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185-055
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Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Brooks, Phoebe L (OGC) To:Alaska NS - CTD DSM Cc:Regg, James B (OGC) Subject:RE: PBU L1-01 Nabors CDR2 Initial BOPE test Date:Friday, April 22, 2022 10:48:12 AM Attachments:Nabors CDR2AC 04-19-22 Revised.xlsx John, Attached is a revised report changing the Sundry # to 321-592 based on well PBU LIS L1-01. Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Alaska NS - CTD DSM <AlaskaNS-CTD-DSM@hilcorp.com> Sent: Friday, April 22, 2022 5:59 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Nathan Wheeler <nathan.wheeler@nabors.com>; robert.coyne@nabors.com; Henson, James <Jim.Henson@nabors.com>; Alaska NS - CTD DSM <AlaskaNS-CTD-DSM@hilcorp.com> Subject: PBU L1-01 Nabors CDR2 Initial BOPE test John Perl Sr. Drilling Foreman – Nabors CDR2 Rig (907) 670-3097 Personal Cell (907) 355-5815 H# 4169 Positional Email AlaskaNS-CTD-DSM@hilcorp.com Alternate: Mark Igtanloc 3%8/ 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:CDR2AC DATE: 4/19/22 Rig Rep.: Rig Phone: 907-670-3056 Operator: Op. Phone:907-670-3097 Rep.: E-Mail Well Name: PTD #11850550 Sundry #321-592 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:2020 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.P Ball Type 2P Standing Order Posted P Misc.NA Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 2-3/8"P Trip Tank PP Annular Preventer 1 7 1/16" GK P Pit Level Indicators PP #1 Rams 1 Blind/Shear P Flow Indicator PP #2 Rams 1 2-3/8" pipe slips P Meth Gas Detector PP #3 Rams 1 3" pipe slips P H2S Gas Detector PP #4 Rams 1 2-3/8" pipe slips P MS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 2 1/16 P Inside Reel valves 1P HCR Valves 2 2 1/16 P Kill Line Valves 1 2 1/16 P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 2 2.0" Piper P Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)2250 P Quantity Test Result 200 psi Attained (sec)18 P No. Valves 12 P Full Pressure Attained (sec)52 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 10 @ 1995 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:5.5 Hours Repair or replacement of equipment will be made within 0 days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 04/17/22 15:00 Waived By Test Start Date/Time:4/19/2022 0:30 (date) (time)Witness Test Finish Date/Time:4/19/2022 6:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Nabors Checked pit level alarms and flow sensor, test H2S and LEL alarms. N.Wheeler / T. Henson Hilcorp J. Perl / R. Burnett PBU LIS L1-01 Test Pressure (psi): AlaskaNS-CTD-DSM@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0419_BOP_Nabors_CDR2AC_PBU_L1-01 9 99 9 9 9 999 9 9 -5HJJ 4/19/22 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU L1-01 Set Whipstock Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 185-055 50-029-21317-00-00 ADL 028302 12856 Conductor Surface Intermediate Production Liner 9573 80 4050 11860 1110 12150 20" 13-3/8" 9-5/8" 7-5/8" 9034 39 - 119 39 - 4089 37 - 11897 11690 - 12800 2020 39 - 119 39 - 4041 37 - 8851 8705 - 9529 12040, 12169, 12170 470 1540 / 2670 4760 7020 12150 1490 3450 / 5380 6870 8160 11900 - 12116 4-1/2" 12.6#13Cr85 / L-80 34 - 117588853 - 9009 Structural 4-1/2" HES TNT Packer 4-1/2" Baker S-3 Hydro Set Packer 7793 / 6409 11586 / 8635 Date: Monty Myers Drilling Manager Trevor Hyatt trevor.hyatt@hilcorp.com 777-8396 Prudhoe Bay, Lisburne Oil February 1, 2022 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. 11.16.2021 By Samantha Carlisle at 7:12 am, Nov 17, 2021 321-592 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2021.11.16 14:25:37 -09'00' Monty M Myers 2020 MGR29NOV21 DLB 11/17/2021 X DSR-11/17/21 10-404 BOPE test to 3500 psi. dts 11/30/2021 11/30/21Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.11.30 11:25:15 -09'00' RBDMS HEW 12/1/2021 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: November 16, 2021 Re: PBU L1-01 Sundry Request Sundry approval is requested to set a whipstock in L1-01 pre-rig as part of the drilling and completion of the proposed L1-01L1 CTD lateral. Proposed plan for L1-01L1 Producer: Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. E-line will then set a 4-1/2"x7- 5/8" flow through whipstock. See L1-01L1 PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. A single string 3.80" window + 10' of formation will be milled. The well kicks off drilling and lands in the Lisburne formation. The lateral will continue in the Lisburne to TD. Potentially obtain open hole Den/Neu logs before running liner or during the liner run. The proposed sidetrack will be completed with a 3-1/4" x 2-7/8” 13Cr solid/slotted liner. This completion will NOT abandon the parent Lisburne perfs. Pre-Rig Work - (Estimated to start in February 2022): 1. Slickline: Dummy WS drift a. Drift past whipstock setting location 2. Fullbore: CMIT-TxIA to 2,750 psi and MIT-T to 2,750 psi 3. E-line: Set 4-1/2”x7-5/8” whipstock a. Top of whipstock set at 11,937’ MD (top of window – 5’ down from top of whipstock) b. Oriented 15° ROHS 4. Valve Shop: Pre-CTD Tree Work as necessary Rig Work: x Reference PBU L1-01L1 PTD submitted in concert with this request for full details. x General work scope of Rig work: 1. MIRU and Test BOPE - MASP with gas (0.10 psi/ft) to surface is 2,020 psi a. 24 hour notice for AOGCC witness BOPE test 2. Mill Window 3. Drill Build and Lateral 4. Run Solid/Slotted Liner a. Open hole Den/Neu Logs 5. Freeze Protect and RDMO Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 DLB Sundry 321-592 Estimated reservoir pore pressure per Trevor Hyatt email 11-29-21: 2900 psi @8800' TVD PTD to follow g This completion will NOTpp p abandon the parent Lisburne perfs. Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3.0" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Kenneth Allen Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L1-01 Permit to Drill Number: 185-055 Sundry Number: 320-104 Dear Mr. Allen: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a ogcc.a I aska. g ov 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, 2ssoieL. Chmielowski Commissioner DATED this 2- day of March, 2020. RSDMS -L'5' MAO 16 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED Mea F 9n9n 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ [" n don no 7OOpera Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Ch ens r g m ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other Set Whipstock 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0 5. Permit to Drill Number: 185-055 • 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-21317-00-00 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PBU L7-01 9. Property Designation (Lease Number): , 10. Fieltl/Pools: ADL 028302 PRUDHOE BAY, LISBURNE 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): 12856 9573 12150 9034 2488 None 12040,12169,12170 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 39-119 39-119 1490 470 Surface 4050 13-3/8" 39-4089 39-4041 3450/5380 1540/2670 Intermediate 11860 9-5/8" 1 37-11897 1 37-8851 1 6870 1 4760 Production Liner 1110 7-5/8" 1 11690 - 12800 8705-9529 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11900- 12116 8653 - 9009 4-1/2'.12.6# 13Cr85 / L-80 34-11758 Packers and SSSV Type: 4-1/2" HES TNT Packer Packers and SSSV MD (ft) and TVD (ft): 7793/6409 4-1/2" Baker S-3 Hydro Set Packer 11586/8635 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: March 15, 2020 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended 0 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hyatt, Trevor be deviated from without prior written approval. Contact Email: Trevar.Hyatt@bp.com Authorized Name: Allen, Kenneth W Contact Phone: +1 907 564 4627 Authorized Title: Engineering Team Lead Authorized Signature: Date: S s2 COMMISSION USE NL Conditions of approval: Notify Commission sothata/representative may witness Sundry Number: Plug Integrity ❑ BOP Test L9' M_e�cnt�hanical Integrity Test ❑ Location Clearance ❑ " Other HZS mEasv4 ej 0.Ye YPgqrl t�'44Tilr';•20rPM I'1? re 0.�lYb rT �OpE��TYO 3s©a s ' RBDMS � ❑ MAR 16 2020 Post Initial Injection MIT Req'tl? Yes No ❑ Spacing Exception Required? Yes ❑ No ff/ Subsequent Form Required: O V APPROVEDBYTHE Approved by: COMMISSIONER COMMISSION Date: / 62.4c ORIGINAL. Forth 10-403 Revised 04/2017 Approved application is valid for 12 months from t a date f approvalMAE11�� Submit Form and Attachments in Duplicate (ift 31shn To: Alaska Oil & Gas Conservation Commission 000 From: Trevor Hyatt i N , CTD Engineera'Wby �or Date: March 3, 2020 Re: Ll -01 Sundry Request Sundry approval is requested to set a whipstock and mill a window in the L1-01 wellbore as part of the drilling and completion of the proposed 1-1-011-1 CTD lateral. Proposed plan: The sidetrack L1-0IL1 will be a "1200' horizontal CST that will kick -out from the Ll -01 parent in the Lisburne. The planned sidetrack will increase rate and recovery within the identified target block in an area of high productivity and reservoir quality in the Lisburne. Pre rig will set a 4-1/2" whipstock, at a kickoff depth of 11,932' MD, and mill a 3.80" window. The rig will move in, test BOPE and kill the well. The well will invert to land in the upper section of the Lisburne. The proposed sidetrack will be completed with a 3-1/4" x 2-7/8" L-80 solid/slotted liner. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre -Rig Work (scheduled to begin March 2020) 1. SL Dummy GLMs. Drift for Whipstock 2. EL Set Whipstock. © t. 3. C Mill Window etL` Lam, 4. F MIT -IA 5. V Pre -CTD Tree work. Rig Work (scheduled to begin May 2020) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2488 psi).t- 3. Drill build section: 4.25" OH, ^243' (21 deg DLS planned). 4. Drill lateral section: 4.25" OH, -1378' (12 deg DLS planned). 5. Run 3-1/4" x 2-7/8" L-80 slotted liner to TD. 6. Freeze protect well to a min 2,500' TVDss. 7 1 Close in tree, RDMO. Post -Rig Work: V: Tree Work as needed S: Set LGLVs, Drift to Dev. Set LTP to isolate mainbore CT: Acidize Lateral by reciprocating acid as deep as possible. SL: Pull TLP if set zo- )o4 QaGGC_ ( The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: • A min EMW of 8.4 ppg KCL ("509 psi over -balance). KCI will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. • The well will be freeze protected with a non -freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil's departure. • Additionally, all BHA's will be lubricated and there is no plan to "open hole' a BHA. Disposal: • All Class I & II non -hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or Pad 3. • Fluids >1% hydrocarbons or flammables must go to Pad 3. • Fluids >15% solids by volume must go to GNI. Hole Size: • The window and 10' of formation will be drilled with a 3.80" OD mill. Well Control: • BOP diagram is attached. • AOGCC will be given at least 24-hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. • Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and at least 3,500 psi. • BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. • BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. • 10 AAC 25.036 c.4.0 requires that a BOPE assembly must include "a firewall to shield accumulators and primary controls". A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. a®azards: • Ll -Pad is NOT an H25 pad. Max recorded H25 reading on Ll -01: 40 ppm on 4/2/2019. o Max H2S recorded on the pad: 70 ppm on 1-1-23 on 1/6/2018. s Reservoir Pressure: • The reservoir pressure is expected to be 3378 psi at 8900' TVDSS (7.3 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2488 psi. • A min EMW of 8.4 ppg for this well will provide 509 psi over -balance to the reservoir. Trevor Hyatt CC: Well File CTD Engineer Joe Lastufka 907-223-3087 I I Choke Mandold 1 I ------------------- moms a�*w wrc ewe. j.Retuma Tank Farm u �._. Coiled iubi29linit t j I I ISource Water Tank Farm I 1F = 41110 -Lm VYELLHE4_D= FMC ACRIATOR= BAKER N 103. TIAL HF .. 64' BF. BEV = 14' KOP= `12076-12154 Max Angle = 62° 9200' zu Datum _MD= ..- 11903' s1#, H-aq Datum TVD= --8900'S5 D=19.124" 9-5/8' CSG, 47#, L-80 VAM TOP, D = 8.861' 1 —110 1 -ORS- tlVwtN CSG PA ICH, D = 9.05' 1--12426- - 243W 13-3/8" CSG, 72#, L-80, D =12.347' 4089' TOP 2 JTS = 68#, K-55, ID=12A15' Minimum ID = 3.813" @ 2232' NIPPLE 4-1/2" TBG, 12.6#, 13CR 85 VAM TOP, .0152 bpf, D = 3.958" 4-1/2' TUBNG STUB (05129114) I TOP OF 7-518" LNR I T6G, 12.6#, L-80-0152 bpf, D =; 9-5/8" CSG, 47#, L-80 BTC, D = FEFb'ORATION SUMU4LRY REF LOG: LDT/CTL ON 05/14/85 AWLEAT TOP PERF 43° Q 119W Wffi: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SOZ 5" 4 `12076-12154 O 01/16/89 5" 4 11900- 11970 O 0126/86 5" 12 11900-12000 O 01115189 5' 4 11988 -12000 O 0126/86 2-71W 6 12088 - 12100 O 01/08106 2-718' 6 12108 - 12116 O 01/08/06 5" 4 12200 - 12310 S 0126186 01/16/89 'b'kLK;TIVE5HOT5 r-- 7-518" LNR, 29.04#, L-80 R3 SH -S, .0459 bpf, D = 6.875" L-01 SAFETY NOTES: CHROME TBG 2232' =LFT 8132383' R2405' CACI FT KUWFFI C I 7788' I 14-12' FES X NP, D= 3.813" 1 19-518- X 4-112" HES TNT RCR, D = 3.903" 1 11431' —{4-1Y1' H(3X NP, D=3.613" 1151 T 6" X 4-112" UNIQUE OV B2SHOT 11575' 9-5/8' X 4-12' BKR S3 PKR, D 11599' 4-12" FES X NP, D = 3.813" { 11690' 1--L97SB' X 7-S/8' T®K SLV, ID 11707 9-518"X7-5!8'807 HYD LN2 FIGR, D=7 11747 4-1/2' VVLEG (8CR), D= 3.&55' 11732 MI340RY Tr LOG oN tons/os 1'ELMI�CBVEI iSHFATH(TAGGEDDt/23/92) �J DISH -3 BKR RCR aBJBJTS (03/02/06) .50' -ST TOC (MILLED T06.75"OD-12129/0, DATE REV BY COLVENTS tNCIE REV BY COMN8JT5 —ISTI MD ND DEV TYPE VLV LATCH PORT DATE RWO 07/10/14 JMMPJC GLV CIO (07/101/14), MN DADDED 12131804 KCF1TLH RWO 3 130491304F8 7 2 5742 518 51 1 7682 6347 56 MMG [XME PoC MMG fXM,E RK MMG SO RK 16 04125/17 16 04!25/17 24 04125/17 07/16/14 JM ICK FINAL ODEAPPROVAL I 7788' I 14-12' FES X NP, D= 3.813" 1 19-518- X 4-112" HES TNT RCR, D = 3.903" 1 11431' —{4-1Y1' H(3X NP, D=3.613" 1151 T 6" X 4-112" UNIQUE OV B2SHOT 11575' 9-5/8' X 4-12' BKR S3 PKR, D 11599' 4-12" FES X NP, D = 3.813" { 11690' 1--L97SB' X 7-S/8' T®K SLV, ID 11707 9-518"X7-5!8'807 HYD LN2 FIGR, D=7 11747 4-1/2' VVLEG (8CR), D= 3.&55' 11732 MI340RY Tr LOG oN tons/os 1'ELMI�CBVEI iSHFATH(TAGGEDDt/23/92) �J DISH -3 BKR RCR aBJBJTS (03/02/06) .50' -ST TOC (MILLED T06.75"OD-12129/0, DATE REV BY COLVENTS tNCIE REV BY COMN8JT5 05/23/86 ORGINALCOMPLETION 07/10/14 JMM'PJC PULL.JC! EVO TREVE(0mat14) 01/19/89 RWO 07/10/14 JMMPJC GLV CIO (07/101/14), MN DADDED 12131804 KCF1TLH RWO 07/101141 PJC I TREFJACIJTATOR lFDATE 06/20/14 D-14 RWO 07/16/14 JM ICK FINAL ODEAPPROVAL 0623/14 JNJJ&U PBE CORRECTIONS 04!27!17 JFK/JMD GLV CJO (04125/17) 06/26/14 J6,D DRLG HD OORRECTIONS - 2 FAILED LISBUR ELNT WELL' L1-01 PNMT No: 1850550 AR No: 50-029-21317-00 SED 1, T11N, R14E� 2187 FSL & 2447' FWL BP Exploration (Alaska) TRFF= WELLHEAD= FMC ACTUATOR= 9-5/8" X 4-12" HES TNT R(R, D = 3.903' INITIAL KB. ELEI _ BF. ELEV = _54' 14' KOP = 3200' MaxA le= I SPF Datum MD = 4-12" HES X NP, D = 3.813" Datum TVD 8900'SS PROPOSED L1-01 L1 SAFETYNOTES: CHROMETBG /' m ` 2232' 4-1/2" HES X NIP, D = 3.813" = 191#,1+40, D = 19.124" 5/8" CSG, 47#, L-80 VAM TOP, D = 8.861" 2426' 9-5/8" BOWS N CSG PATCH, D = 9.05" 2426' - 2430' ; 13-3/8" CSG, 72#, L-80, D = 12.347" 4089' 2 JTS = 68#, K-65, ID =12.415" Minimum ID = 3.813" @ 2232' 4-1/2" HES X NIPPLE t-1/2" TBG, 12.6#, 13CR-85 VAM TOP, .0152 bpf, D = 3-956" 4-1/2" TUBNG STUB (05/29114) I TOP OF 7-5/8" LNR I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, D = 3.958"1174T 9-5/8• CSG, 47#, L-80 Brc, D = e.se1 1111897" 7-5/8'X 4-12" BKR DELTA WHIPSTOCK (_/_/)11 1932' ii-YY6 XN1P1�9:[]lF1 PBTD --12150' SMLS, 12800' .0459 bpf, D = 6.875" L1-01 19-5/8" FES ES CEA� 9-5/8" HES EXT CSG PKR 2 1511/02119 7421 51851 51 MMG DOME I RK 16 RK 1 16 111/02/19 776W —j4112"HESXNP,D=3.813"1 9-5/8" X 7-5/8" BOT HYD LNR HGf PERFORATION SUMMARY 9-5/8" X 4-12" HES TNT R(R, D = 3.903' 41/2' WLEG (9CR), D=3.855" REF LOG: LDT/CNL ON 05/14/85 11431' ANGLE ATTOP PERF: 43" @ 11900' 11517' Note: Refer to Production DB for historical perfdata SIZE I SPF I INTERVAL I O NS z I SHOT SOZ 4-12" HES X NP, D = 3.813" L1-01 5" 4 '12076-12154 O 01/16/89 5" 4 11900 -11970 O 01/26/86 5" 12 11900 -12000 O 01/15/89 5" 4 11988 -12000 O 01!26/86 2-7/8' 6 12088 -12100 O 01/08/06 2-718" 6 12108 -12116 O 01/08/06 5" 4 12200 -12310 S 0126/86 01/16/89 L7-01 Lt SLTD SLTD I _L_L_ ii-YY6 XN1P1�9:[]lF1 PBTD --12150' SMLS, 12800' .0459 bpf, D = 6.875" L1-01 19-5/8" FES ES CEA� 9-5/8" HES EXT CSG PKR 2 1511/02119 7421 51851 51 MMG DOME I RK 16 RK 1 16 111/02/19 776W —j4112"HESXNP,D=3.813"1 9-5/8" X 7-5/8" BOT HYD LNR HGf 7788' 9-5/8" X 4-12" HES TNT R(R, D = 3.903' 41/2' WLEG (9CR), D=3.855" 11732 11431' 41/2" HES X NIP, D = 3.813" 11517' 6" X 4-112" UNIQUE OV 82SHOT 11575' 9-518" —X4-1/2- BKR S-3 PKR, D = 3.875" 11599' 4-12" HES X NP, D = 3.813" 3.70" DEPLOY 3LV, ID = 3.00" 3-1/2" _ X TNF0 = 2.813" D=? ( 11707' (-1 9-5/8" X 7-5/8" BOT HYD LNR HGf 11747' 41/2' WLEG (9CR), D=3.855" 11732 MBv10RY TT LOG ON 10/16/05 L7-01 L7 FR3 2-778^ SLTDTNR, 6.5#, LBo STL, 13553' .0058 bpf, D = 2.441" 1 12150' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS 05123185 ORGINAL COMPLETION 01119/89 RWO 12131/04 KCF/TLH RWO 06/20/14 D-14 RWO / / CTD ML 11/19/19 JMD BULTPROPOSED FISH -3 2 OD -1229/04) LISBURNE UNIT WELL: Ll -W L1 PERMITNo: 1850550, API No: 50-029-21317-00(60) rl lN, R14E, 2182' FSL & 2447' FWL BP Exploration (Alaska) Well Bighole CDR2-AC 4 Ram BOP Schematic Date 21 -Nov -17 Quick Test Sub to Otis 1.1 ft -- -- —* Top of 7" Otis 0.0 ft —.—.—.—.—.—._._. ,—,_,_,_. Distances from top of riser �CDR2 Rig's Drip Pan Excluding quick -test sub Top of Annular ]-1/16" Sk Flange X ]" OGs Boz 6.o ft 16 tlnnul Top of Annular Element 6.7ft Annular r Bottom AnnularBA ft —� CL Blind/Shears 9.3 ft CL 2-3/8" Pipe/Slips 10.1 ft Bi BZ B3 B4 Choke Line Kill Line ,. CL 2-3/8" x 3-1/2" VBRs 12.6 ft CL 2-3/8" Pipe/Slips 13.4 ft CL of Top Swab 16.11 ft �-- Swab T1 CL of Flow Cross 17.4 ft FIA CL of Master 18.8 ftLDS LDS Ground Level 0 T2 Test Pump Hose \,-65 -o55 RECEiVE40 • 2c..o4« Mill biLs, 2 3 261.i PRINT DISTRIBUTION LIST BAKER HUGHESAOGCC Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc. BP Exploration(Alaska)Inc. Petrotechnical Data Center,LR2-1 DATA LOGGED l /26/2016 WELL NAME L1-01 900 E. Benson Blvd. ;vl. K.BENDER Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE RPM:PNC3D BHI DISTRICT Alaska --- LOG DATE October 17,2015 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares@bakerhughes.com TODAYS DATE December 21,2015 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM LOGS (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #ur rrmN I a #OF COPIES #OF COPIES #OF COPIES 1 BP North Slope. 0 I 1 0 0 I 0 EOA,PBOC,PRB-20(Office 109) 1 D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 I 1 1 1 0 0 Attn:Ricky Elgarico ATO 3-344 700 G Street J U L 2 5 201 Anchorage,AK 99510 SCp{itNED 3 ExxonMobil,Alaska 0 1 I 1 I 0 I 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 I 1 I 1 I 0 I 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** I 0 I 1 I 1 I 0 I 0 I Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 **Stamp"otntial"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 0 1 1 1----0- 7(T1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:Dodie Stinson TOTALS FOR THIS PAGE: n TOTALS FOR ALL PAGES: 0 6 5 0 0 • 6,i&.\\I%%y �� i HE STATE h a „a `.1 1 tc v .�' l'-'s !` f'fi'', i � r<,�_`� y`\ tri l` I r\ � l`' 114 t - – — 333 West Seventh Avenue hr � , ov1-J NO1: SEAN SI�iVF,L,(. Anchorage, Alaska 99501-3572 ,1 el �unu_ . F� Moro 907.279.1433 _ NNE MCI 1 8 12.T14Dave Bjork � \g‘5.. dS�Engineering Team Leader BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L1-01 Sundry Number: 314-166 Dear Mr. Bjork: 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, 0 / Daniel T. Seamount, Jr. Commissioner DATED this 27day of March, 2014. Encl. STATE OF ALASKA RECEIVED ALASK. .JIL AND GAS CONSERVATION COMML„1ON APPLICATION FOR SUNDRY APPROVAL MAR 1 4 2014 20 AAC 25.280 AOGCC 1. Type of Request: ❑Abandon 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Change Approved Program ❑Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing 0 Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. 0 Exploratory 0 Stratigraphic 185-055 • 3. Address: 6. API Number: e,Alaska 99519-6612 0 Development 0 Service P.O. Box 196612,Anchorage, 50.029-21317-00-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU L1-01 • Will planned perforations require a Spacing Exception? 0 Yes ® No 9. Property Designatior 10.Field/Pool(s): ADL 028302 ' Prudhoe Bay Field/Lisburne 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): 12856' 1 9554' 12150' 9033' 12150'(TOC), 11599' 12040', 12169', 12170' Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 4089' 13-3/8" 4089' 4041' 3450/4930 1950/2670 Intermediate Production 11897' 9-5/8" 11897' 8850' 6870 4760 Liner 1102' 7-5/8" 11698'- 12800' 8710'-9513' 6890 4790 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11900'- 12116' 8852'-9008' 4-1/2", 12.6# L-80 11747' Packers and SSSV Type: 9-5/8"x 4-1/2"Baker S-3 Set Packer Packers and SSSV 11575'/8626' MD(ft)and TVD(ft): 12. Attachments: 13.Well Class after proposed work: . 0 Description Summary of Proposal 0 BOP Sketch 0 Detailed Operations Program 0 Exploratory ElStratigraphic 0 Development 0 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation: July 15,2014 ' . 0 Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG 0 Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Carolyn Kirchner,564-4190 Printed Name: Dave Bjork Title: Engineering Team Leader Email: Carolyn.Kirchner@bp.com !!�f✓1F Signature: Phone: 564-5683 Date: 03h3b4( Commission Use Only Conditions of approval: Notify Commission so that a representative may witness t 14— t Colo Number: ❑Plug Integrity BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: 0 op fc,$ f ,-/---0 'SU d id 5 i RBDMS 1MAY 1 0 2014 , Spacing Exception Required? 0 Yes ❑No Subsequent Form Required: / d —4 o 4 ;-77 Approved By: - t y� %� MISSIONER THE COMMISSIONAPPROVEDBY Date:3h71/ � Form 10-403 Rev d 10/2012 Approved ablRaa i I,EIA2Lflths from the date of approval SubmitI, Duplicate vi-r-- 3/2/ / / - S V G-co�G'CF 3lacc�l14 -3,0,/ by 0 Sundry Request for casing repair Well: L1-01 Date: 3/14/14 Engineer: Carolyn Kirchner MASP: 2210 psi Well Type: Producer Estimated Start date: July 15th, 2014 History: L1-01 is a Lisburne producer completed in 1985 with a long history of cycle production. Significant lost circulation was encountered near the top of the Wahoo Formation. This is the perforated area 11,900-12000' MD. Lost circulation was also encountered at 12,850' MD. A liner was run and set at 12,800 ft. The well was completed in February 1986 with 2-7/8" tubing. Zone 6 was perforated, 11,900- 12,000'. Zone 4 was perforated and acid fraced, 12,200-12,310'. The well was shut in for a workover during January 1989 due to high watercut and problems with the tubing. This workover replaced the tubing, squeezed off zone 4, the lowest set of perforation, perforated zone 5 and stimulated, 12,076- 12,310'. However, the workover did not successfully shut off the water. During the following years many attempts were made to set an IBP in the liner and cover it with cement. The last report that could be found stated a plug was set at 12,050' with a cement cap on top. L1-01 was shut in from 1998 to 2002 due to high GORs and plant constraints. During 2003 IA x OA communication developed and the well was being operated under a waiver policy. The second Rig Workover took place during December, 2004. The 2-7/8" tubing was pulled as its condition was such that access to the liner could no longer be made. The liner was milled out to 12,150'. A new string of 4-1/2" tubing was run and the well was put back on production. Since that time L1-01 has been relatively trouble free since that time with the exception of a slightly elevated number of OA bleeds(for pressure). In June 2013 bubbling was notice in the cellar after a recent POP and further diagnostics (MIT-OA on 8/3/13) uncovered what appear to be a surface casing leak to atmosphere. The well was immediately shut-in and declared non-operational. Further diagnostics to determine the surface leak depth were unsuccessful due to a partial blockage in the OA. Scope of Work: Pull 4-1/2" completion to the cut. Cut and pull 9-5/8" and run tie-back to surface. Run 4- 1/2" 13Cr completion. Pre Rig Prep Work: S 1 Drift and tag, pull tubing tail plug, SBHP, re-run PX plug in X-profile at 11599' MD. Dump 10 ft of sluggits. E 2 Cut 4-1/2"tubing with RCT at 11501' MD, 2 ft below top of first full joint above packer. F 3 Circ well to KWF based on SBHP. CMIT-TxIA to 1000 psi to ensure post cut integrity W 4 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T& IC. ✓ 5 Set TWC in the tubing hanger. O 6 Remove the wellhouse &flow line. Level the pad as needed for the rig. Proposed RWO Procedure: 1. MIRU Doyon 14. ND tree. NU and test BOPE with fourpreventers configured topdown (annular,Y 9 9- 5/8" fixed, blind shears, mud cross' and 3-1/2"x 6"VBR's). Test the VBR's and annular to 3.500 psi. _ 2. Pull and lay down 4-1/2"tubing to the jet cut at 11501'. 3. RU Wireline and run USIT log across 9-5/8"to locate TOC. 4. Set 9-5/8" RBP and 50' of sand —100' below logged TOC. PT RBP to 3,500 psi. 5. Mechanically cut 9-5/8"casing in 1st full joint above the TOC. Pull 9-5/8"casing through the stack. 6. Scrape 13-3/8"and dress-off 9-5/8"casing stub 7. Run 9-5/8"tie-back fully cemented to surface with 255 bbls of 15.8 ppg class G cement 8. Drill out the 9-5/8" shoetrack and test casing to 3,500 psi. 9. Recover RBP. 10. Run new 4-1/2" 13Cr completion with 9-5/8"x 4-1/2" HES TNT packer. 11. Set a TWC and RDMO. Post rig Work ✓ 1 Pull TWC S 2 Set PX plug in X-profile below packer. F 3 Circulate in packer fluid. Set packer. MIT-T and MIT-IA to 3500 psi. S 4 Pull PX plug, bail sluggits, pull deep PX plug. Run jewelry log from PBTD to surface, install generic GLD. I HE =" FMC GEN NSAFETY NOTES: WELL 'D= FMC L 1 -01 I ACTUATOR= AXE-SON NTIAL KB.ELE 54' BF.B-EV= 14' KOP= 3200' Max Angle= 62°@ 9300' 0 2100' —4-1/2"HES WEL.LSTAR TRSSSV(9CR) Datum MD= 12041' D=3.813" Datum TVD= 8900'SS 2 JTS-13-3/8"CSG,K-55,68# H 4089' GAS UFT MtAN)RE_S 13-318"CSG,72#,L-80,D=12A15' ST M) ND DEV TYPE VLV LATCH PORT DATE L f 5 2996 2994 6 MMG-M DMY RK 0 08/05/13 4 5727 5175 51 MMG-M DMY RK 0 08/05/13 Minimum ID = 3.813" @ 2100' 3 8414 6761 56 MMG-M DMY RK 0 08/05/13 4-1/2" HES TR S S S V 2 10509 7906 49 WAG-M DMY RK 0 12/30/04 1 11485 8566 47 MAG-M DIM RK 0 12/30/04 ' , { 11554' H4-110=3.813' >< ><— 11575' —19-5/8"X 4-1/2'BKR S-3 PKR,D=3.875' A 11599' 4-112"HES X NP,D=3.813' TOP OF 7-5/8"LMR — 11698' -----r— 11599' H4-1/2"XX PLUG(08/04/13) 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" —i 11747' - . 1174T —14-1/2'WLEG(9CR),D=3.855" 11732 HMEMORY TT LOG 10/16/05 9-5/8"CSG,47#,L-80,D=8.681" —E-11897' • - ' PERFORATION SUMMARY — RE=LOG:LDT/CML ON 05/14/85 K 12011' ELM —TOP OF CMT SHEATH,TAGGED 01/23/92 ANGLE AT TOP PERF:45 @ 11900' 4 Note:Refer to Production DB for historical perf data 4 illy 12040' H FISH-3 BKR PKR ELE BYTS(03/02/06) SIZE SPF INTERVAL Opn/Sgz SI-10T SOZ K INTERVAL 5" 12 11900-12000 0 01/15/89 5" 12 12076-12153 S 01/15/89 —12150' —I EST TOC ASL®OUT TO 6.75"00(12/29/04) 5" 12 12200-12310 S 01/15/89 4♦4�♦�♦j♦j♦j 2-7/8" 6 12088-12100 0 01/08/06 04*4♦♦♦�♦♦♦♦/ 2-7/8" 6 12108-12116 0 01/08/06 0�♦�♦�♦�♦♦♦♦4 ♦♦♦♦♦♦♦♦♦♦♦♦. ♦♦♦♦♦♦ FBTD —I —12150' ♦♦♦♦♦♦♦♦♦♦♦ ♦.♦.♦♦♦♦♦♦♦♦ ♦ •♦♦♦ ♦', `SA 1 12169' H BRIDGE PLUG RUBBER ELEMENT ♦�♦�v♦...♦� L- ♦♦♦♦♦♦ ♦•♦♦♦♦ _ ♦4.• 141♦ r 12170' —12 FAL_B)BRIDGE PLUGS •♦♦j♦j j♦.4 7-5/8"LMR,29-7#,L-80,.0459 bpf,D=6.875' 1 12800' �������' DATE REV BY COMvENTS DATE REV BY COMVENTS USBURN=UNT 05/23/85 ORGINAL COMPLETION 08/16/13 RKT/JMO SET XX PLUG/GLV C/O(08/04-0 VUELL: L1-01 01/19/89 RWO PEWIT No:'1850550 12/31/04 KCFITLH RWO AR No: 50-029-21317-00 01/03/05 KSB/TLH GLV C/O SEC 1,T11N,R14E,2182'FSL 8 2447'FVVL 03/06/05 TLHITLH 7-5/8"DEPTH CORRECr(1/19/04) 02/28/07 RL DATUM MD BP Exploration(Alaska) IV "REE1PIELLIfAD= FMc - I_ G�IV L 1 01SAFETY NOTES: ACTUATOR= AXELSON URAL KB.ELE 54' Proposed BF. 10 KO 1 9-5/8" 47#, Max Angle= 62"@9300' L-80; VAMTOP HC KOP= 33200' 4-1/2 X NIP, ID=3.813 ----- 1 I 9-5/8" HES ES Cementer Datum FAD= 12041' i c 9-5/8" BKR E C P Datum TVD= 89900'SS 9-5/8" Bowen Casing Patch 2 JTS-13-3/8"CSG,K-55,68# H 4089' 13-3/8"CSG,72#,L-80,13=12.415" C 'ST MD TVD DEV TY FE VLV LATCH PORT DATE 5 3000 DCR 57Minimum ID =3.813" @ 2100' 3 � o Y 4-1/2" HES TRSSSV 2 10500 DMY 1 11400 DMY I 4-1/2" X NIP, ID=3.813" X —4-1/2" x 9-5/8" HES TNT Packer I 4-1/2" TGB, 12.6#, 13Cr-85 VAMTOP, ID=3.958"— 4-1/2" X NIP, ID=3.813" f 4-1/2" x 9-5/8" Unique Overshot Mi ►_ 11575' H9-5/8"X 4-1/2"BKR S-3 PKR,13=3.875" IMO 11599' 14-1/2"HES X NP,D=3.813" TOP OF 7-5/8"LNR —I 11698' 1-- — 11599' H4 12"xx Plug (8/4/13)I 4-1/2"TBG,12.6#,L-80,.0152 bpf,ID=3.958" 1 11747' i . 11747' 14-1/2"WLEG(9CR),ID=3.855" 11732 —I MEMORY TT LOG 10/16/05 9-5/8"CSG,47#,L-80,13=8.681" H 11897' —A , PERFORATION SUMMARY — REF LOG:LDT/CML ON 05/14/85 t 12011' ELM H TOP OF CMT SHEATH,TAGGED 01/23/92 ANGLE AT TOP PERF:45 @ 11900' 'i illy r Note:Refer to Production DB for historical perf data { 12040' —[FISH-3 BKR PKR ELEMENTS(03/02/06) SIZE SPF IVTH?VAL Opn/Sqz SI-OT SOZ K • 5" 12 11900-12000 0 01/15/89 K 5" 12 12076-12153 S 01/15/89 { —12150' HEST TOC MILLED OUT TO 6.75"OD(12129/04) 5" 12 12200-12310 S 01/15/89 111111111111 2-7/8" 6 12088-12100 0 01/08/06 111111111111 2-7/8" 6 12108-12116 0 01/08/06 1111111111114 1111/111111. PBTD 1 —12150' •1.1.1.1.1.1 111111 111111 11'•111 1' .."1. 12169' H BRDGE PLUG RUBBER ELEMENT 111..0 I11 111111 11••411 1,1 �'•� 12170' —I2 FAILED BRIDGE PLUGS 11111111111 1111111111111 7-5/8"LNC,29-7#,L-80,.0459 bpf,ID=6.875" H 12800' •••••••' DATE REV BY COMMENTS DATE REV BY COMETS LISBUME UNIT 05/23/85 ORGINAL COMPLETION 08/16/13 RKT/JND SET XX ELUG/GLV C/O(08/04-0f WELL L1-01 01/19/89 RWO PERNIT No:'1850550 12131/04 KCF/TLH RWO AFI No: 50-029-21317-00 01/03/05 KSB/TLH GLV C/O SEC 1,T11 N,R14E,2182'FSL&2447'FWL 03/06/05 TLWTLH 7-5/8"DB3TH CORRECT(1/19/04) 02/28/07 RL DATUM MD BP Exploration(Alaska) g // . i §-& . (|® /� / fir \. & o IS t }\ g � » _ A . 41 ƒ § 0 � " � 3r2 § / R . \ \ \•} \'\ / 01 7, \ \ }` | r /| �� . 1 1 § § ° ° | z ( ) i ! S § . rO _ / LI , • • 4 § (\ / ■ § ■ ■ «. A^ C. ) Ln , ! .1� '/ • � §_ § 2 | ' §\\ � _ Li/ Z - . z�� : / ` —� LT— / / 7 Id el: \ � ,. ( {: „ \ � \/% _ \ `} „ / z _ _ ¥ a¢Q '/ kE» ■ @g3 • \ , tl 6 6 .| k ( E ! ! « }.§2| !!3 ¥ } e. :Is1 > @ e q b § ;1. »4;2 % N' Ill _|_ . z 0 14 ■� - _ 9 A . | - _ a \ |/ / _________Li -—/4141111 Ind \ 9cn / A (| ( / 1111 111 ■9� • I 4 |f ■ ; 1 | i 1 & i 1 _ � grit LI-Ol pm I o5o Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator @bp.com] Sent: Monday, June 17, 2013 10:13 PM cif 'L 1L3 To: AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; Sauve, Mark A; Regg, James B (DOA); Wallace, Chris D (DOA); AK, OPS GPMA OSM; AK, OPS GPMA Field O&M TL; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, RES GPB East Wells Opt Engr Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A ✓ Subject: NOT OPERABLE: Producer L1-01 (PTD#1850550) SC Leak Attachments: L1-01 TIO plot 6-17-13.docx; L1-01 wellbore schematic.pdf All, (0505S0 Producer L1-01 (PTD# 1.80550)has a confirmed surface casing leak to atmosphere on 06/17/2013.The well has been reclassified as Not Operable at this time and has been shut in. Plan Forward: 1. APE: write Secure Program A copy of the TIO plot and Wellbore Schematic have been included for reference. Thank you, Laurie Climer Mlle,mac .f,.,{:k SCANNED FEB 2 0 2014 BP Alaska - Well Integrity Coordinator it-in it G I"ti P€ C3rgaro i°on WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator @JBP.com 1 s6868 TT� ffl • • • a 0 a H d H ? M O. o Lc) CO '� cy l0 Q i G CO © o°, TREE= FMC GEN IV WELLHEAD= , FMC L1 -01 SAFETY NOTES: ACT ATOR= AXELSON KB. ELEV= 44' BF.ELEV= 14' KOP= 3200' Max Angle= 62 @ 9300' Q 2100' —4-1/2"HES WELLSTAR TRSSSV(9CR) Datum MD= 12041' ID=3.813" Datum TVD= 8900'SS ' 2 JTS- 13-3/8"CSG, K-55,68# 4089' GAS LIFT MANDRELS 13 3/8"CSG,72#, L-80,ID= 12.415" 1-1 ST MD TVD DEV TYPE VLV LATCH FORT DATE 5 2996 2994 6 MMG-M DOME RK 16 03/14/05 4 5727 5175 51 MMG-M DONE RK 16 03/14/05 Minimum ID =3.813" U@ 2100' 3 8414 6761 56 MMG-M SO RK 24 03/14/05 4-1/2" HES TRSSSV 2 10509 7906 49 MMG-M DMY RK 0 12/30/04 1 11485 8566 47 MMG-M DMY RK 0 12/30/04 I 11554' I--I4-1/2"HES X NIP(KR),ID=3.813" MI ►M 11575' 1-19-5/8"X 4-1/2"BKR S-3 PKR, ID=3.875" I I 11599' I—{4-1/2"HES X NIP, ID=3.813" I I TOP OF 7-5/8"LNR H 11698' I--- 14-1/2"TBG, 12.6#, L-80, .0152 bpf, ID=3.958" H 1174T 11747' H4-1/2"WLEG(9CR),ID=3.855" I 11732 -MEMORY TT LOG 10/16/05 I I 9-5/8"CSG,47#, L-80,ID=8.681" H 11897' I--A PERFORATION SUMMARY I REF LOG:LDT/CNL ON 05/14/85 • 12011'ELM(-TOP OF CMT SHEATH,TAGGED 01/23/92 I ANGLEAT TOP PERF:45 @ 11900' Note: Refer to Production DB for historicalperf data 12040' I-FISH-3 BKR FKR ELEMENTS(03/02/06) SIZE SFF _ INTERVAL . Opn/Sgz DATE , 5" 12 11900- 12000 0 01/15/89 5" 12 12076- 12153 S 01/15/89 —12150' H EST TOC MILLED OUT TO 6.75"OD(12/29/04) I 5" 12 12200- 12310 S 01/15/89 4•�'�•"•4'• 2-7/8" 6 12088- 12100 0 01/08/06 ,&• '• , • 2-7/8" 6 12108- 12116 0 01/08/06 1��� 4.4 ���1,•1i1∎ PBTD —12150' • '.� '',� '4 •\''$ 12169' HBRDGEPLUG RUBBER ELEMENT I 4 4•••• 44 .�.��'±•�4 12170' -2 FAILED BRIDGE PLUGS I 17-5/8" LNR,29-7#,L-80, .0459 bpf,ID=6.875" H 12800' DATE REV BY COMMENTS DATE REV BY COMMENTS LISBURNE UNIT 05/23/85 ORGINAL COMPLETION 11/12/05 RW/PJC MEMORY TT LOG(10/16/05) WELL: L1-01 01/19/89 RWO 01/08/06 JLG/PJC PERFS PERMTNo:1850550 12/31/04 KCF/TLH RWO 03/02/06 SGS/PJC FISH@ 12040' API No: 50-029-21317-00 01/03/05 KSB/TLH GLV C/O 10/25/06 JLP/PAG TOC MLL OUT CORRECTION SEC 1,T11N, R14E,4231'FEL&4731.17'FNL 03/06/05 TLWTLH 7-5/8"DEPTH CORRECT(1/19/04) 02/28/07 RL DATUM MD 03/14/05 DTR/PJC GLV C/O BP Exploration (Alaska) oz/o7/o8 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ~f` ~ FEB ~ r1ry(y~ Anchorage, AK 99503-2838 GtIU ATTN: Beth weu ,lob tF Lo Descri tion Date BL Color CD V-07 11978425 CH EDIT PDC GR (USIT) 12/06/07 1 L1-01 11975753 PRODUCTION PROFILE - 02/06/08 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: NO. 4577 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay,Lisburne • BP Exploration (Alaska) Inc. Petrotechnical Data Center LRZ-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~° ~~.~`:i ail. ~j; ~~~~~~ a ~~~"t9~tBl7`.olttg. a STATE OF ALASKA I AlA~ Oil AND GAS CONSERVATION COMSION REPORT OF SUNDRY WELL OPERATIONS D D o 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Ope rat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 54 KB 8. Property Designation: ADL-028302 11. Present Well Condition Summary: Total Depth measured 12856 true vertical 9554.02 Effective Depth measured 12150 true vertical 9032.6 Casing Length 73 81 3988 11870 1102 Size 13-3/8" 68# K-55 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7-5/8" 29.7# L-80 Surface Conductor Surface Production Liner Perforation depth: Measured depth: 11900 - 12000 True Vertical depth: 8851.86 - 8924.27 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 472 505 x RECEIVED FEB 1 4 í006 Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development ;i'f Stratigraphic D Stimulate D Waiver D Time Extension DAnchorage Re-enter Suspended Well D 5. Permit to Drill Number: 185-0550 6. API Number: 50-029-21317-00-00 Exploratory Service 9. Well Name and Number: L 1-01 10. Field/Pool(s): Prudhoe Bay Field/ Lisburne Oil Pool feet feet Plugs (measured) None Junk (measured) 12170,12169 feet feet .<id;.Û". """\Nt..:: '. \&~if"W,,\;<: ~~.:.." TVD 28 - 101 29 - 110 101 -4041.32 25 - 8849.67 8709.73 - 9512.58 Collapse 1950 470 2670 4760 4790 ~:i MD 28 - 101 29 - 110 101 - 4089 25 - 11897 11698 - 12800 Burst 3450 1490 4930 6870 6890 12088 - 12100 8987.69 - 8996.36 12108 - 12116 9002.14 - 9007.93 4-1/2" 12.6# L-80 25-11747 4-1/2" HES WellStar TRSSSV 4-1/2" Baker S-3 Hydro Set Packer 2100 11575 RBDMS 8Fl FEB 1 4 Z006 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 4782 1302 0 1169 824 0 15. Well Class after proposed work: Exploratory Development ;i'j 16. Well Status after proposed work: Oil ;i'j Gas WAG D Tubing pressure 816 709 Service WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal Signat~~ Form 10-404 Revised 04/2004 r'''~ U Title Data Mgmt Engr Phone 564-4424 Date 2/9/2006 Submit Original Only e e L 1-01 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 1/8/2006 T/I/O=700/1800/750 Assist E-Line w. Freeze Protect Pumped 4 bbls of neat meth and 4 bbls of DSL down F.L. Final WHP's=S/1 /1800/750 1/8/2006 2 RUNS 2-7/8" 2906 POWERJET HMX 6 SPF 60 DEG PHASING. RUN 1: PERFORATE 8' FROM 12108' - 12116', CCL TO TOP SHOT = 5.3', CCL STOP DEPTH = RUN 2: PERFORATE 12' FROM 12088' - 12100', CCL TO TOP SHOT = 11.3' CCL STOP DEPTH = 12076.7' 1/26/2006 T/I/O= 900/1800/1010. Temp= Hot. TIFL PASSED (pre-acid, 02-02-06). IA FL @ 8414' (450 bbls) @ sta# 3 s/o. Stacked out tubing from 900 psi to 1610 psi in 2 hours. SI AIL line to IA. Sled lAP down production from 1540 psi to 600 psi in 2 hours. During bleed OAP decreased 110 psi. Monitored for 1 hour. No change in pressure or FL. Final WHP's= 1600/600/900. FLUIDS PUMPED BBLS 1 I Diesel TOTAL 1 / g-,~o,~~,~ 02/28/05 Schlumberger NO. 3354 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATIN: Beth SCANNED JUN ¡ 6 2005 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color -- Well Job # Log Description Date Blueline Prints CD icr§.a;l D.S. 07-03A 10715406 MCNL 06/03/04 1 20J -1t./5K-1 OB 10715402 MCNL 05/16/04 1 f'1i;;-C'{1 D.S. 02-15A 10715404 MCNL 05/18/04 1 f'17-12~-- D.S. 18-13A 10715395 MCNL 04/16/04 1 703.l'l[- G-12B 10715391 MCNL 03/21/04 1 ~t- ;2,2.( ....D.S. 05-26A 10715420 MCNL 08/19/04 1 ,7 v'3. \ \ ~~15-04A 10715374 MCNL 01/14/04 1 TqS--ð5ð 18-02A 10621764 RST 02/23/04 1 11)/-09ð~ 18-04B 10708056 RST 03/05/04 1 n5-{yj5 L 1-01 10913000 USIT 12/25/04 1 :'6'8-l:R-L5-17 10900124 USIT 11/30/04 1 : '.") .,. /'IH-18 10703975 RST 02/17/04 1 1 '."ð ~ --10 2-62/Q-17 10900129 RST 12/24/04 1 1 !g¿'~L5'15 10708050 RST 02/07/04 1 1 .~ L5-15 10563129 RST 11/15/03 1 1 .~qç L5-15 10672368 RST 04/16/04 1 1 \ L5-15 10913848 RST 09/26/04 1 1 :~Ó-é:'I4Õ-'E-17 10703983 RST 04/09/04 1 / 1 / ~ J;l_ ty.j - G-15A 10679055 RST 02/02/04 1 1 V ¡'J PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: .-0- ý,Þ § Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-238 . /ì A TIN: Beth - ~1 í Receive ~. U~c.A.-r...a..-r Ó STATE OF ALASKA E...-.VE-- D" ALASKA OIL AND GAS CONSERVATION COMMISSION ~ REPORT OF SUNDRY WELL OPERATIONSJAN 202005 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 028302 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): 181 Repair Well 0 Plug Perforations 0 Stimulate 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well r.nn~- r.nmm¡~$ion d~fh~~r~ge 0 Time Extension 54' 12856 9554 12150 9033 110' 4089' 11897' 1190' 4. Current Well Class: 181 Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To Drill Number: 185..055 6. API Number: 50-029-21317-00-00 99519-6612 9. Well Name and Number: PBU L1-01 10. Field / Pool(s): Prudhoe Bay Field / Lisburne Pool feet feet Plugs (measured) 12150 feet Junk (measured) 12169 feet Size MD TVD Burst Collapse 20" 110' 110' 1490 470 13-3/8" 4089' 4041' 3450 1950 9-5/8" 11897' 8850' 6870 4760 7-5/8" 11610' - 12800' 8650' - 9513' 6890 4790 SC¡~NNED JAN 2 1 2005 11900' - 12000' 8852' - 8924' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Printed Name Terrie Hubble Signature~'.:(. ~/~ Form 1 0-404 ReVise~9/~04 4-1/2", 12.6# L-80 11747' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" Baker 'S-3' Hydro Set Packer; 4.5" HES Wellstar TRSSSV 11575' 2100' Treatment description including volumes used and final pressure: RBDMS BFl ,IAN 2 1 2005 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl CasinQ Pressure 11 13,184 ? 1,766 4,067 2,500 15. Well Class after proposed work: 0 Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 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 Scott Kolstad, 564-5347 NIA 13. TubinQ Pressure 2000 1,500 Oil-Bbl Prior to well operation: 545 Subsequent to operation: 349 14. Attachments: 0 Copies of Logs and Surveys ru~ 181 Daily Report of Well Operations 181 Well Schematic Diagram Title Technical Assistant Phone ~8 OR.\G\NAL 0 I 1./ (JI Prepared By NameINumber: Date II I{ oS Terrie Hubble, 564-4628 Submit Original Only Well: Field: API: Permit: L 1-01, RWO Prudhoe Bay Unit 50-029-21317-00-00 185-055 Accept: Spud: Release: Rig: 12/16/04 N/A 12/31/04 Nordic #2 PRE-RIG WORK 12/06/04 SET CATCHER SUB. PULLED GLV'S FROM STA.# 2-4. 12/07/04 PULLED 1.5" LGL V (TG) FROM ST A # 2. SET 1.5" DGL V'S (TG) IN ST A'S 2 & 3, (ST A # 4 IS OPEN). 12/08/04 ATTEMPED TO PULU FISH C-SUB WITHOUT SUCCESS. PERFORMED SIBHPS AS PER PROGRAM. RETURNED WELL TO DSO, NOTE:2.31 " KEYLESS "X" LOCK MANDREL WI FLOW-THRU SUB LEFT IN THE WELL (OAL= 18" WI LOCK OPEN). 12/12/04 SET 21/8" BAKER INFLATABLE RETRIEVABLE BRIDGE PLUG AT 11241'. 12/13/04 PULLED IBP FROM 11,236' SLM. RECOVERED BOTH 6" ELEMENTS. LOST 1" ELEMENT. DRIFTED W/2 PRONG WIRE GRAB TO 11,250' SLM. RECOVERED 1" ELEMENT. 12/14/04 DRIFTED W/1 1/2" TOOLSTRING & 1.75 CENT TAG @ 11,432' SLM. NO PROBLEMS WI DRIFT. PU WEIGHT 350#. NOTIFY DSO. WELL LEFT SI. STRING SHOT ONE STRAND FROM 11280'-11291'. TUBING PUNCHER SMALL 9 SHOTS FROM 11268'- 11270'. CUT TUBING AT 11290'. (CCL INDICATES PIPE IN VERY POOR CONDITION BELOW CUT). WELL SHUT IN. (FOLLOW UP FROM RIG NORDIC 2... 27/8" TBG ONLY CUT ABOUT ONE HALF WAY AROUND.) BP Operati()nsSW.fflrrl~ryRC:)port Pagß1 öf 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-01 L 1-01 WORKOVER NORDIC CALISTA NORDIC 2 Start: 12/15/2004 Rig Release: 12/31/2004 Rig Number: Spud Date: 4/19/1985 End: 12/31/2004 Date From - To H 0 u rs Task Code NPT Phase Description of Operations 12/15/2004 04:00 - 08:00 4.00 MOB P PRE Prep to move. Two tires low on air. Warm up same with heater. Tires properly inflated. Hold PJSM with crews, Security. Back off of L5-17. Post Pad inspection 08:00 - 00:00 16.00 MOB P PRE Move from L5 to L 1 Pad. East Dock Rd to West Dock through Deadhorse. Stop at SWS for crew change. Spine Rd to Ox Bow Rd. 12/16/2004 00:00 - 03:00 3.00 MOB P PRE Continue move down Oxbox and onto West Dock Road. AOL @ 0300 hrs 03:00 - 12:00 9.00 MOB P PRE Standby while wo TS to shoot grade and level location Phz 1 @ 0630 hrs Perform Pad inspection wi DSO Phz 2 @ 1000 hrs 12:00 - 14:00 2.00 MOB P PRE Gravel finally on location. Level area behind well head. Spot rig over well. Accept rig at 1400 hrs. 14:00 - 17:30 3.50 MOB P PRE Take on KCL water. Spot camp near rig. RU kill and choke line to tree. Set spill pools around well head in cellar. Spot and rig up flow back tank. Run hard line to rig behind adjacent well houses to allow access behind rig to cellar. 17:30 - 18:15 0.75 WHSUR P DECOMP DSM pull BPV 18:15 -18:45 0.50 I WHSUR P DECOMP TUPrespud mtg 18:45 - 19:30 0.75 WHSUR P DECOMP Install tree cap and shut swab (to pump thru WV companion valve). Fin RU to circ and reveirc. PT 2500 psi and determine pump #1 has ice plug, swap to #2 WHP 0, IA 70, OA 0, PVT 285 wi 580 bbls on trucks 19:30-20:15 0.75 WHSUR P DECOMP Begin rev circ to get diesel out of tubing by filling IA wI 50 bbls 2% KCI at 3.0/200 psi and no returns to cuttings box. Determine SSSV is a TR and is closed. DSO can't get to location to open it due to Phz 2+, so will circ kill instead (150 bbls diesel in fA and 20 bbls in tbg) 20:15 - 22:15 2.00 WHSUR P DECOMP Circ down tubing wI pump #2 wI returns thru IA at 4.8/3.5/1200 wI open choke at 140 psi initial. Pumped 170 bbls and pump #2 developed a leak. Swap to thawed out pump #1 and gradually bring up rate. Getting lots of gassy KCI wI diesel and crude back. Go thru buster for a bit then swap returns to tiger tank 4.4/970 wI 240 psi on IA. Pumped 186 bbls wI pump #1 while lAP continued to climb to 280 psi-appears we turned a dead well into a live one 22:15 - 23:00 0.75 WHSUR P DECOMP SO pump and SI IA to strap tank-no measureable volume (less than 50 bbls). SI IAP=300 psi. Resume circ kill 4.55/1050 wI 280 psi lAP holding BP thru choke and pumped a total of 300 bbls wI pump #1 or 470 bbls total wI both pumps (STS is 700+ bbls). Need more rate and fluid to circ kill. Continue pump #2 repair PVT 250 23:00 - 00:00 1.00 WHSUR P DECOMP SIIA w/310 psi after red pump rate to 0.5 bpm wlO psi to keep tubing full and let gas migrate up IA. Fin vac cuttings box, tiger tank and contaminated retums from pits. Pump #2 repaired 12/17/2004 00:00 - 03:30 3.50 WHSUR N FLUD DECOMP Phz 2 (wind 30-50 mph, -1 OF, CF -62F) Safety mtg wI vac truck drivers-3 trucks leave location in convoy to get more KCI and dispose of 420 bbls contaminated fluids Continue to pump 0.5 bpm wi 0 psi down tubing with IA SI Printed: 1/4/2005 9:52:48 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Page 2 of9 BP Operations Suml'1)ä.rYB~þÇ)rt L 1-01 L 1-01 WORKOVER NORDIC CALISTA NORDIC 2 Start: 12/15/2004 Rig Release: 12/31/2004 Rig Number: Spud Date: 4/19/1985 End: 12/31/2004 Date From - To Hours Task Code NPT Phase Description of Operations 12/17/2004 00:00 - 03:30 3.50 WHSUR N FLUD DECaMP PT and rate test pump #2 SD pump. SI master and IA valves on tree lAP 390, PVT 50 03:30 - 04:00 0.50 WHSUR P DECOMP Wind is increasing. Safety mtg re: all non critical tasks will end until crew change. Review Phase Weather/Road Conditions procedure 04:00 - 08:30 4.50 WHSUR N FLUD DECOMP Wait on vac trucks 08:30 - 09:00 0.50 KILL P DECOMP Hold PJSM in ops cab to discuss well kill procedure. 09:00 - 12:00 3.00 KILL P DECOMP WHP/IA: 0/333 psi. Circulate down tbg at 3 bpm, take rtns to tiger tank. Gas at surface in IA. IA pressure dropping. Hold 160 psi back pressure on IA with choke while pumping dn tubing. 12:00 - 15:00 3.00 KILL P DECOMP Continue to circulate down tbg. Open choke on IA. IA pressure slowly dropped to zero. Shut well in. Monitor. No Tbg or IA pressure. Well on a vac. 15:00 - 16:30 1.50 KILL P DECaMP Continue to circulate dn tbg. Wait on 50 bbls CaCo pill from MI. Phz 1/2 16:30 - 17:45 1.25 i KILL P DECOMP Pump 50 bbls Ca Co pill down tbg. 3.25 bpm @ 480 psi. Initial IA: 0 psi. Slow rate to 1 bpm as pill reaches perfs at 11900-12000. Once pillvis out of tbg, shut down pump. 17:45 - 18:30 0.75 KILL P DECOMP Monitor well during crew change Safety mtg re: set BPV/fill thru IA 18:30 - 20:00 1.50 WHSUR P DECOMP Verify tbg full. RD choke and kill lines from tree. RU to filllA while ND. Set BPV-tbg on sli vac Loading pipeshed wI DP 20:00 - 22:00 2.00 WHSUR P DECOMP Close TRSSSV. ND tree and adaptor flange. Pump 1.0 bpm down IA continutously thru fillup line 22:00 - 00:00 2.00 WHSUR P DECOMP NU 13-5/8" BOPE in 5 pieces 12/18/2004 00:00 - 08:00 8.00 WHSUR P DECOMP Continue NU 13-5/8" BOPE. Jack up rig to get Hydril inside Finish loading pipeshed w/4 rows of DP. Continue filling IA at 1.0 bpm. Phz 1/2 Fresh water has begun to flow from cellar, between surface conductor and 13-3/8" casing. No hydrocarbons or other contaminants have been detected in water. This is likely due to thawing induced from warm workover fluids. Crews will pump water back onto rig for beneficial re-use in work over operations. Notified L 1 pad operator and Drilling HSE Advisor. 08:00 - 15:00 7.00 WHSUR P DECOMP Continue to NU BOPs. RU kill & choke lines. Modify riser (shorten). Install riser between annular and rig floor. 15:00 - 00:00 9.00 WHSUR P DECOMP Test BOPs. J. Jones with AOGCC on hand to witness. 2 hrs NPT for test pump problems Phz 2 @ 1920 hrs (wind 30-50 E, blowing snow @ -2F) One valve on choke manifold failed and was rebuilt and retested while inspector was on location 12/19/2004 00:00 - 00:30 0.50 WHSUR P DECOMP Fin BOPE test. Phz 2 (wind 30-50 mph, blowing snow) Continue filling hole from IA at 1.0 bpm 00:30 - 03:00 2.50 WHSUR P DECOMP Safety mtg re: next steps/weather RU and pull blanking plug and tbg on sli vac. Leave BPV in hanger. Load Camco spooler to floor. Bleed OAP of 50 psi gas to bleed trailer Vac truck convoy of 2 arrive wI more KCl/fill pits. End filling IA at 1.0 bpm and SI. Close blinds and pump 2 tubing volumes of Printed: 1/4/2005 9:52:48 AM BP Operations Summary Report Page 3 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-01 L 1-01 WORKOVER NORDIC CALISTA NORDIC 2 Start: 12/15/2004 Rig Release: 12/31/2004 Rig Number: Spud Date: 4/19/1985 End: 12/31/2004 Date From - To Hours Task Code NPT Phase Description of Operations 12/1912004 00:30 - 03:00 2.50 WHSUR P DECaMP KCI at 1.5 bpm. Back in landing jt, BOLDS 03:00 - 04:00 1.00 PULL P DECaMP Unseat hanger w/60k and tubing went on good vac. Pull hanger to floor wI max 80k which broke back to 54k after tubing cut released (assumed). Monitor wellbore while filling with charge pump at approx 3-4 bpm. Remove control lines from hanger and hook to spooler. LD landing jt and hanger. Attempt to remove BPV on floor and no-go. Continue filling hole wI charge pump and no returns 04:00 - 04:30 0.50 PULL P DECOMP POOH LD tubing and spool up control line while filling wI charge pump wI no returns. LD 8 jts plus pup and running low on fluid, PVT =250 (used 300 bbls dn BS in 1.5 hrs). Vac trucks convoy off location. Recovered tubing is in good condition 04:30 - 07:00 2.50 PULL N WAIT DECaMP Stab TIW and circ down tubing at reduced rate of 1 bpm wI no returns while wo more fluid 07:00 - 07:15 0.25 PULL P DECOMP Hold PJSM with day crew to discuss hole fill, pulling & handling tbg from well. 07:15 - 10:45 3.50 PULL P DECaMP Two vac trucks on location. Load pits. Resume pulling tbg and spooling control lines. 10:45 -18:00 7.25 PULL P DECOMP Phz 1/2 LD SSSV and CIM. Release SLB spooling unit. Continue to POOH. 18:00 - 18:30 0.50 PULL P DECaMP Safety mtg re: Fresh Nordic crew/Nabors 2 move/hole fill/cellar pumping/wind 18:30 - 19:30 1.00 PULL P DECOMP Resume POOH LD tubing and LD GLM's. Continue to fill hole thru kill line at 1.0 bpm wI no returns-keeping pits full and using 3 vac trucks due to weather and well conditions. Pumping 1 gal/min cellar water to pits 19:30 - 20:30 1.00 PULL P DECOMP At 309 jts out (51 jts left) got strong gas flow from tubing. Stab TIW and monitor. No flow from BS so assume GLM #4 wI open pocket has reached FL (est 800'). Pump 2 tubing volumes to clear, but immediately came back gas. Fill BS at 5 bpm wI charge pump using 100 bbls and drive gas out of tubing until getting mostly air 20:30 - 22:20 1.83 PULL P DECOMP Resume filling wI kill line at 1.0 bpm and pull 23 jts to GLM #4 while tubing blowing air. LD GLM #4. Load out tubing from pipeshed. Resume POOH LD tubing while getting air back from filling ops 22:20 - 22:30 0.17 PULL P DECOMP LD jt #357 which was perforated wI 9 holes over 2' approx 5' from pin. Jt #358 was chemically cut completely thru about 1/2 of its diameter midway in the joint-assume overpull when pulling hanger was from pulling out of seal assy. Start to break connection and see trapped pressure 22:30 - 00:00 1.50 PULL P DECOMP WO hot tap from SWS. RU hot tap. Continue filling from kill line wI no returns 12/20/2004 00:00 - 02:45 2.75 PULL P DECOMP Hot tap each jt at pin end. Recovered 7 gal of white diesel smelling emulsion wI consistency of yogurt along with a few pieces of plastic coating under minimal pressure. First five joints below chemical cut jt were corkscrewed and got worse as each jt was pulled. Plastic coating density increased with depth too. Also had fine sand or scale in mixture Continue to fill hole at 1.0 bpm thru kill line wI no returns 02:45 - 06:30 3.75 PULL P DECOMP Had to pull double of jts 6 & 7 since buckled at connection. Hot Printed: 1/4/2005 9:52:48 AM Page 4 of 9 BP Operations Sumrn~ry:aE!PQrt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-01 L 1-01 WORKOVER NORDIC CALISTA NORDIC 2 Date From - To Hours Task Code NPT I Phase 12/20/2004 02:45 - 06:30 DECOMP 3.75 PULL P 06:30 - 08:00 08:00 - 08:30 08:30 - 15:00 1.50 PULL P 0.50 PULL P 6.50 PULL P DECOMP DECOMP DECOMP 15:00 - 16:00 1.00 FISH DECOMP P 16:00 - 16:15 16:15 - 19:00 0.25 FISH 2.75 FISH DECOMP DECOMP P P 19:00 - 20:30 1.50 FISH P DECOMP 20:30 - 22:00 1.50 FISH P DECOMP 22:00 - 00:00 2.00 FISH P DECOMP 12/21/2004 00:00 - 06:00 6.00 FISH P DECOMP 06:00 - 06:15 0.25 FISH P DECOMP 06:15 - 08:00 1.75 FISH P DECOMP 08:00 - 09:00 1.00 FISH P DECOMP 09:00 - 10:00 1.00 FISH P DECOMP 10:00 - 11 :00 1.00 FISH P DECOMP 11 :00 - 11 :30 0.50 FISH P DECOMP 11 :30 - 12:30 1.00 FISH P DECOMP 12:30 - 13:00 0.50 FISH P DECOMP 13:00 - 14:00 1.00 FISH P DECOMP 14:00 - 16:00 2.00 FISH DECOMP P Start: 12/15/2004 Rig Release: 12/31/2004 Rig Number: Spud Date: 4/19/1985 End: 12/31/2004 Description of Operations tap at bottom pin and got water wi no emulsion. Set in mousehole and cut wI tubing cutter 2' above connection. Found catcher sub 3' above cut Hot tap GLM #5 pin and drained water. Pulled last two jts and were real buckled and had seperated about 4' above the pup attached to packer. Will call fishing depth 11610' based on original tally. Found and recovered the mill and motor bit sub in good pipe (corkscrewed) about 4' above the ragged end Cut up last two joints, clean floor. Unload pulled tbg from pipe shed. Discuss options with town team. Continue to load, drift, and talley drill pipe into pipe shed. Load drill collars on drillers side of cat walk. Baker is prepping burning shoe to mill scoop guide on top of PBR. Replace hydraulic line support clamps along rig floor wall. Phz 1 Load wash pipe, shoe & handling tools into pipe shed. Install wear ring Hold PJSM with rig crew to discuss making up fishing BHA. MU Baker Fishing BHA #1 (8.0" x 4.75" burning shoe, wash pipe) Continue filling thru kill line at 1.0 bpm Operating cellar pump intermittently as volume has decreased MU 9 4-3/4" DC's PU kelly, torque connections. PT upper and lower valves as part of Initial BOPE test to 3500 psi TIH picking up 3-1/2 DP singles TIH picking up 3-1/2 DP Continue filling hole thru kill line at 1.0 bpm PJSM with day crew after tour change. Continue to PU drill pipe and fill hole. 270 jts in hole at 0600 hrs. PU kelly with 358 jts in. Tag fish 26' in on kelly. Set back kelly. Pull 24 stands of dp to get to "safety" for pumping MI pill. RU SLB pump truck & batch mixer to pump pill. Hold PJSM with cementer, vac truck drivers, rig crew to discuss mixing and pumping pill. Circulate down DP at 1 bpm while mixing pill wI no returns. PT DS @ 3500 psi DS pump 5 FW, 68 bbls large grain CaC03 pill followed by 5 FW at 4.4/500 psi down DP wI no returns. Close Hydril Rig displace wI 180 bbls 2% KCI at 4.3/360 psi. With pill at fish SI @ choke to zero psi. Bullhead pill to perfs at 4.3/500. After 40 bbls past packer had positive WHP which gradually built to 80 psi. Red rate to 2.5 bpm, then 1.0 bpm as pressure built to 340 psi. Cut displacement short by 5 bbls and bleed down WHP and take returns. Got diesel, crude and a little gas back so divert to tiger tank Continue to circ and gradually bring up rate to 3.75 bpm while getting steady 8.0 ppg returns. CBU at 3.75/2.751700 and returns gradually cleaning up (based on density). After approx 250 bbls back started losing more returns, but then slowly Printed: 1/4/2005 9:52:48 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Page5 of 9 BP Operations Summ~ryReport L 1-01 L 1-01 WORKOVER NORDIC CALISTA NORDIC 2 Date From - To Hours Task I Code NPT Phase 12/21/2004 14:00 - 16:00 16:00 - 16:45 16:45 - 19:30 19:30 - 20:00 20:00 - 21 :00 21 :00 - 00:00 12/22/2004 00:00 - 02:30 02:30 - 08:30 08:30 - 10:00 10:00 - 11 :30 11 :30 - 13:30 13:30 - 14:30 14:30 - 21 :00 21 :00 - 00:00 12/23/2004 00:00 - 06:00 06:00 - 09:00 09:00 - 15:30 2.00 FISH DECOMP P 0.75 FISH DECOMP P 2.75 FISH DECOMP P 0.50 FISH DECOMP P 1.00 FISH DECOMP P 3.00 FISH DECOMP P 2.50 FISH DECOMP P 6.00 FISH P DECOMP 1.50 FISH I DECOMP I I P 1.50 FISH DECOMP P 2.00 FISH 1.00 FISH 6.50 FISH DECOMP DECOMP DECOMP P P P 3.00 FISH DECOMP P 6.00 FISH DECOMP P 3.00 FISH DECOMP P 6.50 FISH , DECOMP P Start: 12/15/2004 Rig Release: 12/31/2004 Rig Number: Spud Date: 4/19/1985 End: 12/31/2004 Description of Operations getting part of them back (acts like washing pill away). Circ 3.7512.2/645 Divert thru pits to cuttings box to remove 80 psi bp thru hardline to tiger tank and circ at 3.75/2.65/650, but returns are still diesel/crude/KCI and too dirty to keep After 400 bbls back, divert to tiger tank when cuttings box full and still too dirty to keep. Red rate to 2.8/1.9/310 to minimize bp. After pumping 720 bbls returns are clean 2.9/2.0 shutdown to observe well. Well taking fluid wo pump. RID TIW valve and circulating hose. Blow down line to Tiger Tank. Pump down backside 1 bpm and RU to RIH. RIH wtih 24 stds from derrick. Kelly up. RIH tag fish at 11603' with 26' of kelly in. Upwt 143k dwn 108k rot 130k @ 290 amps 45 rpm's. Begin milling on 2-7/8" 3.0bpm in 2.0 out Slow milling ahead without torquing up and stalling. Milled to 11604'. Continue milling. Q= 3.0/2.0 w/3-4k wob 60 rpm's. Continue to have stalling problems. Milled to 11605.5'. Appear to have balled up some tubing up inside the washover shoe. Not able to make further progress. Standback and blowdown kelly. TOH. Pumping 1 bpm down annulus wI no returns Standback DC's and washover assy. Shoe was well worn externally and internally. Recovered a few small pieces of 2-7/8" tubing which were loose inside of wash pipe, one of which was part of the collar from the 6' pup above the seal assy. A few smaller pieces were in junk baskets Discuss. WO BOT to get identical 8-1/8" OD x 4-1/4" ID washover shoe assy from shop which had just been made (this one has metal muchers instead of cut rite) MU washover assy #2. MU 9 DC's and 5 stds CDL 50' TIH wI 3-1/2 DP Continue to fill from kill line at 1.0 bpm wI no returns Continue milling from 11605.5'. Pump 3.0 in 2.0 out 375psi. 3-6k wob 60rpms. Frequent stalls. Milled to 11606.5 Continue milling on junk tubing. Increased to 80 rpm's and 1 0-12k wob. Still numerous stalls. PU and setdown 15-20k on fish wo rotating after stalls. Seems to be helping. Slow but steady progress. Milled (or swallowed) down to 11608'. Last 1.5' went fairly smooth then torqued up. Pick-up but having trouble getting back down to 11608'. Seeing torque at 11605' again. Remill from 11605' to 11608', then slowly make progress to 11611.3' at 80-150 rpm, 10k wob, 400 amps, 120k rot, 100k dn, 140k up at 3.0/2.0/360. Mill to 11611.6' and slow progress. This could be the top of collar at the PBR extension so decide to quit PUH clean at 140k. RBIH clean to 11611.6' and stack 10k, clean Blow down kelly and set back TOH wI DP filling down kill line at 1.0 bpm wI no returns Printed: 1/4/2005 9:52:48 AM BP Op~rations Summary. Report Legal Well Name: L 1-01 Common Well Name: L 1-01 Spud Date: 4/19/1985 Event Name: WORKOVER Start: 12/15/2004 End: 12/31/2004 Contractor Name: NORDIC CALISTA Rig Release: 12/31/2004 Rig Name: NORDIC 2 Rig Number: I From - To Hours I Task Code NPT I Phase Description of Operations I 12/23/2004 '15:30 - 16:45 1.25 FISH P DECOMP Standback DC's and milling assy 16:45 - 17:15 0.50 FISH P DECOMP Find shoe well worn inside and outside wI no recovery inside. Discuss and will go fishing 17:15 - 19:00 1.75 FISH P DECOMP LD burnover assy 19:00 - 20:45 1.75 FISH P DECOMP PU Overshot BHA 20:45 - 00:00 3.25 FISH P DECOMP RIH 12/24/2004 00:00 - 03:40 3.67 FISH P DECOMP Continue to RIH with overshot fishing BHA. P/U single and kelly. Up wt 142k dwn wt 102k rot wt 118k 03:40 - 04:00 0.33 FISH P DECOMP RIH slight tag on top of fish at 11601'. Continue RIH to 11611'. P/U and latched fish. Jarred 11 times and packer pulled free. 04:00 - 06:00 2.00 FISH P DECOMP Circulate at 6bpm with 90% returns. Pumped 290 bbllead of 2% KCL water wI 4#/bbl biozan. Seeing some gas to surface after 550 bbl pumped. Reduced rate and turned into gas buster. 06:00 - 08:15 2.25 FISH P DECOMP Circ out gas thru buster 3.01?1580-can't see out rateldensity I due to gas 08:15 - 10:45 2.50 FISH P DECOMP Continue to circ 2.95/2.25/550 and out density slowly increased from 8.20 to 8.35 ppg. Open Hydril and incr rate to 6.0/1470 and start getting biozan back. Losing 1/2 returns of about 4 bpm over shaker-no noticeable metal except on magnets. Fin CBU until clean 6.0/1150 10:45 - 21 :00 10.25 FISH P DECOMP Blow down kelly and set back. Begin TOH wI packer. Tite on first stand and had to use jars. A little drag first 10 stds. POOH slow filling down kill line at 1.0 bpm wI no returns. Fill DP every 20 stds. Fill hole at halfway point w/1 00 bbls. Continue TOH pumping 1 bpm down annulus. 21 :00 - 22:30 1.50 FISH P DECOMP Standback DC's. UD fishing tools, overshot and PBR. UD seal assembly, packer and tailpipe. 22:30 - 23:15 0.75 FISH P DECOMP P/U BOT washover pipe and make service breaks. Clear floor. 23:15 - 23:25 0.17 EVAL P DECOMP PJSM. Review plan forward to P/U Howco RTTS. 23:25 - 00:00 0.58 EV AL P DECOMP P/U 9-5/8" Howco RTTS and Circulation Valve. 12/25/2004 00:00 - 06:00 6.00 EVAL P DECOMP RIH with 9-5/8" Howco RTTS to 11600'. RIU to test. 06:00 - 07:00 1.00 EVAL P DECOMP Fill hole wI 240 bbls. Takes 3.0 bpm now to keep hole full 07:00 - 08:45 1.75 EVAL P DECOMP Set RTTS @ 11600' DPM. Pressure test casing wI 7.8 bbls to 3000 psi for 30 min and lost zero psi. OA remained constant at 78 psi. PJSM. Bleed down press. Release RTTS. LD single (#361) 08:45 - 15:30 6.75 EVAL P DECOMP TOH wI RTTS filling thru kill line at 1.0 bpm 15:30 - 16:45 1.25 EVAL P DECOMP Load out RTTS, Load SWS control line spooler and centrifuge into pipeshed 16:45 - 17:00 0.25 EV AL P DECOMP Safety mtg re: eline ops 17:00 - 17:45 0.75 EVAL P DECOMP Bring eline tools to floor and RU 17:45 - 23:30 5.75 EVAL P DECOMP RIH wI SWS USIT logging tool. Log from 11650-3900'. No corrision seen. Lost downhole 1 small bowspring centrilizer off tools. RD SWS Filled from kill line @ 1.0 bpm while logging. 23:30 - 23:40 0.17 BOPSUR P DECOMP PJSM review plan forward with removal of wear bushing and PT BOPE. 23:40 - 00:00 0.33 BOPSUP. P DECOMP Pull wear bushing. 12/26/2004 00:00 - 07:00 7.00 BOPSUP P DECOMP Pressure test BOPE 250psi low 3500psi high, annular 2500psi. 07:00 - 08:30 1.50 CLEAN P DECOMP MU BHA #5 (6.75" junk mill wI boot bskts, DC's and jars). RIH w/2 stds DP Phz 1 @ 0730 hrs Printed: 1/4/2005 9:52:48 AM BP Qpf)rations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-01 L 1-0 1 WORKOVER NORDIC CALISTA NORDIC 2 Date From - To Hours Task Code NPT Phase 12/26/2004 08:30 - 10:30 2.00 CLEAN P DECOMP I I 110:30 - 11: 15 0.75 CLEAN P DECOMP 11: 15 - 11 :45 0.50 CLEAN N WAIT DECOMP 11:45 - 17:15 5.50 CLEAN N WAIT DECOMP 17:15 - 18:05 0.83 CLEAN N WAIT DECOMP 18:05 - 19:20 1.25 CLEAN N WAIT DECOMP 19:20 - 19:35 0.25 CLEAN P DECOMP 19:35 - 23:30 3.92 CLEAN P DECOMP 23:30 - 00:00 0.50 CLEAN P DECOMP 12/27/2004 00:00 - 06:00 6.00 CLEAN P DECOMP 06:00 - 06: 15 06:15 - 07:00 0.25 CLEAN P 0.75 CLEAN P DECOMP DECOMP 07:00 - 09:00 2.00 CLEAN P DECOMP 09:00 - 10:00 1.00 CLEAN P DECOMP 10:00 - 12:00 2.00 CLEAN P DECOMP 12:00 - 15:45 3.75 CLEAN P DECOMP 15:45 - 17:00 1.25 CLEAN P DECOMP 17:00 - 00:00 7.00 CLEAN P DECOMP Start: 12/15/2004 Rig Release: 12/31/2004 Rig Number: Spud Date: 4/19/1985 End: 12/31/2004 Description of Operations CDL 50', service crown Phz 2 @ 0900 hrs (wind 30-50 mph) Safety mtg re: hazard assessment due to weather TIH slowly due to weather. Winds getting worse Phz 3 @ 1115 hrs. Gusting to 60 mph on location. BOC indicator must have blown down. . . saw 90 mph on it a few minutes prior to seeing negative numbers Stab safety valve and cease tripping ops w/12 stds plus 9 collars in hole Continue to fill down kill line at 1.0 bpm wI 600 bbls on location. Advise fluid needs to Herb Williams for IMT consideration. Charter flight is delayed-crew change day for rig crews Fuel 8800 gal, water 150 bbls WOW WOW. Fits cancelled. Received 3 trucks wI KCI thru Heavy Eq escort-good tit mid morning. Sent 2 MT's back. PVT 250 Continue filling at 1.0 bpm Phz 2 Dig out. Do crew changes PJSM review plan forward. RIH with DP from derrick. Pick-up DP singles tagged at 11664'. Make-up kelly. With kelly picked up pumping 6bpm it took 150 bbls to see returns at surface. +/- 20% returns. Wts: 143k up, 95k dwn, 114k rot 360 amps. Washing down through previously layed CaC03 pill. Swapping over to 2%KCL w/2ppb biozan for some carrying capacity. Safety mtg/TL mtg re: nonroutine crew changeltodays activities Attempt to dress set down point near 7-5/8" liner top at 11694' DPM (30' in on kelly) so that connection can be made (can't get by wlo rotating) and no progress 6.0/<3.0/1130 (using 6.75" 6 bladed, flatbottom mill). Assume we are probably below the setting sleeve which is 7.65' long and 7"+ ID, but PBR below it is 9.0' long and is 6.75" ID (ID of 7-5/8" liner is 6.875") Circ and condition biozan water while discuss options Set and secure slips in rotary and able to rotate over lip and RIH wlo needing pups TIH picking up singles and RIH wlo pump looking for fill. Then, ream each joint. Liner was clean to tag at 11985' which was solid (perfs start at 11900') Start milling on junk. Very high torque and stalled out. Start milling wI 50 rpm, 5k wob, 420 amps (14k 'fibs), 112k rot wt, 140k up. Still have good returns 6.0/<3.0/1085 Mill to 11986.5' and torqued up. PUH and were temporarily immobile for 4 cycles. Pulled free wlo jars at 40k over. Ease back down and same thing w/20k overpull. Ease back down slower. No metal on magnets except fines, and no CaC03 in returns. Perservance paid off and had one more 20k overpull, then able to make kelly down at 11992'. Ream three times until clean Mill rather firm cement from 11992' 6.0/<3.0/1120 wI torqueldrag indicating some minor junk still in hole, then ream each joint. Milled to 12058'. Last 3' extremely slow going some minor problems but that has since cleared up ROP contiues to Printed: 1/4/2005 9:52:48 AM BP Qper$tiøn$Sl..Immary Report Page 8 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-01 L 1-01 WORKOVER NORDIC CALISTA NORDIC 2 Start: 12/15/2004 Rig Release: 12/31/2004 Rig Number: Spud Date: 4/19/1985 End: 12/31/2004 Date From - To Hours Task Code NPT Phase Description of Operations 12/27/2004 17:00 - 00:00 7.00 CLEAN P DECaMP very slow <1'/hr. 12128/2004 00:00 - 02:20 2.33 CLEAN P DECOMP Continue milling cement f/12058'. Reduced P-rate to 4bpm 50% returns. Finally broke through hard cement at 12065'. waB 9k, 70rpm's. Milled cement to 12150' 02:20 - 06:30 4.17 CLEAN P DECOMP Circulate well clean. Bump up rate to 6bpm 60% returns 06:30 - 10:00 3.50 CLEAN P DECOMP Continue to circ and getting good metal, cement and sand back now-all less than 1/4" 6.0/>3.0/1170 Put 2nd row of tubing in pipeshed. CBU until relatively clean 10:00 - 12:15 2.25 CLEAN P DECOMP Break kelly. POOH LDDP. Pipe pulling wet and hole staying full. RU and fill DP with 2% KCI wlo biozan 12:15 - 18:00 5.75 CLEAN P DECOMP POOH LDDP pumping remaining bio/KCL @ 1 bpm down annulus. 18:00 - 00:00 I 6.00 CLEAN P DECOMP Continue POOH sideways, while filling hole with KCL at 1.0 bpm. 12/29/2004 00:00 - 01 :30 1.50 CLEAN P DECaMP Continue POOH with drillpipe, laying down singles. Continue pumping at 1.0 bpm to keep the hole full. Round tripping vac trucks as needed for new 2% KCL. OAP=60 psi. 01 :30 - 02:30 1.00 CLEAN P DECOMP Lay down BHA. Mill recovered and gauged 6.5". Mill had significant center wear consistent with milling on junk. Both boot baskets were full of metal debris. The debris consisted large chunks of metal, including what appears to be a centralizer arm from a Schlumberger USIT tool. Photo of debris forwarded to town. 02:30 - 02:50 0.33 CLEAN P DECOMP Pull wear bushing. 02:50 - 03:10 0.33 CLEAN P DECaMP Safety meeting prior to rigging up Schlumberger slickline for a wireline junk basket run. 03: 10 - 04:45 1.58 CLEAN P DECOMP RU slickline. 04:45 - 14:30 9.75 CLEAN P DECOMP Run slickline junk basket with an 8.5" guage. Made it down to 9150' and stopped. POH heavy recovered some sandlcement few bits of rubber and very small metal shavings. Run back in hole and made it the top of the 7-518" liner. TOH recovered several small pieces of banding material, scale, rubber and small amount of sand total material equaling 1 quart. RD slckliners 14:30 - 14:45 0.25 RUNCOrvP RUNCMP Hold PJSM and review plan forward. 14:45 - 17:15 2.50 RUNCOrvP RUNCMP RU floor to run 4-1/2" completion tubing. 17:15 - 17:25 0.17 RUNCOfvP RUNCMP Hold PJSM for running tbg. 17:25 - 18:00 0.58 RUNCOrvP RUNCMP Run 4-1/2" 12.6# L-80 IBT-M tbg. 18:00 - 18:30 0.50 RUNCOfvP RUNCMP Hold PJSM with night tour crew prior to resumeing running tubing. Verify tubing tally to ensure that it is correct. Review tubing run order with crew. 18:30 - 00:00 5.50 RUNCOfvP RUNCMP Continue to run 4-1/2" tubing completion. On joint 100 at midnight. 12/30/2004 00:00 - 11 :00 11.00 RUNCOfvP RUNCMP Continue running 4-1/2" completion. Filling down the backside while running completion at 1.2 bbllhr. Slick running in the hole with the packer. Make-up SSSV control line and PT install SS band on each of the 49 jts above valve. Conünue running tbg no problems entering 7-5/8" liner top. Make-up landing jt and TIW valve. Land tbg in wellhead. 11 :00 - 16:00 5.00 RUNCOfvP RUNCMP RIU lines to IA. Pump 600 bbls 2%KCL water treated with Coexit corrision inhibitor down annulus at 3bpm max rate to I avoid packer washout damage. 20% returns 16:00 - 18:00 2.00 RUNCOfvP RUNCMP Drop RHC ball rod. RU chart recorder. PT tbg to 3500psi for 30 Printed: 1/4/2005 9:52:48 AM BP Operations$umI"rtÇtry. Report Page'90f9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-01 L 1-01 WORKOVER NORDIC CALISTA NORDIC 2 Start: 12/15/2004 Rig Release: 12/31/2004 Rig Number: Spud Date: 4/19/1985 End: 12/31/2004 Date From - To Hours Task Code NPT Phase Description of Operations 12/30/2004 16:00 - 18:00 2.00 RUNCOMP RUNCMP min held good. Bleed down to 1500psi. Line up on IA and PT to 3500psi for 30 min. 18:00 - 18:20 0.33 RUNCOMP RUNCMP Safety meeting with night tour to discuss plan forward. 18:20 - 18:30 0.17 RUNCOMP RUNCMP Bleed tubing pressure down while holding 3000 psi on back I side. Good indication of shear of DKC shear valve. Pump to I confirm. Able to pump down lA, taking returns from tubing at 1 ! bpm, 40 psi. Confirm good shear of DKC valve. i 18:30 - 20:00 1.50 i RUNCOMP RUNCMP Rig down landing joint. . Dry rod in TWC. PT TWC to 500 psi from below by pumping down IA. 20:00 - 00:00 4.00 RUNCOMP RUNCMP ND 13-5/8" stack. 12/31/2004 00:00 - 01 :00 1.00 RUNCOMP RUNCMP Finish ND 13-5/8" stack. 01 :00 - 04:30 3.50 RUNCOMP RUNCMP NU 4-1/8" Cameron production tree. Test control lines. Fill tree with diesel. PT tree to 500 psi low pressure test and to 5000 psi for high pressure test, passed ok. 04:30 - 05:15 0.75 RUNCOMP RUNCMP Rig up valve crew lubricator. Pull TWC. 05:15 - 05:30 0.25 RUNCOMP RUNCMP Safety meeting prior to pumping diesel freeze protection. 05:30 - 09:45 4.25 RUNCOMP RUNCMP Spot Hot Oilers rig. Run lines and PT to 3000psi. Hold PJSM I I with new crews. Pump 160 bbls of heated (60deg) diesel for I I ! freeze protection at 2bpm. Open fA to tbg and and U-tube. FP i to 2200'. 09:45 - 10:15 0.50 WHSUR P RUNCMP Set BPV useing lubricator.. 10:15 - 17:00 6.75 RIGD P POST Disconnect hoses used for FP operations. Clean-up cellar. Clean mud, cuttings, slop tanks. UD kelly Rig Released at 1700 hrs 12-31-2004 Moving to Y-06 Printed: 1/4/2005 9:52:48 AM TREE = 4~1/8" CAMERON WELLHEAD = FMC A'CTÜAT6R'~' ÄXELSÖÑ K6'. ElEV = 44' Bþ: Ëi.él;;~"-"' . '-'"'1"4' - . KOP = 3200' i0a~~ngl~;--- . ,.. 6f¿çf9~õ~ì Datum MO = 11903' Datum TVO = - 8700' SS L 1-01 Workover As Built SAFETY NOTES: I I \\<oqß X ~ I TOP OF 7 ~5/8" LNR 1-1 ~I .. . I I 2 JTS ~ 13*3/8" CSG, K-55, 68# 13-3/8" CSG, 72#, L~80. 10 = 12.415" -I 40891 ~ 9-5/8" CSG, 47#, L-80, 10= 8.681" l-t 118971 ~ PERFORA TION SUMMA RY REF LOG: LOT/CNL ON 05/14/85 ANGLE AT TOP PERF: 45 @ 11900' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 5" 12 11900-12000 0 01/15/89 5" 12 12076-12153 S 01/15/89 5" 12 12200~12310 S 01/15/89 - 17-5/8" LNR. 29-7#, L-80, .0459 bpf, 10 = 6.875" l-t ~6' \~~ro FROM DRLG - DRAFT , - 21001 1-1 4 1/2" Well Star TRSSSV ~ .l: 5 GLM's 2995' 5727' 8414' 1 0509' 11485' 4 1/2" Tubing I 115541 -t 41/2"XNIP, 10=3.813" I 115751 l-t 4 1/2" x 9 5/8" Packer I 115991 -I 41/2" X NIP, 10 = 3.813" 4 1/2" Tailpipe, 11747' ~ Existing Zone 6 perfs Cement was cleaned out to -12, 150' MD during workover 12169' 1-1 BRIDGE PLUG RUBBER ELEMENT 1 121701 l-t 2 FAILED BRIDGE PLUGS 1 REV BY OA TE REV BY COMMENTS 07/30/04 KSBITLP FISH LOST IN HOLE 08/09/03 12/31/04 MF/GS RIG WORKOVER LlSBURNEUNrT WELL: L 1-01 ÆRMrT No: 1850550 API No: 50-029-21317-00 SEC 1, T11N, R14E, 4231' FEL & 4731.17' FNL DATE OS/23/85 01/19/89 07/20/01 10/25/01 1 0106/02 02/28/03 COMMENTS ORGINAL COM PLETION RWO RNITP CORRECTIONS GClKAK API # CORRECTION JRCITP 13~3/8" CSG CORRECTION JP/KAK REMOVE WANER SAFÐY NOT~ BP Exploration (Alaska) I/-{:.;' ti';:: /'/' \ :¡":.,¡ í'r' . \..) . ¡ ," ¡' I '. '. !:; ì' I I ".', "')ll'u\'il[ (1.1" L LrÜ L ,_I (,(f\ I' ¡:.:¡ ,I L- LW u~ I':, !! I-; "r:', "1F¡ r--:. nil /i1¡[.\,.LJli¡//\\ ! 1\ \ ¡, { ,\"' ',". 'í \ !'" iA~ L6lf\J liD U ~ if¡j .I i FRANK H. MURKOWSKI, GOVERNOR ! / . ALAS KA 0 IL AND GAS CONSERVATION COMMISSION í 333 W. 7'H AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 12, 2004 Mr. BructYJ. Williams GPB Operations Integrity Manager BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 ¡g5 -.rO5S Dear Mr. Williams: The Alaska Oil and Gas Conservation Commission ("Commission") received well safety valve system (SVS) test reports from BP Exploration (Alaska) Inc. at Prudhoe Bay Unit Lisburne sites as follows: Location Date of SVS Test Failure Rate PBU Ll April 23, 2004 30.0% PBU L2 April 26, 2004 16.7% PBU L3 April 27, 2004 50.0% Copies of the SVS Test Reports are attached. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. Commission policy, as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13,2003, supported retention of the 10% failure threshold. Effective the date of SVS test, and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on PBU Ll, L2, and L3 must be tested every 90 days. When testing is schedul, must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to vÙ th SVS test. Sincerely, ÇJ/~ J . Norman, Chair Commissioner Daniel T. Seamount, Jr. Commissioner 3 Attachments cc: AOGCC Inspectors (via email) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Ron White AOGCC Rep: Waived Submitted By: Ron Marquez Date: 04/23/2004 Unit/Field/Pad: Greater Pt McIntyre/Lisburne/Ll Separator psi: LPS 450 HPS 450 Well Permit Separ Set LIP Test Test Test Date Tested and or Oil, WAG,GINJ, Number Number PSI PSI Trip Code Code Code Passed Retest or SI GAS, CYCLE, SI L 1-0 1 1850550 7/19/2003 SI Ll-02 1851720 450 350 320 P 5 P 4/27/2004 OIL L 1-09 1850010 450 700 690 P P P OIL L1-10 1850830 4/30/1990 SI Ll-14 1851400 3/10/1996 SI Ll-15A 2031200 450 350 350 P P P OIL Ll-21 1780300 450 600 550 P 5 P 4/27/2004 OIL LI-27 1891220 5/10/1994 SI Ll-28 1880250 12/17/1992 SI Ll-30 1900180 3/28/1995 SI Ll-31 1980150 450 350 350 P 5 P 4/27/2004 OIL Wells: 5 Components: 10 Failures: 3 Failure Rate: Remarks: LI-02 4/23/2004: Called grease crew and heater Ll-21 4/23/2004: Called grease crew Ll-31 4/23/2004: Called grease crew Page 1 of 1 SVS PBU LIS L 1 04-23-04,xls 1. Type of Request: STATE OFALASKA COMMt~°,ON 0 R ~ OIL AND GAS CONSERVATION ' REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown__ Stimulate __ Plugging X Perforate _ Pull tubing Alter casing Repair well Pull tubing Oth er 2. Name of Operator ARCO Alaska. lng, 3. Address P, O. Box 100360, Anchorage, AK 4. Location of well at surface 99510 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB ~4' 7. Unit or Property name Prudhoe/Lisburne Unit 8. Well number feet 2183' FSL, 2448' FWL, Sec. 1, T11N, R14E, UM At top of productive interval 1176' FSL, 1227' FWL, Sec. 12, T11N, R14E, UM At effective depth 614' FSL, 1062' FWL, Sec. 12, T11N, R14E, UM At total depth 571' FSL~ 1050' FWL, Sec. 12, T11N, R14E, UM 12. Present well condition summary Total Depth: measured 1 2856' feet true vertical 9572' feet Plugs (measured) L1-01 9. Permit number/approval number ~'.~1-~- 55 ~,,~ 10. 'APl number 50-029-21317-00 11. Field/Pool LISBURNE OIL POOL 12112' md Effective depth: measured 12180' feet true vertical 9020' feet Junk (measured) None Casing Lan gth Structural Conductor 80' Surface 4 0 5 9' Intermediate Production 1 1 8 6 7' Liner 1 1 9 0' Size Cemented 2 0" 2000# Poleset 13-3/8" 2600sx PF E& 400sx G 9-5/8" 800sxClassG& 300 sx G 7-5/8" 200sxClassG Measured depth True vertical depth 110' 110' 4089' 4041' 11987' 8851' 11610'-12800' 8648'-9528' Perforation depth: measured 11900'-11970' true vertical 8852'-8905', 8916'-8925', Tubing (size, grade, and measured depth) 2-7/8" 6.5# L-80 tbg w/tail @ 11722' md Packers and SSSV (type and measured depth) Pkr @ 11640' md, & SSSV @ 2010' md 13. Stimulation or cement squeeze summary 11 988'-1 2000', 1 2050'-121 64' 8961 '-9043' Intervals treated (measured) Wahoo 7,6,5 Treatment description including volumes used and final pressure please refer to the attached RECEIVED JUN - 8 1992 Alaska 0JJ & Gas Cons. Commission Anchorage 14. Reoresentative Daily Averaae Production or Iniection Date OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 354 970 2002 471 Subsequent to operation 966 2162 1692 568 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector ~ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~..~'~(~ Title Lisburne Operations Engineering Aide Form 10-404 Rev 05/17/89 SUBMIT IN DUPLICATE Date 1/21/92: 1/23/92: Lisburne Well L1-01 Hugback Procedure Event Rigged up Arctic Coiled Tubing. Set inflatable bridge plug at 12,050' md. Dumped 33' of cement on top. Rigged down Arctic Coiled Tubing Unit. Tagged top of cement at 12011' md with slickline. Returned well to production. R CEIVED JUN - B 1992 Alaska Oil 8, Gas Cons. Commission Anchoraoe LA[ STATE OF ALASKA A , ,,~ OIL AND GAS CONSERVATION COMMISSI APPLICATION FOR SUNDRY APPROVALS 1. I ype OT Mequest: Abandon Suspend Operation shutdown Alter casing Repair well Plugging X Change approved program Pull tubing Variance 2. Name of Operator 5. Type of W.elh ARCO ALASKA INC. Devmopment X 3. Address Exploratory Stratigraphic · P.O. BOX 100360 ANCH. AK 99510 Service 4. Location of well at surface 2183' FSL, 2448' FWL, Sec. 1, T11N, R14E,UM At top of productive interval 1176' FSL, 1227' FWL, Sec. 12, T11N, R14E, UM At effective depth 614' FSL, 1062' FWL, Sec. 12, T11 N, R14E, UM At total depth 571' FSL, 1050' FWL, Sec. 12, T11N, R14E, UM Re-enter suspended well Time extension Stimulate___ Perforate.__ Other 6. Datum elevation (DF or KB) RKB 54' 7. Unit or Property name Prudhoe/Lisburne Unit 8. Well number L1-01 feet 9. Permit number 10. APl number 50-029-21317 11. Field/Pool LISBURNE OIL POOL 12. Present well condition summa.ry Total depth: measurea 12856' feet true vertical 9572' feet Plugs (measured) 12112' md Effective depth: measured 12180' feet true vertical 9020' feet Junk (measured) NONE Casing Length Size Structural Conductor 80' 20" Surface 4059' 13-3/8" Intermediate Production 11867' 9-5/8" Liner 1190' 7-5/8" Perforation depth: Cemented 2000~ Poleset 2600sx PF E & 400sx G 800 sx Class G +300sx G 200 sx Class G Measured depth True vertical depth Measured Depth True Vertical Depth 8852'-8905', 8916'-8925', 8961'-9043' 110' 4089' 11987' 11610' - 12800' 11900'-11970', 11988'-12000', 12050'-12164' 110' 4041' 8851' 8648'-9528' Tubing (size, grade, and measured depth) 2-7/8" 6.54t L-80 tbg w/tail @ 11722' md Packers and SSSV (type and measured depth) Pkr @ 11640' md, & SSSV @ 2010' md 13. Attachments Description summary of proposal X RECEIVED NOV 1 1991 Alaska Oil & Gas Cons. Commission Anchorage Detailed operations program BOP sketch 14. Estimated date for commencing operation November 15~ 1991 16. If proposal was verbally approved 15. Status of well classification as: Oil_~.. Gas Suspended Name of approver Date approved Service 17. I hereby certify that the fgregoing is true and correct to the best of my knowledge. Siqned /~ ./~_~.,~~ T.E. Krawietz Title: Sr. OperationEn,qr. ATO484 /~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative my witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- ~ 4. ORIGINAL SIGNED BY Approved by order of the Commission Form 10-403 Rev 06/15/88 Date J Approval No. .:',:~, ~ p ~' c.,: v ~-.,. d Copy F.:~tur~',ed LONNIE C. SMITH Commissioner Date II SUBMIT IN TRIPLICATI::' Lisburne Well L1- 01 Plug Back Procedure e ge . TIH w/ 2-1/8' inflatable bridge plug. Well control provided by wellhead valves and lubricator. Inflate bridge plug at 12,060' md and dump 40' of cement on top. TOH w/setting tool. Return well to production. Estimated Static BHP = 3,750 psig at 8,900' ss. RECEIVED NOV 1~ 1991 Alaska Oil & Gas Cons. Commission Anchorage ARCO ALASKA INC. LISBURNE ENGINEERING DATE: FROM: April 15, 1991 Laura S. Lahrson ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: LOGS: (1 blueline, 1 sepia) LGI-06 Gas Detection Log Run L1-01 Collar Log Run L3-12 Production Profile Run L3-12 Production Profile t,~k Run L3-18 Perforation Record Run L5-04 Production Profile mq~ Run L5-31 D-Prop-RES-GR-RWD- 1:240 TVD Run L5-31 D-Prop-RES-GR-RWD- 1:600 TVD Run .L5-31 D-Prop-RES-GR-RWD ~ 1:240 MD Run L5-31 D-Prop-RES-GR-RWD- 1:600 MD Run TAPES: L5-18 Depth Shifted Data L5-23 Depth Matched DLL- SL SIGN AND ~~~ TO: ~AURA S. ~A~RSON ' ARCO A~AS~, ~C. 700 G S~T; ATO ~0¢ 99510 3/02/91 Camco 3/22/91 Camco . 2/21/91 Camco 3/18/91 Camco 11/08/90 Halliburton 1/27- 28/91 Camco 1/04/91 Teleco 1/04/91 Teleco 1/04/91 Teleco 1/04/91 Teleco 8/04/90 Atlas 5/31/90 Atlas RECEIVED BY: State of Alaska TRANSMITTAL # 643 ARCO ALASKA INC. LISBURNE ENGINEERING DATE: 10-24-89 FROM: TINA KINCAID ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: LOGS: ~ L3-23 ~. L4-30 ~--~ L4-31 L5-1 ~ L4-14 ~=~'L4-14 ~ L4-14 ~ L4-14 ~ L4-14 ~ L4-14 ~ L4-14 ~ L4-14 ~ L4-14 ~ L4-14 ~ L1-1 COMPLETION RECORD PRODUCTION PROFILE SE'ri'lNG SERVICE (EZSV) TEMPERATURE LOG PHYSICAL FORMATION CNL IN CASING DUAL LATERLOG NATURAL GAMMA RAY SPECTRA LOG REPEAT FORMATION TESTER COMPENSATED NEUTRON LITHO DENSITY- RAW DATA COMPENSATED NEUTRON LITHO DENSITY, - POROSITY CEMENT EVALUATION CEMENT BOND LOG GCT GYRO DIRECTIONAL SURVEY PRODUCTION PROFILE RUN 1 10-13-89 RUN 1 8-27-89 RUN1 9-12-89 RUN 1 7-6-89 RUN 1 9-21-89 RUN 1 9-30-89 RUN 1 9-30-89 RUN 1 9-3O-89 RUN 1 9-3089 RUN 1 9-30-89 RUN 1 9-30-89 RUN 1 9-30-89 RUN 1 9-3O-89 RUN 1 10-14-89 RUN 1 10-14-89 SCHLUMBERGER CAMCO ATLAS HALLIBURTION ANADRILL SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER 'SCHLUMBERGER SCHLUMBERGER CAMCO TAPES: "~,,,~ L4-14 L4-14 OPEN HOLE LOGS RFT RUN 1' 9-29-89 RUN 1 9-30-89 SCHLUMBERGER SCHLUMBERGER SIGN AND RETURN TO: TINA KINCAID ARCO ALASKA, INC. 700 G STREET; ATO 409 ANCHORAGE, ALASKA 99510 RECEIVED BY: BP STATE OF ALASt ,,,.,,,.= )fi Gas Co ,s. .' 'Anchorage TRANSMITTAL # 624 r FT - - DATE: 8-16-89 FROM: TINA KINCAID ARCO ALASKA INC. LISBURNE ENGINEERING ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: TAPES: L5-33 GCT RUN 1 6-29-89 LOGS: L1-1 COLLAR LOG RUN 1 7-24-89 L3-28 CEMENT EVALUATION LOG (CET) RUN 1 7-23-89 L'3-28 CEMENT BOND LOG (CBT) RUN 1 7-23-89 L3-28 GCT RUN 1 7-23-89 L3-28 GCT RUN 2 8-7-89 '"-..J_3-28 GCT RUN 3 8-7-89 L5-1 PRESSURE DATA RUN 1 7-6-89 ~"-~1,5-32 PERFORATING RECORD RUN 1 6-5-89 i PRESSURE REPORTS: LL5-33 BHP REPORT RUN 1 7-24-89 5-33 BHP REPORT RUN1 7-24-89 SCHLUMBERGER CAMCO SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER SCHLUMBERGER HALLIBURTON HALLIBURTON CAMCO CAMCO SIGN AND RETURN TO: TINA KINCAID ARCO ALASKA, INC. 700 G STREET; ATO 409 ANCHORAGE, ALASKA 99510 RECEIVED BY: EXXON BP ¥" STATE'OF ALASKA TRANSMITTAL # 621 Alaska 0il & Gas Cons. Anehora.Qe 1. Type of Request: 2. Name of Operator STATE OF ALASKA (' '"-" "' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Pull tubing Alter casing Stimulate Repair well ARCO Alaska. In¢, 3. Address P. O. Box 100360, Anchorage, AK 99510 Service 4. Location of well at surface 2183' FSL, 2448' FWL, $EC.1, T11N R14E, UM At top of productive interval 1176' FSL, 1227' FWL, SEC. 12, T11N, R14E, UM At effective depth 614' FSL, 1062' FWL, SEC.12, T11N, R14E, UM At total depth 571' FSL, 1050' FWL, SEC.12, T11N~ R14E~ UM 12. Present well condition summary Total Depth: measured 12856'MD feet true vertical 9572' TVD feet Effective depth: measured 12180' MD feet true vertical 9020' TVD feet 5. Type of Well: Development Exploratory Stratigraphic Pull tubing .) Other "6~'Da~m'-elbv~.:tion (DF or KB) RKB 54' 7. Unit or Property name Prudhoe Bay/Lisburne Unit 8. Well number L1-1 9. P~r~.~number/approval number /85-55.~9-354 10. APl number 50-029-21317-00 11. Field/Pool Lisburne Oil Pool feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 80' 20" 4059' 13-3/8" 11867' 9-5/8" Plugs (measured) 12180' MD 12128' MD Junk (measured) NONE 2000 # Poleset 2600 sx PF 'E' & 400 sx CIG 800 sx Class G & 300 sx CS 1 200 sx Class G Measured depth True vertical depth 110' MD 110' TVD 4089' MD 4041' TVD 11987'MD 8851' TVD 11610'-12800'M D/8648'9528'TVD 11988'-12000', 12050'-12164' 1190' 7-5/8" measured 11900'-11970', true vertical 8852'-8905', 891 6'-8925',8961 '-9043' Tubing (size, grade, and measured depth) 2 7/8", 6.5#, L-80, tubing w/tail @ 11722' Packers and SSSV (type and measured depth) 9 5/8" Baker 'HB'@ 11640 SSSV: AVA SC SSV 13. Stimulation or cement squeeze summary Intervals treated (measured) 14. Tubing Pressure Treatment description includin~l volumes used and final pressure Reoresentative Daily Averaoe Production or Iniection Dat~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 555 2799 1966 1400 452 Prior to well operation 190 2473 2973 1730 440 15. Subsequent to operation 16. Status of well classification as: Oil ,,, X Gas Suspended Service Attachments Copies of Logs and Surveys run Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date Au~ 9, 1989 SUBMIT IN DUPLICATE Sig"fi~""~~ '"~.f]~~ Title Encjineerincj Aide Firm 10-404 Rev 06/15/88 APPLICATION FOR SUNDRY APPROVAL R i 1. Type of Request: Abandon __ Suspend __ Alter casing m Repair well __ Change approved program __ Operation shutdown ~ Re-enter suspended well ~ Pluggin[j~lL Time extension m Stimulate __ Pull tubing __ Variance __ Perforate __ Other 2. Name of Operator .,~{.CO Alaska Thc. 3. Address P.O.Box 100360, Anchorage, AK 99510 5. Type of Well: Developmentxx Exploratory Stratigraphic Service 4. Location of well at sudace 2183' FSL, 2448' FWL, Sec.1, TllN R14E, UM At top of productive interval 1176' FSL, 1227' FWL, Sec.12, TllN R14E, UM At effective depth 614' FSL, 1062' FWL, Sec.12, TllN R14E, UM At total depth 571' FSL, 1050' FWL, Sec. 12, TllN, R14E, UM 6. Datum elevation (DF or KB) RKB 54' feet 7. Unit or Property name Prudhoe Bay Unit/Lisburne 8. Well number Li-1 9. Permitnumber 85-55 10. APInumber 50-- 029-21317 11. Field/Pool Lisburne Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12856 ' MD feet Plugs(measured) 9572 ' TVD feet 12112 ' MD 12112 ' MD feet Junk (measured) 9020 ' TVD feet None Casing Length Structural Conductor 80 ' Sudace 4059 ' Intermediate 11867' Production Liner 1190 ' Perforation depth: measured Size Cemented 20" 2000 # Poleset 13-3/8" 2600 sx PF 'E' & 400 sx C1 G 9-5/8" 800 sx Class G & 300 sx CS 1 7-5/8" 200 sx Class G Measured depth True vertical depth 11900'-11970' 11988'-12000' 12076'-12111' true vertical ll0'lV[D ll0'TVD 4089 'MD 4041 'TVD 11987 'MD 8851 'TVD 11610'-12800 'MD/8648 ' 9528 ' TVD 8852'-8905', 8916'-8925', 8961'-8986' ~bing(size, gmde, andmeasumddepth) 2 7/8", 6.5#, L-80, tubing w/~ail @ 11722' Pac~rsandSSSV~ypeandmeasureddepth) 9 5/8" Baker 'HB' @ 11640 SSSV: AVA SC SSV Alaska Oil & Gas Anchorage 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation August 18, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x__x Gas__ Suspended_ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~/.,~(_ ~ ( ~ Title ~--~~ ~.rtcJo 'J~ ~, FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity m BOP Test m Location clearance ~ Mechanical Integrity Test __ Subsequent form required 10- ~I~ Al~p~'oved Copy Original Signed l~ty Returned Approved by order of the CommissJ~vi d 'W!; Johnston ,¢~.- / '~-' ~:~_~ --- commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment No. 1 1. Set plug below Wahoo 6 perforations with a cement cap. 2. Rig down. 3. Open well to flow after cement has been allowed to properly set. WIRELINE BOP EQUIPMENT 4 I 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRELINE RAI'I$ 5000 PS1 4 1/6" LUBRICATOR 2 4. 5000 PS1 4 1/6" FLOW TUBE PACK OFF AU~-l?-~89 15:50 ID:LISBURNE EN~INEERINS TEL N0:263-4894 ~628 POi ..... ,, ANO/ATO kleeilege center Feollmlle Trenemlelion P.o. Box 1~ II III ..... III I 111 I I __11 I Inetruotlone 1) Number Pege~ ::) Remove 3) U~e Only Bl~ok Ink 4) Use Only Clenr/I)eflnecl S) Think you for your cooperation · -III ...... I ..... II III dl~ III J ....... III II I I I I II . .., Mos.age Center Comments: .. I . III IIII III I I I I III · __ Room No. ........... II I I I II O~y 8ta~e I I iiiii I I I I i. . .... ... m.. ,a ·,, __ Fax It Xerox ~e8 To: [ I . .. _JilL_Il .. Ved~v # ............... ~ ,,, ...... N~ 8ultra-Room Bic~-Rm. ~ o .............. ,,,,,,, , ,--- ,,,,, ,,,, , e ................... hi II I .......... . .... ~llll · .__.~ _1 . . . ~O_'_...of pnGea following oover!, ,,~4t i ~,'~~ ~.o~,. r*~_~_ ~ ~ 1 " ....... ' ...... - ,,,, ,, ,, ~ ........ Miohinee Omnlfax G-39'8 (Grp 1, 2. 3) (907) 285-6470/6890/6488 Omnffax Gi-ge'd (Gq) 1, 2, $) (007) 263-4956 Confirm/Verify (907) 286,.6260 .Treeh Telex 'o gO - 26122 ARCO ALASKA AHG I D: L I SBURNE ENG I NEER I NG TEL NO: 265-4894 .. ~628 PO~ L1-01 PLUG DAILY HISTORY 7-15-89 Set plug with slips at 12,128' ELMD. Ran 1 sand and 3 cement dump bailers. 7-16-89 Shut bridge plug equalizing valve. Ran 3 cement dump bailers. 7-22- 89 Dump bailed 5 feet of cement. PBTD = 12,112' ELMD. ~..:.!;~.sl<a 0]1 & .~4as Cons., Co.n:trr~issk~r..i STATE OF ALASKA APPLI TION FOR SUNDRY APPRO [ 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Operation shutdown __ Re-enter suspended well __ Plugging ~ Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator ARCO Alaska Inc. 3. Address P.O.Box 100360, Anclorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at sudace 2183' FSL, 2448' FWL, Sec.l, TllN R14E, UM At top of productive interval 1176' FSL, 1227.' FWL, Sec.12, TllN, R14E, UM At effective depth 614' FSL, 1062' FWL, Sec.12, TllN, RI~E, UM At total depth 571' FSL, 1050' FWL, Sec.12, TllN, R14;E, UM 6. Datum elevation (DF or KB) RKB 54' feet 7. Unit or Property name Prudhoe Bay Unit/LisburnE 8. Well number 9. Permit number 85-55 10. APl number 50-029-21317 11. Field/Pool Lisburne Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12856' MD feet Plugs(measured) 12180' MD 9572 ' TVD feet 12180' MD feet Junk(measured) None 9020 ' TVD feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth 80' 20" 4059 ' 13-3/8" 11867 ' 9-5/8" 2000 # Poleset 2600 sx PF "E' & 400 sx C1 G 800 sx Class G & 300 sx CS 1 200 sx Class G 1.190' 7-5/8" measured 11900'-11970' 11988'-1.2000' .12050'-12164' truevertical 8852'-8905' 8916'-8925' 8961'-9043' .. True vertical depth Tubing (size. grade, and measured depth) ll0'MD ll0'TVD 4089 'MD 4041 ' TVD 1198 7:'MD 8851 'TVD ., 11610'-12800 'MD/8648 ' 9528 ' TVD REEE'IVED , . MAY .,r,:,.., 2 7/8", 6.5#, L-80, tubing w/tail @ 11722' Pac~mandSSSV~ypeandmeasureddepth) q 5/R" ~ak~r '~' @ 1.1640 SSSV; AVA SC 13. AEachmenm Descri¢onsummarydproposal.z_ Detailedoperationsprogram__ ~as~ ~il & Gas Cons. C~missi0r~ "~,i,. ~ch0rage BOP sketch __x 14. Estimated date for commencing operation 115. Status of well classification as: May 15,1989 16. If proposal was verbally approved Oil .~x Gas __ Suspended __ Name of approver Date approved Service 17. I herebyf, e~tify that the fo/egoing is true and correct to the best of my knowledge. Signed ~_~,,~' ~/~ Title ~),~/'2',/$-/'~:5 ~'/V~/~'~__-~ Date 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 Commission ORIGINAL SIGNED BY LONNIE C; SMI.TH .~pproved Copy Returned Commissioner ]Approval No.,~ Date ,~---// Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment No. 1 1. SI well. RU S/L. 2. Pull orifice at 5447' MD and replace with 1-1/2" dummy GLV. POOH. RD S/L. 3. fiI well for minimum of four days to allow zonal pressures to equalize. 4. Set plug above lower Wahoo 5 perforations with a cement cap. 5. Rig down. 6. Open well to flow after cement has been allowed to properly set. WIRELINE BOP EQUIPMENT 4 jiI· iL I I I I I I I 2 1. $000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRELINE RAMS 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK OFF ARCO ALASKA IN~. LISBURNE ENGINEERING DATE: 4-18-89 FROM: JOHN BARBO ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: FINALS FOR L1-1 PRODUCTION PROFILE RUN I 3/19/89 CAMCO FINALS FOR L5-25 TDT-P RUN I 2/15/89. SCH SIGN AND RETURN TO: RECEIVED BY: EXXON STANDARD JOHN BARBO ARCO ALASKA, INC. 700 G STREET; ATO 415 ANCHORAGE, ALASKA 99510 PLANO Alaska Oil & Gas Cons. Co~issio~ ~' Anchorage D&M STATE OF ALASKA CENTRAL FILES TRANSMITTAL MEMORANDUM State 'of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: LonniecommissionerC Smith /~"'/J~... DATE: February 23, 1989 roLE NO: D.ADA. 158 THRU: Michael T Minder F~'~' Sr Petroleum Engineer TELEPHONE NO: SUBJECT.' BOP Test AAI PBU Li-1 Permit No. 85-55 Lisburne Oil Pool FROM: Doug Amos Petroleum Inspector Tues.day, January l0t 1989: I traveled this date from Anchorage to prUdhoe BaY tO witneS~ the BOP test at AAI PBU LI-1 well. The testing commenced at 2:30 p.m. and was concluded at 6:30 p.~g] The inside kill line manual valve failed this test, and was rep~iced and retested on 1/12/89. I filled out an AOGCC BOP inspection report which is attached. In summary, I witnessed the BOP test at AAI PBU LI-1 well on AUDI Rig No. 4. Attachment 02-001A (Rev. 8/85) O&G #4 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COM}~ISSION B.O.P.E. Inspection Report InsDect0r [i)outC~ Operator Well h_~- I Location: Sec ~ T[\~R I~EM ~, Drillin~ Contractor ~TVq~.~ RiF Location, General w"- Well Sign General Housekeeping ;,,'Rig Reserve Pit Mud Systems Visual Audio Trip Tank Pit Gauge o/' I} ~'/ ti BOPE Stack II Test Pressure Annular Preventer~lJl '~/9~ . Pipe- Rams ~" 516x~o Blind Rams ~ I~ Choke Line Valves ~, :H.C.R. Valve ~4' ~ Kill Line Valves h Check Valve Test Results: Failures Dace ~A~ Well U%- t Representative ~, Representative ~ ' '~ ACTUATOR SYST~ ~', %~'. Oo Full Charge Pressure ~OO psig Pressure After Closure ~O psig Pump incr. clos. pres. 200 psig. min ~ sac. Full Charge Pressure At:ained: ~ min~ sec. N2 I~001 ~~0~/~ ~0 psig Remote /' Blinds switch cover Kelly and Floor Safety Valves Upper Kelly I /Test Pressure Lower Kelly I /Test Pressure Ball Type ~ %,~,.,,.Test' Pressure Inside BOP ~ ~'TesC Pressure Choke Manifold { ~ Test Pressure NO. Valves ' ~ "~'" No. flanges Ii Adjustable Chokes I ~ Hydraui~ally ooerated choke ~ ~'~ Test Time ~ hrs. O(D ,... Repair or Replacement of failed equipmen: to' be made within 3 days and Inspector/ Commission office notified. P~C~ &~- ~O'7 I~ ..~ ..... } Distribution orig. - AO&GCC -. cc - Operator cc - Supervisor Inspector (" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION coaals~{~O~ ~ ~ I ~ ./~, WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [Z GAS ~ SUSPENDED ~ ABANDONED ~ SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-55 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21317 4. Location of well at surface 9. Unit or Lease Name 2183' FSL, 2448' FWL, Sec.1, T11N, R14E, UN Prudhoe Bay Unit/Lisburne At Top Producing Interval 10. Well Number 1178' FSL, 1229' FWL, Sec.12, T11N, R14E, UN L1-1 At Total Depth 11. Field and Pool 571' FSL, 1050' FWL, Sec.12, T11N, R14E, UN Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Li sburne 0i l Pool 54' RKBI ADL 28302 ALK 2313 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 04/19/85 05/08/85 05/23/85*I N/A feet MSLI 1 ,7. Total Depth (MD+TVD) 18. Plug Sack Depth (Ml~TVD) ,9. DirectionalSurvey ! 20. Depth where SSSV set 121. Thickness of Permafrost 12856'ND,9572'TVD 12201 'ND~9070'TVD YES [~ZX NO [] 2010 feet MD 1900' CAonrox) · . 22. Type Electric or Other Logs Run D IL/LSS/GR, LDT/CNL/GR/Cal, EPT/PCD. EGT/CNL/GR. DLL/NSFL/ANS. (;CT. CET. (;BT 23. CASING, LINER AND CEMENTING RE(~ORD' SETTING DEPTH MD CASING SIZE~WT. PER FT. GRADE .TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-kO .~mr~ 11rt, '~n,, ~nnn,~ D,.,'t,,..,,~ / ...... 13-3/8" 68.0#/72. )# K-5~/I-I (~ R,,.f ~,t~Rq, !7-!/2" 2600 s× PF "E" $ ".OO (× Class 9-5/B" 67_0# I-Rn ~,,.~ 11897' !2-!/~.'' 850 =x Cf:cc C & 300 ~ CS '. 7-5/8' 29.0# L-80 11;fi10' 12R~13, R-!/9" 913rl SX r'l~_$ O 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) See Attached 2-7/8" 11,722' 11,640' 26. ACID, FRACTURE, CEMENT SQUEEZE, EI~C. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED Plug ~ !2,838' 150 sx Class G Perfs f/12200'-1;310' 243 sx Class G See Report of Sur dry 0perations~ dated 12/2/86~ for stinulation. 27. N/A PRODUCTION TEST Date First Production I Method of Operation {Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIo TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA None JAN ,Nas~.;0i! .a' Gas Cons..Commission '" ~chorage w NOTE: Tubing was run & well perforated 1/26/86. Workover and SQZ performed 1/19/89. Form 10-407 DAN/WC01 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30, NAME Top Wahoo Zone 7 Top Wahoo Zone 6 Top Wahoo Zone 5 Top Wahoo Zone 4 Top Wahoo Zone 3 Top Wahoo Zone 2 Top Wahoo Zone 1 GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH Truncated 11,891 ' 1 2,036' 1 2,192 ' 12,346' 1 2,424 ' 12,573' 8845' 8950' 9063' 9177' 9235' 9348' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and grav.ty, GOR, and time of each phase. N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /'~'~~'~ , Title Area Dr,,,,ng Eng,neerDate. 'hJ'/Oc~ ........... i'_ ...... INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on ali 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. ~tem 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 WELL COMPLETION OR RECOMPLETION REPORT AND LOG L1-1 (Continued) Item 12 - Perforation Depths MD 11900 11988 12076 12078 12089 12099 12109 12130 - 11970' - 12000' - 12113' - 12136' 12143 - 12153' TVD 8852 8916 8979 8980 8988 8995 9003 - 9005' 9018 - 9022' 9027 - 9035' - 8905' w/12 spf, 90° phasing - 8925' w/12 spf, 90° phasing REC,,'EIVED JAN ,~ ~ ""',",,'~ .Alaska Oil.& Gas Cons. Comr~ission 'Anchorage AL~..,A el L AND STATE OF ALASKA " GAS CONSERVATION COMMI~.,,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pedorate __ Pull tubing __ Alter casing __ Repair well __ Pull tubing ,'" Other Workover 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2183' FSL, 2448' FWL, Sec. 1, T11N, R14E, UM At top of productive interval 1178' FSL, 1229' FWL, 5ec.12, T11N, R14E, UN At effective depth 973' FS'L, 1169' FWL, Sec.12, T11N, R14E, UN At total depth 571' FSL, 1050' FWL, Sec.12, T11N, R14E, UN 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 54 ' 7. Unit or Property name Prudhoe Bay Unil;/Lisburne 8. Well number L1-1 9. Per'nit number/approval n~mber 85-55/8-853 ' 10. APl number 50-- 029-21317 11. Field/Pool Li sburne 0i1 Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12856 'ND feet 9572 ' TVD feet 12201 'MD feet 9070 ' TVD feet Plugs(measured) Junk (measured) Plug ~ 12201 - from cmt. squeeze. None Casing Length Structural 80' Conductor 4059 ' Surface Intermediate 11867 ' Production Liner 1190, Perforation depth: measured Size 20,' 13-3/8" 9-5/8" 7-5/8!' See attached Cemented Measured depth True vertical depth 2000# Poleset 2600 sx PF 'E' & 400 sx Class G 800 sx Class G. & 300 sx CS I 200 sx Class G llO'MD, llO'TVD 4089 'MD 4041 'TVD 11897 'MD 8851 'TVD 11610 '-12800 'MD/8648 '-9528 'TVD true vertical See attached Tubing (size, grade, and measured depth) 2-7/8,', L-80, tbg w/tail ~ 11722' Packers and SSSV (type and measured depth) Baker 'HB' pkr ~ 11640' & AVA '~c-ssv' ~SSV e :~Ql{l' 13. Stimulation or cement squeeze summary Intervals treated (measured) Perforati OhS f/12200 ' -12310 ' Treatment descriDtien including volumes used and final pressure /.~ sx ~,/ass ~ CBT. RE, CEiYED 'Nask Oil & Gas Cons. :, chomge ": 14. N/A 'Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments ~16. Status of well classification as: Copies of Logs and Surveys run ~ I Daily Report of Well Operations .~' * Oil ," Gas.__ Suspended ~ 17. I hereby certify that the~o~rego/j~g is true and correct to the best of my kn°Wledc~e. Signed / - Title Regional Drilling Engineer · Workover We1 ' Form 10-404Rev06/15/88 / * We." 1 History ' (Oani) SW04/010 Service Date (/~-£/~? SUBMIT IN DUPLICATE (m REPORT OF SUNDRY WELL OPERATIONS L1-1 (Continued) Item 12 - Perforation Depths MD 11900 - 11970' 11988 - 12000' 12076 12078 12089 12099 12109 - 12113' 12130 - 12136' 12143 - 12153' TVD 8852' - 8905' w/12 spf, 90° phasing 8916' - 8925' w/12 spf, 90° phasing 8979' 8980' 8988' 8995' 9003' - 9005' 9018' - 9022' 9027' - 9035' ARCO Oil and Gas Company Well History - Initial Report - Daily InalructJona: Prepare and submit the "lnJ§al RIHd" on Ihe first Wednesday alta! a wall is spudded or wa,kava, operations are started. Daily work prior to SPudding should be summarized on the form giving inclusive dates only. District County. 9sr~sh Or Oorougn Field Lease or Unit Auth. or W.O. no. Title Operator Spudded or W.O. begun I Date and depth Complete record for each day reported as of 8:00 a.m. &aDZ 4 01/10/89 ( TD:12856 PB:12788 SUPV:BB 01/11/89 ( TD:12856 PB:12788 SUPV:BB 01/12/89 ( TD:12856 PB:12788 SUPV:GG 01/13/89 ( TD:12856 PB:12788 SUPV:GG 01/14/89 ( '11):12856 PB:12788 SUPV:GG APl: Hour 01/09/89 1930 HRS ARCO w.i. 40.000n Prior status if · W.O. KILLING WELL MW: 8.5 FSW ACCEPTED RIG AT 1930 HOURS 1-9-89. SITP - SICP - 1800 PSI, BLED TBG AND CNG NO RETURNS - WELL TAKING FLUID ON STRONG VACUUM. MIXED 100 BBL HEC PILL. TO 100 PSI. PUMPED 8.5 PPG SEAWATER DOW~ THE THG WITH CNG OPEN FOR RETURNS, DAILY:S32,650 CUM:$32,650 ETD:S32,650 iFC:S?20,000 LD 2-?/8" TUBING MW: 8.5 FSW PUMPED 50 BBL HEC PILL, MONITORED WELL. SET BPV, ND TREE, NU AND TESTED BOP'S SHEARED SBR. PUMPED DOWN TBG AND ESTIMATED FLUID LEVEL AT 2380'. PUMPED 100 BBL HEC PILL, OBSERVED WELL - ON VACUUM. PULL AND LD 2-7/8" PRODUCTZON TBG. DAlLY:S25,158 CUM:$57,808 ETD:S5?,808 iFC:S?20,000 TIH W/ 3-1/2" DP MW: 8.5 FSW TO!; AND LD 2-7/8# PROD STRING. RU TO RUN DP. INSTALL AND TEST RAMS. INSTALL ~EAR RING AND STRAP BHA. MU BHA AND RIH W/ 3=1/2" DP. DAILY:$2$,8$8 CUM:$83,666 ETD:S83,666 EFC:$720,000 TIN W/ MILL MW: 8.5 FSW PO AND RIH WITH DP, ENGAGED BAKER FB-1 PACKER AT 11661', ROTATED RIGHT AND RELEASED PACKER, PULL i JOINT. CIRCULATED 200 B~LS SEAWATER - NO RETURNS, P~MPED 100 BBL HEC PILL - NO RETURNS, MONITOR AND FILL WELL. TOH W/ DP, SHUT DOWN AND SHOT FLUID LEVEL AT 1000-1100', TOH W/ DP AND LD FB-1 PACKER AND STRADDLE EQUIPMENT AND LOWER SEAL ASSEMBLY. MU MILL AND BHA AND RIH W/ DP. FILLING WELL AT 30 BBLS/HR WITH NO RETURNS. DAILY:S26,518 CUM:$110,184 ETD:S110,184 EFC:$720,000 SETTING EZSV MW: 8.5 FSW TIH W/ MILL, TAGGED DB PACKER AT 12028' DP MEASUREMENT. MILLED PKEAND PUSHED DOWN HOLE TO 12459'. SHOT FLUID LEVEL AND FOUND AT 1000'-1100'. POOH W/ MILL. RU SCHLUMBERGER AND RIH W/ EZSV, EZSV STUCK AT 12244', ATTEMPTING TO WORK EZSV FREE. DAILY:S75,725 CUM:$185,909 ETD:$185,909 EFC:$720,000 01/15/89 ( TXH W/ EZSV MW: 8.5 FSW TD:12856 EZSV STUCK AT 12244', COULD NOT MOVE - COULD NOT SET, PULLED PB:12788 OUT OF ROPE SOCKET. POH W/ E-LINE AND RD SCHLUMBERGER. RIH SUPV:GG WITH GRAPPLE AND TAGGED FISH AT 12439', LATCHED AND PULLED FREE, POH AND LD E-LINE TOOLS - FULL RECOVERY. MU EZSV ON DP AND RIH. DAILY:S38,518 CUM:$224,427 ETD:S224,427 EFC:$720,000 The above Is corre~t .... Signature ' · Date/ Title ' For forn~'~at~n a~d~'rl~tlon, see Procedures Manual, Section 10, Drilling. Pages 86 and 87. AR3B-459-1-D INumberall daily well history forms consecutively no. aa they are prepared for each well. ' IPage I ARCO Oil and Gas Company Daily Well History--interim InstnJctioes: This form is used during drilling or wOrkover operations. If testing, coring, or perforating, show Iormation name in describing work performed. Number ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlsrlm" sheets until linal completion. Report official or representative test on "Final" form, I) Submit -Inlerlm" sheets when filled Out but not less frequently than every 30 clays, or (2) on Wednesday of the week in which oil string ia set. Submit weekly for workovsrs and Iollowlng setting of oil slrin§ until completion. District Field ARCO ALASKA INC. ICountyorParish ]Stat~K NORTH SLOPE Lease or Unit LISBURNE L1-1 LISBURNE Well no. Date and depm as of 8:00 a.m. 01/16/89 ( TD:12856 PB:12179 SUPV:GG 01/17/89 ( TD:12856 EB:12179 SUPV:GG 01/18/89 ( TD:12856 PB:12201 SUPV:GG Complete record for each day while drilling or workover in progress AUDI 4 RIH W/ PERF GUNS MW: 8.5 FSW TIH W/ EZSV ON DP, SET EZSV AT 12180' MD, SHEAR OUT & CIRCULATE W/ NO RETURNS. STING INTO EZSV AND ESTABLISH INJECTION AT 3 BPM W/ 250 PSI. SQUEEZE WAHOO 4 WITH 53 BBLS OF CLASS G CEMENT, FINAL SQUEEZE PRESSURE 700 PSI. TOH W/ EZSV SETTING TOOL. RU ATLAS E-LINE AND RUN 8.5" OD GR/JB TO TOL, RAN 14' DUMMY PERF GUN AND TAGGED PBTD AT 12179' MD. PERFORATED AT 12109-113', 12130-136', 12143-153' MD. RIH W/ GUN %2. DAILY:S71,590 CUM:$296,017 ETD:S296,017 EFC:$720,000 TESTING BOP RAMS MW: 8.5 FSW PERF 12076,12078',12089,12099'. RD ATLAS E-LINE. RIH W/ 9-5/8" RTTS AND SET AT 11675', TESTED CASING TO 2500 PSI WITH 8.5 PPG SEAWATER. POH AND LDDP. RiG UP TO RUN 2-7/8" COMPLETION. DAILY:S63,654 CUM=$359,671 ETD:S359,671 EFC:$720,000 FREEZE PROTECTING MW: 8.5 FSW MU AND RIH WITH 2-7/8" COMPLETION. SET BAKER HB PACKER AT 11640'. SHEARED PBR AND DISPLACED WELL TO 8.5 PPG INHIBITED SEAWATER. FREEZE PROTECTING WITH INHIBITED DIESEL AT REPORT TIME. (AVA 'SC-S~V' SSSV @ 2010', BAKER 'HB' PKR @ 11640', & TT @ 11722'.) DAILY=S33,350 CUM:$393,021 ETD:S393,021 EFC:$720,000 The above is correct '~ A ,~ $,gn~.ur. /')// J,~. // . I,D."t/J., t,.-~,, I'"'~ .~ ~ Drilling, Pagas 86 and 87 H · ' AR3B-459-2-B INumber all daily well history forms consecutively as they are prepared for each well. IPage no, ARCO Oil and Gas Company Daily Well History-Final Report Instructions: PreDare and submit the "Final Report" on the first Wednesday alter allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be eubmilted also when operations are susoended for an inclefimte or aooreciable length ct time. On workovers when an official test is not requireO u0on comDletion, reoort completion and representative test data m I~locks provided The "Final Report" form may be used for reporting the entire ooeration ~t space ~s avmlabla. District ~GO ALASKA I Fie~ ~I~U~ ~Lease or ~: I Auth. or W.O. ~UU~ ITitle I Accounting cost center code I Stat~l~K JaJ.~t~ Ia.L-IIWell no. 50--029--ZX3~1 Operator /~,.Kr~U IA.R.Co. ~p. oooo I Spudded or I Complete rece~lJJ;~, eJ~ch day reported Date end depth aa of 8:00 a.m. oii~i~ TD:12856 PB:12201 SUPV:BB otal number of wells (active or inactive) on this Dst center prior to plugging and I [abandonment of this well IHour 1:~30 ttK~ IPrior status if a W,O, I ~v~ ~ut~ mw; 8.5 ~'~w FREEZE PROTECTED TOP 2600' OF TUBING AND ANNULUS WITH INHIBITED DIESEL. LANDED TUBING AND TESTED TUBING TO 3000 PSI AND ANNULUS TO 2500 PSI. SET BPV, ND BOP'S AND NU TREE. TESTED TREE TO 5000 PSI. SHEARED SHEAR-OUT SUB. WAITED ON WEATHER 7.5 HOURS AND RELEASED RIG AT 0130 HRS 1-19-89. DAILY:S196,401 CUM:$589,422 ETD:S589,422 EFC:$720,000 Old TD New TD Released rig Date PB Depth K nd of rig Classifications (o11, gas, etc.) Type completion (single, d. ual, otc,) Producing method Offlcla reservo r name(s) Potential test data Well no. Date Reservoir Producing Interval OII or gasTest time Production OII on test Gas per day . Pump size, SPM X length Choke size T.P, C.P. Water % OCR Gravity Allowable Effective date corrected The above la correct -~ / Signature ,-'~ Drilling, Pages 86 and 87, INumber all daily well history forms consecutively I Page no. · las they are prepared for each well, I I AR3B-459-3-C Olvlilon of AtlantlcRIchfleldCompany ~S~URN~ ~ENG~N~E~RING DATE: 1-2n-Rq FROM: PAM LAMBERT ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: CH Finals ~Li-1 ~Li-1 ~ L5-25 ~ L5-25 ~ L5-25 Junk Basket 6.5" Gauge ring record 1-14-89 Run 1 5" Collar Log 1-15-89 Run'l 5" AWS Compensated Neutron Log 1-8-89 Run 1 5" Sch GCT Directional Survey 1-8-89 Run 1 5" Sch CBL 1-8-89 Run 1 5" Sch Sch ( '/ ~.~ Oil & Gas Cons, Commisei~ RECEdeD BY: '"~i~.:'.~l.,.c,,liOJaga..''.,:';~''' ' ....... PLEASE SIGN AND RETURN TO: PAM LAMBERT . ARCO ALASKA INC. 700 G STREET ATO 477 ANCHORAGE, AK. 99510 CENTRAL FILES D&M .EXXON PLANO STANDARD STATE OF ALASKA TRANSMITTIAL # 611 " STATE OF ALASKA " A ~,.,KA OIL AND GAS CONSERVATION COM MI~,.,,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate Pull tubing ~ Variance __ Pedorate __ Other Z~_ 2. Name of Operator AR~(3 kl~.nka_ In~, 3. Address P. 0. Box 100360~ Anchorage~ AK 4. Location of well at surface 99510 Type of Well: Development Exploratory Stratigraphic 60 Service 2183' FSL, 2448' FWL, Sec.1, T11N, R14E, UN At top of producbve interval 6. Datum elevation (DF or KB) RKFI .St~, feet 7. Unit or Property name Prudhoe Bay Unit:/Lisburne 8. Well number L1 -1 9. Permit number Pool 1178' FSL, 1229' FWL, Sec.12, TllN, R14E, UM j L[iV'EDI At effective depth ~], 10. APl number 614' FSL 1062' FWL Sec.12 TllN, R14E~ UM I 50-- 029-21317 At total depth ~,~ ~ ~ .; 571' FSL 1050' FWL Sec 12 TllN, R14E, UN [ Lisburne 0il 12. Present well condition summary ,::~iaSJ~ .~il & Gas Gone, Total depth: measured 1 2856' MD feet Plugs(~,ll~J.~..rag~":.~""~ione true vertical 9572 ' T V D feet .~ iye..,cl I:l h' r~easured ,~f~.t,~ ~ 1 ~ E ~ue vertical Casing Longth 80' 0il~l~(~rns. Commission 405 9, Intermediate Production 11 867 ' Liner Perforation depth: measured1190, true vertical 1 2788'MD feet Junk(measured) 951 8 ' TVD feet Size Cemented Production logging tool & ap 1000' wireline below tubing (12035' ND) Measured depth True vertical depth 20" 2000 # Poleset 1313/8'' 2600 sx PF .'E ' & 400 sx Cl G 9 -5/8" 7 -5/8" 800 sx Class G & 300 sx CS I. 200 sx Class G 110'MD 110'TVD 4089 'MD 4041'TVD 11897'MD 8851 'TVD l1610'-12800'ND/8648'-9528'TVD 11900'-11970' 11988"-12000' 12050'-12164' 12200''12310' 8852'-8905' '8916'-8925' 8961'-9043' 9069'-9150' Tubing (size, grade, and measured depth) 2 - 7 / 8", 6 .5 # , L - 80 , t u b i n g w / t a i 1 @ 1 2038 ' Subsequent Work l~eported on Packers and SSSV (type and measured depth) ~o:rm No...~'O ~/ Dated 9-5/8" Baker 'FH' @ 11,653, 7-5/8" Baker 'DB' ~ 12012' SSSV: Camco TRDP-1A , 13. Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch ~__ 14. Estimated date for commencing operation 115. Status of well classification as: December 1: 1 16. If proposal was verbally approved " Oil ~ Gas ~ SuSpended .__ Name of approver Date approved '. Service' 17. I hereby certify t, bat, thg~regoing is true and correct to the best of my knowledge. ' Signed // . Title Regional Drilling EngJneerDate · _ / . ' FOR COMMiSSiON ~_1~ pl~lLY£ ^ ~;; ,, ,~ 1 Conditions of approval: Noti~ Commission So representative may Witness ' · ' "" ~Approval No. Plug integrity ~ BOP Test ~ Location clearance ~ . ,. I Mechanical Integrity Test ~ Subsequent form requireo ~u- " " . I.ON~.!"r: c, :-~,~,!TH Re?~ned Approved by order of the Commissioner //~.~ ¢ Commissioner Date ///'-"/"~' Form 10-403 Rev 06/15188 SUBMIT IN TRIPLICATE ,to) L1-1 WORKOVER COST ESTIMATE OBJECTIVE' Pull the 2-7/8" single selective completion, isolate and squeeze the Wahoo 4 perforations, perforate the Wahoo 5, run a 2-7/8" single packer completion, release the rig and perform an acid stimulation on the Wahoo 5 and 6. 1) MIRU WW1. 2) Circulate kill weight fluid through GLM at 11,598'. Set BPV. 3) ND tree. NU BOPE and test. Pull BPV. 4) Engage tubing hanger. POOH with 2-7/8" tubing and seal assembly. 5) RIH with 3-1/2" DP and retrieve 9-5/8" packer and PBR barrel. 6) RIH with mill and PRT to recover 'DB' packer at 12,012'. 7) RIH w/cmt, retainer on DP. Set retainer at +12,170'. 8) Establish injection rate through retainer. 9) Squeeze the Wahoo 4 perforations through the cement retainer. 10) POOH with cementing/running tool. 11) RIH with 6-3/4" bit, clean out cement to top of retainer. POOH LDDP. 12) RU E-line unit. 13) RIH and perforate the Wahoo 5. RD E-line unit. 14) RIH with 2-7/8" single packer completion. Set packer at +11,640'MD. 15) MU tubing hanger, land tubing, pressure test tubing and set packer, test annulus and packer. 16) Set BPV. ND BOPE. NU tree and test. 17) Release rig. 18) Perform acid stimulation on Wahoo 5 and 6. Workover Fluid' 8.6 ppg seawater Anticipated Bottomhole Pressure- 3850 psi LWK/022.3 ANNULAR PREVENTER § BLIND RAMS 5 I TUBIN6 HEAD 1. 16" CONDUCTOR SWAGED TO 10-3/4" 2. 10-$/4" CASING HEAD 3. 5000 PSI TUBING HEAD 4, 15-5/8" - 5000 PSI PIPE RAMS 5, 13-5/8" - 5000 PSI BLIND RAMS 6, 15-5/8" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS ;5000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. ;5. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1, FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RE'I'R. ACTED.,'T'OC, PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD, RUN IN LOCK-DOWN SCREWS IN HEAD. ;5, CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4, TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES, 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES, BLEED TO ZERO PSI, 6, OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7, INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. ~ ;!.] ~_jO:.:~ 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED Gas COilS, .~O.I~IlI~$$iO~I1ANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND )l, ll(;hol'agIl WITH ZERO PSI DOWNSTREAM, BLEED SYSTEM TO ZERO PSi. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO :3000 PSi FOR 10 MINUTES, BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG, MAKE SURE MANIFOLD AN[ LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO ;5000 PSI, 12, TEST KELLY COCKS AND INSIDE BOP TO ;5000 PSI WITH KOOMEY PUMP, 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. JULY 28, 1906 { POOL 102) ARCO Alaska, h( Post Oflide uox 100360 Anchorage, Alaska 99510-0360 1-elephone 907 276 1215 July 28, 1987 Ms. Fran Jones Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Dear Fran: Mi scel 1 aneous GCT Surveys Enclosed are addit.ional copies of the following 1L-6 2A-2 1L-15 2A-3 1L-16 2A-4 L1-1 2D-11 L2-28 2D-12 2G-8 2G-10 2G-13 If you have Si ncerely, any questions, please call me at D. Gruber Associate Engineer JG:pk JG/78 Enclosures GCT surveys: 263-4944. RECEIVEo A/a~ika Oil & Gas Cons. Commissio~ Anchorage ~ RCO AI;~;~ka. I;tc. is ,'t Subsidiary of AtlanllcRIchllehtCompany ARCO ALASI~ INC. LISBURNE ENGINEERING Date: 12-19-86 From: Pam Lambert Enclosed are the following: CH Final for L1-9 Gamma Ray 1-15-86 Run 1 5" DA CH Final for LGI #10 Collar Log 10-16-86 Run 1 5" DA CH Final for LI-1 Collar Log 1-21-86 Run 1 5" DA E Elms _. ~ - Nasla Oil & Gas Cons. Commission Anchcra~e Received by: Please sign and return to~ Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M EXXON STATE STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 126 STATE OF ALASKA . AL~ ,A OIL AND GAS CONSERVATION CO( .ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate~)~ Plugging [] Perforate [] Pull tubing [] Alter Casing [3 Other ~ 2. Name of Operator 5. Datum elevation (DF or KB) ARCO ALASKA, INC. RKB 54 Feet 3. Address 6. Unit or Property name P. O.B. 100360, ANCHORAGE, AK. 99510 Prudhoe Bay/Lisburne 7. Well number L1-1 4. Location of well at surface 2183' FSL, 2448' FWL, At top of productive interval Sec. 1, TllN, R14E, UM 8. Approval numbs/A 9. APl number 029-21317 50-- 10. Pool LISBURNE OIL POOL 1178' FSL, 1229' FWL. Sec. 12, TllN, At effective depth 614' FSL, 1062' FWL, Sec. 12, TllN, At total depth 571' FSLw 1050' FWLt Sec. 12t TllN, 11. Present well condition summary Total depth: measured 12856' feet true vertical 9572 ' feet RI4E, UM R14E, UM R14E, UM Plugs (measured) Effective depth: measured 12788' feet true vertical 9518 ' feet Casing Length Structural 80 ' Conductor 4059 ' Surface Intermediate 11867' Production 1190' Liner Size Junk (measured) PRODUCTION LOGGING ooL ^.D 000' Ce~Te~d BELOW M~~e~IL ( 12~ ~e~l depth 20" 2000# POLESET(app) 110' 13-3/8" 2600 sx PF "E" & 4089' 400 sx class G 9-5/8" 800 sx class G & 11897' 300 sx CS I 7" 200 sx class G 11610-12800' Perforationdepth: measured 11900'-11970', truevertical 8852'-8905', 8916'-8925', ~bing(size, gradeand measureddepth) 2-7/8", L80, 12838' 110' 4041' 8851' 8648-9528' 11988'-12000', 12050-12164', 12200'-12310' 8961-9043' 9069'-9150' Packers and SSSV (type and measured depth) Packers; 7" 12. Stimulation or cement squeeze summary Intervals treated (measured) SEE ATTACHED SUMMARY Treatment description including volumes used and final pressure BAKER FH @ 11653' & 7" BAKER RECEIVED DEC 1 5 1986 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection D,~t~. mi ,-,_-.. ~,~,s.:a u,, & Gas Cons. Commission OiI-Bbl Gas-Mcf Water-Bbl ,.,=s~ng 'Fressure ATEIR~j~ressu re N/A 3100 2582 0 910 700 14. Attachments 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 ~ ~~J6('(jC~F(~A/~-~~~~~'''/'' ~'"'- LISBURNE OP. COORD. Signed Title 12/2/86 Date Form 10-40'4 Rev. 12-1-85 Submit in Duplicate Sequence of Events LI-1 Wahoo Zone 4 02/13/86 '23:35 hrs. to 24:00 hrs. Rig up Halliburton for perforation breakdown treatment (W-4). Pressure test lines to 5000 psi - good. Pump 10 bbl diesel w/10% Musol "A." Pump 72 bbl 15% HCL . Average rate & pressure = 3.4 BPM @ 4800 psi. Switch to diesel flush. Pumped 81 bbl diesel. After pumping 65 bbl diesel press, broke from 4100 psi to 3290 psi. Final rate and press. = 2.8 BPM @ 2150 psi. (sharp pressure break could be due to communication with Wahoo Zone 5) 02/14/86 01:45 Open well to tanks. Well flowing at 2232 BOPD, 120 BWPD, WHP of 1090 psi. 02/17/86 Rig up Schlumberger to run production logs across Wahoo 4 interval (temp, RA tracer & GR) with tools at 12,063. Pull weight check. Tools moving but with 4000 lb weight. E-line parted at top sheave of lubricator @ 5500 ~ pull. SI well. Fish wire and tool string next 1 1/2 months (Schlumberger's expense). 03/29/86 Pull E-line cable out of 2 7/8" tubing. Unknown length of wire & tool string left in hole. (Estimate wire left = 700-1000'). Schlumberger has agreed to fish remaining cable & tool string during the first scheduled workover on this well. Wahoo Zone 5 cannot be perforated due to fish. 08/17/86 Set BCP in AVA BPL to isolate Wahoo Zone 6.' 08/11/86 Rig up Halliburton to pump perforation breakdown treatment in Wahoo 6. Pump 10 bbl diesel w/10% Musol "A." Pump 81 bbl 15% HCL w/additives. Displace acid with 81 bbl diesel. Average treating rate = 1.5 bpm at 3500 psi. The high treating pressures indicate that the "BCP" plug is probably not properly positioned in the AVA BPL. o8/15/86 Flow test Wahoo 6. Well producing at stabilized rates as follows: 1400 BOPD, 10-30% water cut (LCM) WHP -- 525 psi. RECEIVED Alaska Oil & (~as Cons. Commission Anchorage Rig up slickline unit to check "BCP" position. TAP on plug to set in AVA ported "BPL.' Inject hot diesel @ 1.25 BPM. 10/02/86 Pull "BCP" and run commingling sleeve "BPC." 10/02/86 to 10/05/86 Flow test well (W-6) Well producing 46.5 BPH, (1116 BPD). WHP = 880 psi. Water cut Avg. 50% (water & LCM from lost circ while drilling through Wahoo). Decide to cleanup well after startup (L1 trucking expense & LCM plugging L2 LACT meters). RECEIVED Alaska 0il & Gas Cons. C0mmissi0~, Anchorage ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 10, 1986 Mr. L. C. Smith Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Commissioner Smith: Subject: Lisburne Well LI-1 Conservation Order 207 We request an exception to Rule 10 A, Conservation Order 207, for Lisburne Well LI-1. A severe "dogleg" in the LI-1 wellbore makes it very difficult and risky to run any wireline tools. Due to these mechanical problems, we request an exception to the required initial bottom-hole pressure survey and any future pressure monitoring requirements in Well Li-1. Attached is the Li-1 directional survey which has been submitted to the State. Minimum wireline work has identified 9000' MD to 9500' MD as the severe dogleg, which corresponds to a greater than 60 degree wellbore deviation. This minimum wireline work has resulted in lost production tools in Li-1. Reservoir pressure monitoring can be accomplished by the offset wells to Li-1. Attached is an area plat with the initial bottom-hole reservoir pressure of the offset wells as reported in the Reservoir Pressure Report. Please contact Ronald B. Marquez at 263-4939 with any questions or any other information needs. Sincerely, B. T. Kawakami Lisburne Operations Coordinator Attachment BTK:RBM:mc ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompan¥ To: State of AK ARCO Alaska Inc. Lisburne Engineering John Boyle Date: Pam Lambert~ }~ May 27, 1986 Traasmitted herewith are the following: CH Final Prints for Lisburne Wells '~LI-1 CET 10-28-85 Run 1 5" Sch ~LI-1 CBL 10-28-85 Run 1 5" Sch %L2-20 CET 10-31-85 Run 1 5" Sch %L2-26 CET 11-6-85 Run 1 5" Sch ~ L2-3 CET 11-7-85 Run 1 5" Sch Return Receipt to: AItCO Alaska Inc. Para Lambert ATO 477 PO Box 100360 Anchorage, Alaska 99510 Transmittal ~Naska Oil & Gas Cons. Commission Anchorage To: State of Alaska John Boyle ARCO Alaska Inc. Lisburne Engineering From: Pm. Lamber t'~ Date: February 25, 1986 Transmitted herewith are the following: TVD Logs for Lisburne Wells LI-1 DIL/TVD 5-13-85 Run 1 2"&5" Sch · L1-2 DLL-MSFL/TVD 9-6-85 Run 1 2"&5" Sch~~ L3-5 DLL-MSFL/TVD 9-17/28-85 Run 1,2 2"&5" Sch L3-11DLL-MSFL/TVD 10-28-85 Run 1 2"&5" Sch Receipt Acknowledgement ' /~~ ' ~.~i~'~.~.~ ~o: ~:O~:m~ . ". ..... ',,.,,..~, PO Box i00360 Anchorage, Alaska 99510 Transmittal No :.._Q~ ARCO Alaska, Inc. I' Post Office Bc,~'~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 18, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: L1-1 Dear Mr. Chatterton: Enclosed is the Well Completion Report and gyroscopic survey for L1-1. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L141 Enclosures RECEIVED FEB 21 1986 Alaska 0il & Gas Cons. Commission Anch3rage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany t' ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare anti submit the "Initial Report" on the first Wednesday after a well is spudded or worl(over operations are started. Daily work prior to spudding should De summanzecl on the form giving inclusive dates only. District I County. panel1 or t~orougrl I State AZaska North Slope Borough Field I Lease or Unit Prudhoe Bay I ADL 28302 Auth. or W.O. no, ITitle AFE 503584 J Completion Pool 102 API 50-029-21317 Alaska Well no. Operator IARCO W.I. ARCO Alaska, Inc. Spudded or W.O. begun IDate IHour IPrior status Spudded 1/19/86 1630 Hrs. Date and depth as of 8:00 a.m. 1/20/86 1/21/86 1/22/86 1/23/86 1/24/86 Complete record for each day reported 501 if a W.O. 7-5/8" @ 12,800' 12,788' PBTD, POH 9.4 ppg NaCl Accept ri~ @ 1630 hfs, 1/19/86. ND tree, NU & tst BOPE. Tst ann to 3000 psi. RIH w/Bkr Model "C" BP, POH & std back tbg. 7-5/8" @ 12,800' 12,788' PBTD, Perftg 9.4 ppg Nat1 Load 2-7/8" tbg, RIHs set BP @ 4013', POH. chg wellhead to FHC Gen IV. NU & tst BOPE. RU DA, RIH w/perf gun #1. ND BOPE & wellhead, RIH, pull BP, POH. 7-5/8" @ 12,800' 12,788' PBTD, Monitor well 9.4 ppg NaCl Perf w/5" gun~ 12 SPF, f/12,310'-12,200', 12~000'-11,988' & 11,900'-11,970'. Rn gage ring/JB. RIH w/7-5/8" DB pkr, set @ 12,012'; RD DA. RU Torque Turn, open rams, well has press. Close rams i monitor well f/flow. 7-5/8" @ 12,800' 12,788' PBTD, Wt up brine 9.4 ppg NaCi Monitor well. RU CTU & press tst to 1000 psi. RIH to 11,850', pmp brine @ 1.5 BPM, 3750 psi. Heat brine in pits, oil contaminated. Order out new 9.7 ppg brine. 7-5/8" @ 12,800' 12,788' PBTD, RU to rn 2-7/8" 9.7+ ppg NeC1 Displ well to 9.7+ brine. RU to rn 2-7/8" compl. qECEIVED FEB 2 1 1986 Alaska Oil & (las Cons. Commission Anchorage The above ia correct Signature For form preparation and d~tributlon, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date [ Title 2/07/86 Drilling Superintendent ORIGINAL ALASKA ,LAND GAS CONSERVATION C ,,,,MISSION ' WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska~ Inc. 85-55 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21317 4. Location of well at surface 9. Unit or Lease Name 2183' FSL, 2~48' FWL, Sec.1, T11N, R14E, UN ~~'T Prudhoe Bay Unit/Lisburne At Top Producing Interval 1 yEP, tF~ED ~ 10. Well Number 1178' FSL, 1229' FWL, Sec.12, TllN, R14E, UM Surf.~l~ | L1-1 At Total Depth [,,,j ~r/ I 11. Field and Pool 571' FSL, 1050' FWL, Sec.12, T11N, R14E, UM~_~ Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Li sburne 0i 1 Pool 54' RKB ADL 28302 ALK 2313 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 1S. Water Depth, if offshore 16. No. of Completions 04/19/85 05/08/85 05/23/85*I N/A feet MS L 1 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+'rVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 12856'ND,9572'TVD 12788'MD,9518'TVD YES []X NO [] 2095 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run D IL/LSS/GR, LDT/CNL/(;R/Cal, EPT/PCD, EGT/CNL/GR~ DLL/MSFL/AMS, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZEWT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING .RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 110' 30" 2000# Poleset (approx) 13-3/8" 68.0#/72.11# K-55/L-I 0 Surf 4089' 17-1/2" 2600 sx PF "E' & 400 s:c Class G 9-5/87' 47.0# L-80 Surf 118977 12-1/M' 850 sx Class G & 300 s:¢ CS I 7-5/8" 29.0# L-80 11~610.' 12800' 8-1/2" 200 sx Class G 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) 12,200' - 12,310' 2-7/8" 12,037' 11,653' & 12,012~ 11,9887 - 12,000~ w/12 spf, 90° phasing 11,900' - 11,970' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED Plug ~ 12,838' 150 sx Class G 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Bri~fd~script~n~flith~g~r~sity~fract~res~appar~ntdipsandpresence~f ~gas~rwater.~c~r~-~iip~EDNone FEB 21 1986 ~,laska 0il & Gas Cons, C0mmission ~:,~ch.3r~ge Form 10-407 * NOTE: Tubing was run & well perforated 1/26/86. DAN/WC01 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ME~S. DEPTH ? Tt~gE VE~T. DEPTH GO~, and Time of each Top Wahoo Zone 7 Truncated ~: -- N/A Top Wahoo Zone 6 11,891' :~ 8845' Top Wahoo Zone 5 12,036' :,,, 8950' Top Wahoo Zone 4 12,192' ~ 906~I Top Wahoo Zone 3 12~346' 9177' Top Wahoo Zone 2 1 2,424' 9235' Top Wahoo Zone 1 12,573' 9348' .. ............ ........... .................................................................................................................... 32. I herobg cer'tifg that the ~or~floin¢ is true and correct to the b~st ot mg ,knowledge .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 nor 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 titan 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 forrn 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 o'f any multiple stage cement- lng and the Iocation.0f the cementing tool. .. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In.- jection, Gas Injebtion, Shut-in, Other-explain. Item :28: If no cores taken, indicate "none". Form '10-407 ARCO Oil and Gas Company Daily Well History-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 for 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 if space is evadable. Accounting cost center code District Alaska Field ICounly or Parish Lease or Unit Title North Slope Borough State Alaska IWell no. Prudhoe Bay Auth, or W.O. no. AFB 503584 ADL 28302 Completion Operator Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m, Pool 102 AP1 50-029-21317 cost center prior to plugging and A~CO Alaska, Inc. 50% abandonment of this well i Data Hour Prior status if a W.O. 1/19/86 1630 Hrs. Complete record for each day reported Old TD Released rig 1/25/86 thru 1/26/86 7-5/8" @ 12,800' 12,788' PBTD, RR Diesel Rn 380 its, 2-7/8", 6.5#, EUE 8RD tbg & ind. Press tbg to set pkr to 2000 psi. Sheared out @ 2500 psi. RIH, set plug in lnd'g nipple. Tst pkr, POH w/std'g vlv. Set BPV. ND BOPE, NU tree &tst tree. Tst SSSV. Displ well to diesel. RR @ 0600 hfs, 1/26/86. SSSV @ 2095' FH Pkr @ 11,653' DB Pkr @ 12,012' TT @ 12,037' R[CEIVED F E B 2 1 1986 Alaska 0il & Gas Cons. Commission New TD [PB Depth 12,788' Date Kind of rig 1 / 26/86 Rotary I Type completion (single, dual, etc.) Single Official reservoir name(s) · Lisburne 0600 Hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T,P, C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature Date ITitle 2/07/86 For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent 8UB. SURIIA DIRECTIONAL SURVEY ~]UIDANCE [~ONTINUOU8 [~OOL Company Well Name Fleld/Le¢&tlon ARCO ALASKA, INCORPORATED LI-1 (2183' FSL, 2448' FWL, SI~ TllN~ ii i i i i ii i i i i R14E~ PRUDHOE BAY/LISBURNE POOL, NORTH SLOPE, AK i -- ii i · · i , ii Jol~, 71161 HALSTEAD WEST GCT OIR:CTi2N4L SURVEY CUST3~,=o , ZST?NS ARC] AL~SKA~ iNS. LiSSURN~ L!-I PRU2~OE 5AY/LZS~UR~ NORTH SLOPE,ALASKA SURVEY O~.TE-' !D-2.B-85 ':NGiN~-E.~: W~.ST METHDDS O: CgqPUT&'TION TgOL LDC&Ti2N: TANSENYZ~L- AVERAGED DEVZATION .AND ~Zi'qUTH iNTERPOLaTiON: LINEAR VERTICAL SECTi2N:~ ~ORT7~_. ...hiST . PRDJECTmn_:. OqTO ~ TaRgeT,. ~ZIMUTH OF SOUTH 10 3~ 2~ MIN ~:ST CD~PUTATiDN O~TE: 1-~-J-AN-85 ~':~gE 1 ARC3 ALASKA, INC. LiS3UR~E L1-1 PRJOHgE SAY/LrSBURNE N]qTH SLOPE,ALASKA POOL .~NTCRPOLATED_ VALU~S~ FOR HVEN 100 .FE:T. O= TRUE Sg~- SEA MEASURED V~RTi~AL VERTICAL 3EOTH DEPTM DEPTH CgURSE V:RTICAL OOGL~G 2~¥IATZON AZIMUTH SECTION S=VERITY DEG ~IN OEG MIN FE~T OEG/IOO . 9.00 0.00 -5¢.00 100.00 lO0.O0 46.00 200.00 200.00 146.00 300,00 299.9'9 245.99 400.00 399.~9 345.99 500.00 499.99 445.99 500.00 599.~9 700.00 699.97 645.97 300.09 799.97 745.97 ~O0.O9 899.~6 845.96 0 0 .N C O E 0.00 O.O0 0 13 S 50 17 E 0.05 0.47 '~ S ~0 9 E 0.40 0.10 0 21 S 0 25- E 0.92 0.26 0 29 S 38 8 W 1.53 0.79 0 -~0 S 32 34 W 2.50 0.05 0 ~2 S 21 39 W 3.63 0 39 S 26 6 W 4,$0 0.05 0 32 S 40 17 W 5.74 0.02 0 27 S 40 55 W 6.54, 0.23 i000.00 999.96 945.96 t100-.00 1099.96 i0~5.96 1200.00 1199.95 1145.95 l~O0.OO 1299,95 1245.95 1~00.00 1399.~5 1345.95 l~O0.OO 1499.95 1445.95 1500.00 1599.95 1545.95 1700.00 1699.95 1645.95 l~O0.O0 1799.95 1745.95 !900.00 1899.95 1845.95 0 27 S 35 35 W 7.25 0.24 0 25 S 3i 35 W 7.).3 0.22 0 18 S 46 51 W 8.56 0.39 0 15 S 41 59 W a.96 0.15 0 12 S 70 50 E 9.10 'O.OB 0 15 S 76 3 ~ 9.15 0.14 0 23 S 6 45 W 9.46 0.24 0 20 S 13 49 W 10.09 0.25 0 !8 5 5 17 W 10.67 0.14 0 17 N 82 52 E 1!.00 0.30 2300.00 1999.94 1945.94 21OO.O0 2099.94 2045.94 2200.00 2199.94 2145.9, 23n0~ .O~ ~299_ .93 _P24:~.93 2400.00 2399.93 2345.93 2500.00 2499,33 2445.93 2600.00 ~599.93 2545.93 2700.00 2~99.91 2545.91 2~O0,O0 2799.85 2745,85 2900,00 2899,57 2845,67 0 19 N 49 55 = 10.70 0.31 0 24 N 35 $9 ~ 10.15 0.28 0 30 N 33 45 E 9.50 0.37 0 26 N 28 59 5 8.67 0.11 0 30 N 29 43 E 7,88 0.08 0 9 N 30 12 ~ 7,27 0.57 0 30 S 37 38 ; 7.45 I 33 $ 16 45 E 8.$6 ].94 2 37 S 2 53 E i2.19 1.32 4 I S 7 _5~ W 17.94 1.29 3000.00 2999.32 2945,32 3100.00 3098.58 3045.58 3200.09 3197.37 3143.37 3300.00 3295.75 3241.75 3~JO.O0 3393.53 3339.63 3500.00 3490.B1 3436.81 3500.00 3587.51 3533.51 3730.00 B6B3.48 36.29,~B ~BO0,O0 3777,94 372~,9~ 3~00,00 3870.71 3815.71 9 11 1Z 14 15 .17 ZO 23 $-9 S 9 .1~ W 26.40 2.05 1 S 8 43 W 38.41 1.92 ~1 S 6 45 W 53.86 2.05 0 S 1 43 W' 71,66 1,4~ ~.3 S 2 44 W 91,95 2.02 16 S 3 15 W 115.30 1.11 17 S t 53 W 140.53 1,50 38 S 0 52 W 163.24 3.17 ~2 S 1 Z~ W 200.60 2.77 I0 S ! 53 W 237.48 2.40 DATE OF SURVEY: 10-2~-85 KELLY '~USHiN$ eL=VAT!ON: ENGINEER: WEST ME~SURE Ou nEPTH 54.00 =T 10.21 S 3.6'.- W 9.7:., S 3.08 W 9.16 S 2.73 W 3.g0 S 2.24 W 7,68 S 1.83 w 7.11 S 1.51 W 7.3.3 S 1,33 W :~.91 S 0.56 W 12.40 S 0.01 W 1~.I.3 S 0.30 W 2-5.53 S 1.66 w 3~.~4 S 3.35 W 53.72 S 5.70 W 71.50 S 5.86 W 92,05 S 7.64 W 115.5~ S .3.97 W 141,01 S I0,14 W 169.09 3 10.65 W 201.87 S !1.35 W 23'9.1.5 '~ 12.4.5 W ,5.75 S 3.37 7.36 S 3.20 7.93 S 4.20 :~.27 S 4.54 8.43 S 4.49 8.55 S ~.10 B,92 S 3.63 ~.53 S 3.9~ 10.I0 S 4.07 10.45 5 ~.01 0.00 .'i O.O0 E 0.32 S 0.19 W 0,41 S 0.02 =-, 0.9.5 S 0.13 E I · 55 S 0. S 5 w 2.~,1 S 0.67 N 3.47 S 1.24 W ~.5'7 S 1.72 W 5.41 S 2.30 W 6.13 S 2.~B .W 3.00 3.19 0.~2 0.97 1.55 2.51 3,68 5.88 ~.77 7.55 ,.~, · ~,. 29 ~.9~ ~.44 9.55 9.70 1].32 10.~9 11.!9 10. 10.23 3.70 7.89 7.27 7.45 :3.93 12.40 1.~.!9 26.59 S 3 35 ~ 54.02 S 5 3 W 71.93 S 5 2,$ ~ 92.40 S ~+ 4,:, w I15.'~3 q_ 4 26 ,~ 141.38 ~ 4 5 -~ 169.43 S 3 3.5 ~,~ Z02.19 5 3 13 ~ 239.49 5 Z 5,~ ,~ ~ 9 0 .T. S 35 23 N 5 3 13 E S 7 ~2 E S I 4~ ,_,~. S 1~ 30' S 1~ 44 .. S 20 35 S,~P_ 59 W S 25 8 '~ S 19 29 ,,l S 17 33 ,~ S 15 3.5 w S I~ 56 ;7 S 13 24~t. S 12 9 S 13 15 .. S 3 35 ,,~ S 3 1 W S 0 56 w RECTfiNSUL.Aq COORDINATES HDRIZ. 3~qTU~E NDRTH/SOUTH EAST/W=ST 9IST. AZiMUT5 ;EET ::ET FEET DES .~rO al~K&. INC. LiSSU~NE LI-1 PRUOHOE B~Y/LISBURNE NSRTH SLOPE,ALASK~ P3OL COMPUTATION DATE: 18-J~N-85 D,.qT.,_:. DF SJRVEY: 10-23-55 KELLY BUS'qIN$ ELEVATION: ~.CNGIN,=ER.' WEST 5~.00' =T INTE~mOL~TED VALUES FO~ 5VEN 100 TRUE SJB-S;A ME~SURmg VERTICAL VERTICAL DE~TH DEPTH OEPTH 4000.00 3951.76 3907.76 4100.00 4050.90 3995.90 4200.00 4138.07 $084.07 4300.00 4222.$0 $168.40 4500.00 $303,71 ~249.71 4500,00 ~38t,~3 ~327,~3 4600,00 $455,60 4700,00 $526,50 ~$'72,60 4~00.00 $593,5'9 $539,59 4900,00 ~656,75 $602,75 5300.00 a7!8.94 5100.03 ~780.94 4726.94 5200.00 4843.39 5300.00 $906.29 ~852.29 5400.00 ~969.26 ~915.26 5500.00 5032.22 4978.22 5500,00 509~,~3 5040,93 5700.00 5157.87 5103.87 5300,00 5220.57 5166.67 5900.09 5283.$6 5229.46 6000,00 5345,37 5291,37 6100,00 5~07,$9 5353,49 6200,00 5470,$2 5416.02 6300,00 5531,94 5477,94 6500.00 5593,$7 ~539,47 6500.0~ 565~,04 5600,0~ 6600.00 5714,20 5660.20 $700.00 5774.19 5720.19 6900.00 5835.t4 5780.14 6~00.00 5893.99 5839.99 7000.00 5953.52 5899.62 7100.00 6012.66 5958.66 7200.00 5071.38 5017.08 7~OO.OO 6129.08 5075.08 7400.00 5186.78 613Z,75 7500.00 5244.24 6190.24 7500,00 5300,82 52~5.82 7700.00 5356.78 5302.78 7800.00 5~!2.78 5358.78 7900,00 6468.75 6414,75 COURSE VERTICAL DEVIATION AZIMUTH SECTION 25G MIN DEG MI~ FEET ~5 ~.3 S " $ W 278 37 . 27 56 S 2 ~1 W 323.22 30 54 S 4 44 W 371,83 34 1 S 5 3~ 'N 425,36 37 28 S 5 24 W 483,34 ~0 ~7 S : ~: W :~6.00 43 29 S 5 12 ~; 512.78 46 20 S 4 4~ W 592.86 49 36 S ~ 39 M 755.70 5t ZO S ~ 49 N 833.35 51 ~+Z $ 4 41 N 911.78 51 37 S 4~:8 W 98'~.86 51 4 S 4-55 W 1067.63 50 55 S 5 25 W 11~5,02 50 59 S 5 5;' ~' _ _ ,, i 2~2.4~+ 51 4 S ~ 32 W 1299,92 51 6 S 7 1~ ~ 1377,67 51 7 S 7 3~ ;; 1455,27 50 57 S 8 48 N 1533.04 51 25 S 9 46 W 1510.84 51 45 S 10 4~ W t689,37 51 21 S !1 15 W 1767.73 51 28 S' 11 25 W. 1845.76 51 54 S 11 50 W 192~.27 52 ~2 S i2 'i$ W 2003.06 52 56 S !2 29 ~ 2082.58 53 6 '5 12 31 N 2162.41 53 8 S 12 ~2 W 2242.35 53 11 S 12 57 W 2322,32 53 18 S 13 1~ W. 2402.34 53 33 S 13 25 W ~482,51 54 3 S 13 31 W 2563.09 54 75 S 13 25 W 2644.1~ 54 3~ S 13. 18 W 272.5,49 54 ~7 S 13 33 W- 2~07.06 55 18 S 13 35 W 2888.77 55 &5 S i3 ~3 W 2971.10 55 ¢ S 13 50 W 3053.82 55 54 $ 13 4~ W 3135.5! 55 48 S 13 38 W 3219.26 F=ET 3= DOGLEG SEVERITY DES/100 2.63 2.25 3.65 3.05 3.3.3 2.67 1.76 3.1~ 3.15 0.17 0.22 0.75 0.35 0.81 0.35 1.10 0.63 1.6.~ 0.48 0.9~ 0.59 0.55 1.19 1.00 0.3.5 0.30 0.43 0.13 0.4~ 0.49 0.20 0.22 0.47 0.82 0.70 3.15 ,35 0.67 MEASURE RECTAN N3RTH/ FEE D OEPTH GUL5R SOUTh T 280.4'1 S 325.73 S 374.59 $ 428.09 S $86.00 S 548.53 S 615,37 S 635.51 S 759.~8 S 836.74 S 914.75 S 992. ~6 S 1070.75 S 1148.20 S 122;. 49 S 1302.75 S 1380.06 S 1~.57.12 S i 534.14 S I$10.97 S 1588. 1765. 1841. 1918. 1'995. 2373. 2151. 2229. 2307. 2385, 2463. 2542. 2520. 2700. 2779. 2559. 2939. 3019. 3100, 3180, COOROI'~ATES HDRiZ. EAST/WEST DIST. FE~T FEET 13.9~ W 280.81 15.71 W 326.11 18.82 W 375.05 23.81 ~ 423.75 29.48 W ~86.89 35,34 W 549,77 41.62 W 616.78 47.70 W .$37.17 ~3.74 W 761,38 60.1.5 W ~3,9.90 66.63 W 917.20 73,17 W 995.65 30,14 W 1073.75 86.88 g 1151.43 94.62 ~ 1229.14 102.92 W 1306.81 112.38 W 138&.53 122.37 W 1~62.25 133.49 W 1539.9& 145.89 W 1617.57 19 11 62 53 53 3~ 32 39 45 S i$0.21 W 1595.77 S 175.15 W 1773.73 S 190.54 W 1351.45 S 206.35 W 192~.$0 S 2Z2.30 W 2008.02 S 239.37 W 2987.17 S 257.19 W 2166.64 S 274.66 W 2246.25 S 2~2.3~ W 2325.8'~ S 310.66 W 55 03 96 Z1 21 36 83 329.22 W 2535.45 34.~.04 W 2565.74 366.95 W 2546.52 395.77 N 272.7.53 404.~3 W 2803.97 423,93 W 2~90.47 443.29 W 2~72.50 ~-63.12 W 3055.13 482.~0 W 3137.67 502.48 W 3220.25 OED~RTU'~E .~Zi'AUFH 3=3 MIN S 2 50 N S 2 45 W S S 3 10 ~ S 3 ZS,~ S 3 4.1 S 3 52 S 3 58 ~ S $ 2 AR~g ALASKA, L.ZSBURN: Lt-I' PRUDHSE 56Y/L!SBURN2 NORTH SLOPE,ALASKA ~30L COmPUTaTION INTERPOLATED VALUES FGR TRUE SJB-SEA ~:ASURED.~ V:RTirAL~ ~ VERTI''~L~.- DEPTH DEPTH DEPTH 8000,00 6525,20 6471,20 8t00,00 6581,91 5527.91 8200.00 6638.93 5584.93 8300,00 6696,75 5542,75 8400,90 5753,93 6699,98 S590,00 6810,09 5755.09 8600,00 6864.96 6810,96 8700,00 5918,85 6~64,~5 8900,00 6971,9.Z 6917,92 8900,90 7023.8t 5969.81 9'.900.00 7074.72 7020.72 9100.30 7124.45 7070.45 9200,00 7172,70 711-8,70 9300.00 7220.13 7165.13 9400,00 7267,98 7213,98 9520,00 7317,45 7263,45 9500,00 7370,54 7315,64 9700,00 ?425.64 7371,64 ~00,00 7451,15 7~+27,15 9900,00 7537,34 7483,34 lO000.OO 7594.22 7540.22 10100.00 7652.50 7598.60 I0200,09 7712,21 7658,21 103DO,O0 7773.~6 '7719,45 10~00,03 7836,%Z 7782,42 10500.00 7901,00 7847,00 10600,00 7966,78 7912.78 i0703,00 8033,37 7979,37 10300,00 $100o14 ~045.14 10900,OO 8167,73 8113.73 11000,00 8235.70 8181,70 lllO0.O0 B303.98 8249,98 l!ZO0,OO 8372.28 831~,28 1!]00,00 ~HgO,~O 8386,40 11400,00 8508,25 8454.25 11530,03 8575.97 8521,97 !!$00,00 $643.~3 8~$9,43 11700.00 8711.01 8557.01 11~00,00 8780,15 ~72~,1~ 11900,00 88~1,~0 COURSE DEViaTiON AZiMU'Tq 3EG MIN PEG Mlq 55 28 S i3 32 55 24 S 13 31 54 55 S 13 33 54 ~ S 13 20 55 27 S 13 10 56 18 S. 13 15 57 5 S 13 24 57 39 S 13. 46 58 19 S 13 58 59 6 S' 14 18 59 ~4 S 14 31 W 60 40 S 14 41 W 61 35 S 14 52 W 61 36 S 1~ 55 W 61 0 S 14 3~ W 59 9 S 13 13 W 56 58 q 1!' 1~ W 56 3Z S 10 23 W 55 58 S 10 7 W 55 3T S 9 54 W 54 51 S ~ 47 W 53 ~8 S 10 25 W 52 48 S It 4 W 51 38 S 11 32 W 50 24 S 12 9 W 49 15 S 12 31 W 48 28 S 12 37 -W 48 9 S 12 36 !.4 -47 53 S 12 3~ W 47 15 S 13 15 ~ 47 2 S 13 14 W 46 55 S 13 8 W 46 57 S 12 ';2 W 47 11 S' 12 52 W 47 17 S 13 13 W 4'7 Z8 S 13 13 47 38 S 13 11 47 0 S 13 33 W ~5 15 S 15 51 W 43 12 S 17 35 DATE: 18-J~N-B$ EVEN 100 FEET OF MEASURE V;RTICAL DOGLEG RECTAN S.:CT!ON S~V:RiTY NORTH/ FEET DE~/'iO0 3301,67 0,80 3261, ~383,92 0,47 3341, 3465,94 0,71 3%20, 3547,41 3.80 3500, 3629,32 0,87 3580, 3711,99 0.99 3550, 3795,48 0,82 3742, 3879,59 0,66 3823. 3964.19 0.82 3906. ~049,49 9.5~ 3989, ~!35,36 0,79 4072, ~221,88 0,39 4156, 4309,20 0,7~ 4241, ~396,95 0.36 4326. 4484,51 1,05 4411, %571,22 3,27 4495, ¢655,84 2,29 4578, ~739,35 0,47 &660. 4822,53 0,53 4742, %905,25 0,55 4B23, ~987.49 !,25 ~904. 5068.69 0.95 ~984. :148,96 ~,54 5063. 5228.01 i.62 5140. 5305,68 1,44 5216. 5381 5457.24 0,83 5364, 5531,78 0,22 5437, 5606,18 1,08 5510, ;679.79 0.29 5582. DATE O~ .5Je%EY: 10-28-85 KELLY BUSHING ELEVATi3N: :NGINEER: WEST 5753,04 0.43 555.3, 5825,02 0.12 5724, 5898,99 0,39 5795, 5972.1.2 0.44 5867, ~045.52 n.23 5119.00 0,i7 6010o $192.72 0.15 $D82. 5255.34 1.29 6154. 5338.39 2.73 5~24. 5~07.68 1.75 62'90. 9 OE~TM GULAR SOUTH T P&SE 3 O5 S 13 S 98 S 32 S 16 S 74 S 10 S 98 S 25 S 15 S 5:,. O0 FT COOROiNAT:S H]RIZ. CEP~RTURE EAST/WEST DIST. AZIMUTH FCET~ FEET 521,84 W 3302,54 541,12 W 3334,67 560.39 W 3~66.58 579,43 W 3547,95 598,17 W 3629,79 617.05 W 3712.38 636.28 W 3795,81 656,08 W 357~.85 676.46 W 3~64.39 697.30 ~ 404~,64 51 S 718.77 W 4135.46 ¢6 S 7~0.65 W 4221.94 14 S 753.01 W 430}.23 1'9 3 785.72 W 4396.96 09 S 808,14 W 4484,51 37 S ~29,~1 W ~571,2~ 08 S 847,36 W 46~5,~4 17 .S 8.52,77 W 4739,36 O1 $ 877,61 W ~822,54 47 $ ~91,98 W 4}05,16 52 S 4.B S 33'S 86 S 91 S 45 S 99 S 77 S 44 S 24 S 905.97 W 4987.50 920.12 W 505~.69 935.15 W 514B.97 950,53 W 52g8,02 966,52 W 5305,68 982,97 999,31 W 5457.26 1015,65 W 5531,31 1031,84 W 5596,21 1048.43 W 5679.34 50 75 91 3O 47 07 O1 72 1065.34 W 5753.13 1081,96 W 5835.10 1098,44 W 5399.3.:3 1114,65 W 5B72,24 1131,26 W 6045.55 1148,20 W 6119,16 1165,12 W 6192.91 11-82.30 W 6266.56 iZO0,O6 W 633:~.55 1220,40 W 640~,00 S 9 $ W S -~ 1i N S 9 18 w S 9 23 W S 9 Z 9 ,,; S 9 34-- S 9 38 S S ~ 49 ;4 S 9 54 ~ S lO 0 4 S 10 5 w S 13 1! W S 1J 17 ~ S lO 22 ~ S 10 27 J S 10 29 N S lO 29 W S 10 29 N S lO 23 ~ S 1'3 27 4 3 13 27 N S lO 27 W S 13 2g N S 10 29 ;~ S 10 31--' S 19 33 S i0 34 ~ $ 19 35 ,,! S 1'] 3~ 4 uO~PUTATigN~ D6FE: 18-J~r-$54N P&G= 4 ARCO ALASKA, i~C. LiS~URNE Ll-! P~JDHO~_ 3~Y/LiSSU~:-~ NDRTH SLOP~AL~SKA POOL D~TE OF SURVEY: !3-28-25 KELLY SUSqINg ELEVAT£JN: ENGINEER: wEST 5~,.00 FT T~U~ MEASURE2 VERTICAL DE~Tff DEPTH 12000.00 ~924.$2 IZlO0.O0 8996.44 12200.00 9069.14 12300.09 9142.64 12~00.00 9217.00 ~2500.00 9292.10 12600.00 9368.~6 12700.~0 9447.~5 12~00.00 9527.50 12356.00 ~572.Z~ ZNT~RPOL&TED VALUES :OR SJ'8-SEA VERTZ2&L DEPTH CO~RS[ DEVIATION AZIMUTH 3EG FIN DEG 8870.62. 8942.44 9015.14 9089.6~ 9153.00 9238.10 ~31~.96 9393.55 9~73.30 9518.28 5VE~ I00 V_--~T!CAL SECTION FEET 5475.69 5513.40 5680.87 5747.40 $313.07 5876.66 5938.08 ~997.74 7031.14 FE~T O~ DOGLEG SEVERITY OE$/iO0 2.,~2 1.03 0.8~- 0.85 0.61 ! .65 1.35 2.8~ 0.00 0.0-3 MEASURED DEPTH REC'T&N NORTH/ GULAR CO]RDINATES H]RiZ. SOUTH EAST/WEST gIST. T FE~T FEET .6356. 5423. ~89. 6554. 5518. 5682. 5743. 550Z. $~59. 6892. 10 S 1240.3B W 6~76.10 19 S 1259.34 W 6545.42 35 S 1277.78 W 6513.95 50 S 1295.49 W 6581.50 75 S 1315.02 W 6745.12 09 S 1333.67 W 6813.8~ 39 S 1351.~6 N 587'7.58 54 S 1369.96 W 6~39.11 95 5 13~7.62 W 6~98.~8 09 $ 1397.51 W 7032.35 4ZIMUTH ]=G MiN S 11 5 w S 11 ] 11 14 S 11 17 S 11 20 4 S il 23 N 5 11 26 4 S 11 27 W ARC@ ALASKA, INC, LI$SURNE LI-1 oRU~HO:, ~ . ~ 54Y/LIS3URNE NORTH SLOmE,AL4SKA P]OL COMPUTATi2N DATE: O~TE 2= SJRV;Y: !O-2S-B5 K:LLY 8U.SHIN~ EL:V&TI3N: ENGINEER: WEST m6GE 5~ .02, FT ._ ~RED DE~TH iNT-RgOL6T6D VALUES FOR TRUE SUB-SEA VERTICAL VERTt~AL DEPTH DEPTH O.OO 0.00 -$~.00 i000.00 999.96 945.95 20OO.O0 1999.9~ 19~5.9~ 3000.00 2999.32 2945.32 4020.~] 3951.~$ ~907.76 5000.00 ¢7!8.94 ~66~.9~ 6000.03 5345.37 ~291.37 7000.00 3953.62 5899.62 8000,00 5525,Z0 $471.20 9000.00 7074.72 7020.72 00.00 7594.Z2 7540.22 O0.OO 8235.70 8181.70 OO.O0 392~.52 B~70.52 56.00 9572.28 9518.28 100 !10 120 !2.8 COURSE DEV!~TION 2EG ~!N OEG 54 51 S 9 ~7 N. 47 2 S 13 16 W ~4 1 S 16 13 N 36 54 S t7 S W :VEN lOOO VERTIS~_L SECTION FE~T 0.00 7.25 10.70 26.40 ~ 7 911.78 !6~9.37 2482.51 3301.67 ~13~ .36 4987.49 5753.04 5475.59 7031.14 , ME6SURED q=~T DOGLEG REST6NSULAR CD SEVERITY N3RTM/S3UTH EA D~G/IOO FE~T F O.O0 O.OO N 0.24 6.75 S 0.31 10.21 S 2.05 26.53 S 2.63 280.47 S 1 0.22 9t~.75 S 6 0.43 1-583.19 S 16 0.48 2G63.55 S 32 0.83 3261.05 S 52 0.79 4072.51 S 71 1.26 4904.52 $ 90 0.~3 5653.60 S 106 2..42 6356.10 S 124 0.0~ 6392.09 S 139 ST/W:ST HDRiZ. D-ST. F::T 0.00 3.37 3.61 I .i'~6 3.94 6.53 0.21 9.22 1.8~ 8.77 O.O0 7.55 10.83 26.59 280.81 917.20 1595.77 330Z.54 4135.46 5.97 5.34 0.85 7.51 ~987.50 5753.10 6576.10 7032.35 2E ~ &R TU'.q E 6Z i 0=3 N 0 0 2 S 25 32 J S 19 29 4 S 3 35 ,~ S 2 S ~ 9 S 5 ,:.. ~ S 7 3-5 ,~ S 9 5 W S 10 3 10 27 ~ S lO 40 W S 11 2 'x~ $ 1! 27 W C2-~.PUT&TiD'4 DALE: 18-J~N-B$ P~GE 8 i TgmlJqqE Li-1 oRJOHSE B~Y/LiSBUR~E NgRTH SLOmm,A' AS(~, _ ~ P3DL ZNTEROOL&T¢~- VALJES ~"R~ EV:N ~00 FEET 0= TRUE SUB-SE& Mc~.StJR$D VERtICaL V8.RTi-AL DEPTff DEPTH DEmTH 0.00 0.00 -54.00 54.00 5~.00 0.00 154.00 154.00 100.00 2~.OO 254.00 200.00 354.01 354.00 309.00 ~5~.01 ~5~.00 ~OO.OO 554.02 55~.00 500.00 554.02 -654.00 500.00 754.03 754.00 700.00 854.04 85~.00 800.00 954.0~- 95~.00 900.00 1054.00 1054.00 iOOO.O0 1154.0~ !154.00 1100.00 1254.05' 1254.00 1200.00 1354.05 1354.00 1300.00 1&54.0~ 1454.90 t~00,00 1554.05 1554.00 1500.00 i654.05 1654.00 1600.00 1754.05 1754.00 1700.00 1854.0~ 1854.00 t~00.00 i95~.05 1954.00 235~.05 2054.00 2154.06 2154.00 2254.06 2254.00 235~.07 255~,07 2554.00 255~,08 265~,00 2754.~2~ _~754.00 2954,22 2854.00 2954.49 295~.00 3055.0~ 3054.00 3155.06 3154.00 3257.51 3254.00 3359.&$ 3354.00 3~52,0:~ 34~4. O0 3555,29 3554,00 3569.15 3~54.00 3774.50 37~.00 3~!.84 385~.'J0 CO'JRSE VERTICAL OOGLr-G OBVIaTiON AZiMjTq SECTION S~VERITY D=G MiN Or-G._ MIN ~EET ]=G/IO0,. 0 0 N 0 0 ~ O.OO 3.00 0 10 N 50 0 5 0.0t 1.I1 0 14 S 25 45 { 0.21 0.28 0 19 S I0 45 ~ 0.66 0-,07 0 20 S !~ 21 W 1.25 0.17 0 37 S 35 31 W 2.01 0.31 0 ~1 S 29 1~ W 3.08 0.~2 0 40 S 24 19 W ~.28 0.i1 0 3~ S 37 ~0 W 5.35 0.23 0 32 S 37 5 ~ 6.18 0.36 0 27 S 38 40 W. 6.92 0.15 0 25 S 35 3 W 7.62 0.09 0 24 S 34 33 W 8.31 0.2! 0 18 S 46 12 W 8.78 0.11 O 6 S 41 '15 5 9.08 i.0~ '0 14 S 72 31 ~ 9.13 0.0~ 0 18 S 41-18 E 9.19 1,50 0~1 S 15 ~.. W 9.82 0.49 0 20 S 8 9 W !0.41 0 13 S 0 25 W 10.94 i900.00 2000.00 ZlOO.O0 2200.00 2300,00 2~00.00 2500.00 2600.00 2700.00 2800.00 0 15 N 50 5'9 E 10.58 0-20 0 25 N 52 43 E 10.43 0.31' 0 ZO N 28 43 E 9.81 0.25 0 31 N 32 19 E 9.02 0.50 0 29 N. 30 9 E 8.25 0.12 0 23 N 22 ~7 E 7.46 0.82 0 9 S 22 ~ E 7.27 0.27 1 1 S 26 39 - = 7.96 1.30 2 3 S g 35 ~ lO.~Z !.00 3 22 S 2 59- W 1~.96 2.32 2900.00 3000.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 3700.00 3800.00 6 9 10 11 13 14 16 19 22 55 S 9 36 W 22.!3 1..~5 58 S 8 q.-w 32.5.2 2.59 2 S .9 3 W ~6.72 1.40 24 S 3 1T W 63.$5 1.85 59 S 2 19 W ~3.36 1.6~ 49 S 3 25 W 106.15 1.27 53 S 2 26 M 131.60 0.98 44 S O 48 W 15g.2'7 2.55 53 S' 1 22 W 191,93 2,39 $3 S i 48 W 230,46 2.42 SURVEY: 13-23-85 KELLY 3USHING :LEVATZ3N: ENGINEER: WHST .SU~-SEA DEPTH RECTANGULAR NOR'TH/SnUTHu ~EET COOROi~T~S q]RiZ. DE ~AST/WEST DIST. 6~ , ~ FEET FX:T OE O.O0 N 0.05 N 0.20 S 0.69 S 1.29 S 1.97 S 2.95 S 4.08 S 5.07 S 5.80 S 0 · 00 ': 0 · 00 N 0.34 ~ 0.35 N 3 0.05 W O · 21 S 1 0.10 E 0.70 S 0.10 = 1.29 S 0.38 W 2.01 S I 1.O1 w 3.1_) S 1 1.~ ~d 4.35 S 2 2.02 W 5.46 S 2 2.62 W 5.36 S 2 6.~5 7.0'3 7.71 3.12 8.38 E.50 8.54 9.27 9.84 10.37 3.15 W 7.18 S 3.51 w 7.9:., ~,- 4.01 W 8.69 S 4.40 W 9.23 S 4.53 w ~.58 S '~.29 W 9.52 S 3.36 W 9.45 S ~. ~0 W 13.05 S 4.0~+ W 10.6~ S 4.09 W 11.15 S 10 · 36 .S 9.99 S 9.44 S :B. 73 S 8.02 S 7.29 S 7.13 S 7.92 .S 10.56 S 15.2~ S 3.79 W 11.03 S 3.33 W 10.53 S 1.~9 W 9.~7 S 2.43 W 9.06 S 2.02 W :'3.27 S !.51 W 7.~6 S ~ 45 W 7 27 S · i, · · 0.94 W 7.93 S O, 20 N 10,56 S 0.32 E 15.22 S 22.32 S 32.50 S 46.64 S 53.71 S 83.42 S 106.37 S 132. O0 S 193.~0 5 232.07 S 0.99 W 22.34 5 2.5p N 32.70 S 4.6'9 W 46.88 S b.37 W 64.05 S '7.25 W 83.74 5 8.41 W 106.71 S 9.79 W 132.36 S 0.53 W 160.34 S 1.13 ~ 193.~Z S 2.23 W 232.39 S PARTJR; IMUTm G 0 0 E ! 5O '~ 5 33 J 3 15 :_ ~ 1Z 0 57 0 0 4 1 39 N 17 W 27 0 4 27 2B ~ 24 3 W 2Z 4j W 22 1~ ~ 21 ~1 ~ 2 32 4 4 2~ w 5 4 ~+ '.4 3 52 W 4 31 w 4 14 d 3 45 W 3 17 ~ :~ 1 ,,~ CGMPUTATiJN D~T~: !8-J6N-B5 P~GE 7 ARC3 4L~$K4~ INC. LISBURNE LI-1 PqUDHOE '34Y/L iSEOR>~E NORTH SLgPr-~ALASK4 POOL T MEASURED VER DEPTH 0 399'1.4i 39 4103.51 40 4218.55 41 4338.39 42 4%64.18 ~3 4597.83 44 4740.17 45 4895.60 46 5056.57 47 5216.~S 48 5375,75 5534.70 5593.85 5852.97 6013.93 6i74.35 5~35.75 .5499,9~ 6556.37 6833.17 7000.54 7170.67 7343.11 7517.21 7595.02 7~73.53 8050.71 ~226.15' 8400.0~ 8579.90 8765,97 8959,08 9150,88 9371,08 9559,28 9751,32 10t02.3~ INT:RPOL~T~D V4LUES FOR RUE SUa-SE.4 TIC4L VERTIC4L EPTH DEPTH 54.00 3900.00 54.00 ~000.00 54.00 4t00.00 54.00 4203.00 :4 O0 4300,00 54.00 ~OO.O0 54,00 ~500,00 54.00 ~60O.OO 54,00 4700,00 54.00 ¢800.00 4954.00 4900.00 5054.00 5003.00 5154.00 5100,00 5254.00 5200.00 5354.00 5300.00 5454.00 5400.00 5554.00 5503.00 5654.00 5500.00 5754, O0 ~=700. O0 5354.00 5800.00 5954,00 5900.00 5054,00 5009,00 6154.00 6100,00 6254.00 6200.00 63~4.00 6300.00 $454.00 $400.00 6554,00 5500.00 565~.00 5600,00 6754.00 5700.00 5854.30 5~00.00 COURSE D:VI'~TZON~ A~MUTq: ]EG -'4tN OEG 5954,00 5900,00 7054.00 7000.00 7154,00 7100.00 7254.00 720~.00 7354.00 7300.00 7454.00 7400.00 7554.30 7500.00 7654.00 7603.00 7754.00 7700.00. 78~4.00 7903.00 25 30 S 2 5 W 28 I S 2 44 W 31 30 S 5 ! W 35 7 S 5 41 W 39 23 S 5 19 W 43 ,_~6 S 5 13 W · 47 38 5 ~ 40 W 51 19 S 4 50 W 51 40 S 4 48 W 51 2 S 4 53 W 50 59 S 5 47 W 5i $ S 5 51 W 51 6 S 7 32 W 51 5 S 9 11 .W 51 43 S lO 52 W 51 20 S 11 21 W 51 53 $ !i 59 W 52 56 S 1Z 29 W 53 8 S i2 38 W 53 13 S 13 5 W 53 33 S 13 24 W 54 19 S 13 25 W 54 44 S 13 15 N 55 23 S 13 33 W 55 4 S 13 50 W. ~'5 56 $ 13 38 W 55 28 S 13 31 W 54 46 S 13 32 W 55 27 S 13 I0 W 56 57 S 13 21'W 58 2 S 13 55 W '59 26 S 14 27 W · 51 15 S 14 48 W 51 17 S 14 -44 W 57 29' S 11 35 W 56 16 S ID 1.6 W 53 29 S 9 4~ W 53 ~7 S 10 25 W 52 4 S 1i gZ W 50 3 S 12 19 W D4T: 3= SJRCEY: 10-25-85 KELLY 5USqING EL~¢AT£ON: EVEN 100 VERTICAL SECTION FEET 274,73 324,85 ~8!.,50 4~7.08 523,05 611,27 712.08 830.44 955.95 1080,70 1203.66 1325..88 t450.50 1574.19 1'700.31 1825.72 1952.43 2082,53 2215,48 2348,85 2483,02 2620,33 2760,62 2902,93 3049,69 3197.50 ~343.3~ 3487.29 3629.36 3773.66 3935.31 4100,15 $27-4,94 ~39.27 4530.04 4782.13 4929.53 5070.61 5203,23 ~325,76 FEET OF SU.B-SEA OEmTH DOGLEG RECT.4NSUL4R COO~ SEVERITY NORTH/SOUTq E~ST DEG/IO0 FE:T FE: 2.59 276.79 S 13. 2.2¢ 327.38 S 15. 3.27 384.26 S 19. 2.65 449.78 S 25. 3,81 525.70 S 33, 1.64 513.87 S 41. 3.32 7.14.78 S 50. 0.12 ~33,32 S 5'9. 0,20 959,02 S 70. 0.85 1083.84 S 81. 0,35 1206,75 S 92. 0,76 1329,58 S 103, 1,00 1452,38 S 121. 0,78 1574.90 S 139. 0,48 1598.93 S 162. 0.09 1821.~7 S 186, 0,43 1946.10 S 212. 1.OO 2073.29 S 239. 0,27 2203,16 S 268. 0.50 2333.32 S 293, 0,48 2464.05 S 329, O 40 2597 7A S 36' . · -~ ~. 0.47 2734,45 S 393. 0.30 Z~73,00 S 427, 0,15 3015.81 S 462. 0.36 3159,63 $ 497. 0,77 3301.~2 5 331, 0.58 3441.77 $ 565. 0,87 3580.19 S 598. 0,76 37~5.70 $ 632. 0.92 3~78.17 S 659. 0.68 40~8.34 S 709. 1.05 4207.92 S 754. 1.10 ~3~6.51 S 801. 2.80 4552.81 S 842. 0.76 ~70~.25 S 870. 0.42 4347.39 S 896. 0.94 ~9~6.37 S 920. 1.27 5116.57 S 945, 1.4~ 5237.52 S 971. OINATES HORIZ, DEPaRTUrE /NEST DIST, ~ZIMIJTW T ~EE'r 3EG 30 w 277.13 79 ~ 327.75 56 W 384.76 95 W 450.53 18 W 526.74 48 W 515.27 09 W 716.53 86 W ~35.47 29 W 9b1,59 26 W 1085.83 71 W 1210.30 07 W 1333.~0 73 ~ 1457.47 ~3 W 1581.01 26 M 1706.56 59 W 1~31.50 17 W 1~57.63 ~6 W 20~7.12 75 W 2219.4~ 37 N 2352,32 34 W 2485,96 41 W 2522,73 ~5 W 2762,57 25 W 2904.59 13 W 3351.02 34 ~ 3198.53 65 W 3344.15 41 W 3~87,90 19 W 3529,~2 ~1 W 3779,00 48 W 3935.53 ~4 W 4100.27 20 W 4274.97 59 W 4439,27 15 W 4530.04 44 W 4782.1~ 14 W 4929.53 46 W 5070.62 71 W ~20~,23 31 2 5326.77 S 2 45 ~i S 3 16 W S 3 3.5 ~_w S 3 31 S ~ 0 S 411 W S 417 d $ S 4 33 'd S 4 47 w $ 3 ~ w S 3 27 W S 5 50 ,~ S 5 13 S 5 35 N S S 57 W S 7 17 S 7 35 -v, .3 7 55 S 9 11 ,4 S 3 g7 W S -$ S :3 56 S 9 · S ~ !:~ S 9 3=' ,~' ...- C~MPDT&TION D~TE: 18-JAN-S6 PaSE '~ AqCO ALASKa, INC. LISSURNE Li-1 PqUDHOE 5~Y/LISSURNE NDqTH SLOmE,AL4SKA ~30L iNTERmOLATED VALUES ~DR EVEN 100 mEET TRUE MEASUR=3 VERTICAL D:mTH DEPTH S'J'B-S~A VERTICAL D~PTH ~uJRSE V-~TICAL OOGL:G ...... ~m SEVERITY 3EG qIN DF~ M!N :~ET DEG./lO0 10580,77 795~,00 10730,90 8054,00 10879,77 8154,00 11026.82 8254.00 11173.2~ 8354.00 113Z0.0~ $454.00 !1~67,48 855~,00 11515,68 ~65~,00. 11752,47 8754,00 11903.01 8854.00 7903.00 8000,00 8100,00 8200,00 8300.00 8~00.00 8500,00 8600.00 gTO0.OO 8800.00 ~8 37 S 12 35 W 5442.88 1.2~ 48 8 S 12 3~ W 555~.78 0.2g 47 17 S 13 13 W 5664.96 0.51 46 58 S 13 19 W 5772.63 0.29 46 55 S !2 58 ~ ~87~,46 0.32 47 14 S 12 56 W 5986,83 0,39 47 24 S 13 19 W 5095,06 O,&6 47 ~6 S 13 !1 M 5204,29 0,20 45 59 S i4 49 W 531.1,55 2,37 ~3 10 S 17 37 ~ 5409,70 1,55 !204!,0~ 3954,00 12179,28 9054,00 12315,32 9154,00 12449,45 9254,00 12580,78 9354,00 12708,08 9454,00 1Z~33.1~ 9554.00 12856,00 9572.Z8 8903.00 9000.00 9109.00 9200.00 9300.00 9~00.00 ~590,00 ~518.28 44 9 S 15 24 W 5504.18 1.09 43 11 S 15 3~ W 5599.31 0.82 42 i0 S 16 3 N 5591.09 0.73 ~1 19 S 16 2~ W 5780.06 1.15 39 12 S 16 42 W $86~.56 2.!5 37 9 S !7 3 N ~9~2.91 1.90 36 34 $ !? 5 ~ 1017,51 3-,03 36 54 S 17 5 W 7031,14 0,0~ OAT- O= SUR'¢mY: 1D-2~-35 K~LLY 5USHIN3 ELEV~TiO-q: ENGINEER: WEST SUD-S:A DEPTH RECTANGdL.&R rODqD=NATES~ NO~TH/SOUTH EAST/W=ST F~ET FEET 5350.97 S -995.15 W 5~60.23 S 1020.67 W ~67 79 S 10~$ O0 W 5572,70 S 1069,81 W 577~,8~ S 1094,08 W 5881.65 S 111'7.95 W 5987,14 S 1142,58 W 5093.59 S 1167.76 W 5195.05 S 1192.95 W 6292.67 S 1221.03 W 6383.65 S 1248.58 5475.73 S 1273.96 656~.35 S 129~.33 6650,2.5 S 132~.25 6807.18 S 137!.3~ ~87e.97 S 1393.47 6892.09 S 1397.51 ~]~IZ. DIST. ~T 5~2,90 5554.81 5555,01 5772,70 5B79.55 5~86,95 6095,21 6204.48 6410.03 5~.OO FF OEP~PTUR~ ~ZiMUTH S i3 32 ~ 3 10 35 S 10 37 W S 10 40 N S 12) 43~ S 19 45 S lO 45 ,, S 19 50 w S 10 53 ..~ S 13 53 w 6504,62 S 11 4 ;~ 6599,~5 S i1 7 4 5691,74 5 11 ii w 6730.83 S 11 15 4 5865.56 S 11 19 W 6943.95 S 11 23 N 701~.5g S 1! 27 ~ 7032.35 S 11 27 '~ CONPUT~TIDN O~TE: 18-J~N-B8 P~G~ 9 ARCO aLASkA, !NC. LISBURNE LI-i PRJDH]~ BAY/LISHUqNE NgRTH SL3P:,AL~SK.~ D~TE OF SURVEY: 10-23-~5 K~LLY 3USHIN3 ~LEFATZ]N: ENGINEER: NEST FT MARKER TOP NAM30 ZONE TOP WAHJO Z2NE TOm. NAHmOu ZONE T~P ~AH30 ZOnE TOP ~AHJ9 ZONE TOO WAHgD Zg~:~ TOm WHA30 ZOnE DSTD INTEAmOLAT:O, .. ~ VALUCS~ FOR MEASdRE~u D~PTH_ BELOW KB TRUNCATED 11891,00 12036.00 12192.00 12346.00 12~2~.00 12573.00 12788.00 12856.00 'HmSEN HaRTZ]NS :ROM -DRI$i-N= TVO $845.20 8950.41 9063.29 9176.78 9234.92 · 9348.01 9'517.90 ~72.2g 21B3' FSL, SUB-SE4 -379.i. 20 8896.~1 9D09.29 9122.T8 9180.92 929~.D1 9¢63.90 )518.28 SJRFAC,_: _.3CATiDN :~T =.~JL, $32 1, Ti!N, R14F:, R :C T.~ NGU L',I.~ C03RDiNAT~S NgRrH/S3UTd E ~S T/W.--. ST 5284.89 5 1213.53 W 6380,28 S 12~7.55 W ~ 648~.09 S 1275.30 ,l 6584.14 $ 1305.91 ~'~ 6634.08 S 1319.~) w 6727.08 S 13~7.95 w 6853.0~ S 1'335.50 W 5B92,09 S 1397.51 EOMPUT~Ti]~ OAT~: 13-J~N-8$ P4G~ 10 A ~'~ r n At.._ -A C X A . T .'k.j I'" ~ I r~lt~,~F LI-1 P RiO(JOE ~EY/LIS~U~'4~ NEATH SLOPE,~L~,SKA PE~L DATE. 3=, SURVZY'~ · i0-~-3:... , K~LL? ~USHIN$ =LEV.~T~3N: ENGINeeR: WEST 5~.00 FT MA~K:R TOP R~H30 TgP ~AHJO TOP ~AHSO TOP ~AHDO TOP WAHOO TOP WH4 O0 PBTO TD ZON~ ZONE ZONE ZONE ZONE ~IEASJREO DEPTH ~ELOW KB TRJNCATED 11891.00 i2036.00 121gZ.DO 12346.00 I2~24.O0 i2573.00 12788.00 12856.00 SUMMARY OqIGIN= TVO FROM K3 B$45.20 8950.41 9063.29 9176.78 9234.92 9348.01 9517.90 9572.2~ 21~3' mSL, SUB-S:A 8791.20 8896.~! 9009.29 9122.7B 9180.92 9294.01 9~63.90 9518.28 2445' SJmFAC5. ' 3~4r~ON~ . . ~T FWL, SEC 1, TllN, Ri~E, R:CT~NSULAR CJORDZ'd4T~S NORTH/S]UTN EAST/w~ST 6284.~9 S 121~.~'3 5380.28-S 12~7.$5 6¢$4.0~ S 1275.30 65B4.14 S 1305.01 6534.0~ .5 131~.&'~ 5727.0~ S 1347.05 6353.06 S 13B5.30 6~2.0~ -S !3~7.51 . ;INAL ~IEASUREJ DEPTH WEL I O ATI...~'~ TRUE VERTICAL DEmTH AT' TO: SUB-SEA V:RTr-AL · ~ DEP?H HORIZONTAL 2, EP~RTURE DISTANCE 4ZIMUTH FEET DEG M!:'d 12855.00 9372.28 9518.28 7032.35 S ii Z? 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FT 1397.6 FT REF O0007]lSl ,} {" L~nb~rne gnsLneerin~ ~* To: Addzem[: State of Alaska Fro~: Pam Lambert 3001 Porcupine Dr. DaCe: January 24, 1986 Anchorage, Alaska 99508 ACCU: C.V. Chatterton Tranmicced herevich are che follovia~: Magnetic tapes and Surveys for Lisburne ·Wells L~-~ ~c,~ D~~o.~ Su=v~y ~-~-~ s~_~ LI-1 Mag. Tape GCT LIS Run 1 10-28-85 Sch K1-2 LI,-2 ., Ll-i0 Li-J10 L3-5 L3-5 L3-11 L3-11 Mag. Tape GCT LIS Run 1 ,., ' /~3/~ 'Mag. Tape GCT' LIS Run 1 11-17-85 Sc GCT Directional' Survey 1-19-86' Sch-~~, ~'~¢OO'-~-~~-'. (~ -"~ Mag. Tape GCT LIS Run 1 11-18-85 Sch GCT Directional Su~ey 1'-21-86' ~g. Tape GCT LIS Run 1 10-25'85'Sch cc~ D~tio~ Su=ve~ ~-~-S~ S~~a~~--~~~ ~~-- ~,~-~-S~ s~b ., . = f'," 7," ~ ~ ,- .:"""; ', ',~ ~5 i: ! .~ O :, "..'-,~ L: J' Receipt Recurn Race,pc' co: ~//~CO &lash Inc. Lisburn~ ZaSiaeering Aeon: Pam Lambert ATO 477 P.O. Box 100360 Anchorage, Alaska 99510 Transmt. c ca.l. Ho. :' ... 5'"~0 ARCO Al,Bill. Ifle. Il · IUIJlllllr¥ of &llillflel~ieNtiOIg4:OIBlJl~¥ Dace: _ STATE OF ALASKA ALASKA{" _ANDGAS 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. 85-55 3. Address P.O. BOX 100360,, ~chorage, Alaska 99510 4. Location of Well Surface: 2183' FSL, 2488' FWL, Sec. 1, TllN, R14E, UM 1320' FSL, 1320' FWL, Sec.12, TllN, R14E, UM @ Target 634' FSL, 119.5; FWL, Sec.12, T11N, R14E, UM (Approx)@TD 5. Elevation in feet {indicate KB DF, etc.) RKB 44', PAD 14'" ' 6. Lease Desiqr~ation and Serial No. ADL 28302 ALK 2313 8. APl Number 50- 029-21317 9. Unit or Lease Name .~. Prudhoe Bay 'Un i t/L i sburl 10. Well Number L1-1 11. Field and Pool Prudhoe Bay Fle]d Lisburne Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: {Submit in Triplicate) Perforate X]~X Alter Casing [] Perforations Stimulate X]~ Abandon [] Stimulation Repair Well [] Change'Plans [] Repairs Made Pull Tubing [] Other X~( 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 conduct the following on Lisburne well LI-I' C1) Stimulate Wahoo Zone 4 perforations (12,220'-12,226' and 12,270'-12,315) with 3000 gallons of 15% HCL. The acid w111 be pumped through tubing and a flowback to a production tank of 2-3 tubing volumes will be done for c 1 ean-up. (2) Set a temporary sand plug cap at 12,180'MD. (3) Perforate Wahoo Zone 5 (12,050'-12,164') with a tubing gun using 4 SPF and 90° phasing. (4) Stimulate Wahoo Zone 5 with 4800 gallons of 15% HCL, The acid will be pumped through tubing and a flowback to a production tank of 2-3 tubing vo]Lrnes will be done for clean-up. (5) Use coiled tubing unit to flush sand plug, 14. i hereby certify t.hat the foregoing is true and correct to the best of my knowledge. Signed ~/tq~ T. t~.~: The space below for Commission use ; [/ED ~" ~' ~] 2el~ ~ ' I~TINUED. ON NEXT PAGE. " ,~ u~'~ns. Commissloe Conditions of APproval, if any: Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" irt Duplicate January 22, 1986 PAGE 2 of 2 SUNDRY NORICES & REPORTS ON WELLS WELL NUMBER L1-1 (6) Stimulate Wahoo Zone 6 perforations (11,900'-11,970' and 11,988'-12,000') with 3500 gallons of 15% HCL. The acid will be pcmnped through tubing with flowback of 2-3 tubing vol~nes for cleanup. (7) 14 day production test, with flow directed through a portable test facility. (8) Depending on production test results, a gelled fluid fracture of Wahoo Zones 4 and 5 using an estimated 700 barrels of fluid and 50,000~ of 20/40 sand propant. Estimated Start Date: January 29, 1986 (' STATE OF ALASKA ' ALASKA OiL AND GAS CONSERVATION CO~v, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 85-55 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 2183' FSL, 2/+88' FWL, Sec.1, T11N, R1/+E~ UN 1320' FSL, 1320' FWL, Sec.12, T11N, R1/+E, UN ~ Target 63/+' FSL, 1195' FWL. Sec.12. T11N. R1/+E. UM (apprnx) ~ Tn 5. Elevationinfeet(indicate KB, DF, etc.)- ' ! 6.~ease ~esignationand SerialNo. RKB ~4'= PAD 1~' I AnL 28302 ..... AI~ 2313 12. 8. APl Number 50- 029-21317 9. Unit or Lease Name 10. Well Number L1-1 11. Field and Pool Prudhoe Bay Field Lisburne 0il Pool 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 ~L 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.) (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 complete this well as a single selective with perforations ~n the Msburne Wahoo from 11,900' - 12,16/+~ overall and 12,200' - 12,310' w~th a packer between ~he perforations and another above the Wahoo. The 2-7/8", 6.5#, L-80, EUE, 8rd tubing will include provision for subsurface safe~y equipment. Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~6 ~ _~.~'~ Title Assoc,ate Engineer The space belj~v for Commission use la' Date Conditions of Approval, if any: App~'ovecl Cop)' P, eturrted. .... By Order of Approvedby ~'~ LaN.~E ~;. ,~M~.~E COMMiSSiONER the Commission Form 10-403 (JJC;) SN/111 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box~'{' 360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 9, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AX 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton: .Enclosed are Well Completion Reports for the following wells: 2Z-16 L1-1 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRUS/LIO Enclosures RECEIVED OCT ! ! · Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaeka, Inc. I. a Subsidiary of AllanllcRIchfleldCompany " '.:'. STATE OF ALASKA C~ ' . ALASKA { .,ANDGAS CONSERVATION C ~IlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [~X ABANDONED [] SERVICE [] 2. Name of Operator 7. P~.~.~-N~ber AEC0 Alaska, Inc. 3. Address 8. A'PT~umber P. 0. Box 100360, Anchorage, AK 99510 50- 029-21317 4. Location of well at surface 9. Unit or Lease Name 2183' FSL, 2~8t FWL, Sec.1, T11N, RI~E, UN Prudhoe Bay Uni~./Lisburne At Top Producing Interval 10. Well Number To be submil:t:ed when gyro is run. L1-1 At Total Depth 11. Field and Pool To be subm~l;t;ed when gyro is run. Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Li sburne 041 Pool ~' RKBI ADL 28302 ALK 2313 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 0~/19/85 05/08/85 05/23/85I N/A feet MSLI N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 12856'ND 12788'ND YES [] NO I~X N/A feet MDI 1900t (Approx) 22. Type Electric or Other Logs Run D IL/LSS/GR, LDT/CNL/GR/Cal, EPT/PCD, EGT/CNL/GR, DLL/NSFL/AHS 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-~0 Surf 110' 30" 2000# Poleset; (apgrox) "13-3/8" 68.0#/72.(1# K-55/L-~D Surf ~089~ 17-1/2" 2600 sx PF 'E' & ~00 sD Class 9-5/8' ~7.0# L-80 Surf 11897' 12-1/~' 850 sx Class G 7-5/8" 29.0# L-80 11a610t 12800' 8-1/2" 200 sx Class G 24. Perforations open t6 production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) · None N/A ....... 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND O'F MATERIAL USED Plua ~ 12.838' 150 sx Class C . 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing'Pressure CALCULATED.IA OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None kECEi'VED Alaska 0il & Gas C0~s. Anchorage Form 10-407 TENP2/WC26 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. .,. GEOLOGIC MARKERS NAME MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS 32. I herebv certify that the foregoing is true and correct to the best of my knowledge ~l~,. -........,-,.........,.. 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 Oil and Gas Company Wall History'- Initial Report- Dally Inatn~lione: Prelim and aubmlt the 'lnltlM I~1~' on the first Wedne~lay after a well ia ,pudded or workover oPemtlona em sim'ted. Dally work prior to spudding Ilmuld be lummadzed on the fon. giving Inclusive dales only. Dlatdct ~l. aska Field Prudhoe Bay Auth. or W.O. no. A~E 503584 IOounty. ~;~h or Ix)rough North S~ope Bocou~h ~ or Unit ~u, ~L ~28328 State Alaska DS LI-1 Parker 176 50-029-21317 Operator ARCO Alaska, Inc. Spudded or W.O. begun [Date [Hour ji4~ ~ Oot~ ~_c~ 4/19/85 ~ hrs. Date and depth Complete record for each day reported as of 6:00 a.m. 4/19/85 4/20/85 thru 4/22/85 4/23/85 4/24/85 4/25/85 ARCO W.I. Prior at-tua if a W.O. 20" @ 110' HIRU. 20" @ 110' 4110', (4060'), POH Wt. 9.6, PV 8, YP 28, PH 8.2, WL 19.6, Sol 9.5 Accept rt~ @ 0600 hfs, 4/19/85. Scud well @ 1145 hrs~ 4/19/85. Drl 17~" hole to 2510', DD & surv to 4110', short trip to 2500', CBU, POH f/13-3/8" csg. 2510', Assumed vertical 2868', 3.4°, S5W, 2867.84, 10.57, 10.58S, 1.00W 3206', 9.7°, S8W, 3203.51, 49.00, 48.73S, 6.62W 3689', 17.1°, S2W, 3672.95, 160.60, 160.81S, 13.62W 3812', 20.7°, S3W, 3789.32, 200.05, 200.61S, 15.36W 13-3/8" @ 4089' 4110', (0'), Weld csg head Wt. 9.6, PV 9, YP 31, PH 8.2, WL 20.8, Sol 9.5 POH. Rn 101 Its, 13-3/8", 68#, K-55 to 4089', FC @ 4008'. MaP 2600 sx PF "E", followed by 400 sx C1 "G" w/l% C~R-2, 3% CaC1.. Displ using'rig pmp; cma flash seC. Good cma co surf. CIP @z 1945 hfs, ~/22/85. ND dtverter. · 13-3/8" @ 4089' 4110', (0'), Drlg cma 8.8 Frsh War Nil & tst BOPE. TIH w/BHA, tag cmt @ 3066', drl firm cmt to 4082'. 13-3/8" @ 4089' 5375', (1265'), Drlg Wt. 8.9, PV 3, YP 5, PH 7.6, WLNC, Sol 4 Fin drlg out cmt, drl 10' new formation to 4120'. Conduct formation leak-off Cst to 12.6 ppg EMW. Displ DP &.ann w/frsh wtr, tnj 1050 bbls mud dn 13-3/8" x 9-5/8" ann, followed by 30 bbls diesel, POH. RIH, drl 12~" hole to 5375'. 4262', 32-3/4°, STW, 4191TVD, 400 VS, 401S, 32W 4586', 42.7°, S6W, 4446 TVD, 598 VS, 598S, 54W 4826', 50.3°, S6W, 4612 TVD, 771VS, 771S, 73W RECEIVED OCT 1 ! 1985 The above 18 correct Signature For form preparation end dletrl~utlonl asa Procedurea Menu~l, $ectlo~ 10, Drilling, Pe0e8 86 and 8?. '] Date [ Title 7/24/85 rcc' ~,~UI I~,~. ~1~1,~ I l l A,t;horage Drilling Superintendent ...J ARCO 0il and Gas Company Daily Well History--Interim Instn~cllena: This form ia used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerlm" sheets until final completion. Report official or represenlative test ;n "Final" form. 1) Submit "Interim" sheets when filled out but not lass frequently than every 30 days, or (2) on Wednesday of the week in which oil string ia set. Submit weekly for workovere and following setting of oil string until completion. District ICounty or Parish i State Alaska North Slope Borough Field tee__~e or Unit Prudhoe Bay ADL #28328 Complete record for each day while drilling or workover in progress Date ,,nd ~lepth as of 8:00 a.m. 4~26~85 4/27/85 thru 4/29/85 4/30/85 Alaska Well no. DS LI-1 5/01185 5/02/85 5/03/85 The above is correct 13-3/8" @ 4089' 7100', (1725'), Drlg Wt. 9.3, PV 5, YP 6, PH 7.6, WL 18, Sol 7 Drl &surv 12¼" hole to 7100'. 5288', 51.1°, S 6W, 4905 TVD· 1128 VS, 1126S, lllW 5810', 51.1°, S 9W, 5232 TVD, 1533 VS, 1529S, 164W 6271', 52.4°, S12W, 5518 TVD, 1895 VS, 1885S, 230W 6816'· 53.3~, S14W, 5847 TVD, 2329 rS, 2308S· 327W 13-3/8" @ 4089' 9437', (2337'), RIH v/Navi-Drl Wt. 9.6· PV 12, YP 3, PH 9.5~, WL 9.8, Sol 9.4 Drl &surv 12¼" hole to 9437', POH. PU Navi-Drl w/2° bent sub, RIH. 7312' 8214' 8660' 8990' 9334' · POOH wet, lk's f/wshout. Nozzle broken TIH, wsh & rm 11,413'-11,488', drl to 11,586', circ gas , 47-3/4°, Sl3W, 8514 TVD, 6054 VS, 5933S, 1215W , 54.7°· Sl4W, 6139 TVD, 2730VS, 2698S, 424W , 54.8°· S14W· 6651TVD, 3471VS, 3417S, 609W , 57.4°, SlSW, 6899 TVD, 3840VS, 3775S· 702W , 59.4°, SlSW· 7072 TVD, 4120VS, 4047S, 774W · 61.4°, SI6W, 7242 TVD· 4418VS, 4335S, 854W 13-3/8" @ 4089' 9640'· (203'), RIH w/BEA Wt. 9.5, PV 8, YP 5, PH 9.5, WL 8.6, Sol 8.5 Navi Drl to 9640'· POH, LD Navl-Drl. MU BHA, RIH. 13-3/8" @ 4089' 10,383', (743'), Drlg Wt. 9.8, PV 8, YP 5, PH 9.4, WL 7.8, Sol 10.5 RIH, rm 9406'-9640', drl 12¼" hole to 10,383'. 9653', 56.7°, S12W, 7406 TV]), 4691VS, 4600S, 920W 9904'· 55.9°· SllW, 7545 TVD, 4900 rS, 4805S, 962W 10,149', 53.4°, S12W, 7687 TV]), 5099 rS, 5001S, 1001W 13-3/8" @ 4089' 10,989', (606')· Drlg Wt. 9.9· PV 9· YP 4, PH 9.3· WL 7.6· Sol 11 Drl &surv 12¼" hole to 10,989'. 10,393', 50.5°, S13W, 7837 TVD, 5292 VS· 5189S, 1043W 10,640', 48.5°, S13W, 7998 TVD, 5479 US, ~S_ ~ 1086W 13-3/8" @ 4089' 11·586', (597'), Circ sas cut mud Wt. 9.8, PV 7, YP 4, PH 9.3, ~ 8.0· Sol 10.5 Drl &surv to 11,488' on bit. f/mud. 11,414' Signature For form preparation ~nd distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 lDate [Title 7/24/85 Drilling Superintendent RECEIVED Alaska 0il & (las Cons. Commission Anchorage ARCO Oil and Gas Company Daily Well History--Interim Inatructiona: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish IState North Slope Borough Alaska ILease or Unit IWell no. ~ ADL #28328 I LI-1 Field Alaska Prudhoe Bay Date and depth as of 8:00 a.m. 5/o4/85 thru 5/o6/85 5/07/85 5/o8/85 5/09/85 5/lO/85 Complete record for each day while drilling or workover in progress 9-5/8" @ 11,897' 12,187', (601'), Drl$ Wt. 9.5, PV 10, YP 9, PH 9.0, WL 13.6, Sol 8 Circ, drl to 11,912', 15 std short trip. Rm 11,877'-11,912', 11~5 TOH. RU & rn 294 its, 9-5/8", 47#, L-80 BTC csg w/FS @ t-~, FC @ 11,805'. Cmt w/850 sx Cl "G" w/l% CFR-2, .3% Halad-24 & .5% KC1. Pispl using rig pmp, bump plug. CIP @ 0015 hrs, 5/5/85. PU 8½" BHA, DO cmt & flt equip + 10' new hole. Conduct formation leak-off tst to 12.5 ppg EMW. Drl 8½" hole to 12,187'. 11,817', 44-3/4°, Sl8W, 8794 TVD, 6344 VS, 6214S, 1293W 9-5/8" @ 11,897' 12,442', (255'), Drlg Wt. 9.5, PV 7, YP 3, PH 9.3, WL 12.6, Sol 8 Drl to 12,442', losing fluid. Add LCM pill, TOH f/bit. 9-5/8" @ 11,897' 12,670', (228'), Drlg Wt. 9.5, PV 8, YP ~, PH 8.0, WL 14.0, Sol 8 TIH to 12,362', rm undergage hole 12,362'-12,442', drl 8½" hole to 12,670'. 12,374', 42-1/4°, SlSW, 9197.58, 6723.66, 6578.39S, 144.65W 9-5/8" @ 11,897' 12,856', (186'), Pull into. csg shoe Wt. 9.4,.PV 10, YP 10, PH 11, WL 14, Sol 8 Drl to 12,856', lost circ @ 12,850'. Mx & spot 50 bbl LCM pill, monitor well, loosing ±.70 BPH fluid. Mx & spot 2 more LCM pills. Drl f/12,850'-12,856' @ lower circ rates, loosing rtns, POOH to 9-5/8" csg shoe. 9-5/8" @ 11,897' 12,856', (0'), Monitor well Wt. 9.4, PV 9, YP 3, PH 9.5, WL 14, Sol 5 Att to circ out gas f/upper zone while sealing up lost circ in lower zone. Control mud wt & spot LCM pills. Monitor well & prep to POOH, Lost total of 1100 bbls in last 24 hrs. The above is correct For form preparation and distributi(~ see Procedures Manual Section 10,' Drilling, Pages 86 and 87 IDate ITitle 7/24/85 Alas~(a Oil & Gas Cons. 6ommissior, Ar~chorage ARCO Oil and Gas Company Daily Well History---Interim Instructions: This form is used during drilling or workov;r operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish IStete Alaska North Slope Borough Field ILease or Unit #28328 I !Complete record for each day while drilling or workover in progress Prudhoe Bay Date and depth as of 8:00 a.m. 5/11/85 thru 5/13/8s s/14/85 5/15/85 Alaska Well no. DS L1-1 5/16/85 9-5/8" @ 11,897' 12,856', (0'), Spot LCM pill Wt. 9.4, PV 10, YP 5, PH 10, W-L 12, Sol 4 POOH 10 stds, RIH to 9-5/8" shoe. Mx & build mud vol, well flowing, SI. Mx Zone Ck pill, strip in hole to 12,611', pmp BJ Zone Ck & diesel, displ to bit w/final sqz pressures DP=800 psi/2 BPM, ann 375 psi/2 BPM. Displ Zone Ck to 12,680', strip out of hole to csg shoe. Circ out 2 csg vol gas cut mud w/9.4 ppg in, 9.2 ppg out. GIH to 12,611', wsh 12,611'-12,680', lost rtns, POH to csg shoe. M&P 2nd Zone Ck pill & diesel, displ w/9.4 ppg mud; no rtns. POOH to 9-5/8" csg shoe, att to circ w/o success. POOH 3 stds, hole swabbing. Pmp Zone Ok & fin displ'g ann w/9.4 ppg mud using rig pmps. Displ Zone Ck, monitor hole. Fin POOH, LD BHA. GIH to 9-5/8" csg shoe, rm 11,897'-12,070'; lost rtns, POOH to shoe. Build vol, GIH to 12,070', rm to 12,713', lost rtns. Pmp coarse nut plug, gas cut mud in rtns, CBU, POOH to 9-5/8" shoe. Att to est circ, wrk pipe, fluid level dropped rapidly. Fill f/backside, M&P LCM pill, monitor hole. M&P 2nd LCM pill. 9-5/8" @ 11,897' 12,856', (0'), Logging ~ Wt. 9.4, PV 10, YP 4, PH 9.5, WL 14, Sol Fin spot'g LCM pill, POOH, fill & monitor each 5 stds. RU Schl & lubr, rn DIL/LSS w/waveforms/GR f/12,838'-11,897'. Log LDT/CNL/GR/CAL f/12,836'-11,897'. 9-5/8" @ 12,856', Wt. 9.4, Fin POOH. f/12,838' in hole, 11,897' (0'), Circ gas cut mud PV 9, YP 8, PH 8.6, WL 12.8, Sol 5 PU EPT/Pg(~, log f/12,835'-11,897'. Rn EGT/CNL/GR -10,600',P%~il started flowing, POOH, RD Schl. Stage CBU gas cut mud @ 3000' intervals. 9-5/8" @ 11,897' 12,856', (0'), [IH Wt. 9.4, PV 8, YP 6, PH 8.9, WL 12.4, Sol 5 Stage in hole, circ, hole taking fluid. Spot LCM pill, TOH. RU Schl, rn DLL/MSFL/AMS f/12,834'-11,897'. Temp log shows no loss above 12,832'. Chg rams to 5", tst doors to 3000 psi. RIH. Lost total 1600 bbls/24 hrs. The above is correct Signature For form preparation and distribution see Procedures Manual Section 10~, Drilling, Pages 86 and 87 Da,e 7i24i85 ITi,le Alaska Oil & Gas Cons. Commission Anchorage ARCO Oil and Gas Company Daily Well History--Interim Inltmctionl: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Flail" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovere and following setting of oil strin§ until completion. District ICounty or Parish IState Alaska North Slope Borough Field ILease or Unit · I ADL #28328 Date and depth Complete record for each day while drilling or workover in progress Prudhoe Bay aa of 8:00 a.m. 5/17/85 5/18/85 thru 5/20/85 5/21/8~ 5/22/85 9-5/8" @ 12,856', Wt. 9.4, Spot LCM 12,856', 11,850', 11,897' (0'), CBU @ 8500' PV 9, YP 5, PH 8.8, WL 12.8, Sol 5 pill, POH 20 stds, monitor & fill hole. TIH to M&P Super Flow Check. Displ using rig pmps, POH to CBU, TOH. TIH w/bit f/CO. Alaska 9-5/8" @ 11,897' 12,800' PBTD, (0'), Circ lnr Wt. 9.4, PV 7, YP 5, PH 8.8, WL 14.4, Sol 5 TIH to 12,850', spot LCM pill, POH. TIH w/OH BP, set @ 12,841', TOH. TIH, tag BP @ 12,846' (dropped 5'), spot LCM pill, TOH. RU & rn CCL/Temp; tl failure. TIH, spot 150 sx Cl I'G" w/l% CFR-2, .3~ Halad-24 & 3% KCl, TOH to 11,840'. TIH, wsh 11,897'-12,800', CBU, spot LCM pill, TOH. RU & rn 25 ]ts, 7-5/8", 29#, L-80 SFJP. I ~0~::" 7-5/8" @ ~ 12,800' ~, (0'), TIE w/bit & scrpr Wt. 9.4, PV 5, YP 3, PE 8.7, WL 14.0, Sol 5 TIE to 12,770', wsh to 12,800'. Cmt 7-5/8" lnr w/200 sx Cl "G" w/1Z CFR-2, 4Z Gel, 15#/sx Gilsonite & .2Z ER-7. Displ using rig pmps. CIP @ 1715 hfs, 5/20/85. PU 8%" bit~9-5~8" scrpr, TIE. 7-5/8" @ 12,800' 12,788' PBTD, (0'), LD DP 9.4 ppE NaCl/NaBr TIH w/9-5/8" scrpr to 11,084', wsh to 11,482', DO cmt to 11,690', C&C, POH. TIH w/6-1/2" bit & 7-5/8" scrpr to TOL @ 11,690', DO cmt to 12,700'. Tst lnr to 3000 psi; OK. DO cmt to 12,788'. Displ well to 9.4 ppg brine, TOH, LD DP. IWell no. DS LI-1 The above is correct Signature For form preparation and di~tl~ution see Procedures Manual Sectidfl 10, Drilling, Pages 86 and 87 Date ]Title 7/24/85 Drilling Superintendent ARCO Oil and Gas Company Daily Well History- 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 for 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 if space is evadable. I Accounting cost center code District ICounty or Parish I State Alaska I North Slope Sorough I Alaska Field ILease or Unit Well no. Prudhoe Bay [ ADL ~t28328 DS L1-1 Auth. or W.O. no. [Title AFE 503584 [ Drill, Complete & Perforate Parker 176 Operator [ A.R.Co. W.I. ARCO Alaska, Inc. I 21.66% Spudded or W.O. begun ]Date Spudded [ 4 / 19 / 85 Date and depth as of 8:00 a.m. 5/23/85 Complete record for each day reported 50-029-21317 Iotal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our I Prlor status if a W,O. I 0600 hrs. 7-5/8" @ 12,800' 12,788' PBTD, (0'), RR 9.4 ppg NaCl/NaBr POOH, LD DP. RU & displ top 2000' of hole w/diesel. NU & tst tree to 5000 psi. RR @ 0300 hfs, 5/23/85. location on DS 11-13 f/rig move. ND BOPE, ,Prep Old TD Released rig 0300 hrs. Classifications (oil, gas, etc.) Oil New TD pR Depth 12,856' (5/8/85) K nd of ri. JDate 5/23/85 Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Prudhoe Bay Potential test data 12,788' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct 7/24/85 Drilling Superintendent For form preparation ~nd dlei~ibution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. L I S ~-'J ~ N~. LI-1 ~ ~. J.gHO: 54Y/LIS3URNE t,J 3 R TH SLgm=,4L4SK~ ?]3L CgMPUT4TIgN OAT': 18-J~N-B$ DATE 2F SURVEY: 10-25-85 KELLY BUSHING ELEV&TION: ENGINEER: WEST .N 5~. O0 TRUE V:RTIC&L 0.00 O.Oe 190.00 lO0.O0 ZOO.30 200.00 ~nO.O0_. ~ 500.00 ?~O.gD ~9~.~7 ~gO.OO 900.00 l)O0.OJ )~9.}$ il~Ou .OJ 1099.95 1230.D0 1199.~5 1309.00 1299.}5 z4~9,0] 13~9.~5 1530.]0 1499.~5 I5~O.~O 1599.~5 17~0.00 1599.75 1~]0.00 1799.)5 1900.23 =090.32 1995.~ 2130.00 1290.90 219~ )4 2300.00 1199.~3 Z~]O.]3 2399.33 Z390.00 2530.00 2599. 33 2730.30 25~W.~1 c~OO.O0 2799.~3 ~03.30 Z~99.57 3~00.93 29~9.32 3120.00 3093.5~ 3239.02 31~7.37 3300.~0 32~5.75 350S.00 3~0.31 3500.~ 35R?.51 3733,23 3°~a 3) 3777 3~00.33 3870.?1 INTE~POL4TCD VALJE~ FDR EV=N 100 FEE SUE-SE~ C3JRSE V:RTICAL DOG VERTISAL DEVI~TI]~ 4ZiMUTH SECTION S~V DE~H'.· DEG /IN DoG MIN FEET DEG -5~.00 0 0 N O 0 E 0.00 45 O0 0 13 S 50 17 : 0 05 1~$.00 0 1~ S 2-9 0 = 0.40 2~5.99 0 21 S 0 25 ~ 0.92 ~5.99 0 29 S :~ ~ ','/ 1-=3 %~,5.99 0 %0 S 32 3& W 2.50 5%'.98 0 ~2 5 21 39 '~ 3.63 6,..5.97 O 39 $ 25 5 ,,4 4.80 745.97 0 32 S 40 17 W 5.74 8~,5.96 0 ZT S 40 55 W 6.54 T OF MEASURED DEPTH 1045.96 O 25 S 31 36 W 1145.95 0 18 S ~$ 51 W 12~r-,.95 0 15 S 41 5) W !345.)5 0 12 -Z 70 ~0 ~ 1445.~5 O 15 S 7~ 3 5 1545.95 O Z3 S ~ 45 d 1645.95 0 ZO S 1~ 4~ W ~5.95 0 17 N ~- 52 E o ', o.Ta "04: 94 O 2~ ;q 35 ~9' '~'-' 10 15 2145 "~ 4 O 30 rN----.23 ~5 E 9,50 ~2~5.93 ~ 25 '-'N---~,~ ~tO~ 8 67 . 23~.93 0 '~, ,N 2~ ~4~'~'~ 7.88 254. ~ . ')1 1 33 S "l~i'~)'~ E .... °~;0~ 8 . ~ 6 2745.~5 2 37 S 2 ~3 ; 12.19 Z545.67 4 1 S I 3'3 W 17.94 2945.32 5 :~9 ; 8 i~, W 25.40 30,~6.53 6 1 S =, 43 W 38.41 3163.31 9 ~1 S 5 ~5 W 53.86 3241.7~ 11 0 S 1 ~3 W 71.66 3339.63 12 ~3 3 2 ~ N 91.95 3436.81 14 16 S 3 15 W 115.30 3533.51 15 17 S 1 53 W 1~0.53 351).w5 ll 3:5 S 0 5~ ~ 16~.24 3123.9~ 29 ~2 S I 2~ W 200.60 3515.71 23 lO S i 53 W 237.48 LEG RECTANGULAR ERITY NORTH/SOUTH /100 FEET 0.00 0.00 N ~).47 0.32 S O. 10 0.41 S 0.26 0.96 S 0.7-) 1.55 S 0.05 2.41 S ,l. 1 q. 3.47 S 3.05 4.57 S 0.02 5.q~l S 0.23 6.13 S 7.25 O.Zg 6.75 S 7.93 0.22 7.36 S 6.56 0.39 7.:~3 S 8.96 0.15 B.Z7 S ~.10 O.OB B.~,3 S 9.15 0.14 8.55 S 9.46 3,2~ ~,92 S 10.09 0.25 9.53 S 10.67 0.14 10.10 S 11.00 0.30 10.45 S CO3ROIN EAST/WE FElT O O0 0.19 0.02 0.13 0.05 0 .$7 1.2~ 1.72 2.30 Z.88 3.37 3.80 4.20 ~.54 4.99 4.10 3.83 3.9~ 4.07 g. O1 0.31 lO.Z1 S 0.28 9.75 S 0.37 9.16 $ O.ll 8.40 s. 0.0~ 7.5.~ ~ 0.5? ?.11 S 0.6) 7.33 S 0.94 8.91 S 1.32 12.40 S 1.29 18.18 S 3.,$1 3.08 Z.73 2.24 1.83 1.51 1..53 0.56 0.01 0.30 2.05 26.53 S 1.92 38.44 S 2,05 53.72 S 1.44 71.50 S 2.02 92.08 S 1.11 115.58 S 1.50 141.01 S 3.17 169.09 S 'Z.77 201.87 S 2.40 239.16 S 1.66 3.35 5.70 6.86 7.6~, 3.97 10.14 10.65 11.35 12.46 ATES Hi~.R~,,i~ DEPARTURE E 0.97 S 7 52 W 1.55 S 1 W ~.5~ S ( W ~.88 S W 5.88 S ZZ 59 W W 6.77 S W 7.55 S 25 32 w W 8.29 S Z? 15 W W 8.98 S 27 53 W W 9.~4 S 28 47 W W 9.55 S 28 1 W W 9.~8 S 25 37 d W 9.70 S 23 14 d W 10.32 S 22 40 W d 10.89 S Z1 58 W W 11.19 S ZD 58 W W 10.83 S 19 29 W W 10.23 S 17 33 W 9.56 S 15 36 W d 8.70 S W 7.B9 S 13 W 7.27 S lZ W 7.45 S 13 W 8.93 S 3 35 W W 12.60 S 0 I W W 18.19 S 0 56 W W 26.59 S 3 35 W W 38.58 S 4 59 W W 54.02 S 5 3 W W 71.93 $ 5 28 W d 92.~0 3 4 4~ d W 115.93 S ~ 26 d W- 141.38 S 4 6 W W 16-).43 S 3 35 W W 202.19 5 3 13 W W 23~.49 S 2 58 W 6:~'"2 A' AS(A, T'qC. LISqU~'~E LI-! P~JDH3~ 3AY/LIS~URNE NART~ SL2~E,~LASKa C3'APJTATI9q PJOL [NTERPOLA-TED · · TRUE SJB-SEA C~URSE ~£~SURED V:RTIC~L VERTICAL .DEVIATION lEPTa D:PTi DEPTH'"::D~G qIN ~-]O0.O0 3951.76 ~103.33 ~OEO.}O 4300.00 ~222.~0 4~09.33 ~303.?1 ~0.0] 4331.~3 ~730.00 ~525.53 ~9~3.00 ~656.75 5300.00 471B.~4 5130.00 ~780.94 5220.0~ 4843.~9 5390.~O ~906.29 5~90.00 -969.26 5500.00 5032.22 5500.90 5094.33 5703.00 51~7.57 $]03.09 5220.57 5~00.30 5253.~6 6000.03 5345.37 6130.30 5407.~9 6200.30 5W70.32 · 5303.00 5531.~4 6~O0.O0 5593.~7 6500.00 5554.34 5600.00 5714.20 6700.00 677~.19 6~03.00 6)00.00 5893.S9 7003.03 5953,62 7100.00 $012.66 7200,00 5071,08 7300,00 5129.38 7400.03 5186.7~ 7500.00 62~4.2~ 7600.00 7700.00 5356.76 7~00.39 5412.78 7~30.33 545~.75 3~07.76 25 ~3 3996.90 27 56 4084.07 30 j4 a168.40 34 1 ~249.71- 37 28 ~327.43 40 27 ~401.60 43 29 ~472.60 46 ZO ~53~.59 49 ~6 ~602.75 51 ZO VALUES FOR AZIMUTH OEG MIN S 2 ~ d S S 4 44 W S S S 5 12 W S 4 39 w 4664.94 51 42 ~725.94 ' 51 37 4789.39 51 4 w85~._~9 50 55 4915.26 53 59 4976.22 51 4 5340.93 51 6 5103.~7 51 7 5166.57 53 57 $229.~6 51 25 S 4 41 W S ¢ 58 W S 4 56 W $ b 2~ w S 5 52 W S 6 32 W S 7 1~ W S 7 3.q. W S 3 ~,8 W S 5291.37 51 ~5 5353.4'9 51 5416.0Z 51 28 5477.94 51 54 553~.47 52 22 5600.04 52 36 5660,20 53 6 ~7Z~.19 ~3 5789,1w 53 11 b839.99 53 18 5899.62 53 33 5958.66 54 3 5017.08 34 25 5075.08 54 38 ~132.78 54 ~7 $190.2~ 55 ~2~6.82 55 5302.78 56 ~3~8,78 59 S lO ~+9 W $ 11 16 W S 11 25 W S 11 53 W S 12 14 W S 1Z Z.) d S lZ 31W S 1,~ 42 W S 12 $7 W S 13 1~ w S 13 24 W S 13 31 S 13 2~ W S 13 18 4 S 13 33 W S 13 3~ W S 13 ~,3 W S 13 53 ..; S 13 ,,4 W S 13 3B W DAT::= 18-JAN-85 DATE OF SURVEY: 10-28-85 <ELLY BUSHING ELEVATION: ENGINEER: 4EST EVEN 100 VERTICAL SECTION FEET 278.37 323.22 371.83 425.36 433.34 612.78 682.86 756.70 ~33.85 911.T8 9~9.86 1067,63 1145,02 1222,44 1299.92 1377.67 1455.27 1533.04 1610.84 1689.37. 1767.73 1845.76 1924.27 2003.06 2082.58 2162.41 2242.35 232Z.32 ~402.34 2482.51 2563.09 2644.14 2725.49 2807.06 2388.77 2971,10 3053.,32 3136.52 311~.26 FEET OF MEASURED DEPTH DOSLEG SEVERITY OEGtlO0 2.63 2.2.~ 3.6,6 3.05 3.33 2.67 1.76 3.lq, 3.15 --0.17 RECTANSULAR NORTH/SOUTH EAST/WEST FEET FEET 280.47 S 13.94 W 325.73 S 15.71 W 374.59 S 18.82 W ~28.03 S 23.91 W ~86.00 S 2~,48 W 54a.$3 S 35.34 W 515.37 S 41.62 W 585.51 S 47.70 W 759.q. 8 S 53.74 W 836.74 S 60.15 W 280.81 326,11 375.06 ~28.75 r, 86.89 549.77' 51.5.78 587,17 761,38 838,90 0,22 0 .~..5 0.89 0.75 0.35 0,81 0.35 1.10 0,50 1,68 914.78 S 992.96 S 1070.75 S 114~. ZO S 1225.~,9 S 1302.75 S 1380.06 S lr~57.12 s 1534.14 S 1610.97 S 0.48 0.9~+ 0.59 0.36 1,19 1.00 0.36 0.30 0.43 0.13 1688.19 S 1755.11 S 1841.62 S 1918.53 S 1~95.53 S 2073.34 S 2151.32 S 2229.39 S 2307.44 S 2385.45 S PAGE. 0.48 0.49 0.20 0.22 0.47 0.82 0.70 0.15 0.35 0.67 2463.55 2542.03 2620.96 2700.21 277:).68 2,]59.21 2939.36 3019.83 3100.28 3180,81 54.06' DEPARTURE AZIMUTH DEG MIN S 2 50 W S 2454 S 2 52 W s 3j~q w S 3 ':i~ S 3 S 3 ~2 W S 3 58 W S ,4 2 W S 4 6 W 66.63 W 917.20 S 73.17 W ~95.65 S 80,14 W 1::973.75 S 86.!)~ W 1151.48 S 94,62 d 1229.14 S 102,'~2 W 1306.81 S 112.38 W 138~+.53 S 122.37 W 1462,25 S 133.49 W 1539.~4 S 145.89 W 1617.57 S 160.;1 W 1695.77 S 175.15 W 1773.761 S 190.54 W 1851.45 S 206.35 W 1929.50 S 222.~0 W 2008.02 S 239.87 W 2087.17 S 257.19 W 2166.154 S 274.66 W 2246,25 S 292,39 W 2325,89 S 310.66 W 2605.59 S S 329.22 W 2485.45 S S 348.04 W 2565.74 S S 366.95 W 2646.52 S S 385.77 W 2727.63 S S 404.63 W 2808.97 S S 423.93 W 2890.47 S S 443.29 W 2972.60 S S 463.12 W 3055.13 S S 482.~70 W 3137.67 S S 502.~8 W 3220.26 S 4 9 d 4 12 W 4 16 W 4 19 W 4 24 W 4 31 W 4 39 W 4 48 d 4 58 W 5 10 d 5 25 W 5404 5 54 W 6 +,W 7 13 W 725.,I 7 36 W ? 47 W 7 58 W 8 7 ,/ B 16 W 8 26 W 834,1 B A, 3 d 8 51 W 61 58 W C 2:.IDJT ATIDN 4RCJ 4L4SK4, INC. cIStU~q~ ' 1-I P~JOHO: 3~Y/LISEdR~E N]DTH SLOPE,ALfiSK4 P33L INTERPOL&TEO VALJES FO2 T~U qE~SUq£D V:RTI E aJ~-SEA CML VERTICAL TH DEPTH DEVIATICN AZIMUTH DEG MIN DES MIN ~OOO.O0 5525 9130.00 5591 ~230.00 563~ ~703.3D ~9!3 ~30'3.33 5971 ~00.03 ?023 .23 $~71.20 .91 ~527.91 .~3 558~.93 .75 56~2.75 · ;5 ~599.96 .3} 5755.09 .~5 .~5 586¢.S5 · ~2 5917.92 .51 ~330.~3 7374 ')100,93 7124 JDDO.DO 7172 9300.30 7220 )~30.30 7257 ~590,00 7317 ~$OO.JO 7370 ~7~0.03 7425 ~.~3'3.03 7491 ,72 7023.72 · ~5 7070.45 .73 7113.70 · 13 7165.13 ,9~ 7213.9~ .~S 7265.4~ .5~ 7316.64 .54 737'.6~ .15 7427.15 .3~ 7~33.34 S 9 ~4 $ 14 '60 ~0 S 14 51 ~5 S !~ 61 35 S 14 51 0 S 14 5V 9 S 13 56 5~ S 11 5b 32 S 10 55 55 $ 13 31 ~ 41 W 52 ,J 55 ~ 39 W 13 W 7 W 13330.30 l-OlO0.O0 ?b52 10230.30 7712 I]300.20 7773 !0403.33 7935 10~33.00 7901 10500.03 IJROO.O0 ~100 !O~OO.OO ~167 .53 759~.$0 .21 755~.21 .~Z 77~2.42 ,OJ 7~7.20 .7~ 7912.78 ,67 797~.37 · I~ '~046.14 .73 ~113.73 5~ 51 S 53 ~8 5 52 ~.~ S 51 39 S 50 Z4 S 49 15 S 48 9 S 47 53 c 47 15 a ~ 47 W lO 25 W 11 11 32 ~ 12 '12 31 W 12 37 W 12 35 W 12 13 15 d 11330.00 3235 !1100.33 3393 llZO0.OO ~372 !ltO0.O0 9~40 11~00.00 ~508 llSO0.O~ 11600.00 3643 11700.33 ~711 11300.00 97~0 11900.33 ~35! .73 31~!.70 .9~ 3249.98 ,28 331~.28 · GO 8335.40 .25 8a54.25 .97 5521.97 · 21 ~.$57.01 · 15 5725.15 .30 a?)?.~O 47 2 S 46 55 S 45 57 S 47 11 S 47 17 S 47 28 S 47 36 S 47 0 5 45 !5 S 43 i2 S 13 1.~ W 13 6 W 12 52 W 1Z 52 W 13 13 W 13 lB W 13 11 ~.l 13 33 W 15 51W 17 35 w DATE: 13-J~N-95 DATE DF SURVEY: 10-28-85 KELLY BUSHING ELEVATIDN: ENGINEER: WEST EVEN 100 S~CTION FEET 3301.67 3383.92 3~65.96 3547.41 3629.32 )711.99 3795.48 3~79.b) 3964.19 %049.~9 ~135.35 ~221.88 ~309,20 4396,)5 4484.51 ~57!.22 4655.8~ ~739.35 ~22.53 ~905,25 %9u7.49 5058.69 5168.96 5228.0! 5305.59 5381.96 5457.24 5531.76 5605.18 5679.79 5753,04 5626,02 5898.99 5972.12 $045.52 5119.00 $1~2.72 5266.34 5338.39 5~07.68 FEET OF MEASURED DEPTH DOGLEG RECTANGULAR SEVERITY NORTH/SOUTH 3EG/IOO FFET D.80 3261.05 S 0.47 3341.13 S 0.71 3¢20.98 S 0.80 3509.32 S 0.87 35~0.15 S 0.99 3560.7~ S 0.82 37~2.10 S 0.65 3~23.98 S 0,92 3906.25 S 0.55 3969.15 S COORDINATES EAST/WEST 521 34 W 330~t ':: '.i: 541.12 W 3364.~,67 560.39 W 3¢66,58 579.43 W 3547,95 598,17 W 3529,79 617.05 W 3712.38 $35,Z8 W 3795.81 656.08 W 3979.85 676.46 W 3964.39 697.30 W 4049.64 0,79 6072, O,B9 4155, 0.76 4241, 0.35 4326, 1,05 4411. 3.27 4~95. 2.29 4,578. 0.47 ~560. 0.53 4742. 0.55 4~23. 51 S 719.77 W 4135.%6 46 S 7w0.66 W 4221.94 14 S 763.01 W 4309.Z3 19 S 785.72 W 4396.96 09 S 808.14 W 4¢84.51 37 S 829,31W 4571.22 08 S 847.36 d 4555.84 17 S 862.77 W ~739.36 O1 S ~77.51 W 482Z.56 67 S 891.9~ W ~905.26 1.26 4904, 0.96 4984, 1.5¢ 5063. 1,62 5140, 1.44 5216. 0.73 5291, 0,83 5364. 0.22 5~37. 1.08 5510. 0,29 5582. 52 S 905,97 W 4967,50 68 S 920,12 d 5063.69 33 S 935.15 W 5148,97 86 S 953.63 W 5228.02 91 S 966.52 W 5305.68 q5 S 982.97 d 5381.97 99 S 999,31 W 5657.25 77 S 1015,65 W 5531.81 44 S 1031.84 W 5606.21 24 S 1048.43 W 5679.84 0.43 5553. 0.12 5724. 0,39 5795. 0.44 5867. 0.23 5938. 0.17 5010, .0,16 5082, 1.89 5154. 2,7~ 5224, 1.75 6290. 60 S I065,34 W 5753.10 75 $ 1061.96 W 5626,10 91 S 1098.44 W 5Bgg. OB 30 S 1114.66 W 5972.24 88 S 1131,26 W 6045.66 67 S 1148.20 W 6119.16 32 S 1165,12 ~ 6192.91 07 S 1182.00 W 6265.56 D1 S 1Z00,06 W 6338,65 7~ S 1220.40 W PAGE 5~.Ob DEPARTURE AZIMUTH DEG MIN S 9 5 4 S 9 11 ~ S 9 18 d S 9 23 ,I S 9 2.~..t. 4 S ~ .: W S 9 3,~ W S 9 44 W 5 949,/ S 9 54 W S 10 OW S 10 S 10 11 d S 1.3 17 W S 13 22 W S lO 27 W 510294 S 10 29 W S 10 29 W S 10 28 W S 10 40 W S 10 42 W S I0 43 d S 10 4J W S 10 47 w S 10 48 W S 10 52 W S lO 5'~ W S 10 58 W I I'~P. IIK',di~ I 1-i N]RTH SLD;~E, AL~SKj, P]OL CgMPUT~TI]~ DDT=: TRUE M~&SURE3 V~RTI'&L DEPTH OmpTq 12903,00 5924.52 1210~.~ 3)96.4~ 12ZJ0.33 ~059,1¢ 12330.03 1ZG30.O3 9217.00 IJ6OO.~] 9366. '~6 12730.93 ~47.5~ I'Z~O9.O0 12356..~3 )572.23 ZNTERPOL~T;9 VALJ6S FO~ :VZN 100 SJB-SEA V--'RTI~ALoEP CgURSE VERTICAL DEVIATION ~ZIMJT1 SECTION BEG MIN DEg Mit FEET ~870.62 8942.44 ~915.14 9088.64 9153.00 )23~.10 9314.95 9393.55 9473.50 44 1 S 16 13 ~ 5475.69 43 ~4- S 15 21 w 5545,00 43 2 S 15 ~7 w b613,40 42 16 S 15 3 ~ 5580.37 41 43 S !5 13 w 5747.40 40 3~ ~ 15 3~ ~ 5313.07 38 54 S 15 45 J 5376.56 37 22 S 17 2 4 5938,0~ 36 54 S 17 6 d 5397.7~ 36 ~4 S 17 5 W 7031,14 18-JAN-86 PAGE DATE OF SURVEI: 10-28-8'5 KELLY 8USHIN~ ELECATION: ENGINEER: WEST =EET OF M~ASURED DEPTH DOGLEG RECTANDULAR COORDINATES N]~[Z. DEm~qTURE .SEVERITY NORTH/SOUTH EAS WEST ~m~,t.~ AZIMUTH ]E$/100 FEET FE_ .~IIIM~.~. DEG MIN 2.42 5356,10 S 1240.88 W 6¢ mS 11 Z W 1.03 6~23,19 S 125g,34 W 654~{~'~ S 11 5 W 0,36 5~89,3S S 1277.78 w 6~13.9~ S 11 8 W 0,35 6554,50 0,61 5518,75 1.65 5582,09 1,35 5143,39 Z,~5 680Z,54 0,00 ~859,95 0.00 5892,09 S 1296,49 W 6681,50 S 11 ]"~"-'.W S 1315,02 W 67~8,1Z S 11 1. .W S 1333.61 W 6813.89 S 11 l~d S 1351,96 W 6877.58 S 11 20-W S 136t,96 W 693).11 S 11 23 W S 1387,62 W 6~98,88 S 11 26 W S 1397,51 W 7032,35 S 11 27 W 7 10 9 BAY ST I t?D - 02 4219 psi 2 1 1-09 4285 psi 1 1-01 4171 ~si L2-25 £2-29 4332 psi 12 L 1-08 0 L2-JJ 10 9 .R 7 4163 psi 11 10 L2-2~ 10 '°L£-,,~ 8 8 8 8 14 13 ~ Datum @ 8900' SS 10 9 8 7 - so PO/NT' ST I ('12- ' DS ,5 Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. 'OPERATOR, WELL NAME AND NUMBER Date Required Date Received Remarks · Sample~ ' · ~u~ ~o, .w~ ...... Az ........................ - 01~ ~ , Core Chips Core Description .~~~,, ,,~ Inclination Survey' . ~.__. ..,...~ ....................... ~_. '"~'~._.,.L ' ' ' Directional Surve ..~,~ . . ........... :~.-~ ....... ~,, , i g~l. Drill Stem Test Repor=s - ..~' ,'~.-......... Production Test Report,~ ARCO Alaska Inc. New Projects - Lisburne TRANSMITTAL State of Alaska To: Alaska Oil & Gas Conservation Commission Address: 3001 Porcupine Drive Anchorage, AK 99501-3196 From: Kelly Prockish Date: July 30, 1985 Attn: Transmitted herewith are the following: Final Tapes for Lisburne Well LI-I: C. V. Chatterton · /1 Each. Revised Open Hole Unshifted LIS, Run One, 5-14-85 Start Depth 12867.0', Stop'Depth 4019.0' 1 Each Revised Open Hole shifted LIS, Run One, 5.-14-85 Start Depth 12868.0' , Stop Depth 4019.0' Tape 1 of 2 LSS/Waveforms,'Run 1, 5-i4-85, 12886' - 11948' Tape 2 of 2 LsS/waveforms, Run 1, 5-14-85, 11833' - 12842' Receipt Acknowledgement: Return Receipt to: ARCOAlaska Inc. New Projects - Lisburne Attn: Kelly Prockish, ATO-463 P. O. Box 100360 Anchorage, Alaska 99510-0360 · ,~,~,..'.'.~, ~ ~ 6:.;s ConS. Transmittal No.: /q~ Processed by: ~ ~~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany ARCO Alaska Inc. New Projects - Lisburne TRANSHITTAL State of Alaska To: Alaska Oil & Gas Conservation Commission Address: 3001 Porcupine Drive Anchorage, AK 99501-3192 From:. Kelly Prockish Date: July 12, 1985 Attn: C. V. Chatterton Transmitted herewith are the following: Final Copies for Lisburne Well LI-I: (1 Set Bluelines, 1 Set Rolled Sepia) 2" & 5" Dual Laterolog - MSFL - GR, Run 1 5-15-85 2" & 5" Litho Density - Neutron (Raw Data), Run i 5-14-85 2" & 5" Long Spaced S'0nic - GR, Run i 5-13-85 Long Spaced Sonic Waveforms, Run 1 5-13-85 5" Micro - Log / GR, Run 1 5-14-85 2" & 5" Natural Gamma Ray. SpectroscOpy, Run 1 5-14-85 Cyberlook, Run 1 5-16-85 5" EPT.- GR, Run 1 5-14-85 2'" & 5" Dual Induction - SFL - GR, Run 1 5-13-85 2'! &'5" FDC - CNL (Porosity) & FDC (Raw Data), Run 1 5-14-85 2" & 5" Litho Density - Neutron (Porosities),.Run 1 5-14-85 Temperature Log from AMS, Run 1 5-15-85 2" & 5'~ Compensated Neutron Log (In Casing),'Run 1 5-14-85 Receipt Acknowledgement: · Return Receipt to: ARCO Alaska Inc. New Projects - Lisburne Attn: Kelly Prockish, ATO-463 P. O. Box 100360 Anchorage, Alaska 99510-0360 Transmittal No.: /6~. 0 Processed by: ARCO Alaska. Inc. Is a Subsidiary of AtlantlcRIchfleldCompany ARCO Alaska, Inc. ~," Post Office Bo~ ~0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 13, 1985 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton: Enclosed are the May monthly reports for the 3B-4 1Q-13 1R-6 2V-16 4-9 (workover) 3B-5 1Q-14 1R-7 L1-1 4-13 (workover) 3B-6 1Q-15 2V-13 L1-10 4-30 3B-7 1Q-16 2V-14 L2-24 4-31 3B-8 1R-5 2V-15 L2-28 9-34 If you have any questions, Sincerely, Gruber Associate Engineer JG/tw GRU9/L56 · o please call me at Enclosures following wells: 9-35 9-16 (workover) 11-13 263-4944. RECEIVED JUN 1 4 ]91l§ Alaska Oil & Gas Cons.. Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary of AIIsntlcRIchfleldCompany ,, ALASKA .- AND GAS CONSERVATION C ~IMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well I~ X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-55 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21317 4. Location of Well at surface 2183 ~ FSL, 2~8' FWL, Sec.1, T11N, RI~E, UN 6. Lease Designation and Serial No. ADL 28302 ALK 2313 For the Month of. May ,19 85 5. Elevation in feet (indicate KB, DF, etc.) ~+~ RKB 9. Unit or Lease Name Prudhoe Bay Uni1:/Lisbur 10. Well No. L1 -1 11. Field and Pool Prudhoe Bay Field Lisburne 0il Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 11~+5 hfs, 0~,/19/85. Drld 17-1/2" 1:o /+110~. Ran, cm1:d & 1:std 13-3/8" csg. Dr]d 12-1/~' hole to 11,912~. Ran, cmtd, & tstd 9-5/8' csg. Drld 8-1/2' ho]e to 12,856'TD (5/8/85). Lost c~rc. Ran logs. Spot plug @ 12,838~ (cmtd w/150 sx Class 'G'). Ran, cmtd, & ts1:d 7" csg. PBTD = 12,788~, Secured well & RE @ 0300 hfs, 5/23/85. 13. Casing or liner ru.n and quantities of cement, results of pressur~ tests 20" 91 5#/ft, H-~0, weld conductor se1: ~ 1i0~ Instld w/approx 2000# Po]eset 13-3/8", 68.0#/72.0#/ft, K-55/L-80, BTC csg w/shoe @ ~089'. Cmt;d~l~"' A ~00 sx Class G. 9-5/8", ~7.0#/f1:, L-80, BTC. csg w/shoe ~ 11,897~. Card w/850 sx Class G. 7-5/8", 29.0#/ft, L-80, R-3, SNLS csg f/11,690~ - 12,800~, Cmt:d w/200 sx Class G. 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/LSS/GR f/12,838' - 11,8977 LDT/CNL/GR/Cal f/12,836~ - 11,897¢ EPT/PCD f/12,835~ - 11,897~ (9-5/8" shoe) EGT/CNL/GR f/12,838' - 10,600~ DLL/MSFL/AMS f/12,83~~ - 11,897~ 16. DST data, perforating data, shows of H2S, miscellaneous data NONE .AJaska OiJ &.. Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~O ~ ~(~- TITLE Associa1:e Engineer DATE NOTE--Report~J3n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TENP/NR63 Rev. 7-1-80 Submit in duplicate ARCO Alaska, In;(' Post Office' ,_ _ x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 15, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports . ,. Dear Mr. Chatterton: Enclosed are the April monthly reports for the following wells: 1Q-1 2u-10 2V-12 3B-16 9-28 1Q-2 2U-11 2V-13 3-16 (workover) 17-14 1Q-16 2U-12 3B-1 4-32 ~~. 1R-5 2V-10 3B-2 9-16 (workover) L~-9 2U-9 2V-11 3B-3 9-27 L2-28 If.you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU6/LI06 Enclosures MAY'I 6 1985 ~aska 0~I & G~,s Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichll'eldCompany MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well I-~ X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-55 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21317 2183' 4. Location of Well at surface FSL, 2/+/+8' FWL, Sec.1, T11N, R1/+E, UM 6. Lease Designation and Serial No. ADL 28302 ALK 2313 For the Month of Apr~l ,19 85 5. Elevation in feet (indicate KB, DF, etc.) ~ ' RKB 9. Unit or Lease Name Prudhoe Bay Unit/Lisbur 10. Well No. L1 -1 11. Field and Pool Prudhoe Bay Field Lisburne 0~1 Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 11/+5 hfs, 0/+/19/85. Drld 17-1/2" to /+110'. Ran, cmtd & tstd 13-3/87' csg. Drld 12-1//+7' hole to 10,3837 as of 0/+/30/85. 13. Casing or liner run and quantities of cement, results of pressure tests 20'7, 91.5#/ft, H-/+O, weld conductor set @ 1107, Instld w/approx. 2000# Poleset. 13-3/8", 68.0#/72.0#/ft~ K-55/L-80, BTC csg w/shoe ~ /+089'. Cmtd w/2600 sx PF 'E' & /+00 sx Class G. 14. Coring resume and brief description NONE 15. Logs run and depth where run NONE 16. DST data, perforating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--ReI~rt on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP/MR31 Submit in duplicate Rev. 7-1-80 MEMORANOUM State of AlaSka ALASKA OIL AND GAS CONSERVATION CO}~ISSION TO: THRU: C. V~~t~rton Chai~(~ Lonnie C. Smith .... ~ Commissioner FROM: Edgar W. Sipple F~,~ SUBJECT: Petroleum Inspector-" DATE: FILE NO: TELEPHONE NO: May 13, 1985 D.EWS. 33 Inspect Diverter System on ARCO's LI-1, Rowan Rig 33. Monday, May 6, 1985: I traveled to ARCO's LI-1 to check diverter system on Rowan Rig 33' The diverter was in compliance with State of Alaska Regulations and API RP 53. Attached to this report is a drawing of the diverter system on Rowan Rig 33. In summary, I inspected the diverter system on Rowan Rig 33, ARCO's Li-1. The diverter system was installed according to API RP 53 and State Regulations. Attachment 02-00IA(Rev. 10/79) ~ LI- /d ..- "l MEMORANOUM State"of Alaska THRU: FROM: ALASKA OIL AND GAS CONSERVATION COMMISSION TO: C. V~~t:terton Chat~ ....... ~,.~./.' Lonnie C. Smith -'f' Commissioner Edgar W. Sipple, j~.~,"j× Petroleum Inspecto'r ~k,~ DATE: May 13, 1985 FILE NO: D. EWS. 38 TELEPHONE NO: SUBJECT: Witness BOPE Test on ARCO' s LI-1, Sec. 1, TllN,R14E,UM, Permit No. 85-55, Parker Rig 176. Saturday,, May 5, 1985: I traveled this date from Sohio's A-34, (Subjec~"0f another report) to ARCO's LI-1, Parker Rig 176, to witness a BOPE test. The drilling contractor was in the process of nippling up. The BO.PE test commenced at 2:00 am and was concluded at 3:40am. There was one failure. The API ring on the kill line leaked, it was tightened up and tested to 5,00.0 pounds satisfactorily. H2S equipment on the rig as follows: A s.trobe light will indicate~on"at 10 ppm of H9S,. at 20 ppi a szren goes off. There are six air packs on ~ig floor, two air packs in pump room, four air packs in pit area. They have four air packs at camp, they also have H2S lapel monitors for each individual. I filled out the AOGCC BOPE inspection report which is attached to this report. In summary, I witnessed the BOPE test on ARCO's LI-1, Parker Rig 176. Attachment 02-001A(Rev. 10/79) O&G t14 5184 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Operator Well Location: Sec / TI/M R I~ [ M Drillin8 Contractor ~Ar ](_~_. Ri[ # ~ '~ Location, General ~( Well Sign ~ General Housekeepin~ ~i Rig OF'C._ Reserve Pit Visual Audio Mud Systems Trip Tank Pit Gauge Flow Monitor BOPE Stack A~.'n~-a. ~,~,r even t e r ~, L Pipe Rams ~ Choke Line Valves ~:. ..~" ~.(~.'Pj,~ Valve O~ ~%ill LiRe valves Test Pressure ,heck Va~lve ~C~ ~:,, ~ ~;5, ~',~,"'fl Test Results: Failures ~0o0 ---"l Date .... ' ..... - ~ ~ Well / ;'- · ~.~,. ,:- Representative~;U ~'~ l(.,~ / ,{ Permit # ~'- Set ACCU~LATOR SYSTEM Full Charge Pressure Pressure After Closure Pump incr. clos. pres· 200 psig Full Charme Pressure Attained psig. l '~ ~) min ~G sec. _ ~ min ~)~ec. Kelly and Floor Safety Valves Upper Kelly~%~,'~Test Pressure Lower Kelly ~]~,. L-T~st Pressure Ball'Type ~ Test Pressure Inside BOP O ~ Test Pressure Choke Manifold ~" Test Pressure "' ' ' NoValves //3 ill.%~w" ~,,,.I i t'] ,,:,. No. flanges~,~D Adjustable Chokes ~ ~ ~ 7'..~ Hydrauically operated choke~L,..~,' ~,-I' .,.,.i~ '~-~"' Test Time t hrs ~ ~ ~ Repair or Replacement of failed equipment to be made within ~/~' days and Inspector/ Commission office notified· Remarks :_/ N~,¢, ~ f~.,,. /~)~,~/4 .t~,f-f',~, ~Z~. /.r~.~' ~??J4,,'~] ~o~~ ~o~ .... " ' , ~ ..~ ,~ .~..'~ 6 ~ ' ~c~.~ ~ ~ ~ 2~''~-,~,~ : ... ~ 2 (' . ~ "~ ' . . · ,.. Distribution ~;r' /~r Nal ~J,r~r ~. - orig. - AO&GCC ' ~'~c C[~.~ ~.~ ~d~f~ // ee - SuporvSsor Inspector ......... .~. ~ March 27, 1985 Mr. T. L. Fithian Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re:' Prudhoe Bay Unit I~l-1 ARCO Alaska, Inc. Permit No. 85-55 Sur. Loc. 2183' FSL, 2448' FWL, Sec. 1, TllN, R14E, UM Btmhole Loc. 634' FSL, 1195' FWL, Sec. 12, TllN, R14E, UM Dear Hr. Fithian: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is' required. Samples of drill cuttings .and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the Spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of'the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. ~.ir. T. L. Fithian Prudhoe Bay Unit LI-1 -2- March 27, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. %,~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Co~ission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that We may have a witness present. Very truly yours, C. V. Chatter.~on Chairman of Alaska Oil and Gas Conservation Com~_~_ission BY ORDER OF THE COMMISSION lc Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ,, ARCO Alaska, Inc{' Post Office'Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 20, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Lisburne L1-1 Dear Mr. Chatterton: Enclosed are: ° An application for Permit to Drill Lisburne L1-1, along with a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore ° A proximity plat ° Diagram and description of the surface hole diverter system ° Diagram and description of the BOP equipment We estimate spudding this well on April 1, 1985. If you have any questions, please call me. at 263-4610. Sincerely, T. L. Fithian Area Drilling Engineer TLF/o~/tw PD/L63 Attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany . " STATE OF ALASKA ALASKA{ ,)IL AND GAS CONSERVATION CL.vlMISSION . PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~X lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL~ SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE 2. Name of operator ARCO Alaska, Inc. P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface .:i.',., .. Unit or lease name .... !"':'~ "'~ ~.. Prudhoe Bay Unit/Lisburne 2183' FSL, 2z~z~8' FWL, Sec.l, T11N, RlZ~E, UN 4/asira 0// , ''" '~;''f~85 10. Wellnumber At top of proposed producing interval (~ ~'&'$ Cci';%, . 1320t FSL, 1320~ FWL, Sec.12, T11N, RI~E, UN (~ Target;) L1-1 At total depth ~ ~'1II,i~.,1. Field and pool 63q' FSL, 1195~ FWL, Sec.12, T11N, R1/+E, UN ~:'J'e '°~'lO~rudhoe Bay Field 5. Elevation in feet (indicate KB, DF etc.) { 6. Lease designation and serial no. Li sbu rne 0i 1 Pool RKB /~ PAD lb,~I ADL 28302 ALK 2313 12. Bond information (see~0 AAC 25.025) Federal Insurance Company Type St;at;ewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 9-1/2 mi. N of Deadhorse miles 63/~~ ~ TD feet ~GI-5 well 301~ ~ 5293'TVD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 12,606 ~ ND ~ (95~1 ~ TVD) feet 2560 0b,/01/85 19. If deviated (see 20 AAC 25.050) '120. Anticipated pressures 3571 psig@ R~°F Surface KICK OFF POINT 25~/~ feet. MAXIMUM HOLE ANGLE/~9.5 oI (see 20 AAC 25.035 (c) (2) /~/~50 psig@ Rq&~_ ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOp TVD MD BOTTOM TVD (include stage data) 30" 20" 91.5# H-/~0 Weld 80~ 30~ I 30' 110t 110~ 200# Poleset; 17-1/2" 13-3/8" 68.0# K-55 BTC 80' 30' II 30~ 1101 110' 3b~00 PF 'E' & 12-1//~' 9-5/8" /~7.0# L-80 BTC 11b, 20~ 29~ II 29' 11/~,91 8789' 500sxG&300sxPF'C'Arct;icPk 8-1/2- 7- 29.0# L-80 LTC/AilM lb,77' 11129' I~ 859~~ 126061 600 sx Class G 22. Describe proposed program: ARCO Alaska~ Inc., proposes 1;o dr~11 1;his Lisburne development; well t;o 12,606~MD(95/+1'TVD). A 7" l~ner w~11 be set; across t;he Lisburne ~ahoo. A surface divert;er will be inet;ailed and operat;ionally t;ested prior t;o spud. A 13-5/8'~ 5000 psi~ RSRRA BOPE st;ack w~11 be inet;ailed on t;he 13-3/8" surface pipe. It; will be t;est;ed t;o 5000 psi (3000 psi for annular) upon Jnst;allat;Jon and weekly t;hereaft;er. The maximum ant;icipat;ed surface pressure of 3571 ps~g was calculat;ed assuming a full gas column from t;he Top of t;he ~ahoo (z~50 psig ~ 89M+~TVD) considering t;he t;emperat;ure and compressi b~ 1 ~ t;y effect;s. Select;ed Jnt;ervals will be logged. A st;ring of 2-7/8", 6.5#, L-80~ EUE 8rd t;ub~ng, including provisions for subsurface safet;y equipment; will be run wit;h a packer set; above t;he ~ahoo. Select;ed int;ervals in t;he Lisburne will be perforat;ed and report;ed on subsequent; report;s. A non-freezing fluJd w~11 be left; Jn all uncemenl:ed annulJ wJt;hin t;h permafrost; int;erval. Reserve pit; fluids will be disposed (see at;t;ached sheet;) ..23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space below for Commission use CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required I APl number []YES ~j~NO r-lYES ~,N O j~YES r-]NO Permit number Approval date 1~5..~'''' ,¢ ~ ,..,03/.27/85 I SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVEDB //'. ~ ,COMMiSSiONER DATE ~az'ch 27, :].985 ~ ~'' ~ : ~"~~//~'~/ bv order of the Commission Form 10-401 (JJG) PD/PD63 ? Submit in triplicate Rev. 7-1-80 PERMIT TO DRILL LI-1 of down the 9-5/8" x 13-3/8" annulus of L1-1 prior to Arctic Pack operations. The annulus will be left with a non-freezing fluid during any extended interruption in the diposal process. RECEIVED ~,~,!'~ 2 2 ]985 Alaska Oil & Gas Cons. Commission Anchorage J U lO00 2000 3000 4000 5000 6000 7000 8000 900O 10000 11000 L1-1 .. 0 lO00 ti' :0 3000 4000 SO00~', 8000 7000 ___ A,RCO AL~iSKA, IN SCALE I I1~ -1000 FT. SHL: 2183' FSL, 2448'FWL, <OPTVD-2S~4 SEC 1,TllN,R14E,UM 2.5 7.5 THL: 1320' FSL,1320' FWL, 1~.6 SEC 12,TllN,R14E,UM 17.5 22,',> 27,5 ~;2.5 ~7.5 EO~: TV 286 lO - 4622 DEP - 802 (-5 TVD-754, MD-0534 0EP-4810 ~ ~iV~R ~:i~ - .uou ~u - i~.~ ocr - i2~ LCU TI~D - 8080 MD - 10372 DEP - 5247 SAG RIVER TVD ~8187 M I ~10402 DEP · 5338 TOP (IF $AD~ROCH IT TVD - 82~4 MD - 10641 Oi P - 5451 KAVlK TVD '888B MO- 1 310 DEP- 585B g-6/i,' CASING TVD - 8788 MD - 1 144B OEP - 80~16 WAHOO TVD ~ 8788 MD - 11404 DEP ~ 0~78 7' CASING POINT TVD - l ~44 MD - 12411 DEP - 0830 TD TVD, 9~1 MD-12110E DEP-6941 . 0 1000 2000 8000 0 3O00 'iO00 5000 VERT I CRL SECT I ON 1000 2000 3000 4000 5000 6000 7000 8000 9000 I0000 11000 Gas Cons. Oommbslae Anchorage oT £ - ~ COORDINB~F,S o-5OOO - ooo - .ooo - ooo o ooo 2000 ~ J I ~ ~ · I I I I I I I ~ ~ ~ I II I I I I ~ El II ~ ~ I I ~ I ~ I i I I I I I I I I III~' I I ! I I I I I , I I I I II I i ~ I SHL' 2183'FSL, 2448' FWL, SEC 1,T11N,R14E,UM THL' 1320'FSL, 1320'FWL, D SEC 12,T11N,R14E,UM 4017 = )~ TARGET TVD= 8944' 1 - 1 TMD: 11,687' DEP: 6246' , ii · RECEi tED Alas ~a,.l~l & Gas Cms. Comm!ssiol~ Anchora.c ~ J i i i i i i i i I i I ! i i i i i i i i i i i i i i i i i i ! i ii i i i i i i i i i i i i i i i i i i i i i i i i i !11 · I -5000 -4000 -3000 -2000 - 1000 0 1000 2000 P. - W OOORDINRTE]S o -5000 R - H COOROINBTES -~ooo ~ ~oo -~ooo -~ooo ~ 1000 2000 .... vw ~..d ~.., i i , ~ i ! I I I i i i ! i t [ t ! i I I [ I [ I I I I I i i ! i i i i I i i I I I I t i t i i m i ! i i I i I I I I I I [ ! 4017 903 N . 5461 ~,q7 ~-' ' ~ ~ol-~ [-1 RECeiVED. tlaska ~1 & Gas Cons. Comalsslo And )rage ] i i [ , [ i i I i i , i i i i w i i ] [ ] i i [ i i v i i i i i i i w i .[ i ~ i i i [ w [ i [ , i i -5000 -~O00 -3000 -~000 - ~ 000 0 ] 000 ~000 - ~ COORDINATES CD oT I--4 -5000 oT E - N COOROINB~£S -~ooo (ooo -~ooo -iooo ~',' o ~ooo ~.ooo ~.0 3 NG I-~ , I RECEIVED , ~R 2 2 ~85 dask8 Oil ~ Gas Cons. Anc~ :~rage II i i i i J i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i I i i Ii i i i i i i i i i i i i i , i i i i i i i Ii i -5000 -~OOO -3000 -2000 - 1000 0 1000 2000 · E - N COORDINRTES -~000 -5000 ~ ]00 - N COOROINB~ES -2000 -1000 1000 5000 -4000 -3000 -2000 -1000 Fi. - N O00ROINRTF:S 2000 0 1000 2000 -12 -800 -700 -§00 K - I,,l C00ROINFITFS -500 -400 -300 -zuu -100 0 · i i i , I I I ~ ! ' ' ' ' I I i i i i i i i i i i , i , i , ! i ! i ! i i i i i I i i i i , i ,-~ · ~ ~1 , , I I I I I i i i I i i i i i i i l N O/~~ t~~35 / 5925 -- 1 ~5~5~8395 '~5667 i 5065 ~n _,.,,-,. :65 4 51 ~5 ~ 1S3 /~dO~Z 25 NG I-4/ ~5028 ,'"I E C [ IVED !t422 / ~..NGI '12 ~1.,~=~. p~ & Ga,, Cons. Commis / ~,~ FI ~ Anti orage I , I I I I I I I I , I I I I I I I I I I , I , I , I I I I I I I I I I I , I I I I , I I I I I I I I , I , I I I , I I I I I I I I I I I , , , -800 -700 -800 -500 -400 -300 -200 - 1 O0 £ - N OOOROINR?£S ~ - ~ O00ROIN~TFS . -700 -800 ( $00 -qO0 -300 {, -200 -100 0 I I I I 45 ' . O~ ~525 35~ 6~68 ~35 I 839 , 5085 ~5667 81 L~,- ~5495 0 I ~ Z Ai.s~,:a ~,,~ & Gas Cons. Commlsslol Anchorage L --®- zO C = Z C Frl Alaska Oil & 6as Cons, Commissien knchorage RNNULRR · PRE'V~NTOR PIPE RRM$ BL~NO RRPIS SPOOL PZ'PE RRM$ 13-5/8" BOP STACK DIAGRAM ~:cumulator Capacity Test 1. Check and fill accxm~lator reservoir to proper level with hydraulic fluid. Z. Assure that accx~nulator pressure is 3000 psi with 1500 psi downstream of the regulator. $. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with charging pump off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressmte. 13-5/8" BOP Stack Test 1. Fill BOP stack and .manifold with a non-freezing liquid-. 2. Check that all hold down screws are fully retracted. ,~{ark running joint with predetermined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close anraxlar preventer an~ upstream valves. 4. hmctionally test chokes. -5. -In each of the following tests, first hold a 250 psi low pressure test for a minimtm of $ mimutes, then test at the high pressure. 6. Increase pressure to $000 psi ami held for a mimimmn of $ minutes. Bleed pressure to zero. 7. Open ama~ar preventer and close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pressure to zero. 8. Close valves directly upstream of chokes and open chokes. Increase pressure :o 5000 psi and hold for at least $ minutes. Bleed pressure to zero. 9. Open top set o£ pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bott~n set of pipe rams ami hold for at least 3 min- utes. 10. Test reamining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 11. Bleed pressure to zero. Open bottom set of pipe ra~s. lZ Back off running joint and pull out of hole. Close blimi rams and test to 5000 psi for at least 3 minutes. 13. Bleed pressure off all equipment. Open blind rams. Hake sure mani£old and lines are full of non- freezing liquid and all valves are set in drilling position. 14. Test standpipe valves to 5000 psi. 15. Test Kelly cocks and inside BOP to 5000 ps~ with Koomey pump. 16. Check operation of Degasser. 17. Record test information on blowout preventer test form. Sign a~zi send to Drilling Supervisor. 18. Perform complete BOPS. test once a week and func- tionally operate BOPS daily. CEiVED MAR 2 2 · Alaska Oil & Gas Cons. Coral Anchorage Revised !/21/84 Ls$iOa ARCO Alaska, InC. l~~ Post Office ,, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 15, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: Conductor As-Built Wells I & 9 Dear Elaine: Location Plat - DS L1 Enclosed is an as-built you have any questions, Sincerely, location plat for the subject wells. please call me at 263-4944. Gruber Associate Engineer JG/tw GRU3/L57 Encl osure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ LOCATED WITHIN PROTRAC{[ ~ SEC. I,TWR II N., R(~E. 14 E.,U.M. 031 O29 O25 023 019 017 0!~5 '013 011 O? O§ O3 el ;. LEGEND / NOTES CONDUCTOR AS-I~UILT EXIST. WELL 0 FUTURE WELL 520 390 28O 260 24O 220 200 180 160 140 120 I00 8O 60 40 20 ALL COORDINATES SHOWN ARE A.S.P. ZONE 4. BASIS OF LOCATION IS MON'S. bi N. TEMR 8~ I:1S. TEMP. PER. ER. BELL 8~ ASSOC. DES. J.B, CHK. W.S. DATE I-9-85 _ a[ JOB NO. ? I 6 3 WGI CCP VICINITY MAP lB T. IIN. NO SCALE ].1"1 LI-9 CONDUCTOR LOCATIONS~ I .Y=5,974,554.74 LAT.: 70°20'06.64t~'' 2448' F.W.L. ~(= 688r579.25 LONG=I48°28'II.857" 2185' ES.L. Y=5,974,774.15 688,595.84 LAT.= 70020'08.998" LONG=148°28' 11.255" 2468' EW.L. 242~_' ES.L. [.,, !, ,RECEIVED JAN 2 ! ]985 ~.r.,:.:,.,;~, ~.:,~ ,~ ~.~,'s Cons. C0mqlj.~JglrI D.S L.I COND. ~5 S. '! a 9 AS-BUILT ARCO Alaska, Inc. Subsidi.ry of Atlantic Richfield Company NORTH SLOPE DRILLIN, G-PRUOHOE B,AY ,, II SHEET I OF CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. f J.~ ~' /_/--/ ITEM APPROVE DATE (1) Fee :~ ~- ~'~" (2) Loc :.-- (,2 thru 8) .? (3) Admin //~.,..,/"' 5'~.".'~'.~" 9. ~(g thru 12) 10. //:,--# --,, .... . ..... ,.:: ,'.,'-."-. !,c: 11. (10 and 1~2) 12. YES NO 1. Is the permit fee attached ........................................ 2. Is well to be located in a defined pool .......................... 3. Is well located proper distance from property line ....... 4. Is well located proper distance from other wells ........ 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ..... 7. Is operator the only affected party ..................... 8. Can permit be approved before ten-day wait .............. Does operator have a bond in force .................................. · Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... REMARKS thru 2.1)' 13. 14. 15. 16. 17. 18. 19. 20. 21. Is conductor string provided ............................ ~ ......... Is enough cement used to circulate on conductor and surface ...... . Will cement tie in surface and intermediate or production stringsi ' Will cement cover all known productive horizons ............ ~ .... Will surface casing protect fresh water zones ................... Will all casing give adequate safety in collapse, tension and burst Is this well to be kicked off from an existing wellbore ........... Is old wellbore abandonment procedure included on 10-403 .......... Is adequate wellbore separation proposed .......................... · · /; (22 thru 26) 22. 23. 24. 25. 26. 27. ' Is a diverter system required ....................................... .,,,,,:~,.,.,~ Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ,.f] ,~"~-:> psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. , Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks: O ~0 Geology: Engrafting: JAL~.. '' rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature' that is not parIicularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to' simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. bls F.I~E NA~f; :GCT ,001 SERVIC~ NA~E : MAXIMU~ LF~IG'rH : 1024 FIbg TYPg PRE~I[).U~ FiSE ARCO AbASKA .'~OWN:. SECT: STAT: 'PRES': 14~ " liN. 'I '.C~NTENTS '. ,~, ".. . .. . . UN'IT 'TYPE CATE' SIZE coDE ... .~.~ ~.~.~.' ~.~ .~:~,~.. :~.~ .. 0.00. 000 0,t5 065 000 0'00 004 06 000.. '000 013 06:5 '' :' 000 O'O0' "003 0'65 000 O.O0 0..05 :0.65.. 'OOO 000 "00! o65 ... '"' ooo 000 007 :065 o ... 'U~!I.T'...~t.P£. CATE]. SIZE.. CODE . .... .. . " o00 '0'00 ooi '0'65' CAS i,.~,~G CASlC, G 20,0 (b 110 13,375 19 ~089 9,625 0 :1.1697 7.625 ~ 12800 A.Z].~,iI.)']:~.~, ['!F Pl.:,'k{'.i't,it,..f.., VKRTIr'A~, P{'..~Ai"~.:' 190,4 sur, F AC.k? t,(}C A q' 1,3t,,;; 2183' ************************************************************************** ..~ Y PF.,, S'~ '" .,. ,., E [~EPR CODE ENTRY 2 1 6 6 0 4 1 66 255 8 4 7 j 60 9 4 65 ,11 ~' 16 l 6& 1 0 1 66 O O~TU'M 6P~;CIFICATIO~< BLOCKS ,~NE~ SEi~VICE SERVICe; [It'~J]T AP1 AP"{};. .APl" 'APl Fii.,g. SIZe; SP~. REP'R ' lO ,)RDER # PROCE.S.m CODE (OCTAL:) FT O0 000 O0 0 'FT 99 000 00' 0 FT. .00 000 O0 0 D'EG O0 ' OOO oo 0 D'£G 99. .620 11 ....0. F'r ' 'o0 000 O0 FT O0 .OUO. 00.. ..... 0 O. 0 O. 0 DKPt' D£VI DCV1 DEPT DE'VI OEPT OEVI D,EPT DKVI DEPT .OEPT DEVI :. 'OEPT 0.~ 'O.EPT O~VI O'EVI ... D. 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'FI~. N~M~ :OD~M£ .006 'SERVICE' NAME :LO~ .. V,.E ~.S ,i.@ N. ~ : "D"~ T E' ..M:A.[iMOM LENGTH .:.:I0~ F'I LE' TYP[ ': . ~.R.[.V i0 V&. FILM :, .. . [,IS TAPE '~'ERIFICAiION LISTING LVP 010,~0~ VERIFIMA~'IDN I.,T$~ING PA?~; 1 * * WELL $~T~ ~AVA A~D T~BbES AR~ ~OT ~NCbUDED IN ?HIS bTSTING * * * , * ******************************************************************************* LVP Oln,MO.9. V6SR1FICATIO~,~ L. TST,IN(; PAGE 2 8ERYT, CF ~AME :DD~.HC DATE TAPE PREVIOUS TAPE : CONMEN~S :SC~L~IMREPGMR WELL SE~VICE~ PPOPRIETA~Y FTE[,D TAPE FISE NAME 8ERV~C~ NA~E DATE :83/11/17 ~AXI~U~ LENGTH :1.024 ~ILE TYP~ : PREVIOUS F~L~ : ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE REPR COD~ ENTRY I ! 66 0 2 1 66 0 3 2 79 7280 4 1 66 1 5 1 66 6 4 73 30 7 4 6~ INC~ 8 4 73 6 9 4 65 INCH 11 1 66 1,6 1 66 0 0 66 DATU~ SPECTFIC~TtON RbOC~$ MN~M SERVICE SERVICE UNIT API .API API AP1 FILE SIZE SD[~ REPR ID ORDER ~ b~G TYPE CLASS ~OD NO.. 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RI 0 52? ~3 0 522 ~3 o 529 R3 0 522 85 0 524 85 o 580 8'7 0 581 nl 0 581 02 o 582 O1 o 582 02 0 581 03 0 581 04 0 582 03 0 ~82 04 0 580 O1 0 580 Ol 0 580 02 0 580 n3. 0 580 04 0 DATA ** OEPT CILD OTb ?T4 WF1D 12886.0000 -76 8125 27 4844 7.3 8750 815 5000 1,2842 3086 12843 3086 ?00 q327456. IbM 1. TLD 36. TT). 857. WF2D 12R43. WF4D 1.2844. 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IF'iF'A?If'}N blSTIN(,; PAGE 7 -11030 -0670 -8~6~ -77~6 !.6394 14346 1276~ 11.3¢6 -16gb6 -ld51R -12566 -10~38lb054 143K2 8006 66b -12~2~ -11110 -9574 -5222 16634 14410 11770 49?2 -~4746 -1~102 -6~54 ~762 1202~ 10266 3~34 -7318 74 42 42 ~2 4~ 58 5~ 58 74 74 5R ~8 74 74 7a 58 74 58 74 74 74 K8 74. 74 74 74 5¢ 58 5~ 59 10~ 74 4~ o0 5~ 58 5~ 58 58 58 58 58 58 42 5n ~8 58 58 42 d2 42 42 42 4,2 58 ~8 58 58 58 58 5R 58 74 90 650 746 618 202 -11.10 -518 -198 -300 634 2090 3226 3770 970 -533 -1.845 -~677 054 1098 77A 154 -4294 -4006 -266] -422 3338 1514 -342 -191,0 -982 746 21,54 2954 1274 890 748 874 -1606 -~646 -3078 -~742 2186 2496 2186 ~.530 -2630 -~806 -2486 -1702 1,014 1.258 -22 -~750 -6 ~682 4842 6058 -518 -2486 -3~78 -4454 52~ 1098 1482 1850 8~ I146 -310 -1,894 - 6'18 -406 1946 3818 1082 -822 -2502 -3670 -2~ 11.46 1914 2138 -1286 -1558 -1462 -11~.0 554 570 522 522 140~ 1.082 650 234 -310 -102 250 666 666 330 -70 -534 -1734. -1254 -550 218 410 -310 -998 -1.494 266 762 070 874 -1046 -1.254 -1142 -694 2410 ~202 172~ 1114 719t 7850 -5350 -7706 3786 -355~ 1233n -17786 58 5~ 7a 5~ 74 58 58 59 42 58 58 58 58 -486 -966 3834 -2725 -678 2058 -306~ 3098 1114 -1846 634 -614 -3382 6122 -4102 2346 -3398 4858 -4118 1818 -646 68~ -54 1002 -1030 874 -1734 586 90 506 16000 -4054 6794 =13766 12346 -10918 17834 -1~4q6 42 58 58 74 74 74 ~8 58 58 42 58 58 ~2 42 ~8 1~6 -1158 -1494 3514 -1973 -1654 4074 =3638 2810 i130 -646 -326 522 ~4358 5242 -3046 2858 '4518 4970 -3766 10~2 '198 970 -246 1178 -t494 1274 -1606 -54 20170 -1, b134 16206 -1677R 18202 -15766 17322 -16118 4~ 58 58 74 7d 74 7~ 74 74 5~ 42 47 4~ 314 -1590 -1494 2986 -806 -274~ 5034 -3478 2298 538 -1254 1450 -4118 3658 -1686 ,3146 -4902 ,4218 -2790 1,54 186 1290 -]26 1130 -1814 1290 -1126 -230 1786 -438 18842 -10110 18842 -14870 1R810 -16166 15002 -13814 42 58 74 74 74 74 58 59 58 58 42 42 58 42 490 -t558 -726 ~154 298 -3734 46q8 -25~4 1,770 -358 1530 -2054 19~0 -2518 1642 -406 29?O -4294 2858 -!,430 -71.0 ~42 ~466 -374 938 -1926 970 -438 -662 2282 -582 LVP 01.ri,w02 VF. R1F1CA?ION I. IMTING PAGE 8 wF 1 -48~ -166 826 2A6 -1862 -1430 1668 1450 -966 -11g0 106 202 -~78 1~2 426 298 -262 -678 1242 ~1~4 -1510 -~070 39-58 3146 -3814 -3782 1098 1018 -827 -262 89n 4?6 -9-7~ -262 4~06 50q8 314 -374 -854 1167 -1270 154 -1078 2730 -2118 2490 -3318 410 58 -70 4689- 810 -90B -182 8~2 -120b 10 874 3!4 -13q8 9~842 -1606 1_3R6 -7534 154 1 O50 -150 :t78 3642 74 42 42 42 42 58 58 58 74 74 58 58 74 74 74, 58 74 58 74 74 74. 58 74 74 74 7~ 58 58 59 59 106 74 4~ O0 58 58 58 58 58 58 5R 58 58 42 5~ 58 58 58 49- 42 42 42 4~ 42 58 58 58 58 58 ~8 58 58 74 650 746 618 202 -1~.10 -51,8 -198 -390 634 2090 3226 3';70 070 '5)3 -1845 -~677 954 1098 778 154 -4294 -4006 -266~ -422 3338 151,4 -342 -1.9~0 -982 746 21,54 29'54 1~74 890 746 874 -1606 -~646 -3078 -~742 2~86 24~6 2186 1530 -2630 -2806 -2486 -1.702 1914 1,258 -22 -J750 -6 ~6R2 484~ 6058 -51R -2486 -3878 -4454 ~2~ 1.0~8 148~ 1.850 228~ !146 -.310 -!894 1~. -15 5 5 -9 -2 -14 24 -6 -15 -4 15 -~. 10 2O -4 -9 38 -27 -6 2O -30 3O 11 6 ,,,6 -33 61 -41. 23 -'33 49. 26 22 06 9R 14 34 69. 94 3O 47., 74 3O 14 98 74 4).. 58 58 74 58 74 58 58 58 5.".., 42 58. 58 5~ 58 22 86 66 34 25 78 58 98 14 22 07.. 46 1466 -1910 1,130 154 -71.0 -422 1002 362 -1254 1626 6O2 -1334 -598 -918 ~754 -198 2074 186 42 58 58 74 74 74 58 58 58 42 58 58 42 42 ~8 186 -1158 -1494 3514 -1.973 -16~4 4074 -3638 2810 1.130 -646 "3~6 522 -4358 5242 -3046 28~8 -4518 1482 -208A 1530 -230 -406 -550 826 282 554 1802 -2534 ~50 -1~74 1690 31'78 -1718 42 58 58 74 74 74 74 74 58 74 58 42 42 42 42 314 -1590 -1494 2986 -806 -2747 5034 -347~ 2298 666 538 -1~54 i450 -4118 3658 -~686' 3146 -4902 1242 -2070 1.690 -b30 -118 -518 5R6 74 234 -566 2762 -3308 826 -1142 1354 -230 4186 -]334 42 74 74 74 74 58 59 58 42 42 42 58 42 490 -1558 -726 2154 -3 34 4698 -2534 11770 1530 =2054 1930 ''25118 1642 70 -4294 [.,VP Ol0,N02 VEP.iFICA'~Ir~i~ blTSTI.NG PAGE 9 WF2 -267R -406 1046 1087 -822 -2502 -29 1146 10].4 -1786 -1558 -14b? 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VERIFICATION LTS:r.t)!G PAGE -~3m16 -12360 -11.~.28 -1o040 ~.1o96 1~14~, 1.6456 14248 -~6n -20408 -20376 -175~2 -927~ -75~,2 3016 169.~6 ~ 1624 ~744 -7768 ~3o4~ 1~ 16o 9496 72?4 -~7~88 -14968 -~3~76 -11704 7~79 -~215 -9656 ~69~6 1456~ ~2696 1~.176 -2~.20 4232 ~495~ ~191~ 10712 9&56 ~5~4 -~039~ -174~.6 -1108~ -900o 12536 -lb048 2112~ -864B -lOb4 -951~ 968~ -10840 3208 -725b 11.144 -13144 19208 -792 -15144 -440 4872 ?856 -g624 17370 -456 30~2 3752 9944 -11640 8664 -21672 1.1160 16552 -}3704 -8584 15096 -14600 -1592 17160 653~ -10408 14344 13672 -200~8 13656 19112 -20B40 -61~0 133~0 -2~576 -7896 ** FTb~ ~R~I~.,E~ ** FILE N~E ;~DB~C .{')02 VE~STO~ # : 26,2 ~AXI~U~ t, ENGTH :~024 FI[,E TYP~ ~EXT FIbF NA~E : EOF FI. bE N~ME JDDBHC SERVICE NA~E :bOG VERSION ff : 26,2 DATE ~A. Xi~U~ LENGTH FILE TYPE PR~VIO*~$ FIhM ** FIBE ~ibg NAME ~DDB~C .003 S'ERVIC~ NA~E VERSION # : 26,~ DATE :85/1~./!7 ' ~A~I~U~ LE~!GTH :1024 FILE TYPE :PR NEXT FIL~ EOF EOF ~m~m~m~mmmm~m~mm~mm~ V~RIF~CaT~U~ LIST~N~ ~I[,E 5Abm :WOT]' ,001 )AT~j : ~ILE TYP~ : ~, 1HFOR.~.~ATlnW R~C~R~S ** 000 000 015 O65 000 000 004 065 000 000 013 065 OhO 000 003 065 000 OhO 003 065 000 000 001 065 000 000 007 065 000 000 006 065 000 000 003 065 IIII IIII ~III I~II 000 000 001 065 {alT SI~E = 8,5" Ti'.2 19.856' = 7,~70 e 67,0 = 6,200 ~ 67,0 DF' = 6.940 ~ 67 0 D,F' V¥) O~.Oo~.'.O? uk:Pl'.m.ir'.,'.~q'l~hJ 'l.,I8?It. lt.; PAgE A.qF. hr.(l,, ****************************************************************************** * * * ¢[l~'b INDI~CT.Ir~N SPHERIC~i~,'f F'OCtJSFD bOG * OlT~ AVAILABb~; llSR1~ TO 1~786' * I,ITHO DE~T'I'Y CO~P~NgA~ED Ij[)~ * CO~P~NSATEB ~tEU'rpOr~ t,O~ * D~';~ ~VaIl,ARh~: llSrl' ~0 12834' * ~b~C~R~G~.~ETIe PROPAGA~'TFJN TO~L C~P~} * OiTh AV~IT.,ARI.,EI 11881' TO 1~812' *: t..~,l'.A A'~AI[,AP'L~: 40i0' Tn 11926' '* OATA ~DPM~'17 RrCORD ** TYPE 81ZB BE, PR CoDM ENTRY 2 I ~ 0 ~ 4 7] 60 g ~ 6~ ,1TN 18 1 66 1 0 I ~6 0 ~A~l.J~ SP~CTFTC.~TTON ~b~C~6 ;FI,L) 'I,P DII., t; 1' L IR ~AI,I rDN IR A'1. FDW ~NRA F'DN IPH1 ;R LOT :AT,',L )RHO ~,Dt ~RAT ~.,D~ ~N~A LDT IPtti LOt PROCESS bOG TYPK C1.,~$8 MOb NO. CDDE ¢OC~Ab) DPDFR # RT O0 000 O0 0 0 4 ! fib O00000OO000000 OH~ no ?20 Ol 0 0 4 1 68 00000000000000 nH~N n0 ~20 46 0 0 4 1 68 00000000000000 OH.~ no 1,20 44 0 0 4 I 68 00000000000000 ~'V no olo Ol 0 0 4 i ~g 000o0000000000 ~API O0 310 Ol 0 0 4 1 fib OnOOO000000000 CAPI 00 ]10 O1 0 0 4 I RB U0000000000000 IN O0 ~Bo 0! 0 0 4 I 68 00000000000000 m/C) 00 350 02 0 0 4 ! 6B 00000000000000 q/Pi O0 ]56 O1 0 O 4 1 68 00000000000000 00 420 0l U 0 ~ 1 68 00000000000000 no 000 00 0 0 4 1 68 00000000000000 PU 00 ~9n o0 O o 4 1 68 00000000000000 CPS O0 330 31 0 0 4 i 68 00000000000000 CPS 00 330 ~0 0 0 4 1 68 00000000000000 ~API 00 ]10 ~1 0 n 4 1 68 00000000'000000 T~4 O0 280 O1 0 o 4 1 68 00000000000000 ~/03 o0 350 02 0 o 4 I 68 00000n00000000 g/C3 00 356 ol 0 0 4 1 68 00000000000000 O0 ~o ol o o 4 ~ 6~ oooooooooooooo oo ~oo oo o o 4 ~ 6~ oooooooooooooo ~,u oo ,~o oo o o 4 ~ ~ oooooooooooooo oo ~s, o~ o o ~. ~ ~8 oooooooooooooo fps n,'~ 33n 31 0 CPS nO .I)30 qJO 0 ~).~g n~) .354 01 0 CPS O0 ]54 O1 0 CPS nO 354 nl 0 mPS no 354 Ol 0 ~PS nO nt)O nO 0 CPS O0 oOn no O CA~i oO 3 1. 0 n 1 0 ~API nO 310 01 0 PU O0 7 tq 5U 0 PlJ ~0 71q 50 0 mp~4 oo 790 5o 0 mp~i O0 799 50 0 CPS O0 3~0 nl o ~PS O0 ]10 O1 0 CPS no 310 Al 0 CPS OO 3lO Ol 0 CP~ O0 )10 01 0 Oi,{~M O0 ~52 O0 0 nH~t,~ no ~50 O0 0 TN O0 ~80 Ol 0 ~API O0 )lO O1 0 TN dO 280 O1 0 OH~ O0 270 04 0 OH~ ~0 22~ 1 0 0 aH~,~ nO 220 09 0 ~V O0 010 Ol 0 ~AUl nO )10 O1 0 YlS/F O0 520 RO O ~.]S/~ O0 !. 32 O1 0 ~.~,/~ O0 l~O 01 0 ~ O0 280 O1 0 ~ O0 ~80 01 0 V 00 n 00 00 u V O0 000 O0 0 ~AOI O0 ]10 O1 0 ~Ami O0 310 O1 0 PU nO 890 O0 0 ."C ,~] L -a99,~5oo -999.~5~0 -C99.9500 -g9g.?500 -a99.~500 -99a,~50o D R H 0 ~P~I POmA -ogq .7500 -990 2500 -qg9 2500 -99g ~500 -ggO 2500 -999 ~500 -99~,~500 -999.~500 -090.7500 .Tho NR~T POTA 4 1 68 4 I 68 4 1 68 4 I A8 4 ! 68 4 1 68 4 I 68 4 I 68 4 i 68 4 I 68 4 I 68 4 1 68 4 1 68 4 1 68 4 I 68 4 1 68 4 I 68 4 I 68 4 1 68 4 1 68 4 I 68 4 I 68 ¢ 1 68 4 I 68 4 I 68 4 1 68 4 I 68 4 I 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 I 68 4 1 68 4 i 68 -999.2500 -090.2500 CALl -999.2500 -999.~500 I999.2500 NRAT -999,2500 tlCNb -~9q.~500 !,,U -099.25n0 SG~ -qga.2500 ~snR onoOonO0 ooO00000 oO0OOOO0 ononooo0 00000000 O00nOOOn 00000000 oOOOO000 000o0000 0o000o00 0o000000 OHO00000 O0000oO0 O0000OO0 O00OO000 O000000O O00OO000 00000000 00000000 00000000 00000000 onoooooo 00000000 0000000~ 0000000 00000000 00000000 00000000 00000000 O00OO000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 000000 O0000O O0000O 000000 000000 000000 000000 O0000O 000000 000000 000000 000000 000000 000000 000000 O0000O 000000 000000 000000 0~0000 0 0000 000000 000000 0000 000000 000000 000000 000000 O0000O 000000 0~0000 0 0000 000000 00000 00000 O0000n 000000 000000 000000 000000 '999.2500 '999,~500 '999, ~500 '999. 2500 'q9g,~500 ~999i2500 999 999 ~500 ¥o ¢~l,n..,qO,,2 V~.~]~.LrA~.T, nr.,~ L..T~I'L~(:; PAC.,E; 6 )KPT 12700.0000 SFLU ;P -65,4102 {PHI ~. 0547 ~.'C ~ b ?ALI q,0254 ~N~A J . 40~4 NPHI PCNL. 3~85 ~000 ~GP 1 R. 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'999,2500 '~99.~500 'q99 2500 64:5020 -999,2500 '999,~500 -999, 500 -999.~500 -999 2500 -999!~500 -999 ~500 -999 ~500 *****~$~* EOF EOF EOF -nya,2500 'ri,Dk -aga,25oO w3~'G -o9a,25o0 ,,~:uoR -a99.7500 CALl -999,2500 $~' -o9q.2500 -099.2500 -~90,2500 -n99.7500 -990,2500 -99a.25nO -~9q.2500 75.~7R9 ~mmmm~mmmmmm~m#mmmmmm~ RIGTN :7042 O~'TT~ATInN RF¥ II.II-~$ TAV~ O~M~S : '* IN~PR~,A?IDN R.,F, CnRD$ ~RFS: E ~, COMWE,V,T$ ** 000 000 015 O65 000 000 004 065 OOO 000 Ol~ 065 000 000 003 065 000 000 003 065 000 000 001 065 000 000 007 065 000 000 006 065 000 000 003 065 000 000 001 065 ,¥~ olO,w09. VE~IF']CATIO~, L.T~TI~'.]G PAGE 2 ACC; 7049.9 LIqGCEDI 14 mAY 85 KRI. T~IrLT., L, CIJ~N~2Y :YPE: Ff.liTb rlFCOS]'TY "LI~ID t. OSS = 9,6.?.b" ia 1.~8g7' ' BiT SiZE : 8,5" ?U 1~856' ~ 9 4 bB/G R~4 = 7,~70 ~ 67,0 DF ~6,n S R~' : 6,~00 ~ 67,0 DF = 9 1, Rm~C = 6,940 m 67 0 DF - 1~ ~ ~3 R~ AT BHT = 2,,15 8 17~, DF * , ~u~.,. ~,u,,CTI~:~ SPH~C~b~.~ FOCPS~U bOG cp£t.) * DATA AVIILARL, F..I 118m1' TO l~.B]6' * r~UAI, bA'f~l~t,O~ fDI,b) * [)lTl aVl~II, A~bFt 118~1' TO lP820' * DATa IV~ILA~]LF{ 118~1' TD 12817' * T,OrG SPACE~ SO~IC lOG fl,SSi * D~TA IVllhA~b;~l 11881' TO 1~7R6' * FOR~!~TTU~I DE[:SITY COMPFNSA~ED [,,O~ fF'DN) * C~?PFt~SATED k'E~ITPU~ LO~ fFDN) * OATA AValLABLEI 118R1' TLm 1~832' * r,ITH~ DE~SITY COmPENSAtED LOG (b~l') * C~'PFNSA~E~ NEUTROn! {,0C; (hOT) * EbEC~RDMAG~'ETIC PROPAGAT70~ TOOb (EPT) * D~TA ~VRILA~LFI ' li, 881' TO 12812' V~ Ol.O.,H09 VEP]I:'.ILC'~?inh L~TS'T'II'~G PAGE 2 1 66 0 4 1 b6 1 8 4 73 60 9 4 6~ .lin !~ 1 b6 I t) ~ 66 0 IN~:~ SERVICE SMRVIC~ UNTT APl API APl AP7 WILE SIZE ~Pb NMPR 1,~ [3PDE? # bOG TYPE CbRSS MOD )EDT FT O0 000 00 0 O 4 ;FLU DII, OMEN 00 220 Ol 0 0 4 :L,D DIF, OH.N O0 i20 46 0 0 4 :~ 5I[, OM~ O0 120 44 0 0 4 ;a ~I!., ~¥ O0 010 O1 0 0 4 :R D1L GaPl O0 310 O1 0 0 4 ;R ~OW ~A~I O0 310 Ol U ~AI,I FON TN O0 280 Ol 0 0 4 )HDB rl)~ ~/C3 O0 350 02 0 0 )RHO FDW G/C3 O0 356 Ol 0 0 )Rn.T ~D~' O0 420 n! 0 0 4 )N~A ~O~ O0 000 O0 0 0 4 lPWI FD~ ~O O0 g90 O0 0 0 4 !C~*b ~'O~ CPS O0 330 ~1 0 0 4 ~C~tb rO~ CPS Ou 330 30 0 0 4 )F~C WON CPS O0 )54 O1 0 0 ~FD(] FDN CPS Oo 354 02 0 ;. oo o o ~HO8 LD? C/C3 O0 350 02 0 0 4 )R"O !:a? G/C3 O0 ~56 Ol 0 0 4 ;R~T t.,DT O0 420 Ol 0 0 ~N~A T,,Dm O0 000 O0 0 0 4 PROCBSS COD~ (OCTAb) 1 ~8 00000000000000 I 6B 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 2 68 00000000000000 1 68 00000000000000 I 68 00000000000000 ~ 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 I 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 i 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 I 68 00000000000000 ]PNi ! DT PU no ,~ r.i)) ~P~ O0 ]54 ~S ~.DT ~P$ O0 354 ,U LOT ~P~ .,1TH ~,DT ~PS 00 ]54 ;S~ [DT CPS O0 000 ~GR ~GT ~APl 0o ~10 )I]TA ~,G~ PI.i O0 710 ~0~A ~:0L PU O0 PHnR ~;GT PF~ 00 790 )R~,i~ ~G~ PP~ n0 792 V 2'.'G ~GT CPS nO ] 10 ~3~C4 ~:'G~ CPS O0 310 ~G ~'G~ CPS O0 310 ~5~:G ~G~ CPS 00 ~R v~L ~APl nO 310 ~I)"V ~'ST, ~HM~ O0 250 4D ~ b~., TN O0 280 ~R DLI, ~iPI O0 310 3AL1 PDt, ~N O0 ~80 ~SFL D~[, OHMM' O0 270 ~hD DLL OH~ O0 220 SDS nhL OH~ O0 220 ~P r)~L MV nO 010 ZR ~,SS ~APX O0 320 ~'F ~,SS tlS/F O0 520 JT[., l..,S R tIBIF 00 520 ~ATT KPT OSta O0 130 HO ~PT Ykq O0 280 $i FPT IN O0 mVD FPT V 0'0 000 ~VU ~PT V O0 000 IR ~pm ~API O0 ~R tNT, GAPI ~PRl CN[, Pkl O0 890 3SS Y,OT O0 000 3bS [,OV ** DaTa OEPT 12867 0000 SFLU 2.45~2 SiP -53:73R3 ~R , 64,15/3 RHOb -g99,9500 DR~O 999,~5~0 NPHi -o9q,~500 ~IC~b -'999 ~5 0 WFDC -09o,~500 GR -099:500 no o! ]0 01 nl 01 O0 ,no Al O1 5O 50 50 5O O1 O! Ol 01 O0 O0 01 O1 04 10 n9 n! O! RO ~0 01 O! Ol 01 nO o 0 01 O1 O0 O0 O0 YLD ~CNL I ~8 OOO00000000000 I ~8 O00nO000000000 1 68 00000000000000 1 68 OnO000OO000000 ! 68 UP000000000000 1 68 00000000000000 1 68 00000000000000 1 ~8 OOOO0000000000 1 68 00000000000000 1 68 00000000000000 I 68 O000000000000O i 68 00000000000000 I 68 00000000000000 1 ~8 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 OOO00000000000 1 68 00000000000000 1 68 00000000000000 I 68 O00nO000000000 I 68 00000000000000 ! 68 00000000 0 68 00000000° 0000 000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 i 68 00000000000000 1 68 00000000000000 1 ~8 00000000000000 1 68 00000000000000 1 68 O0000OO0000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 ! 68 000000 00000 1 68 oooooo88gooooo 1 88 00000000000000 1 68 000000 090000 I 68 000000~000000 I 68 00000000000000 1 68 00000000000000. i 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1,90fl3 IbM -999,2500 CALl -999,2500 RNRA -990'2500 NFDC -999~500 RH~B t -999 -999 -999 7881 2500 2500 2500 2500 ,Vp oln.H()9. ¥C.Ul~.'/CA,'IO~'4 LT$?It.tG PAGE 6 . 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MNOR 754,9 CALI ,64U5 FVh ,~5()0 NPUI )BPT 12600 ;P ~HOB 2 CFD(] 129fi 0000 SFLU 6133 ~R 0061 nRUO 3105 qCNb 6~75 G~ -99q 2500 -99q 25n0 -99q~2500 q99,~500 ~90 2500 -999 2500 -999 2500 -99q -099 2500 .o9o 7500 3 2463 b2 35~5 0 05~2 212~ 5000 57 4492 2 9768 2i2! 5000 25~ 8125 14 29~8 I 0567 7,~718 1,8663 q,6895 1~,~145 . ~,8521 99,.,~500 90 5273 1~ 7549 0103 ~775 250O 16 9893 1 3546 4775 ~500 ~0~ 0625 1~ 0049 ....1213 10 5645 47 4805 S ~770 -67 7852 10 ~848 3 -q99 3 8069 65 3308 -0 02~5 2313 5000 76 5898 rC"! b LITH t"GR ulNV FATT ~R NH.mT ~CWB CGR IJRRN t,~4NG "IwV EATT rVU NRAT PAL! -q~g -q9q -990 -999 -q99 -999 -999 -999 64 -999 -999 -o99 .25OO ,2500 .7500 ,2500 ,2500 ,2500 ,1523 ,2500 ,2500 ,2500 3,8538 56.1367 3,2522 69n,]125 9.5879 3,0725 ~90,~125 44,4180 10.6973 0,7563 1,;110 1, 659 5.6453 62,3555 ]8~,6406 0,9995 0.0239 237 1 3289 9 3~89 3! 14 0 53 92 16 ~99 3 0 4 74 4 619 10 6875 5986 4796 5000 0176 ,4512 ,15000 . 455 ,9707 ,8340 ,1729 6680 7773 7549 9375 7229 0186 ,3601 .8398 067i i ~125 79~8 POTA WING w5)~G HD .~.bD DT CAI, I ~NRA NFDC !,b SSi POTA WlNG W5NG "b G~ RNRA wFDC RHOB POTA WiNG WLNG HD DT IbM CALl -q99 2500 -999~500 -999.~500 -999~2500 -999,~500 -999, 500 -999,2500 -999,2500 73.4023 '999,{500 '999, 500 '999,2500 9 6562 3 0725 ~9 8125 2 5471 27 9785 135 6875 8 5625 220 2930 56 9!80 2 4 21 7775 7~ 0275 9301 50 2930 0 0073 133,3125 9,0254 1,4512 508,8906 2,6096 4,5410 98,4023 174,I575 0,2930 60,4492 1,1729 8,869i 115,5929 58,1367 8,8691 14,9551 0,0039 125 2,5491 ,VP 01c~.~t[17 '~!Emlwl'f'AT[n:~, I.,TS.~j.t'G PAGE 7 ,S ;R }TI. IA ;P JPHI ~EW ~OTA ;2~,G )TT., qHnB 'VPHI ~FDC 1..1'7 '7.5 4 oR 12~00 -24 ? 14 .]45 0 ~07 54, 3~ 20 °0 -q9a o000 5471 5020 OlO7 ~421 4375 3125 SGP 0103 7305 W3FG .7861 ~NnR .6455 CA[.I .85~5 SP ~2 3 ~PL O0 NPHI ~24,00 -34 4, -0 4 0 17 2~ 1,67 0 O00u 5820 GR 6780 DNHO 0073 4343 ~CNb 4375 LU 31~5 ~GP 0039 ?HOH 8955 W3NG 0674 06P2 SP 3867 6475 ~500 NPHI 12300 0000 SFt, U 4043 ~881 DRHO 1309 7 3 1 -4 1 1 2 4,13 3 443 2O 3 2 5 -3 -99 !4 2 504 1 504 'IR 1 10 -4 1 ,,,99 5 2 603 2 72n9 1.6523 2129 1367 ?°5775 ~°4707. · 1~5~45 ~,7046 1.6J1 ~861 176 ~500 ~643 8438 2500 0625 9180 5374 4424 1,680 96?9 9883 59R6 6975 ~500 4111 0103 ?5O0 ~455 413 2500 3125 ,1924 5266 1348 ~398 3008 0098 5256 ~500 9805 9580 0146 ?500 34~6 'f DD GR .~:RAT CAL! 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