0800-hrs. Printed: 2/19/2007 1 :06:48 PM FMC FMC AXELSON 61' . 03-08 FROM DRLG - DRAFT TREE = WELLH 0 = ACTUA TOR = KB. ELEV = BF. ELEV = KOP = 3200' Max Angle = 36 @ 8800' Datum MO = 9800' Datum 1V0 = 8800' SS I 9-5/8" CSG, 40#, L-80, 10 = 8.835" I 113-3/8" CSG 72#, MN-80, 10= 12.347" I 14-1/2" TBG 12.6#, 13CR-80, .0152 bpf, 10 = 3.958" I 8884' Minimum ID = 2.79" @ 9214' 5-1/2" TUBING PATCH 15-1/2" TBG-PC 17#, L-80, .0232 bpf, 10= 4.892" H 9423' ÆRFORA TION SUMMARY REF LOG: BHCS ON 11/06/76 ANGLE AT TOP ÆRF: 33 @ 9604' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 3-3/8" 6 9604 - 9636 C 11/02/87 3-3/8" 4 9732 - 9772 C 01/10/85 3-3/8" 4 9774 - 9788 C 01/10/85 3-318"? 9789 - 9793 C 11/02/87 3-3/8" 4 9804 - 9829 C 01/10/85 3-3/8" 4 9831 - 9842 C 01/10/85 3-3/8" 4 9850 - 9860 C 01/10/85 3-3/8" 4 9870 - 9875 C 01/10/85 3-3/8" ? 9915 - 9918 C 11/02/87 ? 4 9909 - 9944 S 01/01/85 2" 6 9910- 9930 C 03/13/01 2" 4 9957 - 9977 S 01/01/85 I PBTD I 9-5/8" CSG 47#, MN-80, 10 = 8.681" I 10255' 10337' ~ 10370' DATE 11/13/76 11/12/86 OS/22/01 09/26/02 03/25/03 09/27105 REV BY COMMENTS ORIGINAL COM PLETION LAST WORKOVER RNlTP CORRECTIONS BMlTP WAIVER SAFETY NOTE JLA/KK WAIVER SAFETY NOTE REV. EZL/TLH WAVIER SFTY NOTE DELETED DATE 10101/06 11/20106 02/18/07 02/18/07 REV BY COMMENTS RRD/PAG SET BKR IBP@ 9304' TQfPAG TBG LK SQZ @ 9214' (01/04/99) GMH NABORS 4ES RWO JDM/PAG DRLG DRAFT CORRECTIONS PRUDHOE BAY UNrT WELL: 03-08 ÆRMrT No: "1760730 API No: 50-029-20231-00 SEe 11, T10N, R15E, 1395.51' FEL & 1608.76' FNL SA.NOTES: BROKEN LATCH PATCHED 02/26/92 *** ME TBG ..* ST MD 5 2991 4 4908 3 6362 2 7524 1 8719 8790' 8811' 8835' 4-1/2" HES 'X' NIPPLE. ID = 3.813" 9-5/8" FOC 9-5/8" FOe GAS LIFT MANDRELS 1VD DEV TYÆ VLV LATCH PORT DATE 2990 5 MMG OCR 0 02/17/07 4776 29 MMG DMY 0 02/17/07 6022 33 MMG DMY 0 02/17/07 6987 35 MMG DMY 0 02/17/07 7970 35 MMG DMY 0 02/17/07 -i 4-112" HES 'X' NIPPLE. 10 3.813" I 9-5/8" X 4-1/2" BAKER S-3 PKR, ID = 3.875" 4-1/2" HES 'X' NIPPLE, 10 - 3.813" 9214' 5-1/2"ALPHA TBGPATCHw/CMTDONUT. ID = 2.79", TOC = 9115' (TAG 01/06/99) -i 2-1/2" BKR IBP LEFT IN HOLE I 9-5/8" X 5-112" BAKER SB-3 PKR, 10 - 6.000" 5-112" OTIS XN NIP, ID = 4.455" I 5-1/2" BA KER SHEA ROUT SUB 5-112" TUBING TAIL I ELMO TT LOGGED 11/02/87 9829' 9851' 10225' 5/16" RKP - 11/02/91 I FISH: IBP RUBBER ELEMENT LOST 01/18/99 2 CA-RD-RK's - 08/17/891 BP Exploration (Alaska) · . ~ 1r ~ "IT Œ mJ ~ ~ ~ ~ ~ [r& ~ / SARAH PAUN, GOVERNOR I AI~~IiA OIL AlO) GAS / CONSERVATION COMMISSION / / 333 W. 7th AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 SCANNED JAM 1 r¡ 2007 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, Well Name: PBU 03-08 Sundry Number: 307 -003 Dear Mr. Reem: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this Ik:'day of January, 2007 EneL r1~-O'7_3 A.1\rJ1 "1-;1 0 . STATE OF ALASKA . --fJ!£ , 111' ALASKA Oil AND GAS CONSERVATION COMM~ON fA- RECEIVED APPLICATION FOR SUNDRY APPROVAC"f\) 20 AAC 25.280 JAN 0 4 Z007 1. Type of Request: 0 Abandon o Alter Casing o Change Approved Program o Suspend g Repair Well g Pull Tubing o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate .~sv.~ÜTI~~~f Cons. Cmnmission o Stimulate 1j Re-Enter 1tWeRB~åßrell o Waiver 0 Other 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. If perforating. closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? 0 Yes 181 No 9. Property Designation:O~8331 æcd'. \10. KB Elevation (ft): 11. Field / Pool(s): ¡ ADL ð2SJJ1 /,//-1)7 61' I Prudhoe Bay Field / Prudhoe Bay Pool 1~.{><.···· ...... ........./». i>.....{><i/. "'i< vvr::i..L '" iX:/.ii>ii"'> iF»~ ',<'; >/ Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10370 (9338 10255 9242 9308 None Casino Lenath Size MD TVD Burst eollacse Structural Conductor Surface Intermediate Production Liner 4. Current Well Class: I 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number 176-073 ,/ 6. API Number: 50-029-20231-00-00/ 8. Well Name and Number: PBU 03-08 / 73' 2677' 20" 13-3/8" 101' 2708' 101' 2707' 1530 5380 520 2670 10307' 9-518" 10337' 9311' 6870 4760 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I 9604' - 9930' 8697' - 8970' Packers and SSSV Type: 9-5/8" Baker '8B-3' packer Tubing Size: 5-1/2".17# Tubing MD (ft): 9423' 13. Attachments: 181 Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 15. Estimated Date for eommencing Operations: 17. Verbal Approval: COl}lmission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Nam~avid Reem Title Drilling Engineer Signature f)-(' /0." A, Phone 564-5743 Tubing Grade: L-80 I Packers and SSSV MD (ft): 9308' 14. Well elass after proposed work: o Exploratory 181 Development 0 Service January 20, 2007 Date: 16. Well Status after proposed work: 181 Oil 0 Gas o WAG 0 GINJ o Plugged DWINJ o Abandoned o WDSPL Contact David Reem. 564-5743 Frank Roach, 564-4373 Prepared By Name/Number: Date 1_ 4-- Or DeWayne R. Schnorr, 564-5174 Commission Use On Iv . I Sundry Number: 30'7-,003 Conditions of approval: Notify eommission so that a representative may witness o Plug Integrity $.BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: '3500 \,S \ ""\ "-, "",-,-"",,- \"">:'a~~ Subsequent Form Required: \-\~}L\W 1 j) ( I 1A1/1 APPROVED BY Approved By: L.-"". ,z'f/!OMMISSIONER THE COMMISSION Form 10-403 Revised 06/2006 \.../ V 0 K-rGTN A L RBOMS BB 1 6 2007 Date /-/2, ...p r- Submit In Duplicate . . 03-08 Rig W orkover Scope of Work: Pull 5-W' L-SO completion, cut and pull 9-5/S" casing above TOC, tie-back w/new 9-5/S" casing, replace 9-5/S" hanger with emergency slips and primary pack-off, and run 4-%" 13CrSO completion. MASP: 2116 psi Well Type: Producer Estimated Start Date: January, 2006 P R" re- Ig: S 1 Drift for 5-1/2" chemical cutter to top-of-cement. E 2 Power Jet cut ~ -SS90'. (Ref: 11/12/19S6 tubing summary). Chemical cut desired to be in the middle of the 15 full joint above the top-of-cement. F 3 Circulate well with seawater and FP w/ diesel thru the cut. CMIT TxlAxOA to 2000 psi to confirm mechanical barrier and casinQ inteQrity. Bleed WHP's to 0 psi. 0 4 PPPOT-T, -IC, check all LDS. 0 5 Set a BPV in the tubing hanger. Remove the wellhouse & flow line. Level the pad as needed for the riQ. Proposed Procedure 1. MIRU. ND tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 5-W' tubing string to the cut. 3. RU wireline and run USIT from packer to surface. 4. Run 9-5/S" RBP and set at -1000'md below TOC determined from USIT. PT RBP to 1000 psi to prove up barrier. Stack -50 ft of sand on RBP. 5. Mechanically cut 9-5/S" casing in 2nd full joint above TOC. Circulate out Arctic Pack. Pull casing thru stack. Back-off 9-5/S" stub and pull same. Note: VBR's will not be changed to 9-5/8" pipe rams as the well has two tested barriers (IBP and RBP) to the reservoir. 6. Screw back in with new 9-5/S", 40#, L-SO casing and land on new emergency slips with new primary pack-off. PT 9-5/S" pack-off to 2500 psi. Cement new 9-5/S" casing to surface. 7. Run 4-W' 13CrSO stacker packer completion with Baker S-3 packer. Position packer at -S030' MD. S. Displace the IA to packer fluid and set the packer. 9. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 10. Set BPV. ND BOPE. NU and test tree. RDMO. . .' ==- . TREE = FMC WELLHEAD = FMC 03-08 SAFETY NOTES: BROKEN LATCH PATCHED 02/26/92. ACTUA TOR = AXELSON KB. ELEV = 61' BF. ELEV = KOP= 3200' Max Angle = 36 @ 8800' Datum MD = 9800' . 2228' H 5-1/2" CAMeO BAL-O SSSV NIP, ID = 4.562"1 Datum TVD = 8800' SS GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 113-3/8" CSG 72#. MN-80. ID = 12.347" I ... ~ 1 3011 3010 5 MMIG RK 2708' 2 4996 4853 29 MMIG RK 3 6377 6034 32 MMIG RK L 4 7466 6940 35 MMIG RK 5 8035 7409 24 MMIG RK Minimum ID = 2.79" @ 9214' 6 8314 7639 35 MMIG RK 5-1/2" TUBING PATCH 7 8593 7867 35 MMIG RK 8 8916 8130 36 MMIG RK 9 9071 8255 35 MMIG RK IFWR ClJT TBG (12/24/06) I VV 10 9229 8385 35 MMIG RKP 8880' I ~ I hr-xJ 9214' 5-1/2" ALPHA TBG PATCH w /CMT DONlJT, I .~ ID = 2.79". TOC = 9115' (TAG 01/06/99) ~ ~ 9298' H 9-5/8" X 5-1/2" BAKER SB-3 A<R. ID = 6.000" I I"'--'" 9308' -12-1/2" BKR IBPSET IN A<R SEAL STEM (10/01/06) I I 9408' H 5-1/2" OTIS XN NIP, ID = 4.455" I I 9422' H 5-1/2" BAKER SHEAROUT SUB I 15-1/2" TBG-PC 17#, L-80. .0232 bpf, ID = 4.892" H 9423' I 9423' H 5-1/2" TUBING TAIL 1 I 9414' H ELMD TT LOGGED 11/02/87 I ÆRFORA TION SUMMARY REF LOG: BHCS ON 11/06/76 ANGLE AT TOP ÆRF: 33 @ 9604' ] Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 3-3/8" 6 9604 - 9636 C 11/02/87 3-3/8" 4 9732- 9772 C 01/10/85 ] 3-3/8" 4 9774 - 9788 C 01/10/85 3-3/8" ? 9789 - 9793 C 11/02/87 3-3/8" 4 9804 - 9829 C 01/10/85 ] 3-3/8" 4 9831 - 9842 C 01/10/85 3-3/8" 4 9850 - 9860 C 01/10/85 3-3/8" 4 9870 - 9875 C 01/10/85 3-3/8" ? 9915-9918 C 11/02/87 I ? 4 9909 - 9944 S 01/01/85 2" 6 9910 - 9930 C 03/13/01 2" 4 9957 - 9977 S 01/01/85 I PBTD I 10255' I 9-5/8" CSG47#, MN-80, ID = 8.681" I 10337' I I 9829' H 5/16" RKP - 11/02/91 I I I 9851' H FISH: IBP RUBBER ELErvlENT LOST 01/18/99 I I 10225' H 2 CA-R£>'RI('s - 08/17/891 [§] 10370' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNrr 11/13/76 ORIGINAL COM PLETION 10/01/06 RRD/PAG SET BKR IBP@ 9304' WELL: 03-08 11/12/86 LAST WORKOVER 11/20/06 TQ/PAG TBG LK SOl @ 9214' (01/04/99) ÆRMrr No: ~ 760730 OS/22/01 RN/TP CORRECTIONS 12/24/06 RRD/PAG FWR ClJT TBG @ 8880' API No: 50-029-20231-00 09/26/02 BMIT? WAWER SAFÐY NOTE SEC 11. T10N. R15E, 1395.51' FEL & 1608.76' FNL 03/25/03 JLA/KK WAWERSAFÐY NOTE REV. 09/27/05 EZUTLH WAVIER SFTY NOTE DELETED BP Exploration (Alaska) ~ ===e JREE= FMC \NELLHEAO = FMC 03-08 SAFETY NOTES: BROKEN LATCH PATCHED 02/26/92. ACTUA TOR = AXB.SON KB. B.EV = 61' PROPOSED BF. B.EV = KOP= 3200' Max Angle = 36 @ 8800' I 1- 4-1/2" HES 'X' NIPPLE, 10 = 3,813" I Datum MD = 9800' Datum TVO = 8800' SS 2326' 1- 9-5/8" FOC J 9-5/8" CSG. 40#. L-80, 10 = 8.835" r-- If ~ 245" ,.. ...... FCC I GAS LIFT MANDRELS ST MO TYÆ VLV 113-3/8" CSG 72#, MN-80. ID = 12.347" I 2708' - 5 3001 4-1/2" 1-1/2" II .......! 4 4885 4-1/2" 1-1/2" 3 6353 4-1/2" 1-1/2" 2 7539 4-1/2" 1-1/2" I . 1 8697 4-1/2" 1-1/2" t:g: ~ 4-1/2" HES 'X' NIPPLE, 10 - 3.813" I I . 9-5/8" X 4-1/2" BAKER S-3 PKR, 10 - 3.875" I 14-1/2" TBG 12.6#, 13Cr-80, .0152 bpf, 10= 3,958" I I 4-1/2" HES 'X' NIPPLE, 10 - 3.813" I ~ I 9214' 5-1/2" ALPHA TBG PATCH w /CMT DONUT, I Minimum ID = 2.79" @ 9214' ~ I) = 2.79". TOC = 9115' (TAG 01/06/99) 5·1/2" TUBING PATCH ~ ~ 9298' -f 9-5/8" X 5-1/2" BAKER SB-3 PKR, 10 = 6.000" I '-"" I 9408' -1 5-1/2" OTIS XN NIP. 10 = 4.455" I I 9422' -1 5-1/2" BAKER SHEAROUT SUB I 15-1/2" TBG-PC 17#. L-80. .0232 bpf, 10 = 4.892" H 9423' I I 9423' -1 5-1/2" TUBING TAIL I I 9414' H ELMO TT LOGGED 11/02/87 I PERFORA TION SUMMARY REF LOG: BHes ON 11/06/76 ANGLE AT TOP PERF: 33 @ 9604' I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9604 - 9636 C 11/02/87 3-3/8" 4 9732 - 9772 C 01/10/85 I 3-3/8" 4 9774 - 9788 C 01/10/85 3-3/8" ? 9789 - 9793 C 11/02/87 3-3/8" 4 9804 - 9829 C 01/10/85 I 3-3/8" 4 9831 - 9842 C 01/10/85 3-3/8" 4 9850 - 9860 C 01/10/85 3-3/8" 4 9870 - 9875 C 01/10/85 3-3/8" ? 9915 - 9918 C 11/02/87 I ? 4 9909 - 9944 S 01/01/85 2" 6 9910 - 9930 C 03/13/01 2" 4 9957 - 9977 S 01/01/85 I PBTD I 10255' I 9-5/8" CSG 47#, MN-80, ID = 8.681" I 10337' I I 9829' -1 5/16" RKP - 11/02/91 I I 9851' -1 FISH: IBP RUBBER B.EMENT LOST 01/18/99 I . I 10225' -i 2 CA-RD-RK's - 08/17/891 [JÐ 10370' DATE REV BY COMMENTS DATE REV BY COM'v1ENTS I PRUDHOE BA Y UNrr 11/13n6 ORIGINAL COMPLETION 10/01/06 RRDlPAG SET BKR IBP@ 9304' \NELL: 03-08 11/12/86 LAST WORKOVER 11120/06 TQ/PAG TBG LK SOZ @ 9214' (01/04/99) PERMIT No: '1760730 OS/22/01 RI'VTP CORRECTIONS 12/13/06 FVR RWO PROPOSAL API No: 50-029-20231-00 09/26/02 BM'TP WAWER SAFETY NOTE SEC 11. nON. R15E, 1395.51' FEL & 1608.76' FNL 03/25/03 JLA/KK WAWERSAFETY NOTE REV. 09127/05 EZLfTLH WAVERSFTY NOTEDB.ETED BP Exploration (Alaska) 01/05/2007 Schlul11berger NO. 4101 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth N 1 0 2007 SCAttNEO Jþ. Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 17ro --()?-3 Field: Prudhoe Bay Well Job# Log DescriDtion Date BL Color CD 17-20 11536189 PRODUCTION PROFILE 12/13/06 1 N-22A 11538587 LDL 12/10/06 1 R-04 11536188 LDL 12/12/06 1 17-12 N/A PRODUCTION PROFILE 11/27/06 1 B-01 N/A LDL 11/28/06 1 J-12 11513655 PRODUCTION PRO PILE 11/29/06 1 13·24A 11522675 MEMORY INJECTION PROFILE 11/28/06 1 L2-06 11487579 LDL 11/29/06 1 DS 04-15 11477943 INJECTION PROFILE 12/01/06 1 P-25L 1 11513656 LDL 12/05/06 1 W-29 11549353 US IT 12/18/06 1 P2-50B 11513652 SCMT 11/26/06 1 03-08 11536186 SCMT 12/10/06 1 M-15 11486170 USIT 12/02/06 1 S-31A 11478134 USIT 11/27/06 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, Petrotechnical Data Center LRZ-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~jAN '] 1) 2007 Received by: Date Delivered: . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Mike Bill Commissioner THRU: Tom Maunder Petroleum Engineer FROM: Lou Grimaldi Petroleum Inspector DATE: February 9, 2003 SUBJECT: MIT OA PWDW2-1 PTD #176-0730 Prudhoe Bay Field I had previously witnessed the Leak Detection log run by E-line. This had exhibited temperature anomalies at approximately 900 feet and just below the Outer Anulus shoe at 2724'. The following day an OA MIT was called for to check for OA competency. I witnessed the attempted MIT of the Outer Anullus on BPX PWDW2-1 at Flow Station 2 in the Prudhoe Bay field. I met Mike Eagling (DHD tech) at the well. The test was accomplished in four stages of pumping. I gathered too many data points to fit on the standard MIT sheet. A data sheet and chart accompany this report. Essentially this casing string failed its MIT although it is unclear where the leak is. A liquid leak rate of. 23 gallons per minute at 1400 psi (avg.)was established after the MIT was concluded. ------ Furthur diagnostics are being considered for this well CC; Anders/Cubbin BPX Sheet by L.G. 3~25~02 Updated 10-26-02 Page1 of 1 MIT OA PWDW2-1 02-09-03 LG.xls 2/10/2003 PWDW 2-10A MIT 02-09-03 1400 1200 1000 8OO 600 400 1st Pump 2nd Pump 3rd Pump 4th Pump Time in minutes Action existing pump & shut-in +1 +2 +3 +4 +5 +6 +7 +8 +9 +10 +11 +12 +13 +14 +15 +16 +17 +18 +19 +20 +21 +22 +23 +24 +25 +26 +27 +28 +29 +30 1st Pump 0 200 120 105 85 85 OA psi 2nd Pump 85 5OO 455 435 42O 410 395 385 375 365 36O 36O 351 342 333 324 315 3rd Pump 120 9OO 85O 815 8O0 785 765 75O 74O 725 710 695 685 67O 66O 650 640 630 620 615 610 605 601 597 593 589 585 577 569 561 553 545 4th Pump 545 1315 1205 1180 1145 1110 1085 1055 1025 1005 98O 96O 939 918 897 876 855 839 823 807 791 775 767 759 751 743 735 Notes Pumped; lst-3/4, 2nd-1/4, 3rd-1/2, 4th-1/2 barrel red numbers indicate average pressure, not taken red numbers indicate average pressure, not taken red numbers indicate average pressure, not taken red numbers indicate average pressure, not taken at end of 2nd pump, bled to check for gas, none red numbers indicate average pressure, not taken red numbers indicate average pressure, not taken red numbers indicate average pressure, not taken red numbers indicate average pressure, not taken red numbers red numbers red numbers red numbers indicate average pressure, not taken indicate average pressure, not taken indicate average pressure, not taken indicate average pressure, not taken red numbers red numbers red numbers red numbers indicate average pressure, not taken indicate average pressure, not taken indicate average pressure, not taken indicate average pressure, not taken SCANNED NAR ! 0 ?.003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 4077' FNL, 4442' FEL, Sec. 11, T10N, R15E, UM At top of productive interval 1369' FNL, 1164' FEL, SEC. 15, T10N, R15E, UM At effective depth At total depth 1609' FNL, 1396' FEL, Sec. 15, T10N, R15E, UM 5. Type of Well: Development _X Exploratow__ Stratigraphic__ Service__ (asp's 714101, 5937262) (asp's 712177, 5934639) (asp's 711952, 5934391) 6. Datum elevation (DF or KB feet) RKB 61 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 03-08 9. Permit number / approval number 176-073 10. APl number 50-029-20231 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10370 feet Plugs (measured) 9339 feet Effective depth: measured 9965 feet Junk (measured) true vertical 9000 feet Tagged PBTD @ 9965' MD on 3/13/2001. Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 73' 20" 350 Sx PF II 73' 73' Surface 2647' 13-3/8" 5321 Sx PF II 2708' 2708' Production 10276' 9-5/8" lOOO Sx Class G &275 Sx PFC 10337' 9330' Perforation depth: measured 9608' - 9640'; 9732' - 9772'; 9774' - 9788'; 9791' - 9795'; 9804' - 9829'; 9831' - 9842'; 9850' - 9860'; 9870' - 9875'; 9910' - 9930'. true vertical 8700' - 8727'; 8804' - 8838'; 8840' - 8852'; 8855' - 8858'; 8865' - 8886'; 8888' - 8897'; 8903' - 8911'; 8919' - 8923'; 8953' - 8970'. Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 PCT @ 9423' MD. Packers & SSSV (type & measured depth) 9-5/8" X 5-1/2" BAKER SB-3 PACKER @ 9298' MD. 5-1/2" CAMCO BAL-O SSSV @ 2228' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production orlniection Data OiI-Bbl Gas-Md W~er-Bbl 153 321 1879 188 425 2606 Casing Pressure Tubing Pressure 290 306 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas m Suspended _ Service 17. I hereby certify tha~,th~ foregoing is true and correct to the best of my knowledge. y~~.~f J ~~ Title: DS 3 Surveillance ~~¢~-' i~' ~¢% ~ ,~ ~,~. [~' i!D~te April 9,2001'~ [.~' ~;~--~, Engine~.r% ~ ~ ~,~-~ I ~ ~ "'~ ~! ~ Signed Danielle Ohms Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · 0RI01iqAL / PR 1 Z 2001 Alask3 0il & G~s uo~-~s, v ..... ~!S';'~BMIT IN DUPLICATE Anchorage 03-08 DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 2/21/2001 - 2/28/2001- 3/10/2001' 3/11/2001' 3/12/2001' 3/13/2001' 3/28/2001 - 4/01/2001' Installed new GLV design. RIH & tagged PBTD @ 9892' MD. MIRU CTU. PT'd equip. RIH & tagged PBTD @ 9891' CTM. FCO'd to 9960'. POOH w/CT. RIH & cleaned out to 9965' CTM. POOH while logging GR/CCL. RIH CT conveyed perforating guns & shot 20' of reperfs f/: 9910' - 9930' MD (Zone 4) Reference Log: BHCS 11/06/1976. Used 2" PJ carriers & all shots @ 6 SPF, underbalanced press, & random orientation. POOH w/guns - ASF. RD CTU. Performed GLV work. Placed well BOL & obtained a representative well test. Page 1 03,/~08/2001 15'43 FAX 907 564 4264 bp BP EX PLORAT I or-~:!i~ March 7, 2001 Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7~ Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 · Dear Commissioners: Re: Pmdhoe-EOA, Pt. Mac, & Lisburne Well Work BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 This listing is provided as required under the terms of Conservation Order No. 341C (Rule 14) & Order No. 342. This is a list of well work tentatively scheduled for March 5 - 12, 2001: Well 03-08 03-25A 03-27 03-28 06-18 13-27A 16-05Ai 16-21 NK-22 S-101 S-103 S-105 Work Planned REPERFORATION REPERFORATION REPERFORATION / HYDRAULIC FRACTURE TREATMENT REPERFORATION CT ACID WASH - GEL CEMENT SQUEEZE Gsa CT ADD PERFORATION W/WORK PLATFORM CTD SIDETRACK (NABORS 3S) REPERFORATION ADD PERFORATION ADD PERFORATION INITIAL PERFORATION INITIAL PERFORATION If additional data or scheduling information is needed, please call me at 564-5799 or E-mail me at raufpc @bp.com~ -~ /~ Sincerely, /~~~~ ~;~lh~a~aUAfssistant, BPX~"~"~ ~ . Alaska Drilling & Wells RECEIVED [vl zl 0 8 ZOOt Alaska Oil & Gas Cons. Commission Anchorage FEB 26 '01 09:05PM BP MILME POIMT GROUP P.2 BP Exploration Endicott Well Operations .su,d?~' -: ~J25 Slickline: 4-10 E-line: 1-47 Other: Dummy off GLV~s a'~l drift tul~i~,g, to 3.625" Leak detection water flow log Monda~ 2/26 Slickline: 3-25 E-line: 2-14 Other: Pull SSSV, drift ~v!th dummy w.h.[pstock Water flow Io~__ Tuesday 2/27 Slickline; E4ine: Other: 3;~,5 Run static pressure survey ...... 3-39 ~as-lift survey & FSPL 1-0.5L2-12; 3-45! .4-10~ 5-ol & 5-02 MIT's w/AOGCC witness Wednesday 2/28 o Slickline: 1-25 ther: ........ Brush, Flush [ pull ,S,$$V;-di'ift'tubing Thursday 3/01 ISlicl<line.' 1-25 Other: 2-56 ---- Caliper s~rvey tul:;i~~ & liner- PFO .F.r.j.d..ay 3/02 IISlickline: Oth_?r!~ _ 1-25 Static pressure ~u~y. Saturday 3/04 Sliekline; 1-21 ' ~Calip~r_sUrvey of tubinl~. lOthe~r~ ..... ~ ........ 1-25 Injectivity test MEMORANDUM TO: Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor THRU: State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 15, 2001 FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Field Drill Site 03 January 15, 2001: I traveled to BP's Prudhoe Bay Field to witness Safety Valve System tests on DS 03. Mark Womble was BP representative in charge of testing DS 03. Testing had been canceled on DS 03 1-14-01 due to blowing snow & chill factor of-50 degrees. Testing was conducted in a safe & efficient manner. Two failures were witnessed. The AOGCC test report is attached for reference. 21 wellhouses were inspected during SVS tests. Wellhouses are in fair condition considering these were inspected after our recent blow. No heat or lights are installed in wellhouses for producing wells. SUMMARY: I witnessed SVS tests in PBU on DS 03. 21 wells, 42 components tested. 2 failures witnessed. 4.8% failure rate. 21 wellhouses inspected. Attachments: SVS PBU DS 03 1-15-00jc cc; NON-CONFIDENTIAL SVS PBU DS 03 1-15-01jc.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test RepOrt Operator: BPX Operator Rep: Mark Womble AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Prudhoe Bay Field DS 03 Separator psi: LPS 185 HPS 1/15/01 690 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 03-01 1750750 185 150 100 P P OIL 03-02 1760240 185 150 120 P P OIL 03-03 1760390 185 150 110 P P OIL 03-04 1760510 03-05 1760570 03-06 1760600 03-07 ]760530 6'3-68 1760730 185 150 130 P P OIL 6'3-69 1790220 185 150 100 P P OIL 0'3-i'0 1790210 03-11 1790470 03-12 1790580 03-13 1790710 03-14 1790820 185 150 100 P P OIL 03-15A 1930150 185 150 100 P P OIL ~3-16A 1970330 " b3-/'7 1791020 ' 63-i'8^ 1930420 03-19 1830920 185 150 90 P P OIL 03-20A 1930470 185 150 100 P P OIL 03-21 1831120 185 150 100~ P P OIL ~3-52 1831230 690 600 420 P P OIL 03-23 1831270 185 1501 0 1 P OIL ~3-24A 1980060 690 600 530 P P · OILi 03-25A 1930230 ~ 03-~6 1831510 185 150 110 P P OIL 03-27 1840620 185 150 100 P P OIL i03-28 1840720 03-29 1840790: 185 150 110 P" P OIL 03-30 1840830 185 150 90 P P OIL 03-31 1840920 185 150 140 P P OIL 03-32A 1940540 185 150 110 e e OIL 03-33A 1970390 ~3-34B 2000110 185 156 0! 1 V " OIL ,, 1/18/01 Page 1 of 2 SVS PBU DS 03 1-15-01c.xls Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code· Passed GAS or CYCLE 03-35 1910800 185 150 90 P P OIL , 03-36 1930190 · Wells: 21 Components: 42 Failures: 2 Failure Rate: 4.8% Elg0 var Remarks: 1/18/01 Page 2 of 2 SVS PBU DS 03 1-15-01c.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown _ Stimulate _ Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4077' FNL, 4442' FEL, SEC. 11, T10N, R15E, UM At top of productive interval 1369' FNL, 1164' FEL, SEC. 15, T10N, R15E, UM At effective depth At total depth 1609' FNL, 1396' FEL, SEC. 15, T10N, R15E, UM 5. Type of Well: Development__X Explorato~__ Stratigraphic__ Service__ 6. Datum elevation (DF or KB feet) RKB 61 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 03-08 9. Permit number / approval number 76-73 10. APl number 50-029-20231 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summit Total depth: measured true vertical 10370 feet Plugs (measured) 9339 feet PBTD tagged @ 9818' MD (12/30/98) Effective depth: measured true vertical Casing Length Conductor 73' Surface 2647' Production 10276' 9818 feet Junk (measured) 8876 feet Size Cemented Measured Depth True vertical Depth 20" 350 Sx PF II 73' 73' 13-3/8" 5321 Sx PF II 2708' 2708' 9-5/8" 1000 Sx Class G &275 Sx PFC 10337' 9330' Perforation depth: Tubing (size, grade, and measured depth) measured 9608' - 9640'; 9732' - 9772'; 9774' - 9788'; 9791' - 9795'; 9804' - 9829'; 9831' - 9842'; 9850' - 99860'; 9870' - 9875'; 9914' - 9920'. true vertical 8700' - 8727'; 8804' - 8838'; 8840' - 8852'; 8855' - 8858'; 8865' o 8886'; 8888' - 8897'; 8903' - 8911'; 8919' - 8923'; 8956' - 8961'. 5-1/2", 17#, L-80 POT @ 9423' MD. =ackers & SSSV (type & measured depth) 9-5/8" x 5-1/2" Baker SB-3 Packer @ 9298' MD. 4-1/2" Camco Bal-0 SSSV @ 2228' MD. ;~ 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 Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcr Water-Bbl Casing~.l~t~ ~P Tubing Pressure 723 6619 2738 313 1417 9237 5361 335 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _._X 16. Status of well classification as: Oil ___X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,,,,/~..~,,.~ '~)'), (~~ Title Arco Engineering Supervisor Erin Obi Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE~ 03-08 DESCRIPTION OF WORK COMPLETED TUBING CEMENT SQUEEZE Date Event Summary 12/30/1998: 12/31/1998: 1/04/1999: 1/06/1999: 1/08/1999: 1/13/1999: 1/14/1999: 1/18/1999' 1/19/1999: RIH & tagged PBTD @ 9818' SLM. Difficulty getting through patch. MIRU. PT'd equip to 3000 psi. RIH w/1-11/16" gun & punched tubing holes f/9268' to 9270' MD. POOH w/guns - ASF. RIH & set IBP @ 9380' MD. POOH & RD. A CTU Tubing leak Cement Squeeze was performed as follows: MIRU CTU. PT'd equip to 4000 psi. RIH w/CT & tagged IBP @ 9380' MD. Pumped gelled sand slurry containing 1100 lbs of 20/40 mesh river sand f/9370'. Attempted to tag TOS w/CT but unable to pass through patch. POOH w/CT. RIH w/stinger & tagged TOS @ 9322' CTM. Swept wellbore w/650 bbls of Crude down 5-1/2" Tbg, taking returns f/IA. Pumped 12.5 bbls of 15.6 ppg Latex Acid Resistant Cement, placing 7.5 bbls into IA & 5 bbls into the 5-1/2" tubing f/TOC to -9100'. Jet washed w/Slick Crude to 9100'. POOH w/nozzle. Left 500 psi on tubing & IA. RD. RIH & tagged PBTD @ 9115' SLM. MIRU CTU. PT'd equip. RIH w/UR & reamed f/9115' to 9214' MD (patch). POOH w/UR. RIH w/BHA & milled Cement to 9247'. POOH. RIH w/UR & reamed f 9238' - 9334'. POOH w/UR. Performed MITIA to 1050 psi - passed. RD. MIRU CTU. RIH & tagged TOS @ 9325' MD. Performed FCO to top of IBP @ 9375' CTM. Swept Biozan gel w/nozzle on top of IBP. POOH. PF'd wellbore. RD. Attempted to retrieve IBP but no success. RD CTU. RU SLU. RIH & retrieved IBP except for 1 rubber element. POOH. RD Fished one 6" piece of rubber from IBP from wellbore. Returned well to Production & obtained a valid well test. GeoQuest 500 W. International Airport I:~aF ,~ E!V E D Anchorage, AK 99518-1199 ATTN: Sherrie kiz,~,,f.: L,... NO. 9228 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay 2/3/95 Well Job # Log Description Date BL RR Sepia RF Sepia Mylar Floppy Disk ,.).S. 5-11 94409 DUAL.BURST TDT-P 120294 ":1 D.S, 1-22A DSI 01 I 395 I 1 D.S. 3-3 PROD PROFILE 01 0595 1 I =,, D,S. 3-8 PROD LOG 01 0695 I 1 D,S, 3-11 INJEC'PROFILE 01 0595 1 1 D,S, 3-14 PERFRECORD 01 0895 1 1 .......... D.S. 3-22 PROD PROFILE 01 0895 I 1 D.S. 3-25A PROD PROFILE 01 0995 I 1 ,., D.S. 3-24 PROD PROFILE 01 0795 I 1 D.S. 3-31 PROD PROFILE 011 1 95 I 1 D.S. 4-41 LEAK DETECTION 011 095 I 1 D.S. 6-23 PROD PROFILE 011 1 95 I 1 D.S. 7-13A PRODLOG 01 0695 I 1 D.S. 9-11 PROD PROFILE & JEWERLY LOG 01 0695 I ,, 1 D.S. 9-42 PROD PROFILE 011 095 I 1 ).S. 11-23A ~DUAL BURSTTDT-P 01 21 95 I .... 1 D.S. 11-23A ICNTG 012095 ,,, I ...... 1 D.S. 13-3 REPEATA PATCH SETTING RECORD 01 0595 I 1 D.S. 13-33 I INFLAT BRIDGE PLUG RECORD 01 0595 I 1 , ,, D.S. 15-30 LEAK DETECTION 01 0995 I I , D.S. 16-6 PROD PROFILE 01 0895 I 1 /D'S. 16-15 PROD LOG 010795 I I SIGNED' DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ARCO Date' Alaska, Inc. ~.._~ P.O. Box 100360, ,..~_~torage, AK 99510.~ ~, Feb 25, 1994 Transmittal#: 94024 ~~' Subject: ARCO Static Pressure Surveys From/Location- John E. DeGrey/ATO-1529 Telephone: (907) 263-4310 To/Locatio n: Distribution ~0 i 2-3 i 6-5-93 Static Press Surv. ! 2-5 i 7-21-93 Static PressSurv. ~3~ ! 3-8 i 11-22-93 I Static Press Surv. ~;~'"q?" I 3-19 f 1-3-94I Static PressSurv. ~'Z,--l~5 3-34A i 11-22-93 Static Press Surv. ~I:) i 3-35 i 12-7-93 Static Press Surv. 1°1 ! 3-36 I 7-24-93 Static PressSurv. '~0~t~ I 4-12 ! 11-17-93 Static Press Surv. ~55~ i 4-31 ! 1-3-94 Static Press Surv.. f 4-32 { 9-8-93 Static Press Surv. ~c¢~ ! 4-41 11-21-931StaticPressSurv. IL~* I 5-12 ,! 7-21-93 l StaticPressSurv. Itq I 6-19 . 11-28-93 Static Press Surv. ._..~!t'5 i 7-7A I 7-2J-93 StatiC press Surv. !14¢ ! 7-8 I 9-2-93 Static Press Surv. I~ 9-49 l 9-14-93 Static Press Surv. · "" 11-! 9-5-93 Static Press Surv.i " Sch ~ 16ST1 ' . ~ \Oc~ O---. Roi 11-17 I 11-26-93 Static Press Surv. Iq8 I 12-16A i 11-8-93 Static Press Surv. ~ 13-14 t 7-2-93 Static Press Surv. i " Sch i to~'~-'-~~ 13-14 j 7-2-93 Static Press Surv. ~0 t 14-01 i 11-25-93 Static Press Surv. f~ t 14-6i 11-25-93 Static Press Surv. Cfc 14-18 11-26-93 Static Press Surv. " Sch c-4 l~Loo-'-~q,'~'l [0-~ 14-38 12-4-93 Static Press Surv. " Sch i I "~-~0 [~ 14-39 12-4-93 Static Press Surv. " Sch ct )c~O--ot~4ctct ~ 15-6 5-28-92 Static Press Surv. " Sch ~I~ 15-15 7-5-93 Static Press Surv. " Sch :Fur 15-16 8-26-93 Static Press Surv. ~O 15-18 ! 10-26-93 Static Press Surv. 1'55 ! 15-23 I 9-23-93 Static Press Surv. ~ ! 16-12 I 7-21-93 Static PressSurv. ~-iZ,?.z~ I 16-17 ! 12-29-93 Static Press Surv. ~c_._~!?,,q2~ f 16-18 ! 7-18-93 Static Press Surv. ~:.L~, ! 16-22 I 7-18-93 Static Press Surv. ~o'~5 I 17-1 I 11-23-93 Static Press Surv. '8~-t'~ I 17'13 ! 8-27-93 Static Press Surv. [/O t 18-29A ~ 5-19-93 Static Press Surv. ARCO Alaska, Inc. I$ a Subsidiary of AllanllcRlchfleldCompany ARCO Alas~rs, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-22-93 REFERENCE: ARCO CASED HOLE FINALS -~%-~% 1-0 3-29-03 1-11 "7~--~"/ 4-2-93 ~.-~-$1-1o 1-22 ~--~ 4-6-93 f~-~ ~-lO 4-6-9~ 1-33 ~~ 4-4-93 2-~11 ~%~ 4-0-93 7~~ 3-8 3-28-93 3-10 ~-~k 3-28-93 7o ~ 4-2 3-20-93 4-29 ~ ~-~--3-26-93 4-33 3-25-93 5-11 '7"2----:~0 3-29-93 6-3 4-5-93 6-9 7~7~ 4-5-03 s-3o-os -4A 2-93 ~ll-13A 4-9-93 12-11 ~~ 3-31-93 ~~3-20 3-21-93 14-15 ~[~ 3-30-93 ~~4-22A 4-2-93 ~4-22A 4-2-93 ~o-~o 9~-9~ 3-2~-03 ~7-20 4-3-93 ~8-26 3-24-93 18-27 :18-27 3-23-93 3-24-93 Leak Detect Run 1. 1",5"&25'~.I Production Run 1. Production Run 1, Perf Record Run 1. P~oduction Run 1. Perf Record Run 1.5~' InJ Profile Run 1. Perf Record Run 1, Production Run 1, Tubing Puncher Run 1, CNL Run 1. Static Pressure Run I, Press/Temp/Spin Run 1, 2"&5' Static Pressure Run 1, Production/Gas Entry Run 1, Perf Record Run 1, Leak Detect Run 1, 1"&5" Production Run 1, Perf Record Run 1. Perf Record Run 1, Static Pressure Run 1, 5~' Perf Record Run 1. Production Run 1, Perf Record Run 1, Production Run 1. PITS Run 1. 1~' Perf Record Run 1. 5~' Perf Record Run 1, Perf Record Run 1, Perf Record Run 1. Static Pressure Run 1. GR/CCL Run 1. Static Pressure Run 1, GR/CCL Run 1, 5~' Please sign and return th% attached copy as receipt,of data. SonyaWallace ~. X~ ~,, APPROVED ATO-1529 .~ Trans# 93050 # ~ CHAPMAN ~. #BPX # ~ ~,'.~/~ # STATE OF ALASKA Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch 8ch Sch Sch Sch Sch Sch Sch Sch ARCO AlAska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 11-3-92 REFERENCE: ARCO CASED HOLE FINALS 10-3-92 Prod Profile Run 1. g' Camco 9-28-92 Leak Detect (Flexstak) Run 1. ~" Camco 9-14-92 InJ Profile Run 1. [~' Camco 9-29-92 InJ Profile Run 1, [~' Camco 10-2-92 Prod-lnJ (Flexstak) Run 1. [~' Camco 9-19-92 Leak Detect Run 1, [~' Camco 9-26-92 GR/Collar Run 1, [~' Camco 9-27-92 GR/Collar Run 1, [~' Camco 9-25-92 Prod Profile Run 1, [~' Camco 9-14-92 Prod Profile Run 1, g' Camco 10-2-92 InJ Profile Run 1, [~' Camco 9-4-92 Prod Profile Run 1, [~' Camco 10-4-92 lnJ Profile Run I, [~' Camco 9-26-92 Prod Profile Run 1, [~' Camco 9-26-92 GR/Collar Run 1, [~' Camco 10-5-92 InJ Profile/PITS Run 1, [~' Camco 9-27-92 InJ Profile Run 1. [~' Camco 9-19-92 Leak Detect Run 1, [~' Camco 9-27-92 Prod Profile Run 1, ~' Camco 10-4-92 InJ/6hut-ln Temp Run 1, ~' Camco 10-2-92 InJ Profile Run 1, [~' Camco 10-2-92 InJ Profile (Flexstak) Run 1, [~' Camco 10-1-92 InJ Profile Run 1, [~' Camco 9-15-92 InJ PrOfile Run 1. [~' Camco 9-17-92 Prod Profile (Flexstak) Run 1, [~' Camco 10-1-92 Prod Profile Run 1. [~' Camco 9-28-92 GR/Collar Run 1, [~' Camco 9-28-92 Prod Profile Run 1, ~' Camco 9-15-92 Prod Profile Run 1, [~' Camco 10-1-92 Prod Profile Run 1. [~' Camco Please sign and return ~le ,ttac~e~d copy as receipt of ~~ E ] V E D RECEIVED B/Y~~~~ ' MAFt 0 9 1993 · ---- Alaska Have A Nice D~ / fi' v 0il & Gas Cons. COmmission Anchorage) Sonya Wattace APPR 0.VED_ ._.~.~__ ATO- 1529 Trans# 92245 '~ # CENTRAL FILES # CHEVRON # LUCILLE JOHNSTON # EXXON # MOBIL # PHIL~ PB WELL FILES # BPX # STATE OF ALAS~ ARCO Al/ski. Inc. P.O.BoE 100360 Anchortge, ALub4 004510 DATE: 13-18-02 REFERENCE: ARCO 1-SST ? ° - ~/° 2-IS 2-1S S-20 ~S-2S ~-/~ ~s-2s ~~ ~s-so (3-30 (3-33 ~ ~3~T CASED HOLE lo. 11-02 10-23-92 1O.2-02 11-6-02 11-1242 10-12-02 11-7-02 1O-0-02 10-0-02 11-S-e2 11-12-02 lo.S-OS 10-18-02 11-8-02 Ia-0-02 10-11-02 Ia.S-e2 10-24-02 o-28 J~'-27 o.24-o2 ~.~'~/~ [o-2o 2-28-02 o-29 2-28-02 ~/_/~ 11-3A ?/-/S~ 11-11-o2 12-8B , lo.13-02 12-2o lS-2O ~~ ~-~6-02 ~_~/~ ~2 0-2~-02 1~2 1~8-02 ~ - ?~ ~z ~o-s~02 1~12 ~/-~ lo.2~02 1~14 ~/~ 1O.22-02 1~2~-~/~ 10-22-02 ~_ ~ ~Z~o o.27-o2 ~o Ia.ILo2 J/-/~ 17-]$ lO-2o.o2 FIHALS Leak Detect (flexotak) Run 1. 5"&10" Camco Perf Record Ibm 1. 5" HL8 Perf Record Run 1. 5" HLS Collar (IBP) Run 1. 5" Cameo ]nj Profile {Step Rate} Run 1. 5" Camco Leak Detect(flexstak) ibm 1. 5" Camco Collar (IBP) Run 1. 5" Camco Ga/Collar Run 1.5" Camco Prod Profile Run 1. 5" Camco Collar (IBP) Run 1. 5" Camco Prod Profile Run 1. 5" Camco Perf Record Run 1, 5" HLS Leek Detect (flezstalrJ Run 1. :r'&5" Camco Prod Profile · Run 1, 5" Camco InJ Proflle/PITS/Colhr Run 1, 5" Camco Prod Profile Run 1. 5" Camco Perf Record Run 1, 5" HL8 Perf Record Run 1. 5" HL8 PITS Run 1, 5" Camco TMD Run 1, 5" HLO Perf Record Run 1. 5" HLS Perf Record Run 1. 5" HIS PSG/GR (Computed ReaulteJ ibm 1. 5" HIS PaG/GR ~/ Run 1, 5" HIS Leak Detect (flezstak) Run 1. 5" Camco Set IBP Run 1. 5" Camco Perf Record Run 1. 5" HIS Collar Run 1, 5" Camco Perf Record Run 1. 5" HL8 InJ Profile/PFF8 ~ Run 1, 5" Camco Perf Record ~ Run 1. 5" HIS Prod Profile (flezstak) Run 1. 5" Camco Perf Record Run 1. 5" HIS Perf Record Run 1. 5" HIS Perf Record / Run 1. 5" HIS Prod Profile (flezstakJ ~ Run 1, 5" Camco lnJ Profile/Tamp/ Run 1, 5" Camco Perf Recital ~ Run 1. 5" HIS GR/Collar / Run 1. 5" Camco 8BL/GR/CCL ,/ Run 1. 5" Atica RECEIVED the attached copy aa receipt of dam. JCZ~TRALr~ 5 0 ~997- # cHz~.,o__~I.. ~,, .~ r~ Cons. Commissio~ STATE OF AZ,ASEA STATE OF ALASKA ALASKA AND GAS CONSERVATION CC..,IlSSION REPORT SUNDRY WELL OPEFIATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1199' FSL, 837' FWL, Sec. 11, T1 ON, R15E, UM At top of productive interval 1369' FNL, 1164' FEL, Sec. 15, T10N, R15E At effective depth At total depth 1578' FNL, 1438' FEL, Sec. 15, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 61 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-8 9. Permit number/approval number 76-73 10. APl number 50 - 029-20231 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth' measured true vertical 10370 feet Plugs(measured) 9338 feet Effective depth: measured 10255 feet true vertical 9242 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 73' 20" 350 sx PF II 73' 73' Sudace 2647' 13-3/8" 5321 sx PF II 2708' 2708' Production 10276' 9-5/8" 1000 sx CIG & 275 sx PFC 10337' 9330' Perforation depth: measured 9608-9640'; 9732-9772'; 9774-9788'; 9791-9795'; 9804-9829'; 9831-9842'; 9850-9860'; 9870-9875'; 9914-9920' true vertical 8700-8727'; 8804-8838'; 8840-8852'; 8855-8858'; 8865-8886'; 8888-8897'; 8903-8911'; 8919-8923'; 8956-8961' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9423' MD Packers and SSSV (type and measured depth) Camco Bal-0 SSSV @ 2228' MD; Baker SB-3 packer @ 92_9~'.M,D,- n E f" E/\1 Ir' ~) 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. 14. Treatment description including volumes used and final pressure Representative Daily Average Produ~ion or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3295 5936 3130 -- 405 Subsequent to operation 3269 5812 3156 -- 408 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas__ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~' --orm 10-404 Rev 06/15/88 820/8 SLW cc: SW, JWP Title Sr. Area Operations Engineer Date z~.-//~/¢~... SUBMIT IN DUPLICATE~ 3-8 TUBING PATCH INSTALLATION DESCRIPTION OF WORK COMPLETED 2/25/92 · RIH & set a 4.5" OD soft set tubing patch from 9214' to 9236' MD across GLM # 10. POOH. Rigged down. Returned well to production w/gaslift & obtained a valid production test. /0 ARCO Alaska~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-27-92 REFERENCE: ARCO CASED HOLE FINALS ~ 2-19-92 GR/PerI Run 1, 5" HLS 3-8 2-25-92 Collar R~_~n 1, 5" HLS 3-35 2-21-92 CCL/Per~ Run 1, 5" HLS 4-3 2-9-92 Perf Record Run 1, 5" HLS 4-3 3-2-92 Perf Record Run 1, 5" HI~ 4-7ST 3-2-92 Perf Record Run 1, 5" HI~ 5-14 2-11-92 Perf Record R~_~_n1, 5" HLS 6-21 2-22-92 CCL/Perf R~_m 1, 5" HLS 9-43 2-12-92 Perf Run 1, 5" HLS 11-3A 2-23-92 CCL/Perf R~_m 1, 5" HI~ 14-32 2-28-92 Perf Record Run 1, 5" HLS ~--~/~17-11 2-28-92 Perf Record Run 1, 5" Please sign and return the attached copy as receipt of data.~ ~ ~ ~ I~ ~ 0 RECEIVED BY ~_f~ ~R~O~°J°J~' GaS Cons. Gomm'tssio~ Have A Nice Dayl ~ Naska 0it ~ APPROVED .... ~n~ W~ce ATO- 1529 ~s~ 920 # CENTRAL FH~S # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHH~LIPS PB WELL ~ R&D # BPX # STATE OF ALASKA TEXACO * The correct APl# for 11-3A is 50-029-20666-01. ARCO ALASKA, .INC. F'.O. BOX iOOS60 ANCHORAGE, ALASKA 995 i 0 DATE: t 2-Si -9t REFERENCE · 5~7... ¢33-4 3-8 .77 4-7 PLEASE ARCO CASED HOLE FINALS t 0-'~7-°t v/ . , LEAK DETECT ti-5-9i / F'~OD PROFILE 11-5-9i~/ F'ROD PROFILE ~ i -2-9t JEWELRY t i-~9-9t ~/ 1NJ F'ROHILE tt-t8-9t~,~/GA~ LIFT t t-23-9t -/LEAK¢, DETECT t~-2t-9t / 6R/CCL TIE-IN t t-tt~t~ PRODUCTION tt 29-9t~ INJ PROFILE tt-~-9t~ INJ PROFILE 9-2t-9t INJ PROFILE RUN t, t" F,:UN t , 5 · RUN t , 5 · RUN t , 5 · RUN t, 5 · RUN t, 2"&5" RUN i, 2"&t0" RUN t, 5 · RUN i , 5" RUN RUN RUN ~, 5' RUN ~ , 5" RUN t , 5 · RUN i , 5' RUN t, 5 · RUN t , 5 · SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. RECEIVED BY ~_~~--~ HAVE A NICE DAY! SONYA WALLACE AT0-t529 AF'F'ROVEI) TRANS~ 9 CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO UAMCO CAMCO CAMUO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL ~ F'H ILL I F',S' F:'B WELL FILES R & D · .--"' BF'X ~- STALE OF ALASKA TEXACO RECEIVED JAN 10 199z Alaska Oil & Ga~ Cons. 6ommissior. Anchorage STATE OF ALASKA ALA ~, OIL AND GAS CONSERVATIO ;OMMISSION REPOFrI' OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing , Alter casing Repair well Perforate O~her 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1199' FSL, 837' FWL, Sec. 11, T10N, R15E, UM At top of productive interval 1369' FNL, 1164' FEL, Sec. 15, T10N, R15E, UM At effective depth At total depth 1578' FNL, 1438' FEL, Sec. 15, T10N, R15E, UM 5. Type of Well Development X Exploratory ~ Stratigraphic .... Service 6. Datum of elevation(DF or KB) 61 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-8 9. Permit number/approval number 76-73/90 -643 10. APl number 50 - 029-20231 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10370 feet Plugs(measured) 9338 feet Effective depth: measured 10255 feet true vertical 9242 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 73' 20" 350 sx PF II 73' 73' Sudace 2647' 13-3/8" 5321 sx PF II 2708' 2708' Production 10276' 9-5/8" 1000 sx CIG & 275 sx PFC 10337' 9330' Perforation depth: measured 9608-9640'; 9732-9772'; 9774-9788'; 9791-9795'; 9804-9829'; 9831-9842'; 9850-9860'; 9870-9875'; 9914-9920' true vertical 8700-8727'; 8804-8838'; 8840-8852'; 8855-8858'; 8865-8886'; 8888-8897'; 8903-8911'; 8919-8923'; 8956-8961' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9423' MD Packers and SSSV (type and measured depth) Camco Bal-0 SSSV @ 2228' MD; Baker SD-3 packer @ 9298' MD 13. Stimulation or cement squeeze summary REEEIV~D Intervals treated(measured) See attached Treatment description including volumes used and final pressure ,NOV 2 ? 990 14. Prior to well operation Re tuction or ~chorag~ OiI-Bbl Gas-Md Water-Bbl Casin ~ssure ' 2523 2587 904 -- Tubing Pressure 396 Subsequent to operation 6472 8712 2490 312 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Date Form 10-404 Rev 06/15/88 564 MJB c: J. Gruber, ATO-1478 SH SUBMIT IN DUPLICATE DS 3-8 FRACTURE TREATMENT DESCRIPTION OF WORK COMPLETED 8/28/90: Replaced LG LV's w/DGLV's. 8/30/90: MIRU, & PT equipment to 8500 psi. perforations at: 9608 - 9640' MD (Sag) 9732 - 9772' MD (Z4) 9774 - 9788' MD (Z4) 9791 9795' MD (Z4) 9804 - 9829' MD (Z4) 9831 - 9842' MD (Z4) 9850 - 9860' MD (Z4) 9870 - 9875' MD (Z4) 9914 - 9920' MD (Z3) Pumped a propped fracture treatment through Ref. Log: 11/6/76. Pumped treatment as follows: a) 235 bbls Pre Pad, @ 55 bpm, followed by b) Shutdown. ISIP @ 829. Resumed c) d) pumping: 98 bbls Gel, at 30 bpm, followed by Shutdown. Resumed e) f) g) h) pumping: 2900 bbls Cross Linked Water Pad, @ 55 bpm, followed by 1112 bbls Slurry w/proppant concentrations of 2 to 10 ppg, followed by 229 bbls Flush, @ 55 bpm, followed by Shutdown. ISIP @ 2367. Placed a total of 148,000 lbs of proppant into formation. Rigged down. 8/31/90: Replaced DG LV's w/LGLV's. 9/5/90: RIH & performed a carbolite fill cleanout to 10000' MD. RD. 9/7/90: Performed a scale inhibition treatment. Returned well to production and obtained a valid production test. STATE OF ALASKA ALASKA _ AND GAS CONSERVATION C( JlISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon . Suspend Alter casing Repair well Change appr(~'v'ed program 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510~0360 4. Location of well at surface 1199' FSL, 837' FWL, Sec. 11, T10N, R15E, UM At top of productive interval 1369' FNL, 1164' FEL, Sec. 15, T10N, R15E, UM At effective depth At total depth 1578' FNL, 1438' FEL, Sec. 15, T10N, R15E, UM Operation shutdown Plugging Pull tubing Variance 5. Type of Well Development X Exploratory Stratigraphic Service Re-enter suspended well Time extension Stimulate X Perforate Other 6. Datum of elevation(DF or KB) 61 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-8 9. Permit number 76-73 10. APl number 50 - 029-20231 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10370 feet 9338 feet Effective depth: measured 10255 feet true vertical 9242 feet Casing Length Size Conductor 73' 20" Su dace 2647' 13-3/8" Production 10276' 9-5/8" Plugs(measured) RECEIVED AUG 1 61990 Junk(measured) Alaska 0il & Gas Cons, Commissic,~! Cemented I~~depth True vertical depth 350 SX PF II 73' 73' 5321 sx PF II 2708' 2708' 1000 sx CIG & 275 sx PFC 10337' 9330' Perforation depth: measured 9608-9640'; 9732-9772'; 9774-9788'; 9791-9795'; 9804-9829'; 9831-9842'; 9850-9860'; 9870-9875'; 9914-9920' true vertical 8700-8727'; 8804-8838'; 8840-8852'; 8855-8858'; 8865-8886'; 8888-8897'; 8903-8911'; 8919-8923'; 8956-8961' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9423' MD Packers and SSSV (type and measured depth) Camco Bal-0 SSSV @ 2228' MD; Baker SB-3 packer @ 9298' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation 15. Status of well classification as: September 1990 16. If proposal was verbally approved Oil X Gas Suspended Name of al)prover Date approved Service 17. I hereby .certify that the foregoing is true and correct to the best of my knowledge. Signed ' Title Sr. Area Operations Engineer FOR COMMI~RION U~l= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical IntegritY Test Subsequent form required 10- ~ ~' Date IAppr°va'N°' Approved by order of the Commissioner Form 10-403 Rev 06/15/88 477 MJB c: J. Gruber, ATO-1478 ORIGINAL SIGNED BY LONNIE C.'SMITH " Commissioner A~ r~ov' v'~e~lC~ SH Returned Date ~ J/~21~~-~ SUBMIT IN TRIPLICATE Well 3-8 Hydraulic Fracture Trea_l:ment AFE AP6192 Subcomponent # KS3411 Preliminnry Procedure , . o . . . Pressure test tubulars and annulus. Rig up fracturing service company. Pump propped fracture treatment at 50-55 bpm using a dual cross linked water system with approximately 150,000 lbs of 16-20 proppant. The maximum injection rate possible will be obtained following pressure limitations. The pump schedule is outlined as follows: A. 3000 bbl cross linked water pad. B. 100 bbl with 2 ppg in cross linked water. C. 100 bbl with 4 ppg in cross linked water. D. 175 bbl with 6 ppg in cross linked water. E. 175 bbl with 8 ppg in cross linked water. F. 50 bbl with 10 ppg in cross linked water. G. 228 bbl gelled water flush. Perform slickline tag. Rig up CTU and cleanout to PBTD. Bring well on gradually using gas lift. 5 4 3 2 C0~LED TUBIN0 UNIT BOP E0U l PHENT 1. 5000 PSI ?" W£LLH~I~D CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PiPE RAU$ 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 4 H]RELINE BOP EOUIPHENT 1. 5000 PSI ?" WELLHEAD CONNEC'IOR FLANGE 2. 5000 PSI WIRE:LINE RAMS (VARIABLE 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ANC;HORA6E, At..A21<A D A -i' F: · 2 -- 9 - 9;'~ I;,'EFEI:;eENCE' ARCO PRESSURE DATA i-i':':' i i-'i ,' ._:,. i .'"; ~.7 -~:_> it""8 S9 '"'---'~:' ": i i - q -':::' o .,.;. ~,:..._, ~ ,..., ... :'-'.-'5:.' i i .-i *; .... :!ii: 9 S-' 6 i i .... i 3; -,.., '::~ 9 S"" 6 i i .... 'i 6 -:!ii'".:.') .]~'-'8 i i .... i 2'"':.:39 .']-2 O i i '-9 '- E: ? 3;"-2 i i i -i ._X .- 2 .:: t i '-' 9 "- 8 9 :-'"'":" t i '-i '.3 .... 7-',¥S i I '-'"":'-89_, 7-":~4 t ! '-'i 5:'-8? '9..- ? t "::".., - .~. ''') -",' --:.4 9. -,,..4 i t -t c,-'::'°,.., / 9-54 t i-i6-89 ,~.:,-,-, i i--1 t .-.,ti3 9 t6-i8 i i-'i9-89 i '7-- i 3', t t -9-°c:',., ,. B H F'-- 5' T A T I C E.; R A D ]: E N T B t--t F' -- 5' T A T :[ C (: F;.: A D ]: E N T BHF ..... FL_OW ]:NC (;- F;..' A D t E::i'~ T BHF ....Ft_O W :[ i',i'(; (:;RAD i Ei'~T :E': H P -- F' L. 0 W .1: N (:: G R A D .1: E N "f' B H F: .... 37 T A "f' :[ C ('.'- F;.: A D I E N T :E,'. H ~ .... FI...OI, d: N (:: GF;,'AD T_ E:NT BI.-tF .... FL. OW .1: NG GNA D I EN"I' ):i-:'HF: .... f"L. OW 1: i'4G GRAD I ENT B H P-- 37 T A T ii,: C (; F,: A D :[ E N T BHP--',S"T'A T :I; C t].F;~AD l ENT B H F'--P F;,' E ,S',','.,' b F;.: F_' F'A LL_-O F'r--" BHF: .... F:'RE£',S'URE FALL-OF:'F B I--tF .... FL_OW:CNG GRADIENT B'HF: .... STATIC [-;RAD ]:ENT BHF'--Si'ATI C E-RAD lENT Bt"IP--$TAT I C t:.;RAD t: ENT' Bi4F'--$TAt' I C 6RAD l' ENi- ~HF'--S'TAT I C (.;RAD IEN T' F'I_EA$1E SIGN AND I-~,'ETURN THE A'TTACi..tlED COPY AS HAVE A NICLE DA'C! SALLY' I"IOF'F:'ECI':.'.' ER A T 0 - 'i..,'- '-" '') o, FEB 1 5 !990 >la31<a Oil & Gas Cons. Comm~SSi~J1 Anchorage C A H C O CAMCO CAMCO CAMCO C A M C 0 (:;ANCO CAMCO CAM, CO C':Ai'iC 0 CAMCO CAi'iCO C A i'~ C 0 CAMCO CAi'iCO [;-AiqCO CAMCO (]ANCO CAMCO CAMCO I;.'.ECEiPF OF DATA. AF'F'ROVED ~..(~ _ TR.A N 37.'f 9,3 DISTRIBUT]:ON CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON NARA'T'HON i~OBIL 'W ..lt. T .ii. F' Ft I L I_ :I: F' $ F:'B WELL F]:LE,.S' R & D BPX STATE OF AL. A2.:<A TEXACO ARCO ALASKA, INC, P,O, BOX i06, S6¢' AN_,HOR~4L, E .. ALASKA 995~ DATE' t2-5-89 REFERENCE' ARC(] CASED HOLE FINAL~ -~3 ~i 8-89 2-25 ~ ~ -9-89 S--2 i i-~ i-89 S-6 t ~ -i 3-89 S.-8 i i -t 2-89 S.-20 t i-9-89 ~-2i t t '-f 0-89 4-27 i i -i 2-89 ~--27 i t -t 2-89 6- i t i -8-89 7-S i i-6-89 i S--26 i i-8-89 PRODUCTION PROFILE LEAl< DETECTION PRODUCTION F'ROFILE INJECTION PROFILE F'RODUCTION PROFILE PRODUCTION PROFT_LE PRODUCTION PROFILE INdECTION PROFILE GR-COLLAR LEAK DETECTION PRODUCTION PROFILE LEAK DETECTION PLEASE Y lGN AND RETURN THE ATTACHED COPY HAVE A NIC · P"FO- 1 D29 RUN t , F..' U N t, RUN i , RUN t, RUN t, RUN t, RUN i , RUN i, RUN i , I:;:UNi , RUN i , RUN t , A~' RECEIPT OF' DATA,,. CAMCO CAM(](] CAMCO (]AMC(] CAMCO CAMCO C A Pi C: 0 ('~ A N C 0 CAMCO CAMCO C A M C 0 CAMCO DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL. PHILLIPS F'B WELL F'ILE R & D BF'X STAi'E OF ALASKA TEXACO * THE CORRECTED AF'I~ FOR 3-2t IS 5e-029-20990. ** 'THE CORRECTED AF'I.~ FOR 4-27 IS 5G-029-2t50S, ARCO Alaska, Inc. Prudhoe Bay "E-~gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 5, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 3-8, Approval No. 9-637 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Sincerely, ~Co¢. D. F. Scheve DFS/TPA/jp Attachment CC: J. Gruber, ATO-1478 PI(DS 3-8) Wl-3 R CEIVED Anchorage AR3B--6132-C ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ STATE OF ALASKA ALASt~A v..~ AND GAS CONSERVATION COl. IlSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well · Perforate 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1199' FSL, 837' FWL, Sec. 11, T10N, R15E, UM At top of productive interval 1369' FNL, 1164' FEL, Sec. 15, T10N, R15E, UM At effective depth At total depth 1578' FNL, 1438' FEL, Sec. 15, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service X 6. Datum of elevation(DF or KB) 61 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-8 ,, 9. Permit number/approval number 76-73/9-637 10. APl number 50 - 029-20231 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10370 feet Plugs(measured) 9338 feet Effective depth' measured 10255 feet true vertical 9242 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 73' 20" 350 sx PF II 73' 73' Surface 2647' 13-3/8" 5321 sx PF II 2708' 2708' Production 10276' 9-5/8" 1000 sx CIG & 275 sx PFC 10337' 9330' Perforation depth: measured 9608-9640'; 9732-9772'; 9774-9788'; 9791-9795'; 9804-9829'; 9831-9842'; 9850-9860'; 9870-9875'; 9914-9920' true vertical 8700-8727'; 8804-8838'; 8840-8852'; 8855-8858'; 8865-8886'; 8888-8897'; 8903-8911'; 8919-8923'; 8956-8961' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9423' MD Packers and SSSV (type and measured depth)Camco Bal-0 SSSV @ 2228' MD; Bak~l~,-~I~(~_-9. _~8' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attachment 14. Treatment description including volumes used and final pressure Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 3252 3371 461 Tubing Pressure 353 Subsequent to operation 2668 2796 519 380 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x.. Gas .. Suspended. · Service, 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed-~ '~ ~' / ~,~, ~ ~c-J~,~--Title Form 10-404 Rev 06/15/88 208 T. P. Allen, 263-4837 Operations Engineering Manager Drill Site 3-8 Description of Work Performed Treatment: 12% HCI Perforation Breakdown Treatment With Ball Sealers Objective: To remove near wellbore damage in Zones 4 & Sag Intervals Treated: 9608-9640, 9732-9772, 9774-9788, 9791 -9795, 9804- 9829, 9831-9842, 9850-9860 and 9870-9875' MD (ref BHCS 11/6/76) Treatment Date: August 16 through August 22, 1989 Obtained a wellhead fluid sample from Well 3-8 and perform emulsion and sludging tests with acid and additives. Obtained a valid well test. MIRU wireline unit. Changed out the live GLVs from station #1, 2, 3, 4, 6, 7, 8 and 10 to dummy valves for isolation during'the treatment. Loaded the 5-1/2 x 9-5/8" annulus with dead crude/diesel to surface. · Pressure tested annulus to 2500 psi to ensure no communication existed. MIRU pump truck and VMT. Shut-in well. Mixed the following sand slurry: Pumped the slurry down the production tubing, 100 bbls sand slurry 120 bbls dead crude 20 bbls Diesel 80 bbls of fresh water (100 °F) 550 lbs of KCL 100 lbs of gelling agent; XCD polymer or CMHEC (mix 'until gel is fully hydrated) 10000 lbs of 20/40 mesh sand 7000 lbs of 100 mesh sand J~ EC E I V E D OCT 1 1989 Alaska 0ii & Gas Cons. C0mmissi0~ Anchorage 7. Shutdown pump and allowed sand to cover lower squeezed perforations. Verified sand top was at 9889' MD. 8. Loaded 14,000 gals of 12% HCL. All fluids prior to loading should be filtered into the clean transports with a 2 micron filter, j, '~, 9. Mixed and loaded 4000 gals of one of the current acceptable amine phosphonate inhibitor blends. 10. Loaded 40 bbls of xylene, 6000 gals of 2% NH4CI water, 90 bbls of slick diesel and 230 bbls of crude. 11. MIRU pump trucks, blender and transports. Placed 2500 psi on the 5-1/2 x 9-5/8" annulus. 1 2. Rolled all acid compartments on location before pumping fluids downhole. I~$ 3-8 Report of Sundry W~I Operations Page 2 13. 14. 15. Pumped the following fluids down the 5-1/2" tubing to treat the perforated intervals from 9608 to 9875' MD: 1 680 gals 1390 gals 6850 gals 1 760 gals 6680 gals 1 050 gals 3990 gals 2810 gals 5 0 bbls 21 0 bbls 2 0 bbls slick diesel xylene 12% HCI w/additives and 325 ball sealers 2% NH4CI water w/gellant and 100 ball sealers 12% HCI w/additives and 325 ball sealers 2% NH4CI water w/gellant Scale inhibitor blend w/gellant 2% NH4CI water w/gellant Slick diesel Dead Crude Slick diesel Unloaded the well to an open top tank. After all stimulation fluids were recovered, obtained a valid well test. ARCO Alaska, Inc. Prudhoe Bay~ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager July 20, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 3-8, Permit No. 76-73 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/TPA/jp Attachment cc: T.B. Gray, BP J. Gruber, ATO-1478 PI(DS 3-8)Wl-3 RECEIVED J U L 2 ~:- ~c3~9 Alaska 0il & Gas Cons, CommisSi0-~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASK/ :LAND GAS CONSERVATION Or 'MISSION APPLICATION FOR SUNDRY AI- r.'ROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well AItercasing Repairwell Plugging Time extension Stimulate X Change approved program Pull tubing Variance Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1199' FSL, 837' FWL, Sec. 11, T10N, R15E, UM At top of productive interval 2186' FNL, 991' FEL, Sec. 15, T10N, R15E, UM At effective depth 2232' FNL, 1051' FEL, Sec. 15, T10N, R15E, UM At total depth 2396' FNL, 1264' FEL, Sec. 15, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 5. Type of Well Development Exploratory Stratigraphic Service 10370 feet Plugs(measured) 9338 feet Effective depth: measured 9878 feet true vertical 8955 feet 6. Datum of elevation(DF or KB) 61 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-8 9. Permit number 76-73 10. APl number 50 - 029-20231 I 11. Field/Pool Junk(measure~JaSka Oil & Gas Cons. Commissiol~ Anchorage Casing Length Size Cemented Measured depth True vertical depth Surface 73' 20" 350 sx PF II 73' 73' Intermediate 2647' 13-3/8" 5321 sx PF II 2708' 2708' Production 10276' 9-5/8" 1000 sx Class G & 275 sx PFC 10337' 9330' Perforation depth: measured 9608-9640'; 9732-9772'; 9774-9788'; 9791-9795'; 9804-9829'; 9831-9842'; 9850-9860'; 9870-9875'; 9914-9920' true vertical 8700-8727'; 8804-8838'; 8840-8852'; 8855-8858'; 8865-8886'; 8888-8897'; 8903-8911 '; 8919-8923; '8956-8961' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9423' MD Packers and SSSV (type and measured depth) Bal-0 SSSV @ 2228' MD; SD-3 packer @ 9298' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation July 1989 16. If proposal was verbally approved Oil x Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~.~.,, ~.,-~ ~. '"'j~.~e~¢~ Title Operations Engineering Manager FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 06/15/88 15. Status of well classification as: Gas Suspended Date I Approval No. ¢.,.~_~t.~ 7 Date SUBMIT IN TRIPLICATE · ,.~,p,or o~ed OoP'Y Commissioner 095 T. P. Allen, 263-4837 Drill Site 3-8 HCL Perforation Breakdown Treatment ARCO Alaska, Inc. proposes that a perforation breakdown treatment using HCL be performed on Well 3-8. The treatment will be performed as follows: 1. Obtain a wellhead fluid sample from Well 3-8 and perform emulsion and sludging tests with acid and additives. 2. Obtain a valid well test. . MIRU wireline unit. Ensure that the PBTD is near 10232' MD. Change out the live GLVs from station #1, 2, 3, 4, 6, 7, 8 and 10 to dummy valves for isolation during the treatment. In the top GLM, place an Otis RP circulating valve set at 2800 psig differential. Load the 5-1/2 x 9-5/8" annulus with dead crude/diesel to surface. Pressure test annulus to 2500 psi to ensure no communication exists. 4. MIRU pump truck and VMT. Shut-in well. 5. Mix the following sand slurry: - 80 bbls of fresh water (100 °F) - 550 lbs of KCL - 100 lbs of gelling agent; XCD polymer or CMHEC (mix until gel is fully hydrated) - 10000 lbs of 20/40 mesh sand - 7000 lbs o'100 mesh sand ~ E~r"~i'[~r,.. 6. Pump the slurry down the production tubing at 5 BPM as follows: 100 bbls sand slurry 1 38 bbls deadcrude 7. Shutdown pump and allow sand to cover lower squeezed perforations. 9890' _+ 10°. Anchorage Verify sand top at . Load 14,000 gals of 12% HCL. All fluids prior to loading should be filtered into the clean transports with a 2 micron filter. . Mix and load 4000 gals of one of the current acceptable amine phosphonate inhibitor blends. 10. Load 40 bbls of xylene, 6000 gals of 2% NH4CI water, 90 bbls of slick diesel and 230 bbls of crude. 11. MIRU pump trucks, blender and transports. Ensure that 2500 psi is placed on the 5-1/2 x 9-5/8" annulus. 1 2. Roll all acid compartments on location before pumping fluids downhole. 13. Pump the following fluids down the 5-1/2" tubing to treat the perforated intervals from 9608 to 9875' MD: A. 4 0 bbls Slick Diesel B. 3 0 bbls Xylene DS 3-8 HCL Perforation B~-~,~down Description Summary Page 2 C. 7000 gals 12% HCL w/additives, 2 gals/1000 gals of acid gellant and 325 ball sealers D. 200 0 bbls 2% NH4CI water with 10#/1000 gals of gel and 100 ball sealers E. 7000 gals 12% HCL w/additives, 2 gals/1000 gals of acid gellant and 325 ball sealers F. 1000 gals 2% NH4CI water with 10#/1000 gals of gel G 4000 gals Scale Inhibitor Blend with 10#/1000 gals of gel H. 3000 gals 2% NH4CI water w/10#/1000 gals of gel I. 50 bbls Slick Diesel J. 230 bbls Dead Crude 14. Immediately following the treatment, shear the RP valve in the top station by placing 2500 psi differential pressure. Unload the well. 15. After all stimulation fluids have been recovered, obtain a valid well test. 5 4 3 2 COILED TUB[NG UNIT BOP EOU ! PHENT 1. 5000 PSI 7" WELLHF. AD CONNECTOR FLAIN0[ 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5,000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5,000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 3 H]REL]NE BOP EOU]PMENT 1. 5000 PSI ?" WELLHEAD CONN£CIOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF F;,' E F:' E t;;: E N C E.'". ' A 1'7 fi) O C: A 5; ~"' D t"t O !... E I::' .[ N A I._ ,?:; F'I...EA3:IE 5,'I[.'..'.N AND F;: Iii: ]" U F;,' N "l"J-tl?: A"f'TACHED COF'Y A;:,2 i;..'F'CEiF'T OF DA'FA,. Cfi H C ] C A id C C] C A i"i C 0 C; A i'i C (i C ;::; t.i C O [] A i'fi C O C A ~"'i [.)0 R Iii: C E .t V Iii: I) B Y DAY. I..IAVE A NICIE A T 0-' ~ 5 2 9 Gas ~.~ns. Commission · ~,~C E N ¥1;..'AI.. F I I... I.:J.'? :II: C I-.i E V R 0 N :[)&Fi 41: I!!: X "F E N..? I C] N Iii: × F:' I... 0 R A T I 0 N :~ I?.'1X X O N N A F;.'. A T H O N :~ N [] B I I... ~ F'H i L L I F'.'_";' F'B WELL. F:iL.E..~: R & ).') · ,'Il: BF'X ~ ,S"i"ATE OF' AL. AS/KA :~ '1" E X A C [] A N C H 0 [:~'A G E.:., ~ L d,,fi' k' ~ 9 9 5 t ~.) DATE · 4-7-.[~B F:' [' -, ...; t:: ..'? ;[ (',~ t".J i}~ i'J T) t:;.' !iil 'T'I IF;.' I'-J '1'* I'-I !!:' .,'~', 'T' 'T' ~.".~ (': I--1 I::' T.', l*~ f'i I::' Y ;}, S; F;: F' I"'.' 1::' ]' !"' 'T' f'l I::' ~T) (:~ 'r ~ .o I:~: I:!: C: I::' ]: V I::' :[) I'." y .... · ............. ' ............................... (,/" APR t :,' ':.:" H A ',,,' [!] (.:, i'.~ ;I; C'. F!' ir) A Y ~ Alaska Oil & Gas Oons. Commission F:' I::' r:; ~'7; Y [.'~ F: t'.J N I!!: 'T' 'T' Anchorage ~':.', 'i" ["1 ~ r.:-..-) ~.:) .... ..} ,... ~ I".', T .".'.' 'f' F-;.: T R I I'T' T {"i i'....t f': p, H r: f". ~ iH f". [': ~ M f': ri r'. A H F:. fl f:t A H r'.' r! r: A M r'. !"1 r'. 4,, H [": F! r'. ~ H f:: F! ARCO AI...A~KA. THC, P..OA RD× tOCZ6~ ANCHORAGE, AI..A~KA DATF' REFERENCE' ARCO CASED HOI...F FINAl.. ..X'-% 9-"~"-,qR,,_, , · :~-8'¢ I i-?-~7 4-2O 1 ¢-{ ~-R7 6-3 o_~o_o-~ 6-8 { ~.)-{ -87 ,6--t 7 6-?~ { ¢-t -87 A--?m 6-?3 t . 9-5 i O-R-R7 PLEASE R~CETVFD HAVE A COl. C{'!1.. Crll_ COl.. C 0 I... C. OI. COl_ COl.. ...AR/F'ERFORAT T ON AR/F'FRFF1RATT IqN ...AR/F'ERFORATT ...AR/PFR'FRRAT T tan ...AR/F'FRFFIRAT ! F1N ... A R'./I:'..g.. R F ri R A'T ...AR /F' E F;: F ii F;.' A T ... AR' / F' F R'F:F!R AT T ON N N C OI...I...AR / F'FRFOR AT T. 0 COl.. I..AR/F'ERFCIRAT T 0 C 0 I...I... AR / F:' E F:. F O R. A T I ITl COl. 1... A R / F'E F,' F nl:;t AT T n N COl.. I... Al;.' / F'F..RFOR AT I ON i (-)-24-87 ~jqt:.I.'t.~'/F'ER'FOR.A,T.,7ON ~ RUN t , T.(;N. AND R~--~'TA F"¥ r!l-- DATA,. NTC!--. U$Y ' K'I.!N RUN RI!N PI. IN RIIN Itl. IN RIIN RI. IN F(I.IN R'!..IN RI.IN F'F{; [;,Y [~FNNFTT ATO-i 529 'TRAM,5.' :~,°,P,i AR AF'F'~'OVF!) DTSTRTRI. ITT~N CENTRAl... FILES C H E V R F} N EXTENSION EXF'L.ORATIRN EXXON MARATHON MOBil_. ~ PHI I...t... 1: P,.g F'R I,IEI...I F'rt F~' ""- ,~ A F' f"t. ,.,11. ¢ -- STATE OF AI..A,:,KA · "'.,- T F"X A f':. []. STATE OF ALASKA ALA-~<A OIL AND GAS CONSERVATION COtv.,-,.vilSSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, ][nc. 3. Address P. 0 4. Location 1199 · Box 100360, Anchorage, AK 99510 Stimulate [] Plugging [] Perforate ]~¢. Pull tubing [] of well at surface 'FSL, 837'FWL, Sec. 11, T10N, R15E, UH At top of productive interval 2186'FNL, 991'FEL, Sec. At effective depth 2232'FNL, 1051'FEL, Sec. At total depth 2396'FNL, 1264'FEL, Sec. 5. Datum elevation (DF or KB) 61' RKB Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number 3-8 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length 15, TION, R15E, UM 15, TION, R15E, UM 15, TION, R15E, UM 8. Approval number 7-814 9. APl number 5O-- 029-20231 10. Pool Prudhoe Bay 0il Pool 10370 feet 9338 feet 9878 feet 8955 feet Size Plugs (measured) Schlumberger Plus plug w/30' of cement @ 9878' Junk(measured) Wireline tag indicates fill @ 9865' Cemented Measured depth True Vertical depth Conductor 73 20" 350 sx PF 1'1 134' 134' Surface 2647' 13-3/8" 5321 sx PF 11 2708' 2708' Production 10276' 9-5/8" 1000 sx Class G & 10337' 9330' 105 sx PF 11 Perforation depth: measured 9732-9772', 9774-9788', 9804-9829', 9832-9842', 9850-9860' 9870-9875' 9909-9944' (squeezed), 9957-9977' (squeezed), 9608-9640' true vertical 9791-9795', 9914-9920' ,SS 8743-8777', 8778-8790', 8801-8824', 8829-8839', 8840-8848' 8857-8861' 8891-8920' (squeezed), 8931 8948' (squeezed), 8639-8666' , , -- , Tubing (size, grade and measured depth) 8792-8796' 8896-8901' 5x" 17# L 80 w/tail @ 9423'MD 2 ~ , -- Packers and SSSV (type and measured depth) BAL-0 SSSV @ 2228', SB-3 Packer @ 9298'MD 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Gas Cons. 5200 4370 160 -- 312 14. Attachments Daily Report of Well Operations ¢ Copies of Logs and Surveys Run [] is true and correct to the best of my knowledge ~" ~'-/~- ~ 15. I hereby certify that the foregoing Form 10-404 Rev. 12-1-85 Submit in Duplicate STAT17/3-8 S. A. Digert (263-4290) Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 4900 2540 150 -- 385 DS 3-8 Daily Report of Well Operations Add Perfs 11/2/87 MIRU. PT equipment to 3500 psi. OK. SI wel 1. RIH w/gun #1: 3-3/8", 120° phasing. Tagged PBTD @ 10232'MD, TTL @ 9412'. Open well. Shot 9917' and 9920' (1 shot/3'). Shot 9791-9795' @ 4 SPF. S.I. well. POH. All shots fi red. RIH w/gun #2: 3-3/8", 6 SPF, 60° phasing. Open well. Shot 9620-9640'. S.I. well. POH. All shots fired. RIH w/gun #3: 3-3/8", 6 SPF, 60° phasing. Open well. Shot 9608-9620'. S.I. well. POH. Gun misfired. Rerun Gun #3. Open well. Shot 9608-9620'. S.I. well. POH. All shots fired. RD. STAT17/3-8 STATE OF ALASKA AL/-,...~.,A OIL AND GAS CONSERVATION CO,~ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order' [] Perforate I~ Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0, Box 100360, Anchorage: AK 99510 4. Location of well at surface 1199'.FSL, 8.27' FWL, Sec At top of pro(~uc[~ve interval ' 2186'FNL, 991'FEL, Sec. 11, TION, R15E, UM 15, TION, R15E, UM Ateffective depth 2232'FNL, 1051'FEL, Sec. 15, TION, R15E, UN At total depth 2396'FNL, 1264'FEL. Sec. 157 TION, R15E, UM 10370 feet 9338 feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured 9878 feet true vertical feet 8955 Casing Length Size. 5. Datum elevation (DF or KB) 61' RKB Plugs (measured) 6. Unit or Property name Prudhoe Bay' Unit 7. Well number 3-8 8. Permit number 76-73 9. APl number 50-- 029-20231 10. Pool Prudhoe Bay Oil Pool Junk (measured) Cemented Measured depth True Vertical depth Conductor 73 20" Surface 2647' 13-3/8" Production 10276' 9-5/8" 350 sx PF 11 134' 134' 5321 sx PF 11 2708' 2708' 1000 sx Class G 10337' 9330' Perforation depth: measured 9732-9772' 9774-9788' 9804-9829' 9870-9875', 9909-9944' (squeezed), 9957-9977' (squeezed) true vertical 8743-8777' 8778-8790' 8801-8824' 8857-8861', 8891-8920' (squeezed), 8931-8948" (squeezed) Tubing (size, grade and measured depth) , 9832-9842' , 8829-8839' 5½", 17#, L-80 w/tail @ 9423'MD Packers and SSSV (type and measured depth) BAL-O $$SV @ 2228'; SD-3 Packer fa 929R'MD 12.Attachments Description summary of proposal Detailed operations program [] BOP sketch [] , 9850-9861 ,8840-884~ 13. Estimated date for commencing operation October 27, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby/~ertify thc, t the fo_regoing is true and correct to the best of my knowledge Signed Title Operations Engineering Manager Date Commission Use Only Conditions of approval Approved by Form 10-403 Rev 12-1-85 Notify commission so representative may witness i rova, No. [] Plug integrity [] BOP Test [] Location clearance Dy order of ~ ; the commission Date STAT17/3-8 S. A. Digert (263-4290) feet I I Submit in triplicate ARCO Alaska, Inc. proposes to add perforations in DS 3-8 for selectefd intervals within the Sag and Sadlerochit Sands from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operations. Proposed Perforation Intervals: 9608-9640' MD (32') 9791-9795' MD (4') 9914-9920' MD (6') Sag River Sand Ref: BHCS 11/6/76 ADDENDUM WELL: 11/01/86 3-8 RIH w/DBP blanking plug to 9287' SLM, unable to get past PBR, POOH. Rn impression block; showed lip on low side. POOH. RIH w/2.875" swage to 9500' SLM, POOH. SI well. RU DA, rn ~emp tl & tst ea GLM; determined leaking orifice vlv @ 9238'. Rn impression block to 9307'. RIH, pull vlv. Pmp 275 bbls diesel dn tbg. RIH w/gas lift dummy. Dril~g SuperviSor /Date ARCO AI.a~-ka, Inc. F:'. O, Box Anchorage, Alaska 995i0 DATE: February i 9.. i987 I-,, I::. I.. E:. I.,, E. N C E · A R C 0 C. a .'.s' e (:1 I..I o l e F' i n a l ~ :3-.-. 6 2 .-- t -8'7 I n j, I::' r o f i l e R ,.x'ni , ..., --"' 3 '? ,.."~ -,=. ''~-.',.-¢~'7 I n j , F' r o f i l e ' R u n i , ~ :3"-' 8 '2-'2"" 8'? I::'r o (:1, F:' r o f i I e F;.'. u'n i , 5" ~:3--- t '2 t -- :3 t - 8'? I n .j F:' r o f i l e F,' u nt , '-"":3-t:3 2-ti .... 8Y In.j, F:'rofi Le Run t, ."~" :3- 26 "~ "> R"~ P ,.- ..-.,~, r o d. F:' r o '1:' i I. e F,' u nt , -"9-5 t/2(~.--30/87 F:'rocl. I::'rofi le Run t, 5" --'---9--[5 2-4-87 Temp, Log I_eak Det'eci'iona Run t, 2" -'--' 9-7 2-4-87 GR/F lowmeter I:;:uni '-------9-t t t-26-8'? ~'p inner/GR Run t , '--'~9-.t .'3 :').-5-8'? GR/F lc')wme'l:er Run i 9- ,.~ 6 2- 6 - 8 '7 I:; R / F l o w m e t' e r F: u n t , '"""'9 .... 2"? 2/6-7/87 I::'rod, F:'rofii: le I:;:L~nt , 5" ~ t 8-. t ''~ ") .... ,.. ~.. t5.-8'? (;R/Tubing ollar I..og Run 1, C 8 hi c o C a m c: o C ~ ~nc o C a m c: o C a m ~ o C ~ iii c o C a m c o g i~ Iii (~ 0 C a m c o Camco C a m~ o C8 I::'lea~e sign and re+.urn ~he a~ached copy a~ rec:eip+, of data, F;,'ec e i red HAVE:_' A NIE:E II)AY! R o.<;' 61 lrl I'l e Peek A'I"O .... t "~'.,,= ''~ g. 'I'RAN~; ~871 05: A p p r o v ecl FEB231987 Alaska Oil & Gas Cons. Commission Anchorage D :[ ::~ T R I B U T :1:0 N · ,,.'"' C e n 'f. r a L F:' i L e ~' · "' Cl') ev~" D & M ..-""E x T e n .s i o n IF- x p I. o r a T i o n · .-'"' E x x o n Pi a r a T h o n :',': M o b i L ARCO Al~'km, Inc P~O. Box A'r'~c' h c,r e g e, A 99.5~ 0 _.OA]"E · Dec emb er 'l 'i , 'i oo,. ,_,,_,': REFERENCE' ARCO r'_:a~:ed HoLe F'ina L ~_ I (.) t i - ;-.,':.'i,_4 C:i'.JL,.'(.~R Mu I. 'f i-'::?pace -' 'GR Mut'l' i '-'-">4 ~ 'i - ,'-RA ;'" i'"J L_ .,' S .... 8 'i '~ ~ ("). "- o'" 6 ['~ a m m a R a ':..' ,~-'i '~ 0~(b-86 F'F"-' ,...og Run F~'~,"n ~ , 5'" Run l)'~" e~ D r e .~ :~.' D'r' es:-: D r e .'._--. ~ D!£TR!BUTiON A L a z i.-'. a STATE OF ALASKA 0 RIG IN ALASKA'OIL AND GAS CONSERVATION C~MISSION f&~/' ~,,, WELL COMPLETION OR REcoMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ~ 2. Name Operator, ~/ of 7. Permit Number ARCO A1 aska, ~nc. 76-73 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-20231 , 4. Location of well at surface 9. Unit or Lease Name 1199' FSL, 837' FWL, Sec. 11, T10N, R15E, UN Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1369' FNL, 1~64' FEL, Sec. 15, T10N, R15E, UN 3-8 At Total Depth 11. Field and Pool 1578' FNL, 1438' FEL, Sec. 15, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.)16.Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 61' RKBI ADL 29331 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 1 0/21/76 11/06/76 11/13/76*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey i 20. Depth where SSSV set 21. Thickness of Permafrost 10370'MD,9338'TVD 10255'MD, 92z~2,;T~/~) YES~] NO []I 2228 feetMD 1900' (Approx.) 22. Type Electric or Other Logs Run D IL/SP, BHCS/GR, FDC/CNL/GR/Cal, CNL/CCL, GR, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD ] CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20:: 94.0#Ve~:co H-40 Surt 7:3' 32" 350 sx PF II 1:3-3/8" 72.0#Butt MN-80 Surf 2708' 17-1/2" 5321 sx PF il 9-5/8" 47.0#Butt MN-80 & Surf 10337' 12-1/4" 1000 sx Class "G" & 275 sx PFC SM -95 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) *9732' - 9772'MD 4/spf r~-!/2" 9~.23' 9298' *~9774' - 9788'MD *added on 1/09/85 **9804' - 9829'MD **re-perf'd on 1/09/85 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. **9850' - 9860'MD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED *'9870' - 9875'MD .N/A 9911' - 9946'MD 9956' - 9980'MD TVD of Perf,: ~O~:' - 90!2' 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) June, 1977I F1 owing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIo 03/12/82 6.2 TEST PERIOD I~ 879 200 18 25I 422 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr') Press. 829 NA 24iHOUR RATE I~ 2857 1 248 70 26.3 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None **Note: Well was worked over 11/12/86. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE (DAM) WCl/159 Submit in duplicate 29. 'NAME Top Sag River Top Shublik Top Sadlerochit Base Sadlerochit GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 8714' 8747' '8819 ' 9332' 30. 9605' 9644' 9730' 10338' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravitv, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Addendum (dated 11/15/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge _~_~ ~J~J~.y~L~ Associate Engineer Signed__~.~_I ~ Title INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 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 cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 STATE OF ALASKA ALASKA '~.[. AND GAS CONSERVATION COMMIS~.~JN REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Alter Casing [] Other Operation shutdown 99510-0360 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360 Anchorage, AK 4. Location of well at surface 1199' FSL, 837' FWL, Sec. 11, TION, R15E, UM At tOp of productive interval 2186' FNL, 991' FEL, Sec. 15, TION, R15E, UM At effective depth 2388' FNL, 1170' FEL, Sec. 15, T10N, R15E, UH At total depth 2396' FNL, 1264' FEL, Sec. 15, TION, R15E, UN 11. Present well condition summary Total depth: measured true vertical measured true vertical 10370 'MD feet feet 9338 ' TVD 10255 ' MD feet 9242 ' TVD feet Effective depth: Stimulate ~ Plugging r2 Perforate ~ Pull tubing WORKOVER 5. Datum elevation (DF or KB) RKB 61 ' 6. Unit or Property name Prudhoe Bay Unit 7. Well number 8. Approval number 256 9. APl number 50-- 029-20231 10. Pool Prudhoe Bay 0il Pool Plugs (measured) None Junk (measured) None Feet Casing Length Conductor 73' Surface 2647' Production 10276' Size Cemented Measured depth True Vertical depth 20" 350 sx PF II 134'MD 134'TVD 13-3/8" 5321 sx PF II 2708'MD 2708'TVD 9330 ' TVD 9-5/8" 1000 sx Class G 10337'HD Perforation depth: measured true vertical Tubing (size, grade and measured depth) 5-1/2", L-80, tbg w/tail @ 9423' 9732'-9772'MD 9804'-9829'MD 9870'-9~ 9774'-9788'HD 9850'-9860'ND 9911'-9946'MD 8826 ~ -8854 ' TVD 8880 ' -8901 ' TVD 8938 ' -8941 ' TVD 8856'-8867'TVD 8920'-8928'TVD 8971 '-9000'TVD 9008'-9029'TVD Packers and SSSV (type and measured depth) SB-3 pkr @ 9298 & Bal-O SSSV ~ 2228' 12. Stimulation or cement squeeze summary None Intervals treated (measured) Treatment description including volumes used and final pressbr'e 13. Representative Daily Average Production or Injection Data N/^ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation Subsequent to operation Tubing Pressure 14. Attachments (Workover Well History) Daily Report of Well Operations~ - Copies of Logs and Surveys Run 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Title A~ogi~ Engineer (DAM) SW0/131 Date Submit in Duplicate ARCO Oil and Gas Company Well History- Initial Report - Daily Instructions: Pre0are and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only, District Alaska Field Prudhoe Bay Auth, or W.O. no. AS0740 JCounty, parish or borough North Slope Borough IkeaseorUnit ADL #29331 ITitle Recompletion JState Alaska - w/o WWS #1 &PI 50-029-20231 Operator ARCO Alaska, Inc. Date and depth as of 8:00 a.m. Spudded or W.O. begun IDate IHour Workover 11/02/86 11/o2/86 thru 11/03/86 11/04/86 11/o5/86 11/06/86 11/07/86 11/08/86 thru 11/10/86 11/11/86 thru 11/12/86 Complete record for each day reported 1230 Hrs. IARCO W.'. 21.66% Prior status if a W.O. 9-5/8" @ 10,337' 8.5 ppg Brine Accept ri~.@ 1230 hrs, 11/2/86. Pull BPV, set tst plug. Kill well. ND tree. NfO' BOPB. 9-5/8" @ 10,337' 9.1 ppg Brine RU DA, perf tbg @ 9255'-9258'. Displ well w/8.8 ppg brine & circ. SI well, wt up to 9.1 ppg & displ well; well dead. Pull tbg hgr to flr. Pull tbg. 9-5/8" @ 10,337' 9.1 ppg Brine Fin POOH w/5½" tbg. OK. TIH w/FTA #2. Chg pipe rams to 3-1/2" &tst to 5000 psi; 9-5/8" @ 10,337' 9.1 ppg Brine 9878' PBTD RIH, tag PBR, rotate, POH; no rec'y. RIH w/wsh pipe, tag top of fill @ 9280', wsh & rm to 9319', mill on pkr @ 9319'. 9-5/8" @ 10,337' 9.1 ppg Brine 987&' PBTD RIH, tag PBR, rotate, POH; no rec'y. RIH w/wsh pipe, tag top of fill @ 9280', wsh & rm to 9319', mill on pkr @ 9319'. 9-5/8" @ 10,337' 10,255' PBTD, POH w/GR/CCL 9.1 ppg NaC1 Brine Mill on SAB pkr, CBU, circ out gas. SI well, circ thru choke, POH w/pkr. RIH w/8-1/2" bladed flat btm mill, tag TOC @ 9805', drl cmt to 10,160'. Wsh & rm to 10,255', CBU, POH. RIH w/RTTS, set @ 9711', tst 9-5/8" csg to 2300 psi. RIH to 9893', rn GR/CCL correlation log f/10,256', set RTTS @ 9891'. 9-5/8" @ 10,337' 10,255' PBTD, WO S/L unit 9.1 ppg NaC1 Brine Set RTTS @ 9877', tst lower perfs f/9909'-9977' to 800 psi, lost 10 psi in 30 min. RIH to PBTD, circ& filter brine, POH, LD DP. RU Schl, rn GR/JB to rec rubber lost in hole, stuck GR @ 9970'. Wrk free, POOH, RD Schl. Instl 5½" rams &tst. PU pkr assy, RIH on 5½" tbg, lnd tbg hgr. RU S/L to set &tst pkr. The above Is correct Oate 12/04/86 ]Title Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pagea 86 and 87. ARCO Oil and Gas Company Daily Well' istory-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended tot an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation d space is available Accounting cost center, code State Alaska JWell no. 3-8 W/O District County or Parish Alaska North Slope Borough Field Lease or Unit Prudhoe Bay ADL #29331 Auth. or W.O. no. Tit e AS0740 Recompletion WWS #1 API 50-029-20231 I otal number of wells (active or inactive) on this cst center prior to plugging and J bandonment of this well I our I Prior status if a W.O, I 1230 Hrs. Operator A.R.Co. W.I. ARCO Alaska, Inc. 21.66% Spudded or W.O. begun Date Workover 11/02/86 Date and depth Complete record for each day reported as of 8:00 a.m. Old TD Released rig 9-5/8" @ 10,337' 10,255' PBTD, RR 9.1 ppg NaC1 Brine RIH, pull SSSV dummy. RIH w/std'g vlv to 9403'. to 3000 psi. ND BOPE, NU & tst tree to 5000 psi. 11/13/86 Classifications (oil, gas, etc.) Oi[ protect well. Ri{ @ 2400 hrs, 11/12/86. (TT @ 9423', SSSV @ 2228') Press tst ann Freeze J New 10,255 ' TD PB Depth Date K nd of r g 2400 Hrs. 11/12/86 Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Sadlerochit Potential test data Well no. Date Reservoir Producing Interval lOll or gasTest time Production , Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % iGOR Gravity Allowable Effective date corrected The/,~l~.~ts correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IOate Title 12/04/86 Drilling Supervisor STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL ;t~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510-0360 4. Location of Well Surface: 1199' FSL, 837' FWL, Sec.11, TION, R15E, UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 61 ' 6. Lease Designation and Serial No. ADL 29331 7. Permit No. 76-73 8. APl Number 50-- 029-20231 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 3-8 11. Field and Pool Prudhoe Bay Fie]d Prudhoe Bay 0i1 Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment · Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of startin~g any proposed work, for Abandonmentsee20 AAC 25.105-170). The workovers described in our Sundry Notices, dated 9/13/85 and 5/21/85, have not been performed, nor are they scheduled to be done as proposed. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below fc~Commission use Title Associate Engineer Date Conditions of Approval, if any: Approved by CQMMISSIONER By Order of the Commission Date Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1-80 (JC) SN/170 and "Subsequent Reports" in Duplicate STATE OF ALASKA ALAS~ OIL AND GAS CONSERVATION COMI~'~,~$SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend [] Operation Shutdown [] Re-enter suspended well ~ Alter casing Time extension [] Change approved program ~ Plugging [] Stimulate ~ pUll tubing X Amend order ~ Perforate ~ Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 61 'RKB 3. Address P. 0. Box 100360 Anchorage, AK 99510 4. Location of well at surface 1199'FSL, 837'FWL, Sec.ll, TION~ R15E, UM At top of productive interval 2186'FNL, 991'FEL, Sec.15, TION, R15E, UM At effective depth 2232'FNL, 1051' FEL, Sec.15, TION, R15E, UM At total depth 2396'FNL, 1264'FEL, Sec.15, T10N, R15E, UN 6. Unit or Property name Prudhoe Bay Unit 7. Well number ~-~ 8. Permit number 76-73 9. APl number 50-- 029-20231 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 1 0370 feet 933 8 feet Effective depth: measured feet true vertical 9878 feet 8955 Casing Length Size Conductor 73 ' 20" Surface 2647 ' 13-3/8'? Producti on 10276 ' 9-5/8" Plugs (measured) Schlumberger Plus plug w/30' of cement @ 9878' Junk (measured) Wireline tag indicates fill ~ 9865 ' Cemented Measured depth 'True Vertical depth 350 sx PF II 134'MD 134'TVD 5321 sx PF ! I & 2708 'MD 2708'TVD 1000 sx Class G 10337'MD 9330'TVD Perforation depth: measured See attached sheet. true vertical See attached sheet. ~bing(size, grade and measured depth) 5-1/2" tubing w/tail ~ 9478' Packers and SSSV(type and measured depth) BAL-0 SSSV ~ 2198', SAB packer ~ 9343' RECEIVED JUL 1 7 1986 Atask30ii & G~s Cons. commissio..n Anchorage 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation August 25, 1986 14. If proposal Was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~0~ ~,,~.~.'~J Title Associate Engineer Commission Use Only ~r?( TEM ) SA/082 Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity ~l, BOP Test [] Location clearance I Date Approved by Form 10-403 Rev 1 by order of ~ _ / Commissioner the commission Date ~/ /~ Submit in triplicate APPLICATION FOR SUNDRY APPROVALS DS 3-8 Summary of Proposal ARCO Alaska, Inc., proposes to perform a workover on 3-8 in August, 1986, to squeeze perforations and install gas lift mandrels. The workover will be executed in the following manner: 1. MIRU workover rig. 2. Circulate well to brine workover fluid. 3. ND tree. NU BOP stack and test. 4. Pull 5-1/2" completion assembly. 5. Mill 9-5/8" permanent packer and cement plug. 6. Squeeze lowest 2 perforated intervals. 7. Run 5-1/2" tubing string with gas lift mandrels. 8. ND BOP stack. NU tree and test. 9. Displace well with diesel. 10. Shear out sub and install SSSV. 11. Secure well and release rig. 3-8 Perforation Depths 9732 9774 9804 9850 9870 9911 - 9772 MD - 9788 MD - 9829 MD - 9860 MD - 9875 MD - 9946 MD* 9956 - 9980 MD* 8826 8856 8880 8920 8938 8971 - 8854 TVD - 8867 TVD - 8901 TVD - 8928 TVD ~ 8941 TVD - 9000 TVD 9008 - 9029 TVD * Below plus plug. BHP = 3800 psi Workover Fluid - NaC1 filtered brine SA/O82a:tw II ANNULAR PREVENTER 6 BL ! ND RAMS PIPE RAMS 4 TUBING HEAD 3 ~ ,,.,-o/c, CASING HEAD 2. 9-5/6" CASING HEAD 7 ~'000 '"" , o-._,, ,_, ~uO0 P.?;I RAMS =~, .... :.-'1-~--;/;--~" - 5(:00 PSl BLIND F,'~MS.. 6. !3 :' ANN JL,~ -o/e -5000PS! ..... ACCUMUL -~ ~ .._ A~OR CAPACITY TFST i, CHECK AND :¢:',-,.~ ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. Y. AID.SL, :,E THAT ACCUMULA,'rOP. PRESSURE tS 3000 PSI WiTH :500 PSi DOWNS .... ;" ~cA!l OF THE REGULATOR, - ' .... H,,-N c. OBo:RVh_ TIME, ~- ~' CLOSE ALL'"v'~'~' ,--, · u~o ~MULTANEOUSL¥ AND RECORD THt:: TiME AND PRESSURE ~EMAINtNG AF, E,. ALL UNITS ARE CLOSED WiTH CHARGING PUMP OFF. 4. P, ECOP, D ON THE IADC REPORT, THE ACCEPTABLE LOWER LiMiT it,.; 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING R [ C r !V E D i2 13 J U L 1 7 i986 FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. CHECK THAT ALL HOLD-DOWN SC¢,!EWS ARE FULLY PETP. ACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT i.,',l WELLHEAD. RUN iN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES TEST ALL COMPONENTS TO 250 PSt AND HOLD FOR 10 MINUTES. ,LErD 'FO ZERO PSt. ---'-' _, I--'I .~, OPEN ANNULAR PREVEN'*-' AND CLOSE TOP SET O; PiPE RA ! - ~ -~ PRESSU;~E .'_-.,000 PSi AND HOLD FOR t0 ,M~NuTES ..-, ,-,c,= ;'A: ,;cc ~-,~c,--'r~ TC'.EAM ac ~ ' 8LSED PC'.ESSURE TO ZERO PSi TO TEST VALVES. TEST REI71A!NiNG UNTESTED ,~A,~i~¢,'",, c: V'ALV~S, iF ANY, WiTH .~0()0 DS~ ' ~mc'rm~^M C;F VAi t,'c AN? ": , ~ , ,,,'g.~, ...... f ~.l,~' ,~¢ i t~,~_~-~; , -! , .,~ -, ~.. w'i TH ZERO PSi DOWNSTREAM, 6LEED ,--,,c.~ ..,-:~"i ,-n TO ZERO PS', ',.,', ~.: ~ ,... , CL'''''''~' ~ i.ND F-<AN$ ..... "' ....... :,r_ bL AND TEST lO aOvO ~"'" , r-.al FOR t0 MINUTES, ;'.':PEN ~.~ AN:~ pc,',',', ,~m T'P'qT n, ...... _ . : !AN!rk.~LU L~",iES ~.:.:E FULL C;F A~'CT!C DIESEL AND ALL VALVES APE SET ~N THE u~ c_ :"~,.J ,.. _,, S .... K..~ Al-ID I ~r_bi ¢~'~ LY COCKS .NS!DE BOP TO 5000 PS! WiTH KOOMEY P.!MO. q;ECOPD TEST ~NFO,~:MAT!ON ON 5LOWOUT P~EVENTEg: TEST FO~;"'~. SiGN AhD SEND TO DRiLLiNG SUPET-.'ViSOF.~. OPEC!ATE 8OPE DALLY· OG dUNE 16, 1986 ARCO A[a_'.:-.ka, inc. F'..O. ?.c,x J,'"J;?..'7,6¢, A'.,-'-.-chc:'?age, A[aska STATE OF ALASKA ALASKA CIVIL AND GAS CONSERVATION Co~'MlSSlON SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc, 3. Ad~res~_. v. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 1199' FSL, 837' FWL, Sec.11, T10N, ELSE, UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 61 ' 12. I 6. Lease Designation and Serial No. ADL 29331 7. Permit No. 76-73 8. APl Number 50- 029-20231 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 3-8 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing ~ Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of start!ng any proposed work, for Abandonmentsee20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perform a workover on 3-8 in September~ 1985, to install gas lift mandrels. Th~ workover wi]] be executed in the following manner= 1. MIRU workover rig. 2. Circulate well to brine workover fluid. 3. ND tree. NU BOP stack and test. 4. Pull 5-1/2" completion assembly. 5. Mill 9-5/8" permanent packer.I 6. Run 7" x 5-1/2" tapered tubing string with gas lift mandrels. 7. ND BOP stack. NU tree and test. 8. Displace we. ll to crude oil, leaving diesel cap on annulus. 9. Shear out sub and install SSSV. 10. Secure well and release rig. RECEIVED Anchora9~ A subsequent sundry will be submitted following the completion of this workover detailing the new completion details. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. 14, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ Title Area Drilling Engineer _Th~,~ b~l~or Commission use Date Conditions of Approval, if any: · Approved by. Form 10-403 Rev. 7-1 ~0 (GLA) ~proved Copy I~eturnect By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska. Inc. Post Othce Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: May 29, 1985 Reference: Arco Pressure Data 1-4 Static Test 1-16 Static Test 2-1A Static Test 2-5 Static Test 3-8 Static Gradient 3-14 Static Gradient 3-15 Static Gradient 3-25 Static Gradient 5-3 Static Test 7-2 Static Gradient 9-21 Static Gradient 9-23 Static Gradient 13-26 Gradient 12-8 Static Gradient 12-8B Gradient 13-14 Static Gradient 14-15 Static Gradient 14-31 Static Gradient · 5-19-85 ARCO 5-19-85 ARCO 5-20-85 ARCO 5-20-85 ARCO 4-24-85 C~mco 4-24-85 Camco 4-24-85 Camco 4-24-85 Camco 5-19-85 ARCO 4-27-85 C~mco 5-6-85 Camco 5-6-85 C~mco 5-4-85 Camco 4-29-85 Camco 4-18-85 Camco 4-21-85 C~mco 4-26-85 Camco 4-26-85 C~mco Please sign as receipt of data. Received by Pam Lambert Chevron ATO 1429C D & M Trans 123 Expl. Servi=es Ext. Explor-zt ion Exxon Marathon Mobi 1 Alaska Oil & Gas Cons. Commission Anchorage Phillips PB Well Files R& D Sohio State of Alaska Texaco STATE OF ALASKA ALASKA OTL AND GAS CONSERVATION COI~IMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL ~ OTHER 7. Permit No. 2. Name of Operator ARCO Alaska, Inc. 76-73 3'Ad~lr. es~. Box 100360, Anchorage, AK 99510 4. Loc~atio, n of Well burTace: 1199' FSL, 837' FWL, $ec.11, T10N, R15E, UH 6. Lease Designation and Serial No. ADL 29331 5. Elevation in feet (indicate KB, DF, etc.) RKB 61 ' 8. APl Number 50-- 029-20231 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 3-8 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well ~ Change Plans [] Repairs Made Pull Tubing J~ Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perform a workover on 3-8 in September, 1985, to install gas lift mandrels. The workover will be executed in the following manner: 1. MIRU workover rig. 2. Circulate well to brine workover fluid. 3. ND tree. NU BOP stack and test. 4. Pull 5-1/2" completion assembly. 5. Mill 9-5/8" permanent packer. Cleanout to Z~BTD. 6. Run 7" x 5-1/2" tapered tubing string with gas lift mandrels. 7. ND BOP stack. NU tree and test. 8. Displace well to crude oil, leaving diesel cap on annulus. 9. Set packer and test completion. 10. Secure well and release rig. RECEIVED M. AY 2 ]98§ Alaska 0il & Gas Cons. Commission Anchorage A subsequent sundry will be submitted following the completion of this workover detailing the new completion details. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A 5000 psi WP wireline lubricator will be used and teste~ on all wireline work. 14. I hereby certify that the/t~egoing is true and correct to the best of my knowledge. ,,d . It Signed -~. L- ~~ ...... Title Area Dri 11 inq En.qineer ,The space below for Commission use Date Conditions of Approval, if any: I~I1111[ llllil' Approved by (GLA) ~q~provecf By Order of COMM~SSIONfiR the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: Apr il 23, 1985 Reference: ARCO CH Finals 3-8/ Perf Log 1-9-85 Run 1 5" Sch 6-5 ,j Collar Log 1-12-85 1 5" Sch 6-11~ Collar/Perf 12-25-84 1 5" Sch 11-12/TDT 3-20-85 1 5" Sch 12-23:J/Spinner/Temp 4-8-85 1 5" Camco 12-25 JCollar/Perf 12-7-84 1 5" Sch 12-26 / Collar/Perf 12-2-84 1 5" Sch 12-29L~ Collar/Perf 12-10-84 1 5" Sch 14-35~/ Collar/Perf 3-33-85 1 5" GO 17-10'j S 'inner 4-4-85 1 5" GO ~gn as Received by receipt of d~'ta. · , ~ Pam Lambert ATO 1429C Trans 081 Chevron D & M Expl. Services Ext. Exploration Exxon Marathon Mobil Mobil E & P Phi 11 ips PB Well Files R& D Sohio State of Alaska Texaco ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer February 5, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 3-4 DS 3-8 DS 3-11 DS 3-12 DS 3-13 DS 3-16 DS 3-17 DS 11-7 Permit No. 76-51 Permit No. 76-73 Permit No. 03-11 Permit No. 76-58 Permit No. 79-71 Permit No. 79-93 Permit No. 79-102 Permit No. 71-177 Dear Mr. Chatterton: Attached are Completion Reports for work completed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JB/mjb Attachments cc: Sohio Alaska Petroleum Co. File PI(DS 3-4)W1-3 File PI(DS 3-8)W1-3 File PI(DS 3-11)Wl-3 File PI(DS 3-12)Wl-3 File PI(DS 3-13)Wl-3 File Pi(DS 3-16)Wl-3 File Pi(DS 3-17)Wl-3 File Pi(DS 11-7)Wl-3 RECEIVED FEB 1 1 ]g85 Alaska Oil & Gas Cons. Commissjo~ Anchorage ARCO Alaaka, Inc. II · Subsidiary of AllanllcRIchlleldCompany STATE OF ALASKA ALASKA._--AND GAS CONSERVATION CO~_~/IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG r/1. Status of Well Classification of Service Well OIL [~× GAS [] SUSPENDED [] ABANDONED [] SERVICE [] :2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 76-73 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20231 4. Location of well at surface 9. Unit or Lease Name 1199'N & 837'E of SW cr Sec 11, TiON R15E, UM Prudh°e Bay Unit At Top Producing Interval "i0. Well Number 1369'N & 1164'W of NE cr Sec.15, TION, R15E, UM 3-8 At Total Depth 11. Field and Pool 1578'S & 1438'W of NE cr Sec. 15, TION, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 61' RKBI ADL 29331 12. DateSpudded10/21/76 13'OateT'D'Reached11/06/76 11/13/7614'DateC°mp"Susp'°rAband' Jl5'WaterDepth'if°ffsh°re 116'N°'°fC°mpleti°nSfeetMSL single 22. Type Electric or Other Logs Run DIL/SP, BHCS/GR, FDC/CNL/OR/Ca 1 iper, CNL/CCL, GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94#Vetco H-40 0' 73' 32" +350 sx PF II 13-3/8" 72# Butt MN-80 74 2708' 17-1/2" 5321 sx PF II 9-5/8" 47# Butt MN-80& 2709 10337' 12-1/4" 1000 sx Class "G" cmt SM-95 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) '9,732' - 9,772'MD 4/SPF 5-1/2" 10~261' 10~134' **9,774' - 9,788'MD *added on 1-9-85 **9,804' - 9,829'MD **re-perf'd on 1-9-85 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. **9,850, - 9,860,MD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAE USED *'9,870' - 9,875'MD N/A 9,911' - 9,946'MD 9,956' - 9,980'MD TVD of Perfs: 8804 - 9012' ,. 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) June 1977 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 3-12-82 6.2 TEST PERIOD I~ 879 200 18 25I 422 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 829 NA 24-HOUR RATE I~ 2857 1248 70 26.3 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Aiaska Oil & 8as Cons, C0~rnissi0a Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 2L). 30. GEOLOGIC MARKERs FORM,~TI'0N ':" ' :TESTS NAME Include interval tested, pressure data, all fluids recovered and graviiy, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sag River 9605' 8714' Top Shublik 9644' 8747' Top Sadlerochit 9730 ' 8819' Base Sadlerochit 10338' 9332 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ..... T itleRog~nn.ql t'~,~r_ l~ng_ Date'~/~ Signed INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 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 cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. Prudhoe Bay ,_,,gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer February 5, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 3-8 Permit No. 76-73 DS 11-7 Permit No. 71-177 Dear Mr. Chatterton: Attached are Subsequent Sundry Notices for work completed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JB/mjb Attachments cc: Sohio Alaska Petroleum Co. File PI(DS 3-8)W4-3 File PI(DS 11-7)W4-3 ARCO Alaakn, Inc. la e Subsidiary of AtlentlcRIchfleldCompany STATE OF ALASKA ALASKA C~IL AND GAS CONSERVATION COIglMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. NameofOperator 7. PermitNo. ARCO Alaska, Inc. 76-73 3. Address 8. APINumber P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20231 4. LocationofWell 1199'N & 837'E of SW cr Sec 11, TION, R15E, UM (surface) 1369'S & 1164'W of NE cr Sec 15, T10N, R15E, UM (top prod) 1578'S & 1438'W of NE cr Sec 15, T10N, R15E~ UM (TD) 5. Elevationinfeet(indicateKB, DF, etc.) 61' RKB 6. LeaseDesignationandSerialNo. ADL 28331 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 3-8 11.FieldandPool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and givepertinentdates, includingestimateddateofstartingany proposedwork, forAbandonmentsee20AAC25.105-170). Began perforating operation on 1-9-85. RU perforating unit and pressure tested equipment. RIH w/gun #1, shot select-fire interval 9870 - 9875' MD (4 SPF), pulled up and shot select-fire interval 9850 - 9860' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun #2, shot select-fire interval 9831 - 9842' MD (4 SPF), pulled up and shot select-fire interval 9824 - 9829' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun #3, shot interval 9804 - 9824' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun #4, shot interval 9774 - 9788' MD (4 SPF). Shut-in well, POOH, all shots fired. 1-10-85 RIH w/gun #5, shot interval 9752 - 9772' MD (4 shots fired. RIH w/gun #6, shot interval 9732 - POOH, all shots fired. Secured well, RD. Ref: BHCS 11-6-76 SPF). Shut-in well, POOH, all 9752' MD (4 SPF). Shut-in well, RECEIVED 1 1 1985 Alaska Oil & Gas Cons. C~mmmsion Anchorage Signed ~/~ ' Title Regional Engineer The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Prudhoe Bay~'~r~gineerin g Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer December 20, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 3-8 Permit No. 76-73 Enclosed is an "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/JEB/la Attachments cc: SOHIO Alaska Petroleum Co. File Pi(DS 3-8)W1-3 ARCO Alaska, Inc. t8 a Subsidiary of AllantlcRIchfleldCompen¥ STATE OF ALASKA ~,. ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE L LX[~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 1199'N & 837'E of SW or. Sec. 11, T10N, R15E, UM (surface) 7. Permit No. 76-73 8. APl Number 50-029-20231 9. Unit or Lease Name Prudhoe Bay Unit 1369'S & 1164'W of NE cr. Sec. 15, T10N, R15E, UM (top prod) 1578'S & 1438'W of NE cr. Sec. 15, T10N, R15E, UM (TD) 5. Elevationinfeet(indicateKB, DF, etc.) 61' RKB 6. Lease Designation and Serial No. ADL 28331 10. Well Number DS 3-8 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate ~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposedwork, forAbandonmentsee20AAC25.105-170). ARCO Alaska, Inc. proposes to perforate well 3-8 at selected intervals within the Sadlerochit Sand of the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 9732-9772' MD (40') Ref: BHCS 11/6/76 :gubsequant Work Report~l 14. I hereby ~tify that the fo[egoij0g is tr~e and correct to the best of my knowledge. , ~ , -, Regional Engineer Title Signed · v - c-~'~'~,'~ ' ~ ~ The space below for Commission use Date Conditions of Approval, if any: IRIGl#kt SIGN[I) IT LIIII~ilE C. S~iTR Approved by COMMISSIONER ~pproved Copy Ret, urned By Order of the Commission Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCC: Alaska, Inc. ?ost Office . 360 I'elephone 907 277 5637 April 13, 1984 Reference- ARCO Pressure Data D S. 3-8 3-17-84 Static .D.S. 3-11 3-17-84 Static Camco Camco /~Please sign and return the attached copy as receipt .of data. FRIDAY THE 13th is upon us - Have a Nice One! Kelly McFar land ATO-1429F Trans. #143 DISTRIBUTION Chevron D&M Dallas Drilling Ext. Exploration Exxon Getty Marathon Mobil Mobil E & P Phillips Prudhoe Bay Well Files R& D Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc. Post Oftic ~x 360 Anchorage. ~- ska 99510 Telephone 907 277 5637 December 16, 1982 RE: ARCO Pressure Surveys D.S. 3-8 11-20-82 D.S. 3-13 12-3-82 D.S. 3-15 11-21-82 D.S. 6-4 12-2-82 D.S. 6-11 11-11-82 D.S. 6-12 11-11-82 DiS. 11-6 11-7-82 D.S. 11-7 11-7-82 D.S. 13-1 10-22-82 DoS. 13-3 10-23-82 D.So 13-5 10-29/31-82 D.S. 13-22 11-22-82 D.So 13-23A 10-12-82 D.S. 13-24 11-19-82 Stat i c Survey Pressure Build-up Static Survey Pressure Buil d-up Static Survey Static Survey Static Survey Static Survey Static Survey Static Survey Pressure Bui ld-up Static Survey Static Survey Static Survey Camco Gearhart Camco Otis Camco Dresser Camco Camco Camco Camco Camco Camco Camco Camco D.S. 17-5 11-18-82 Static Survey Camco DoS- 17-6 11-18-82 Static Survey Camco 'L~Please sign and return the attached copy as receipt of data. Becky Benedict AFA- 403 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON Trans. #662 EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS Alask2 Oil & Gas Con~ Commissio~ Anchora9~ ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldComp~nv ARCO Alaska, Inc. Post Offic * 360 Anchorage'~ska 99510 Telephone 907 277 5637 October 26, 1982 Reference' ARCO Pressure Data D.S. 3-8 9-11-82 D.S. 3-11 9-8-82 D.S. 3-15 9-11-82 D.S. 12-6 Static Survey Static Survey Static Survey 7-30/31-82 Pressure Build-Up Analysis CAMCO CAMCO Gearhart CAMCO sign and return the attached copy as. receipt of data. Becky Benedi ct AFA - 403 Trans. #581 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY STATE OF ALASKA DALLAS Alaska 0il & Gas Cons. Commissior~ Anchorage ARCO Alaska, Inc. Telephone 907 277 5637 May 25, 1982 Mr. C.D. Chat Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Subject: D.S D.S D.S D.S . 3-8 Permit No. 76-73 · 12-10 Permit No. 81-53 . 12-11 Permit No. 81-73 · 12-12 Permit No. 81-83 Enclosed are Completion Reports for work done on the above-mentioned wells. V%~y truly yours, .... - ~ /~ "'-d.:. '~-~ ~ ,1 /~,D. F. Scheve District Operations Engineer DFS:TKKW:mlc Enclosures Distribution- Sohio Petroleum Co. STATE OF ALASKA ALASKA b"~-~ AND GAS CONSERVATION COF,~..~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE.E~ 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 76-73 3. Address 8. APl Number P.O. Box 360 Anchorage, AK 99510 50-029-20231 4. Location of well at surface 9. Unit or Lease Name 1199'N & 837' E of SW cr Sec 11, T10N,R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1369'S & 1164'W of NE or Sec 15, TZON,R15E, DM D.S. 3-8 At Total Depth 11. Field and Pool 1578'S & 1438'W of NE cr Sec 15, T10N,R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Oil Pool RKB 61' ADL 29331 _ 12. Oats Spudded 10-21-76 13. Date T.D. Reached 11-6-76 14. Date Comp., Susp. or Aband. 11-13-76 17. Total Depth(MD+TVD) 18.PlugBackDepth(MD+TVD) 19. DirectionalSurvey 1(_2CO>)DepthwhereSSSVset I ~'j,)ThicknessofP~rmafroSt 10370MD 9359T,V,'D10255MD 9262TVD YES;~] NOV] feetMD 22. Type Electric or Other Logs Run DIL/SP, BHCS/GR,FDC/CNL/GR/Caliper. C_NI./CCT.. 23. CASING, LINER AND CEMENTING RECORD -'~ ~I~NG DEPTH MD CASING SIZE WT. PER FT. GRADE '~ BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 2 0" 94~V~tco H-40 / -0' \~ -' '73' 32" +qqn .~Y PU' TT 13-3/8" 72#Butt MN-80 [ 74' ] 270R' ] 7-]/~." qq~] .~v P~ TT 9-5/8" 47#Butt ~-80& / 2709'/ 10337' . ]2-]'/4" ]~:~S _~ ~1~ "c."~me SM-95 \ ~../_..// .............. 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) .SIZE . DEPTH SET (MD) PACKER SET (MD) 5-1/2" 9478' 9343 ' 9778-9790 ~ 9832-9842" '~; 8842 ' -8910 ' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9802-9827 ~ ,~,~ .~.: ~/~o!,.~_ . DEPTH INTERVAL (MD). AMOUNT & KIND OF MATERIAL USED 9848-9858 -~ · 4 shots per foot 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas I.i~t, etc.) June 1977I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE sIzE 3-12-82 6.2 TEST PERIOD ~,. 879 ~.:. 200 18 25I 422 Flow Tubing Casing Pressure CALCULATED OI.I~-BBL GAS-MCF. WATER-DEL OIL GRAVITY-APl (corr) Press. 829 NA 24-HOUR RATE I~ 2957 1248 70 26.3 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · . /,.~ , /' , : · , Anch0ra¢~. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ' 30. .' . . GEOLOGIC MARKERS FORMATION TESTS NAME Include interVal tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sag River 9605 8714 Top Shublik 9644 8747 Top Sadlerochit 9730 8819 Base Sadlerochit 10338 9332 · 31~ LISI OF ATIACHMENTS 32. I hereby certify that the fore§oisg is true and correct to the best of my ksow~ed§e Signed /~~ ~ T itt eD i st-Opr. Enc~-. Date // - INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 AFICO Alaska~ Inc A~chora..qe. Alaska 99510 '!'elephon~ 907 277 5637 May 25, 1982 Mr. C.D. Chat Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Subject: D.S D.S D.S D.S · 3-8 Permit No, 76-73 . 12-10 Permit No. 81-53 · 12-11 Permit No. 81-73 · 12-12 Permit No. 81-83 Enclo detai wells sed are our Subsequent Sundry Notices ling the work done on the above-mentioned Very truly yes, f s, ,/ / / '?; . ~,. /~},,-~b. D. F. Scheve IDistrict Operations Engineer DFS:TKKW:mlc Enclosures Distribution: Sohio Petroleum Co. STATE OF ALASKA ALASKA ~-L AND GAS CONSERVATION CO-~.,'MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED W E L L:~;~: OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 76-73 3. Address 8. APl Number P.O. Box 360 Anchorage, AK 99510 5o- 029-20231 4. Location of Well 1199'N & 837'E of SW cr Sec ll,T10N,R15E,UM (surface) 1369'S & 1164'W of NE cr Sec 15, T10N,R15E,UM (top producin§) 1578'S & 1438'W of NE cr Sec 15, T10N,R15E,UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) RKB 61 ' 6. Lease Designation and Serial No. ADL 28331 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 3-8 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations C~: Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing E~ Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began reperforating operations on 3-10-82: Tested wireline BOP to 3000psi. Pulled subsurface safety valve with slickline unit. Also ran 3.6" gauge ring through landing nipple for minimum I.D. check. Rigged down slickline. .Rigged up conductor wireline unit for perforating. Tested wireline BOPs to 3000psi. Reperforated old intervals 9848'-9858' (10') and 9802'-9827' (25')MD with 3-1/8" hollow carrier gun, 4 shots per foot at 120° phasing. Perforated new interval 9832'-9842' (10') and 977819790' (14')MD with 3-1/8" hollow carrier gun, 4 shots per foot at 120° phasing. Well was flowing when guns fired and during POH to facilitate better well clean-up. Rigged down conductor wireline unit. Tested well at two different rates. Attempted to run spinner survey but well rate too low for tool used. Tests indicate rate improvement of approximately 1500 BOPD to 800 psi FTP capacity of 3500 BOPD from above perforating operations. R~E~V~D iVtA¥' 2 ? i982- 14. I hereby,,c~r~ify that the foregoing, j~ true and correct to the best of my knowledge. Signed ,,-'~-~~J-~'~'"- -- Title Dist. Oprs. The space/ow for Comm~ission use Conditions of Approval, if any' Alaska 0ii & Gas Cons. Commission Anchorage Engineering By Order of Approved by. COMMISSIONER the Commission Date Form 10~403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ~510 Anchorage. A..,ska a-n Telephone 907 277 5637 April 12,1982 Reference: ARCO CASED HOLE FINALS D.S.17-8 3/15/82 Collar & Perf Log Run 1 2"/5" D.S.17-9 3/13/82 Collar & Perf Log Run 1 5" D.S.3-8 3/12/82 Collar & Perf Log' Run 1 5" /Pleasesign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal JJ 89 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CtlEVRON EXXON D&bl GEOLOGY ;~ C ~'~] ~:~j ~ STATE OF A~S~ ARCO Alaska, In( February 24, 1982 Mr. C. D. Chat Chatterton State of Alaska Alaska Oil and Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Subject. D.S. 3-8 Permit No, 76-73 Enclosed is our Sundry Notice detailing the work to be done on the above mentioned well. Very truly you~, /~f.~' A. Rochon JAR'TKKW:ml c Enclosure ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieidComparly STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION COmlVllSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLX~ OTHER [] 2. Name of Operator 3. Address 4. Location of Well ARCO Alaska, Inc. P.O. Box 360 Anchoraqe, AK 99510 l199'N & 837'E of SW Cr. Sec. ll, TION, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 61' RKB 6. Lease Designation and Serial No. ADL- 28331 7. Permit No. 76-73 8. APl Number 50- 029-20231 9. Unit or Lease Name Prudhoe Bay [Init 10. Well Number D:-~: 3-8 1 1. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit Sand for production from the Prudhoe Bay Unit. Upon perforating the well will be flowed to the flow station for clean up and production. Should additional drawdown be necessary to unload the wells it may be flowed to a tank for initial clean up. The perforated intervals will be given in the subsequent report. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to working pressure. The SSSV will be installed at the conclusion of the perforating and clean up operation. 14. I hereby certi~y~lhat the forgoing is/t~e and correct to the best of my knowledge. ~./_/'] ~.~i ///~--~/¢~_,*-----//* / /// T~t~e District Operations Engineer Signed t /~ The space belo,fN/for Commission use Date Conditions of Approval, if any: Approved Copy Returned Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc October 12, 1981 Mr. Lonnie C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 De ar Mr. Smith' Attached is a Sundry Notice for reperforation of D.S. 3-8 for increased production. A subsequent report will be filed upon completion of the job. Please give me a call at 263-4246 if there are any questions. V..er-x~ tru 1,~lyours, ;J A. Rochon JAR/LWC/mjs Attachment ARCO Alaska. inc. is a subsidiary of AllanticRichfieldCompany STATE OF ALASKA ALASK~.__L AND GAS CONSERVATION C._~,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] cOMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 76-73 3. Address 8. APl Number ?. 0. Box 360, Anchorage, Alaska 99510 50_029-20231 4. location of Well 1199' N & 837' E of SW Cr Sec. 5. Elevation in feet (indicate KB, DF, etc.) 61' RKB 28' Pad Elev. 11, T10N, R15E, UM 6. Lease Designation and Serial No. ADL - 28331 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 3-8 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate E~:x Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent derails and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ,. ARCO Alaska, Inc. proposes to perforaLc this well to increase production.. The work will include perforation of new interval (25' at 8 shots per foot) and reperforation of the existing interval (4 shots per foot). The well will be flowed through the normal productio~ system during testing. The exact perforated interval will be reported on the subsequent report. All work will be performed using a 5000 psi working pressure wireline lubricator. The lu- bricator will be tested to working pressure before use. The subsurface safety valve will pulled for perforating activities and reinstalled after completion of perforating. Estimated start date - October 31, 1981. Subseque~t Work Reported 14. I hereb~'t,~fy that the/f,f~goin~true and correct to the best of my knowledge. il- ×' District Engineer Signed . Title ? ,- The sl~ace..below for Commission use Conditions of Approval, if any: Date Approved by . Approvecl 'opy COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate DRILL SITE # 3- 8 PERFORATION ANY) CLEANUP RECORD May 16-17, 1977 D.S. #3-8 has a bottom hole location in the NE Corner, Section 15, T10N, R15E, Prudhoe Bay Field. Depths of interest: Measured Depth Subs ea Depth Zone Top of Sadlerochit Gas/Oil Contact Perforations (four shots/foot) Water/Oil Contact Base of Sadlerochit 9727 8738 Not Present 9802-9827 8801-8824 9848-9858 8840-8848 9868-9873 8857-8861 9909-9944 8891-9920 9957-9977 8931-9948 10088 9O4O 10338 9251 UBS UBS UBS UBS CGL RIH with 1st gun, tagged bottom @ 10268',~and ran CCL log from 10243 to 9000'. Perforated 9957-9977' with choke open on 36/64". Saw immediate tubing pressure response of 450 psi and 6000+ BOPD. Flowed well for 145 minutes to cleanup. Recovered 216 bbls. of diesel in 42 minutes and 46 bbls. of CaC12 water in another 18 minutes. The CaC12 water was produced as a slug (100%). The highest anm~t of BS recorded was 0.1% by shakeout and the final sample taken showed 100% oil with just a trace of CaC12 water and a trace of BS. The final AP1 gravity was 24.6°. 2he final flowing tubing pressure, temperature, m~d average flowrate were 1280 psi, 39°F, and 7324 BOPD. RIHwith fluid density tool and discovered CaC12 water/oil contact @ 9954'. No emulsion was present above the contact. RIHwith 2nd gm~ and perforated 9924-9944' while flowing on 48/64" choke. Observed flowing tt~2ing pressure increase from 1020 psi to 1050 psi in 3 minutes. Rltt with 3rd gun and perforated 9909-9924' while flowing on 64/64" choke. Observed a 20 psi increase in tubing pressure within 5 minutes. RIH wi_th 4th gun (select fire) and perforated 9868-9873' and 9848-9858' M~ile flowing on 64/64" choke. Observed flowing tubing pressure increase from 1360 psi to 1380 psi in 5 minutes. The 10' gun (9848-9858') misfired. Choke is not same opening as indicated. Lost-four hours' time working on CCL. RIIt with Sth gtm and perforated 9802-9827' while flowing on 64/64" choke. Observed flowing tubing pressure increase from 1350 psi to 1375 psi in 5 minutes. Switch to using other choke. RIH with 6th gun and perforated 9848-9858' while flowing on 48/64" choke. Observed flowing tubing pressure increase from 990 psi to 1080 psi in 15 minutes. D.S. #3-8 ..... Perforation and Cleanup Record Page 2 RIH with dual Amerada bombs, making static stops near bottom. Flowed well for 95 minutes on 40/64" choke. Final flowing tubing pressure, temperature, and average flow'rate were 1260 psi, 55°F, and 10261 BOPD. SI well for 1-1/2 hour pressure buildup and recovered Amerada bombs. Determined that the static pressure @ 8800' ss was 4378 psi and the maximum drawdoxm while flowing was 362 psi, giving us an approximate Productivity Index of 28.3 STBD/psi. Maximin BHT was 196°F. rfl~e total volumes of oil and ga~ produced during perforating are estimated @ 1174 bbls. of oil and 881 MCF of gas. PDL 6/23/77 ARCO Oil and Gas Company North Ah "istrict Post Offici~-:.,~x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer April 15, 1981 Reference: ARCO Magnetic Tapes & Listings D.S.3-8 3/16/81 NLL 9400-10230 D.S.16-4 3/19/81 Tape #61471 Dresser Atlas Schlumberger - Please sign and return the attached copy Mary F. Kellis North Engineering as receipt of data. Transmittal #187 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOB I L GETTY PHZLLIPS /~ F F£ IVED ~., CHEVRON A~SKa 0~ & Ge, s bon. C0mmiss~ - Anch0~g~ ARCO Oil and Gas Company is a Division of AtlanticRichlieldCompany ARCO Oil and Gas Company North Ala: ;strict Post Oflice-"b~x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer April 7, 1981 Reference: ARCO Magnetic Tapes & Lists p.s.6-1 3/19/81 D.S.16-3 · 3/18/81 D.S.17-6 3/18/81 D.S.6-9 3/17/81 D.S.16-8 3/18/81 DDNLL 9100-9816 CNL/MS 10900-12240 CN 9200-10600 DDNLL 10090-10950 DNLL 9400-10200 CN 8648-10120 Dresser Atlas 11 II 11 II 11 II Il !! 11 I! ~lease sign and return the attached copy as receipt of data Mary F. Kellis North Engineering Transmittal #173 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON ARCO Oil and Gas Company ~s a Division of AllanticR~chfieldCompany ARCO Oil and Gas Company North Al 3istrict Post Offi~x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer March 13, 1981 Reference: ARCO Cased Hole Finals D.S.3-8 1/24-25/81 Run 3 & 4 DDNLL 5" sign and return the attached copy as receipt of data. Mary Kellis North Engineering Transmittal #122 D I S TR I BUT I ON NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA ARCO Oil and Gas Company is a Division of AtlanticRichlieldCompany EXXON MOBIL GETTY MARATHON MAR ! 8 CHEVRON Al~k~ 0il & Bas Oons, Oommi88io~ Anchorage ARCO Oil and Gas Company North Al District Post Ofl~ic~--~*.~ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer February 13, 1981 Reference: ARCO Cased Hole Finals D.S.3-8 Temp Log 1/25/81 Run 1 5" D.S.3-8 Plus Plug Bag Set 1/25/81 Run 1 5" Mary Keiiis North Engineering Transmittal #63 DISTRI BUTION NORTH GEOLOGY EXXON R & D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D & M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Nor!h Al;' "'~ DislricJ Post Oil. ox 350 A n c h o r a g ~-~,~1 a $ k a 99510 Telephone 907 277 5637 Jerry A. Roc!lon District Operations Engineer January 27, 1981 Reference: ARCO Cased }tole Finals D.S.i-i7 1/9/81 D.S.3-8 1/8/81 D.S.3-13 1/17/81 D.S.6-11 1/18/81 D.S.6-12 1/15/81 D.S.6-15 1/12/81 D.S.14-5 8/22/80 D.S.15-10 1/11/81 P.S.15-10 i/ii/Si D.S.16-1 1/12/81 D.S.16-1 1/12/81 DDNLL Run 1 5" DDNLL Run 2 5" Collar log Run 1 5" Spinner Run 1 5" Spinner Run 1 5" Collar log Run i 5'~ DDNLL Run 1 5" Collar log/Gyro correlation Collar log/Gyro correlation CNL/~ulti-Spaced Run 1 5" Collar log/Gyro correlation Please sign and return the attached copy as receipt of data. DIP 2"/5" (same log) Mary Kellis North Engineering Transmittal #17 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA ARCO O11 and Gas Company ~s a Division of AtlanhcR~chfieldCompany EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON? '..:' ARCO Oil and Gas Anc?.nr~,~;e. Al.:~ska 3~'5!0 Tet,~l~one 907 277 August 8, 1980 Reference' ARCO Pressure Surveys S. 3-7~'7/9/80 Pressure Build-up S 3-8~ 7/9/80 " Build-up S 3-17. 6/30/80 " Static S 3-18 7/2/80 " Static S 9-1 L .... 4/25/80 " Build-up FI I._,':: ? .- D.S S S S 9-3 u"5/3/80 " " 9-4 '- 5/4/80 " " 9-6 / 4/20/80 " " 9-10 '" 5/7/80 " " 9-15;., 5/~/80 " " 1~-7 :'5/2-5/80 Pressure Build-up /~ease sign and return the attached copy as receipt of data. K. J. Sahlstrom North Engineering rRANoMI I ?AL DISTRIBTI'ION North Geology [tx~xon R f~ D ~IoI_)il Drill lng Getty D f, ~I So]~io Geolo2)' ~.[arathon State off /Daska ~:evron ARCO Oil and Gas Company '," ", , :, .' ~ C':'i:.'.' ,) /. · "..... - I. -.-, "i "' ,.~ ,'., , .... ! --,~ ~; ..'.. '-' . ,.r, i' .? ~ ..... ~ .:" January 11, 1980 Reference' Enclosed are Pressure Surveys for the following ARCO wells' D..S. 9-1 }0/29-30/ 9 " D.~. 9-8 10/31-11/1/79" ease sign and return the attached copy as receipt of data. K. J. Sahlstrom North ,Engineering Ttb~{ITTAL # 011 DISTRIBI~TION North Geology Drilling Eng. Manager C, eo]_ogy St:ate of Alaska Exxon Mobil Getty Phillips Sohio }.larathon Chin,TOn Nor[h Ataska D!strict Pos~ 0 f,"ic x Telephone 907 277 5637 November 2, 1979 Reference: Enclosed are Cased Hole Logs for the following ~CO wells: ~~ '3/23/79 Epilog D.S. 14~-7 4/30/79 CNL 2" Please sign and return the attached copy as receipt of data; K. J. Sahlstrom North Engineering TRANSMITTAL # 451 ])ISTRIBUi"!ON North o. o., ~,~.oloo} Exxon D£J. 11 ing Mob i1. ling. Manager Getty R & D Sohio Ceo logy ~lara thon State of Alaska Pl~illips I) & bt Chevron Post O1ii~× 35,3 Anchor ,Ala3ka 99510 Tel.aphon~ 907 277 533? July 13, 1979 Reference' Enclosed are final p,r.~ints for the following ARCO cased-hole well~---!-,,, ~D.$. 1-13 .... ~al SpacCng Thermal Neutron Decav-..Time. ~/?x/~,?:~':(,, ~;~D.S. 7-12 '~CNL' (~'~-4=-~-~r'~=~;~. , _ / 7 ~' ~' - ...... o ..... ~fF~"~~ ~ qlZZ//~ '~ ~;5."--14-4 ~ompensated NeU~rc~T ...................................... 1/20/79 D.S. 14-5 ~coustic Cement Bond Lo~ ~L 2/20/79 D.S. 14-2 /~erforation Collar Lo; 3/9/79 5 D.2. 1-18 ~ Tie In L% For' ~wer Baker Packer 5/2/78 5" Run 1 ~ ...... 318 ...... ~-luid Density 2/12/7q ~" ~7~2- i'37~- ~0-i~f-'~-~-~--~ ....... ~ ........................................ 2/10/79-'-5 Please sisn and return the attached copy as receipt o~ data. Ve~, truly yours, R. A. Bellinger TRANSMITTAL # 215 DISTRIB(fI'ION North Geology Dri 1 ]. ing Eng. Manager R&D Geology State of Alaska I) & bi '~.ALXO TI Mobil. Getty Sohio Marathon Phil 1 Chevron Noi !h , e, Alaska 99510 Telephone 907 277 5037 July 13, 1979 Reference' Enclosed are Cased ttole Logs fOr the following 7kRCO wells' D.S. 3-6~ .g~gTna Average 3/23/79 D.S..3-6~Carbon/Oxygen Average 3/23/79 (~z~_.~'~~' S~gm? Average 3/23/79 D.S. 3-8-~..~12,~rbon/Oxygen Average 3/23/79 D.S. 3-6j .z>~l Detedtor NeutrOn Lifetime Log 2/20/79 D.S. 14-5 VB/erehole Geometry Log 1/18/79 D.S. 7-9~Z/Compensated Neutron 2/9/79 5" ('~ D.~ ?-~ ~,~,~.~ ~-r.-~..,, -~/"~ ~'~, ~/,'/~ ~" ..~ ease s zgn VeDz truly yours, /71 ,q ""' R. A. Bellinger TI~NSiXlI%rAL # 219 DISTRIBIH'ION North Geology Drilling Eng. Manager R & D Geology State of Alaska }7~X X OI 1 Getty Sohio Marathon Phillips Chevron July 12, 1979 Re~erence' Enclosed are Pressure Data Repo:ts for the following ARCO wells' ' i)~~S. 9-6 "<'? ~I)x5. 4- 5 ~~ %s'. ~-8 ~./. ~.s. ~-~ l lewlett Packard Pressure Data t lewlett Packard Pressure Data llesenroir Pressure & Temp. Data Hewlett Packard Pressure Data 5-22-79 ' .~' 5-22-79 6-19-79 6-19-79 Please sign and return die attached copy as 'receipt of data. Very truly yours, ~ .- ~ -) ~ :/: . ::.,t :.:,t ,';':-.'..':',: ..... R. A. Bellin:er TK&NSHITTAL I! 206 D; STf(I' l:i'l' ION Nort.}~ (;co'l ogy l.) i: i ] 1 i ~ ~ R & I.) (;cc;log)' StifLe o[ Alaska 1) & ~,I June ]_9, 19'79 Reference: t:!ncloscd is the cased hole log: Llietime log DS 3-8 Dual Detector Neutron ' ~ ' ~l. easc sign and return the copy as receipt of data. Sincerely, V. G ReJmers Nor th 'l'-!ng inc e r lng TRANS!vIiI TTAL /t 189 D t S'f], I }) ( iT t' ,i ]97,9 ] (¢;'~'01'oJ lc(:', · lh'~c'lo.';ed aro 'tl~e [7o-l. low:i_ng cased hole z~"f,$ 9--.1 6 T1)T 11./22/78 , ~c.~ 5-6 C/O 2/20/79 ~])S 5 6 1;]. i)ens. 2/].9/79 ,. ~S '5-'8--* (-:/O 2/]4/79 ~S 'i. 4-6 CN1, 3/25/79 ~-DS $ - '.I.'])T 10 /1.9./78 ~)S 5- 2 TJ)T 11/10/78 f:"~ ZS-S CNL .t/17/79 ~S ] 3~4 OR 5/30/79 ,~h;1)h~ ;l--i 'l'en~p. 1/15/79 ~ ].)S 7-1] CNL 3/27/79 (' nnd 're-tu].'n the copy as receipt- of da.-~a..~~~ ])J.e;Iso Sz).]I(:.o]'O ] v V.(:;. ]),c:ilncrs Nori ]~ ]ing-i netting 'J'IO\NS?,lJ TTAI, It 18 7 ~'~orth ,,t:l.,,,~,:, ' .... :" Post Of/ice ~r 'gO Tel;_":;'.:',-,o;~ .307 .'277 April 11, 1979 Reference: Enclosed are the following Magnetic tapes: DS 3~6 C/O NLL 4/2/79 <-" DS 3~'8 '~"~ C/O NLL 4/2/79 Both drill sites are on 'the same tape. Please sign and return the copy as receipt of data. Sincerely, /~ W~/~'/~ .. V.G. Reimers North Engineering TRANSMITTAL #152 DISTRIBUI'IOX North Geology I_~illing Eng. Manager R & D Geology ~State!Of AlaSka ~XXOI1 Mobil Getty SM~io Marathon Phillips Chevron ,,A!an ~,c;,~ic~!jleldCompany Nortl~ Arnerican Producii'{g Division North Alask 'istrict Post Olfice ',:~: × 360 Anchorage, Alaska 99510 Telephone 907 277 5637 HKVP December 28, 1978 Reference: Enclosed is the following'Pressure Survey: ]DS 3-8 12/1/78 Please sign and return the copy as receipt of Sincerely, V.G. Reimers North Engineering TRANSMITTAL #628 North Geology Drilling Eng. Manager R&D Geology State of Alaska D & M DISTRIBUT ION Exxon Sohio Mobil Marathon Phillips Chevron Getty AtlanticRich[ieldCompany North American Producing Division North Alas' '~istrict Post Office ~x 360 Anchora§e, Alaska 99510 Telephone 907 277 5637 ~'~ly 24, 1978 Reference' Enclosed are copies of the following Transient Pressure Surveys' D.S. #5-10.' 6-7-78 D.S. #5-12~ 6-9-78 Please sign and return attached copy of transmittal as receipt of data. Very truly yours, R.A. ~,o~ue North Operations Engineering Transmittal. #384 North American Pr°duc[rig Division North Alaska District Post Of'rice' (360 Anct~orage, ~aska 99510 Telephone 907 277'5637 ~¢une g7 1978 Re~erence: Enclosed are prints of. the following ~:ells: Gmnma-Ray Neutron Log . D.S. #4-9 1I Compensated Neutron D.S. #4-11 5" D.S. #4-14 5" ConVey Borehole Audio Tracer Survey - Dif£erential Temperature Log NGI ~12 5" -v ' Due to an error in reproduction, Some copies of sepias are prefolded. If this~:of any ir:convenience to you, please request another copy and it '...;ill be sent as soon as possible. If all data is acceptable to you, please sign attached copy of letter and return it as receipt of data. Very truly yours, R. A. Logue North Operations Engineering RECEIVED 9 o !978 Division of 01t & ~ ¢,sn,~srvatic, tic~ict~[ieldCompany Nor~i~ American Producing Horth Alaska 3istrict Post OUice x 3~0 Anchorago, Al~ska 99510 _- ~?~ ~k~Telephone 907 277 5837 ...- , ' . !, , ..: '.¢ ~ ' · .,. :.June 26, 1978 :, .,~. Reference' Enclosed are copies of the following cased' hole logs' Differential Temperature Log NGI D.S. #4-9 Fluid Density D.S. #3-8 D.S'. t~4-9 Collar Log D.S. D.'S. ltl-IS D.S. tfl-16 D.S. ttl-17' D.S. ~f4-13 D.S. tt4-15-- 11 Hydro Log S" D.S. tt3-8 Please sign and return copy of tra~smittal as receipt of data. R.A. I,ogu'e~ North Operations Engineering Transmittal 1~' 371 AtlanticRichfieldCompany _ · North American Producing Division North Alask 'strict Post Office b~,' 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 16, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural ReSources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' DS 3-1 (31-10-10-15) Permit No. 75-75 DS 3-2 (14-10-10-15) Permit No. 76-24 DS 3-3 (13-11-10-15) Permit No. 76-39 DS 3-4 (11-13-10-15) Permit No. 76-51 DS 3-5 (31-14-10-15) Permit No. 76-57 DS 3-6 (11-14-10-15) Permit No. 76-60 ~_~---~. 1D~S'-3-T-Z-~11-15-10-15) Permit No. 76-53 .~ 15-10-15) Permit No. 76-73 Dear Sir' Enclosed please find a Completion Report for the above-mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer /am Attachments ~' SUBMIT IN DU}~CATE* STATE OF ALASKA ~Seeother st rUCtions on reverie OIL AND GAS CONSERVATION COMMITTEE ii i iii ii WELl COMPLETION OR RECOMPLETION REPORT AND LOG* W E I,L W E I,L DR Y Other b. TYPE OP COMPLE~ON: ~:w ~],,,.~:,'""~' ~ ~.'~':~:}'- ~ ~,~'"~ ~ ~'~,.~.~ ot~ ~Pr°ducing WE[,I. o N&ME OF OPERATOR ^tlantic Richfield Company ,'~. ADDRESS OF OPERATOR P.O. Box 360; ^nchorage, fib( 4. Lo('.,.'r~).x oF w~:n~, (Report location clearly and in accordance with any State requirements)* At surfaco 11. 5. API NLFM_F_,RICAL CODE 50-029-20231 6. LF_.ASE DF-,SIGN~KTIO~ A_ND SERIAL NO. ^DL 28331 7. IF INDIA2'q, ALLOTTEE OR TRIBE NAlx, IE 8. UNIT,FAiTM OR LEASE NAME Prudhoe Bay Unit 9. WE3.~L NO. DS 3-8 (31-15-10-15) 99510 lO. Prudhoo Oil Pnnl SEC., T., R., M., (BOTTOM HOL~ 1199'N & 837'E of SW cr Sec. At top prod. Interval reported below 1369'S & 1164'W of NE cc Sec. At total dep~ 1578'S & 1438'~ of NE cr Sec. 11, TION, R15E, UM 15, TION, R15E, UM 15, TION, R15E, UM O~IVE) Sec. 15, TION, R15E, UM 12. P~P, iVIIT INTO. 76-73 16. ¢J.EVAT'IONS (DF, t~BiB, i%T, GR, ~-I'C)* 17. EI_~V. CASINGtIEAD 10-21-76 11-6-76 11-13-76 161' RKB, 28' Pad..Elev. ~ lO,.370'MD, 9359'TVD [10,255', 9262'TVD [ ~ow~=.Single ~o~= ~oo=~All CABI, B TOOLS 22. PlIODUCING !NT'EHVAL(S~, OF THIS CO.MPLETIO.N--TO,I:', BOTTOM, NAME (MD AND TVI))~ ,23, ~,VAS DIRECTIONAL Top Sadlerochit 9730'MD 8819'TVD ~ Su~WYMA~ ' ' ' ' Yes Base Sadlerochit 10,338 MD, 9332 TVD ~ 2.1. 'FYPIC I-;L,NCT[:IC AND £)TIIEtt LOGS RUN DIL/SP, BHCS/GR, FDC/CN_L/GR/Caliper., CNL/CCL/GR · i i 2~. ~'A~c;.~,~.= ! lb/ft-thd 20" [ 94#-Vetco 75' 13-3/8" 72#-Butt 2708' 9"5/8" [ 47#-Butt 10~337. ' . 26 .',:; ~ ' 2 SIZtq ~ TOP (?,ID, i3OTTOA/i(A,ID) ISACKS CEMENT* [ I I11 ~8. PI, ii{.F()RA'I, tONS OPEN TO PRODUCTION (interval, size and number) ~,9957'-9977' ~9802' 9827' CASING RECORD (Report all strings set in we~'l) H-40 t MN-80 ] MN-BO&l SM- 95 [ ! HOLE SIZEI C-~\ILNTING RECOP~,D 32"1,+350 sx PF II 17-1/2'I[5321 sx PF II "G" 12-1/4" 1000 sx Class (mt 27. TUBING SCi-~ EETq (ACD) 9478' ,:! 9909' -9944' 'j 9868'-9873' 9848' -9858' w/4 shots per ft. ii ii i 30. PI%ODUCTION DEPiVIi INA'F_2~V.~ (MD) N/A I P IIODUCTION MILI[{OD (Flay.ring, g:as lif[, pumping--size and type of pumP) Flowinq i £),¢OUNT PULLED DATE I;'I H >; ~.. dune, 1977 I_--0 /TE~T P~ILIOD 9-10-77 [ 4.1 137 85/641 ~- 11743.6 i=-aou~ 10207 31. tusrOsl'rIox or ~s ~Sold, u~ed ]or ~uel, vented, etc.) Reinjected 32.1.18TOF ATTACHMENTS i' t 5-1/2'i':' ' 9343' i i' , ACID, Si:fi)T, FiiAC2 URE, C~,IENT SQUL~Z~, ~TC. D:. ';.;(.... ~ ..... ' ,]W. nLL STATUS (Producing or ] prOducinq,, GA~i~ICF. W/fI'E~BBL. l GAS-OIL rL~TIO I1155'1 I 16.4 [ 662 I PACtfE]7t SET (MD) GAS--MCF. WATER--BBL. [ OIL GRAVITY-API (COI~I~.) ! 6762 I 96 t27o API ...... t TEST WITNESSI~D BY hereby certify that the foregoing and attached information is complete and correct as determined from all-available records /dh District Drilling Engineer DATE 2-15-78 SICNEI~ _ TITLE *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lands and leases in Alaska. item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given ~n alher spaces on this forn~ and ~n ar~y atta:~il::~e:~ls Items 20, and 22:: If this welt is completed for separate prcctucti©n fror¥~ r"~ore th~n one ~nterval zone (multiple completion), so state ~n item 20. and in ite'~ 2_'2 show thc? p~c:J~c,'~7~ interval, or ~ntervals, top(s), bottom(s) and name (s) (if any) for only the interval! reported ir~ iten~ 20~ Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the ackJitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoul:J show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interva to be separately produced. (See instruction for items 20 and 22 above). "34. SUMMAI{¥ OF' I,'(){I:LMAq'ION TT2~'I'S 1Nt'I,IJI)IN(; INq'I~.ILVAL T.~q'FED. I>}IE.~4,..SIJ~E l)AT/k ~ ~OVEI~I~ ()F OIL GAS. 35. G~GIC MARK~ WAT~ AND MUD Top Sag River 9605 8714' - Top Shublik 9644' 8747' Top Sadl erochit 9730' 8819' Base Sadlerochit !0,338' 9332' AN:D. IIE~t'Ec'q'ED ~'I'IOWS O~' OIL, GAS Oil WAT~t. n I I I I Ir I11, ,fll"li, ' I I1' ' I II I ,, , , ,, Atlantic~Ri c l¥I~;~:;,'~ C o m pa n y North American Producing Division North Alas~ istrict . Post Office L:'.'~x 350 Anchore. ge, Alaska 99510 Telephone 907 277 5637 June 23, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, A1 aska 99501 2 ENG 14 ENG J 2 GEOL; 3 G~OL D~AFT s~ CONFER: Subject:cD~'-'~"z-7~11-15-10-15)~3 Permit No. 76-53 1 15-10-15)Permit No. 76-73 Dear Sir: Enclosed please fi nd our Sundry Notice of Subsequent Report detailing the work done on each of the above-mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer /jw Enclosures Form 10-403 REV. 1-10-73 Subml t "I ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) OIL ~--~ GAS ~ WE L L L:.:I WELL g_J OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.0. Bo× 360, Anchorage, Alaska 995]0 4. LOCATION OF WELL At surface 1199'N & 837'E of SW cr Sec. 11, T10N, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 61' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS 5. APl NUMERICAL CODE 50-029-20231 6. LEASE DESIGNATION AND SERIAL NO. ADT, 28331 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. D.S. 3-8 (31-15-10-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 15, T10N, R15E, UM 12. PERMIT NO. 76-73 }ort, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING ORACIDIZlNG ABANDONMENT* (Other) (NOTE: RePort results of multiple completion on Well COmpletion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Began perf opexrations on 5/14/77. Tstd tree, csg, tbg & wireline BOPs. Pulled dummy valve. Perf'd~.~ntervals 9960'-9980', 9926'-9946', 9911'-9926', 9870'-9875', 9850'-9860', 9804'-9829' w/4 shots per ft. Ran Amerada 'press'bombs~ Flowed well 'for 1~1/2 hrs. SI ~ell. Suspended operations on 5/18/77 to await delivery of downhole safety valve. On 5/20/77 resumed operations & installed ball valve @ 2193'. Tstd balance & control lines to 5000 psi OK. Bled pressure above ball valve to 0 psi, 'held OK. Installed & tstd tree cap to 5000 psi OK. Released well to Production Department on 5/21/77. 16. I hereby certify that the foregoing Is true and correct District Drilling Engineer TITLE DATE 6/21/77 (This space for State office use) APPROVED BY. CONDITIONS OF APPROVAL, IF ANY; T IT LE DATE See Instructions On Reverse Side North Alaska District EngineerJ_ng T R A N S H I T T A L Dai;e: June 13, 1977 Well Nane: D.S. #3-8 T'ransmitt:ed herewith, are the following for the subject well: Run No. Scale Xerox Sepia BL Line BI-lC Sonic/Caliper Log BI.lC Sonic/Caliper - Gamma'Ray Log Bi IC Sonic/Gm~una tbay Log Cai. ii, er/eCL Cement Bond I,og/Vl)L Compensated Fm~ation I)ensity Log Con~pensated Neutron--Formation Density Compensated Neutron Log Core ~mlysis -Int. em~al Core No. Core Description (SIVC) - Interval Core Description (Cony.) - Core No. Directional Su~ey - Gyro Single Shot Multishot 1)'rill Stem Test - Test No. ])ual In&~ction Laterolog Formation DensJ. ty I,og Fo'rmation Density Log/Gamma Ray Gamma Ray/CCL I,aterolog Location Plat MJ. crolate~-o] og ~udlog- Interval Sample Log (A.R. Co~ - Interval Synm'getic Log TVI)-- DI L TVl)--Porosi.ty Log Fluid Densitz ! ea. I ea. r . Receip'b Acknow].edged' For- Date',/i'/ ' / ' Please ret. urn receipt to' ,~t~?tic Rich:~eld Company ~rth Ala.ska Engineering ~lanager P. O. Box 360 ~chorage, Alaska 99510 #483 STATE of ALASKA Division of Oil and Gas Cor~~~ FROM: umnie c.th Chief Petroleum Eng~ DATE , J~le 9, 1977 Petroleum Inspectnr SUBJECT: Subsurface Safety Valve and Surface Ccmtrolled Safety Tests on Arco's DS 2-8, 3~7, 3-8 ~/ and BP's F-2 .Th.ur_ sday, ~y 19, 1977 - I departed my hc~e at 7:30 A~! far a 8:00 s~wup and 9:00 AM d~parture f~r Deadhorse, arriving at 10:35 AM. ccmtacted ¥~irk White, drip. foreman, who picked me up and took to drill site #2. John Craig, Arco drilling foreman, picket me up at 3:15 PM and te~ts began at DS 2-8 at 3:30 PM. ~ SSSV was closed and shut in tubing pressure was 1425 psig. F~SV was then closed and pressure downstream bled to 200 psig and monitored far five minutes. ~he SCSV w~s then opened and pressure downstre~a of the SSSV, set at 2197', bled to zero and mc~itored far ten min~. Tests w~re oancluded at 4:0'0 PM and a field inspection report preIk3red with th~ original given to John Craig, a copy mailed to Bob }Lines, and a copy attad~d to this repart. .Friday,. May_ 20, 1977 - Tests an DS 3-7 began at 10:30 AM with John.Craig. SSSV was c~_n and shut in tubing pressure was 1525 psig. SCSV was then closed a~d pressure d~,a~stream bled to 200 psig and ~qitored far five minutes. SSSV, set at 2218', was then closed, SCSV opened and pressure downs~am of the SSSV bled to 350 psig and manitared for ten minutes. Tests w~re cancl~ at 11:00 ~4 and a field inspectian report prepared with the original given to John Craig, a copy mailed to .Bob ~Lnes, and a oopy attached to this report. _.S9_ .barday, ~hy 21,_ 1977__- ~Rsts on DS 3-8 began at 12:05 AM with L~my Butnmr, Arco drilling f~. ssSV, set at 2218', was closed with shut in tubing pressure 1425 psig. Pressure dcwnstream of the SSSV was then bled to 800 psig and monitored for ten minutes. SC~V was then closed and pressure dc~ns~~ bled to zero and mani~ed for ten minutes. Tests w~re concluded at 12:35 AM and a field inspection report prepared with th~ original given to Lanny Butner, a copy mailed to Bob Hims. s, and a copy attad~d to this report. .Sunda..y_,..May 22~ 1977~ - Nelson }k~ .~per, ~P petroleu~ engineer, picked mm ' ~ at 9:30 AM'and w~ arrived, at wellF-2 at 10-10 AM. SSSV, set at 2165' · , was orxm m~ ~tut in t~ing l~essure downstremm bled to 850 psig and mani~ for five minutes. '~ mastar valve was then close<t and presto/re DS 2-8, 3-7, 3-8 and F-2 2- June 9, 1977 downstre__m~ bled to zero and m~tored fGr five minutes. Tests were co~clu~ at 12:15 PM and a field inspection re~ prepared with the ~riginal given to Nelson }k~ and a copy attached to this report. I departed De~__!horse at 9:20 AM via Wien flight ~2020, arriving 'in Anchorage via Fairbanks at 11:25 PM and at my hcme at 11:55 PM. ~ ~ _S~~.: I witnessed success~al SSSV and S~"V tests c~ Arco's DS 2-8, 3-7-and 3-8 and SSSV and master valve tests c~ BP's F-2. - Attachment ........ Alo~, .i0~! and..Gas Conservation Commit~_ . Drlg...Perm~'~qN6'. ' '-'4.. ,' . '~. '~- ' ~m~~ ~ "' ~Wel 1/~ Sec,' T Operator ~~~- Represented by~y~~~~-Name & Number ~ ~~ Satisfactory. ~'~ Type Inspection. Satisfactory-'~? Type Inspection Yes No 'Item ( ) Location,General Yes No It6m ( ) BOPE Tests 1. Well Sign ( ) ( ) 15. "Casing set ~ () () ( ) ( ) 2. General Housekeeping ( ) ( ) ~. Reserve Pit-( )open( )filled ( ) ( ) 4. Rig ()(. ) (&,)'~Jafety Valve Tests ( ) ( ) (~ ( ) 5. Surface-No. Wells ~ ( ) ( ) (~/~ ( ) 6. Subsurface-No. Wells ! ( ) ( ) ( ) Well Test Data ( ) ( ) ( ) ( ) 7. Well Nos. , , , ( ) ( ) ( ) ( ) 8. Hrs. obser , , , ( ) ( ) ( ) ( ) 9. BS&W ,--,--,-- ( ) ( ) ( ) ( ) 10. Gr. Bbls. ( ) ( ) ( ) Final Abandonm~ent ( ) ( ) 11. P&A Marker ( ) ( ) 12. Water well-( )caPped( )plugged ( ) ( ) () ()- () () () () ( ) ( ) 16. Test fluid-( )wtr.-~--~)mud ( ) oil ( ) ( ) 17. Master Hyd. Control Sys.- psig 18. N2 btls. ,__,__, psig 1.9. Remote Controls 20. Drilling spool- "outlets 21. Kill Li.ne-( ) Check valve 22. Choke Flowline ( ) HCR valve 23. Choke Manifold No. vales fl~s' 24. Chokes-( )Remote( )Pos.(~dj: 25. Test Plug-( )Wellhd( )csg( )none 26. Annular Preventer,psi.e 27. Blind Rams., psi~ 28. Pipe Rams ~psiq 29. Kelly & Kelly-cock psig 13. Clean-up ( ) ( ) 30. Lower Kelly valve psi~ ( ) ( ) 14. Pad leveled ( ) ( ) 31 Safety Floor valves--Z-(---)-BV ( )Dart Total inspection observation time ~_~ hrs/d~j~ Total number leaks and/or equip, failures ~1~ Remarks days or when ready BP ALASKA INC. P.O. BOX 4-13?9 3111 - C - STREET ANCHORAGE, ALASKA 99503 TELEPHONE (907) 279-0644 May 16, 1977 CONFIDENTIAL State of Alaska Department of Natural Resources Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. Hoyle Hamilton, Director Gentlemen: Well Number D.S. 3-8 (31-15-10-15) Enclosed please find in triplicate, Form 10-403, Sundry Notices and Reports on Wells, for the above named well. This report contains our proposal to perforate the well. Very truly yours, BP ALASKA INC. G. D. Taylor Manager Operations Enclosures cc: Drilling Well File: D.S. 3-8 #17 C~s Forr~, 10-403 REV. 1-10-73 Submit "Intentions" in Triplicate & "Subsequent Reports'" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--~' for such proposals.) )NFIDENTIAL .. 5. APl NUMERICAL CODE 50-029-20231 6. LEASE DESIGNATION AND SERIAL NO. ADL-28331 7. IF INDIAN, ALLOTTEE OR TRIBE NAME ~' O,L ~ GAs !--I WELL~ WELU, , OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME BP Alaska Tn¢. ~udhoe 3. ADDRESSOF OPERATOR 9. WELL NO. ~.0. ~ox 4-1379, A~cho~age, Alaska 99509 D. S. 3-8 (31-15-10-15) 11, T10N, R15E, UM 4. LOCATION OF WELL At surf ace 1199' H and 837' E. of S.W. cr. Sec. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 61' RKB 28' Pad elevation Check Appropriate Box To Indicate Nature of Notice, Re 14. 10. FIELD AND POOL, OR WILDCAT Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 15, T10N, R-t-3L 12. PERMIT NO. 76-73 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all Dertlnent det&lls, and give pertinent dates, Including estimated date of starting any proposed work. The well will be perforated at 4 shots/ft, over the following intervals. 9802'-9827' ft. BKB (ref. BHCS/GR, 11'6-76) 9848'-9858' " ( " ) 9868'-9873' " ( " ) 9909 '-9944' " ( " ) 9957'-9977' " ( " ) The reservoir pressure will be measured prior to putting the well on production. A downhole safety well will be installed and closure tested. I hereby certify that the foregoing is true and correct SIGNED ~ ~)~ TITLE Manager Operations DATE May 16, 1977 (This space for State office use) CONDITIONS OF APPROVAL, IF ANY~ TITLE See Instructions On Reverse Side DATE Approved Copy Re~ume~ BP ALASKA INC. CONFIDENTIAL P.O. BOX 4-1379 3111 -C-STREET ANCHORAGE, ALASKA 99503 TELEPHONE (907) 279-0644 December 13, 1976 State of Alaska Department of Natural Resources Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. Hoyle H. Hamilton Director Gentlemen: Well DS 3-8 (31-15-10-15) Enclosed, in duplicate, is Form P-7, Completion Report, for the subject well, along with the Drilling History, Well Logs, and Directional Surveys. Very truly yours, BP ALASKA INC. P. R. Judd District Drilling Engineer PRJ: j le Enclosures cc: Well File Ms. Venita Moore !976 DiViSiON O~ Oit. ^.~t~ ~')$ Drilling History DS 3-8 (31-15-10-15) . API #50-029-20231, ADL 28331, Permi~ No.' 76-73 Spudded well @ 0200 hrs 10-21-76. Drld 17-1/2" hole to 2750'. Cond hole for csg. Ran 71 jts 13-3/8" 72# MN-80 butt csg w/shoe @ 2708', FC @ 2626'~ Cmtd w/5321 sx PF II cmt, slurry 14.8 ppg, displ w/326 bbls mud. ND BOPE & cmtd top 13-3/8" x 20" anul w/183 sx PF II cmt, slurry 15 ppg,-displ thru 1" pipe from· surface. NU wellhead &'13,3/8" BOPE. Press tstd rams & Hydril. Drld FC @ 2626', tstd csg to 1500 psi, drld cmt, shoe & 10' new form. Tst. form to 0.65 grad OK. Drld 12-1/4" hole to '2800'. PU Dyna-drill. RIH, orient & drld to 3566'. Trip & drld ahead to 4544'. Trip PU Dyna-drill. RIH, orient tool & drld to 4870'. Trip, PU BHA. RIH. Cont drlg 12-1/4" hole to 10,370'. POH. Ran DIL/SP, BHCS/GR, FDC/CNL/GR/Caliper logs. RIH and cond for csg. Chgd & press tstd 9-5/8" rams. RU & ran 268 jts 9-5/8" 47# MN-80 & SM-95 csg w/shoe @ 10'337', FOs @ 2456' & 2330'. Cmtd 9-5/8" csg w/lO00 sx Class G cmt mixed w/l% CFR-2 & 0.15% HR-7, slurry 15.8 ppg. Displ w/740 bbls mud. Bumped plug w/3000 psi. Floats held. .Installed & tstd csg pkoff to 5000 psi OK. Opened lower FO & circ 9-5/8" x 13-3/8" anul. Broke down @ 300 psi w/7 BPM. Pumped 20 bbls,2% caustic wash & cmtd w/275 sx PF "C" cmt, slurry 15.6 ppg. Displ w/26 bbls of wtr max squeeze press 1200 psi. Closed & press tstd FO to 3000 psi OK. Opened upper FO. Circ 9-5/8" x 13-3/8" anul. Pumped 326 bbls of wtr w/break thru @ 177 bbls. Pumped 277 bbls Arctic Pack w/25 bbls Geltone added last 227 bbls. Final contamination 0%. Closed & press tstd FO to 3000 psi OK. Rev out excess Arctic Pack. RIH w/8-1/2" bit & csg scraper. Drld cmt to FC @ 10,255'. POH. Ran gyro & CCL logs. RIH w/8-1/2" bit & csg scraper to 10,255'. Displ mud w/!0.2 ppg CaC1.2.wtr. LD.DP. Ran wireline gauge ring & junk bskt. Chgd & press tstd 5-1/2" pipe rams & Hydril preventer. RU & ran 292 jts 5-1/2" 17# L-80 A-B Mod LT&C tbg w/4 jts 4-1/2" 12.6# N-80 BTC tailpipe set @ 9478', Baker SAB pkr @ 9343', PBR @ 9325', ball valve landing nipple-@ 2198!. Landed tbg. Installed & tstd OCT tbg hgr to 5000 psi. OK. ND BOPE. NU & tstd xmas tree. RU & tstd Camco. lubricator. Pulled dummy valve. Dropped ball & set pkr @ 1500 psi, sheared out @ 2900 psi. Tstd · w/200 psi on tbg, 2000~psi on anul OK. Increased tbg press to 3000 psi; csg press 200 psi OK. Opened XA sleeve @ 9217'. Displ tbg w/218 bbls diesel. Closed & press tstd sliding sleeve. Ran CNL/CCL/GR & dummy gun. Ran & set dummy valve. RU for long term press tst. Released rig @ 1530 hrs 11-13-76. DIVISION OI~ 011. AND ~A~ ,, '~ SUBMIT IN STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE III I I · ,.:ther II1~ st ructions on reverse side2 WELL COMPLETION OR RECOMPLETION REPORT AND LOG* · la. TYPE 0F WELL: ()11,~[ GAS W E1. L W ELL DR ¥ Other b. TYPE OF COMPLETION: v< El,i. (IVES ~ EN BACK RESVR. Other __ 2. NAME OF OPERATOR BP Alaska, Inc. ,SI. ADDRES.q OF OPERATOR P.O. Box 4-1379, Anchorage, Alaska~ 99509 4. ],o(',,ru)x vF wxm, (Report location clearly and in accordance with a~y State requirements)* -"~'~ l199'N & 837'E of SW cc Sec ll, TION, RI5E, UM ORIGINAL -§, API NLriVLF_~CAL CODE 50-029-2023] 6, LEASE DESIGNATION A_ND SERIAL NO. ADL 28331 7. IF INDIA_N, ALLOTTEE OR TRIBE NA_M~ 8. UNIT,FA_R~/I OR LE~kSE NAI~IE Prudhoe Bay ~S 3-87(31-1 5-10-1 5) i'~:-~re:~3~o POOL. OR WI~C~T [ Prudhoe Bay-Sadlerochit m. s~.c.. T.. R.. ~.. (BOTTO~ ~0~ Pool OBJECTIVE) At t,~p prod. interval reported below 1369'S & 1164'W of NE cr Sec 15, TION, RI5E, UM Sec 15, TION, R15E At total depth '12. PEI~!IIT NO. 1578'S & 1438'W of NE cc Sec 15, T1ON, RI5E, UM [76-73 10-21-76[ 11-6-76 11-13-76 ~ 61'RKB, 28'Pad El,evatio~ F(:FAL DtqPTH, MD & TVDfg. PLUG, BACK MD & TVDr, LF 1VI]ULTIPLE CONI.PL., 21. INTERVALS DRILLED BY I-[OWI~,~NY* ROTARY TOOLS I CABLE TOOLS lO,370'MD,9359'TVD! 1,0,255',9262'TVD ~sin91e all PRODUCING !NT'~iI{VAL(SI. OF THIS CO,MPLETION--TO~, BOTTOM, NAME (MD AND TVI))* .. ,23. SVAS DIRECTIONAL , ~ SURVEY r/fADE Top Sadlerochit 9730'MD 881 9'TVD Base Sadlerochit 10,338'MD 9332'TVD -~ ~ YES 2.1. TYI'E EI-,I~7.'Ti'~IC AND C)TttER. LOGS RUN DIL/SP, BHCS/GR, FDC/CNL/GR/Caliper, CNL/CCL/GR -- I ,I Illl II I I CASING RECORD (Report all strings set in well) 94~ Vetco / H-40 'l 73' 32" }+ 350 sx PF II 72~ butt ]MN-80 ] 2708' 7-1/2"15321 sx PF II JMN'-80&[ "ILO00 sx Class G cmt ...... ISM-95 [ .... ~ 26 LINk]2 28 O~' O P~OD~C~O~ ' [h~crval ~ n0 number) CID II I I II I I ~ I IIII Illl I PI%OD UCTION DA'I i'; 1,'I~;>; P PI~UDUCTION [ PI'tODUCTION MEI [1OD ~Ph~v;h~fJ, ~.;a:5 11fi, pumping~size and type of pump~ ]V:'~LL STATUS (Producing or 20'l 13-3/8" --975/8 pi PAT£ ,~F T~-ST, ICItOI(E SIZE[ ~~OD'N FOR i~uURS q EST~ ' ~:~'] Tt flING ,CAS[NQ Pn. ESSUnE/CA1.CU~TD ] qkEz;S. [24-HOU~ ~'~. ]Uspo~:{' 0x or c*s (Sol~, Used l~r /uel, vented, etc.)" oIL--BBL. I I GAS~AICF. GA$--7~4CF. 1 32.l.ls'r OF ATTACHMENT,q Drilling History, Multishot & Gyroscopic Directional Survey. ~all Lo~ :;2. I her'vb~- c'ertifv i_tka.t~la~ fore'going and attached information 1~ cOmplete and correct as determined ~o~ all-available~ecords *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for subm,tting a complete and correc~ v,,,ell completion report end log or~ all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise showr~) for depth measure- merits given in cther spaces on this form and in any atta.--h?,~er-~ts. Items 20, and 22:: If this well is completed for separate prcduction from more than one interval zone (multiple completion), so state ~n item 20, and in ite,'~ ?2 show the p~cd~Jci~0 ir~tcrval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interv,~! ret)orled ir~ iter~ 30. Subr'n,~ a separate report (page) on this form, adequately identified, for each additior~al ir~te~val to be separately produced, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoutJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMAII. Y (')V I"OH. MATION TE,S'I'".'-; IN('L,UI)IN(; IN'I'T~I,LVAL. TF~$'FED, t.'HE,.'C.$UHE DATA A.N'D ,P,.ECOVERIF~ OF ()IL. GAS, 35 G ]~OI-,OG I C M ARKI~R~ WAT~r'L AND MUD NAMg Top Sa~ R-iver 9605' 8714' Top Shubl~k 9644' 8747' Top Sadleroch~ Base Sadleroch~t 10,338' 9332' ."ICl. CC)lIE DATA. A'I'I'AcI! tlTIIEIe DI~CRIPI"VION'?, OF' LITiIOLOG¥. POROSITY, FIIAC"VUI~ES, AND DETEC'TEI) SIIOWS Ole (.)IL, GAS .... ,, , .... SPERRY. SUN DIRECTIONAL SURVEY REPORT FOR ATIJ~ NTIC RICIt~'it']IJ) COMFA?.iY 0EC 1.. ~ !976 DIVISION OF OIL AND GAS TYPE OF SURVEY: Gyroscopic Multishot SURVEY DEPTH: FROM ,Surface ~a~: l)rill Site #~ , FIELD: , Prudhoe Bay COUNTY/PARISH, North Slope DATE OF SURVEYNOVember 11; 1976 ~OB OFEICE' AnchoraFe; Alsska FT. TO 10: 37Q , WELL NO. 8 STATE /t 1 a s ka 27l,-6696 ATLANTIC RICF!FIELD DS PRUDI-iOE RAY ALASKA SP_ EP~RY_tS UN__WELL_~URVEYI NG. COMPANY_- MEASURED DEPT~{ ANCHORAGE, ALASKA COMPANY ........... CP~iRU TA.TI ON .DA TE ,,, NOVED~BER 15, 1976 TRUE .' SUB-SEA COURSE COURSE DOG-LEG VERTICAL ......... _V_E.R_.TICAL ...................... INCLINATION DIRECT.IOr; .SEVERITY REC DEPTH DEPTH DEG f,iIN DEGREES DE$/100 NOR O lOG 290 3OO 400 5OO 6O0 o.oo , -61.-,.¢o ........... ~ ..... 0 ............ r? ..... o._.o .... ~ ....... ........ 9's,"~ 3a.e~ o lO 199.99 158.99 0 4 S 45.75 E 299.9~ 258.99 0 10 S 68 80 E . . ...... 399,99 338,99 O 16. S 7.,98 E ~95.99 ~58,99 0 27 S 75,69 E 599.98 558.98 0 56 S 7 o o .......... g~ 800 799.96 900 899.96 1000 ................. 999.96 1200 1300 1400 1500 1600 1700 1800 1900 ...... 189~.89 2000 .1999.88 638o9~ 0 52 S 76,2~ E 758.96 0 28 S 61,8q E 838.96 0 28 S ~1,19 E 938.96 O 31 S ~9,61 E · 1099.95 10~8.95 0 ~8 S ~5.9~ E 1199.94 1138.9q 0 ~3 . S 57.88 E ......... 1'299':~-~----~'~'; ~ .............. ~ ..... ~ ............ ~'i"a'i" ...... 8'--'[ .......... 1399.93 1338.9~ 0 ~6 N 87,75 E ..... 15~s.9~ 15~8.~1 o 52 r,~ 82.90 c 1699.90 i6~8.90 0 ~8 N 77.3~ E 179~:8~ ......... ?_~.8~.8_9 .................. o ..... 15 ................ ~ 8~. 57 _E 1838.89 0 16 N 67,58 E 1938.88 1 q'. DJ 67.8~ E 2100 209~.'82 2038.82 2 ~+ N 5~, 1 E 2230 ........ 2199,G-9 ....... 2i'~'~-~--~S .................... 2 ....... 57 .......... ~"-'5~,97]E 2500 2299.57 2238,57 2 ~5 N 5~.~2 'E 2~oo 2 s 9 ~ ,...~...8 ...... e.~ ~.8_, .~.8 ................. e_ ........... ~ .............. ~ __.58.83.. E ...... 2500 ........... 2~9~.~3 2~8.~5 i 32 N 60,71 E 2600 2599.~0 2700 2699.38 2800 ...... 2799.36 2900 2899.25 3000 2998,92 0.00 0,16 0,23 0,10. 0,10 0,18 0.48 0.07 0.~3 0.16 0.05 0,12 0.18 0,30 0,14 0.0~ . 0.08 0.10. 0,58 0.08 0,80 1.72 0.22 0,20 0.67 0.56 0,~2 0.57 , . 1.74 3,27 2.85 ') RAG g__l DATE OF SURVEY NOVEMBER 10, 197~ SURWEL GYROSCORIC.~LTIS~OT_ SUpVE JOB NUMBE2 SU3-161~3 KELLY BUSHING ELEV, = 61.~ :T. CONTROL PCIN!__WELL NO, .1 ...... TOTAL TADiGULAR COORDINATES ....... VERTICAL TH/SOUTH EAST/WEST SECTIOi,J 818.00 817.89 817.82 817.91 816.02 818.18 81R,50 818.90 819.27 819.77 .. 820.,2 821.17 S _175..00._E ............... ¢25.~2 S 17~.90 E 625.57 s 17~.85 E ~2~.~ S _ !7~..02.E ............ 6~ S 175.38 E 625.25 S 175.99 E 625.09 S ................ 1.~_o_!5..E ................624.79 S 178.67 E 62~.59 S 179,77 E 62~.17 S ....... I~Q,_~.9....E ................... 62~.~0 S 180,95 E 62~.59 S 181.62 £ .628.9i 821.9 o _s ......... ...z..a..2 ._~.5 ..... E ................... 6.2 5 ..1 o 822,55 .S 185,72 E 62~.89 822.~1 822.32 822.17 821.92 821,75 821.6~ 821.20 819.~1 .. 816.47 81~,56 811,21 809.61 808,66 808.36 807.28 80~,86 80~,17 S 185,05 E 62~.30 S. 1.8.6...~0 E .......... 62~.56 S 187.8~ £ 622.72 S 189,27 E 62~.80 S 19O.!3._E ...... 621.22 . 6'~ 93 S 190 5~ E s t~1.61E 6 ~.01 s . 194._38.__E .................. 6.17.1o S 198.37 E 612.57 S 202,40 E 608.05 S 20.5,92__E .................... 6.0~'27 S 208.65 E 601.53 S 210.90 E 599.60 S .............. 2.12...6.5.....E___' ........... ~.~9~..~7 S 212.90 E 597.~1 S 209.21E 597.12 S ........201,.21....~ ............... ~O0,~7 CONFIDENTIAL ATLANTIC RICHFIELD COMPANY DS PRUDHOE ALASKA -__S..U.N.___W E L L~I~U R V E Y I N G C 0 M P A N Y ....., ANCHORAGE, ALASKA COF!PUTATION DATE N0'~Ei'IBER' i5" ' 1976 DATE OF SURVEY NOVEMBER 10, 197.6 _.SURWEL GYRoScoP_IC_M_PLT! SHQ_~___S.__URVE ,JOB NUMBER SU5-1615~ KELLY BUSHING ELEV. = 61.00 FT CONTROL POINT WELL NO. i MEASUEED DEPTH . TRUE .' SUB-SEA COURSE COURSE DOG-LEG VERTIC'AL VERTICAL INCLINATION DIRECTION SEVERITY DEPT~--~ .... . DE~-~'H .......... DEG' MIN DEGREES DEG/IO0 RECTAr,' NORTh/ 51oc ~osa..~_, 5o57.~G 6 ~1 s ss.6? w 3200 ...... 3197.5~ $Y~-6"-~'~ ......... 9 ..... 2'6 ....c $-'53.-6~ ..... W 2.61 .s~oo ~2~D.~o ~25~.6o 11 55 s 5~.2~ w 2.65 3~00 3393,15 53~2.15 15 27 S 55.19 W 2.02 ~500 ...... ~90,'~'~ ~42~,-S~-- ...... 13 ....... 581 ........ -S-57.69-U .... ~.69 ~60~ ~D~?.oo ~526.00 1D ~ s 29.31 ~ 2.76 570o ~6B~.~1 ~62~.11 1G 22 s 51.BQ W 0 . 58o0 .......... ~7'ia.82 5V-i9',82 ~900 ~7~.~1 ~12.91 ~000 ~968,0'7 ~907.07 ' -4100 ............. ~d'~'l'.2o ~ooo.2o 4200 ~15~.26 ~092.26 ~500 ~2~.25 ~18~.25 4400 ........ 4~'~"98 ~272.98 4500 %422.16 4561.16 ~6oo ~5o9.o9 4,,~.o9 17 18 S S0.~6 W 18 ~5 S 51.98 W 1 20 ~5 S 55.85 W 2 2~ .......... ~ .......... S ~6'~ ..... g'-"~ ............ 1 25 50 S'~1,12 W 2 25 lO s ~.25 w 1 27 .... i'0 ........... ~'-'~"~-~'""~ .................... 2 29 .5 S ~8,$~ W 2 50 10 S ~5.65 W 1 ~8C0 4651.~5 ~900 ~769.02 ~708.02 28 55 S 5 o o o ........ ~ 5 G i. ~ ~ ...... ~-?-~5'7~ ............... ~-~ ...... ~ 1 ............ ~'-'-2 ~, ~'6 --~ ..... 5~00 .~9~3.22 ~82'o22 29 ~7 S ~0o93 ~ 5200 502'9.85 ~968.85 ~0 9 S 31. 7 W 5 ~ 0 o ........ 5 ~16,-i~---~'5~7¥~ .............. ~"~ ..... ~-7 .............. ~'-'--29 · ~S'--'~.~ ..... 5~00' 5202.30' 52~1.30 ~0 ~0. s ~1. 5 'w . .5500 ........... ~288o27 5227.27 $0 ~7 S 52.~ W ~620.~5 28 55 S 58,25 W 5 5 0 0 0 0 0 5600 557,.0~ 5~25.08 ~1 0 ............. ~--~-'"~-~ ..... w ........... o 5700 5~59o76 5598,76 51 5 S 31.81 W '1 5800 55~5.25 5~8~.25 ~1 25 . s ~.57 w o 5~oo .......... ~'g'~'O'";'¥f ..... ~6-~--;~-~ ....... ~'~ ....... ~'~ ........... ~---~,--~'~ .... ~---' ............ o 60oo 5725.~ 5~5~.~ 52 5 s s~.~5 ~ c ~100 ........... 5~.O_q,_~. ~7_.~X~_O_O ............ ~.~ ...... Z~ .......... ~...~_,.~_~._...~ ................ 0 808. 816. 826, 839, 855, 877, 95 900. O1 925. 52 952, 21 979. .77 "100-9, .07 1039, .85 1069. .22 ...... 11Oo. .11 1132. .71 1166. ,07 1202. ,25 1241. ,85 1280. ,75 1523. .77 1~66. ,37 lq08, .68 "1~52. .6~ 1~96. ,71 .... 1539, ,7% 1582, .0~ 1625. ,97 1669, · ~0 1757. · ~0 1801, TOTAL GULAR COOP_,DI.NATES ...... VERTICAL SOUTH EAST/WEST SECTION 37 S 191.67 E 608.82 78 S 180.2q E 621.77 9~ s 16~.75 E 638.25 19 S .1~6,56_E ............. ~' .87 07 s 115.a6 E 705.97 85 S ~01.~0 E 753.59 6~ S ........... ~-g~'~'-~ .............. 7'~2,5~ 09 S 70.78 E 795.~6 95 S 51.99 E 826.96 ois .............. ~d~-i"6 ........ ~ ............... 86~.0~ 06 S' 5.20 52 S 22.91 ~ 9~1.52 ~85 ............... S~"~-~'-"-'~ ................ oas ......... 225~.~2__.~ ............. ...lO.76.~2 89 S 160,66 W 1125.77 13 S 19~.22 R 1175.09 98 S 220.~8 ~ 1225o~5 28' S .... 2~q,69 ~ 127~ ,9~ O~ S 269o57 W 1~_.~0 8'5 S 295.,29 W ............. 1371.33 34 S 320.87 W 1~21.77 16 S ~6.65 W 1~72'61 59 s ~Ol.58 ~ 1574.8~ 92 S ~29,52 W 1626.~7 58.S .............g.5.Z,~_~__W ............... !678,16 12 s ~86.55 ~ 17~0.~5 06 S 515,86 W 1783.03 275 ....... · ...... D~...~.d~. ............... ]. ® 0 ATLAETIC RICHFIELD DS PRUBHOE_6.~.~, ALASKA .. COMPANY MEASURED DEPTH ANCHORAGE, ALASKA 60~PUTATION DATE NOVEMBER 15, 1976 DOG-LEG SEVERITY . . DEG/IO0 TRUE .' SUB-SEA COURSE COURSE VERT I C 4.L_ ....... _V~R__T. iC AL. _.INCL!D!_ATION DIRECTION DEPTH DEPTH DEG MI'~'~ ......... DEGREES 6200 5884.49 ~,~oo 6400 6~00 6157.28 6600 ...... --6221.26 6700 ~505.09 6800 6588.74 .... 6900 6~72.2~ 5907.89 52 52 S 55.40 W 0 7000 6555,57 7100 6658.59 7200 6720.85 75O0 6805.24 7~00 6885.~8 750'0 ........ 7~ DUO 70~9.75 5992.13 32 qO S ~0.59 6076.28 ~2 45 S ~2.88 6160.26 55 0 S ~4.55 6244.09 53 5 S 5%.22 6527.74 35 22 S 52.19 6~11,23 53 2'6 S'""~'~-~'-~ 6494.57 ~5 59 S ~0.26 6577.~9 ~, 52 S 51.~8 6659.85 ~4 2¢ ---~-'$f','-7'?-'"-~ 6742.24 5~ 36 S '32. 7 68£~.48 54 ~5 S 52.55 6906.61 3~ 58 .... S ..... 3i"'"96"~ 6988.75 3~ ~2 S 52.65 7700 7131.97 7070.97 ~ 42 S ~3.25 W 0 7880 ................ ?"21'~',"3~ ....... 7~-~,-~g ................. 3~ .....2~ .......... S '$$.~5 W ..... 0 7~00 7297.08 7236.08 3~ 1 S 33.75 W 0 8000 7579.98 7518.98 56 0 S 54.47 W 0 8200 75~5.19 748~.19 ~ 41 S ~6.8~ W 0 8500 8400 8500 7790.77 7729.77 8600 7872.58 7811,58 8800 8035,48 797q.48 89oo 8116.5o 8o55.5o 9o'o0 ........... ~i~7.55 8156.55 9100 8278.81 8217.81. 7627.25 7566.25 ~5 % S 37.85 W 0 55 6 s 5~.77.'w 0 ~5 7 s 41.z~ w 0 35 57 S ~3o13 ~ 0 35 50 S 43,90 W 0 35 55 S 45° 3 W 0 35 20 S 45,87 ~ 0 9200 ......... _8._.~6__~.,.Z_~__' 8299.7~ 54 ~a s .~.6...4~ ~ ............... 0 '}____EA GE _~. DATE OF SURVEY NOVEMBER 10, 197A SURWEL G YR 0 SCO~ I~ __.~.UL TI~O~_~U~ VE JOB NUMBER SU5-16133 KELLY BUSHING ELEV. = 61.00 ~To CONTROL POIN~_WELL__~Q, 1 TOTAL RECTANGULAR COORDINATES VERTICAL NORTH/SOUTH EAST/NEST SECTION .SA 1845. .85 1889. .51 1955, .2~ 1981. .83 2026. .10 2071. · 1~ 2117. .65 216~. ,46 2211. .11 2259,92 .21 2308.11 .26 255.6.18 .21 2~04.32 . .~ · 22 2~52.62 · ~0 2500.81 .S~ 254~8.58 .56 2595.95 .37 2642.73 .~0 2689.04 .71 2734.97 .79 2780.61 .66 .... 2826.04 .71 2871.11 .45 2915.63 ,81 2959,~8 ,7~ 30'02,~2 ,72 30~5,23 ,~& 3087,75 .66 ..... 5129.57 ,76 3170.4~ .77 . 3210.15 29 S ..... 575.98_W ........ 1889.45 67 S 606,11 W 19~2.89 55 S 63~,65 W 199~.70 30 S 663_.._07_ W ............ 20( .69 50 S 69~.12 W 2104.8~ 55 S 725.85 W 2159.17 39 S ........ Z53._8_3_~ 2213.8.4 27 S 782.67 W 2268.85 81S 8~0.85 W 252~.09 S ~39.5%..U .................. 2380.12 S 869,26 W 2~56.68 S 899.21 ~ 2~5.27 S 959.91W 2807.10 S 990.59 w 2664.05 S 10.21.~6 W 2720.88 S 1052.51 W 2777.45 S 1083.59 ~ 2855.47 29~ . 7 S 11~7.19 W 6 s ileo.~5 w 30 _.29 .s .... i215_,~2__w ........ ~o57,9o s 125~.o'~ ~ 5ii4.75 S 1287,65 W 5171.51 S 1563.~3 W 328~.57 s 1~o5.oo ~ ~5~1.15 S .......... 1.~.~_.~ ............ 3398.02 S 1~8,.4i W s 1525.92 ~ 55io.~G ATLANTIC RICHFIELD COMPANY DS PRUDHOE '~ A ~'- ................ .,, A L A S K A TRUE .' $?E.R_~..Y._-_SUf'J WEL URVFYIt,AG.. COFiPANY ANCHORAGE, ALASKA COMPUTATION DAlE NOVEMBER 15, 1976 SUB-SEA COURSE COURSE DOG-LEG TOTAL DATE OF SURVEY NOVEMBER i0, SU~EL K~LL¥ ~USHI~G ~LEV. = ~1.00 CONTROL POINT ~E~L ~0. i MEASURED VERTICAL DEPTh r..,EpTH ............ -DE~TR ...... ; BEG-' ~.IN ........ DEGREES... DEG/IO0 NORTH/SOUTH VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COOnDINATES EAST/WEST 9300 .... 8~5.25 , 8582,2_5 .......... ~ ..10 ........ S ~7.68 .... ~ ...... 0.BM _$2Na. G~ S 9400 8526.17 8q65.17 55 ~8 S qB.16 W 0.~5 ~28&.iO S 9500 8609.q6 85qB.q6 53 2q S qB.8O W 0.55 5322.78 S 9600 8693.06 8632.06 35 10 S 50. 8 W 0.7~ 5558.qG S 9700 ~' '8776.89 ............ 871-5.89 ........ 32 .... 55; ......... S 50.35"W ' · 0,28 5595.36 S ~8C0 8860.75 8799.75 55 5 S ~9.S9 W 0.2~ $~t28.25 S 9900 89~.g8 888~.68 52 N7 S 50. 5 W 0.30 5~6~.18 S VERTICAL SECTION 1,6o8._.62 w ...... ~619. q.'7 ioooo .......... 90~;'~' :~9-g~;'~'5 ...... ~2 .... ~? ......... S ~"g'~-~ ......... 0.20 's,~98.o9 s loioo ~i12.6i 9o5i.6i 33 i5 S 50.60 W 0.6~ 3553.01 S 10200 9196.29 9155.29 55 8 S 50.72 ~ O.1M 5567,71S 10500 ...... 92791~"9~-- .... 9~'i'8~-9'8 ............. 3~ ........ i~ ............. S'i'~9.'Cg---~ .......... ' 0.58 3602.75 S~ 2026.20 W ~133.~2 10570 9~58.5~ 9277.5~ ~5 1~ S ~9.66 ~ 0.00 5627.58 S 2055.~4 ~ ~169.~ 1650.1! W 5672.51 1691.5~ W 5724.85 17ss.2s ~ ~ .~5 1775.12 W 3827.~6 1816,9~ W 5878.~ 18~8.60 W 5929.56 1899,99 W ~980.1N 19g1.82 W gO~l.l~ 198~,16 W ~082.20 HORiZONTA~'-"~'i~-P-~-~-~E-R-E-~--~---~'~-~'9'~"6-'~- .... -FEET .... ~'T ...... ~b-UYH'; 2'9 DEG. 32 MIN' WEST ~T ~0 = 10570 THE CALCULATION PROCEDURES ARE'BASED ON THE USE OF THREE DIMENSIONAL RAOIUS OF ClJRVATLJRE METHOD. CQN. F !DENTIAL, ATLANTIC RICHFIELD COMPANY DS ~-8 PRUDHOE ~AY .,, ALASKA ..~ ALASKA S8£.REY_%$U~_~ELL~J~UBVEYING ANCHORAGE, ALASKA · £OF:PUTATION DATE NOVEF"BER 15, 1976 COMPANY_ DATE OF. SURVEY NOVEMBER SURWEL GYROSC~PIC___~.~L.~ISHO~_~URVE dOB NUMBER SU~-16~$ KELLY 8USHIDJG ELEV, = 61,00 FT, CONTROL POIN!_.WELL__~Q..._I KELLY BUSHI~,IG ELEV, : ................. i~E'F( p--~-i_--~-T--E'~) .... -V--A-I~-t~ E',S'- F 0 ~"-~'~ E ~.~ 1006 .... F E E T KEASUFED DEPTH TRUE :' SUB,_SEA ............................ _TOTAL 'vERTICAL VERTICAL RECTAt',IGULAR Co0-R~'NATEs DEPTH DEPTH NORTH/SOUTH EAST/WEST 0 ........... 0'¥0'6 ........ ----~'~-.-~ d ................ 8-~8'. ~ 0'--~ ............. i-75'-0-0 E ~ooo ~9~.9G 9~8.96 82o.~2 s 28o.s5 E 2000 1999.88 1938.88 621.20 S 191.61 E ~ o o o ......... 2 9 ~8"; e~ .....~"':~ ~-- ......... ~ 0'~"'~ ~-"S ................... :21--'E ~000 ~968.07 ~907.07 979,95 S 51.99 E 5000 ~856.~2 ~795,52 1~25,28 S 7000 6555,57 6,9~.57 2211.81 S 8000 757~.98 7518.98 2689~0~ S 111~.95 900'0 ............ ~'1-~7,55.--81~6.55 ~129.57 S 10000 9028.75 6967.75 3~98,09 S 1899,99 W 1 O 570 ........... 9.~.~,,_~ ......... '_~1Z_.~.5-3~ ................ 5.~.27 · 58_..~ ............ w THE CALCULATION PROCEDURES ARE BASED OFi THE USE OF THREE OF MEASURED DEPTH MD-TVD DIFFERENCE 0°03 O,11 · 1,07 31.~2 1~3.67 284.6~ 620.0~ 802.~6 971.2~ 1031.~6 vERTicA-L- .................................... CORRECTIODt 0.03 0,07 0,96 30.8~' 111.75 140.93 159. 175. 182, 168. GO. ~5 77 .9_2 DIPiENSIONAL RADIUS OF C!iRVATURE EETHOD. I <) ATLANTIC RICHFIELD COMPANY DS ~'-8 ALASKA SPERRI- SUN _WEL_L. _~U._R.VEY I NG ..COM. PA.NY_ ANCHORAGE, ALASKA DATE OF SURVEY NOVEMBER 10, 1976 C 0 Fj_P.U~ A!!_O N ._D ~ TE ........... SURWEL G Y R 0 S C. Q.~P IC___~_.U L_T_!_S.'_H_ O_T___ S. UR V.E NOVEMBER 15, 1976 dOB NUMBER SU3-16133 KELLY BUSHING ELEV, : 61,00 FT, CONTROL POI?"T WELL NO, 1 VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH INTERPOLATED MEASUREO [EPTH .... T R. 0-~' ....... -~-(J-~-~-S'E ~ ......................................................... TOTAL VERTICAL VERTICAL RECTAt, JGULAR COORDTNATES DEPTH , DEPTH NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL . CORRECTION 0 0.00 61 61.00 16i 16i. 00 262 261.00 56i 36i.00 ~61' ~61,00-- 561 561.00 661 661,00 -61.00 818,00 S 175.00 E · O,OO 817,97 S 17~,97 E 200.00 817.87 S 17~.92 E 300,00 817.97 S 175.21E ~00.00 8~'.~-0--"~ ................. 1~'5,'69'E 500.00 818,32 S 176,5~ E 600,00 8!8,76 S 178;10 E 761 761.00 661 861.00 961 961.00 "1061 ............... i061',00 1161 1161.00 1261 1261.90 1~61 .... 1 1~61 1 1661 1761 700.00 819.12 S 179,~9 E 800.00 819.5~ S 180.18 E 900.00 820.15 S 180.72 E. ~000.00 820;'-86-~ .............. 1100.00 821',6~ S 182.12 E 1200.00 822.25 S 18~,21E 36'1'"-'~-~) ........... i-3[J6';-~--0 ..................... 8'22 .'~3 "S ........... 18q, 5~ E q61.00 1~00.00 822.37 S 185.87 E 15~1,00 1500.00 822.2~ S 187.25 E 1661 ,-00 ...... 16-0--b '-0 O ................ '-'-822.0 ~ S ............. 188.7 ~ E ,iv6i.oc i700.-00 82i,77 s 189.99 E 0.00 0.00 0 0.00 0 0,00 0 0,00 0 0,00 0 0.00 0,01 0.03 0.03 0.03 0.04 0,04 0.05 0.06 0,07 0.06 0,09 O.lO .00 ,00 0,00' 0,01 0.01 0.00 · 0.00 0.00 0.00 0.00 0,00 0.00 0,00 0,01 { 0,00 ATLANTIC RICHFIELD COP~PANY DS ~'-8 PRUDttOE ~AY ALASKA S P ER HY_~_S UI't._W EL L URVEY.ING_ COMPANY ANCHORAGE, ALASKA ¢ o?_LP__U T A_T I ON.. O ATE NOVEMBER 15, 1976 'r)__PAGE :_3 DATE OF SLIRVEY NOVEMBER 10, 1976 .... SURWEL GYROSCOPIC_.._MULTISHOT_SURVE JOB NUMEER SU3-16133 KELLY BUSHING ELEV, = 61,00 .. . CONTROL POINT_.WELL_NO,__.i INTERPOLATED VALUES FOR EVEDi 100 FEET OF SUB-SEA DEPTH MEASU DEPTH RED 1861 1961 2061 2161 2261 2q61 2561 266I' 2761 2861 2961 3062 326~ 33~6 3~ 3573 VERTICAL VERTICAL R£CTANGULAR COORDINATE O.E P. T.H_ ..... _, ....... p E _P_T~_ ........ NOF~TH/_SOUTD ..... EAST/WES 156~.oo laoo.oo 196~.oo 1~oo.oo 2o61.o0 ........... 2'o00.0'6 ............... 2161.00 2100.00 2261.00 2200.00 ....... ~361.oo 2~oo.oo 2~61,00 2qO0,O0 821.71 S 190.37 E 821.~7 S 190.9q E 820.53 S 192.90 E 817.6~ S 196.75 E 8!~._.6~ S ................ 2..00.,89...E 811.9~ S 20~.71 E 810,11 S 207,75 E ...... 2561.00 2500.00 808.89 S 210~07 E 2661.00 2600.00 808.37 S 212.14 2761.00 27O0.00 80a.10 s 2i3.22 2,561.00 2600.00 805.85 S 211.29 ....... 29~ i',-d-~,- ............ -2'~'d'-d--;'-d'6- ................. adz .97'-'-S .... : .............. z 0 4.60" 3o6i.oo 3ooo.oo ~o6.13 s 3!61.00 3100.00 813.38 S ' 3261.00 ............... ~20'O-,-d~ .................. 82~.26S ....... ~sGl.oo ~3oo.oo ~s~.58 $ ~l..on 3~oo.oo ~5o.2o s 3561.00 3500.00 870.88 S 3661,00 3600,00 895.33 S 195.28 18~.86 170.72 152.72 13~.52 119.50 105.22 S MD-TVD T DIFFERENCE VERTI CORREC 0.10 0.10 0.13 0.25 0,38 0,~9 0.55 0.58 0.61 0.62 0.67 0.92 1,39. 2.20 3.69 5,95 8,78 12.01 15,95 CAL , TION 0.00 OeO0 ._i~ .................. ~:i: . 0,02 0,11 0,1.3 ........................................ 0,10 0.06, 0.02 0.01 · 0,05 0,25 0.~6 0,81 1.~8 2.26 2.8~ ~,2~ 3,93 '3 ATLAF!TIC RICHFIELD COMPANY DS ~-8 PRUDHOE P"ZY ,, ALASKA ............ $ P E ~_R._Y_-~.b_'..D{_~_E L S U_.R_ V E_Y I NG..C 0 MPA N.y_ ........................... EA G E L_~8 ANCHORAGE, ALASKA COMPUTATION DATE NOVE~SER 15, 1976 DATE OF SURVEY NOVEMBER 10, 19-76 SURWEL GYROSCOPIC MULTISHOT SUAVE JOB NUMBER SU3-16133 KELLY BUgHIN6 ELEV. = 61.00 FT, CONTROL POINT WELL NO. 1 'INTERPOLATED VALUES FOR EVEN 100 FEET OF SUBiSEA DEPTH P~EASURED DEPTH - TR-i]F_'- ...... .---§U~-2 ~'~X- ............................................................. TOTAL VERTIC&L VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL · CORRECTION , J ,© 5781 3886 3992 4099 4208 4318 5761.00 3700.00 920.85 S 89.64 E. 5861.00 3AO0.O0 9~8.~7 S 75.10 E .... $gGZ;-O0 .......... ~gdO-.'O~ .................. 977.80 S 55'.5~ E ~o61.oo ~ooo.oo zoo8.95 s ~o.z:~ E 4161.00 ~100.00 10~1.64 S 2.95 E ~361.00 ~300.00 1110.03 S 64'.~ W 4461.00 ~400.00 1146.79 S 105~.1~ W 4776 ~661.00 q'60,O.O0 1232.21 S 186.04 W 4890 5005 5120 5236 5351 5~66 558~ 476i.00 ~+700.00 1277.19 S 218.10 W ~961.00 ~900.00 157~.76 S 27~,80 W 5o6z.oo 5ooo.oo t~2~.~4 s 5o~.6~ w 51Gl',-O'O .... 51"6'~"~-~"~ ............... :-1~75"17 S 3~.05 w 5261.00 5200.00 1525.90 S 56~.80 W 5~61.oo' 55oo.~o, 1576.o6 s ~7.2o w W 5818 55&1.00 5500.00 1677.59 S 462.86 20.32 25.36 38.77 57.50 69.36 83.45 99.17 115.56 129,85 14~,~7 159.47 175,01 190.98 207.25 223.75 2~0.~4 257.~ 4.37 5~03 ............................. :: 6.07 7,33 8,68 10,04 11,85. 14,09 15.71 16,59 · 14,26 1~.54 15.10 15,5_3 15.97 i6.27 16.~7 16.70 17.00 CONF DENTI^L. t;, j ATLANTIC RICHFIELD COMPANY DS 3-B PRUDHO-E---R-A~, ............ ~. ,, ALASKA INTERPOLATED SP.. E .R- R ~_%S'U. N__~,~£ LI,I_IJ .R V.E Y 1 N6 ..~c oP!P A NY ANCHORAGE, ALASKA C O.~! P_U T__~..T I_O!.,l_.. DA NOVEMBER 15, 1976 F:,EASURED VERTICAL VERTICAL DEPTH DEPTH , DEPTH VALUES FOR EVEN 100 FEET OF RECTANGULAR COORDINATETS NOR T~/S~_U_.T_? .... EAST/WE S T -A~E .... 9 DATE OF SI.!RVEY NOVEMBER 10, 197~ SURWEL GYROSC. ORIq.~ULTI.S~OT_SURVE UOR NUMBER SU3-16133 KELLY BUSHING ELEV. = 61.00 KT, CONTROL POIN.T__WELL_NQ, 1 SUB-SEA DEPTH ND-TVD DIFFERENCE VERTICAL CORRECTION 5935 566 6053 576 6172 586 6290 596 6~09 606 6528 616 6647 626 676b 636 6886 6~6 7006 656 1.00 5600.00 1'728.78 S ~97.03 W 1.oc 57oo.oo 178o.88 s 5~1.75 u 1.co 5~oo.oo z~65.~7 s 6o~.~q w 1.00 6000.00 1939.69 S 637.21 W 1.00 6100.00 1994,11S 671,35 W 1,00 6200.00 2I]q7,81S 707.68 W i.oo 6~oo.-oo 21o~.p&_~ ................... 7.~.~..;i.o._w 1.00 6~00.00 2157.92 S 778.85 W i. O0 6500.00 22i~.95 S 6i2.6~ W 7127 6661.00 6600.00 227~o19 S 8~7.71W 7570 6861.00 6800.00 2389.97 S 920.q5 W 7~91 6961.00 6900.00 2~8.72 S 957.~8 W 7755 7161.00 7100.00 2565.~9 S zo~2.58 w 7856 7261.n0 7200.00 2622.~7 S 1070.06 U 8097 7461.00 7~00.00 27~8.00 S 11~6,~e ~ 274.87 292.85 311.18 329.63 3~8.33 367.20 586,38 17,42 17.9~ ............................ 18,32' 18.45 18.Z0 ................................... 18.86 19,17 ~05.77 1 ~25,5~ 1 ~5.51 1 ~66.~ ~87.68 509.19 530,9~ 552.67 57~.30 595.~5 616.10 636.87 9.39 9,76 9.96 20,93. 21.2~ 21.50 21.7~ 21.72 21.63 21.15 20,g4 20.77 CONFIDENTIAL -] .S.F_' EBB Y__-__.S..U}L W__E.L ~,_.~ U R~ E _'(.I N G__ C O.M P A ~')Y ANCHORAGE, ALASKA ATLANTIC RICHFIELD COMPANY DS ~-8 COF~PUTATION PRUDHOE ~'A"~ ............ .,, ' .................... NO~'EPBER' -~5, ALASK4 DATE is7~ DATE OF SURVEY NOVEMBER 10, 19%6 SURWEL GYRosc OP IC_MU.L_TI SIlO T_~UR YE dOB NUMBER SU5-16155 KELLY BUSHING ELEV, : 61,00 _. COHTROL POINT .... WELL__NO,_.i INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH , J DEPTH ....' TRU~ ............ ~J ~' :S~-A- ....................................... TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES OEPTH. ~_ ...... _D. EP_TH NoR. T..H/SOUT.H ...... EA_S!/.WEST ~D-TVD OIFFERENCE VERTICAL , CORRECTION .D 821.9 6585 8708 883£ 895~ 9078 ~200 9521 5~1 956i 9681 9800 9919 1003~ 10157 1O277 10~70 756i.00 7500.00 2759.37 .S 7G61...00 ......... 7.~00,_~0 ............... 284.4.71S 77G1.00 7700.00 2.899.5'5 $ 7S~1o00 7800.00 295~.25 $ 796!..~.q~ .......... 7_~.~z~ .............. 30.05,96._.6 ....... ..... 8061,00 8000,00 $058,7~ S 8161.00 8100,00 82G1.00 8200.00 .... ~6i,'0-'~ ........ '-'~'~Oo. oo ~6i. On e~O0.O0 8561.00 8500.00 5110.85 ~161.6q, ~'210 .'27 5256.7~ 5~01.6~+ 1187.21 1229.8~ 127~,26 1~1~.62 1566.66 1~15.65 S 1~65,72 S 1516~86 S 1567.~0 S 1617.5~ $ 1667,~7W s 6~ 1 ~ o-~- .......... 8g0'5:'~"0- .......... ~'$ 45 '--o'2----$ .......... 17 i 7 $ i-g-- w 676i.00 8700.00 55S6.79 S 8s~i.oc asoo...~q ...... . ..... ~28.~5 s 89Gl.on ....... 890"0.00 3~69.9~ S 9061.00 9000,00 ~511.52 S 9i~i.oo ~1o0.oo ~5~.1£ s 92~i.oo ........ 92oo,O~ ............ 95~.S5 927V.5~ $627.5S $ 1767.20 W 1817.06 W 1666'65 W 1915.82 W !966.$2 N · 2016.72 W 2055.~ W 658.22- 680.20 702,60 72~.83 7~7.28 770.51 795,89 21.3~ 21.97 22,~0 22,23 22,._~.~ 25,2~ 25,~8- 817.16 25 859.51 22 860,4% 21 680,90 20 900.69 ...... 19 920.07 19 959.28 19 958.~0 19 977.$~ 18 996.85 19 1016.50 19 1031.~6 15 .26 .1~ ,15 . o~5 .79 .21 ,11 .9~ .50 .1~ THE CAt_cUL$.TIOi<I PRoC~-O'0'RES---'i3SE -A 'Lii~JEAR INTERpoL'ATiON' FBETWEEN THE kEAREST 20 FOOT ME) (FROM Rt~OlUS CF CUPVATURE) POINTS it' J ,ii : , . , ~, HE~IZIZxI, TAL VIEW __L.J_.L.J._...L.X_..Z~ ~' !.. L._!_L ..... L...L_..--._~ ~,TL'ANTIC RIO-FIELD CEI~ANY , . . :!! :i :i~ !', . . / 'FlY I ! ·'I ' · l....-il,-.i ~ :,~ i: ~' · :'1 : ;l ; I L ! I !.~1 '~:/ l':: I i --L4--b-!--F-L ........... :--: , ' I-:--:.---:-- t .... i : :"'::': ::,ii, i H ~ -t-.?-.-,---T--- il ' ~,, I :1 j , , · t i I .-i DON BAKER, INC. DIRECTIONAL & DRILLING CONSULTANTS REPORT AND PLAN OF SUB-SURFACE SURVEY FOR COMPANY: ATLANTIC RICHFIELD CO. WELL NO: DRILL SITE #3-8 DATE: 11/16/76 LOCAT ION: PRUDHOE BAY D[{] i 4 197~ OIVISiON OF Oil. ^.HD ,~.~C~tO~.~ O ...... 0.. .... O ..... G, O0 ....... 6!-, '~0 -. ~ .. - ..... ., .......... Sl-t 9z*'-S -6t-~,00 6 ----i-73-,00-~ ...... ~36,09 .... S'- tt .... 5;. -29 E ........... ~3-~--<,~;"C- ........... - z+F, 6 ........ 0--t5 ......... 485,09 ....... z,£4,gq ...... N89,0.05.- ~----.8-t-6,56--S ....... -~-.7--3,-7~.--E ........ eB6.eO .... 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Z% ~Zg~_?_~_P ..... ~J~!~ ...... s~.t,~p% .... ~_p.?S~__8 _._~_~5 .p_%.f. ............. ~x5 Z ,c.~,.....~ ..... ~.: .... ~.Z 5! .~ ........ Z....~.Z_.q ............. 33~3 I! 0 =3OJ',S~ 3239,~a S6C.OC;',' ~a3,25 c 152-~1 E Z~C'.~4 S !C 15 5 i' 2.960 .... i ' -3-~ = ~ 12 .... ~ ..... ' ~ ""' '- l'-~' vO ..... S ~ ~ *' ~"'"; ......... ~-A-~ ................. - " ' ................. ...... ~.. C _, -: - ._.~ ..... . ..... . .... ,;~.]. != 15 3515.11 ..... 3~5'2.!I 'S 3 ~, ,'h {}',:, ....... 873.3/~'-~' ........ !~'~-~:0"~--~ ..... 6~,.~= S" 7'~i =6 z- ..I 0 ......... A'a"f, ~ 15 ' ' 'O ........ $"?i52"~'-7 = ....... A'~ S i'5"'7 ~ ........ '~ s-~' :~..'~$;: ...... ~'~', p";'-~'~ ...... ~ ................ ~ :"-~"~-'~ ......... ,-,--~'; '" r,"S ...... -E ........ 2 .... ~',/ '_ .......... S ..... x'~74 ............... ..... ~7 ........... 1~ O --3'863,79 .... =7'99,'7d' c3~,O0". - ..... ~'5~.el ......~'< ......... o..~7~'A'" ~ ....... -~ ..... ~56. .~5 S 3 55 ~ -- .,~S9 ...... ~' ~ ~ ~ ~ ' ~' ' ' ~ ' '~ - ' .... ,~-' ~ ..... r~' ',- / ...... '~ .... - ......... ~ ---'-'~ ....... - -, - -- .... , ......... z,~:: .... ~ ~.~ ~:.~,~7 .... a~5'Z,=~~ ~ S50,PO?~. - Z12O,:g S ~C,IZ. ~'~ ~2:~,'~5 S g 3~ 4=.. ,.~ ~,~5:.. .. ~0.~7,~.,~_, .. ............ . ........................ ......................... ~7V0 3~ !5 ....... ~:g6~.q9 ..... ~'59~.99 STb;00v.: t228.~9 s 196.~a. ~. i~.i9 s 9 6 33 ',¥ i.15t~ iib!.7~ --'as~'vo .... Z ~ ......... ~- ..... S'% ?';'S'-~'~XT'~"~T'fZ ........... S'S'~";"0"0"i:~ ...... f2"~'~"'~-~ g ....... ~'Y~T~TT ........ i'f'}TC/';"fS---16"-i-~ ......... ~ "i z ,,,: .......... -~'-~'S-6' ................ ......................... --523:f 30 ' -0 5"0S8;"2-i ........... 5007-.21 .... S.3Z.00W la21".o~-s ......... 3-~-5'-*-':/2 .... '.~,.. ......... ~57.~C-'"~-~--~'- o ',., 0.280 ...... S s ~ 0....'~: .'..-~_oii_l?'? ~i?.E__i'?7?,:li?.Ci"i.>./~.C(s.I~):''-I .... ~--5's. ~-"-5 a"--~ ............ ~"~-:'-5-i- ..... .:~7 ....... ~'s ~-7 ,' ~'~' ..... ~ .... ~"5 ...... v'~ s '-,~:' ......... ~:; x ~' ~ ............. ~ ~ 7 z., .~ --"5's~77 32 0 5572.4~ 5511.a2 S35.OOV,' 167o.64 S 491.98 ':,' i745.~i S 16 22 19 W 0:.264 1~66.Z7 ~'- s~ ~ ...... ~-~"Ts-':'--~o ...... ~-~'-i'~',-~-o ......... ~s'6;'o'~;~ ........ ~--;-~5--'-'~ .......... 4S'~?T~'~-'-'~ ........ ]~'C',"SS ...... S"-"z'h ~s ~'~ ~. ..... ~':--~--~ .z~2~.~- --'~"~ o:.~.~,' 34 ......................... 0 72.,~,>~~Z .... ~"~- ................... 723u,~1~ ..... ~ ............ 5~6,~ ..... ~";f~;~ 2~0~,45 S i!5S.06 k' =055,97 S ~'---5'6 ...... 2~ ,,.~ 0015o ....... ............................................................................................................................................................... .............. :..:: ..... :-::::.::: ..... ........=========================== :...- ....... ::CON[-DENT!AL .............. ~zCOF, D OF SUF4VEv ALL CALCLJLATI,5;kS ',~ET';'Oi~.:"-."E~ CY I ~ v EL. ZCT~ONIC CC'.',FUT~i;, .... -B"~T "', .,., ,-""' x --~-~,-,,~ .... F~---'_-'~-O~U,qE'?i ........................................................................................................................................................ 4167,a3 FEET AT S 3i 19 47 ~ NEASURED DEPTH AND OTHER DATA FOR_EVERY EVEN !00 FFET OF SUB -SEA -OEP-T++, TR'u~ ' HEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH ~ SEA DIFFERENCE CORRECTION TOTAL COORDINATES , %, ! 16! 161, 100 0 0 818.10 S 173.04 25! 261. 200 0 0 818,24 S 361 361. 300 0 O 818.40 S , ,, 461 461,, 400 0 0 8 1 ~:_,,5. 4 S 551 561. 500 0 0 8 1~_.__.~ 8 _5 6 ~! 661 · 600 0 0 8 761 7&1 · 700 0 0 861 861. 800 0 ., 0 819.64 S 961 981. 900 0 0 820.02 S 1061 1061. 1000 0 116! 1'1"61, 1100 0 0 820,63 S 0 821,34 S '174.58 E ,. 1'261 1261, 1200 0 0 821.85 S 175.32 E "' 13-6-1 1361. :'lBO0 0 lg~'l 1461. 1400 0 0 821,81 S 176,31 E 0 821.24 S 177.46 E %561 1561, 1500 0 0 820,74 S 178,62 600 0 0 820.31 S 179..76 E 1-TEl 176'1. "',.%' 07-0-0 0 0 819.95 $ 180.90 E 1861. 1800 0 0 1961. 1900 0 0 819.66 S 182.03 E 819.43 S 183.14 E 2-0%-1 2U-C'F;-----20---¢~ U 0 819.26 s 184.23 E 216I 2i~i. 2100 0 0 819.16 S-- 185.30 E 2261 2261. -2200 2~'~ 1 2361 · ,2300 0 0 819.11 S 186.31+ E 0 0 819.13 S 187.36 E 2a61 2461. 2400 0 0 819.20 5 188.34 E 2561 2561, 2500 0 0 819.32 S 189.29 E 2661 2561. 2500 0 0 819.49 S 190.21 E 2761 2761, 2700 0 0 819.72 S 191.10 E 2861 2861, 2800 '2--~-i- 0 821.96 S 191,50 E 2961, 2900 0 0 822.55 S 185.58 E '3062 3061, 3000 3152 0 0 82a.47 S 178.85 E 3161, 3100 1 1 830.86 S 170.57 E 3263 3261, 3200 2 1 83~.49 S 158.66 E 3365 3361. 3300 4 2 849.91S 1~2.28 E 3a67 3461. 3400 6 2 864.01S 125.87 E 3570 3.561. -3500 - 9 ~ 882.73 S 111.45 E MEASU~E'D DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. TR'U~ ' MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH . DEPT~ '!SEA DIFFERENCE CORRECTION TOTAL COORDINATES, 3661 . 3600 12 376i , 3700 16 3B ,61; .... 3~8DO- 21 3'g61, . ~ ~00 ' 2-7' aO-~'!. ' ~+O'G'q~ '34 416!, ~+leC 43 904.54 S 97.5~ [. 928,53 S 82,63 E 5 95a~61 S 65,57 E 6 982.78 S 45.a8 E 7 1013.07 S 21,55 E 9 1045.07 S 6.68 ~ ~a26 4361, 4300 64 4539 4a61, ~400 78 -065a 4561, ~500 93 477-0 4661,' · 4600" '.,1'~9 4885 4~61, 4700 1~3 10 1079.09 S 38,92 ~ 1i 1112,05 S 75,43 W 14 11a6,94 S ~ 115,77 W 15 .... . 1185.62 S "157,5~ W 16 1228,49 S 196,98 W 14 1274,31S 230,32 W ~ .15 !321,05 S 260,45 W 4999 5 f!"~ 4861, '...4800 4961, 49'00 5230 5061, ·5000 5345 ~1-6-!-.,~ . 5!OD- 1'84 ~462 5-2-6-~, 5578 5361, 53~0 2~7 · 5696 5461. 5400 234- 15 1368,8.3 S 290.88 W 15 ' 1417,51S 321.52 W 16 1466.56 S 352,49 W 16 1516,67 S 384.89 W 17 1566,69 S 418.0i W 17 1617.73 S 452,58 W 5-8-I'3 556! · 5500 2'$2 5'9-:3~'-- 566i · 5600 2?0 5~5e 57-6--~' , 5700 289 ~ ~sco 30V 18 1668.56 S 487,73 W 18 1720.31S 524,03 W 19 1771.76 S 560.33 W 18 1823.75 S 597.20 W 6297 5961, 5900 326 19 1876.0~ S 63a,50 w 640~ 6061, 6000 345 19 1928,99 S 672.40 6526 6161, 6100 364 19 1981.80 S 710.44 66~6 626i, 6200 384 20 2035.10 S 749,03 6766 7I'2-8 6361. 6300 404 6~"g-f" ' "6-'4-00 425 S-561 · --'6 5--0-0 ~+4 5 ~-6-61 , ' i. 6'600 ~--7-61, "67--0-~ - · 487 20 2089.01 S 788.10 W 21 2143.17 S 827.11 W 20 2198.17 S 866,49 W 21 2253,59 S 905,93 W 21 2309.42 S 945.42 W 22 2365.66 S 9'84.96 W 6861, 6800 509 6961, ': 6-gOU .531 7-061. ...... TOO0 '552 22 2422,39 S 1024.83 W 21 2z+78.a7 S 1064.58 W MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN l_0_O FEET OF, SUE. SEA DEPTH, ) ~v'I='ASUR'"'D_ c. VERT I CAL SUB · DEPTH DEPTH ~ SEA %,, MD-TVD VERTICAL DIFFERENCE CORRECTION TOTAL COORD Ii"1ATES 773~ 7161. 7100 573 21 253~.02 S 1104.29 7855 7261. 7200 594 21 2589.04 S 1143.98 ) '~9''~. ,.. 7361. 7300 20 26~3.62 S 1183.96 W 8097 7a61. , 7400 635 21 2697.59 S 82!8 7561. 7500 656 21 2751.16 S 122 5.-1¢ ~',: 1267 ._6_a_ .. W _13_!! ,_4_2_ W 14 Q3_~__0_3 W 1450.94 ~ 8~9 7661. 7600 678 22 2804.07 S 8461 7761, 7700 699 21 2856.58 $ 8583 7861. 7800 721 , 22 290~.34 S 8705 7961. 7900 743 22 2959.70 S 8827 8081. 8000 766 23 3010.48 S 1500.08 W 8950 816'1. 8100 789 23 ~061.10 S 1550.87 W 9073 8261. 8200 ~'.: 812 23 3110.34 $ 1602.56 W -,~- 9%95 834 22 ~.,< 3157.43 S 1654.31 W 9317 856 22 3203,50 S 1706,6B W 9439 8361. :,8300 8461, 8561. ', 8500 878 ~-6'Y-'l J 860-0 899 8?'-El. :- :877::)-0 .... 91'9 '88 61 · 880O 22 3248.22 S 1758.88 21 B291.74 S 1811.2a W · 20 3334.C7 S 1863,67 W 939 20 337D.23 S 1916,18 W 8961. 8~¢0 '- 959 20 3~15.20 S 1968.73 W 9-~ ~9070~--9~9 20 345~o01S 2021.32 w ~'~-~1'. 9100 --~8 19 3492.18 S 2073.87 W ~560 i-027 8 9261. 9200 1017 19 3530.32 S 2126.37 W /INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH. TRUE M'~Su:R E D VER T I' C,~. L' .SUB DEPTH DEP_TH SEA TOTAL COORDINATES 1000 99,9. 938. 820.23 $ 174.28 2000 1999. 1938. 819,36 S 183,57 E 3000 2999. 2938. 822.86 S 183.75 E z+30C 3972, :3911, 986,08 S 42,99 E 5000 ~+861, 4,800. 1321.~6 S 260.71 W ~6~0:0 57i~. 5657. 17~9.97 S 544.93 W 65~5 '"'? O 00 · 649~. 2194.98 S 864.,21 8~000 7BS1. 7320. 265~+. 39 S 1192.03 qOOO 8201. 81aO. 3081.27 $ 1571.76 10000 9027. 8966. 3441'. 2~+ S 2003.87 ;] - i , ' ATLANTIC RICHFIELD CO. · 'i,~'}i'":~'':''.'i''{ ! 'i'!:::;-i MAGNETIC SINGLE-SHOT SURVEY .'..~ ',.: .... ' . ALL DEPTHS SHOWN - i ~,~ ....... '· . 1 - * .... , ~ ' . j . , ~ : ,/ i ~ ~ : ,_L,.L',,.~: ,' ..L ,. ; ,,.- ,.: ;.' . ; ' . , ;.'. .... ; VERTICAL SECTION 1200 ~ " RADIUS OF CURVATURE METHOD iiiii ALL :.DEPTHS SHOWN ARE TVD 3600 :' : 4000 ........ ' ~ 4400 ':" ........... I ........... : ~,'t :'' i ',~ : ,. ; , ' ' '7' j ' . , , ~ , , . ~ ' '~' ' ' · ~ .':>~':' ': ,~ -' · ' ! ' . ' : ' · , · ': . , , - · . .... · ' . · +..,,~. ,,.,' .... ', ............. ~ ....... :; .... ' ~ · , · , ' -. , '. '.~ 72~,,', -' :, ........ .,. ,:'? · ", .l · - · ~ : ,,....'...,,..~; . :' .... ,.; ~..:~ x..:-; -"~ '-:::i N .;'4 ' -." ', ' ; : t ' : ' :' ~ ' ' ! '~8400 ,'. .... : ' t ~ ..... . ,. ~__~. ' . .% SPERRY' $11N DIRECTIONAL SURVEY REPORT FOR A TL t~.~LT IC RICHFIEID BEg ~ 4 1976 DIViSiON OF OIL AND GAS A, NCHORAO; TYPE OF SURVEY: Ma~gnetic Multishot SURVEY DEPTH: FROM,' 2; ?0.8, FT. TO,, LEASE: [}rill Site #3 ,WELL NO. FIELD: . Prudhoe Bay COUNTY/PARISH NQrth Slope DATE OF SURVEY November 6, 1976 OFFICE' ~nchorage~ Alack~ STATF A 1 n s ka JOB NO MS-16131 27~-6696 S~*I3SC '1 ATLANTIC RICHFIELO COMPANY DRILL SITE.-~ ? 8 , PRUDHOE BAY ALASKA SPERRY-SUN -WELL...-SU EYING -COMPANY ANCHORAGE, ALASKA COMPUTATION ...DATE NOVEPiBER 10, 1976 MEASURED DEPTH TRUE SUB-SEA COURSE COURSE DOG-LEG .... VERTICAL .... ~ERI. ICAL----INCLINATION DIRECTION SEVERITY DEPTH DEPTH DEG MIN DEGREES DEG/IO0 ....... 2708 ......2708.00 ---26~7.,00. --0 ........ 0 ..... N.-.84. 0 W O, 2812 2811,9~ 2750.9~ 3 15 N 84,0 W 2905 2904.74 2843.7, ~ 10 S 69. 0 W 2. .... 299d .......299~,~Q._ 29~6..40 5_.__~0 .......S..~5,_O_.W .............. 2. ~08~ 5087,95 ~026,95 6 0 'S ~6, 0 W O, ~18, ~182,20 ~121,20 8 10 S ~9, 0 w 2, 457~ 4766 ...... 4952 5137 ........ 5229 5321 5~15 ..... 55O9 .......... 3277 ...... ~2Z~_,O.% .. $213_,..Q1 .... ___lO .... ~5 .... S_5~, 0 .... W 2, 5371 3566,17 3305.17 12 25 S 52, 0 W 2. 3464 3456.95 3395.95 12 50 S 37. 0 W .............. 5557: ....... ~54~.~L__,.~86..4~ ...... 13 .... ~5 .......S..26,_0 _W.._~ ....~ ..... 2, ~650 ~637o55 ~576,55 15 ~ S 28, .0 5745 ~727,00 5666,00 16 ~5 S 30, 0 ~ 1, .......... 3835 ........... 58.1~o19 .... ~Z~5,7~_ . ~8 ...... 0 ..... S ..... ~I,._O..W ................ 1, 3927 5902,0~ ~841,0~ Z~ 0 S ~4, 0 ~ 1, ~018 ~987,53 5926,5~ 21 0 S ~6, 0 ~ 2, ....... --~1'2Z'-'7. ......... ~07~o93 ........ ~.012o. 9~ ........... 22 .... 25 ........... S.39,50 ~ .................... 2, ~205 ~160,48 4099,~8 2~ $0 S ~2, 0'~ ~299 42~6,18 4185,18 25 0 S 4~, 0 ~ 1, .... ~328,86 .... ~.26Z_,86 ........... 27 .... 0 ........ S.._~6o 0..~ ................ ~412,72 ~5~,72 2~ 0 S 48,50 ........ ~57.5,.~9 ~5Z2...,.~9 .... . ~2 .... 0 ..... S ~, O .~ ...................... ~654.18 4595.18 29 30 S ~7. 0 W 4. ~735.59 4674.59 28 22 S ~1.50 W 5. ....... 4817,17 ......~Z56,17 23-- O ........... S..50,50 .W .............. O, ~897.q~ 4836,44 29 30 S 50,50 W O. ~978,22 4917.22 29 55 S ~0.50 W O. ....... 505Z. M5 ..... ~96,~5 ~0 .... 0 ........... S .... ~0, ...O_.W ................... O, 51~7.60 5076.60 ~0 0 S ~1. 0 W O. 5218,86 5157.86 ~0 22 S ~2; 0 W O. .......... 5~00,01 ........ 5239.01 ......... 30___15 .......... S..~, 0 ~ .................... O. O0 12 09 57 5g 31 81 72 88 97 39 50 32 06 55 81 ~7 4~ 33 08 2~ 10 85 54 28 5~ 66 55 DATE OF SURVEY NOVEMBER 5, 1976 -RULTISHOT--SURVEY dOB NUMBER MS-16131 KELLY BUSHING ELEV, = 61,00 FT, -- -.CT, PT. WELL-NOD 1 TOTAL RECTANGULAR -.COORDINATES ......... VERTICAL NORTH/SOUTH ..... 818,00 817,69 818. .. 822. 829. 837, .............. 845, 856. 870, ......... 888. 909, 951, .... 955, 980, 1005. 1032. 1060. '1088. 1117, 1147. 1178, 1212, 1248., 1285, .- 1526. 1562. 1402. 14~2. 1%81, 1522. 1562. EAST/WEST SECTION S ......... 175,00-E ............. 617,88 ..... S 172.06 E 619,09 62 S 166.29 E 622.82 98 S ......... 159.9-8:_E .............. 629.~ .._. 37 S Z53.48 E 638.56 25'S '144.81E 649.75 84....S ........... 152,73_£ ............ 663,25 ........ ~8 S 117,60 E 679.98 78 S 103.50'E 699.53 97 S ............ 92.~4_.E ................ 720.82 ........ 55 S 81.94 E 743.86 76 S 69.59 E 769~29 43 S .................. 55,64_5 ...................... 796.76 .......... 03 S 59.9.~ E 825.92 50 S 22,08 E 856.93 66 S ............ 1.00-..5 ................ 891.01 42 S 22.93 ~ 927.06 64 S 49.27 W 964.71 13 S .............. 77,79--~ .................. 1005.70 ..... 37 S 110.55 W 1046, 16 S 14'4.44 W 1090'0 05 S ............... 178.26..-~ ................. 1136~5 .... 76 S 209,18 W 1183.65 89 S 234.51 W 1228.~9 15 S ............. 257,50-W ................ 127~.12 .... 89 S 280,31 W 1318.07 60 S ~03.71 W 1564.16 28 S ................ 326,85 -W .......... 1~10,10 92 S 350.20 W 1~56.10 21 S 37~.89 W 1503.55 22. S ~00,36----~ ............. 1550.75 ATLANTIC RICHFIELD DRILL $ITE---3-.~.-8 PRUDHOE BAY ALASKA it! MEAS DEPT URED H COMPANY SPERRY'SUN--- WELL.-SU,, EYING-COMPANY ANCHORAGE, ALASKA ~OMP.UTATION OATE · NOVEMBER 10, 1976 TRUE SUB-SEA cOURSE COURSE VERTICAL.---VERTICAL .... INCLINATION--DIRECTI OEPTH DEPTH DEG MIN DEGREE DOG-LEG ON .-SEVERITY S DEG/IO0 5602 5697 5789 5883 ~/6071 6165 6257 6351 65~7 66~ 6816 ....... 5380,03______ 55q0,12 5620.16 5700,05 5779.8~ 5857..90~. 5937.5~. __5519.05 51 ......... 0 ......... S 35. 0 5400.47 31 0 S 54, 0 5479.12 31 30 S 35. 0 555.9.16 ............ ~1 ~5 ...... S 5639.05 50 5718.8q 57~6~90 5876.5~ 5955.86 52 0 S 34 32 15 S ~q 32 qO S ~q 6016,86 · 0 609~.49_ ' _6033.q. 9 .......... , .0 617~,76 6112,76 , ..0 6251,03 6190.03 , 0 6~29,86.. L_~268.86 .......... 5.3._.~ .... 0 ....... 6~07.75 6546,75 3~ 15 S 35,50 -W .............. 1. W O. W O, 35',_0W ........... O, S ~. 0 W 1. , 0 W O, ,-O-..W ........... O, · 0 W O, 32 .... 15 ........ $-34 32 q 5 S 34 33 0 S 34 W O. W O, W O, W ....... ] ........ W O, 691i 6487.08 6~26.08 33 ~0 S 3~ 7095 7137 727~ 7371 7459 756~ ,50 ,50 66~0.37 6579.37 3~ 0 S 33.50 6716,6~ 6655,63 5~ 1 S 35.50 6791.96 ..... ~30,96 5~ ...... 15 .......... S .3~.50 6868.60 6807.60 3q ~5 S 33. G 6949.~2 6888.32 3~ 20 S 35 7026.79 ........ 6965,79 ............... ~q ....... ~0 ...... : ....... S~..~5 W O. W ........... O, W O, W O. W ..... O. W · OW O. , o_W .0, 36 5~ 2'6 12 5a O9 35 53 27 28 26 26 O~ 63 O1 25 61 ~2 ~5 7657 775U :. 7845 7938 .. 6120 6213 6306 710q.30 70q3.30 7181.26 7120.28 3q 0 S 33 ...... 7260.16 ..... 7199.16 ........ 33 ._~5 ...... S--3q 7337,71 7276.71 33 15 S 35 7415,26 755~.,26 33 ....... 7q8.~,15 ........... Z~28,1.5 54 ........ 0_..: ............ S..36 75~6.02 7505.02 76~2,55 7581,55 6397 ......... 7717.21 ...... 1656.2i ,50 W O,b3 ,50 W 0.26 ,.0 W ......... 0.59 , 0 W 0,80 , 0 W 0.53 , 0 W .................. 0,68 3q 30 S 37, 0 W 0.80 3q ~5 S 38.50 W 0.95 55 ........ 0 .......... S-39, 0 W ............ 0.~! DATE OF SURVEY NOVEMBER 5, 1976 --NULTISHOT-SURVEY JOB NUMBER MS-1G131 KELLY BUSHING ELEV, = 61,00 FT. CT. PT. WELL.-NOo-t ....... TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERTICAL SECTION · 1601,q8 S ..... ~26,87---W ....... 1598. 16gl,80 S g5q,58 W 16q6. 1681,13 S ~81,62 'W 169'~. 1721,51S .509.89.-W ............17~5, 1762.56 $ 537.58 W 1792-. 180~.00 s 565.01 ~. i8~2. 1885.76 S 620.16 W 19~0. 1¢27.58 S 6~8.~7'W 1991. · 1~68.52 S - ........... 675.98.--W ................. 20~0o 2010o39 S 70~.22 W 2051e79 S 732.1~ W 21qO; .209 . 6 s .............. 7 0.59_ .............. 2 91. 2136.7~ S 788.6, W 22~2. 2180.32 S 817,~8 W 2294. 2222.61S~.~~ ........ ;=~W5-~,~-8~:.~ .......... 23q5. 2265.19 S 873.66 W 2596. 2308.10 S 902.06 W 2~7. 2550.68 S 930,2~ ~W ....... 2498. 239~,73 S 959,12 W 2551. 2~1,35 S 989,38 W 2606. 2~85.98 S , loiS.Saw ......... 2660. 2530,~6 S. 1047,5~ W ' 2713. 2573,97 S 1076,~ W 2765. .2617,99 S ..... 11o5,75-W ........... 2818. 2660,50 S 1134,82 W 2869. 2702,5% S 116~,27 ~ 2920. 2742,73 S ...... 1193,07..~ ................... 2969. 278~,80 S 122~.21W 3021. 2526,57 S 125&,56 2867,15 S ........ 1289.15..~ ............ ~125. 81 95 57 98 60 ......... O0 86 5l ....... ~8 86 25 20. 55' 37. ATLANTIC RICHFIELg COMPANY DRILL SITE 5__---8 , PRUDHOE BAY ," ALAS:<A ~ MEASURED DEPTH ..... 8~89 8531 867~ 6856 .SPERRY'SUN---WELL SU~,~* KYING COMPANY TRUE VERTICAL DEPTH ANCHORAGE, ALASKA COMPUIATION DATE NOVEMBER 10, 1976 SUB-SEA COURSE COURSE .VERIICAL IHCLINATION --DIRECTION DEPTH DEG MIN DEGREES DOG-LEG .SEVERITY DEG/iO0 7792.8~~ 7868.58 79%~.06 ...... 8018.~_9 8093.62 8032.62 /89%6 8167. O0 8106.00. ........ 8i, ao.2a 9126 8315.89 825~,89 9219 8391.00 8330.00 ....... 9312 9%03 85 .39 8 83.s9 Yr31,8% ....... 3%_-__25 ....... S %0.50 W 7807,58 3~ ~5 S ~1.50 W 7883,06 35 0 S q3, 0 W 7957.%9 35 .... ~5 ..... S'..~$,50 W 9~96 8623.95 8562.95 33 0 S 50.50 W ........... 9591 ....... 8Z0.2.06_ ~6~1.06_... .... 32 .... ~5 ........... S_52. ..... O_W 9683 8779.51 8718.51 32 35 S 52,50 W 9777 8858.77 8797,77 32 27 S 52.50 W 9871 ....... 8938.22 ....... ~_8_~_7_..22 .......... 32 ...... _10 .............. S .5~.__0 .... W 35 15 S ~. 0 W O. 35 30 S %5.75 W 1. __35 ...... 5 .... S..,.-~5.75_W ............... O. 3~ ~5 S ~6.50 W O. 3~ 0 S ~7.50 W , 1. 33 15 S 99, .0 W O. ~-96~ 9016,91 ...... lo152 .......... 9175_.50 ~02~7 9255.25 Z0277 ___10302 ............ 9301.50 'L,,?~0370 9358.69 8955.91 9036.22 ....... 911~.50 ........... 919~.25 9219.g? .92~0.50__ __ 92~7.69 32 15 S 52, 0 W ,32 20 S 53. 0 W :~3 ............ 0 ............... S ,..52.50 32 50 S 52,50 W 32 %5 S 5;".50 W __32 ...... q. 5 ........ S 52. .0 .... W 32 ~5 S 52.50 W 12 71 97 31 15 ~5 59 US 69 90 91 %1 58 56 77 17 27 08 ~9 DATE OF SURVEY NOVEMBER 5, 1976 ~ULTISHOT-_SURVEY dOB NUNBER MS-1613! KELLY BUSHIN6 ELEV. = 61.00 FT. CT. PT, ~ELL TOTAL RECTANGULAR COORDINATES ....... VERTICAL NORTH/SOUTH EAST/WEST SECTION 2907.~3 S 29~6.8~ S 2~85.77 S 3023.91S 3062.26 S 3099.18 S 3171.96 S 3207.01S 32%1.71S '327%.8% S 3508.38 S $~39,98 S 3370,38 S 3~01.1~ S 5%51.55 S 5%61.7~ S 3523.01 S 355~3 S $56%.32 S 3572.60 S _3595.12 S ..... 1322.$2-~ .......... 3177.51 1356.87 W 3228.82 1392,2~ W 3280.28 ..... 1~2&.12._~ ............. 333i.3~r. 1~6~.83 W 5382.95 1501,59 W ~%~3.57 1576,80 W 353~.16 161~,~7~W 3585.38 ...... 1652,57-W .................36~2.62 1690.02 ~ 3680.12 1729,6~ W 3729;07 . ,,1769,00 _~ ................. 377&.21 18~8,27 ~ 3822.27 18~8,35 W- 3869,06 .... 1688,3~._~ ................. ~915.50 1927,67 W . 3961.39 -- t967,93 W ~008.38 20~7.89.._W ............. ~05~,78 -20~8,8~ W ~102.5{ 20~1,73 N ~117.62 2072,~ .W .......... ~130.17 ..... 2101,51 ~ ~16~o29 HORIZON'£AL---DISPLACEM£NT._=__J416~.29. FEET AT.-,SOUTH~ 30 DEG, THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL I 18 MIN. WEST .AT MD = 10370 ...................................... RADIUS- OF CURVATURE METHOD. ATLANTIC RICHFIELO DRILL-SITE-5.--- 8 PRUOHOE BAY ALASKA ALASKA COMPANY SPERRY-SUN--.WELL--Sb'"~EYING-..COMPANY ANCHORAGE, ALASKA COMPUIATION .DATE NOVEMBER 10, 1976 DATE OF SURVEY NOVEM8ER 5, 1976 -MULTISHOT-_SURVEY OOB NUMBER MS-16131 KELLY BUSHING ELEV, = 61,00 FT. ................................ CT, PT, WELL ~0, --1 .......... KELLY BUSHING ELEV, = 61,00 FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH ......................... TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH --IOTAL .............................................................. RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTIO~.i 2708 2708.00 26q7.00 818,00 S' '175,00 E 0,00 5708 3693,~8 3652.~8 923.03 S 74.63 E 1~.51 14,51 .......... ~708 ...... ~60~,06 ..... ~-~,-08 122&,0~..-$. -190,82.~ .............. 103,~1 ......................... 89,~0 5708 5~70,89 5~09,89 16~6,50 S ~57.75 W 237,10 1~3, 6708 6317.28 6256.28 2087.5~ S 756.08 ~ 390,71 153, ' _ ....... 7703 .... 71~6.~6 '7085...46 --2.55~,38_S ......... 1063,~7.._W .................. 561,5~ ......................... 170, 87o8 7972,73 7911,73 3000,45 S lq. 05,93 W 735,26 173, ~708 8800,57 8759,57 3378,58 S 1818,95 W 907.~2 172. ........ 10~70 ........... 9~_58..69 ~2~2_..6~ ~595,12._$ ..... 2101,51_.W ........ 1011,30 ........................ 103, 18 60 7~ 88 ............................. THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD, t ¸'3 COMPANY SP. ERRY-SUN--WELL--SU,~EYING COMPANY. ANCHORAGE, ALASKA COMPUTATION DATE NOVEMBER 10, 1976 ATLANTIC RICHFIELO DRILL SITE__$ ~-8 PRUDHOE BAY ALASKA o INTERPOLATED VALUES FOR E VEN 100 FEET OF SUB-SEA TRUE SUB-SEA TOTAL DATE OF SURVEY NOVEMBER 5, 1976 -MULIISHOT SURVEY dOB NU~BE~ MS-16131 KELLY BUSHING ELEV, : 61,00 FT, CT, PT,.WELL NO,--1 DEPTH VERTICAL CORRECTIOF.!-. MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVO DEPTH ....... DEPTH ~OEPTH .........NORTH/SOUTH ...... EAST/WEST_.DIFFERENCE 2706 2708,00 2647,00 818,00 S 175,00 E 2660 _.2661.00_.__2600,00 ............... 818,02 S__. ..........175,25 E 276i 2761.00 2700.00 617.91 S' 17%.21 E 2861 2861'00 2800.00 817.60 S 169,22 E _2961 ..... ~961,00 .... 2900.00 820,55-.~ ..... 162.%6 .E 5061 5061.00 3000.00 827,~0 S 155.5i E 5162 3161,00 3100.00 855,25 S 1~7.11 E 5263 ........326.1,00 ....... ~20.0,00 ............ 8%%,63 S .......... 1B%.Gg_E 5~65 3361,00 3300,00 855,69 S 118,%9 E 3%68 3~61.00 3%00.00 871.52 S 102,95 E 3570 ....... 3561.00. 3.500.00 ................. 891.9%_~ ................ ~0.98_E _ 367% 3661,00 3600,00 915,08 S 78,99 E 3778 3761.90 3700.00. 9%0,62 S 6%.%7 E 3865 ....... 3861.00 ...... 3800,00 .................... 968,33 S .................... %7.78.E 393~ 3961,00 3900,00 997,26 S 28,06 E 409.7 4061,00 %090,00 1028,55 S ~,%0 E %205 .. %1~1.00 ..........~100.0.0 ' 1060,59 S ............. 23,08 ~515 %261,00 %200,00 1093,61 S 5%,07 W 4%27 ~361,00 %300,00 1128,50 S 89,57 0,00 -0.00 ...... 0,00 ................ i' . O,OU 0,00 0,1~ 0,13 0,42 .......................... 0,28 ............................................ 0.90 0,~7 1.57 0.67 2,76 ................................. 1.21 ....... g,70 1.91 7,15 2,~ · 9,92 ....................... 2.77 .................................................... 13,26 17,50 22,61 ..... 28,57 36,00 5~.3% 66,06 3,34 4,23 5,10 5.96 8,55 .............................. 9,7& 11,72 ATLA~,'TIc,, RICHFIELD DR ILL SITE PRUDHOE BAY ALASKA COMPANY SPERRY-SUN-WELL-SU~- YING COMPANY ANCHORAGE, ALASKA DATE OF'SURVEY NOVEMBER 5, 1976 COMPUTATION DATE .......... _MULTISHOT-_SURV~Y NOVEMBER 10, 1976 JOB NUMBER ~S-161~i KELLY BUSHING ELEV, = $1,O0r FT. CT, PT, NELL ~O. I TRUE MEASURED VERTICAL OEPTH .......... OEPIH INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL ~gEPIH ..... NORTH/SOUTH ........ EAST/WEST ___DIFFERENCE ..... CORRECTION ~5ql ~GI.O0 ~00.00 ~657 ....... ~561.0.0 ..... ~500.00 ~77~ ~661.00 ~600.00 ~887 ~761.00 ~700.00 .._ 5002 .......... ~861,0~.~S00.,00 5~I? ~961,00 ~00,00 52~2 5061,00 5000,00 .... 55~ ....... 516!,0..0 _ 5100o00 5~63 5261. 557~ 5361. 5696- ._5061. 581~ 5561. 5951 5661. 60~ ~761. 6166 5861. 628~ 5961. 1165.~$ S 130.66 W 80,29 la, 1206,q8.$ 172.98..W ..... 96.~2 ............... 16, 1251.8~ S' 211.~6 W 112.81 16. 1297,59 S 2~1.68 W I26.87 1~, 1~,5.,1~-..-S ....... 269,86-~ ........... 1~1,1~ .......................... lq, 1~9~,06 S 298,68 N 156,12 1~, 1~q~,82 S ~27,7' W 171,5q 15, ~9~,&9.~ ........ ~57,15..W ......... 187,01 ...................... 15, 00 5200,00 15~3,12 S ~88,00 N 202,83 15, O0 5500,00 1592,11 $ ~20,$1N 218,78 15, 0.0_ _ ~_OO.~.O_O .16.~1,5~.-S .......... ~5~,~__W ............. 235,~5 ........................16. O0 5500.00 1691,61 S ~88,96 W . 252,48 17, 00 5600.00 17~2,2~ S 52~,~ W 270.02 17, O.O 5~00..00 ...... 179q,2~..S .......... 558.~2 W 2B7.77 ............ 17, OO 5800.00 18~5.97 S 595,~1 ~ 505.6~ 17, O0 5900.00 1898.0~ S 628.q5 00 ......... 6000.00 ............ 1950.98 S .......... 66~.15 W ..... 542.59 ........... 18, O0 8100.00 2005,58 S 699,65 W 560.81 OO 6200.00 2057,15 S 7~5.76 W 579.86 6~OJ .... 6061. 6521 6161. 66~0 6261. 22 05 26 99 8.2 95 66 05 5~ 7~. O~ 19.06 ATLANTIC RICHFIELD COPPANY DRILL SITE 3_.~_8 , PRUDHOE BAY '" ALASKA ~ INTERPOLATED TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH ............... DEPTH ' 0EP_Ih '1 SPE RR Y-SUN-.-WELL--SUr~ YING -COMPANY ANCHORAGE, ALASKA COMPUTATION.DATE NOVEMBER 10, 1976 VALUES FOR EVEN 100 FEET OF SUB-SEA TOTAL RECTANGULAR COORDINATES MD-TVD NO.RTH/SOUTH ......... EAST/WEST DATE OF SURVEY NOVEMBER 5, 1976 ~ -MULTISHOT-$URVEY dOB NUMBER NS-1G131 KELLY BUSHING ELEV, = 61.00 FT. CT. PT, WELL-NO,-1 DEPTH VERTICAL -.DIFFERENCE ..... CORRECTION 6760 6361.00 6300 6879 ....... 6~6!.0.0. .64.00 6999 6561.00 6500 7119 6661.00 6600 72~0 ........ 6761.,00 ..... GT~Q 7361 6861.00 6800 7483 6961.00 6900 7604 ........ 7_06~,_00. IQQO 7725 7~61,00 7100 .00 2111.21 S 771 .00 ............. 2165.92 $ ...... 807 .00 2221,05 S .00 2276.79 S 881 .00 23~3.10__S 918 .00 2390.30 S 956 .00 2448.02 S 993 .00 2505,82.._S ...... 1031 ,00 2562,56 S 1068 7846 7261.00 7965 ............... 7~61.00 7200.00 2618.4.6 S 1106 . 7_300_,0.0_~ __2672.80_S ........ 1143 8086 7461.00 7400.00 2727.36 S llB1 8206 7561.00 7500.00 2782.0~ S 1222 8328 ........ 766!.00 .... Y.~O0,OO ........... 2836.59..S ........... 126~ 8~50 7761,00 7700,00 -28~0,84. S 1308 857~ 7861,00 7800.00 2942,89 S 1553 ~695 ........ 7S61.00 .... 7900.00 ................ 299~,4~--..$ ............. 1400 8~16 8061.00 8000,00 30~5,67 S 1~4.8 69~6 8161.00 8100.00 3096.19 S lq98 .74. .95 .61 .25 .73 .2G .78 .07 .58 .92 .52 .4.5 .39 .33 .82 .53 W 399,11 19,23 W .... 4.18.71 ................ 19.59 W 438.59 19.87 W ~58,87 20,28 .W ................ 479.54 .................. 20.66 ~ 500,?~ 21,19 ~ 522,13 21,38 W 564.52 20.9~ W 5~5.00 20.~7 W 625.03 20.1~ W 64.5.89 20,~5 W ..... 667.4.4 ............. 2 W 689.40 2 W 710,76 2 W - 732,67 2 W 755.05 2 W 777.62 2 1.9~ 1.~6 1,90 ................................. 2.37 2.56 ATLANTIC RICHFIELD DRILL 'SITE PRUDHOE BAY ALASKA SPERRY-SUN -WELL----S EYING COMPANY ANCHORAGE, ALASKA COMPANY , COMPUTATION DATE '" NOVEMBER 10, 1976 DATE OF SURVEY NOVEMBER 5, 1976 .... MULTISHOT-SURVEY dOB NU~qBER MS-16131 KELLY BUSHING ELEV. = 61.00 FT. CT. PT. WELL NO. 1 INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB'SEA DEPTH TRUE MEASUREG VERTICAL DEPTH ....... DEPTH- SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD 'OEPTH .......... NORT~I/SOUTtt .... EAST/WEST DIFFERENCE VERTICAL , CORRECTION ................................. 9061 9182 .... 9305 9422 9592 ....... 9661 9779 9897 ..... ldO16 1025~ .......... 9261.00______9.200.08 10570 9558,69 9297,69 8261.00 8200.00 31~5,53 $ 15~9 8~61.00L ...... 8300,00 ............. 5193,31 .S ....... 1599 8q61.00 8qO0.O0 ~2~8,q5 S' 16q8 8561.00 8500.00 5281.98 S .1698 .8661.0-0 ..... 8600.,-00--~ ......... ~32~.65--.-S ........ 17~8 8761.00 8700,00 8861,00 8800,00 8961.00 ...... 8900.00 9061.00 9000.00 9161.00 9100,00 ~363.18 S 1798 3q02.00 S 18~9 5,~0.1~-S ....... 1899 ~478.81 S 19~9 3517,27 S 2000 5556.69_S '__2051 3595.12 S 2101 .17 W 800.09 22,N7' .~ W 821,79 21.6'9 ................................... ,96 W 8q2.17 20,37 ,2~ W 661,85 19,68 .21W ...... 881e15 ..........................19,30 .... ,88 W 900,02 18,86 ,~7 W. ~18.63 18,60 .78.W ......... 936,90 18,27 ,6' ~ 965,13 18,22 ,~1 W 973,70 18e56 · ,78 W .... 9~2,83 19,13 ,51 W 1011,30 18,~7 THE CALCULATION_PROCEDURES__USE. A__LINEAR .... INTERPOLATION BETWEEN THE NEAREST 20 FOOT MB CFROM RADIUS OF CURVAFURE) POINTS CONFIDENTIAL · . I ! i BP ALASKA INC. 31 1 1 - C - STREET · TELEPHONE (9071 279-0644 CONFIDENTIAL State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. Hoyle Hamilton Acting Director Gentlemen: MAILING ADDRESS: P.O. BOX 4-1379 ANCHORAGE, ALASKA 99509 November 3, 1976 Well DS 3-8 (31-15-10-15) Enclosed, in duplicate, is form P-4, Monthly Report of Drilling Operations for the subject well covering the month of October, 1976. Very truly yours, BP ALASKA INC. ?. R. Judd District Drilling Engineer PRJ:jle Enclosure cc: Well File #17 Fo~ ~o, P--4 REV. ,~- I- 70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT 1~ DU!:?LICAT~ MONTHLY REPORT OF DRILLING AND WOR'KOVER OPERATIONS WI~LL W~.LL OTHER 2. NAME OF OPEP,.ATOR BP Alaska~ Incorporated 3. ADDRESS OF OPERATOR P. O. Box 4-1379, ^nchoraqe, ^laska 99509 4. LOCATION OF WEL~ 1199'N & 837' E of SW cr Sec ll, TION, R15E, UM ~--API NU~,IEmC,{.L CODE 50-029-2023] LEASE DESIGNA?ION AND SEEIAL NO. ADL 28331 ' IF INDIA~T, ALOTTEE OR TRIBE NAME 8. L~'IT FAI'iA{ OR LEASE N.~J~IE Prudhoe Bay 9 WELL NO DS 3-8 (3]-15-10-15) 10 FiFJ.2D A_ND POOL, OR WILDCAT Prudhoe Bay - Sad]erochit Pool I1 SEC., T., R., Ai. (BOT'TOM HOL,E OBJECT~ Sec ll, TION, R15E 12 PI~:G'VIIT NO 76-73 13.REPORT TOTAL DEPTH AT END OF MONTH, CtiA~NGES IN HOLE SIZE, CASING AND CL-MF~TIHG JOBS INCLUDING DEPTH SET AND VOLUMES USED. PER¥ORATIONS, T~$TS AND I~ESULTS FISHING JOl~ JLrNK LNI HOLE AND SlDE-T~CKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONI)ITIONS Spudded well @ 0200 hrs 10-21-76. Drld 17½" hole to 2750'. Cond hole for csg. Ran 71 jts 13-3/8" 72# MN-80 butt csg w/shoe @ 2708', FC @ 2626'. Cmtd w/5321 sx Permafrost II cmt, slurry 14.8 ppg, displ w/326 bbls mud. ND BOPE~& cmtd top 13-3/8" x 20" anul w/183 sx Permafrost II cmt, slurry 15.0 ppg, displ thru 1" pipe from surface. NU wellhead & 13-3/8" BOPE. Press tstd rams & Hydril. Drld FC @ 2626', tstd csg to 1500 psi, drld cmt, shoe & 10' new formation. Test form to 0.65 gradient OK. Drld 12¼" hole to 2800'. PU Dyna drill. RIH, orient & drld to 3566'. Trip & drld ahead to 4544'. Trip PU Dyna drill. RIH. Orient tool & drld to 4870'. Trip, PU BHA. RIH. Drld to 6919'. As of October 31, drld 12¼" hole to 7460'. 14. I hereby certif . , ~,,~.~ / NOTE--Report on this form is required for each calendar month% regardless of the status of operations, and must I~ filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month, unless Otherwise directed. 02~1B '~ STATE of ALASKA DEPART~qENT OF N^TU~AL RESOURCES Division of Oil and Gas Conservation Director FROM: Thru- Lonnie C. Smith Petroleum Engineer, ~ef Ben LeNorman Petroleum Inspector DATE -' October 29 t97F, · . SUBJECT: BOPE Test, Arco DS ~ o October 23, 1976~ Saturday - Departed my hm~e at 5:30 /~M for a 6:00 AM showup and a 7-00 A~q departure via ~en Flight #23 to Deadhorse Arrived Deadhorse via Fairbanks at 9:35 AM. I caught a ride with Shorty Allen and Bill Clanton to Drill Site #3 where t met ~ith Buck Rice, ~Arco drilling foreman, and Red Adams, Rowan Rig #35 toolpusher. It appeared a top job would be needed and tests would not begin until late that night or early the next morning. Temperature +16* F, light snow, light ~ind. Due to the BOPE test delay I caught a ride with Gil Meyer to the topping plant where I had talks with production personnel, the subject of a separate report. October 24, 1976, Sunday - Tests began at 12:45 ~ Both sets pipe rams, ~.i~-wing--wl~s anti-check valve on the kill line a~d two wing valves on the choke line tested to 5000 psig. However, the .annular preventer would not test. Drill pipe was removed from the test plug and the blind rams tested to 5000 psig. Steaming of the annular preventer began to effect closure. ~,ttempts to test the hydril failed and by 5:.00 A~ it was decided the packing element and seals would have to be replaced. In the intedrim the temperature dropped 36 degrees to -20° F. Tests resumed at 12:05 PMo llwelve valves and forty-eight flanges in the choke manifold tested to 5000 psig. The manual adjustable choke was free moving and the Swaco automatic choke was actuated to both fully opened and fully closed positions. While awaiting drill pipe to be screwed back into the test plug, we toured the location which was well organized, reserve pit well built, steel welded fuel tanks not bermed, rig in good repair, and vmll sign not yet received from Anchorage. Accumulator pressure was 2900 psi§. N2 back. up bottles tested 2500, 2450, 2500, 2450, !300 and 2000 psig. Both dart and ball type floor valves were on the floor. At 1:40 PM, .iust as we were about to test the hydril, a wing valve on the spool suddenly started leaking, so replacement.was initiated. Tests resumed at 3-45 PM with the hydril testing to 3000 psig. Kelly cock, kelly and lower kelly valve tested to 5000 psig and tests were concluded at 4:~.0 PM. 1976 H. Ham1] ton -2- AFteld Inspection Report was~p~pared w!~ ~e original got~ to Buck Rtce, a copy to Bob Htnes, and a copy attached to thls report, t~ then awatted a call fro~ Alan~Leske, BP drj111ng ~glneer, ~rdJr~ ~tnessing an SSS¥ test on thetr Well F-5 ~Ich ls the subject of a separate report.. October 25, 1976..,. ,Mo~- Arrtv~ at BP operations at.6:~ P~ and learned t'he"sSsV WO.uld-be 'teste Tuesday morn~, ~tober 26th October 26, 1976~ TuesdaJ~.._- Witnessed testing of SSSV on BP lF-:§: .~parted ~}ea~h~e' vta'"BP' cha~ at 3:05 pr4, arriving tn Anchorage at 4:~ ~ and at my home at 5:05 P~. In sua~ary, ! witnessed successful BOPE test at Arco's '~ 3-8. Attachment ~~ ...... ~ . .,.~,.~ ~,,, ~.¥..-, ............... ~ield Inspec~on Report ' Operator ~~ . :'"".';:;:;-, Represented '~y' ~.~-.; -- ';.~' .Name:: & Num~er;~;fcD'~-~ '~' Yes No 'Ite~ (~oc~¢ion,Gener, 1 '--'Yes No Ieem];<(~BOPE;.TeSts '. ~'~ II ' (~ ( ) 2. ~ener~l Housekeeping (~ ( ) 1~. Test f'/uid,( (~ ( ) 3. Reserve Pi¢-( )open( )filled (~ ( ) 17. Hester Hyd.~C'ontrol (~ ( ) ~. Rig (~. ( ) 18. N2 b¢ls~-~-~9~~~sig ( ) S~fe¢7 V,lve Tests (~ ( ) 10. Remote Controls . ( ) ( ) ~. Surf, ce-No. Wells (~ ( ) 20.-Drilling sp°ol, (..) ( ) ~. Subsurface-No. Wells (~ ( ) 21'~ Kill Line-(.~Check. v~]ve-.. ( ) Hell Test D~¢a (~ ( ) 82. Choke F1o~11ne ( ) HCR'v~lve ( ) ( ) 7. Well 'NOS. , , , (~ ( ) 23. Choke Manifold No~ val.vs~flgs.~..'.. ( ) ( ) 8. Hrs. obser ~ (~' ( ) 24 Chokes-(~emote( )PQs.(~dj'.. ( ) ( ) 9. BS&W , ,__, -:'~' (~ ( ) 25. Test Plug-(")Wellhd(~sg(' )'none:. ( ) ( ) 10. Gr. Bbls. , , , (~ ( ) 26. Annular Preventer,~o~sig ( ) Final A~andonment (~ ( ) 27. Blind Rams~psig ( ) ( ) 11. P&A Marker (~() 28. Pipe Rams~mm~psig ( ) ( ) 12. Water well-( )capped( )plugged (~ ( ) 29. Kelly & Kelly-coc~~psig ( ) ( ) 13. Clean-up (~ ( ) 30. Lower Kelly valve~psig ( ) ( ) 14. Pad leveled (~ ( ) 31 Safety Floor valves-(~V..(~af.t Total inspection observation time ~ hrs/d~ Total number leaks and/or equip, failures .~'. Remarks ~ -. cc- ~';~ F? ~/,^~'~,'~ Notify in days or when ready September 22, lC~76 Re: Prudhoe Bay OS 3-8 (31-t5-10-15) B. P. Alaska, Inc. State Permit No. 76-73 P. R. dudd District Orl 1ling Engineer B. P. Alaska, Inc. P. O. Box Anchorage, Alaska 0ear Si r: Enclosed Is the approved application for permit to drill the above referenced ~ell at a locatlon In Section 15, Township 10~, Range 15E, U.Pi. tde11 samples, core chips and a mud log are not required. A directional survey Is required. Hany rivers in Alaska and their drainage syst~ have been classtftod as Important for the spawnt~ or migration of anadromous fish. Operat!ons in these areas are subj~ect to AS 16.50.870 ~ the regulations pro~ealgated thereunder (Tltle 5, Alaska Administrative Code). Prior to ~nclng operations you may be contacted by the Habitat Coordt~tor~s off~ce, Depart- ment of Fish and Game. Pollutlon of any waters of the State is prohibited by AS: /~6, Chapter 03, Arttcle 7 and the regulations promulgated there~ander (Title 18, Alaska Admlnlstratlve Code, Chapter 70) and by t~ Federal ~ter Pollution Control Act, as amended. Prior to commencing operations you may ~ contacted by a representative of the Department of £nvlronm Ia! Conservatl~. Pursuant to AS 38./~0, Local Hire Under State Leases, the Alaska Department of Labor Is being notified of the Issuance of this ~-rmlt 'to drill. To aid us in scheduling field work, we would appreciate your ~tifylng this office within q8 hours after the well is spudded. 't4e ~id also like to be notified so that a representative of the Olvtsi~ may be present to witness testlng of blc~ut preventer equipment before surface, casing shoe is drilled. P. R. dudd -2- Septe~r 22, 1976 In the event of suspens'ton or abandoruaent please give thts off~'ce adequate advance notification so that we may have a w~t~ss present. Very truly yours, Hoyle H. Haml I ton I~eeber Alaska 011 and Gas Conservatl°n C.~ittee Enclosure CC: Department of Fish and Game, Habitat Section w/o ~1. Department of 'Envlro~eental Conservation W/o encl. Department of Labor, Supervisor, Lair La~ C~llanee rOlVl$1on W/O enct. September 13, 1976 Mr. Hoyl e Hami 1 ton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99504 Subject: Drill Site 3-8 (31-15-10-15) Prudhoe Bay Field Dear Mr. Hamilton' We have reviewed a copy of BP Alaska, Incorporated's Application for Permit to Drill the subject well from a surface location of 1199'N and 837'E of the SW cr Sec 11, TION, R15E, UPM to an 8800' subsea target 1320'S and 1320'W of the NE cr, Sec 15, TION, R15E, UPM. We understand the well is projected to be 1512' west of Atlantic Richfield Company's lease ADL 28332 at TD. Atlantic Richfield Company being the affected operator as per Paragraph 22. 050, Title II, Part 3 of the Alaska Admin- istrative Code, has no objection to the drilling of this well. Very truly yours, C. R. Knowles .. District Drilling Engineer CRK/jw Form 10-401' REV, 1-1-71 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN SUBMIT IN TRIPLICATF (Other instructions on , reverse side) DEEPEN r-'l. la. TYPE OF WORK DRILL [] b. TYPE OF WELL Oil, GAS SINGLE MULTIPLE r--I WELL ~ WELL [~ OTHER ZONE F=l ZONE I I 2. NAME OF OPERATOR BP Alaska, Incorporated 3. ADDRESS OF OPERAI OR P. O. Box 4-1379, Anchorage, Alaska 99509 4.LOCATION OF WELl. At surface _ l199'N & 837'E of SW cr Sec ll, TION,"R15E, UM At proposed prod. zone lq?(l'q and lq?n,w n~ N~ ~, qe~ l~ Tln~ v!Sr UN ]3. DIS'I:A~.E"IN ~,'~ILI(S AND l~[~l:."~.'qVlok' l:l).~o.~I N'E'~"'RE~'~"TO~'O'~ P~S~ 'oFI~I&E~'' ' " '- ' Well Site 5 miles N'E of Deadhorse, Alaska No. 50-029-20231 $. 6. L,EASE DESIGNATION AND SERIAL NO. ADL 28331 7.IF INDIAN, ALLO'ITEE OR TRIBE NAME 8, UNIT FARM OR LEASE NAbtE Prudhoe Bay 9, WELL NO. DS 3-8 (31-15-10-15) 10. FIELD AND POOL, OR WILDCAT ~rudhoe Bay - Sadlerochit Pool 11. SEC., T., R., M., (BOTTOM IIOLE OBJECTIVE) .~ Sec 15, TION, R15~ 14. BOND INFORMATION: T~EStatewi de 8039-1192 Surety and/or No. . * ~oun, '. $100,0001 O0 15. DISTANCE FROM ['ROI~'OSED * LOCATION TO NEAItFSI' PROPERTY OR LEASE LINE, FT. (Also to nearest drig, umL if any) 1320' 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST V,'ELL DRILLING, COMPLETED, OR APPI. IED FOR, FT. g600' (DS 16. No. OF ACRES IN LEASE · ' 2560' 19. PROPOSED DEPTH 1 O, 500' MD .17.NO.ACRES ASSIGNED TO TillS WELL 320 20. ROTARY OR CABLE TOOLS Rotary : 3-7) 21. ELEVATIONS (Show whether DF, RI', CR, etc.) 22. APPROX. DATE WORK WILL START 61' RKB, 28' Pad Elevation OctOber 15, 1976 23. PROPOSED CASING AND CEMENTING PROGRAM ' SIZE OF tlOLE SIZE OF' CASING WE1OIIT PER FOOT GRADE sL'TTING DEPTIt Quantity of cement 20" 20" 94#" H'40" 80'"' Circ to surf approx 350 sx PF · . · 17½" 13'3/'8" 72# MN-80 2700' Cir.c. to surf a~prox 5500 sx PF 1.2~" .. 925/8".. 47# MN-80 10,500.' 1st stg w/appr~ 1'000 sx Class ........ &S00-95 2nd .qtg w/approx 300 sx PF ',C" BP Alaska, Inc., proposes to' directionally drill this well to IO,500'MD, 9336'TVD to produce the Sadlerochit zone. Dual Induction Laterology, Self Potential, Sonic, Gamma Ray, Density, Caliper and Neutron logs will be run from TD to 8500'MD. 20-3/4" 2000 psi Hydril BOP will be used on the 20" conductor. A 13-5/8" 5000 psi Hydril, two 13-5/8" 5000 psi pipe rams and one blind ram will be used on the 13-3/8" and 9-5/8" casing.. The. BOP equipment will be pressure tested weekly and operationally tested each trip. A non- freezing fluid will be left in all uncemented annuli within the permafrost interval. A single 5½" tubing string, packer, and appropriate subsurface safety equipment will be run in a weighted calcium chloride solution. The tubing will be dlsplaced to the top of the packer wi th diesel. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on. present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measmed and true vertical depths. Give blowout preventer program. 24. 1 hereby certify that ibc Foregoinz is l'ruc and Correct DAm September 16,. 1976 ~TLESeniOr Drilling~ Engineer (This space for State office usc) I SAMPLES AND CORE ClllPS REQUIRED I ~ v~s ~ NO DIRECTIONAL SURVEY REQUIRED I~1 yES [] ~o CONDITIONS OF APPROVAL. IF ANY: MUD LOG [] yes I~1 NO OTIIER RFQL IREMENTS: A.P.I. NUMERICAL CODE 50-029-20231 76.-.73 APPROVAL DATE, [ ~Po~'ED'BY' ~'f-'~4 J~/'~,' ,~,~~>~--~'~/--" TITLE' Member . !~':!' · ...... ~ -c~, !-[;~'/ ' *See Instruction On Reverse Side September 22, 1976 ..... DATE ,,, September 22, 1976 ~ 664' · ...---- 688' ------- 713' .a..--- 7:38' ,,------- 83 AL.,~,UILT WELL No. ] LAT. 70© LO N G. 148© WELL LAT. LONG. WELL LAT. LONG. WELL LAT. LONG. 'NELL LAT. LONG. 14'01.509" Y 5 938 074.68 16' 22,773" X 71 3 903.'73 No. 2 70© 14' 00.393" Y 5 937 961.93 148© 16' 22.066" X 713 9:3 I 25 No. :5 70°13' 59.238" Y 5 937 845.28 148016' 21.335" X 713959.73 No. 4 70°13' 58.085" Y 5 9:37 728.76 148°16' 20.610 X 713 988.01 No. 5 WELL No. 6 LAT. LONG. WELL No. 7 LAT. 70°i3' 54.620 LONG. 148° 16' 18.428 Y 5 937 378 2'6 x [ 14 073.C7 WELL No. 8 LAT. 70'""~3' 53.4.70 Y 5 0~7 ,262.50 LONG. 148<: ,3 iT.T01 X ?!4 101.'%7 lO II 15 14 CERTIFICATE OF SURVEYOR I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE .LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY -ME OR UNDER MY SUPERVIStON, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. APRIL 25~ 1976 DATE OF SURVEY SURVEYOR NOTE 0 EXISTING WELL OR CONDUCTOR PIPE ARCO No. HVL No. 34-D$3--76 ATLANTIC RICHFIELD CO. AS BUILT DRILL SITE No. 3 WELLS No. 4, 7 8 LOCATED IN PROTRACTED SECTION II,T.!ON., R.15E.~U.M. PREPARED BY HEWITT V. LOUNSBURY & ASSOC. 723 W. 6J-h AVE.~ ANCHORAGE~ ALASKA DATE MAY 5~ 1976 · SCALE : 300' CHKD. BY G.D.D. FIELD BK LOOSE LEAF RLC £HECK LIST FOR ~iEi.! WELL PERi-tITS I-s the permit fee attached . Is well te be located in a defined pool Company Yes rio P, ema rks Lease & Well ~Io. ~_~ :,_ Is a registered survey plat attached ~:. Is ',-;'ell located oroo~r. , ~ distance from proper~"v.~ line 3. Is ;..'ell located proper distance from other wells . :. Is sufficient undedicated acreage available in th~s pool ?_ Is ',.,'ell to be de,,,iated . ~- Is operator the only affected party ::'. Can permit be appreved before ten-day wait . . Does operator have a bond in force ]. Is a conservation order needed 7. Is administrative approval needed 3. Is conductor string provided ......... Is enoueh cement used to c~rculate on conductor and surface . $. Will cement tie ~n surface and intermediate or production strings 6_ Will cement cover all kno',.,'n productive horizons . . 7. Will surface casing protect fresh water zones . . 3. Will all casing give adequate safety in collapse, tension & burst 9_ Does BOPE have sufficient pressure ratin~,~:7~~ .~./)~' *~? ~.~(~.~.c~'s!~. ~.pproval Recommenc~J' Geel oav Enaineerina' TRY, H!iK ,.~,/~ ~' OKG HHH J AL L C S .... ?~'ii' J CM Revised 1/15/75 .- 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 APPEN. DIXi No special'effort has been made to chronologically organize this category of information. The Basic Information Tape (BIT) is a binary, partially multi- plexed tape containing up to 20 data c~rves. The data samples are r~presen~ed~ as ._tBb[, 50-bit. floating point numbers. The lape consists of a 276 byte heading record folio;~'ed by a series of data records ¥;hose length is de¢in~d in ~n~ heading record. The last data record .is followed by t~,o end-of-files. The tapes are D trac]t, 800 bits per inch. The heading record contains the information necessary to recover the curve data from the data records and some identification information. 1 The Epilog Computation C~l~er (fCC) number is a unique number assigned at one of the Dresser Comouter Centers. Any questions regarding the.data should, if possible, include this number. 2. Company name - Well name. These are free format fields used to identify the well. The n'm-nber of curves (N) is designated as a 16 bit binary inte=~r ntimb=r This number mu~t be ~ess than or eoual to 20. It gives the number of curves of data that will be in t?~e data records. 4. Curve names. Each Curve is designated by a 4 character name. A list of Dresser Atlas standard names is given in the appendix. ?hese names appear in the order in which the data a,~ea_rs in the data record. 5 'fh~ starzin~ and enaing .epth g~ve~ the first depth for which there is data on the rape and the iasz d~p~n respect- ively, h~hen ~he szar~ing depth is smaller than the end- ~.g~, depth t~e ..... data ~s recorded downward · With fie~d data, the ending depth may be smaller since the da~ta is recormed zzom t~e bottom o~ ~ne well u~ward. ~ne er~d~ng ~ . depth may be given as 0 or 99999 when ~t is 'not known du'~ing ~ecording; this occurs on BIT tapes recorded in tLe field. · .,_.~,ve! Spacing (L). Th~s field designates the d~pth incze- ;~ent between %k,e data samples. The daze samples are taken at zegu!a~!y spaced depth i~czements. · ~,u er oz ~anpi~s (F) ~nis zie!d gives the ~umber of sam- plea oz each curve recordem in each-~a~a record, inis nu:,:~,er will be ~,,~ss t~an or equal to i25. D A T A ii !~ C 0 ~ D S The samples in the data records are recorded as floating point members (iBM standard). This consists of a sign bit, 7 bit exponent and a 24 bit mantissa .normalized to the neares.t 4 bits. ' sign bit. mantissa The exponent'.is biased by 40 . Thus, 4110000.0 represents the number !.0. ~ ~ : ~ The data record consists of N '~ F · 4 bytes of data where N is the number of curves and F is the .number of samples of each C!fi YV e . The first F samples in the record will-be of curve 1, the next F samples w~ be o~ curve ? eta Each record will contain data for F . L feet of data, where L is the level spacing. The cuzrent standard usage at Dresser data center is Level spacing = L = .S feet Samples per record = F = 125 'f?:us each record re~resents 62.5 ~eet of data. These numbers are g-iven as an example only, however, since L and F may vary f~:om tal, e to tape, and will certainly be different for BIT tapes recorded in the field. D~T[ 10- 6- 77 FILE DATA SPECIFICATIONS (ConTinued) EXHIBII_~L_- Page.~ 1 of FILE NAME I FILE NAt4E 2 APPL I CAI-I Ok FILE RU~4 B ER IDEN']'IFICAtlOH ] FIELD ~B FIELD1 POSI 710R ].0 FIELD DESOR IP'TI ON HEADER RECORD o£ each curve Eoi]o~ Comnutation Number Comoanv Name . l,~ Il Name Number of Curves on tape Fi!2er Tape starting de~th Tape ending denth Data level smac~n~ De~th Column (=0) 11 Filler 12 .,umber o sam~)!es Der record 13 Yil2er STAR7 85 165 t67 169- 247 251 255 259 261 263 267 CHAR- NO. ACTEg- OF SlOP I SiICS DECII4ALS 4 FP 84 I ] 64 AN [ ! 246. AN 250 FP 254 FP 258 FP I 260 !NT~ 262 266 5P 276 NC OF BY BASIC INFORMATION TAPE CURVE SPECIFICATIONS FILE 2 Company Well Field County, State Atlantic Richfield Company Drill Site 3 No.8 (42-15-10-15) Prudhoe Bay North Slop~, Alaska Date 4- 3- 7 9 Curve Name (Abbreviation) Standard Curve Name Log Used ScaleandUnits 1.125-1.625 0.837-1.087 0.9-1.9 CO 1 (SI 1 SCA ] . . SI CO 2 (SI 2 _S_L_ 2 Carbon./OX%gen Ratio (Runl) Ca__l c i u_m/S i 1 i.c o. n/Ne 1 as t i c (Ru SiliconZCalcium Capture (Run Silicon (l__un 1) Carbon/Oxygen Ratio (Run2.) (al cium/Silicon/Nelastic. (Ru __.S_Lli_cDzL~_C_aJ3zixzm_C2p t~ r e (RUn P~AT Ratio Curve G 1 Gate One _G_ ....... :2:_ ...... Gate Two .. Continuous C/O Log hi)Continuous C/O Lo 1)ContinuouS.C/O Log Continuous C/O Log Continuous C/O Log ~2)Continuous 'C/o Lo ~LCLomffAnuou$ C/O Log Continuous C/O Log Dual Detector Neutron Lifetime Lo Dual Detector Neutron Lifetime Lo 10.8-4:8 (CPM) 1.125-1.62S 0.75-1.0 0.95-1.95 10,8-4,8. (CPM) ,.._.SO-lO (7,_Sigma U~ 17.25-7.25 Dual Detector Neutron Lifetime Lo 0-120 Dual Detector Neutron Lifetime Lo 0-20 Dual Detector Neutron Lifetime Lo Dual Detector Neutron_Lifetime Lo 0-100 (CPM) (APl Unit Dual Detector Neutron Lifetime Lo~ 50-10 Dual Detector Dual Detector ~Lem&r~m l,ifetime 1,o~ 50-__10 ~_Sjgma_lJ~ Dual Detector Neutron Lifetime Lo 50-10 (Sigma 50-10 (Sigma_Un (Sigma U__~r. (Si ~m__a Ur its) s) its) its) its) its) its) LIBRARY TAPE CURVE SPECIFICATIONS Company Arco Oil ~ Gas Well DS 3- 8 Field Prudhoe Bay County,State North Slope, Alaska Date 3-16-81 Curve Name (Abbreviated) Standard Curve Name Logs Used Scale NL7 Sigma ' DNLL 50-10 NL6 Sigma ,,, " " NL5 Sigma DNLL 50-10 NL4 Si.gma " " NL3 Sigma " " NL2. Sigma DNLL S0-10 NL1 Sigma DNLL S0-10 NLL Sigma Average " S0-10 R7 Ratio " 9--1 ,, :~6 Ratio DNLL 9--1 R5 Ratio : " 12-2 R4 Ratio " 12-2 ., R3 Ratio " 12-2 R2 Ratio DNLL ,, R1 Ratio DNLL 12-2 , , · . A7 Gate 1 DNLL 0-21.43 A6 Gate 1 DNLL 0-21.43 A5 Gate 1 DNLL 0-17.14 .-. A4 Gate 1 DNLL. ,, A3 Gate 1 " " LIBRARY TAPE CURVE SPECIFICATIONS Company Arco Oil ~ Gas Well DS 3- 8 Field Prudhoe Bay County,State North Sloper Alaska Date 5-16-81 Curve Name (Abbreviated) Standard Curve Name Logs Used Scale A2 Gate 1 DNLL 0-17.14 A1 Gate 1 " ,, B7 Gate 2 " 0-3.57 ,, B6 Gate 2 " ,, B5 Gate 2 DNLL 0-2.86, B4 Gate 2 DNLL ,, B3 Gate 2 DNLL ,, ,. , B2 Gate 2 " 0-2.86 B1 Gate 2 DNLL 0-2.86 -GR7 .Gamma Ray " 0-100 GR6 Gamma Ray " 0-100 GR5 Gamma Ray " 0-100 GR4 Gamma Ray " 0-100 GR3 Gamma Ray " 0-100 GR2 Gamma Ray " 0-100 GR1 Gamma Ray " 0-100 LIBRARY TAPE CURVE SPECIFICATIONS Company Arco Oil &Gas Well DS 3-8 Field Prudhoe Bay ~ County,State North Slope, Alaska 3-19-81 Date CurVe Name (Abbreviated) Standard Curve Name Logs Used Scale NL1 ..... Sigma DNLL _,, 50-10 NL2 Sigma DNLL 50-10 NL3 Sigma DNLL 50-10 NL4 Sigma DNLL S0-10 NL5 Sigma DNLL S0-10 Ri, R~tio ... DNLL 9--1 R2 Ratio ..... DNLL.,, 9-,-.1 R3 Ratio DNLL 9--1 -'R4 Ratio DNLL ' 9--1 R5 Ratio DNLL 9--1 Gll Ga~.e I DNLL ...... 0-33.3 G12 Gate I DNLL 0-55.5 G13 Gate I DNLL 0-55.5 G14 Gate I DNLL 0-55.5 Gl______5 Gate 1 ........ DNLL 0-33.3 G21 Cate 2 DNLL 0-S.S · . G22 Gate 2 DNLL 0-5.5 LIBRARY TAPE CURVE SPECIFICATIONS Company Arco Oil & Gas Well DS 3-8 Field Prudhoe Bay ~ County,State North Slope, Alaska Date 3-19-81 Curve Name ~'~ (Abbreviated) Standard Curve Name Logs Used Scale G23 Gate 2 DNLL 0-5.5 G24 Gate 2 DNLL 0-5.5 ,. G25 Gate 2 DNLL 0-5.5 , , ,. , - ,,, GR1 Gamma Ray DNLL 0-100 GR2 Gamma Ray DNLL 0-100 GR3 Gamma Ray DNLL 0-100 GR4 Gamma Ray DNLL 0-100 GR5 Gamma Ray DNLL 0-100 , --. -- .- · , .., · . ECc NUMBER ~707'00 ARCO oIL AND GAS ORiLL~i SITE: 3'-8 NLi NL2 NL3 NL~ NL5 NL6 NL7 NLL' FRoM 9BO0.O0 TO 10210.00 · LE:VELi ~PAC~NG 0,5000 125, SAMPLES PER RECORD .... ARCO O ZL AND sAS DRILL SITE 3'8 DATA EVERY I SA LES 9401,00 9401.50 9402,00 ~402,50 9403.00 9403.50 .940~, O0 940~.50 9405,00 940~,50 940~,00 940G.50 .. 9~07.00 9~07',50 9qO~.O0 9408,50 9409.00 9q09.50 ~410.00 9~10.50 9~11.00 9q11'§0 9ql~oO0 9~12o50 9q13.00 9~13'.50 9~1~o50 9~15.00 9415.50 941G,00 g41G.~O g417,00 9417,50 941~,00' 941~.§0 9419,00 9419,50 9~20.00 g420,50 9421.00 9421,50 g422,00 9422.50 g42~,00 942~.50 942~,00 9422,50 9425.00 NL1 31.75 30.53 30,11 30.59 29,61 29',~2.~ 30.08 30,08 29.56 29.07 28,79~ 2~.65~ 28,52 27.98 28.39 29.05 2~,83 30,28 30,33 29.77 29,1.8 28.5G 29.66 29,2~ 2~.71 29,~3 29,97~ 30.~7 29',6~ 29.33. 29,16 28,57' 28,22 28,35~ 28,34 28,64 28.76 30.82 31.91 32.49 32.92 32.87 31.93 30.78 31.56 31.85 32.05 31.72 32,38 32.85 33.04 NL2 29.81 30.56 30.03 30.09 30.41 30.30 28,7~ 29'01 29.77 29:.9~ 30,24 30.40 29.43 29.30 30.03 30,7~ 31.66 32'46 31.05 31.07 31.73 32.~1 32'~0 32.09 32.~9 32'88 31.~G 31.90 30.32 27,93 27',37' 27'77 28.23 30-06 30.29 29,82 30.~5 31.17 30.61 29.6~ 29.80 30.23 29.2~ 29.77 30.42 30.88 29.46 30.21 31.09 31.01 31.31 ~L3 0.00 0.00 0.00 0.00 0.00 0,00 0.00 0.00 31'13 30.5~ 30,35 29',91 ~9.49 29.62 30.79' 31.11 30.0!. 27,78 29.07 ~9.91 30.67 31.18 31.48 31.g~ 31.58 31.66 31.96 ~0.88 30.46 31.59 32,39 32.39 32.66 32,75 31.~ 31.08 30.71 30.55 30.34 30.77 31.00 31.10 31.53 31.46 31.52 31.56 ~0.64 30.83 30.53 11.89 MLg 0.00 0.00 0.00 0.00 0,00 0.00 0.00 0.00 30,39 30.95 30.55 30,72 30.66 30.34 29.65 ~9.33 29.54 30'0~ 30.26 29.29 29,27 30.06 30.37' 30,0~. 29.59 29,45 29.09 29.~7 29.51. 30.00 30,0~ 30,0~ 29.71 29,12 29.35 29.19 29.18 29.86 30.14 30.2~ 31.~1 31.70 31.97 32.23 32.30 32.22 31.7~ 32.21 32.33 32.87 NL5 0.00 0,00 0.00 0.00 0,00 0-00 0,00 0,00 0.00 0.00 0.00 0,00 0.00 0.00 29,50 29,31 30.11, 30'50 30.58 31.02 31,35 30.69 30,~0 30,4~ 29,97 29.77 28.63 28.29 28,~0 27.98 28.00 27"97 27'.&5 28,59 29,26 28,99 29.20 29,67 30,73 31.11 31.~9 31.82 31.81 31,1~ 30.12 29.~2 29.63 30.16 30,44 30.68 29.40 NL6 31,19 31.44 30.90 ~1.45 30.90 31.50 31.16 30,89 30.05 29,95 30°20 28.4~ 30-g2 30'80 30.55 30.61 30,6~' ~0.73 ~0.~ 29.91 30.13 29.98 30.29 30o9~ 30.69 30,58 ~9.92' ~9.58 ~9,73 29,87 ~9.~2 29.91 30,59 31.4~ 31.70 31,96 32.05 31.79 31.lB 31.52 32,05 31.70 31.79 32.31 32.78 NL7 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0,00 0,00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2.55 27.18 28.30 28.71 28,87 28,~0 28'56 28.15 28.35 ?8.05 28.08 28.9~ 29.~2 29.12 28.58 28.0~ 28,08 28.55' 28.92 28.91 28.63 28.85 29.61 30.10 30.35 30.75 31.16 30.97 30.59 30.~! 30.01 30.02 NLL 0,00 0,00 0,00 0.00 0.00 0.00 0.00 0,00 29.77' 29.9% 30.2~ 29'91 29.~3 29.30 29.50 29.31.' 29.83 30,28 30.33 29,77' 29.91 29,91 29,77' 29,97' 30.29 ?9.63' 29.33 29,16 29.42 29.12 29.12 29.35 29.1~ 29.20 29.~1 30,55 ~Oo~k 31.~1 31.70 31.21 31.18 31.1. B 3!.52 31.56 ~0.6~ 31.0~ 31.01 31.~9 PAGE 2 ARCO OIL AND GAS R ! LL;' ~':IT E: 3- 8 [DATA EVERY 1 SAMPLES e eS.so 9~26.00 9~27,00 · 9~27,50 9428. oo 9428.50 9429.00 9429.50 · 9430,00 9430,50 9431,00 9431'50. 4432'00 9~32.,50 9~3~,50 9434°00 9~3~,50 9435,0O 9435,5O 9436,00 9436,50 9437.00 9437.50 9438,00 · 9438,§0 9439'00 9439,$0 9440,00 9440'B0 9441,00 9441,§0 9442.00 9442.50 9~43,00 9443,§0 9~44.00 944~,§0 944~.00 944~.§0 9446,00 g~4G,~O 9447'00 9447,50 944~.00 94~,~0 9~49,00 9449,§0 94§0,00 9450.50 NLi UL2 . ~L 3 33.~2 30.7~ 31.31 32,88 31,85 30.69 31'15" 30.99' 31,05 30,50 30,~9 ~1,~ 29,18 31,30' 29,07 31.G2 30.56 30.20 ~4.19 ~1,37 29,86 33,05 3~.00 30.22 ~2.87 3R,43 30.7'0 51.08 32,41 29.09 31,~3 32.41 28.13 31.81 31,14 27.90 311.44! 30,11 29'85 30,07 31.~0 31'27 29,47 30,89 31'58 28.89 30.18 31.91 ~8,22 29,38 3~,',08 28,17 29.58 521,09 27,84 29,07 31'50 29,79 29,39 31,~I 30,34 29,12 30,83 30,51' 29,28 32'2~ 29,5~ 30,86 32,59' 29,03 30,59 32,01 29,47 30,08 29.22 29.~4 31'85 28.65 29'.03 ~l'O& 27,27 29.37 3~.75~ 27.17 27.~7 3'1.~6 28,23 .27'.~2 3[,20 28,99 26-86 31,11 29'67' 26.~0 50,95 30,33 26,89 3[,2~ 28,75 27'~ 31.71 27,61' 28.95 32~09 27.97 29'69 32,5! 27.61 29,47 31,27 28,68 30.28 ~0.74 29,17 30.9~ 30.03 28.60 31.69 28.62 29.08 32.21 ~8.81 28.92 32,56 ~9.04 29,18 31.75 28.25 29,63 $0,73 ~8.59 28.71 30.26 50.40 29.57 29.01 50.69 ~0.16 29.16 50.63 30,03 29.2% 50.69 30.34 29.10 ~i.27 30.?3 29.29 ~1.8I ~L~ 32.77' 52.50 31.98 ~2.15 ~2.15 32.42 ~2.56 31.93 31.~4 31.~0 31.5~ 31.§1 ~0.9§ 30.93 ~0.13 ~9.1g 28.66 ~9.1~ 28.94, 29.221 28.78 28.62 29,78 30.~9 30,44 30.69 30.68 30.83 31.~8 31.43 31.03 30.88 30.50 29,97 29,85 29,87 29,B5 2g.~5 29.81 30,49 30,~1 31,12 30,86 30.50 30.21 NL5 29.92 30.3~ 30.76 30.8q 30.75 30.90 30.66 30.78 30.6~ 30.81 31.60 32-00 32.13 31,57 31-57 31'76 32.50 32, O~ 3I'52 3~,80 31,30 30.62 29.70 29.91' 30,~5 30,62 30,85 30,21 30,43 30.3~ 30,59 30o1! 29,72 29.30 29,21 29.~7 ~0.06 30.~7 50.29 ~0.~ 30.03 30.00 30.~9 31.35 31.04 31.07 31.32 31.25 ~L6 32.36 3~.26 3~.~0 ~.SG 32.66 31.91 31,57 30.79 30.82 50.92 3!.72 B1.70 29.86~ 30.9~ 30,82 31,09 30.82 31,09 31,28 32,~5 32.76 3~.90 3~'~7' 30.88 31.09 30.~1 29.56 29.88 30.~6 31.25: ~1.72 30.99 ~0.5~ 29.97 ~9.88 30.~0 ~0.57 50.52 ~0.07 ~9.95 30.97 31.76 31.71 ~1.?0 31.%% NL7 50.~3 30,57 ~0.29 $0.78 31.23 31.54 51,63 ~1.27 30.85' 30.~ ~0.38 ~9.68 ~9.28 29.~7 29.87 ~0.35 30.08 29.16 27.73 28.7~ 29'23 29,80 30,02 29.6~ 29,59 29.62 28.~7 28,65 27.83 27.07 26.56 26.77 27.~8 28.28 28.93 ~9.51 ~9,96 29,90 ~9,38 29,09 28.7~ 29.10 29.94 ~0.38 30.13 ~9.73 30.22 30.96 ~1,11 NLL 31.31 31.85 31.G2 31.57 31,gl 30.85' 31.58 31,4%. ~0.89 31.23 3n.29 ~0,~5 30,0~ 29,07 29.79~ 30,51 50.86 30.59 29.70 ~0,~5~ 50.3! 29,55~ 29,88 30.~$ 30,59' ~0,11 29,72 29,~9 29.51 ~9.87 ~9.85 29.~5 ~0.~0 30.5! 30.G~ 30.9~ DRILL SITE DATA EVERY ARCO OZL AND 3-8 I SA~PL'ES NL1 NL2 NL3 NL4 NL5 NLG NL7 9451.00 30.01 29,2~ 32.91 30.31 30,7t 31.55 31.00 9451.50 29.48 31.2~ 33.41 30.93 30.65 31.81 31.32 ~52.00 29.74 32.33 33,03 30.82 30.84 31.42 31.76 9~52.50 50.18 52.76 32.64 30.~3 30,50 30.&3 51.69 9~53,00 31,01 30,88 32,77 30.75 30,~2 30,86 31,75 9~5t,50 31.&7 51,02 32.52 30.~2 30.~G ~0.~5 B1.79 9~5~.00 32.20 50.93 32.85 30.10 30,05 30.18 31.~8 9~5~,50 32.25 29.50 3~,2~ 29.~2 29,63 30,30 31,50 9~55,00 32,07 30.07 31,58 ~9.72 29.10 ~9,91 tl.42 9~55o50 32,24 30.83 50,98 29,65 28,62 30,64 t1,07 9~5~,00 32.19 31.26 30,50 t0.00 28,47 31,06 30,66 9~56,50 31,86 32.11 50,51 29.69 28,81 31,57 30.37' 9~57'.00 31,26 31.66 29.86 28.90 29,25 31,66 30,52. 9~57.50 30.~4 31.96 29,98 28.88 29,84 31,70 31.06 9~58,00 29,75 32.79 50,66 29,28 50,01 51,23 31,6~ 9~58.50 30.06 31.73 31.56 28.88 30.37 30.83 30.83 9~59,00 30.42 30.88 30.~7 28.88 30.O& 3~.69 29.96 9~59,50 30.93 30.85 30,15 29,13 29.60 30,09 28,83 9~60.00 30.02 30,21 30,78 28,~§ 2~.B9 ~9,~7 28.99 9460.50 29.16 28.64 ~O.lO 28.12 27.66 ~7.82 ~9,22 9461,00 2~.98 27.33 29,81 ~8.12' 26,83 26,~5 29,15 9461.50 25.09 25.15 2B,79 27.52 25,38 25.51 28.78 9~62.50 21.72 22,05 25,39 23.97 21'.67 21.34 25.71 9463.00 22.24 22.~S 24..08 22.3$ 22-~8 19.17 2~.50 9463.50 22,70 22.64 aa.,~3' 21.~0 22,93 18,57 946~.00 22.36 22.26 al.55 20.72 22.16 17,78 20.10 9~6~o50 2~.72 21.58 21.69 ~0.98 21,~1 18.19 ~8.96 9465.00 22,85 21.05 19.82 20.77 20,38 19.25 17.99 9~65.50 21,50 20.51 20,62 20.0~ 19,90 19.B0 17.37 946&.00 19,96 20.99 19-63 19.80 20.t5 19,95 16.68 94&~.50 19.20 19.75 20.9~ 18.73 20.82 lg.5'0 16.31 9~67.00 19.24 18.92 21.~0 1~.08 20.65 18.~0 16.98 9467,50 20.06 17.t9 ~0.90 18.56 ~0.~8 18.R1 17,57 9468.00 20.33 16.92 20,0~ 20.~8 20.06 17.99 17.66 9468.50 20.47 17,28 20.15 22.00 19.7~ 18.19 18.19 9~6g.00 19.99 20.~1. ~0.51 22.77 19.97 17.92 1R.~1 9469.50 20.35 20.98 20.92 21.6~ 20.GG 15.23 18.09 9470°00 20.67 20.83 ~.34 21.09 21,10 19.87 17.11 9~70.5~ ~0.01 20.~5 ~.02 21.20 ~0.5~ ~0.~1 16.19 9~71,00 19.83 21.30 19,67 21,~0 19,88 ~0.81 9471,50 20.10 21,77 19,67 ~1.&6 19.60 20.37 15.62 9472.00 20.09 22,~3 19,99 ~0.65 20.16 19,91 I~.B9 9~7~,50 20,85 22,3~ 20.3~ 19,66 21,35 ~0,~9 1~,19 947~,00 20,t9 2~,~0 ~0,11 19,~8 ~2,~1 9~73',50 20,70 20,51 18,98 19,~1 22,36 ~0,53 15.7! 9~74,00 21,24 21.99 19,64 19,92 22,67 1R,89 16,02 9~7~,50 21e27 21,50 20,09 19,9B 22,75 17,32 17,03 9~75,00 22,1.6 22,~ 19.~3 ~0.75 23,50 17,~0 9~75,50 20,~2 23.01 19.3~ ~1.93 2~,12 17,72 17.9~ 9~76,00 20.05 23.57' 21.69 22.19 24,61 17.64 ~8.35 NLL 30,73 31.2~; 30.6t 30.88 30.95 30,30 30.07' 30,83 50,6~, 30.37 ~0,5~ 30,4~ 30.66~ 30.83 30.~ 30.09 29.37' 27,33' ~5,51' 22.05' 22.~ 21,55 ~!.~l 20,3~ 20,0~ 19,95 ],9.50 !~.9~ la.~l 20.0~ 19.7~ 19,99 20.GG 20.83 1,9.88 20.10 ~0.09 ~0.49 ~n.39 PO,SI 19,92 ~0.09 ~0.75 ~0.12 ~.6~ ~._~_._ ARCO DRILL SITE 3-8 DATA EVERY 1 OIL AND SAMPLES NL1 NL2 NL3 NL~ NL'5 9%7&.50 20.79 23.70 22.99 21.93 25.07 9477°00 21.22 24.68 23;50 21.59 25.65 9%77'50 21.70 25,56 23'25 21.2G 25.13 9%78.00 20.72 22.70 23.67 20.83 23.37 9%78.50 19.~5 22.58 25;69 21.67 22,36 9%79.00 19,11 21.89' 2.5'61 21.51 22..~8 9%7q.50 18.65 21.92' 23,17 21.27 21.73 9480.00 18.82 21.30 22.69 20.65 21°01 9480,50 18.~9 20.88 21,25 Y0.27 20,~7 9~81.00 17.79 21.03 19,9! 20.79 20.11 9481.50 19.20 21.36 ~I'.78 20.52 20.50 9~82.00 20.50 18.87' 22,06 20.73 20.50 9~82,50 21,51 19.52; 22.02 20.51 21.25 9%85.00 20.27 19.99 ~.80 19.92 21,70 9~83.50 20.50 20.05 21.12 19,52 21.5~ 9~8~.00 20.6~ 21.00 20.11 19.00 21o51 9~8~.50 22,53 22.38 20.$3 18.71 22.03 9~85.00 22.05 25.~3 ~0.66: 18.92' 21.57 9q85.50 22.2' 22.85 22,56 19.~8 21.0~ 9~8~.00 21.81 21 90 22~ 76 20 08 21 66 ' . · 9~8&.50 21.63 18.88 21,95 19,85 22.17 9q87.00 22.65 19.56 21.53 20.7~ 23.13 9~87,50 21.%6 20.5% 21.26 20.81 25.66 9~88.00 21.81 19.89 21.~$ 20.17 2~.17 9~88.50 22.03 18.9~ 21'~5 19.58 2~.21 9~89.00 21.1~ 18.21. 21.~5 19.38 23'57' 9~89.50 20.66 20.82 20.87 19.~2.' 2~.~7 9~90.00 21.~9 21.89 20.19 19.65 22,12 9~90.50 22.18 22.05 18.05 19.38 21'96 9~91.00 23.03 21.95 18.58 19.%0 22,18 9~el,50 22,73 20.08 18.25 20.~5 2#°56 9~92.00 20.95 20.70 18.61 21,56 25.16 9~92.50 20.61 21.~3 19.76 21.70 25.78 9~9~.00 19.56 20.9" ~.0.57' 21.98 25.07 9~93.50 20.63 21.33 22,18 22.16 2~.70 9~9~.00 21.07 21.8~ 23'.62 21.90 25.&2 9~9~.50 20.15 22.03 2~.~2 22.29 25.79 9~95.00 21,26 21.27 22.69 21.89 9~95,50 21,65 19.37' 20.66 al,lO 2#.~5 9~96.00 22.20 20.~1 19.58 20.53 2~.98 9~96.50 22,76 21,93 18.99 21.~7 2~.96 9~97.00 22.98 22.83 18.5~ 20.87 2~.16 9~97.50 22.~ 25.~8 18.~2 20.12 9~98,00 22.15 27.11 19.15 20.05 23.51 9~98.50 23.38 25.19 20.81 19.~6 22.63 9~99,00 2~.08 23.32 21.35 20.83 22.22 9~99.50 23.55 2~.58 20.26 20.70 22.90 17,63 18'12 18.15 20.77' 21,51' 22,16 ~1,55 19,25 19:,70 18.75 17,77' · 17'~7 17-90 19,36 19,67 19:,21 19.87 20.~9 21.12 20,82 20.~2 20.03 19'78 20,0~ 20.17 · 20,79 20,96 21,1~ 20,95 21.70 22.15 20.~7 20,~0 20,59 20.52 29.66 20,20 19.52 18.22 17.91 18,98 19.38 19.99 NL7 18.50 18.~0 18.58 17.51 17.66 18.11 17.80 17.2~ 18.05 17,9q 18.01 18.17 18,1~ 17.78 17.75 17.03 17.07 15'91 15,~1 1~.73 15,61 15.92 15,28 15.32 15.3~ 15.85 15,37 15,~2 15.58 16.28 17'21 17.62 17.28 16.9~ 17.~8 18.5~ 18,65 18.90 19.38 19.59 19.22 18.57 19.Gl 21.25 21.~1 ~0.77 20.0~ NLL 21.93: 21,59' 21'70 a0,83 21.67' 21.89 21,55~ 20.63 20.27' 20.11' 20.30 20.50 20.51 ~9.99' 20.05' 20.11 20.33 20.68, 21.0~ 21.65' 20,46 20.7G 21,12 20.82 20.~2: 20.03 20.6~ 20.19' 20.17' 20.79 20,65 20.95 20,95 20.9% 22.13 21.8~ 21.27 20. ~6 20.53 21.~7 20.87 20.12 21.25 21.~1 21.~5 20.70 ) ) ECC NUMBER ~707.00 ARcO OZL~.AND GAS.' DRILL;~ SITE )-0 CURVES B2 B,3 B~ B5 FROM 94.00.00 TO 10210-00 LE{~'EL~ SPACING O' 5000 125' SAMPLES PER RECORD R3 R5 R6 D R I L L !' S I T E DATA EVERY ARCO OIL' AND 5'8 1 SAMPLES 9400 · 50 9401, O0 9401.50 9~02,00 9'402,50 9~03.00 9404-00 9404,50 94.05,00 9~05.50 9406,00 9406,50 9407.00 9407,50 9408,00 9408,50 94~09,00 9409,50 94 ! 0 · 00 9410-50 9411,00 9'411,50 ~412.00 9412.50 941~'00 941~.50 ~414.00 9414.50 9415- O0 9415.50 9416,00 9~16,50 9~17.00 9417o50 9~18,00 94~8,50 9419,00 9419,50 9~20,00 ~420,50 ~421.00 9421,50 9422.00 9422,50 942~,00 942~.50 9924,00 9424,50 9425.00 B1; 0.65: 0.67' 0,73: 0.69 0'70 0.71 0.69 0,731 0.72~ 0'74~ 0,83 0-80 0,92: 0.95.. 0.99~ 1,15~ 1.20 0.99~ 0'90 0.82 ~0,81 ~0.75 0,89' 0.81 0.85 0.82 0.91 0.78 0.71 0.75 0,92: 0.95 1.10 l.l~ 1.19 1.15 1.05. 0.89 0.83 0.74 0.68 0.62 0,65 0.73 0.78 0.6~ 0.65 0,70 0,71 0.64 0.60 82 0.62. 0.60 0.57' 0.55 0.56. 0.62 0.67 O. 6~ 0'61 0.59 0.61' 0.61 0.65 0.72 0.73 0,68 0.61 0.60 0.~I' 0-59: 0.53~ 0.52; 0.51 0,48 0.~7 0. 0.51 0.52 0.58 0.68 O' 81 0.86 0.79 O. 64 0.55 0.58 0,59 0.53 0.50 0,59 0,68 0.60 0,59 0.57 0.59 0.5~ 0.62 0.58 0.46 0.49 0.51 GA S 3 0.42 0.39 0.~7' 0.50 0.59 O.G1 0.67 0.60 0.62 0.68 0'81 0,?~ 0.75 0.70 0,70 0.63 0.60 0.55 0.57 0.55 0,55 0.55 0.57 0.52 0.52 0.57 0.57 0.58 0,65 0.71 · . 0.7~ 0.75 0,67 0.64 0.68 oi. 67 0.62 0.59 0.56 0.57 0.59 0.59 0.51 0.53 0.59 0.61 0,59 0.50 0.58 0.59 0.76 0.68 0.68 0.66 0.62 O.G! 0.62 0.69 0.72 0.73 0.73 0.81 0.96 0-98 0,89 0,8~ 0.8~ O,B1 0.87 0,83 0.85 0,77 0,76 0.82 0.86 0.86 0.92 1.04 1.08 1.01 1.0~ 1.00 0.77 0.67 0.60 0.69 0,65 0,76 0.82 0,81 0,76 0.64 0.6~ 0,65 0,6~ 0,67 0.68 0,66 0.61 0.59 95' 0.77 0.85 0,9~ 0,90 0,93 0,87 0,82 0,81 0,77 0.70 0,64 0,71 0.75 0,90 0,99 0,91 1.01 0.gB 1.09 1.22 1.1~ 1,07 1,08 1.11 0.82 0.74 O.GB 0,67 O.GB 0,67 0.71 O.Bg 0.87 0.86 0.81 0.77 0.80 0,83 0.8~ 0.78 0.74 0,67 0.65 0.67 0,65 0.66 0.68 0.67 0.70 0.69 0.66 0-85 0,89 0,97 1- 09 1,14 1- 28 1,23 1'18 1,29 1.26 1,17' 1'08 1,22 1,31 1, 1'1,7 1.32 1.51 1.~9 1.~3 1.63 1'62. 1.45 1.37 1,17 l'41 1.52 1.54 1,42 1'32 1,42 1,~6 1, 55 1,57 1.82 1,89 1.83 1,78 1,52 1,~0 1.25 1.21 1.10 1.05 ! .~_1 87 0,67 0,69 0,69 0.72 0,77 0,7~ 0,7~ 0.68 0,72 0,74 0.76 0.82 0.83 0.73 0,74 0.78 0.70 0.72' 0.Sa 0.93 1,07 1.04 0.97 0.88 0.82 0.77 0,75 0.76 0.79 0.79 0.75 0.79 0.72 0.71 0.74 0,89 0,93 0,91 0,91 0,98 0.90 0.84 0,77 0.76 0.70 0.67 0,67 0.G9 0,71 0,7~ RI 5.59' 5.66 5.50 5.37 5.37 5.27 5.20 5.27 5.?~ 5,33 5.31 5.37' 5.35 5.32 5.25 5,11 5.05~ 5,11 5,07 5.1~ 5.~1 5.27 5.35~ 5,q0 5,39 5, ~6 5.22 5.05 5.1& 5,~7 5.~1 5,11 4.9~ 4.81 ~,90 ~,97 5.07 5.15 5.20 5.1.3 5,06 5,13 5,28 5,~ 5,~ 5.31 5,~0 5.55 5'91 5,95 6,21 5,7k~ 5,71 5,73 5,64- 5,60 5,78 5,93 6.0~ :6, !. 0 5,9~ 5,79 5.59 5.4!. 5.39 5. 5,5~ 5.7~ 5,80 5,95 5,77 5.91 6,01 G. Og 5,~.5 = 73 5,91 5,85 5.60 5.50 5,55 5,5~ ~ 7~ 5.91 G.O~ 6.01 5,99 6,0~ 6.07 ~ 99 6.06 G.1G 6.0~ 5.82 5.~G 5.77 R3 G,49 G.O4 5.86 5,95 6,17 6,30 6,30 G,11 5.87 5,79 5.78 5.8~ 5,79 5.7~ 5.82 5.86 5.79 5.72 5.59 5.68 5,76 5.Bq 6.00 6.0~ 5,60 5.60 5.38 5.15 5.11 5.11 5.17 5.27 5.~ 5,59 5,~ 5,~ 5.53 5.66 5.~1 5.97 5.91 5.95 6.05 6.03 5.~7 5,5~ 5,63 ~.71. 5.80 5,59 5, fi5 5,62 5,62 5.52 5, 52 5,53 5.60 5,69 5,70 5,91 5.72 5.77 5.83 5' 90 5.99 5.98 5. ~7 ~.7~ 5.6,3 ~,~ . 5,46 5,39 F,30 5,29 5.32 5,~7 5.51 '~,51 5,72 =.90 ~.0! ~., 1.1 r'.97 =.94 P5 5.59 5.53 5,58 5,~ 5,~ ~ 57 5.57 5.~ 5,~2 :: 71 5.5~ 5,5~ 5.~3 5.~2 ,~ . .. 5,1~ 5.05 5.02 5.10 q.99 ~.97 ~.95 5,15 5,28 5.4.8 5.~2 5.46 5.62 5.60 5.57 5.78 5,~9 &.!.~ 6.~6 6.32 5,$7 5.49 ~.~7 3.20 2,9~ 2,9a P,~.q P,Tq ?,8~ 2.~0 P.Ga 2.64 ~.qq 2, q. 7 .... 2.71 ~.7!. 2.72 ?.6~ p. SV P.~g 2.an P.5= .. P.57 R7 ~.n7 . ; ~.q9 ...... - ~.95 ~.~0 2 . 75 3.~0 2,89 2.n7 2.79 ~.~5 2.75 2.4t PAGE 2 ARCO; OIL AND GAS DR ILL ~"ITE~ 3-8 DATA EVERy' ! SAMPLES. ¢ 2 -50 0.53 o. S 0. 1 0.57 0.66 1.1 0.86 9~26'00 0,52 0.52 0,41 0,57· 0,62 1,31 0.86 9~26'50 0,56 0.~0 0.~0 0.5~i 0.65 1'11 0.82 · 9~27'00 0.61 0.%5 0.44 0.53 0.6~ 1,07 0.79 9~27',50 0.65 0.~6~ 0.~9 0.56 0.68 1.19 0.79 9~28.00 0.65 0.4.7' 0.50 0,60 0.62 1.11 0.76 9~28.50 0.64 0.55': 01'50 0.66 0.66 i;.20 0.73 9~29,00 0,68 0.63~ 0.~8 0.58 0.65 1.19 0.67 9~29,50 0.65 0.53: 0.45 0.58 0.73 1-17' 0.63 9430,00 0,62 O.~T 0,45 0,6~ 0.79 1.0~ 0.56 9~30.50 0,59 0.%9 0'51 0.75 0.72 1.04 0.57 9431.00 0.56 0.50 0.5~ 0.86. 0.77 0'85 9~31,50 0,55 0.56 0.54 0.87 0.90 0.85 0.57 9432,00 0.58 0-59' 0.58 0.83 0.82 0.91 0.61 9~32,50 0,64 0,5~:' 0,58 0,82; 0.8% 1,09 0.70 9433,00 0,73 0.52~ 0.51 0,76 0.86 1"!2 0,82 94~3,50 0,80 0,59 0'50 0,76 0,82 1,26 0,79 .. 943~,00 '0,85 0,61: 0,48 0,80 0,76 1'28 0,7~ 946~,50 0,86 0.551 0,~5 0,88 0.73 1.30 0.66 9q35'00 0,89 0.62:~ 0.49 0.81 0,79 1"11 0.70 9435.50 0.93 0.62' 0.52 0.78~ 0.77 1,06 0.88 9~36.00 0.95 0.59 0.58 0.75~ 0.69 1.16 0.87 9436,50 0,85~ 0.67' 0.57 0.70 0.72 1.35 0.81 9~$7,00 0,82: 0.62 0.52 0.67 0.80 1'~2' 0.7~ 9~37.50 0.8~ 0.5%: 0.56 0.65 0.82 1.28 0.69 94~8.00 0,88 0.55 0,56' 0.63 0.81 1'18 0.72 9~38,50 0,9'0 0.53 0.53 0.65~ 0.80 1'19 0.7~ 9~39,00 0.81 0"52' 0~.49 0,62 0.79 1.85 0.72 9:~39,5;0 0,75 0.54~ 0.48 0,62' 0,85 1.23 0.72 9440.00 0.80 0.60 0.47 0.69 0.86 1,13 0.7~ . 9~40,50 0,95 0.65: 0,50 0,71 0,90 1,09 0.77 9~1,00 0,97 0.69: 0.60 0.71' 0.87 1.22 0.80 9~41.50 0,90 0.68 0.69 0,79 0.86 1,32 0.83 9442.00 0,85' 0.64 0.67 0.83 0.7~ 1.32 0.89 9~42.50 0.79 0.69 0.67 0.81 0.78 1'18 0.94 9~43,00 0,75 0,65: 0.73 0.84 0,73 1.35 0,98 9~43,50 0,81 0.58 0.76 0.82 0.68 1.%2 0,93 9~.00 0.90 0.62 0.65 0.76 0.72 1.~8 0.82 9~44,50 0,95 0.67' 0,60 0.82 0.81 1'.4~ 0.73 9445,00 0,95 0.66: 0.61 0.84 0.73 1.~2 0.72 9~45.50 0.93 0.63 0.60 0.78 0.81 1.~1 0.7~ 9446,00 0,93 0.54 0.61 0.78 0.85 1.35 0.70 9446.50 0,90 0,~8 0.59 0.79 0.82 1.25 0.65 9447,00 0,90 0.~7 0.51 O,BO 0,86 1.3~ 0.75 9~47.50 0.9t 0.53 0.48 0,80 0.87 1.~2 0.82 9448,00 0,90 0,56 0,~7 0,82 0,83 1,3% 0,85 9~48,50 0.87 0.52 0.44 0.89 0.88 1.31 0.8~ 9449.00 0.83 0.62 0.~2 0.95 1.00 1.q5 0.81 9~49,50 0.83 0.62 0.~0 0,89 0.93 1.~9 0.83 9450.00 0,82 0.60 0.~8 0.82 0.84 1.~5 0.86 9~50.50 0,76 0.60 0.53 0.81 0.79 1.~$ 0.91 R1 5.70 5.6% 5.63 5.79 5.87 5.9~ 6.09 6.26 5.5% : 30 5.31 5.39 5.45 5.46: 5.5B 5.4.7_ 5.23 5.11 5.15 5.1.2 5,05: 4.97 5.04 5,17 5.aa 5.30 5.23 5.30 5.35 5.26 5.2% 5.31 5.25 5.23 5,42 ~.~9 5,37 5.37 5.~2 5.50 5.52 5.~9 5.49 5.59 R2 5.90 6.02 6.3? 6.16 6.19 6.31 5.98 5.97 6.09 6,11 5.65 5.7? 5.87 5.81 5.90 6.05 5,78 5.9~ 5.81 5.64 5.49 5.51 5.66 5.75 5.76 5.64 5.78 5.6~ 5.54 5.~3 6.01 6.15 6.1~ 5.a~ 5.71. 5.85 5.99 5.7~ 5.~ 5.66 5.81 5.70 5.49 5.45 5.54 5.~3 5.9~ 5.85 ~3 5.95 6.06 6.16 6.25 5.99 5.81 5.76 5.80 5.84 5.93 5.90 5.84 5.77' 5.80 5.79 5.~6 5.91 5.~ 5.77 5.6~ 5.68 5,67 5.75 5,56 5.~1 5.42 5.56 5.7~ 5.~1 5.95 5.92 5.~8 5.96 5.B7 5.80 5 5.67 5.59 5.62 5.71 5.57 5.~5 5.41 5.'+7 5.57 5.S5 5.86 ~.0~ 6.~2 ~.01 5.92 ~.02 5.05 5.~0 ~.75 ~.55 ~,...:7 5.76 =' 73 5'75 ~,76 5.90 g. O2 5,9q ~.~0 = 76 :.70 ~.~0 e =.67 = ~7 . 5.q7 =,~ 5.55 5,61 5.6~ 5,75 5.77 ~ ~70 5.6~ 5.65 ~ ~5 5,67 5.S6 5.65 5.5~ 5.~7 5.55 : 62 ~.00 5.75 5.S6 5.57 5,76 ~.5~ 5.~9 5.2.2 5 . 27 5.31 5.~1 5.1.8 : 10 · -~ . ~.~0 5.72 5.72 5.GO 5, ~8 5,~ P6 P.65 P.7! 2.P, 1 3.04 2.7~ P.7~ 2.9~ ~.04 2.~0 2.92 ?.7~ 2.eO P.TM 2.74 ?.6~ ?.51 ~.~9 ~.7~ 7.79 -- · ~.7~ 2.6° ~.7~ ~.7~ 9.7! ~7 ~,~7 ~, ~7 '~ 04 ~.31 3,19, 3,16 3.09 ?,~7 2.gO 2.75 .. .' ~ 2.7~ ~ .75 ., ARCO OIL AND GAS DRILL, SITE 3'8 . DATA EVERY' 1 SAMpLEs 9%51,00 9%51.50 9%52,00 9%52,50 9%53, O0 9%53,50 .._ 9%5~,00 9'~5~,50 9%55.00 9%55- 50 9~.56. O0 9%5&,50 9%57.00 9~%57.50 9458,00 9458.50 9~59,00 9~59.50 9'460· O0 9'460;,, 50 9'461,00 9'461.50 9462,00 9462,50 9~+63.00 9463.50 9~6~, 50 9465,00 9465.50 9'466, O0 9466.50 9467'. 00 9467, 50 9468. O0 9468.50 9'469.00 9470.00 9'470.50 9'471,00 9'471.50 9'472.00 9'472,50 9~73.00 9'473.50 9'474.00 9'475.00 9'475,50 9~76.00 0.83 0,86 0,83 0.81' 0,75 0,67' 0.66' 0.65 0.631 .62 0.64 0.67' 0.71 0.77 0,78 0,67 0.57 0.53 0,5! 0.54 0.59 0,61 0.67 0.78; 0,86 0.91 0.91 0.84 0,82 0.91: 0.96 0.96 0.93 0.86 0.83 0.86 0,87 0.82 0.74 0.73 0,76 0.78 0.78 0.80 0.83 0,87 0.87' 0.80 0.80 0.86 0.69 0,66 0,55; 0,52 0.59 0.52 0.~+9 O. 54. 0. G 3 :' 0,52. 0.51 0,51 0.53' O, 52: 0.45' O. ~+~+ O. 38 0,35~ 0.39~ 0. '43 O. 50' 0.63: O. 63: 0.62: 0.60: 0.59 0,67' 0.69 0'65 0,63~ 0.60 0'60 0.60 0.63 0,60 0.53 0.55~ 0.58 0.62 0.55' 0.55 0.$2 0.64 0.58 0.5q. 0.60 0.58 0.5'4 0.51 3 0.55~ 0,48 0.54 0,63 0,58 0.58 0,57 0.52 0.56 0,59 0,52 0,51 0.43 0,44: 0.38 0,4~ 0,56 O.&2: 0'69 0.74 0.75 0.83 0,76 0.65 0,62 0.77 0.84 0.77 0,76 0'74 0,80 0.70 0.68 0.67 0.63 0.63 0.68 0.70 0.57 0.61' 0.68 0,60 0.59 0.5~ 0.52 0'48 0.51 0.53 0.55 0.61 0.85 0,92; O. 81 0,76 0,84 0,85 0,85 0.87' 0.87' 0,75 0.73 0.75~ 0.74 0'62 0.52 0,52; 0.53:: 0,57 0,60 0.70 0,77 0'88 0,88 0,89 0,92 0,9~ 0.91 0.91 0,77' 0'82 0.89 0.87 0.88 0,77 0.79 0,73 0.91 0.96 0.96 0.92 0.88 0.80 0.79 0.79 0.82 0,76 0,81 0.83 0.77 0.83 0.88 85 0.78 0.71 0.68 O.G7 0.6~ 0,56 0.50 0.~7 O.q5 0.63 0,67 0,68 0.73 0.82 0.85 0.82 0.83 0,82 0.90 0,90 0.9~ 0,91 0.90 0.82 0.78 0.7'4 0.77 0.82 0.85 0.80 0.7~ 0.70 0,68 0.77 0,84 0.83 0.77 0.71 0.73 0.79 0.88 0.83 0.79 0.95 0.97 1.06 0.99 0.93 O.B5 1.50 1.22 1.15 1.32 1.23' 1.25 1' 32 1.36 1. 1'32 1- 39 1.q7' 1.20 1,18 1-16 1. ~1 1'15 1.12 0,92 1. O0 1.03 0.98 O, 87 1.0'4 1.22 1.~& 1.80 1.94 1,65 1'58 1.55 1.~8 1.60 1.52 1.%! 1.5~ 1.65 1.&6 1.~ 1.60 1.~ 87 0.78 0.73 0,70 0.66 0.66 0.67 0.65 0.67 0.68 0,67 0.62 0,63 0.69 0.76 0.71 0.67 0.66 0.69 0.73 0.77 0,84 0.85 0.69 0.58 0.56 0.58 0.62 0.69 0.75 0.80 0.89 0.99 1.05 1.14 1,07 1.00 0.98 0.91 0.81 0.86 0.94 0,86 0.88 0.91 0.96 1.08 1.21 1.1~ 1.21 1.05 1.10 RI 5.66 5,43 5.30 5.29 5.23 5.19 5.29 5.35 5.27 5,30 5.35 5.28 5,10 5.21 5, '49 5,66 5.75 5,68 5,83 5,98 6,07' 6.22 6,'49 6,6:6 6.56 6,09 6.02 5,65 5,62; 5.79 5.59 5.59 5.79 5.89 5.89' 5.97 5.92 5.88 5.6~ 5.61 5.B1 5.96 6.17 6,2~ 5.91 5.91 5.80 5.65 5.6~ 5.63 R2 5.74 5.8~ 5.a. 1 5.7~+ 5.68 5.63 5.83 6.0...8.. 6.2'4. 6,31 6,0~ 6.12 6.29 6.21 5.90 5.8~ 6.70 '7.18 7.q-! 7.59 7.56 6.61 6.69 6.39 5.85 5,94 5.95 5.89 5.90 5.96 5.58 5.80 5.91 6,08 6,23 6.03 6,1~ 6.!.~ &.O~ 5.~6 6.0~ 5.8~. 5.,~6 6.00 6.~2 6.33 6.43 6.53 6.38 5.03 5.90 5.67 5.5P~ 5.67 ~ 76 5.~1 5.75 5.80 5.80 5.B~ 5.95 5.90 6.59 6,72 6.91 6,75 6,54 6.8~+ 6.96 6.57 . 6.07 6.2~ 6.25 6.32 6.31 6.17 G.30 6.17 6.22 ~. 4.7 6.61 6.72 6.71 6.56 5.97 5.87 5.90 ~.0~ ~.lq 6.23 g. O1 5.~7 ~.29 ~', 74 5.28 5.58 ~.7~ ,. O1 ~.74 ~. 77 ' 57 ~,02 ~, 19 ~.~5 ~.q9 ' 70 ~.lO ~.!~ R5 5.67 5.~6 5.8~ 6.0~ 6.~5 6,57 6.82 6,95 7,1! 7,15 7.00 6.97 7.~0 ~.76 = 79 5.~9 99 . 5.9~ 6.00 6.12 6.~0 6.q6 6.72 G.~8 6.64. 6.90 6.73 6.56 6.55 6.46 6.26 2.6g 2.77 ~.76 2.76 2.67 ~ rtl. 2.7~ ~.55 ~.6~ ~.74 7.7~ ~.97 ~. 7~ 2.~& 2.~ ~.3~ 2.~ 0e ~' 2.7Z ?.77 2.7~ 3.05 ~.~5 ~.77 2,60 2.q. 7 2.1.5 ,. 2.1.2 ~.~5 ~.!~ o DATA EVERY' 1 S AMPLES 9~76.50 9477,00 9477.50 9478.00 9N78-50 9q79-00 9479.50 9480,00 · 9480.50 9q81.00 9q81 o 50 9~82.00 9~82'50 9~83,00 9483,50 948~.00 9~8~.50 9485-00 9485'50 9~86,00 9486.50 9~87,00 9q87,50 9q88,00 9~88.50 9~89,00 9489.50 9~90.00 9490.50 9~91.00 9491.50 9~92.00 9~92,50 9~9~.00 9493,50 9q9~.00 9~9~.50 9495.00 9495.50 9~9&.00 9'496,50 9~97.00 9~97.50 9~98,00 9498.50 9499.00 9~99.50 81 82 9~ 0.8~ 0.53: 0-62 0.76 0,53' 0-70 0.76 0.56 0.66 0,80 0,63~ 0,66 0.88 0.59 0,59 0,92 0,57 0,65 0.91 0.61 0.7~ 0.90 0-67' 0.76 0.86 0.70 0.71 o.85 o.61 0.78 0.85 o.5 o.7o 0.89 o.s o.6 0.87 0.74,~ 0.65 0.8~ 0.75: O.6q 0,81 0,8~ 0,6~ 0.78 0.75 0,68 0.80 0,55 0.6'9 0,87' 0,53 0,63 0,88 0,56 0.62 0,83 0,59: 0,69 0,8~ 0,70 0,73 0,86 0.67' 0.78 0.89 0.68 0.83 0.90 0'73 0,71 0,85~ 0,8~ 0.65 O,8q 0,83 0.65 0.86 0.71 0.56 . 0,88 0,63: 0.5'4 0.91 0,60 0.58 0.87' 0.67' 0.61 0,78" 0.66 0.71 0.73 0.~9 0.8~ 0.72 0.72 0,83 0.76 0.71 0,80 0,83 0,67' 0,7~ 0.87' 0,65:~ 0,74 0.90 0.67' 0.72 0.92 0.72; 0°74 0,95' 0,77' 0,71 0,96 0,73 0.68 0.92 0.70 0.65 0,86 0.66 0.6~ 0.80 0.51 0,71 0.81 0,45 0.73 0.83 0.53 0.69 0.79 0.57 0.66 0,7~ 0.60 0.68 0,96 0,96~ 1,02 0.96 0,89' 0.85< 0.95' 0,95 0-88 0.91 0,86~ 0.9t 0.87 0.88 0.88 0,83 0.92' 0 , 91 0 . 86 0.85 0.8~ 0,88 0.99 0.99 0.88 0.82 0.77 0.75 0.78 0.82 0.87 0,8~ 0,81 0.86 0.89 0.88 0.96 1.00 1,05 0.94 0.88 0,90 0.8~ 0.80 0.75 0.74 B5 0.91 0.98 0-94 0-88 0.98 1.08 1.11 0.92 0.76 0.71 0.69 0,76 0-80 0.81 0.9~ 1,OB 0.8~ 0.74 0,64 0.69 0.78 0.79 0.80 0'77 0.7~ 0.77 0-76 0.77 0.80 0.77 0.76 0.83 0.78 0,~1 0.90 0.88 0,86 0,9~ 0.91 0.86 0.97 1.0~ 0.93 0.87 0.89 1.00 1,Oq 86 1, qO 1'37' 1.63 1,65 1. 1.43 1.54 1.55 1.58 1,60 1.50 1.27 1.35 1.50 1.55 ~.~0 1.79 1.66 1.65 1.59 1.55' 1.5q 1.58 1.57 1. :39 1. q. 7 1.~ 1.36 1'37' !. 51 1 ', 72 1.81 1,75 1.68 1,60 1.q7 1 1.55 1.447 1.442 1,56 1.~$ 1.70 1.64 87 0,9~ 0,79 0.71 0,77 0.82 0.91 0.76 0,77 0.82 0.87 0.88 0.94 0.83 0.86 0.88 0,93 0.98 0.99 0.85 0.90 0.99 1.00 1.06 1.11 1.12 1.02 0.91 0.93 0.99 1.04 1.01 1.00 0.gq 0.91 0.96 0.87 O.gq 0,99 1.00 0.78 0.74 0.72 0.88 0.96 0.91 0.76 0.79 R1 5.63 5.61 5.53 5.40 5.52 5.52 5.3q 5.25 5.20 5,3;$ 5,5~ 5,65: 5.72 5.69 5.71 5.67 5,93 6.00 5.88 5.82 5.70 5.56 5.65' 5,~3 5,98 6.0~ 6.1'7 6.2~ ~.09 5.92 6.05~ 6.19 g.07 5,73 5.81 5.91 6,0~ 6.0~ 5.81 5.75 ~.0~ 6,31 6.~7 6.17 R2 6.29 6.30 5.91 5.89 5.95 5.93 5,92 6.2~ 6.37 6.q5 5,99 5,97 5.9~ 6.00 6.11 6,09 6,25 6.03 6.20 6.~1 6. 6.60 6.70 ~.97 S.77 6,66 6.q.~ 6,3.3 6.q9 6.24 G.)5 6.86 6.30 6.qB 6,18 6.06 6.05 g.42 6.~~ 6.5~ 6.25 5.9~ 5.99 5.75 5.88 5.91 5.80 5.66 5.81 5.77 5.87 6,01 ~.~5 6.21 6,!.0 5.70 5.77 5.85 5,92 5,99 &,02 5.87 5.77 5,66 5.9~ 5,9q ~.03 ~,18 5.~2 5.97 5.9q 5.99 6.08 6.11 $.05 6.03 5.95 6.20 ~.35 6.37 6.5q ~.~7 6.92 R5 6,37 6.58 6.5~ 6. ,~,1, 6.70 ~7 6.50 6,30 ~.4-~ 6.~6 6.~7 6 . '~ 6. ~7 6,17 6,2~. ~.~0 6.09 6,!! 6,04 6.30 6.q! 6.~7 6.58 6.~ 6,q3 6,~1 6.70 ~.~8 2,30 2,4.1. 2.3.1. 2.30 2.27 2.35 ~.~7 ~.~6 ,,, . ?.2~ 2.2! 2,25 ?,?~ 2.27 ,...~ 2.gB · o 75 /., . fL ® .... , 2.~,n 2,57 ~. q 7 P,~7 ~.~7 P.~7 2.40 2.~o ?.4~ 2.49 P.~O p. Zl P.qO ) ) NUMBER G?07, O0 ARCO OIL AND,. GAS DRILL SITE: 5-8 [~ CURV'Es : GR~t GR2 GR;5 GR4 GR5 $R6 r. R7 A1 A2' A5 AG A7 FRoM 9400.00 TO 10210.00 LEVEL: sPACING 0.5,000 lp5, SAMPLES PER RECORD PAGE:_I,. ARCO OIL AND SAS DRILL SITE' DATA EVERY.· I SAHPLES 9{+O0, O0 · 9{+00 · 50 9{+~01, O0 9~+01-,50 9'~+02o00 9{+:02,50 9~03,0{3 9~'03,50 9q'04,00 9'+.04.50 9~+05, O0 9'+05,50 91+06.00 91+06,50 9{407,00 91+07- 50 9{+08.50 9{+09, O0 9{+09,50 9{+10. O0 9~+t 0.50 9411,00 9~11,50: 9 ~ 12.00 9~12- 50 9413. O0 9413,50 9~14.00 9~14.50 9415.00 9415.50 9~+16. O0 9~16.50 9417, O0 9q. 17' 50 9~18.0~0 9418.50 9~19- O0 9419,§0 9{+20,00 9420,50 9421,00 9421,50 9422.00 9422,50 9423'50 9424,00 9424,50 9~+25o O0 GR1 GR2 GR3 GR4 $R5 111.01 125.87 120.38 134.63 131.42 107.72 118,29 128.22 117.85 127.54= 110.17 13.1.94 123.31 131.26 119-.91 127.10 107,67 115.26 125-01 131.08 125.91 129.24 104.18 121.5B 125.73 132.62 125,72 127.56~ 104..25 124.95 128.89' 138.77 151~.11 131.79 1011.02 124.07 129.64~: 1~1.06 125'53 1~2.62 102..00 124.14 124.~7 140.09 127.42' 1~6.)3 100.71 128.58 12~.56 130.7) 122.99' 1~5.06 109.80 15~.71 125.~4 I24"00 115'81 129.~4 114.81 1~5.q8 123.27' 119,95 110.82' 119.00 117'67 156.02 122.81 114.91 98.9? 106.55 111.07~ 12~.14,. 104~.98 91.77 99.16 109.~2 133.64 115'74~ 96~,70 95.36 93.66 106..16 !~7.~6 103,11 91':92: 96-22 92.~5 104:,06 88.27 9~",14 101,87' 93.99 97'65 143.63 87'20 98..29 107',15~ 97,~9 97'79 1~6-35 89'84 991,76 106.65 lOG.GO 95'57 88-28 101:.52 109-~1 109.50 94.61 1~0,82 97,25 104,12 110.78 107,~2 92-35 138,79 100,66~ 107'.29 107"1~ 102;.52 89.54 157.22 100.37 103.29 105~05 99.8~ 92.80 100'04 100.61 103';31 100.98 93'49 I05.21 100'36 98.77' 101.86 95'71 103.41 107,80 97.18 ~5'-81 102.70 108.06 100o~7 105o01 91.93 92'38~ 102.~9 119'"25 96.51 100,83 87.82 86.81 97',27 121.62 98-01 98,13 86,,2:1 83,80 92'26 124,97 111.12' 97,46 83,48 83:,13' 88,58 1~{+,,67 120,71 95,~3 78,23 80.56:' 8~.~1 12§'22 121.58 94,00 73:,89 82,76 85.33 129,56 118.12 85,6~ 77'30 88,11 92.58 136,46 11~,1.1 78,7~' 84,39 98,59 96,56 140,75 104.84 77'78 92:,85 107,55 103,85 145:,30 78,78 100,31 109,71 107.50 151,10 105,~1 8~,21 103.:,45 110,34 108.64 161,30 100,15 105,51 113.,16 113.09 155:,15 104,76 107,10 107,86 1~0.17 119,83 150,~8 108,94 111,12 123~47 118,~5 144,45 98,49 107,96 115,93 129"23 129,71 139,28 90,88 109,66 123,39 137,81 141,25 137.82 84,$3 112,74 127.50 141.98 152.76 136,98 83,95 118,66 131,47 143'.26 !52.95 141,18 91,03 121,92 134'91 1{:3.9{+ 150.59 141,24 97,03 1~7,0~ 143.35 14{.07 1~9.26 138.40 99,81 132,50 148,79 135.49 144.01 144,84 115,92 138,08 1~1,28' 132.55 137.98 151,07 143.99 134.69' 132.90 133.65 160.26 117.30 143,31 12B,GI 131.68 132,63 163,37 122,65 143,82 122.67 133.94 136.28 162,16 129,80 139,23 119.98 137.41 134.15 153,80 GR7 123.57 129.46 130,51 131.28 132,04 132.86 132.27 154.86 139.~1 153,10 155,1~ 152.78 149,90 147.01 14!-25' 132,10 128.10 123.53 111.53 110,56 111.96 112,52 122.00 126,16! 127,17 ~20.~7 117,46 115.89 111.94 105.02 100.92 102.41 !0%.73 101.24 104.47' 101.12 109.32 ~16.50 1~8.56 132.22 134.0) 133.49 142.44 141.42 155.73 A1 5.22 5.20 4.98 4.90 5.06 5.07 4.87 4.85~ 5.12 4,99 5.10 5.51 5,75: 6.~0 6.42 6.~4 6.43 5.90 5.77 5.17 5.2~: 5,~7 5.42 5,4) 5,43: 5,40 5.48 6.0~ 6.38 6,67 7.11 7.40 T.OB 5.77 5.49 5.15 4,94 5.09 5.~2 5.4~ 5.~$ 5.13 5.23 5.22 5.OB 4.97 3.63 3.76 3,89 3.93 3.98 3.94 3.90 3.81 3,92 3.92 3,94 3.97 4.41 4.52 ~.~4 4'25 4.07 3.97 4.0~ 4.10 ~.18 4.15 4.18 4.18 4.16 4.1~ 4.71 q.83 4.90 4.85 4.63 4.~5 4.07 5.9q 3,85 3.79 3.81 4.04 3.97 5.~0 3.74 ~.79 4.09 3.93 3.9~ 3.78 3.80 3.86 3.80 3.89 3.96 4.16 4.22 4.26 4,27 4.42 4.73 4.80 4.7~ 4.5B 4.3~ ~.06 3.85 3.73 3,95 3.99 3.79 3,98 4.A6 4.43 4.51 4.7~ 4.89 5.23 5.51 5.29 4,95 4.52 4.12 4.07 4.~.1 ~.04 3.92 4.04 4.02 4.04 4.11 4.17 4.21 4.12 3.92 3.99 3.99 3.72 3.57 ~4 5.26 5. 5.67 5.73 5, 76 5' 44 5.18 6~. 08 5,13 5 . ~G 5.~.1 5.70 = 5.~0 5. ~9 5,62 5' 61 ~. 69 ~.69 6.20 5'37 5. e2 5- nq ~.09 =.?5 = ~2 ~5 5.58 6.1_~ 6.31. 6.!5 5.88 5.~8 5. ~9 5.89 5.53 5.36 5.2q 5.16 5.~e 5,~ 5.5~, 5.70 5.~8 ~.01 6.10 6.35 6,57 6.7~ 6.16 5.59 5.39 5.26 5.2¢,, 5.34 5.5& 5.~7 5.5~ 5.72 5,71 5.54 5.~4 4.97 4.95 ~,90 4.83 4.40 ~.27 4.27 5.10 5.30 5.14 4.95 8.9! ~.9~, 8.8g 8.77 8,52 8.80 8.75 8.89 ~.~5 8.76 8.60 8.65 8.72 8.90 8.99 9.73 9.9! 9.22 8.5q~ 8.?? 8.?~ 9.~9 10.]6 10.3~ 10.23 10.3~ ~.8~ 13.35 ~0.~3 9.7~ o 2P 8.6~ 8.7n A7 ~4.05 4.42 . ~, 5~ 5.04 5.21 ~.~G q.7R 5.~9 .... ~ ~ 5.42 t~ q, 7 ~..~5 5.~ . .... ~.79 ~.~0 5.97 e -. 4 7 m ~..Tn 2AG,~,_~,.~,2, ARCO OIL AND GAS DRILL=. SIT£': 3-8 DATA EV£RY~ 1 SAMPLES GR1 GRA GR3 GR4 9%25.50 131.89 123,%6 138.3~ 142.00 150,31 9426.00 130.31 136.03 158.41 143.91 155'79 9426.50 133'79 I36.81 140.52 148.25 I59.51 9427.00 135.70 135.$I 115.49 151.21 177'.67 9427,50 136.~5 133.~2 148.61 158.62 168.99 9428,00 13~.66 136.69' 115,~8 156.09 170.13 9428,50 13~,0~ 149.65 112,~6 149.89' 156,68 9429,00 1~0,20 1~7.94 141,~9 145,90 153'98 9~29,50 145.48 1~5.21 1%0.83 1~4.91 138,12 9430.00 14~.65 1~.79 1~6.71 1~2.87 109,06 9430.50 143.10 142.11 15~.52 152.5~ 103.24 9431.00 1~0.9~ 142.43 15~.16 162.I3 100.35 9451.50 138.05 14'9.47 15~.05 162.52 88,~0 9432.00 15&.03 l&0.7~ 145!.27 163.80 85.24 9~3~.50 141.1~ 1~0.18 1~5=.09 155.27 943~.00 1~7.~2 153.27 1~.73 142.93 89.11 94~.50 155.35 1~%.28 110.88 127.19 95.09 913~.00 161.04 131.25 104.67 115.26~ 95,28 943~.50 155.~2 118.$0 98.2~ i02.2~~ 97,19 9435.00 1~I.4! 108.12 9~.15 9~.15 100,80 9435.50 127.07 97.54 91.02 92,17 111'03 943&.00 11~.06 89.80 89=.~1 88.~5' 107,28 9436.50 105,02 83.~ 88.85 85.7~' 103.29 9437,00 97, I7' 77.5~ 85.60 86.83: 106-34 9~37.50 69,55~ 76.15 S6.9~ 87.~9 943~.00 85.9& 79.2& 88.51 90.5'0 107.73 9433.50 85,30 81,05 90.19 93.00 109,~1 9439,00 86.78 81.53 95.23 97,97 107,61 9%39.50 89.~5 82.69 101.70 103.75 11~,25 94~0,00 89.21 83.31 108.53 107,34 115~85 94~0.50 89.06: 81.23 107.92 10~.'72 123'29 9441.00 85.74 89.99 103.05 105.09 128.43 ~.50 85.80 96.51 99.92 107,31 131.55 94%~.00 92.69 98.68 100.11 109.68 12%,25 94~2.50 97.72 102.5~ 102.53 111.1% 120.21 9%~].00 98.10 106.42 102,80 115.01 117.69 94~.50 96,25 106.5% 105.87 117.53 117.00 9%4%,00 95.72 10%.51 112.60 116.84 114.66 9%44,50 97.76 103.25 117.~ 117.~5 117.51 9445.00 101.58 105.89 118.96 122.~0 115,85 9%~5.50 103,%6 110.01 115.35 123.15 112.61 9%46.00 105,~1 110.59 111.76 119.16 107.6a 9%%6.~0 105.9~ 112'.23 110.18 118.59 102.~0 9%~7,00 108,16 111.81 112.23 120.~7 97.71 9%47.50 11#.08 115.52 1~0.98 121.85 89.73 9448.00 1~0.0~ 112.~9 106.07 118.56 87.~0 9%%8.50 12~.25 111.62 105.~5 114.27 88,18 9%%9,00 115.67 112.15 104.52 107.17 93.02 9%49.50 11a,89 110.88 100.78 101.72 9%50.00 113,10 110.70 96.55 100.~1 98.12 9450.50 109,80 106.78 90.19 98.14 102.~ 152'07 15~.~5 15~.74 15~.5~ 157'. 99 157. a5 132,62 150.%5 151.72 133'93 135.08 11~..~9 144,73 1611.23 1~6,69 1~4,87' 165'10 168,02 150,15 152,77 17'0.79 174,1~ 178.26 168,51 97.22 122-~5 106.77 99.90 97.3~ 98.85 100.~ 103.49 1.04,60 105,30 105'99 101,54 103,~8 10~,17 109,~3 109,77 110,05 111.90 116,08 118.91 121.09 165,~0 170,79 16,9,16 161.52 157,28 150.37 148.9.6 152,78 152.58 151,61 15'4.. 57 15~.00 161.34 176.01 170.92 170.37 175,~2 176.62 177.9'0 181'67 175,8! 168.68 162.04 152.95 1.36.94 120.06 11'4,93 1,07.72 10'4.16 1.03.4~ 108.17 106.1'4 106.11 183.89 ~02.99 107.51 109.%'4 115.89 119.20 122.26 120'%2 126,68 122.85 131.23 139.82 145.51 147.83 139.27 135.75 A1 4.99 4.95 4.7 B 4.63 4.55: 4.27' ~.10 4.25: 9..76 5.03 4.95 4 5.11 5.59' 5~ 5~. 5.~5 5~ 5.17 5.19 5.0 5.15 5. ~G 5.~G 5.~Y' 5.19 5. !5 5.40 5.5Y 5.5 ~ 5.~9 5.~7 5.49 5.5~ 5.49 5.5~ 5.65 5.69 5.79 5.50 5.55 5.5~ 5.q7 5.50 A2 3,61 3.2G 3.05 3.11 3.22 3,72 3,94 3.~5 3.~x 3.31 3.36 3.~3 3.93 3.9~ 3,90 3'89 3.88 3.80 3.37 3.86 3.97 ~,0~ 3.94 4.00 ~.01 3.9° · 4.03 3.9~ 3.73 3,78 5.82 3.87 4.00 4.15 4,26 4.20 4.08 4.03 4.09 4.16 ~.0~ 4.12 q.lO 3.96 ~ 70 4.00 4.09 3.85 A3 3.55 3.~3 3.28 3.42 3.76 4,06 3.94 3.79 3,77 3,89 3.95 4,00 ~.03 4.05 4.09 4,0~ 4.04 3.96 3,~9 ~,00 3.93 3,87 3.85 3.77 3.8% 3.98 4.05 3.9~ 4.0~ 4.06 ~.1.0 3.99 3.87 3.~9 3.97 4.20 4.25 ~.08 ~.07 4.26 4.40 4.39 64 4 .. ~,~ 4 4.1.2 4-.17 4.70 5. ~.99 ~.73 ~.75 ~. ~7 5' ~9 ~.07 ~.0~ ~7 5,4.6 5. ~7 ~:. ~6 5.2~ : ~ 6 5,71 5.75 F . S6 ~.6~ = 65 5.66 5.71 ~ 72 5.06 5.23 5.~5 5.01 5.07 5.09 5.32 5.~8 5.~ ~ 50 5.5,2 5.55 5.31 ~9 5, 5.~ 5.~5 5.~2 5.~S 5.40 5.4G 5.58 5.~? 5.59 5.55 5.59 5.~9 5.~7 5.84 5.90 5.90 5.0G 5.05 AG 8,69 8.7~ 8.5D 7.~, 7.~ 7.27 7.7G ~.5~ 7.62 ~.03 7.90 8.77 8.76 9,09 9.0~ 9.0~ P.92 .' ~ 9.!5 B.72 B.SK~ P.81 9.67 DRILL SITE DATA EVERY ARCO OIL: AND 3'8 I SAMPLES 9~51,00 9%5! .50 9%52,00 9~52.50 9%53- O0 9%53,50 9 {454 ', 00 9N,5~.50 9{455.00 9~55,50 9%56,00 9~56.50 9{457.00 9%57,50 9~58.00 9%58.50 9%59.00 9%59,50 9%60.00 9%6 .oo 9%61,§0 9{462.00 9%62,50 9{+63.00 9%63.50 9%6~. O0 9{465.00 9'4.65,50 91466.00 9{+66.50 9{+67.00 9{467,50 9~68.00 '9{+68- 50 9{+69,00 9{469,§0 99-70,00 9{+70,50 91+71,00 9%71,50 9472,00 9{472,50 9{+73.00 9473,50 9~+7~+, 50 9{+75,00 9475,50 9476,00 GRI 105.91 102,.~2 98,97 94,09 87,09 80,55 79,98 85,55 91.56 87.89 90,52 97,19 101..16 102'.59 101.52 97'.96 '9~.95 96.76 112.20 119.62 150,93 1~3,03 1%.9,89 151.27 150.{+7 1%8,55 1%7,23 1~7,06 1~7,58 152.76 158,19 162,29 166.76 166.27 160,35 152.38 11+2.40 138.~4 1%5.75 158.51 163,39 156,~5' 151.79 149.82 11+9,79 152.30 11+9,32 1142,52 138,%3 GR2 99,70 97,58 95.18 86,.93 78,52: 79.86: 88,2{4 103.01 98,1B 98.72 102.149 105.32 107.90 109.81 106,7~ 100.79 96.02 '96.03 101.60 107.61 120.67 153:.56 137,77 1~3.'22 11+0.651 137.71+ 137.07 137,3~ 135.86 141,01 149,82 150.2~ 1~6'.71 1{+6.72 1{+7.21 11+0.01 135.53 144.23 160.16 167.91 161.85 152.1~ 1{+5.70 1~5.39 11+5,80 151,10 150,B~ 141,%3 133.20 130,05 86,17 8%,92 87.15 88.98 90.18 91,08. 9{4.08 100.40 106.96 102.79 1014.148 1014.23 100.81 100.37 106.71 109.86 117.57 132.76 151.12 153.%6 1149.91 151.32 1~&.37 155.25 15{4.83 157,%5 160.51 157~.86 1514.56 153.19 150.30 159.79 1514.97 138.83 163.17 169.28 161.99 155.91 15~.90 148.00 1%7.05 1~2.~9 1~1.37 1~9,95 131.63 12~.7~ 125.28 93,&8 90.79 89.2~ 91.02 96.51 100.77 101.97 102.80 108.58 11~.78 113.71 112.80 114.00 115.~5 108.70 108.30 11].48 125.85 135'06 143.36 150.69 158.79 159.36 160.75 160.~5 160.30 158.35 157.6% 161.16 162.59 160.79 158,22 158,~7 159,17 157,79 152,%5 165.98 171.90 175.36 164,72 158.R2 159,8~ 158.63 155.~8 15~,~ 151,~8 146.08 134,61 135.~6 134.50 103.72 108.30 110.09 109.19 107'58 105'56 107,23. 107.77 111.2B 122.71 131.44 1{+3.60 150.04 157,66 159.25 1G2.3G 159,32 159.93 157'99 168,57 165,89 170,11 1714,97 166.83 161.60 157,32 150.97 1~9,20 148,06 150.92 186,76 16B.~9 159.68 157,75 155,{+2 161.31 16~.24 153,50 152,67 147.89 142,~5 139,96 1~0,62 141.10 143,70 151.10 154.32 139,05 136.93 127'27 135;62: 132,97' 131,70 130-17 125'10 119:,99 110,90 10%'34 100,15 109,10 109.07 101o.01 109,00 Ill;lB 111'60 1114-27 11~,31 118.20 117,~5 111+,97 111,~6 115-0~ 1~3,93 159.62. 17~,05 1~6.15 18~.17 1~1.14 170.&7 170.29 173.65 178.02 1~1.~7 179,26 179'~9 175.62 172.06 170.01 175,58 191.23 197.?~ GR7 136,62 136.90 1~3,72 128,29 120,99 117,83 109'16 10~.~6 101.66 t05,9~ 105,95 105,96 105,25 103,6~ 103,38 102,%0 121,27 ]~3.61 118.23 11~,6,0 112.95 1.12.5% 117.95 126,87 140,5% 150,~9 155,83 162.30 166,63 168.80 171.2~ 16~.75 166.92 175.28 180.81 176.92 171.73 169.1~ 171.73 161.55 !85.29 198.43 191.~? 175.78 A1 5.49 5,38 5,45' 5,52 5,59' 5, 5,65 5.61 5,55 5,30 5,30 5,30 5.~3 5' 12. {+ . 99- {+. 63' ~.11 3.71 3,55: 3'54. 3.53: 3,45 3,65 3.9~ ~+.IB 4. ~'7" 4.02 3.8G 3.75 3.61 3,5% 3. 3.31 3,23 3.15 3.11 3.07 3.lB 3.32 ~.~7 ~.~2 .3.72 3.69 3.6% ~ 5B ~ ~9 3.80 g,O~ 4,07 3,95 3.92 5,~5 3,69 3.63 3,63 3,59 3.&5 3,6~ 3,35 2,91 2,71 2.40 ~',5~ 2,~0 2,97 3,10 ~.05 3,04 2,S9 2,90 2,74, 2,~5 2.55 2.51 ~,52 2.51 ~.55 2,~ 2.~1 2.~3 2.~1 2.a~ 2.q~ 2.65 2,F~ 2.7~ 4.4~4 4.32 ~+,30 4 4.13 ~. 31 4.24 4.11 3.98 3.89 3.77 3, ~ 3 3.18 3,05 2.67 2.~5 2,45 3.04 ~.~0 3.20 3.09 2,96 2,72 2.77 ~.~7 2.92 2.98 ~.10 2.85 2.71 2.69 2.91 2.93 2.72 2.61 ?.70 9_.58 2.60 .0.63 2,65 ~.55 2,~7 2. BG ?.~9 3.00 ~4 5,~.3 ~,~6 5,76 5,60 5,a. 4 5'o~ :. 5.~& ~.~7 Z.30 ~0 !,99 ~.!2 '172 z q2 . , Z .~9 . , ~' , , 3,~9 ~ 4,5 . ' 72 A5 5.!2 4.90 ~ ~0 3 . 50 3,53 3.00 3.79 3. ~ 3.5I ~ ~0 3.1& ~ ~6 3.~2 ~.52 5.7 ! ~.~2 ~.~7 4.~5 q. !3 4.05 9.67 c, 1? 9,15 ~ ,77 8.49 S.90 q,45 8.70 8.6!. ~,~5 7.~9 ~ ~0 5.7~ ~.21 6,11 5.70 . ~ · 5.~~ · , ~ . ~ 7 ,,, 4. 7 o 5.~ ~ ~+ 5.00 . 3.Z2 3.t, 5 3,Z7 ~ ~7 3.4Z 'z n ~ :, ~ · ~.~5 ~eTM ~.o? PAGE 4 ARCO OIL AND DRILL ~[T£ 3-8 DATA EVERY I SAMPLES ~A GR1 GR2 GR3 GR4 GR5 GR6 GR7 9476,§0 139,09 128,11 129.00 133,09 130.96 199,06 17'3,06 9477,00 139,75 124-70 13~.16 1,36.09 127.53 180.95 171.37 9177,50 137'71 126.11 135.52 1,39.28 126.17 180,66 1.74,~6 9478,00 135.36 131.77 137.79 141.1.0 141.99 180.60 175.35 9478,50 133,34 133,19 138.55 140.25 140,53 178.56 170.19 9479,00 133,83 156.67 1,36.71 142.G0 140o80 177.~5 167.05 9479.50 13~.65 132,52 1335.26 1,38.84 140.45 173.65 157.44 9480,00 13~,~6 133.94 150.56 13S.42 135.94 174.18 150.57 9~80.50 130.88 126.17 129.332 141.4~ 132.65 1'7~.44 150.~7 9481,00 129.44 123.54 1RB.30 1,39.92 136.24 157.~5 !4'3.96 9481,50 132.15 123.73 12,3.90 1~1.51 157.60 156.1~ 9482,00 131,85 131.41 121,17 139.72 136,56 147,62 1~9.77 9~82.50 130o43 136.27 1~5.18 1~4,9~ 134o88 1~8.56 154.07 9~83,00 128,94 126.75 125.49 132,9'1 126.52 150.93 162.21 9483°50 128,02 128.63 1~2.86 13~,71 124.33 157,4~ 1.60.58 948~,00 129-75 129.24 125.65 131.77 123.71 16~.36 15~,94 9484.50 128,68 121.16 129.55 126.26 110.48 !6~'54 152.91 9485,00 I25.47 119.20 1~7.9! 125.78 104,98 160.42 146.71 9485.50 1~2.58 121.03 1~%.68 13~.61 107'.91 159'~? 143.27 9~8~.00 122.55 125.73 1~.73 135.13 115.4~ 159.56 148.08 948~,50 127,4~ 119.59 I17,54 130.27 116,49 156,45 152.99 9~87.00 131.96 11~.89 111.~9 t2~.56 110.81 155.1~ !5,3.65 9487,50 131,13 111,30 107~.96 123,15 110,45 15~,~1 ~5~.01 9488,00~ 126,90 1131.51 10~.36 119.86 114.79 153.~6 156.30 9~88,50 12~,~7 108.58 107,~7 112,61 119.72 158.65 142.08 9189,00 119,64 100..1~ 108.28 11~.66 117~.27 161,09 1~B.~1 9489.50 11g.75 99.71 109.36 121.99 116-14 155.58 139.50 9490,00 110,0A 105.23 107.77 129.20 112.99 150.10 1~8.21 9'490.50 110.92 108.95 107.05 12~.19 113.78 151.70 !51.07 9191.00 111o8~ 102.11 109.~7 112.36 110.79 151,41 137.2~ 9491.50 114,03 96.11 109.36 106.39 108.53 155.15 ~25.95 949~.00 112.41 96.08 107.99 104.64 110.81 157.07 123.~5 9492,50 105.33 100.82 101.71 106.51 107,72 153.06 122,55 9~9,3,00 102,47 103.22 1~1.89 108.51 107.09 112.95 12~.76 9193.50 102.19 105.67 102.66 107.88 112.59 140.79 1]~.18 9~94,00 102,17 103.64 105.44 105,89 111.9g 136.13 116.68 9494,50 101,95 99.70 102.65 105.72 120.9~ 1~9.~0 9495.00 101,44 98.51 99.00 105.88 12~.04 1~5,§0 128.90 9495,50 102.11 98.32 98.25 104.~0 125.21 136.28 121,34 9~96.00 105.02 96.59 9~.94 !O0.B1 126.~q 110.35 116.37 9496.50 105.41 95.0~ 100.00 98,56 1331.3~ 1533.10 122.55 9197,00 102.42 92.16 101.42 10~.80 13~.93 128.77 122.86 9497,50 98.65 94,80 104.58 108,57 129.86 12A.98 125.58 9~98,00 97.05 97.01 110.88 11,3.90 127.56 124.9~ 127,05 9498.50 100.19 99.78 115.40 116.97 126.6~ 1A7.03 1~4.36 9499.00 102,49 105.11 115.53 122.26 117.96 126.72 122.67 9499,50 106.77 10~.89 122.17 126.26 ~12.80 13~.19 118.63 A1 3.q,B ,5.52 3.65 3,70 `3.60 3.5~ 3.64 3.7'9 3.70 `3.74 3.88 3.86 3.633 3.`38 3.`37 3.5~ 3.6.2 ,3.66 3.69 3.67 3.GG 3.7G `3.8% 3.80 3.72 `3.66 3.59 ,3.GO 3.60 3.52 3.~6 3.G1 3.90 3.~7 33.91 3.95 3.B_;> 3.77 3.65 3,,67 5.12 5.12 3.t9 2.91 2.75 2.80 2.91 2.7'6 ~.77 2.61 2.68 2.87 2.7~ 2.7~ 2.~1 2,7e 2.~6 2.67 2.71 2.76 ~.90 3.01 2.~9 2.7~ 2.67 2.6~ 2.62 2.7~ 2.?4 2.?~ 2.86 e.97 ~.90 2.84 2.74 2.75 ~.78 ~.76 2.75 2.75 2.74 3.12 3,28 `3,08 3.06 2,96 3.0~ 2.99 2,9! ,3,01 2.89 2.59 2.9~ 2,9'~ 2,98 `3,04 3,09 3.24 `3'.24 3.0~ 2.97 2.96 `3.03 ~.9~ 2,82 2.84 2.99 2.98 5.0~ 2.97 2,92 2.82 2,69 ~.~8 2.82 2.89 2.87 2.76 2.72 2.7~ 2.7'`3 2.70 ~.?G 2.73 ~'.93 ~,79 g',75 ~.62 ~.~5' ;~.79 ~,94 ~,~5 ~.~9 3,70 ~'~0 ~'.51 ~,57 5.88 ~'~8 ~.~6 ~.81 5.~8 ~.9~ ~.50 ~.0~ ~.O~ ~.95 ~.~7 Z.67 A5 3.97 ~.96 ~4. O0 ~. ~5 3,99 a,07 g.~l ~.!7 4.01 4.06 ~.~0 q.~2 3.G2 5.7~ 5.7° ~.4~ 5.~1, 6.6:2 G.~G ~o07 6.28 ~.0~ ~.17 5.60 F.~O 5.8! 6. G.~,7 ~.79 6.~1 G.?~ ~AG£ 1 AT~'t~JTIC RI£HFIELD CO.~PA~JY ~ILL1 RAT S!. 9400,00 33,~0 12,16 15,96 1,58 9400,50 32,52 12,07 16.76 1,85 9401,00 32.68 12,21 17.74 1,98 g401,50 32,0G 12,06 18,44 2,23 9407,00 32,09 11,64 1B.7G 2,23 9402,50 32,50 11,42 19.94 2,24 9403,00 33,21 11,33 13.71 2,19 9403.50 33.29 11.50 1~.71 2,~2 ~40~.00 ~2,98 11,73 1~.72 2,15 4404,50 32,24 11,70 19.18 2.21 9405,00 31,94 11,73 19.59 940&.00 31,24 11.56 19.34 2.%0 9406,50 31,&~ 11,51 13.98 2,40 9~07,00 3~.04 11,4~ 19.32 9407,50 32,07 11,57 !9,~6 9408,00 31,51 11,~7 ]9,61 ~,47 9408,50 30,54 11,73 ~0.18 2,59 9409,00 30,97 11,52 20.77 9409.50 31.~0 11.53 21,58 2.78 9410,00 5~,19 11,11 22.34 9410,50 31,99 10.98 ~3,31 9411,00 32.55 10.88 ~3.79 941],50 3~,~0 10,35 ~3.31 2,69 941~.00 3~.24 10.94 21.8~ 94].2.50 32,29 10.97 R{.29 2,45 g~l~,O0 3~,65 11,00 20,50 2.36 ~13,50 33,03 11,12 19.61 ~,26 941,~,00 33,45 11.20 19.~0 2.19 9414.50 33.98 11.33 19.71 2.13 ~15,00 3~,20 11.46 19.7~ 9415,50 ~,26 11,51 19.90 2,20 9416,00 3~.57 11,36 P0.21 ~,3~ 9416,50 51,71 11,09 ?1.~I ~,53 9417,00 ~1,26 10,85 22,05 2,71 9417.50 31,07 lO.G9 ?~.BG 2,91 9~18,00 30,78 10,G& ~3.~7 3.07 9418,50 ~0,55 IO,GB ~,~2 9419,00 29,98 10,7~ 75.51 9~19,50 30,40 10,73 2G,08 3,48 9420,00 31.25 10.73 2&.4~ 5,~0 9420,50 31,82 10.79. 2G.02 4421.00 37.3G 10.79 ~2.4G 9.78 9~2~,50 32.93 11.14 20.89 9422,00 35,~ 11,30 19.71 2,19 9~2~.50 3~,65 11,34 18.95 94~3,00 3~,87 11,17 1. B.60 1,98 9~23,50 ~4.30 11,~1 18,39 1,98 g424,00 3~.~7 1~.,3~ 18.6]~ 1,90 942~,50 3~,19 11,~9 18.61 1.BG 9425,00 34,45 11,5~ 13.61 1,90 91,12 96,07 102,75 105.80 107,00 109,22 112,~3 113.73 116.~6 118,75 120,78 120.78 121.2~ 122.24 122.79 122.80 121.42 118.30 107.29 99,35 95,13 89,~6 87,89 88,79 91,1~ 9~.21 97,77 97,~1 93,01 89,~1 87.63 ~.8.0 82,53 78.95 77,10 73,97 72,~9 6~,75 69,09 790G3 B5.~8 98,42 105,60 116,9~ 127.41 132.33 ~LL2 NLL3 NLL4 Ntt5 NLL~ 33.29 3~.79 32.7~ 33.~9 33,~2 32.69 33.59 ~.8~ 34.00 32.43 32.07 33.~1 32,8~ 33.78 32.51 3t.3~ 3~,78 32.59 33,32 52,85 30.87 33.35 52,14 33.52 33.27 31,25 33,77 31,~0 33.2G 33.53 31.80 33.2! 33.1! 33.51 33.47 32.23 32.92 33.6~ 33.97 33.47 32.85 3~.03 33.36 3~.51 33.59 32.09 32.9G 34.07 32.43 33.49 3~,B~ 3~.6~ 34,71 3~.47 33.G8 32,92 32.09 3%.92 5~.4G 33.09 33.2~ 3].70 33.43 32.1~ 33.17 32.61 32.30 32.82 32.82 33.51 32.10 3~.5~ 3~o57 32,46 33.1~ 31.90 34,06 31.95 3~,52 32.79 3~.3~ ~3,35 31.80 3~,88 32,20 3~.33 33.43 32,G6 33.5~ 32.19' 33.~0 33.01 31.98 33.54 33.09 33.2~ 3~.95 30.62' 33.10 33.05 33.14 3~.04 30.68 3~.~ 33.35 32.51 31.00 31.18 33.09 33,49 33.01 29,96 31,29 33.51 32.G~ 33.~9 30.33 31,12. 33.61 32.08 32.§~ 30.59 31.38 53.35 31.67 32.2~ 51.3~ 32.31 33.5~ 32.10 31.91 3~.55 3~.99 33.71 33.27 .... 3~.5~ 37.13 31.96 33'03 52.54 33.27 3~.~0 31.83 33.05 31.97 32.~B 32.~4 32.39 33.38 31.71 3~.~9 31.I1 31.~5 3~,94 31.77 32,36 30.51 3'1.20 3~.~2 32.30 31o73 31.09 31.21 3'1.73 31.27 31.9"~ 30-52 30,5~ 31.56 31.23 31.79 30.19 30.30 31.7,..'5 31.19 30,68 30.89 31,6,9 31'84 '3'0'48'':'~ 30-~.:9 31.16 30.59 30.13 29.80 31.02 30.03 30.10' 30,57 29.55 30.97 30.06 30.87 ..... 30.90 2'9.~'0 30.51 31.%1 31.06 30.93 29.32 29.79 31.75 31,10 30,30 30,~7 29,98 ~.5~ ~t.GO .... ~0.90 30.80 29.57 3~,50 32.51 31,G5 31.Pl 31,85 31.46 31.92 32.01 ~2.G? ~.51 32.52 3~.02 32.11 34.14 33.26 52,45 33.01 31,5~ 35,61 33.7'8 32.5'5 32.08 31.03 33.36 34.5~ 32.62 32.35 30,89 34.97 33,59' 32°64 33.27 30.7~ 3§.9~ 32.~8 PAGE 2 aTI ANTIC RICHFIELD COMPANY ORTLL SITE 3 NO,q NLL1 RAT 9425.50 34.g0 11.G8 9426.00 33.G9 11.97 g426.50 33.65 12.02 9427.00 33.88 12,01 9%27.50 33.87 11.88 9428.00 34.17 ll. B2 Q428.50 34.59 11.73 9429.50 34.88 11.79 9%30.00 35.32 11.92 9%30.50 33.99 12.06 943].00 32.66 17.11 9431.50 31.87 12.15 g437.00 32.23 12.16 943~.50 32.06 11.91 9%33.00 $2.21 11.55 94~3.50 3~.7~ 11.55 9434.00 33.24 11,27 ~435.00 35.08 11.09 9435.50 3~.53 11.26 943G.00 33.89 11.39 g43&.50 32.84 11.51 9~37.00 31.90 11.00 94~7.50 ~1.23 11.06 94~8.50 3].~9 11.15 9~39.00 31.57 11.07 9~39.50 ~1.78 10.96 9440.00 51.6G 10.92 9440.50 ~1.84 11.00 94~1.00 31.50 11.10 94~1.50 30.82 11.30 944-~.00 31.40 11.28 94~2.50 32.19 11.18 ~443.00 32.72 11.20 94~.50 3~.55 11.30 9%49.00 33.77 11.35 9~U.50 ~2.95 1]..43 94~'5.00 3~.71 11.49 9~5.50 32.61 11.31 94~.00 3~.3~ 11.19 94~6.50 ~.61 ll.lB 9~47.00 33.3~ 11.15 9447,50 3~,27 11.12 9~8.00 30~:97 11.05 94%8.50 30.80 10.91 ~449.00 30.54 10.7~ 9%50.00 30.90 10.~1 9~5~.50 ~0.75 10.~8 $1 1~.62 18.89 19.01 1B.71 1B.63 1B.51 1B.16 17.89 17.64 17.~9 17.31 17.07 1G.78 17.12 ~7.~3 1.7.80 1B.6~ ].8.14 1.7.97 19.16 1.9.89 19.69 19.42 19.55 19.76 19.86 19.72 19.35 19.20 19.36 19.30 19.~ ]9.79 19.80 ~9.83 ~'0.6~ 20.68 ~0.99 21.15 21.31 21 21 21.5B ~1.34 1,91 1.94 I .95 ~.02 1.99 1.94 1.90 1 .~8 1.83 1.86 1.79 1.79 1.99 2.11 2.16 2.21 2.14 2.07 P..05 1.95 1.91 1.99 ~.13 2.27 2.45 2.'41 2.39 2.39 ~.39 2.40 2.39 2.30 ?.25 2.28 2.35 2.33 2.32 9_.36 2,56 2.?$ 2'.BO ~.76 1. t5.98 138.45 134,18 128.7o 123.69 121.81 119.55 119.02 121.52 121,qq 121.77 123.03 130.36 136.39 139.52 137.35 136.36 135.96 136.~6 143.&3 148,83 148.6~ 1~1,57 138.01 122.q7 102,85 90.4~ 85.50 81.73 7B.6~ 75.85 7q.68 7'5,1.5 76,15 77.16 79.75 B1,79 85.23 88.68 90,24 90.97 8'8.86 87.78 89.22 91.0~ 91.88 93.80 94.61 96.qq NLL~ NLL3 32,53 3~.15 31.74 3~.22 31.70 33.92 33.60 33,34 54,50 33.23 33.~5 33.62 3~.77 3~.q8 53.04 32.35 35.87 32.80 33.33 3~.~6 53.72 33.62 33.~6 34.23 32.51 33.06 3~.95 33.20 3~.7& ~.~0 3~.33 33.93 34.85 33.~3 ~5.09 32.31 34.30 31.57 33.97 31.60 3~.36 31.97 54.1B 31.51 33.~9 31.21 3~.97 M3.04 3~.52 33.9~ 3~.10 ~3.51 FO.~ ~.80 ~9.05 32.22 28.95 32.36 30.50 31.69 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RICHFIELD gRILL SITE ~ NO,B NLL1 RAT 9451.00 31.20 10.76 20.91 9451.50 51.60 10.32 20.52 9452.00 5~.16 10.90 20.22 9q52.50 32.30 11.05 ~0.1~ 945~.00 55.21 11.04- 20.00 9453.50 55.30 11.02 20.23 945~.00 52.71 10.9~ 20.50 945~.50 ~.46 10.90 20.85 9455.00 52.0& 10.39 20.96 9455.50 3~.54 10.95 20.71 9~56.00 3~.55 11.02 20.02 945~.50 37.51 11.06 20,25 9~57.00 33.~6 11.1~ 20.26 9457.50 55.76 11.23 ~0.1~ 9~58.00 33,28 11,~2 19.9~ 9458.50 5~,~8 11.56 19.67 9459,00 ~5.1.3 11.64 19.~3 9459o50 55.0~ 1.1.56 19.15 9460.00 53.29 11,69 18.8~ ~%&0,50 5~,19 11,95 9461,00 ~,71 12,09 ~7.65 9461,50 34,70 1~,4~ 16.79 ~4~9,00 ~&,lS 12.79 9462,50 37,00 13,1& 1~.~1 ~465.00 35,99 15,BO 13.05 ~46~,50 37.25 14.24 11.0~ 946~.00 5R.02 1~.94 9,~9 9~&4.50 57.54 15.74 9465,00 3&.4~ 16.69 7.~5 g~65.50 5~.14 16,99 ~,90 946~,00 36.98 !~.55 ~.90 9466.50 3~.29 16.09 ~,91 9467.00 56.68 i5.3~ 6.91 9467.50 36.23 15.~ 7.14 9%&8.00 ~5.61 15.32 7.00 94&B,50 ~9.55 15.19 9469,00 40.50 15'.10 6.68 9969.50 40,05 15.07 9470.00 39.22 15.15 ~.77 9470.50 40.07 15,55 9471.00 ~0,00 15,50 9471.50 bl.59 16.11 ~.91 947P,0~ ~0,20 16.47 ~.57 9472,50 39,~3 1&,45 947K.00 35.~8 16.59 5.25 9473.50 3~.12 IS.4& 947~.00 37.55 1~.69 947%.50 57.50 1~.35 5.01 9~75,00 57,77 1~,72 9475.50 37.B0 1~.40 947&.00 36.5~ 15.9~ 6.30 $2 2.60 2.60 2.45 2.37 2.53 2.30 2.29 2.33 2.55 2.53 2.30 ~.25 2.06 2.05 ~.05 2,05 ~.02 1,91 1.75 1.$1 1,47 1.27 1.08 0.90 O.BO 0.69 O.G7 0.02 O,&l 0.63 0.63 0.59 0.57 0.53 0.51 0.55 0.55 0.58 0.55 0.51 0.51 0.55 0.55 0.52 0.5~ 0.53 0.55 GRN VLL2 NLL3 97.40 32.11 30.52 98.74 51.75 30.31 98,6~ 31.62 29.99 98.09 31.02 95,22 ~1.63 31.39 92.32 32.57 31,89 39.~9 ~$.~0 ~1.93 85.7~ 3~.70 33.22 79.07 33.16 ~3.7~ 7~.16 32.51 52.73 70.19 33.03 53.37 6B.56 33.33 33,85 67.26 32.~9 33,01 68,96 3~.38 32.47 75.25 33.50 32.79 79.76 5%.8~ 3~.99 ~3.55 3~.30 53.22 89,06 3~.26 33.43 92.07 33.5~ 33.~3 93.70 52.70 33,07 95.13 3~.91 33.&I 9~,32 53.52 92.06 5~.25 3~.83 90.70 ~6.0~ 3~.18 89.~0 37.15 ~3.52 88.74 37.68 33.~2 90.33 37.60 3~.73 96.73 33.07 35.59 99.97 37.~5 35.&~ 115.24 3~.06 37'59 121.03 33.26 123.51 38.6~ 37.29 125.88 33.57 37.85 127.5~ 33.9~ 37.32 128.20 57.09 36.28 128.20 37,26 128,5~ 57,45 ~?,21 129.9~ 57,27 37.62' 131,62 37,11 36.81 13~.07 3'7.89 37.52 .... 131.58 37.73 38.~9 132.22 37.51 3&.93 132.22 38.4~ "37.12 13~.23 39.57 37.32 131.4~ 55.83 35.77 130.91 37.91 131.1~ 33.~5 37.25 135.~1 35.5~ 38.12 !~3.~9 30.5~' 37.90 1.~8.2B 37.BB 37.82 I45.~5 37.47 3~.99 NLL4 NLL5 NLL~ 31.64 31,~9 32.31 3~.07 $1.33 31.57' 31.86 3~,53 31.05' 31'96 31,26 31.90 32.B~ 31.65: 3~,87 3~,79 31.75 3~.95 33,11 32.83 32.~9 33.70 3~.9! 3~.90 3q.91 33.33 33.17 3~,65 3~.24 33.29 33.53 33.~3 33.65 33.12 53.06 34.09 33.6~ 3~.6~ 33.37 3~'.16 5~.19 33,29- 3~.50 3~,57 33.60 33,00 33.6~ 33.99 31,~3 3~.10 33.B0 31.03 3~.49 30.97 34.26 32.76 32.00 33.13 33.19 3~.B0 32.~9 33.11 33.06 32.91 33,32 33,03 33.45 33.99 3q,7~ 33.92 34.20 35,50 35.89 33.70 3~.50 37.71 33.09 33.~ 3~.97 53-,20 3~.36~ 37.91 33,9~ 35.~3 38,09 35,37 36.57 38,~' 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7,~8 0.~1 9487,00 ~9,05 1~,11 7.~8 0,60 9~87.50 59,68 16.1~ 7.1~ 0.57 9488,00 37,59 16,15 7.05 0,57 9~88.50 5&,72 16.07 6,93 0,57 9489,00 3~,73 1~.16 7.05 0.61 9~89,50 57,17 16,~ 7.06 0,~7 9~90,00 36,95 16.~0 6,78 9490.50 55,50 16.06 6.5.8 0,65 9~91,00 ~5,2~ 15.98 6.59 0,70 949~,50 5~,71 16,04 7,~ 0,7~ 949~,00 56.9~ 16,~0 7.~ 0,7~ 9~92,50 55,a5 1~.~2 7.55 0,77 949~.00 5~,90 16,~ 7.56 0,77 949~,50 3~,54 1~,06 7.56 0,77 9%94.00 55,~7 15.98 7.80 0.78 9~9~,50 5&,81 15,95 ~.05 O,B1 9~95,00 57,92 16.32 8.05 0.75 9495,50 3B.~3 16,~ 8.05 0,74 9496,00 37,47 I6,~5 8,06' 0,69 g~9&.50 37,~8 16,19 5.06 0,66 9~97.50 40,35 16,55 8,07 0,6~ 9~9R,00 ~1,~1 16,62 7.84 949~,50 41,~7 16,49 7,8~ 0,55 9999,00 qO,O~ 1~.~8 7.84 0,56 9%99,50 37,85 16.~1 7.77 0.60 GR~ NLL2 NLL3 NLL% ~LL5 1~5,~4 ~7.72 57,15 39.89 35.~ 127,59 ~,93 ~7,7~ 38,51 36,~1 36,72 12~.60 ~.23 38.32 ~9.~3 35.20 36,35 126,80 37,31 38,0R 39,53 3~.~0 36,69 126,17 37.17 37,82 39,15 33,9~ 37,16 122.B6 37.32 37,06 36,~5 33.~? 38.25 121.40 ~B.l.~ 36.49 35,~0 33.GB 38,B3 118,46 ~7,79 37.2~ 35.50 33,77 ~7,92 lOB,80 36,77 ~5.18 37,57 3~,89 103.1~ 36.65 3~.06 39.55 35.5~ 3B.55 101.06 36.~9 33.06 38.80 3~.~? 37.~0 100.93 36.51 36.3~ ~7.75 3~.&5 37.B6 106.32 3B.18 ~7.68 36.96 33.07 3'?.03 110.23 37.66 38.20 ~5,95 34.66 35.62 111,2~ 36,69 37,1~ 35.62 35,61 3~,54 111.42 ~.87 36.5~ 5~,56 36.10 33.9'0 110.7'0 F6.29 36.51 33,92 35.6~ 33.69 108,08 35,18 37,20 33,9~' ~7,10 35,11 107.07 3~.35 36.63 35.09 33.~7 36.00 106.58 ~3.98 36.11 35.30 36.11 ~.38 107.22 ~2,9~ 36,65 37,70 35.15 35,93 110,26 35,02 36,5~ ~0,~ 35,~ 36,60 109.70 36.~8 34,9~ 41,~6 35,~ 105,~5 3~.05 37,56 38,89 35.~ 100,43 35,71 37,59 56,77 55,7I 36,90 102,89 5~'33 37.12 3~,66 56,35 3~,98 96,0~ 34.B3 39,71 3~,OB 36,25 3~,65 95,12 ~3.5~ 38,90 36,5& 37,13 3.4.2~ 91,~5 ~5,~ 36,56' 36,~ ~6,57 $~,0~ 89,78 3B'02 3~,56 36,?0 55,6B 3{,96 87,73 59,~ ~5,13 36,79 35,9~ 35.~-1 85,0~ 35,95 35,0~ 37,82 35,2~ 84-56 59,73 55,99 ~8'5B 3&,55 35,34 80,~7 39,32 35,09 36,45 3~,9~ 36,98 79',80 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