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179-049
7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU WGI-03 Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 179-049 50-029-20385-00-00 9672 Conductor Surface Intermediate Production Liner 8577 80 2695 8543 1415 9627 20" 13-3/8" 9-5/8" 7" 8543 28 - 108 28 - 2723 26 - 8569 8255 - 9670 28 - 108 28 - 2723 26 - 7724 7468 - 8575 None 520 2670 4760 7020 None 1530 4930 6870 8160 9046 - 9580 7-5/8" 29.7# x 7" 26# L-80 / N-80 23 - 7928, 7999 - 8017, 8145 - 8161 8105 - 8509 Structural 7" Baker S-3 Packer 7845, 7131 7" Camco A-1 2175, 2175 7845, 7993, 8145 7131, 7255, 7379 Bo York Operations Manager Dave Bjork david.bjork@hilcorp.com 907-564-4672 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028302 23 - 7202, 7260 - 7274, 7379 - 7392 N/A N/A 239461 261971 5 5 3500 3706 325-166 13b. Pools active after work:Prudhoe Oil 7" Baker SABL Packer 7993, 7255 7" Baker SB-2 Packer 8145, 7379 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 10:08 am, May 09, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.05.09 09:48:47 - 08'00' Bo York (1248) RBDMS JSB 051525 JJL 6/13/25 ACTIVITY DATE SUMMARY 4/29/2025 T/I/O=2700/0/0 WATER WASH Pump 1bbl 60/40, 75 bbls 180* diesel, & 380 bbls fresh water w/surfactant down tbg.. Soak for 2 hrs. Pump 220 bbls FW w/surf & 12 bbls 60/40 to flush. FWHPs500/0/5 Daily Report of Well Operations PBU WGI-03 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: 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 this pool? Will perfs require a spacing exception due to property boundaries?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 ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU WGI-03 Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 179-049 50-029-20385-00-00 ADL 0028302 9672 Conductor Surface Intermediate Production Liner 8577 83 2695 6343 1415 9627 20" 13-3/8" 9-5/8" 7" 8543 25 - 108 28 - 2723 2226 - 8569 8255 - 9670 25 - 108 28 - 2723 2226 - 7724 7468 - 8575 none 520 2670 4760 7020 none 1530 4930 6870 8160 9046 - 9580 7-5/8" x 7" L-80 / N-80 23 - 79288105 - 8509 Structural 7" Baker SB-2 7" A-1 Modified 8145 / 7379 2199 / 2199 Date: Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com 907 - 564-4672 PRUDHOE BAY 5-2-2025 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: 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 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 11:08 am, Mar 25, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.03.25 06:58:29 - 08'00' Bo York (1248) 325-166 JJL 4/7/25 DSR-4/1/25 10-404 A.Dewhurst 10APR25 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.14 16:50:46 -08'00' 04/14/25 RBDMS JSB 041725 Well Work Prognosis Well Name:WGI-03 API Number:50-029-20385-00 Current Status:Gas Injector Leg: Estimated Start Date:May 2, 2025 Rig:N/A Reg. Approval Req’d?10-403 Date Reg. Approval Received: Regulatory Contact:Carrie Janowski Permit to Drill Number:207-0530 First Call Engineer:Dave Bjork Office: 907-564-4672 Cell: 907-440-0331 Second Call Engineer:Jerry Lau Cell: 907-360-6233 Gas Injection Rate: 245,298 Mscf/Day Injection Pressure: 3,557 psi Reservoir Pressure (Estimate): 3500 psi Program Objective(s): WGI-03 is a gas cap injection well that has demonstrated a decrease in injectivity. The well has not been water washed since perfs were added in 2023. Water washes are designed to dissolve salts and asphaltenes in the tubing and formation. The objective is to perform a tubing water wash to increase injectivity and perform a general maintenance on Gas Injection Wells. Proposed Program: Pump diesel followed by Fresh Water and Surfactant as per attached pumping template. Well Work Prognosis Well Work Prognosis MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC WGI-03 PRUDHOE BAY UNIT WGI-03 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 WGI-03 50-029-20385-00-00 179-049-0 G SPT 7133 1790490 1783 3522 3522 3524 3526 40 41 42 42 4YRTST P Kam StJohn 6/22/2023 4 Yr AOGCC MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT WGI-03 Inspection Date: Tubing OA Packer Depth 22 2506 2434 2399IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS230623161306 BBL Pumped:3.1 BBL Returned:3 Thursday, July 27, 2023 Page 1 of 1 Operator Name:2. Development Exploratory Service 5 5 Permit to Drill Number:179-049 6.50-029-20385-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 9672 7877 7160 none none 7131,7255,7379 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 83 20" 25 - 108 25 - 108 1530 520 Surface 2695 13-3/8" 28 - 2723 28 - 2723 4930 2670 Intermediate 6343 9-5/8" 2226 - 8569 2226 - 7724 6870 4760 Perforation Depth: Measured depth: 9046 - 9580 feet True vertical depth:8105 -8509 feet Tubing (size, grade, measured and true vertical depth)7-5/8" 29.7# L-80 x 7" 26# N-8 23 - 7928 23 - 7202 7842,7993,8145 7131,7255,7379Packers and SSSV (type, measured and true vertical depth) 7"Baker S-3, 7"LTP, 7"Baker SB-2 Liner 1415 7" 8255 - 9670 7468 - 8575 8160 7020 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 361316000 0269,883 100 280,654 0 3578 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Dave Bjork David.Bjork@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:907- 564-4672 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ 5 SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8577 Sundry Number or N/A if C.O. Exempt: 320-456 7" A-1 Modified INJ SSSV 2199 2199 Junk Packer Printed and Electronic Fracture Stimulation Data 5 water wash Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028302 PBU WGI-03 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 7842 , 7993 , 8145 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.12.08 09:58:18 -09'00' Bo York By Samantha Carlisle at 12:30 pm, Dec 08, 2020 RBDMS HEW 12/9/2020 SFD 12/9/2020 SFD 12/9/2020 DSR-12/9/2020MGR04FEB2021 ACTIVITYDATE SUMMARY 11/17/2020 Tbg Wash (TUBING WASH/PICKLE) Pumped 10 bbls 60/40 meth, 50 bbls 140* DSL and 359 bbls 140* fresh water w/ F-103. Let soak for 2 hours. Pumped 218 bbls fresh water w/ F-103 and 15 bbls 60/40 meth down Tbg after soak. DSO notified to bring well back on njection. SV,WV=C SSV,MV=O IA,OA=OTG Daily Report of Well Operations PBU WGI-03 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:179-049 6.API Number:50-029-20385-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028302 Property Designation (Lease Number):10. n/a 8. PBU WGI-03 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown water wash Op Shutdown GAS GSTOR WAG 5 SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 9672 Effective Depth MD: L-80 / N-80 11. 11/7/2020 Commission Representative: 15. Suspended Contact Name: Dave Bjork Contact Email: David.Bjork@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 7" A-1 Modified INJ SSSV Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8577 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 7842,7993,8145 / 2199 7131,7255,7379 / 2199 Date: Liner 1415 7"8255 - 9670 7468 - 8575 8160 7020 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 28 - 2723 28 - 2723 14. Estimated Date for Commencing Operations: BOP Sketch 25 - 108 Structural 6870 Proposal Summary 13. Well Class after proposed work: 7" Baker S-3, 7" LTP, 7" Baker SB-2 9046 - 9580 8105 - 8509 7-5/8" 29.7# x 7" 26#23 - 7928 Production 7877 7160 none none 25 - 108 520 13-3/8" 9-5/8" Contact Phone:907 - 564-4672 Date: 10/23/2020 4760 83 153020"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2695 4930 Intermediate 6343 2226 - 8569 2226 - 7724 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:28 am, Oct 26, 2020 320-456 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.10.23 16:38:12 -08'00' Bo York X 10-404 DLB10/26/2020MGR26OCT2020 DSR-10/27/2020 eption Required? Comm 10/27/2020 dts 10/27/2020 JLC 10/27/2020 RBDMS HEW 11/9/2020 Well Work Prognosis Well Name:WGI-03 API Number:50-029-20385-00 Current Status:Gas Injector Leg: Estimated Start Date:Nov 7, 2020 Rig:N/A Reg. Approval Req’d?10-403 Date Reg. Approval Received: Regulatory Contact:Carrie Janowski Permit to Drill Number:207-0530 First Call Engineer:Dave Bjork Office: 907-564-4672 Cell: 907-440-0331 Second Call Engineer:Ryan Thompson Office: 907-564-5280 Cell: 907-301-1240 Gas Injection Rate: 252,725 Mscf/Day Injection Pressure: 3,528 psi Reservoir Pressure (Estimate): 3500 psi Program Objective(s): WGI-03 is a gas cap injection well that has demonstrated a decrease in injectivity. The well has not been water washed since perfs were added in 2014. Water washes are designed to dissolve salts and asphaltenes in the tubing and formation. The objective is to perform a tubing water wash to increase injectivity and perform a general maintenance on Gas Injection Wells. Proposed Program: Pump diesel followed by Fresh Water and Surfactant as per attached pumping template. Well Work Prognosis Well Work Prognosis MEMORANDUM State of Alaska Tubing Alaska Oil and Gas Conservation Commission Initial 15 Min 30 Min 45 Min 60 Min 3565 3564 3562 - DATE: Wednesday, June 12, 2019 TO: Jim Regg P.I. Supervisor �C�l'C �(1 3 `l SUBJECT: McEXPLORATIal N (ALASKA) 8P EXPLORATION (ALASKA) INC. 2500 2453 2425 1 2 �BL Returned: 2.4 WGI-03 FROM: Guy Cook PRUDHOE BAY UNIT WGI-03 Petroleum Inspector P b Src: Inspector -- Reviewed By: calibrated gauges. P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT WGI-03 API Well Number 50-029-20385-00-00 Inspector Name: Guy Cook Permit Number: 179-049-0 Inspection Date: 6/712019 - Insp Num: mitGDC190608161353 Rel Insp Num: Packer Depth Tubing Pretest 3565BBLPumped Initial 15 Min 30 Min 45 Min 60 Min 3565 3564 3562 - Well WGI 03 Type Inj�G -ITVD 3� --.— PTD 1790490 "`TypeTest SPT'!!Testpsi 1783 143 2500 2453 2425 1 2 �BL Returned: 2.4 EIA 7 5 6 6 j �__ Intervale 4YRTST �P/F J P b -- Notes: Job was completed with a triplex, bleed trailer and calibrated gauges. Wednesday, June 12, 2019 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TOJim Regg k� 2 DATE: Wednesday,June 17,2015 P.I.Supervisor 'l�(C( 7( I i5 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC WGI-03 FROM: Jeff Jones PRUDHOE BAY UNIT WGI-03 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 1:6z- NON-CONFIDENTIAL NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT WGI-03 API Well Number 50-029-20385-00-00 Inspector Name: Jeff Jones Permit Number: 179-049-0 Inspection Date: 6/13/2015 Insp Num: mitJJ150616074429 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 WG1-03 • Type Inj G TVD 7133 Tubing 3576 • 1 3591 ' 3627' 3572 - 3575 - PTD 1790490 Type Test SPT Test psi 1783IA 345 2502 2542 2511 2507 14YRTSTP � 9 8 9 9 9 Interval �P/F L- OA 1 Notes: 1 well inspected,no exceptions noted SCANNED: ) i ;/01,-, Wednesday,June 17,2015 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED OCT 272014 1. Operations Abandon L Repair Well L Plug Perforations L Perforate ✓ Other Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown[] Stimulate - Other ❑ Re-enter Suspended Well[--] 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development❑✓ Stratigraphic❑ Exploratory ❑ Service ❑ 179-049-0 3. Address: P.O. Box 196612 6. API Number: Anchorage, AK 99519-6612 50-029-20385-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028302 PBU WGI-03 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 9672 feet Plugs measured None feet true vertical 8576.68 feet Junk measured None feet Effective Depth measured 9627 feet Packer measured See Attachment feet true vertical 8543.34 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 83 20" 94# H-40 25-108 35-110 1530 520 Surface 2695 13-3/8" 72# N-80 28-2723 8352.11 - 8352.94 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner 1415 7 29# N-80 8255-9670 8199.15 - 8199.99 8160 7020 Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer 7 A-1 Modified INJ SSSV 2199 2198.93 SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED NOV 0 4 2014 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 401 24765 1727 0 232 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil E Gas WDSPLL GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCE:] 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita.Summerhays(p7bp.com Printed Name Nita Summerhays Title Petrotechnical Data Engineer Signat Phone 564-4035 Date 10/27/2014 RBC M8 OCT 2 8 Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028302 FLUIDS PUMPED BBLS —WELL S/I UPON ARRIVAL— pe ora ing TAGGED A-1 INJECTION VALVE @ 2175' MD. PULLED A-1 INJECTION VALVE{bws-242}FROM SVLN. DRIFT TUBING WITH 11' OF 3.375" DUMMY GUN AND SAMPLE BAILER. TAG TD @ 9507' SLM. BAILER RETURNED EMPTY.(bottom pert @ 9580' md/ no correction) 9/27/2014 ""'`WELL LEFT SHUT IN. DSO WALK THROUGH UPON DEPARTURE"* """ WELL SHUT IN ON ARRIVAL """ (ELINE: PERF) INITIAL T/I/O = 2400 / 200 / 0 RUN 1: RIH WITH HEAD (11X3) / ERS / GR / CCL / 2-7/8" POWERJET OMEGA GUN. LOADED 31' WITH 1' SPACER IN THE MIDDLE. 6 SPF, 60 DEG PHASE SHOOTING INTERVAL = 9310'- 9341'. CCL TO TOP SHOT = 3.5' CCL STOP DEPTH = 9306.5' CORRELATED TO SLB BOREHOLE COMPENSATED LOG DATED 20 -SEP -1979. RUN 2: RIH WITH HEAD (11X3) / ERS / GR / CCL / 2-7/8" POWERJET OMEGA GUN. LOADED 31' WITH 1' SPACER IN THE MIDDLE. 6 SPF, 60 DEG PHASE SHOOTING INTERVAL = 9281'- 9312'. CCL TO TOP SHOT = 3.5' CCL STOP DEPTH = 9277.5' 10/2/2014 CORRELATED TO SLB BOREHOLE COMPENSATED LOG DATED 20 -SEP -1979. =2612/205/0 Temp= ssis E-LinePumped s o meth, 543 bbls of 2% KCL down tubing to kill well "" JOB CONTINUED ON WSR 10-3- 10/2/2014 14 "" —JOB CONI INUED FROM 2 -OCT -2014* RUN 3: RIH WITH HEAD (11X3) / ERS / GR / CCL / 2-7/8" POWERJET OMEGA GUN. CCL STOP DEPTH = 92177, CCL TO TOP SHOT = 4.3', PERFORATION INTERVAL = 9222'- 9252'. POOH RUN 4: RIH WITH HEAD (11X3) / ERS / GR / CCL / 2-7/8" POWERJET OMEGA GUN. CCL TO TOP SHOT = 4.3', CCL STOP DEPTH = 91607, PERFORATION INTERVAL = 9165'- 9195'. POOH RD. WELL SHUT IN UPON DEPARTURE. DSO NOTIFIED. FINAL T/I/O = 680/150/0 PSI 10/3/2014 """JOB COMPLETE""" **JOB CONTINUED FROM WSR 10-2-14— T/1/0=7601190/0 E-LINEASSIST( L&K) Pumped 59 bbls 2% KCL, 175bbls 1% KCL down tubing to kill well Pumped 114 bbls 60/40 meth down tubing for Freeze protect E- Line in control of well upon 10/3/2014 departure IA/OA=OTG FWHP's = 761/179/0 """WELL S/I ON ARRIVAL""" (Perforating) SET 6.00" CA. A-1 ISSSV (s/n = BWS-137, 3.50" bean) AT 2,155' SLM / 2,175' MD. PERFORMED SUCCESSFUL DRAW DOWN TEST (Bled from 1450 to 950 psi). 10/4/2014 WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS""" FLUIDS PUMPED BBLS Daily Report of Well Operations ADL0028302 3 DIESEL 10 METH 602 2% KCL 114 60/40 METH 175 1% KCL 904 TOTAL AB ABANDONED Perforation Attachment APF ADD PERF MIS BPP BRIDGE PLUG PULLED ADL0028302 BPS BRIDGE PLUG SET OH SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base WGI-03 3/2/1987 APF 9046 9059 8105.16 8115.27 WGI-03 8/18/1980 PER 9059 9079 8115.27 8130.8 WGI-03 3/2/1987 APF 9079 9099 8130.8 8146.3 WGI-03 8/18/1980 PER 9099 9119 8146.3 8161.77 WGI-03 8/18/1980 PER 9137 9147 8175.66 8183.36 WGI-03 3/2/1987 APF 9147 9165 8183.36 8197.2 WGI-03 10/3/2014 APF 9165 9195 8197.2 8220.19 WGI-03 3/2/1987 APF 9195 9219 8220.19 8238.51 WGI-03 10/3/2014 PER 9219 9222 8238.51 8240.8 WGI-03 10/3/2014 APF 9222 9252 8240.8 8263.57 WGI-03 10/3/2014 PER 9252 9259 8263.57 8268.87 WGI-03 10/2/2014 APF 9281 9301 8285.47 8300.5 WGI-03 10/2/2014 APF 9301 9310 8300.5 8307.25 WGI-03 10/2/2014 APF 9310 9312 8307.25 8308.75 WGI-03 10/2/2014 APF 9312 9321 8308.75 8315.5 WGI-03 10/2/2014 APF 9321 9341 8315.5 8330.49 WGI-03 10/2/2014 PER 9341 9352 8330.49 8338.73 WGI-03 8/18/1980 PER 9365 9375 8348.46 8355.95 WGI-03 3/2/1987 APF 9375 9387 8355.95 8364.93 WGI-03 8/18/1980 PER 9413 9433 8384.38 8399.31 WGI-03 3/2/1987 APF 9433 9451 8399.31 8412.73 WGI-03 8/18/1980 PER 9451 9471 8412.73 8427.62 WGI-03 8/18/1980 PER 9485 9495 8438.03 8445.46 WGI-03 3/2/1987 APF 9495 9511 8445.46 8457.33 WGI-03 8/18/1980 PER 9511 9521 8457.33 8464.75 WGI-03 3/2/1987 APF 9534 9549 8474.4 8485.52 WGI-03 8/18/1980 PER 9549 9559 8485.52 8492.94 WGI-03 8/18/1980 PER 9570 9580 8501.1 8508.51 AB ABANDONED MIR APF ADD PERF MIS BPP BRIDGE PLUG PULLED MILK BPS BRIDGE PLUG SET OH FCO OUT STC FIL FILL STO SQF SQUEEZE FAILED SPS SQZ SQUEEZE SL PER PERF SPR RPF REPERF REMOVED MECHANICAL ISOLATED LEAK OPEN HOLE STRADDLE PACK, CLOSED STRADDLE PACK, OPEN SET LINER SAND PLUG REMOVED Casing / Tubing Attachment ADL0028302 Casing Length Size MD TVD Burst Collapse CONDUCTORI Length 20" 94# H-40 25 - 108 35 - 110 1530 520 INTERMEDIATE 9-5/8" 47# L-80 26 - 2238 8063.48 - 8508.86 6870 4760 INTERMEDIATE 9-5/8" 47# SOO-95 2226 - 2306 8365.35 - 9114.64 8150 5080 INTERMEDIATE 9-5/8" 47# N-80 2306 - 8569 2087.91 - 2088.91 6870 4760 LINER 7" 29# N-80 8255 - 9670 8199.15 - 8199.99 8160 7020 NIPPLE 7" R Nipple 7811 - 7813 8236.98 - 8237.82 NIPPLE 7" RN Nipple 7874 - 7875 8323.89 - 8324.72 SURFACE 13-3/8" 72# N-80 28 - 2723 8352.11 - 8352.94 4930 2670 TUBING 7" 26# L-80 23 - 25 8370.3 - 8371.13 7240 5410 TUBING 7-5/8" 29.7# L-80 25 - 2171 33 - 8485.37 6890 4790 TUBING 7" 26# L-80 2171 - 2174 34 - 2692.9 7240 5410 TUBING 7-5/8" 29.7# L-80 2174 - 7755 35 - 8379.38 6890 4790 TUBING 7" 26# L-80 7755 7928 7240 5410 Packers and SSV's Attachment ADL0028302 SW Name Type MD TVD Depscription WGI-03 SSSV 2199 2168.93 7" A-1 Modified INJ SSSV WGI-03 PACKER 7842 7100.95 7" Baker S-3 Packer WGI-03 PACKER 7993 7224.84 T' Liner Top Packer WGI-03 PACKER 8145 7348.6 7" Baker SB-2 Packer TREE = - 6-3/8" CAN WELLHEAD = CNV ACTUATOR= BAKER KB. ELEV = 30' BF. ELEV = _ KOP = 3150' Max Angle = t2'@ 9500'' Datum MD = 10014 Datum TVD = 8800 SS' 7-5/8" TBG, 29.7#, L-80 VAM TOP HC, 2174' 0459 bpf, D = 6 875" 7" TBG, 26#, L-80 TCI, .0383 bpf, D = 6.276" 2177 9-5/8" CSG, 47#, L-80 TCI TIEBACK, 2223' D = 8.681" 13-3/8" CSG, 72#, N-80, D = 12.347" 2723' 7-5/8" TBG, 29.7#, L-80 VAM TOP HC, 7759' QAAQ - MInImuM ID- . 0' BAKER SHEAROUT SUB WELL WGI-03 DOSURF RJLLLYYYCM C£ EwICCLASSUARESA �RC0AtS INTERVAL Opn/Sqz 2174' SOZ 2175' 7" CAMCO DB -6 NP, D = 6.000" 19046-9119 O 03/02/87 9 5!8" FES E5 CEMBITH� D = 8.861" 17- TBG, 26#, L-80 TC4 .0383 bpf, D = 6.276" 7931' MD 7-5/8" TBG STUB {02/19106) 7959',,,,,,....._ 7-5/8" TBG, 29.7# UT -95 STL, 7992' .0459 bpf, D = 6.875" 7" TBG, 26#, L-80 NSCC, .0383 bpf, D = 6.276" ( 8017' T TBG, 29#, N-80 AMB 8RD, 8161' .0371 bpf, D = 6.184" TOP OF 7" LNR 8255' 9-5/8" CSG, 47#, N-80, D = 8.681" 8569' PERFORATION SLMMRY REF LOG: BRCS ON 09/20f79 ANGLE AT TOP PERF. 39° @ 9045' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz SHOT SOZ 3-3/8" 4 19046-9119 O 03/02/87 RWO 3-3/8" 4 9137-9259 O 03/02/87 PJC 2-7/8" 6 9165-9195 O 10/03/14 2-7/8" 6 9222-9262 O 10/03/14 2-7/8" 6 9281-9312 O 10102114 3-3/8" 4 9281-9352 O 03/02/87 2-7/8" 6 9310-9341 O 10/12/14 3-3/8' 4 9365-9387 O 03/02/87 3-3/8" 4 9413-9471 O 03/02/87 3-3/8" 4 9485-9521 O 03/02/87 3-3/8" 4 9534-9559 O 03/02/87 3-3/8" 4 9570-9580 O 08/18/80 7" LNR, 29#, N-80, .0371 bpf, D = 6.184" 9670' 7759' 7814' 7- FES R NP, D =_5_._%_37- 7"W 5.963" 7845' —j 9-5/8" X 7" BKR S-3 PKR, D = 6.040" 78� 7" HM RN W. D = 5,770- 7931' 1--) 7" WLEG, D = 6.276- 7992' — j 7-5/8" X 7" XO, D = 6.276" 7993' 9-5/8" X 7" BKR KBK22 ANCHOR 8 SA BL PKR 6.00" 8008' 7" FES RN NP, D = 5.500" 801 T T WLEG, D = 6.27 S� IAW 1 9-5/8" X 7" BKR SB -2 PKR 8160' 7" BKR SHEAROUT SUB, D = 4.843" 8161' T VVLEG, D = 6.276" 8146' ELMD TT LOGGED 09!26(79 SCE " DATE REV BY C00JENTS DATE REV BY COM AIMS 09/26(79 PKR 14V ORIGINAL COM PLETION 10/18/14 Rfn PJC APDPERFS (10/02-03/14) 11/16/97 Dib RWO 03119!06 NOES RWO 05112111 MES RWO 05/27/11 PJC DRLG DRAFT CONS 06/26/11 RCT/ PJC SLUGGITS/ MILL PRN (5/30/11) FRUDHOE BAY LINT WELL. WGF03 PERMf No: '1790490 AR No: 50-029-20385-00 SEC 11, T1 IN, R14E, 494' FN_ 8 1160' FEL BP Exploration (Alaska) ~ge Project Well History File' Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: , NOTES: ~ : Logs of various kinds BY: BEVERLY BREN VINCENT SHERYL~vlAR~,LOWELi. Project Proofing .. BY: ~BE~ BREN VINCENT SHERYL MARIA LOWELl. \ / Other III IIIIIIIIIII II III Scanning Preparation ZIL x 30 = /c,0-O + /~"~ = TOTALPAGES /)Z ~ Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: P~-GL~OUNT MATCHES NUMBER IN SCANNING PREPARATION: X YES NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO (SC~NING ~ COMPLE~ AT THIS ~ UN~ 8~C~ A~ENT~N IS REQUIRED ON AN ~DNIDUAL PAGE BAS~ DUE TO ~. ~YSC~E OR C~OR ~S) I ReScanned (individual page [special attention] scanning completed) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl. DATE: Is~ General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3 NOTScanned.w~:l ra ‘4, 1MI V - C LJ ' STATE OF ALASKA AL P 2012 A OIL AND GAS CONSERVATION COMMN REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Water Wash Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Exploratory ❑ . 179 -049 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service El 6. API Number: Anchorage, AK 99519 -6612 • 50- 029 - 20385 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028302 PBU YOGI -03 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 9672 feet Plugs measured None feet true vertical 8576.68 feet Junk measured None feet Effective Depth measured 9627 feet Packer measured See Attachment feet true vertical 8543.34 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 78 20" 94# H-40 25 - 103 25 - 103 1530 520 Surface 2699 13 -3/8" 72# N -80 24 - 2723 24 - 2722.93 4930 2670 Intermediate None None None None None None Production 8546 9 -5/8" 47# N -80 23 - 8569 23 - 7724.04 6870 4760 Liner 1415 7" 29# N -80 8255 - 9670 7468.38 - 8575.2 8160 7020 Perforation depth Measured depth See Attachment feet 3 True Vertical depth See Attachment feet SCANNED MAR 0 4 5!! �� b Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer 7" A -1 Modified INJ SSSV 2199 2198.93 SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 130674 0 0 3364 Subsequent to operation: 0 150511 0 0 3391 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service El Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ i NA. Gas 151 WDSPI4J GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC❑ 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: 312 -120 Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature Ac4A,v. c Phone 564 -4424 Date 9/6/2012 ���?AliS SEP 1 0 �?1 a J tiv ! , r9/2.- Form 10 -404 Revised 10/2010 Submit Original Only • • Packers and SSV's Attachment ADL0028302 SW Name Type MD TVD Depscription WGI -03 SSSV 2199 2168.93 7" A -1 Modified INJ SSSV WGI -03 PACKER 7993 7224.84 7" Baker SABL -3 Packer WGI -03 PACKER 8145 7348.6 7" Baker SB -2 Packer Perforation Attachment ADL0028302 SW Name Operation Date Peri Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base WGI -03 5/30/2011 BPP 9046 9059 8105.16 8115.27 WGI -03 5/30/2011 BPP 9059 9079 8115.27 8130.8 WGI -03 5/30/2011 BPP 9079 9099 8130.8 8146.3 WGI -03 5/30/2011 BPP 9099 9119 8146.3 8161.77 WGI -03 5/30/2011 BPP 9137 9147 8175.66 8183.36 WGI -03 5/30/2011 BPP 9147 9165 8183.36 8197.2 WGI -03 5/30/2011 BPP 9165 9195 8197.2 8220.19 • WGI -03 5/30/2011 BPP 9195 9219 8220.19 8238.51 WGI -03 5/30/2011 BPP 9219 9259 8238.51 8268.87 WGI -03 5/30/2011 BPP 9281 9301 8285.47 8300.5 WGI -03 5/30/2011 BPP 9301 9321 8300.5 8315.5 WGI -03 5/30/2011 BPP 9321 9352 8315.5 8338.73 WGI -03 5/30/2011 BPP 9365 9375 8348.46 8355.95 WGI -03 5/30/2011 BPP 9375 9387 8355.95 8364.93 WGI -03 5/30/2011 BPP 9413 9433 8384.38 8399.31 WGI -03 5/30/2011 BPP 9433 9451 8399.31 8412.73 WGI -03 5/30/2011 BPP 9451 9471 8412.73 8427.62 WGI -03 5/30/2011 BPP 9485 9495 8438.03 8445.46 WGI -03 5/30/2011 BPP 9495 9511 8445.46 8457.33 WGI -03 5/30/2011 BPP 9511 9521 8457.33 8464.75 WGI -03 5/30/2011 BPP 9534 9549 8474.4 8485.52 • WGI -03 5/30/2011 BPP 9549 9559 8485.52 8492.94 WGI -03 5/30/2011 BPP 9570 9580 8501.1 8508.51 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET 1 SQZ SQUEEZE SL SLOTTED LINER i PER PERF SPR SAND PLUG REMOVED RPF REPERF • • i II Casing / Tubing Attachment ADL0028302 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20" 94# H-40 25 - 103 25 - 103 1530 520 LINER 1415 7" 29# N -80 8255 - 9670 7468.38 - 8575.2 8160 7020 PRODUCTION 8546 9 -5/8" 47# N -80 23 - 8569 23 - 7724.04 6870 4760 SURFACE 2699 13 -3/8" 72# N -80 24 - 2723 24 - 2722.93 4930 2670 TUBING 2 7" 26# L -80 22 - 24 22 - 24 7240 5410 TUBING 2205 7 -5/8" 29.7# NT -95 24 - 2229 24 - 2228.93 8180 5120 TUBING 6 7" 26# L -80 2229 - 2235 2228.93 - 2234.93 7240 5410 • TUBING 5757 7 -5/8" 29.7# NT -95 2235 - 7992 2234.93 - 7254.03 8180 5120 TUBING 25 7" 26# L -80 7992 - 8017 7254.03 - 7274.43 7240 5410 TUBING 16 7" 29# L -80 8145 - 8161 7378.6 - 7391.64 8160 7020 111 Daily Report of Well Operations ADL0028302 SUMMARY 171/0= 260b/100/20 temp =Sl a was plc e ° umpe• m o •g' ® • • s me + ® • "• • iese 7/15/2012 xylene 50/50 mix ** *wsr continued to 07- 16 -12 * ** ** *wsr continued from 07- 15- 12 * * *T /I /0= 2600/100/20 temp =Sl TBG wash/ pickle Pumped an additional 741 bbls 1% KCL with .02% F -103 surfactant for a total of 746 bbls, and a 10 bbls meth cap down tbg. Final WHP's VAC /40/20 SV, SSV= closed WV,MV,IA,OA= closed DSO 7/16/2012 notified to POI • s . TREE = 6 -3/8" CM! SA NOTES: WELL REQUIRES A SSSV *** O A 15 WELLHEAD = CIW W �' 1-03 FULLY CMT'D TO SURFACE w /CLASS G LARC *** ACTUATOR= BAKER KB. ELEV = 30' �1� 11.� BF. ELEV = �'� , 28' H7" X 7 -5/8" XO, ID = 6.276" I KOP = 3150' . • ∎•∎ ■. 4 • ■ 2174' 1-17-5/8" X 7" XO, ID = 6.276° I Max Angle = 42° @ 9500' 14 1 IV Datum MD = 10014 ��� o • I 2175' H7" CAMCO DB -6 NIP, ID = 6.000" I Datum TVD= 8800 SS 4* �� ∎,4 . 2177' H 7" X 7 -518" XO, ID = 6.276" I ■ 7 -5/8" TBG, 29.7 #, L -80 VAM TOP HC, 2174' ,,• A 2208' I I 9 -5/8" HES ES CEMENTER, ID = 8.861" I .0459 bpf, ID = 6.875" IT TBG, 26 #, L -80 TCII, .0383 bpf, ID = 6.276" Fl 2177' 9 -5/8" CSG, 47 #, L -80 TCII TIEBACK, -1 2223' I 7759' H 7-5/8" X 7" XO, ID = 6.276" I ID = 8.681" 13-3/8" CSG, 72 #, N-80, ID = 12.347" H 2723' I r 7814' J-17" HES R NIP, ID = 5.963" I 7 -5/8" TBG, 29.7 #, L -80 VAM TOP HC, -1 7759' .0459 bpf, ID = 6.875" S Z I 7845' IH 9 -5/8" X 7" BKR S -3 PKR, ID = 6.040" I Minimum ID = 4.843" Q@ 8160' 1 1 ( 7877' I -17" HES RN NIP, ID = 5.770" I BAKER SHEAROUT SUB _ 7931' I- T' WLEG, ID = 6.276" ( 17" TBG, 26 #, L -80 TCII, .0383 bpf, ID = 6.276" H 7931' I 17-5/8" TBG STUB (02/19/06) I-J 7959' MD �1 -� J ____________---1 7992' J� 7-5/8" X 7" XO, ID = 6.276" I 7 -5/8" TBG, 29.7# NT -95 STL, 7992' .0459 bpf, ID = 6.875" 7993' I- 9 -5/8" X 7" BKR KBH-22 ANCHOR X & SABL PKR, 6.00" ' I 8008' H 7" HES RN NIP, ID = 5.500" I 17" TBG, 26 #, L -80 NSCC, .0383 bpf, ID = 6.276" H 8017' ( / \- I 8017' I -17" WLEG, ID = 6.276" I Z 8145' -1 9 -5/8" X 7" BKR SB -2 PKR I 7" TBG, 29 #, N -80 AMB 8RD, -I 8161' .0371 bpf, ID = 6.184" \ I 8160' I-17" BKR SHEAROUT SUB, ID = 4.843" I 'TOP OF 7" LNR I 8255' -------- 8161' J-17" TUBING TAIL, ID = 6.276" 19 -5/8" CSG, 47 #, N-80, ID = 8.681" H 8569' I 8146' H ELMD TT LOGGED 09/26/79 I PERFORATION SUMMARY • REF LOG: BHCS ON 09/20/79 ANGLE AT TOP PERF: 39° @ 9045' ' Note: Refer to Production DB for historical pert data I SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 4 9046 -9119 0 03/02/87 I 3 -3/8" 4 9137 -9259 0 03/02/87 3 -3/8" 4 9281 -9352 0 03/02/87 3 -3/8" 4 9365 -9387 0 03/02/87 I 3 -3/8" 4 9413 -9471 0 03/02/87 3 -3/8" 4 9485 -9521 0 03/02/87 ' 3 -3/8" 4 9534 -9559 0 03/02/87 I 3 -3/8" 4 9570 -9580 0 08/18/80 I I PBTD H 962T I 7" LNR, 29 #, N -80, .0371 bpf, ID = 6.184" H 9670' VA • • DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/26/79 PKR 141 ORIGINAL COMPLETION WELL: WGI-03 11/16/97 016 RWO PERMIT No: 1790490 03/19/06 N4ES RWO API No: 50- 029- 20385 -00 05/12/11 N7ES RWO SEC 11, T11 N, R14E, 494' FNL & 1160' FEL 05/27/11 PJC DRLG DRAFT CORRECTIONS 06/26/11 RCT/ PJC BAIL SLUGGFTS/ PULL PRN (5/30/11) BP Exploration (Alaska) • • , i M L i 7 SEAN PARNELL, GOVERNOR H ' ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION C OMmISSIOIQ ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Bob Chivvis Petroleum Engineer 0 'I ' 'II Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU WGI -03 Sundry Number: 312 -120 Dear Mr. Chivvis: <,> Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair r� DATED thi day of April, 2012. Encl. 1 STATE OF ALASKA ' h 1VD ALA OIL AND GAS CONSERVATION COMMON ` APPLICATION FOR SUNDRY APPROVALS' "' MAR ' zi . 2 0 1 2 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program Q I Suspend ❑ Plug Perforations ❑ Perforate Pull Tubing ❑ timerxte'fi T1 i Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate Alter Casing ❑ -'' "11 i a ` I Other: Water. Wash cit wr I 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: J BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 179 -0490 ' 3. Address: P.O. Box 196612 Stratigraphic ❑ Service isi , 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20385 -00 -00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No PBU WGI -03 0 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 028302 ' PRUDHOE BAY Field / PRUDHOE BAY Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9672 • 8577 • 9627 8543 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 94# H -40 25 103 25 103 1530 520 Surface 2699' 13 -3/8" 72# N -80 24 2723 24 3723 4930 2670 Production 8546' 9 -5/8" 47# N -80 23 8569 23 7724 6870 4760 Liner 1415' 7 "29# N -80 8255 9670 7468 8575 8160 7020 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 7" 26# L -80 22 24 - - 7 -5/8" 29.7# NT -95 24 2229 - - 7" 26# L -80 2229 2235 - - 7 -5 /><" 29.7# NT -95 2235 7992 Packers and SSSV Type: 7" CA A -1 Ini SSSV Packers and SSSV MD and TVD (ft): 2175 2175 7" Baker S-3 Packer 7845 7133 7" Baker SABL -3 Packer 7993 7255 7" Baker SB -2 Packer 8145 7379 12. Attachments: Description Summary of Proposal IN 13. Well Class after proposed work: . Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service El 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/12/2012 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ o WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bob Chivvis Printed Name Bob Chivvis Title PE Signature A Phone Date 564 -5412 3/29/2012 Prepared by Nita Summerhays 564 -4035 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: % Z- 12.0 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: `e -4/641 Pta...41 APP ROVED BY xv Approved by: COMMISSIONER THE COMMISSION Date: ¢.3 ..-1 R DMS APR 4 _ . . 6 `" . /.3 /iL. 0 R 0 R1 G I N Form 10 -403 Revised 1/2010 , 1__ �/ Submit in Duplicate 'fir WGI -03 179 -049 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base WGI -03 8/18/80 PER 9,059. 9,079. 8,115.27 8,130.8 WGI -03 8/18/80 PER 9,570. 9,580. 8,501.1 8,508.51 WGI -03 8/18/80 PER 9,549. 9,559. 8,485.52 8,492.94 WGI -03 8/18/80 PER 9,511. 9,521. 8,457.33 8,464.75 WGI -03 8/18/80 PER 9,485. 9,495. 8,438.03 8,445.46 WGI -03 8/18/80 PER 9,451. 9,471. 8,412.73 8,427.62 WGI -03 8/18/80 PER 9,365. 9,375. 8,348.46 8,355.95 WGI -03 8/18/80 PER 9,413. 9,433. 8,384.38 8,399.31 WGI -03 8/18/80 PER 9,281. 9,301. 8,285.47 8,300.5 WGI -03 8/18/80 PER 9,219. 9,259. 8,238.51 8,268.87 III WGI -03 8/18/80 PER 9,165. 9,195. 8,197.2 8,220.19 WGI -03 8/18/80 PER 9,137. 9,147. 8,175.66 8,183.36 WGI -03 8/18/80 PER 9,099. 9,119. 8,146.3 8,161.77 WGI -03 8/18/80 PER 9,321. 9,352. 8,315.5 8,338.73 WGI -03 3/2/87 APF 9,433. 9,451. 8,399.31 8,412.73 WGI -03 3/2/87 APF 9,534. 9,549. 8,474.4 8,485.52 WGI -03 3/2/87 APF 9,495. 9,511. 8,445.46 8,457.33 3/2/87 APF 9 375. 9 WGI -03 3/2/ 9,387. 8,355.95 8,364.93 > WGI -03 3/2/87 APF 9,079. 9,099. 8,130.8 8,146.3 WGI -03 3/2/87 APF 9,195. 9,219. 8,220.19 8,238.51 WGI -03 3/2/87 APF 9,147. 9,165. 8,183.36 8,197.2 WGI -03 3/2/87 APF 9,301. 9,321. 8,300.5 8,315.5 WGI -03 3/2/87 APF 9,046. 9,059. 8,105.16 8,115.27 WGI -03 1/14/06 SPS 8,008. 9,580. 7,267.09 8,508.51 WGI -03 1/15/06 SPS 7,970. 9,046. 7,236.05 8,105.16 WGI -03 1/6/08 BPS 7,911. 9,046. 7,187.74 8,105.16 • WGI -03 2/14/08 BPP 7,911. 9,046. 7,187.74 8,105.16 WGI -03 4/3/11 BPS 8,008. 9,046. 7,267.09 8,105.16 WGI -03 4/4/11 SPS 7,967. 8,008. 7,233.6 7,267.09 WGI -03 5/29/11 SPR 7,967. 8,008. 7,233.6 7,267.09 WGI -03 5/30/11 BPP 8,008. 9,046. 7,267.09 8,105.16 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED 1 1 WGI -03 179 -049 PERF ATTACHMENT FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • Version 1.1 04/28/2010 Fullbore Pumping Design Template Well Name WGI -03 Job Scope Select Job Scope • H2S (ppm /date) WBL Cat IOR Cost 2500 Max Pumping Pressure (psi) Well Type GI AFE APBinjec Main Fluid Type Date 3/27/2012 IOR 100 700 Main Fluid Volume (bbls) Engineer Bob Chivvis Phone 564 -5412 Methanol (60/40) Freeze Protect Type 10 Freeze Protect Volume (bbls) Job Objective • If Applicable Recent Tbg Fluid Level (ft) Improve injectivity by dissolving salts and possibly asphaltenes in the If Applicable Recent IA Fluid Level (ft) tubing and formation. Diesel /Xylene washes have been used If Applicable Recent OA Fluid Level (ft) successfully in the past on the NGI/WGI /AGI gas injec s-to..tmprove If Applicable Expected Tbg Fill Up Volume (bbls) injectivity. ' If Applicable Expected IA Fill Up Volume (bbls) If Applicable Expected OA Fill Up Volume (bbls) 428 Wellbore Volume to Perfs (bbls) Fullbore Pumping Schedule 3300 Anticipated Bottom Hole Pressure (psi) Pump Volume Rate Max Select I Tubing /Casing within Pressure Limits? Stage Fluid Type Into (bbls) (bpm) Pressure Size Burst /Collapse 80% Burst /Collapse Tubing Burst (psi) 7.625 6890.00 5512 Pre -Flush 1 1 Methanol (60/40) I I Tbg 1 101 1 5 2500 Tubing Collapse (psi) size See helpful tips tab Casing Burst (psi) size See helpful tips tab 1 Solvent 1 1 Select Fluid Type 1 1 Tbg 1 l 1001 1 5 1 1 25001 0 Casing Collapse (psi) size See helpful tips tab Load 1 1 Select Fluid Type 11 Tbg 7001 1 5 2500 Select Input Depth Integrity Issues? No unknown I Freeze Protect 1 1 Methanol (60/40) 1 I Tbg 1 1 101 1 5 1 1 25001 No Input Depth I Select Stage 1 I Select Fluid Type 1 I Select 1 1 1 1 1 1 No 1 Tubing Caliper? Burst/Collapse ratings may need to be derated based on tubing condition Select Production Packer within Pressure Limits? Detailed Pumping Procedure Rated Packer dp Max Anticipated dp at Packer 11 1 10 bbls 60/40 meoh spear II 2 100 bbls 50/50 diesel/xylene Not Necessary I Hold Pressure on Other Strings? 3 700 bbls of fresh water with 0.02% F-103 surfactant Tubing (psi) 4 10 bbls 60/40 meoh IA (psi) 5 RDMO. Return well to gas injection OA (psi) 6 • ~ TREE _ 6-3/8" CNV • SAFETES: WELL REQUIRES A SSSV *** O A IS WELLHEAD = • cm/ WGI-03 FULLY CMT'D TO SURFACE w /CLASS G LARC *** ACTUATOR = BAKER KB. ELEV = 30' ' t 4,0 BF. ELEV = ••,,4 . ���� 28' I--17" X 7 -5/8" XO, ID = 6.276" I KOP = 3150' Off. ∎•1 ■ Max Angle = 42° @ 9500' j � 2174' H 7 -5/8" X 7" XO, ID = 6.276" I ■ Datum MD= 10014 � I ���« � �� 0 2175' 1 CAMCO DB -6 NIP, ID = 6.000" I Datum TV D = 8800 SS �.� ��' 2177' H7" X 7 -5/8" XO, ID = 6.276" I 7 -5/8" TBG, 29.7 #, L -80 VAM TOP HC, - 2174' ��i� * • A 2208' H9-5/8" HES ES CEMENTER, ID = 8.861" I .0459 bpf, ID = 6.875" 7" TBG, 26 #, L -80 TCII, .0383 bpf, ID = 6.276" I - I 2177' 9 -5/8" CSG, 47 #, L -80 TCII TIEBACK, - 2223' I 7759' H7-5/8" X 7" XO, ID = 6.276" I ID = 8.681" 113 -3/8" CSG, 72 #, N -80, ID = 12.347" H 2723' 1 r 7814' I HES R NIP, ID = 5.963" I 7 -5/8" TBG, 29.7 #, L -80 VAM TOP HC, - 7759' .0459 bpf, ID = 6.875" g Z 7845' I- I9 -5/8" X 7" BKR S -3 PKR, ID = 6.040" I Minimum ID = 4.843" @ 8160' 1 1 ( 787T H7" HES RN NIP, ID = 5.770" I BAKER SHEAROUT SUB _ 7931' 1 WLEG, ID = 6.276" I 17" TBG, 26 #, L -80 TCII, .0383 bpf, ID = 6.276" I-1 7931' I I7 -518" TBG STUB (02/19/06) H 7959' MD 1--- I 7992' I - I7 - 5/8" X 7" XO, ID = 6.276" I 7 -5/8" TBG, 29.7# NT -95 STL, - 7992' 1----t 1 .0459 bpf, ID = 6.875" 7993' I 9 -5/8" X 7" BKR KBH -22 ANCHOR _ & SABL PKR, 6.00" 1 1 I 8008' I -7" HES RN NIP, ID = 5.500" I 17" TBG, 26 #, L-80 NSCC, .0383 bpf, ID = 6.276" I-I 8017' I / I 8017' I-17" WLEG, ID = 6.276" I S Z "--- -- 8145' -I-I 9 -5/8" X 7" BKR SB -2 PKR I 7" TBG, 29 #, N -80 AMB 8RD, --I 8161' .0371 bpf, ID= 6.184" / \ 8160' 1 BKR SHEAROUT SUB, ID = 4.843" I • I (TOP OF 7" LNR I-1 8255' 8161' H7" TUBING TAIL, ID = 6.276" I I 9-5/8" CSG, 47 #, N -80, ID = 8.681" H 8569' I 8146' I-1 ELMD TT LOGGED 09/26/79 I PERFORATION SUMMARY ' REF LOG: BHCS ON 09/20/79 ANGLE AT TOP PERF: 39° @ 9045' I Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 4 9046 -9119 0 03/02/87 ' 3 -3/8" 4 9137 -9259 0 03/02/87 3 -3/8" 4 9281 -9352 0 03/02/87 ' 3 -3/8" 4 9365 -9387 0 03/02/87 , 3 -3/8" 4 9413 -9471 0 03/02/87 3 -3/8" 4 9485 -9521 0 03/02/87 , 3 -3/8" 4 9534 -9559 0 03/02/87 ' 3 -3/8" 4 9570 -9580 0 08/18/80 I PBTD I-I 9627' I •♦1•♦1 1 7" LNR, 29 #, N -80, .0371 bpf, ID = 6.184" I-I 9670' ...���� DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/26/79 PKR 141 ORIGINAL COMPLETION WELL: WGI-03 11/16/97 D16 RWO PERMIT No: ° 1790490 03/19/06 N4ES RWO API No: 50- 029 - 20385 -00 05/12/11 N7ES RWO SEC 11, T11N, R14E, 494' FNL & 1160' FEL 05/27/11 PJC DRLG DRAFT CORRECTIONS 06/26/11 RCT/ PJC BAIL SLUGGITS/ PULL PRN (5/30/11) BP Exploration (Alaska) Monthly Injection Report for GPBBPMA, Northstar, Milne Point & Endifi for Decem... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] Sent: Tuesday, January 17, 2012 8:52 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer; Sauve, Mark A Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for December 2011 Attachments: AOGCC Inj Report 01- 12.ZIP Tom, Jim, Phoebe, and Guy, Attached is the December 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. « AOGCC Inj Report 01- 12.ZIP>> Notes on wells: Added to Report: NGI -11 (PTD #1770800) Under evaluation for IA repressurization. MPC -10 (PTD #1850150) Under evaluation for IA repressurization. Taken off Report: 16 -05A (PTD #2010100) Economic evaluation completed and well returned to Not Operable status. NGI -03 (PTD #1750610) Under Evaluation for IA repressurization in October 2011. No repressurization observed post SSSV change out WGI -03 (PTD #1790490) A 4E.027 for TxIA communication cancelled post RWO. Please call with any questions or concerns. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com 1/31/2012 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, September 13, 2011 TO: Jim Regg ' � P.I. Supervisor 1 7(13 I( SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI -03 FROM: Bob Noble PRUDHOE BAY UNIT WGI -03 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry R.— NON- CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT WGI -03 API Well Number: 50- 029 - 20385 -00 -00 Inspector Name: Bob Noble Insp Num: mitRCNI 10803052113 Permit Number: 179 -049 -0 Inspection Date: 8/2/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well WGI -03 `Type Inj. 1 G 'i TVD 1 7133 - IA 638 2430 ' 2439 2456 ' P.T.D 1790490 ',TypeTest sPT Test psi t 1783.25 -1 OA 20 20 20 20 Interval P/F P Tubing 3318 3319 I 3309 3305 Notes: Well was hot. Waited for 43 min for temp to stablize. IA psi went from 2325 psi to 2430 psi in the 43 min. Tubing and IA psi stayed steady. • C '. A ." d) S ; ' :1 fl Tuesday, September 13, 2011 Page 1 of 1 STATE OF ALASKA AND GAS CONSERVATION CONN REPOR F SUNDRY WELL OPERA NS 1. Opera ens Performed: - ❑ Abandon ® Repair We[ ❑ Plug Perforations 0 Stirtwlale ❑ Re -Etter Suspended Wel ❑ Ater Casing IN Pei Tubing ❑ Perforate New Pool ❑ Waiver i Other ❑ Charge Approved Progan 0 Operation Steadman ❑ Perforate ❑ Tine Eamon ' 2_ Operator Name: 4_ Wel Class Before Work 5. Permit To Dui teeter_ BP ) Inc. ❑ Development. ❑ Exploratory ` 179-O49 3_ Address: IN Service ❑ Sbatigraplic 6_ API Number_ P_O_ Box 196612 Anchora9e, Menke 99519 -6612 - r 7_ Property Designation: We! r_ Name and Numbe ADL 18. 9 P'BU WGI-03 9_ Feld / Pool(s): Prudhoe Bay Fold I Bey CH Pool 10_ Preset well condition summary Total depth: measured 9672 feet Pugs (measured) None feet true vertical 8577' feet Junk (measured) None feet Effective depth: measured 962T feet Packer (measured) 7845,. Mg, 8146' feet true vertical 8543 feet Packer_ (true vertical) 7133% 7255, 737g feet Casiu9 Length Size Lft3 7VD Burst Collapse Stnrctual Conductor 76` 20" 78 76" 1530 520 Surface 2723 13 - 318" 2727 2723" 4930 2670 Irdermedate 856g 7724" ..' 70 4760 Production Liner 1415! 7" 8256 - 967' 7 - Elvis 8V - n Perforation Depth: Ideastued Dom: 904 - ! . • JUN 2 1 201 True Vertical Depth: 8105' - 850g Tubing (size, grade, measured and true vertical depth): 7 -516', 29.7* x 7", 269 / 290 L / NT9S ' Packers and SSSV ( type, measured and true vertical depth): 9-5'r x 7" Baker '5 $ Packer CD 7133' 9.516" x7' Baker "SABI: parker 7255 9 x 7" Baker "513 packer 8145' 7379'' 11_ Stirnutation or cement squeeze summary: Intervals treated (measured): RECEIVED ; Treatment description inducing volwnes used and real pressure: -1 U �� 0 2 2011 Alaska Gil & GM CMS. Commission 12_ Representative Daly Average ProducM01801418on Data 08-Bbl Gas44cf VV -8bt Casing Pastime Tubing Pressure Prior to well operation: fit: 13_ Attadvnennts: ❑ copies of Logs aid surveys no , 14_ Wet Class alter work ► ❑ Exploratory 0 Devetopmert :- El service EI Stratigrapl is 1$1 Dal Report ambit Operators Wel Schematic. 15_ Well Status alter wodc - Ii GINJ 0 O 0 suSP ❑ WDSPL 0 Gas 0 GSTOR N SPUJG ❑ WAG 0 Watt 16. I hereby certify that the foregoing is true and correct to the best of my knowledge_ Number or NIA d CO_ Exempt Contact Ckwidliftork, 554-5693 311 -098 Printed Plane Tee Hubble Title Ekftvg Tedwrriagiist / , i taea By r�nu.� Signabre g n J( / , , I 4 I ' Phone Dale � Tecne Hubble, 564 -4628 Form 10404 Revised 102010 - ai24) eb Sns Original Ordy • _ Page 1 of 18 North America - ALASKA - BP O Summary Report Common Well Name: WGI -03 _ —� v LI AFE No Event Type: WORKOVER (WO) Start Date: 4/30/2011 End Date: 5/12/2011 X4- 00TLY -E: (2,709,000.00 ) Project: Prudhoe Bay (various) Site: WGI Rig Name /No.: NABORS 7ES Spud Date/Time: 9/5/1979 12:00:00AM Rig Release: 5/12/2011 Rig Contractor: NABORS ALASKA DRILLING INC. LUWI: 500292038500 Active Datum: 5 : 03 7/23/1997 00:00 @44.50ft (above Mean Sea Level) Date From - To Hrs Task I Code i NPT ' NPT Depth Phase Description of Operations (hr) (ft) ft ' 4/30/2011 j 16:00 - 00:00 8.00 MOB N WAIT PRE ' RIG ACCEPTED AT 16:00 ON 4/30/2011. I WAITING ON WGI-03 PAD PREP. RIG MOVED OFF ON 13 -09 AND STAGED ON EDGE OF PAD. DRILL LINE SPOOL SWAPPED OUT ON ROOF. CHANGED OUT KILL LINE HCR VALVE. 5/1/2011 00:00 - 10:00 10.00 MOB I N WAIT PRE WAITING ON WGI-03 PAD PREP WITH RIG I STAGED ON EDGE OF DRILL SITE CHECKED PRESSURES ON ACCUMULATOR BOTTLES REPAIRED ONE ACCUMULATOR BOTTLE REPLACED 0-RING SEALS ON LOCK DOWNS FOR DUTCH RISER I PERFORMED VISUAL INTERNAL INSPECTION , OF BOP STACK USING BORE SCOPE OPENED WELL WORK TRANSFER PERMIT FOR WGI-03 WITH PAD OPERATOR 10:00 - 19:00 9.00 MOB P PRE MOVE SUB BASE FROM DS 13 TO WGI. SPOT UP IN FRONT OF WGI -03. 19:00 - 22:00 3.00 MOB P PRE SET MATTING BOARDS AROUND WELL. NOTIFY PAD OPERATOR TO SPOT RIG OVER I WELL - PAD OPERATOR DECLINED TO OBSERVE . WSL & TP WITNESSED SPOTTING RIG OVER WELL. SPOT RIG OVER WGI -03. - - 22:00 - 00:00 2.00 I -- RIGU P � 1 - -- PRE _ - -- 2.00 RIGU P PRE RAISED DERRICK 5/2/2011 00:00 02:00 BRIDLE DOWN AND SECURE BRIDLE LINES IN DERRICK. RU TOP DRIVE 02:00 - 04:30 2.50 RIGU: P • ' PRE SPOT SHOP, SATELLITE OFFICE, AND PIT /PUMP MODULE. ADJUST RIG SUBSTRUCTURE TO ACCOMODATE PIT — _ MODULE. 04:30 - 08:00 !, 3.50 RIGU I P PRE GENERAL RIG UP OPERATIONS I HOOK UP ELECTRICAL AND CIRCULATION LINES BETWEEN PUMP /PIT MODULE AND I MAIN RIG SUBSTRUCTURE. I RIG WELDERS WORKING ON SPLICING NEW SPOOL TO DRILLING LINE. BEGIN LOADING 9.8 PPG BRINE IN PITS. 08:00 - 09:00 1.00 ! RIGU P PRE PERFORM RIG EVACUATION DRILL WITH ALL EMPLOYEES ON LOCATION. ' HELD AFTER ACTION REVIEW TO DISCUSS ' LEARNINGS FROM 13 -09 RWO AND LAST RIG MOVE. DISCUSSED OBJECTIVES AND PROCESS SAFETY CONSIDERATIONS FOR UPCOMING WGI -03 RWO. ,09:00 - 10:00 1.00 RIGU PRE CONITNUE GENERAL RIGUP OPERATIONS. 10:00 - 12:00 2.00 RIGU P PRE PERFORM INSPECTION OF SAFETY CRITICAL ' EQUIPMENT. CHECKED FOR CREW /LEADERSHIP COMPETENCIES, EQUIPMENT INSPECTION RECORDS. Printed 5/25/2011 4:03:35PM North America - ALASKA - BP P 2 of 18 *ration Summary Report rY P Common Well Name: WGI-03 1, AFE No Event Type: WORKOVER (WO) I Start Date: 4/30/2011 End Date: 5/12/2011 X4- 00TLY -E: (2,709,000.00 ) J Project: Prudhoe Bay (various) Site: WGI Rig Name /No.: NABORS 7ES Spud Date/Time: 9/5/1979 12:00:00AM 1Rig Release: 5/12/2011 Rig Contractor: NABORS ALASKA DRILLING INC. : UWI: 500292038500 Active Datum: 5 : 03 7/23/1997 00:00 @44.50ft (above Mean Sea Level) Date i From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) L hr (ft) [12:00 - 14:00 2.00 RIGU 1 N WAIT 1 PRE NON- BILLABLE NPT: WAITING ON 1 INSPECTION RECORDS AND 1 DOCUMENTATION FOR SAFETY CRITICAL I EQUIPMENT FROM NABORS. 4" DRILLPIPE LOADED INTO PIPE SHED. 1 14:00 - 18:30 4.50 WHSUR P DECOMP ; RIG UP API VALVE SHOP LUBRICATOR. - PRESSURE TEST TO 250 LOW / 4000 PSI HIGH FOR 5 MIN AGAINST TOP OF MASTER VALVE. AFTER MULTIPLE ATTEMPTS TO j TEST AGAINS SSV FAILED - PULLED 6 -3/8" TYPE J BPV WITH NO PRESSURE BELOW. - PERFORMED TEST OF SIERRA GAS , MONITORING SYSTEM. PASSED. 18:30 - 22:30 4.00 WHSUR P DECOMP ' RIG UP API VALVE SHOP CREW LUBRICATOR. ' PRESSURE TEST TO 250 LOW / 4000 PSI HIGH FOR 5 MIN AGAINST MASTER VALVE. SET 6 -3/8" TYPE J TWC. ' PRESSURE TWC FROM ABOVE TO ' 250 PSI LOW 5 MIN AND 4000 PSI HIGH FOR 10 MIN. TEST CHARTED AND OBSERVED BY WSL (SEE ATTACHED) ' RD VALVE SHOP LUBRICATOR. i 22:30 - 00:00 1.50 WHSUR P DECOMP ' ND AND MOVE OUT 7- 1/16" X 6 -3/8" CAMERON _ TREE. 5/3/2011 00:00 - 01:30 1.50 I BOPSUR P DECOMP INSPECTED THREADS ON TUBING HANGER AND FOUND TO BE BAD. WEAR AND THREAD DAMAGE NOTICED ON RIG SIDE OF HANGER, ' COULD NOT MAKE UP CROSS OVER FOR LANDING JOINT. 1 ' SET STACK ON TUBING SPOOL AND NU 01:30 - 02:30 1.00 BOPSUR P DECOMP CHANGE OUT TOP RAMS FROM 4 -1/2" X 7" TO — - 7 -5/8" PIPE RAMS. 02:30 03:30 11 1.00 BOPSUR P DECOMP RU TO TEST BOPF FILL ALL LINES WITH WATER. ' 03:30 - 11:30 8.00 I BOPSUR P ' DECOMP FUNCTION AND PRESSURE TEST BOPE (WITNESS WAIVED BY AOGCC AGENT CHUCK SCHEVE ON 5/2/2011). CHOKE MANIFOLD, CHOKE/KILL HCR ( 01° VALVES, BOP STACK RAMS, FLOOR VALVES AND ALL ASSOCIATED LINES TESTED TO 250 , PSI LOW FOR 5 MIN AND 4000 PSI HIGH FOR 5 MIN. HYDRIL ANNULAR TESTED TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MIN EACH. ACCUMULATOR UNIT FUNCTION TESTED. ' 200 PSI BUILDUP ON DRAWDOWN TEST = 28 SEC, FULL SYSTEM PRESSURE = 2:25 5 NITROGEN BOTTLES @ 1975 PSI. ! RECORDED CLOSURE TIMES FOR COMPONENTS AS FOLLOWS: ANNULAR PREVENTER = 26 SEC UPPER 7 -5/8" PIPE RAMS = 6 SEC BLIND / SHEAR RAMS = 14 SEC LOWER 3-1/2" X 6" VB RAMS = 7 SEC ' CHOKE AND KILL HCR VALVES = 1 SEC EACH ! "TESTS WITNESSED BY WSL. SEE ATTACHED CHART** 11:30 - 12:00 ' 0.50 BOPSUR P! DECOMP RD AFTER TESTING BOPE. Printed 5/25/2011 4:03:35PM North. America - ALASKA - BP Page 3 of 18 dik . • ration Summary Report Common Well Name: WGI -03 — AFE No _ Event Type: WORKOVER (WO) I Start Date: 4/30/2011 ' End Date: 5/12/2011 X4- 00TLY -E: (2,709,000.00 ) Project: Prudhoe Bay (various) I Site: WGI Rig Name /No.: NABORS 7ES I Spud Date/Time: 9/5/1979 12:00:00AM !Rig Release: 5/12/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292038500 Active Datum: 5 : 03 7/23/1997 00:00 @44.50ft (above Mean Sea Level) Date From - To Hrs I Task Code NPT NPT Depth Phase 1 Description of Operations I I (hr) 1 (ft) 12:00 - 14:00 2.00 I BOPSUR P DECOMP rRU AND TEST LUBRICATOR TO 250 PSI LOW FOR 5 MIN AND 4000 PSI HIGH FOR 5 MIN. I PULLED 6 -3/8" J TYPE TWC. RDMO I LUBRICATOR AND VALVE SHOP CREW. 14:00 15:00 1.00 r PULL P DECOMP PICK UP BHA #1, MULTI - STRING CUTTER ASSY. 15:00 - 16:00 1.00 PULL P I DECOMP RUN IN THE HOLE WITH BHA #1, PICKING UP 4" DRILL PIPE. - FROM 33' TO 95' DPM. - CIRCULATE DIESEL FROM DRILL PIPE AND ANNULUS. I - 3 BPM AND 400 PSI. I PICK UP TO MULTI- STRING CUTTER AND RE -TIE CUTTERS. 16:00 - 17:00 1.00 PULL P DECOMP CONTINUE TO RUN IN THE HOLE WITH BHA ' #1, PICKING UP 4" DRILL PIPE. I 1- FROM 95' TO 409' DPM. - INSTALLED 4" FOSV AND DART VALVE TO 1 _ , PREVENT OVERFLOWING DRILL PIPE. 1 T00 - 18:30 1.50 P PULL ■ DECOMP I SHUT IN THE WELL. - 12 BBL PIT GAIN TAKEN AT 409' DPM. - CLOSED THE ANNULAR PREVENTER AND SHUT -IN THE WELL. - INITIAL SHUT -IN CASING PRESSURE = 20 PSI. - PRESSURE BUILT TO 90 PSI OVER 50 MIN.. - BLED CASING PRESSURE BACK TO 0 PSI. - DISCUSSED WITH SUPERINTENDENT AND I DETERMINED THAT COMPRESSED PACKER GAS FROM 48' OF TAILPIPE AT 7955' WAS THE CAUSE OF THE ISSUE. - INFORMED AOGCC INSPECTOR, LOU GRIMALDI, OF THE SITUATION. 18:30 - 19:30 1.00 PULL P DECOMP 1 CIRCI II ATFD OUT THE GAS IN THE WELL I I BORE. I- CIRCULATED 2 SURFACE TO SURFACE I VOLUMES. - 38 BBLS OF 9.8 PPG BRINE. - 2 BPM AND 170 PSI THROUGH THE CHOKE AND GAS BUSTER. 19:30 20:30 I 1.00 PULL P 1 DECOMP OPEN THE WELL BACK UP. , - MONITORED THE WELL FOR 30 MIN. 1 - NO FLOW THROUGH THE CHOKE AND GAS BUSTER. i - OPENED THE ANNULAR. - MONITORED THE WELL FOR 30 MIN. - NO FLOW. 20:30 - 21:30 1.00 PULL P DECOMP PULLED OUT OF THE HOLE AND LAID DOWN BHA #1. ' - AFTER DISCUSSION WITH NS SUPERINTENDENT AND RWO ENGINEER ' DECISION WAS MADE TO RUN IN THE HOLE WITH A MULE SHOE AND DISPLACE THE DIESEL FROM THE WELL. 21:30 22:00 I 0.50 PULL P DECOMP 1PICK UP 4" MULE SHOE AND FLOAT SUB WITH FLOAT. Printed 5/25/2011 4:03:35PM North America - ALASKA - BP Page 4 of is , f eration Summary Report Common Well Name: WGI -03 AFE No Event Type: WORKOVER (WO) I Start Date: 4/30/2011 1 End Date: 5/12/2011 X4- 00TLY -E: (2,709,000.00 ) Project: Prudhoe Bay (various) 1 Site: WGI I Rig Name /No.: NABORS 7ES 1 Spud Date/Time: 9/5/1979 12:00:00AM 1 Rig Release: 5/12/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292038500 Active Datum: 5 : 03 7/23/1997 00:00 @44.50ft (above Mean Sea Level) Date ! From - To Hrs I Task Code 1 NPT NPT Depth 1 Phase Description of Operations (hr) ( ft ) 22 :00 - 23:30 1.50 I PULL i P DECOMP 1 SHUT IN THE WELL. ' 1 1 1- WHILE TORQUING THE LAST CONNECTION FOR THE MULE SHOE TO THE FIRST STAND ! THE RETURN FLOW WENT TO 45 %. 1 '- PICKED THE MULE SHOE OUT OF THE HOLE ' ! AND CLOSED THE BLIND /SHEAR RAMS. ' - INITIAL SHUT IN PRESSURE = 10 PSI. 1 - PRESSURE BUILT TO 50 PSI OVER NEXT 40 MINUTES. - 11 BBL PIT GAIN - NOTIFIED SUPERINTENDENT AND RWO 1 ENGINEER. - AFTER DISCUSSIONS, DETERMINED THAT THE PACKER GAS WAS MIGRATING UP THE ' 1 1HOLE AND THE DIESEL SWAPPING WITH THE ' ! 1 9.8 PPG BRINE WAS EXACERBATING THE ISSUE. 23:30 00:00 0.50 I PULL 1 P DECOMP j BLEED DOWN THE CASING PRESSURE THROUGH THE CHOKE AND GAS BUSTER. 5/4/2011 00:00 - 00:30 ! 0.50 I PULL P DECOMP 'BLEED DOWN THE CASING PRESSURE ,THROUGH THE CHOKE AND GAS BUSTER. 00:30 - 02:00 1.50 PULL L P 1 ' DECOMP 1RIG UP AND MIT THE TUBING AND IA TO 250 • PSI LOW AND 4000 PSI HIGH FOR 30 CHARTED MIN. 1 - PRESSURE UP TO 250 PSI FOR 5 CHARTED I ' MIN. - GOOD TESTS. I - CONTINUE TO PRESSURE UP TO 4000 PSI. - SENSATOR ON IA BROKE AT 2500 PSI. BLED OFF ALL PRESSURES AND REPAIRED I SENSATOR. - PRESSURED UP TO 250 PSI FOR 5 ' 1 C MIN. 1 1 - GOOD TEST. - CONTINUED TO PRESSURE UP TO 4000 PSI ON BOTH IA AND TUBING. I - GOOD TESTS. - IA LOST 105 PSI IN FIRST 15 MIN. AND 146 PSI THE SECOND 15 MIN. - TBG LOST 94 PSI IN THE FIRST 15 MIN. 45 PSI THE SECOND 15 MIN. 02:00 - 02:30 T 0.50 PULL P DECOMP BLEED DOWN THE CASING PRESSURE THROUGH THE CHOKE AND GAS BUSTER. DIESEL CONTINUED TO SURGE AND FLOW. 02:30 - 03:00 0.50 PULL P ' DECOMP 1MONITORED WELL. - OPENED BLIND SHEAR RAMS. - MONITORED WELL FOR 30 MIN. - NO FLOW. Printed 5/25/2011 4:03:35PM North America - ALASKA - BP Page 5 of 18 gfl eration Summary Report r'l/ ort P Common Well Name: WGI -03 1 AFE No Event Type: WORKOVER (WO) I Start Date: 4/30/2011 I End Date: 5/12/2011 I X4- 00TLY -E: (2,709,000.00 ) 1 Bay Site: WGI �I Project: Prudhoe ea various Rig Name /No.: NABORS 7ES Spud Date/Time: 9/5/1979 12:00:00AM I Rig Release: 5/12/2011 Rig Contractor: NABORS ALASKA DRILLING INC. I UWI: 500292038500 Active Datum: 5 : 03 7/23/1997 00:00 @44.50ft (above Mean Sea Level) Date I From - To I Hrs I Task I Code I NPT NPT Depth Phase Description of Operations (ft) 03:00 - 12:00 9.00 PULL P DECOMPRUN IN THE HOLE WITH 4" MULE SHOE ON DRILL PIPE I - RAN IN ONE STAND FROM THE DERRICK. I - DIESEL FLOWING OVER. - STAB FOSV AND DART VALVE. ! I - NO FLOW DOWN THE FLOWLINE. - WELL WAS OUT OF BALANCE OVER THE 90' STAND. - STAGE IN THE HOLE CIRCULATING A SURFACE TO SURFACE EVERY 200' TO 500'. I - 2 TO 3 BPM AND 60 TO 85 PSI. - CIRCULATING THROUGH THE CHOKE AND GAS BUSTER. AT 2365' DPM BEGAN CIRCULATING AT 7 BPM, TAKING RETURNS DOWN THE I FLOWLINE. 'I- HAD GAS BREAKING OUT ON EVERY BOTTOMS UP. 12:00 23:30 11.50 PULL P I DECOMP CONTINUED TO STAGE IN THE HOLE WITH 4" ' I MULE SHOE PICKING UP DRILL PIPE. I I - FROM 3775' TO 7955' DPM. r - CONTINUE TO CIRCULATE A SURFACE TO I SURFACE VOLUME EVERY 500'. I 1 - 7 BPM AND 460 TO 800 PSI. ! - GAS BREAKING OUT ON EVERY I I BOTTOMS UP. 23:30 00:00 I 0.50 I PULL P DECOMP DISPLACE THE WELL WITH 9.8 PPG BRINE. - 7 BPM AND 800PSI. 5/5/2011 00:00 01:30 1.50 I PULL P DECOMP CONTINUE TO DISPLACE THE WELL TO 9.8 ! i _ I PPG BRINE. ' - 7 BPM AND 800 PSI. ! - 1000 STROKES BEFORE BOTTOMS UP I I REDUCED THE RATE AND DIVERTED THROUGH THE GAS BUSTER IN I I ANTICIPATION OF GAS. I I - 3 BPM AND 118 PSI. I I I - HAD SOME GAS AT BOTTOMS UP. - OPENED BACK UP AND CIRCULATED A SECOND BOTTOMS UP. I - 10 BPM AND 1480 PSI. ' - SHUT DOWN AND MONITORED THE WELL. - NO FLOW. 01:30 - 04:30 3.00 PULL P DECOMP I PULL OUT OF THE HOLE STANDING BACK 4" I DRILL PIPE. - FROM 7955' TO MULE SHOE ASSY. 04:30 05:00 0.50 PULL P DECOMP LAY DOWN DART VALVE, FOSV, FLOAT SUB AND MULE SHOE. ' 05:00 - 05:30 0.50 PULL P DECOMP RIG UP DUTCH RISER AND DSM ' LUBRICATOR. 05:30 - 06:00 0.50 I PULL I P DECOMP TEST LUBRICATOR AND INSTALL TWC. I - TESTED LUBRICATOR TO 250 PSI LOW 3500 I PSI HIGH FOR 5 CHARTED MIN. - GOOD TEST. 06:00 - 06:30 0.50 PULL P I DECOMP PRESSURE TEST TWC TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MIN. - GOOD TEST. 06:30 - 07:00 ' 0.50 PULL P DECOMP RIG DOWN LUBRICATOR AND AND DUTCH RISER. Printed 5/25/2011 4:03:35PM • orth America - ALASKA - BP Page 6 of 18 Aeration Summary Report. Common Well Name: WGI -03 AFE No Event Type: WORKOVER (WO) Start Date: 4/30/2011 I End Date: 5/12/2011 X4- 00TLY -E: (2,709,000.00 ) Project: Prudhoe Bay (various) Site: WGI Rig Name /No.: NABORS 7ES I Spud Date/Time: 9/5/1979 12:00:00AM Rig Release: 5/12/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292038500 Active Datum: 5 : 03 7/23/1997 00:00 ©44.50ft (above Mean Sea Level) Date I From - To I Hrs I Task 1 Code NPT ' NPT Depth Phase Description of Operations 07:00 08:30 1.50 BOPSUR P ' O I DECOMP _ (hr) j ft__ - �, � r ;TEST BOPS USED WHILE CONTROLLING , PACKER GAS. - TESTED ANNULAR PREVENTER WITH 4" , I TEST JOINT. - 250 PSI LOW 3500 PSI HIGH FOR 5 I CHARTED MIN. . - TESTED BLIND /SHEAR RAMS. - 250 PSI LOW AND 4000 PSI HIGH FOR 5 CHARTED MIN. ALL TESTS WERE GOOD. RIG DOWN TEST EQUIPMENT. 08:30 - 10:30 2.00 BOPSUR P DECOMP I PULL TWC. - RIG UP DUTCH RISER AND DSM LUBRICATOR. '= PRESSURE TEST LUBRICATOR TO 250 PSI LOW 3500 PSI HIGH FOR 5 MIN. ' - - GOOD TEST. . - PULL TWC AND LAY DOWN. ' r - RIG DOWN LUBRICATOR AND DUTCH RISER. 10:30 - 11:00 0.50 PULL P DECOMp ' PICK UP MULTI - STRING (:I ITTFR ASSY , 1 , , - ' - PJSM WITH RIG CREW AND BAKER FISHING REPRESENTATIVE. I - PICK UP CUTTER ASSY FROM PIPE SHED. 11:00 14:30 3.50 i PULL P DECOMP RUN IN THE HOLE WIHT THE MULTI - STRING CUTTER ON 4" DRILL PIPE. - FROM 33' TO 7920' DPM. ! 14:30 - 15:30 1.00 PULL P DECOMP POSITION MULTI - STRING CUTTER AND CUT 7 I 5/8" TUBING. I - TAG 'RN' N(PPLE AT 7941'. - PICK UP AND POSITION CUTTER AT 7912'. - RIG UP TO TAKE RETURNS FROM IA THROUGH CHOKE. ' - CUT 7 5/8" TUBING PER BAKER FISHING ' REPRESENTATIVE. - UP WEIGHT = 148K LBS, DOWN WEIGHT , = 120K LBS. - ROTATING WEIGHT = 135K LBS. ' - 80 RPM AND 4.5K FT -LBS TORQUE. 6BPMAND1500PSI. 15:30 - 16:30 1.00 PULL P DECOMP CIRCULATE DIESEL AND 8.5 PPG SEAWATER OUT OF IA. ' - CLOSE ANNULAR PREVENTER AND TAKE ' RETURNS THROUGH CHOKE. - 2.5 BPM AND 460 PSI. I ' - DISPLACED 33 BBLS OF 58 DEG F DIESEL AND 99 BBLS OF 8.5 PPG SEAWATER. 16:30 - 22:30 6.00 PULL P I I DECOMP PULL OUT OF THE HOLE WITH THE MULTI- STRING CUTTER. 22:30 - 23:00 0.50 I PULL P ' DECOMP LAY DOWN THE MULTI - STRING CUTTER ' ASSY PER THE BAKER FISHING REPRESENTATIVE. 23:00 - 00:00 1.00 PULL P ' DECOMP PICKUP SPEAR DRESSED TO CATCH 7" ' I TUBING HANGER AND ENGAGE TUBING HANGER. 5/6/2011 00:00 00:30 0.50 PULL P DECOMP BACK OUT LOCK DOWN SCREWS AND PULL HANGER TO RIG FLOOR. - PULLED FREE WITH 240K LBS. 00:30 - 01:00 0.50 PULL P DECOMP ' CIRCULATE THROUGH SPEAR. ' - SPEAR CUP PACK -OFF LEAKING. Printed 5/25/2011 4:03:35PM orth America - ALASKA - BP Page 7 of 18 Aeration Summary Report Common Well Name: WGI -03 AFE No Event Type: WORKOVER (WO) Start Date: 4/30/2011 End Date: 5/12/2011 X4- 00TLY -E: (2,709,000.00 ) Project: Prudhoe Bay (various) Site: WGI I 1 Rig Name /No.: NABORS 7ES Spud Date/Time: 9/5/1979 12:00:00AM Rig Release: 5/12/2011 I Rig Contractor: NABORS ALASKA DRILLING INC. ! UWI: 500292038500 Active Datum: 5 : 03 7/23/1997 00:00 @44.50ft (above Mean Sea Level) Date From - To ! Hrs 1 Task 1 Code NPT ''! NPT Depth I Phase ! Description of Operations j (hr) I- ( ) 1 ft I I 01 :00 02:00 , 1.00 I PULL I P DECOMP ! RELEASED SPEAR FROM HANGER AND LAID !DOWN. I- WELL IS SLIGHTLY OUT OF BALANCE AND I FLOWING OUT OF TUBING. RIGGED UP TONGS AND PULLED TUBING 1 ! !HANGER AND PUP AND LAID DOWN. ! ! I- MADE UP'XO' AND SAFETY VALVE TO 75/8" TUBING IN SLIPS. - UP WEIGHT = 235K LBS, DOWN WEIGHT = 1195K LBS. 02:00 - 03:30 1.50 PULL P DECOMP CIRCULATE 1.5 TIMES SURFACE TO `SURFACE VOLUME. - 10 BPM AND 1825 PSI. 03:30 - 04:30 1.00 PULL I P DECOMP — I RIG UP TO PULL 7 5/8" TUBING FROM CUT AT 7912' ! 04:30 - 15:00 10.50 PULL P I DECOMP !I PULL AND LAY DOWN 75/8" TUBING. —_ _ - FROM 7912' TO 3871' DPM. PULL ' 15:00 - 16:00 1.00 P DECOMP I CIRCULATE A SURFACE TO SURFACE VOLUME. - ACTUAL DISPLACEMENT DIDN'T MATCH I CALCULATED DISPLACEMENT. - DECIDE TO CIRCULATE THE WELLBORE. PUMPED 242 BBLS OF 9.8 PPG BRINE. I !- 8 BPM AND 1095 PSI. MONITORED THE WELL. ! - NO FLOW OR LOSS. 16:00 23:30 7.50 PULL P DECOMP ! ; CONTINUED TO PULL AND LAY DOWN 7 5/8" TUBING. ! - FROM 3871' TO CUT JT. - RECOVERED THE FOLLOWING: ! - 195 JTS OF 7 5/8" TUBING. - (1) 'R' NIPPLE ASSY. I I - (1) 'DB-6' NIPPLE ASSY. I 1 CUT JOINT OF 7 ", 7.66' LONG. 23:30 - 00:00 0.50 PULL P DECOMP RIG DOWN 7 5/8" TUBING HANDLING ! EQUIPMENT. 5/7/2011 ! 00:00 - 01:30 1.50 I PULL P DECOMP RIG DOWN 7 5/8" TUBING HANDLING I EQUIPMENT. ! - RIG DOWN 75/8" ELEVATORS, COMPENSATOR AND DOUBLE STACK TONGS. - CLEAN AND CLEAR RIG FLOOR. 01:30 - 02:00 0.50 PULL P ! DECOMP RIG UP TO RUN PACKER MILLING ASSY ON 4" DRILL PIPE. Printed 5/25/2011 4:03:35PM . North America - ALASKA - BP Page 8 of 18 !iteration Summary Report rY` p Common Well Name: WGI -03 AFE No Event Type: WORKOVER (WO) Start Date: 4/30/2011 End Date: 5/12/2011 I X4- 00TLY -E: (2,709,000.00 ) Project: Prudhoe Bay (various) Site: WGI 1 Rig Name /No.: NABORS 7ES Spud Date/Time: 9/5/1979 12:00:00AM I Rig Release: 5/12/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292038500 Active Datum: 5 : 03 7/23/1997 00:00 @44.50ft (above Mean Sea Level) Date From - To Hrs Task I Code NPT ' NPT Depth Phase I Description of Operations (hr) (ft) --j , 02:00 - 04:30 2.50 PULL P I DECOMP I PICK UP AND RIH WITH PACKER MILLING I BHA. I PJSM WITH RIG CREW AND BAKER FISHING I REPRESENTATIVE. i- PICK UP PACKER MILLING BHA AS FOLLOWS: I - 53/4" ROUND NOSE S/L MILL - PIN x PIN'XO' I - 8 1/2" MM PACKER MILL 1 - TRIPPLE CONNECT I 1 - (4) 7" BOOT BASKET I 1 , - BIT SUB I - (2) STRING MAGNET - 6 1/4" BUMPER SUB ! - 6 1/4" OIL JAR ! ! - PUMP -OUT SUB - (9) 6 1/4" DRILL COLLAR I , ! - `XO I IOVERALL LENGTH = 349.49'. I ' MAX OD = 8,50 ". MIN ID= 2.00 ". 04:30 07:30 3.00 I PULL P DECOMP RUN IN THE HOLE WITH PACKER MILLING - "BHA ON 4" DRILL PIPE - RIH WITH PACKER MILLING BHA FROM 349' TO 7872'. I- PUW 158K. SOW 135K. 07:30 - 08:00 0.50 PULL I P 1 DECOMP ESTABLISH PARAMETERS - CIRCULATE AT 12 BPM WITH 1940 PSI � I ! - ROTATING WEIGHT 148K. - ROTATE AT 80 RPM WITH 4K TORQUE. - OBTAIN SLOW PUPM RATES 08:00 - 10:00 2.00 FISH P ! DECOMP MILL PRODUCTION PACKER I - RIH SLOWLY. TAG 7 5/8" l UBING STUB AT • I !7912' I I - MILL 2' OF 7 5/8" TUBING STUB WITH 80 RPM, 5 -8K TORQUE ! - 5 BPM WITH 410 PSI - WOB 10 -15K I- MILL PRODUCTION PACKER. PACKER FELL I j I FREE. I PUSH PACKER 4' DOWN AND SET DOWN 10KAT7919' 110:00 - 14:30 4.50 PULL P DECOMP ,CIRCULATE ; PICK UP TO POSITION TOOL JOINT ABOVE I BOP. I - CLOSE ANNULAR PREVENTOR. I ' - CIRCULATE BOTTOMS UP THROUGH THE , CHOKE AND GAS BUSTER. SOME SURGES OF FLOW NOTED IN THE POSSUM BELLY INDICATING THAT GAS WAS COMING UP THE WELL. - OBSERVED WELL FOR 10 MINUTES. NO FLOW. ' - OPEN BOP, CHECK FOR FLOW. CIRCULATE AROUND 40 BBL HIGH VIS 1 SWEEP AT 12 BPM WITH 1829 PSI - MONITOR WELL. - NO FLOW. 14:30 - 18:00 3.50 PULL P DECOMP PULL OUT OF THE HOLE WITH PACKER ! MILLING ASSY. FROM 7890' TO BHA. Printed 5/25/2011 4:03:35PM ` orth America - ALASKA - BP Page 9 of 18 Aeration Summary Report . Common Well Name: WGI -03 1 AFE No Event Type: WORKOVER (WO) I Start Date: 4/30/2011 End Date: 5/12/2011 lX4- 00TLY -E: (2,709,000.00 ) Project: Prudhoe Bay (various) Site: WGI Rig Name /No.: NABORS 7ES Spud Date/Time: 9/5/1979 12:OO:OOAM I Rig Release: 5/12/2011 Rig Contractor: NABORS ALASKA DRILLING INC. 1 UWI: 500292038500 Active Datum: 5 : 03 7/23/1997 00:00 @44.50ft (above Mean Sea Level) Date 1 , From - To 1 Hrs Task 1 Code 1 NPT 1 NPT Depth', Phase I Description of Operations (hr) (ft) I 18:00 20:30 2.50 PULL 1 P DECOMP 1LAY DOWN PACKER MILLING ASSY. 1- RECOVERED 2 GAL OF METAL CUTTINGS FROM STRING MAGNETS. ' I- RECOVERED 6 GAL OF METAL CUTTINGS FROM BOOT BASKETS. 20:30 - 21:30 1.00 PULL P DECOMP 1PICK UP PACKER SPEAR ASSY AND RUN IN THE HOLE. - PJSM WITH RIG CREW AND BAKER FISHING REPRESENTATIVE. PICK UP SPEAR ASSY AS FOLLOWS: I - BULL NOSE 1 ' - 5 3/4" ITCO SPEAR - SPEAR EXTENSION I - STOP SUB - 6 1/4" BUMPER SUB - 6 1/4" OIL JAR - PUMP -OUT SUB - (9) 6 1/4" DRILL COLLAR 1 - ` I 10VERALL LENGTH = 309.42'. MAX OD = 8.25 ". _ I __ _ 1MIN ID = 2.00". U 21:30 - 00:00 I 2.50 PULL P 1 DECOMP !RUN IN THE HOLE WITH PACKFR SPFAFt, ASSY. - FROM 309' TO 6421' DPM. - UP WEIGHT = 135K LBS, DOWN WEIGHT = 1120K LBS. 5/8/2011 00:00 - 00:30 0.50 I FISH _ P DECOMP ' 'I CONTINUE TO RUN IN THE HOLE WITH THE PACKER SPEAR ASSY. - FROM 6421' TO 7863' DPM. I 1- UP WEIGHT = 158K LBS, DOWN WEIGHT = 135K LBS. 00:30 - 01:00 i 0.50 FISH 1 P 1 DECOMP 1 ENGAGE FISH WITH PACKER SPEAR ASSY. - ESTABLISH SLOW PUMP RATES AT 7863' I I DPM. - ESTABLISH PARAMETERS PRIOR TO ENGAGING FISH. I - 3 BPM AND 180 PSI. - TAG FISH AT 7919' DPM. - ENGAGE FISH AND SET DOWN 15K LBS ON NO-GO. PICK -UP AND VERIFY THAT FISH IS ENGAGED. - MONITOR WELL FOR 10 MIN. - WELL IS STATIC. 01:00 04:30 3.50 FISH P DECOMP 1 PULL OUT OF THE HOLE WITH PACKER I 1SPEAR AND FISH. 1 1 , - FROM 7925' TO 309' DPM. 04:30 06:30 2.00 1 FISH 1 P DECOMP 1 AY !OWN PACKFR SPFAR RHA - UNABLE TO RELEASE SPEAR FROM FISH. 1 - CALL OUT WACHS CUTTER TO CUT FISH TO A LENGHT THAT WILL FIT THROUGH THE PIPE SHED DOOR. 06:30 - 08:00 1.50 FISH N WAIT 40.00 DECOMP WAITING FOR WACHS CUTTER. - NORDIC 1 RIG IN THE MIDDLE OF THE ROAD WITH A FLAT TIRE. I - SERVICE HANDS HAD TO DRIVE THE , LONG WAY AROUND TO GET TOOL AND THEN RETURN. 1- BLOW AIR THROUGH FISH TO ENSURE NO TRAPPED PRESSURE. Printed 5/25/2011 4:03:35PM orth America - ALASKA - BP Page 10 of 18 a .. Aeration Summary Report Common Well Name: WGI -03 AFE No Event Type: WORKOVER (WO) Start Date: 4/30/2011 End Date: 5/12/2011 X4- 00TLY -E: (2,709,000.00 ) Project: Prudhoe Bay (various) Site: WGI 1 ' Rig Name /No.: NABORS 7ES Spud Date/Time: 9/5/1979 12:00:00AM Rig Release: 5/12/2011 Rig Contractor: NABORS ALASKA DRILLING INC. ' UWI: 500292038500 Active Datum: 5 : 03 7/23/1997 00:00 @44.50ft (above Mean Sea Level) Date From - To Hrs Task 1 Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:00 - 09:30 1.50 FISH j N HMAN ! 40.00 DECOMP CAMERON REPRESENTATIVE CUT FISH IN HALF USING THE WACHS CUTTER. ; I- PJSM WITH RIG CREW AND CAMERON PERSONNEL. _—' - CUT AND LAY DOWN FISH. 09:30 - 11:00 1.50 FISH P ' DECOMP PICK UP RCJB BHA AND RUN IN THE HOLE. - PJSM WITH RIG CREW AND BAKER FISHING REPRESENTATIVE. - PICK UP RCJB BHA AS FOLLOWS: - 5 3/4" OD JET BASKET WITH 6 1/2" HEAD ' - DOUBLE PIN SUB ' - (4) 7" BOOT BASKETS - BIT SUB - DOUBLE PIN SUB - 9 5/8" CASING SCRAPER ; - BIT SUB - (2) STRING MAGNET I - 6 1/4" BUMPER SUB -.6 1/4" OIL JAR - PUMP -OUT SUB - (9) 6 1/4" DRILL COLLAR - `XO' OVERALL LENGTH = 359.75'. MAX OD = 6.50 ". MIN ID = 0.875 ". ,11:00 14:00 3.00 1 FISH P ; DECOMP RUN IN THE HOLE WITH THE RCJB ON 4" i DRILL PIPE. -FROM 360' TO 7882' DPM. 1 - UP WEIGHT = 160K LBS, DOWN WEIGHT = 125K LBS. 14:00 - 14:30 ' 0.50 FISH P ' DECOMP WORK CASING SCRAPFR ACROSS NFW PAC:KE SFTTIN(+ nFPTH AT 7867' r)PM , - 7.5 BPM AND 1053 PSI. - SLACK OFF AND TAG TUBING STUB AT 7964' ; DPM. - EASE INTO TUBING STUB AND TAG SAND _ AT 7969' DPM. 14:30 18:00 3.50 FISH P ' DECOMP DISPLACE WELL TO CLEAN 9.8 PPG BRINE. ; - RECIPROCATE FROM 7934' TO 7910' DPM. OFF LOAD 430 BBLS OF 9.8 BRINE PRIOR TO BEGINNING DISPLACEMENT. ' DISPLACE BRINE AT 8.5 BPM AND 1500 PSI. - UP WEIGHT = 160K LBS, DOWN WEIGHT = 125K LBS. 18:00 - 20:00 2.00 FISH P DECOMP DROP BALL TO ACTIVATE RCJB AND WASH DOWN TO TOP OF SAND. - WORK RCJB WITH 30 RPM, 8.5 BPM AND 1907 PSI. - SET DOWN 15K LBS AND CONTINUE TO ATTEMPT TO GET BELOW 7969'. ' UNABLE TO WASH DOWN. - TORQUE INCREASES RAPIDLY. - SOME OVERPULL, 5K - 15K LBS, NOTED WHEN PICKING UP. - CONSULT WITH RWO ENGINEER AND SUPERINTENDENT. - DECIDE TO PULL OUT OF THE HOLE, _ ' _ _ STANDING BACK DRILL PIPE. 20:00 - 00:00 4.00 FISH P , DECOMP PULL OUT OF THE HOLE WITH THE RCJB AND STAND BACK DRILL PIPE. - FROM 7969' TO 390' DPM. Printed 5/25/2011 4:03:35PM orth America - ALASKA - BP Page 11 of 18 eration Summary Report W P rY ort . P Common Well Name: WGI -03 I AFE No Event Type: WORKOVER (WO) I Start Date: 4/30/2011 I End Date: 5/12/2011 IX4- 00TLY -E: (2,709,000.00 ) i Project: Prudhoe Bay (various) I Site: WGI Rig Name /No.: NABORS 7ES I Spud Date/Time: 9/5/1979 12:00:00AM I Rig Release: 5/12/2011 Rig Contractor: NABORS ALASKA DRILLING INC. I UWI: 500292038500 Active Datum: 5 : 03 7/23/1997 00:00 @44.50ft (above Mean Sea Level) Date � From - To Hrs Task I Code I NPT NPT Depth Phase Description of Operations I (hr) (ft) r 5/9/2011 00:00 02:00 2.00 � FISH P DECOMP LAY DOWN RCJB BHA. I - RECOVERED 1 CUP OF RUBBER AND ' METAL PIECES FROM RCJB AND BOOT I I BASKETS. • - RECOVERED 1 GAL OF METAL CUTTINGS FROM MAGNETS. INSPECTED RCJB HEAD. ' - NO WEAR NOTED ON THE INSIDE OR FACE OF HEAD. , 1 .- LEADING EDGE OF HEAD IS WORN I I I INDICATING A RESTRICTED ID OR JUNK I 1 WEDGING ON THE OD OF THE HEAD. _ L ! - SEE ATTACHED PICTURES. ' �1 1 02:00 02:30 ' 0.50 FISH N WAIT DECOMP CONFERENCE CALL WITH RWO ENGINEER, SUPERINTENDENT, WSL, AND FISHING ' REPRESENTATIVE. - - DISCUSSED WEAR PATTERN ON RCJB HEAD AND LACK OF SAND IN BOOT (BASKETS. I- DETERMINED NEXT COURSE OF ACTION WOULD BE A 6 3/4" OD JUNK MILL ASSY. ' 02:30 04:30 I 2.00 FISH C 1 DECOMP I PICK UP JUNK MILL BHA AND RUN IN THE I HOLE. j - PJSM WITH RIG CREW AND BAKER FISHING REPRESENTATIVE. j 1- PICK UP JUNK MILL BHA AS FOLLOWS: - 6 3/4" OD JUNK MILL - (4) 7" BOOT BASKETS - BIT SUB ' - DOUBLE PIN SUB - BIT SUB - (2) STRING MAGNET - 6 1/4" BUMPER SUB I I - 61/4" OIL JAR - PUMP -OUT SUB 1 I - (9) 6 1/4" DRILL COLLAR 1 1 1 - `XO' I OVERALL LENGTH = 350.07'. MAX OD = 6.75 ". - -T ' MIN ID = 1.5 ". 04:30 06:00 1.50 FISH C DECOMP RUN IN THE HOLE WITH THE JUNK MILL ASSY ON DRILL PIPE. - FROM 350' TO 7904' DPM. - UP WEIGHT = 167K LBS, DOWN WEIGHT = 132K LBS. Printed 5/25/2011 4:03:35PM • orth America - ALASKA - BP Page 12 of 18 Aeration Summary Report . Common Well Name: WGI -03 AFE No Event Type: WORKOVER (WO) I Start Date: 4/30/2011 End Date: 5/12/2011 X4- 00TLY -E: (2,709,000.00 ) , Project: Prudhoe Bay (various) I Site: WGI Rig Name /No.: NABORS 7ES Spud Date/Time: 9/5/1979 12:00:00AM Rig Release: 5/12/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292038500 Active Datum: 5 : 03 7/23/1997 00:00 @44.50ft (above Mean Sea Level) Date From - To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 07:00 1.00 FISH I C DECOMP rRUN IN THE HOLE AND MILL ON OBSTRUCTION. - ESTABLISH PARAMETERS: - 80 RPM AND 4.5K FT -LBS TORQUE. I I - 3 BPM AND 220 PSI. ! - 5 BPM AND 460 PSI. - UP WEIGHT = 167K LBS, DOWN WEIGHT 132K LBS. - ROTATING WEIGHT = 148K LBS. j - TAG TOP OF TUBING STUB AT 7964' DPM. CONTINUE IN THE HOLE AND TAG OBSTRUCTION AT 7969' DPM. 1 - DRY MILL ON OBSTRUCTION. ; - 80. RPM AND6K- 10K FT -LBS OF :TORQUE. , 1 - WEIGHT ON MILL= 1K - 4K LB. - MILL TORQUES UP AND STALLS OUT THE 1 TOP DRIVE. - 75K LB OVER PULL AFTER STALLING OUT. 1 07:00 - 09:00 2.00 ! FISH X ! WAIT 7,969.00 DECOMP T, CONSULT WITH ANCHORAGE ADW RWO I - PERSONNEL AND CIRCULATE A BOTTOMS ' UP. DISCUSS OPTIONS WITH RWO ENGINEER ' ! AND ANCHORAGE RWO MANAGEMENT. ' - MOST PROBABLE SCENARIO IS THAT ' THE ORIGINAL COMPLETION TALLY IS : INCORRECT. I - EVIDENCE INDICATES THAT THE 7 5/8" x I 7" 'XO' IS AT 7969'. - CIRCULATE AT 7 BPM AND 850 PSI. MONITOR THE WELL FOR 10 MIN. - NO FLOW. 09:00 - 11:30 I 2.50 FISH C , ! DECOMP PULL OUT OF THE HOLE WITH THE JUNK ; MILL BHA. - FROM 7969' TO 350' DPM. 1 11:30 - 13:00 1.50 FISH C ! I DECOMP LAY DOWN THE JUNK MILL BHA. ! 1/2 GAL OF METAL RECOVERED FROM THE MAGNETS. I - THE BOOT BASKETS WERE EMPTY. ! - THE WEAR PATTERN ON THE JUNK MILL i I !WAS SIMILAR TO THE WEAR PATTERN ON ' !THE 6 1/2" OD RCJB HEAD. Printed 5/25/2011 4:03:35PM ' orth America - ALASKA - BP ' - . Page 13 of 18 . • . peration Summary Report . . . , Common Well Name: WGI-03 I AFE No Event Type: WORKOVER (WO) I Start Date: 4/30/2011 I End Date: 5/12/2011 )(4-00TLY-E: (2,709,000.00 ) Project: Prudhoe Bay (various) [ WGI Rig Name/No.: NABORS 7ES I Spud Date/Time: 9/5/1979 12:00:00AM 1Rig Release: 5/12/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292038500 Active Datum: 5: 03 7/23/1997 00:00 @44.50ft (above Mean Sea Level) Date , From - To ' Hrs Task ' Code : NPT i NPT Depth Phase Description of Operations (hr) , (ft) , I 13:00 - 14:00 1.00 FISH C „ : DECOMP I PICK UP THE 6" OD RCJB BHA AND RUN IN „ , I THE HOLE. : I I „ : 1 - PJSM WITH RIG CREW AND BAKER FISHING I I REPRESENTATIVE. I „ I - PICK UP RCJB BHA AS FOLLOWS: 1 , - 6" OD RCJB I 1 , . - DOUBLE PIN SUB - (4) 4 3/4" BOOT BASKETS • 1 „ - BIT SUB 1 , • - DOUBLE PIN SUB - (2) 7" BOOT BASKETS • • - BIT SUB 1 „ . ' I - (2) STRING MAGNET -6 1/4" BUMPER SUB -6 1/4" OIL JAR , 1 - PUMP-OUT SUB - (9) 6 1/4" DRILL COLLAR , . . , I , OVERALL LENGTH = 363.90. MAX OD = 7.00". MIN ID = 0.875". 1 , , 14:00 - 17:00 3.00 FISH - C , DECOMP RUN IN THE HOLE WITH THE 6" OD RCJB ASSY. FROM 364' TO 7918' DPM. I ! : I : UP WEIGHT = 168K LBS, DOWN WEIGHT = ' , 130K LBS. — — ,- 17:00 - 19:00 2.00 FISH • C DECOMP DROP BALL TO ACTIVATE RCJB AND WASH 1 , . ' DOWN TO CLEAN SAND AND DEBRIS . . . , . - TAG TUBING STUB AT 7964' DPM. , • , 1 „ - TAG TOP OF SAND AT 7973' DPM. , . - CLEAN SAND AND DEBRIS FROM 7973' TO . , . , „ I 7978' DPM. . , - 10 BPM AND 1676 PSI. 1 l , , ! - 40 RPM AND 4K FT-LBS OF TORQUE ON AND OFF BOTTOM. , - UP WEIGHT = 168K LBS, DOWN WEIGHT = 130K LBS. 1 , - ROTATING WEIGHT = 150K LBS. , — 19:00 - 20:30 : 1.50 ' FISH C , DECOMP PULL OUT OF TUBING STUB. - PULL 50K LBS OVER AT 7 5/8" x &' X0 AT ! , , 7969' DPM. , - ATTEMPT TO JAR FREE WITH 60K LBS OVER PULL. - WORK PIPE AND ABLE TO WORK PAST 7969' WITH ROTATION. , . 20:30 - 22:00 1.50 : FISH C ' DECOMP ' CIRCULATE TO CLEAN WELL BORE. , I - CIRCULATE A 45 BBL HI-VIS SWEEP. , , ! , - 12 BPM AND 2270 PSI. - LITTLE TO NO SAND ACROSS SHAKERS. 22:00 - 23:30 ! 1.50 FISH C DECOMP CUT AND SLIP 75' OF DRILLING LINE. - SERVICE TOP DRIVE AND DRAWWORKS. 23:30 - 00:00 0.50 FISH C DECOMP PULL OUT OF THE HOLE WITH THE 6" OD RCJB LAYING DOWN DRILL PIPE. - FROM 7886' TO 7604' DPM. . , 5/10/2011 00:00 - 05:30 5.50 FISH C ' ' DECOMP CONTINUE TO PULL OUT OF THE HOLE WITH THE 6" OD RCJB LAYING DOWN DRILL PIPE. - FROM 7604 TO 364' DPM. Printed 5/25/2011 4:03:35PM • orth America - ALASKA - BP Page 14 of 18 Aeration Summary Report Common Well Name: WGI -03 AFE No Event Type: WORKOVER (WO) ' Start Date: 4/30/2011 End Date: 5/12/2011 X4- 00TLY -E: (2,709,000.00 ) Project: Prudhoe Bay (various) ' Site: WGI Rig Name /No.: NABORS 7ES Spud Date/Time: 9/5/1979 12:00:00AM Rig Release: 5/12/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292038500 Active Datum: 5 : 03 7/23/1997 00:00 @44.50ft (above Mean Sea Level) Date From - To Hrs Task I Code 1 NPT NPT Depth Phase Description of Operations (hr) (ft) T , LAY DOWN 6" OD RCJB BHA. 05:30 08:00 2.50 FISH C DECOMP - BALL AND SEAT WASHED OUT. REVERSE ' NOT ACTIVATED. ,- 1/2 GAL METAL AND RUBBER RECOVERED IN THE BOOT BASKETS. 08:00 - 09:30 1.50 I BOPSUR P DECOMP RIG UP TEST EQUIPMENT TO TEST BOPE. Printed 5/25/2011 4:03:35PM • orth America - ALASKA - BP Page 15 of 18 . • peration Summary Report Common Well Name: WGI-03 I AFE No Event Type: WORKOVER (WO) Start Date: 4/30/2011 I End Date: 5/12/2011 X4-00TLY-E: (2,709,000.00 ) L 1 Project: Prudhoe Bay (various) , Site: WGI Rig Name/No.: NABORS 7ES 1 Spud Date/Time: 9/5/1979 12:00:00AM Rig Release: 5/12/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292038500 Active Datum: 5: 03 7/23/1997 00:00 @44.50ft (above Mean Sea Level) Date 1 From - To Hrs 1 1 Task Code NPT NPT Depth I Phase 1 Description of Operations - 1 (hr) , 1 (ft) 09:30 - 20:30 11.00 I BOPSUR P DECOMP TEST BOPE PFR Ancr.c REG( II ATI('NS AND 1 BP ADWOP POLICY. - PRESSURE TESTED TO 250 PSI LOW / 4000 I , PSI HIGH FOR 5 CHARTED MINUTES. I , , - TESTED ALL CHOKE MANIFOLD VALVES 1 , . (16 TOTAL). - 2 FAIUPASS: - FLANGE UNDER VALVE 12 LEAKED. - RE-TIGHTENED AND RE-TESTED GOOD, - VALVE 12 LEAKED. - GREASED AND RE-TESTED GOOD. - MANUAL CHOKE AND MANUAL KILL VALVES. P e - HCR CHOKE AND HCR KILL VALVES. - HCR CHOKE CLOSED IN 1 SEC. - NCR KILL CLOSED IN 1 SEC. • - FULL OPENING SAFETY VALVES (4" & 5"). - 4" DART VALVE. - TOP DRIVE AIR ACTUATED IBOP. , , • - LOWER MANUAL IBOP ON TOP DRIVE. • - BLIND/SHEAR RAMS. - 1 FAIUPASS: . 1 - DOOR SEAL LEAKED. - RE-TIGHTENED AND RE-TESTED GOOD. - BLIND/SHEAR RAMS CLOSED IN 14 SEC. • - UPPER 7 5/8" RAMS WITH 7 5/8" TEST 1 , . JOINT. 1 , , , 1 - UPPER PIPE RAMS CLOSED IN 4 SEC. I 1 • - LOWER 3 1/2" x 6" VBRS WITH 4" TEST , I JOINT. , 1 1 - LOWER PIPE RAMS CLOSED IN 7 SEC. , I - TESTED THE ANNULAR PREVENTER WITH , , 1 4" TEST JOINT. , - 250 PSI LOW AND 3500 PSI HIGH FOR 5 , CHARTED MINUTES. , 1 . - ANNULAR PREVENTER CLOSED IN 40 SEC. - TESTED THE SUPER CHOKE. - 250 PSI LOW AND 4000 PSI HIGH FOR 5 CHARTED MINUTES. - TESTED THE MANUAL CHOKE - 250 PSI LOW AND 4000 PSI HIGH FOR 5 CHARTED MINUTES. - PERFORMED AN ACCUMULATOR DRAWDOWN TEST. - 16 SEC TO 200 PSI, 79 SEC TO FULL PRESSURE. -5 BOTTLES WITH 1950 PSI. - TESTED THE SIERRA GAS MONITORING , SYSTEM. - ALL TESTS WITNESSED BY BP WSL AND NABORS TOOLPUSHER. - AOGCC, BOB NOBLE, WAIVED THE STATE'S RIGHT TO WITNESS THE TEST. 20:30 - 21:30 1.00 BOPSUR P DECOMP LAY DOWN BOPE TEST EQUIPMENT AND 1 , BLOW DOWN ALL LINES. Printed 5/25/2011 4:03:35PM N orth America - ALASKA - BP Page -16 of 18 M erat ion Summary Report ort P rY P Common Well Name: WGI -03 I AFE No Event Type: WORKOVER (WO) I Start Date: 4/30/2011 I End Date: 5/12/2011 IX4- 00TLY -E: (2,709,000.00 ) ! Project: Prudhoe Bay (various) I Site: WGI Rig Name /No.: NABORS 7ES I Spud Date/Time: 9/5/1979 12:00:00AM Rig Release: 5/12/2011 Rig Contractor: NABORS ALASKA DRILLING INC. 1 UWI: 500292038500 Active Datum: 5 : 03 7/23/1997 00:00 @44.50ft (above Mean Sea Level) Date I From - To Hrs Task 1 Code ' NPT 1 NPT Depth I Phase Description of Operations (hr) I (ft) 21:30 - 00:00 2.50 RUNCOM P i RUNCMP RIG UP TO RUN THE 7 5/8" COMPLETION , 'WITH 7" JEWELRY. - MAKE DUMMY RUN WITH TUBING HANGER I AND MARK LANDING JOINT. - RIG UP 8 5/8" DOUBLE STACK TONGS W/ TORQUE TURN EQUIPMENT. - RIG UP COMPENSATOR AND SINGLE JOINT ELEVATORS. 5/11/2011 I 00:00 01:00 1.00 RUNCOM P RUNCMP ' CONTINUE TO RIG UP TO RUN THE 7 5/8" ;COMPLETION WITH 7" JEWELRY. I - RIG UP TORQUE TURN EQUIPMENT. , `- RIG UP SINGLE JOINT ELEVATOR AND COMPENSATOR. - MAKE UP SAFETY JOINT AND FOSV TO 'XO'. 01:00 - 14:30 T 13.50 RUNCOM • P RUNCMP I RUN IN THE HOLE WITH THE 75/8 ", 29.7 LB/FT, L -80, VAMTOP HC IPC COMPLETION WITH 7" JEWELRY. TO 7901' SLM. - UP WEIGHT = 250K LBS, DOWN WEIGHT = 185K LBS. - OPTIMUM TORQUE ON THE 7 5/8" = 14,450 I FT -LBS. :- OPTIMUM TORQUE ON THE 7" TCII L 'JEWELRY = 10,100 FT -LBS. 14:30 15:30 1.00 RUNCOM I P RUNCMP RIG UP THE 4" ELEVATORS AND MAKE UP THE LANDING JOINT TO THE TUBING ' HANGER. ,15:30 16:30 1.00 RUNCOM I P i ! RUNCMP LAND THE 7 5/8" COMPLETION. I UP WEIGHT = 250K LBS, DOWN WEIGHT = ! 1 185K LBS. WIRE LINE ENTRY GUIDE AT 7931'. CAMERON REPRESENTATIVE RAN IN THE LOCK DOWN SCREWS. 16:30 19:30 3.00 RUNCOM j P RUNCMP I !, REVERSE IN HEATED BRINE AND CORROSION INHIBITED BRINF I - REVERSE IN 375 BBLS OF 120 DEG F, 9.8 PPG BRINE. - REVERSE IN 130 BBLS OF CORROSION INHIBITED BRINE. - 3 BPM AND 235 PSI. 19:30 - 22:00 I 2.50 , RUNCOM P RUNCMP REVERSE IN HEATED DIESEL FREEZE PROTECT. RIG UP LITTLE RED HOT OIL SERVICE. - PRESSURE TEST LINES TO 3000 PSI. REVERSE IN 40 BBLS OF 70 DEG F DIESEL. - 1.5 BPM, FINAL CIRCULATING PRESSURE = 425 PSI. - U -TUBE DIESEL. - PICK UP LANDING JOINT AND DROP BALL & ROD. Printed 5/25/2011 4:03:35PM North America - ALASKA - BP P age 17 of 18 Q"peratiou Summary Report Common Well Name: WGI -03 AFE No Event Type: WORKOVER (WO) Start Date: 4/30/2011 End Date: 5/12/2011 X4- 00TLY -E: (2,709,000.00 ) Project: Prudhoe Bay (various) . Site: WGI Rig Name /No.: NABORS 7ES r Spud Date/Time: 9/5/1979 12:00:00AM Rig Release: 5/12/2011 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292038500 1 Active Datum: 5 : 03 7/23/1997 00:00 @44.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations 22:00 00:00 2.00 RUNCOM P RUNCMP - SET THE 7" x 9 5/8" BAKER 'S3' PACKER AND 'TEST THE IA AND TUBING. 1 - PRESSURE UP ON THE TUBING TO 4000 PSI AND HOLD FOR 30 CHARTED MIN. - PACKER FULLY SET AT 3000 PSI. - LOST 55 PSI IN THE FIRST 15 MIN. - LOST 25 PSI IN THE SECOND 15 MIN. - LOST 1.8% OF TOTAL PRESSURE OVER THE 30 MIN TEST. - GOOD TEST. BLEED OFF TUBING TO 1500 PSI. . ! - PRESSURE UP ON THE IA TO 4000 PSI FOR 30 CHARTED MIN. - LOST 189 PSI OVER THE FIRST 15 MIN. ' - LOST 72 PSI OVER THE SECOND 15 MIN. I LOST 6.4% OF TOTAL PRESSURE OVER THE 30 MIN TEST. , - GOOD TEST. - DISCUSSED PRESSURE TEST RESULTS WITH RWOWTL. - SEE ATTACHED TEST RESULTS. 5/12/2011 00:00 - 00:30 0.50 RUNCOM 1 P RUNCMP ' RIG DOWN AND BLOW DOWN TEST —+ EQUIPMENT. 00:30 - 01:00 0.50 RUNCOM P RUNCMP RIG UP DUTCH RISER. - UNABLE TO CONNECT DUTCH RISER TO LUBRICATOR DUE TO HEIGHT ' 1 CONSTRAINTS. . 1 - NEED THE QUICK TEST SUB TO INSTALL LUBRICATOR. 01:00 - 01:30 0.50 RUNCOM N WAIT RUNCMP WAITING FOR DSM TO BRING OUT THE QUICK TEST SUB. 01:30 04:00 2.50 RUNCOM P RUNCMP INSTALL TWC WITH DUTCH RISER AND !HYDRAULIC LUBRICATOR. - NIPPLE UP THE DUTCH RISER WITH THE QUICK TEST SUB. - NIPPLE UP THE HYDRAULIC LUBRICATOR AND TEST. - 250/4000 PSI FOR 5 CHARTED MIN. I GOOD TEST. - INSTALL TWC AND TEST FROM ABOVE. - 250 PSI FOR 5 CHARTED MIN. I - 4000 PSI FOR 10 CHARTED MIN. - GOOD TEST. - RIG DOWN LUBRICATOR AND DUTCH RISER. ' 04:00 - 06:30 2.50 BOPSUR P RUNCMP NIPPLE DOWN THE BOPE. ' - BLOW DOWN ALL LINES TO THE STACK AND PITS. - DRAIN STACK. PJSM WITH RIG CREW FOR NIPPLING . DOWN BOPE. ' - NIPPLE DOWN BOPE AND STAND BACK. 06:30 07:00 0.50 WHSUR P RUNCMP NIPPLE UP TREE IN CELLAR. - PJSM WITH RIG CREW AND CAMERON ' REPRESENTATIVE. - HANG TREE WITH BRIDGE CRANE IN CELLAR. - ADAPTER FLANGE WAS SENT BACK TO STORES BY MISTAKE. 07:00 - 07:30 0.50 WHSUR N WAIT RUNCMP LOCATE AND MOBILIZE THE ADAPTER FLANGE. Printed 5/25/2011 4:03:35PM • orth America - ALASKA - BP - Page 18 of 18 Aeration Summary Report W Common Well Name: WGI -03 I AFE No Event Type: WORKOVER (WO) Start Date: 4/30/2011 End Date: 5/12/2011 X4- 00TLY -E: (2,709,000.00 ) Project: Prudhoe Bay (various) I Site: WGI Rig Name /No.: NABORS 7ES Spud Date/Time: 9/5/1979 12:00:00AM I Rig Release: 5/12/2011 Rig Contractor: NABORS ALASKA DRILLING INC. i UWI: 500292038500 Active Datum: 5 : 03 7/23/1997 00:00 @44.50ft (above Mean Sea Level) Date From - To Hrs Task I Code NPT NPT Depth Phase Description of Operations k ft P RUNCMP i NIPPLE UP TREE AND ADAPTER FLANGE. (hr) - (ft) 07:30 09:00 i 1.50 WHSUR �, PJSM WITH RIG CREW AND CAMERON REPRESENTATIVE. ;- NIPPLE UP ADAPTER FLANGE. — _ _ T - NIPPLE UP TREE. 109:00 - 12:30 3.50 WHSUR P E. RUNCMP I PRESSURE TEST HANGER VOID AND TREE I - FILL TREE WITH DIESEL. I- TEST ADAPTER FLANGE AND CHART WITH CAMERON'S DIGITAL RECORDER. - 250 PSI LOW FOR 5 MIN. - 5000 PSI HIGH FOR 30 MIN. - BOTH TESTS WERE GOOD. - TEST TREE AND CHART WITH RIG CHART . I ' ' ' RECORDER. ' - 250 PSI LOW FOR 5°MIN. - 5000 PSI HIGH FOR 30 MIN. _ - BOTH TESTS WERE GOOD. 12:30 - 14:00 1.50 WHSUR ' P , ' RUNCMP 1SECURE TREE AND CELLAR - INSTALL VALVES AND GAUGES ON TREE. I- SECURE TREE AND CELLAR. ** RELEASE RIG AT 14:00 ** RIG DOWN MOVE OF TO F -14 Printed 5/25/2011 4:03:35PM TREE= • 6 -3/8" CNV SAFETY NOTES: WELL REQUIRES A SSSV. POST 2006 7" MULE SHOE & 7-5/8" TBG WELLHEAD .= CNV w G N UB. i ®3 S D TO SURFACE ASS G ACTUATOR= AK BER KB. ELEV = 30' o ` I '.k ' LARC BF. ELEV = PJC DRAFT , ;4« 28' 1-17" X 7 -5/8" XO, ID = 6.276" KOP= 3150' *M 1s Max Angle 42° @9500' *4 . N Datum MD = 10014 ∎•` • V 2175' H7" CAMCO DB -6 NIP, ID = 6.000" I Datum TVD = 8800 SS ii• A �, . 2177' x-17" X 7 -5/8" XO, ID = 6.276" I 7 -518" TBG, 29.7 #, L -80 VAM TOP HC, 2174' ,,. 't 2208' 1- 19 -5/8" HES ES CEMENTER, ID = 8.861" I .0459 bpf, ID = 6.875" 7" TBG, 26 #, L -80 TCII, .0383 bpf, ID = 6.276" H 217T 9-5/8" CSG, 47 #, L -80 TCII TIEBACK, -I 2223' I 7759' H7-5/8" X 7" XO, ID = 6.276" I ID= 8.681" 13 -3/8" CSG, 72 #, N -80, ID = 12.347" I-J 2723' 7814' H7" HES R NIP, ID = 5.963" 7 -5/8" TBG, 29.7 #, L -80 VAM TOP HC, -I 7759' .0459 bpf, ID = 6.875" ��� 7845' 9 -5/8" X 7" BKR S -3 PKR, ID = 6.040" I Minimum ID = 4.843" @ 8160' 1 7877' 1-17" HES RN NIP, ID = 5.770" I BAKER SHEAROUT SUB N---, 7931' I -I 7" WLEG, ID = 6.276" I 7" TBG, 26 #, L -80 TCII, .0383 bpf, ID = 6.276" H 7931' I 7 -5/8" TBG STUB (02/19/06) H 7959' MD I 7992' H7-5/8" X 7" XO, ID = 6.276" I 7 -5/8" TBG, 29.7 #, NT -95 STL, -I 7992' / ^- .0459 bpf, ID = 6.875" 7993' 119 -5/8" X 7" BKR KBH-22 ANCHOR & SABL PKR, 6.00" 8008' I-{ 7" HES RN NIP, ID = 5.500" I 7" TBG, 26 #, L -80 NSCC, .0383 bpf, ID = 6.276" 1-I 8017' - $017' H7" WLEG, ID = 6.276" I I∎M 81 4 5 ' - 19 -5/8" X 7" BKR SB -2 PKR I 7" TBG, 29 #, N -80 AMB 8RD, 8161' \ = 8160' ,-17" BKR SHEAROUT SUB, ID = 4.843" I .0371 bpf, ID = 6.184" TOP OF 7" LNR 8255' 8161' I--17" TUBING TAIL, ID = 6.276" I 2: 8146' IH ELMD TT LOGGED 09/26/79 I 9 -5/8" CSG, 47 #, N -80, ID = 8.681" H 8569' PERFORATION SUMMARY REF LOG: BHCS ON 09/20/79 ANGLE AT TOP PERF: 39° @ 9045' ' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE I 3 -3/8" 4 9046 -9119 0 03/02/87 ' 3 -3/8" 4 9137 -9259 0 03/02/87 3 -3/8" 4 9281 -9352 0 03/02/87 3 -3/8" 4 9365 -9387 0 03/02/87 , 3 -3/8" 4 9413 -9471 0 03/02/87 3 -3/8" 4 9485 -9521 0 03/02/87 I 3 -3/8" 4 9534 -9559 0 03/02/87 I 3 -3/8" 4 9570 -9580 0 08/18/80 I PBTD H 9627' I '•♦•fff1 7" LNR, 29 #, N -80, .0371 bpf, ID = 6.184" I-I 9670' i �i � i�• * a * i: DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/26/79 PKR 141 ORIGINAL COMPLETION WELL: WGI-03 11/16/97 016 RWO PERMIT No: 1790490 03/19/06 N4ES RWO API No: 50- 029 - 20385 -00 05/12/11 N7ES RWO SEC 11, T11 N, R14E, 494' FNL & 1160' Fa_ 05/27/11 PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) • • Page 1 of 1 Regg, James B (DOA) From: Sarber, Greg J [SarberJG @BP.com] '3t,& w -o-3 Sent: Wednesday, May 04, 2011 4:05 PM P - i 4'7 - u4 To: DOA AOGCC Prudhoe Bay Cc: Daniel, Ryan; Kilfoyle, Jeffery A; Bjork, David; Smart, John C; Rossberg, R Steven; Cismoski, Doug A; Sheffrey, Tom (Fircroft) Subject: BOP Usage on Nabors 7ES May 3, 2011 Attachments: AOGCC BOP Use Reporting.Nabors 7ES.5- 4- 2011.doc All, Attached you will find a description of use of the BOPE on Nabors 7ES to circulate gas from the wellbore. The gas is suspected to be packer gas, which is from behind a tailpipe below a packer. This was encountered while conducting a rig workover on WGI -03. Please contact me if you should need additional information Sincerely, Greg Sarber Greg Sarber Operations Superintendent RWO /CTD +1 (907) 659 -5329 (Office - slope) +1 (907) 242 -8000 (Cell Phone) Harmony 2157 F Alternate: Jim Willingham . ,; MAY I ZO O 5/9/2011 • • Blow Out Preventer Equipment ( BOPE ) Usage Report to the AOGCC The purpose of this document is to ensure timely reporting to the AOGCC of any BOPE use to prevent the flow of fluids from a well. Field Superintendent Name: Greg Sarber Wellsite Leader Name: Duncan Ferguson Contact Number: 659 5329 Contact Number:659 4835 Traction Number: 3834184 Well Location /Name & Rig Name: WGI -03. Rig Nabors 7ES - Permit To Drill (PTD) Number:179 -049 / Date and Time of Incident: 3 May 2011 17:00 hrs - Original Scope of Work: The rig is performing a workover on WGI -03 in the Greater Prudhoe Bay Area. The scope of the work was to swap the tubing string. The rig moved on the well, nippled up And tested BOP's. They checked the well for flow, and it was dead. Prior to rig arrival the well had Been secured with a downhole plug and loaded with seawater and diesel. The operation the rig was Involved with was RIH with multi string cutter on 4" drill pipe. The BHA was 12 joints of drill pipe in the hole at 409' Operational Description Leading up to Well Control Event: The rig noticed an increase in flow, bubbling in the hole at surface. 12 bbls of fluid was taken to the Rig pits. BOPE Used and Reason: Annular was closed per BP Well Control RP. Lou Grimaldi of AOGCC notified. The shut in pressure On the wellhead stabilized at 90 psi after 1 hour shut in. Gas is suspected to be from under the production packer at 7907' and not from the reservoir as there is a PRN plug set at 8008'. Is a BOPE Test Required after use ( Yes / No): If no, why? Yes. BOP will be tested when next out of the hole. 24 hour notice required to NS AOGCC Inspectors prior to testing BOPE components. Plan Forward: After talking with AOGCC inspectors on the slope, bleed off the 90 psi gas. Flow check the well. POH with cutter BHA. MIT tubing and IA to confirm integrity of PRN plug and production packer. RIH with open ended mule shoe on 4" drill pipe to tubing tail pipe at 7955'. Circulate and displace tubing to clean 9.8 ppg brine. POH and test BOP. Additional Comments: As of 16:00 hours on May 4, 2011 the rig was staging in the hole in 500' intervals. They were Circulating bottoms up at each stage and getting a small amount of gas that quickly dissipated. They -- Plan to continue to the bottom of the tail pipe at 7955'. Email to AOGCC North Sloe Inspectors within 24 hours of the incident: doa.ao.cc..rudhoe.ba • alaska.•ov Email CC List BP WSL Harry Engel Wells Team Leader Jeff Kilfoyle Engineering Team Leader Operations Drilling Engineer- Well File Wells Operations Manager Drilling & Completions Engineer Manager Wells Intervention Manager BOPE Usage Report for AOGCC Rev 1 September 1, 2010 HRE 1 • • • SITATE [1 ALASKA SEAN PARNELL, GOVERNOR �T ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 David Reem Engineering Team Leader BP Exploration (Alaska), Inc. 1 T P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU WGI -03 Sundry Number: 311 -094 Dear Mr. Reem: $Iii,NNED APR 6 4 201' Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, AO,/ Daniel T. Seamount, Jr. Chair DATED this day of March, 2011. Encl. • RECEIVED . • STATE OF ALASKA r- . ALASKA_ AND GAS CONSERVATION COMMIS* �C't MAR 2 4 1;j ... W. APPLICATION FOR SUNDRY APPROVAL i ' .s.50-' ' 1 20 AAC 25.280 , . ka 011 & Gas Cons. C i ; 1. Type of Request: Anchorage Perforate New Pool - Repair Well Change Approved Pro ❑ Abandon ❑Plug for Redrill ❑ ® p ❑ g pp Program 9 ❑ Suspend ❑ Plug Perforations ❑ Perforate , ® Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Development ❑ Exploratory 179 -049 3. Address: - ® Service ❑ Stratigraphic 6. API Number. P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 20385 -00 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU WGI -03- Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028302 ' Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9672' - 8577' - 9627' 8543' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 78' 78' 1530 520 Surface 2723' 13 -3/8" 2723' 2723' 4930 2670 Intermediate 8569' 9-5/8" 8569' 7724' 6870 4760 Production Liner 1415' 7" 8255' - 9670' 7468' - 8575' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9046' - 9580' 8105' - 8509' 7 -5/8 ", 29.7# x 7 ", 26# / 29# L -80 / NT95 7955 a 7959' - 8011' & 8145 - 8161' Packers and SSSV Type: 9-5/8" x 7" Baker 'SB -2' packer Packers and SSSV 8145' MD / 7379' TVD 9-5/8" x 7" Baker 'SABL' packer MD (ft) and TVD (ft): 7993' MD / 7255' TVD 9-5/8" x 7" Baker 'S -3' packer 7907' MD / 7184' TVD 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Development - ∎_ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 10, 2011 ❑ 011 ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas - ® GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Bjork, 564 -5683 Printed Name ° "'David R em Title Engineering Team Leader Prepared By Name/Number. Signature -- / Phone 564 - 5743 Date • `Ly�ZCt/ Elizabeth Barker, 564 -5674 Commission Use Only Conditions of approval: Ncliy Commission)o that a representative may witness d3 w-�U Sundry Number _dig ❑ Plug Integrity Mit OP Test 110 Mechanical Integrity Test ❑ Location Clearance 4 /60 0 1 > Si Boo h� ' -/--;:s " Other. >E Z $ DO t ' /4.4%.4-14..--t, 'f 6.....:....) f QG6.. P la a rise '� - lero ""j t evo� Zo AAC Z ST y /L C b Subsequent Form Required: /Q — Li a 1 APPROVED BY Approved By: / / COMMISSIONER THE COMMISSION Date 3/1 liw Form 10-403 Relgl O 1 APR 0 4_ 2011 3. ` ►-{ G Y Submit I� Duplicate w�7 1 /( • • �bp Gjit WGI -03 Rig Workover Scope of Work: Repair TxIA communication. Pull 7 Tubing. Mill and retrieve the packer. Install new 7 - injection completion. MASP: 2,460 psi Well Type: Gas Injector Estimated Start Date: May 10 2011 Production Engineer: Bob Chivvis Intervention Engineer: David Bjork Pre -rig prep work: S 1 Set a 5 - RN plug at 8,008' MD. Cover with sand to 7,955'MD. F 2 Fluid Pack T /IA/OA with 9.8 -ppg brine and CMIT -T x IA to 4,000 psi. MIT -OA to 2,000psi. Record LLR as necessary. W 3 Check the tubing and casing 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. ✓ 4 Set a BPV in the tubing hanger. Secure well. O 5 Remove the wellhouse & flow line. Level the pad as needed for the rig. Proposed Procedure: 1. MIRU Nabors 7ES. ND tree. NU 4 Preventer BOPE with annular, 7 - / fixed rams, blind / shears, V mud cross and 3 - x 6" VBR's. Pressure test the 7- fixed, blind rams and VBR's to 4,000 psi, annular to 3,500 psi. 2. RIH with multi- string cutter on drill pipe. Cut the tubing in the first pup on top of the packer. Circulate' out freeze protection fluid and circulate well to 9.8 -ppg brine. 3. Pull and LD 7 - / tubing string from cut. • 4. Mill and retrieve the upper packer. Clean out sand. • 5. Run 7 - / 29.7# L -80 VamTopHC IPC injection completion with DB-6 SVLN. 6. Displace the IA to completion fluid, freeze protect and set the packer. 7. Test tubing and IA to 4,000 psi. 8. Set TWC. ND BOPE. NU and test tree. RDMO. Post -riq work: S 1 Pull isolation sleeve, Pull Ball -n -Rod, pull RHC seat, pull RN plug, set A -1 injection valve. L 6 -24.° F 2 Post RWO AOGCC MIT -IA OCs) - gy p C C 74C / 4 �� �l uS 1 r L (.12 4 7 h �-1 / K, 2 . 3.2 ?_•r • ' TREE= `6 -3/8" CAMERON SAFETY : WELL REQUIRES A SSSV. POST 2006 • ACTUATOR = BAKER I -O S UB. 4' OA�SFULLLY /CLASSG KB. ELEV = 49' LARC BF. ELEV = •,• 4. 1 22' I-17" X 7 -5/8" XO, ID = 6.184" I KOP= 3150' ∎.1 •• Max Angle = 42 @ 9600' '•∎ 4 Datum MD = WA �1•� •A' 2201' H 7 -5/8" X 7" XO, ID = 6.184" I Datum TV D = �'• 14' 4., 2208' H 9 -5/8" HES ES CEMENTER, ID = 8.861" I ∎4 • 4 4• 1 2212' H 7" CAMCO DB -6 NIP, ID = 6.000" I •• .' I9 -5/8" CSG, 47 #, L -80 TCII TIEBACK, ID = 8.681" H 0' - 2223' ' t• 1 2223' 1-1 7" X 7 -5/8" XO, ID = 6.184" i 13 -3/8" CSG, 72 #, N-80, ID = 12.347" H 2723' -79 c �-, r- (-O4 . 4-" --roc � 17 -5/8" TBG, 29.7 #, L -80 IPC, .0459 bpf, ID = 6.875" 1-1 7875' I 1 7875' I- I7 -5/8" X 7" XO, ID = 6.184" 1 1 7886' H 7" HES R NIP, ID = 5.963" I Minimum ID = 4.843" @ 8160' * M I ► _ 7907' 1 -19 -5/8" X 7" BKR S -3 PKR, ID = 6.080" I BAKER SHEAROUT SUB I 7931' H 7" HES RN NIP, ID= 5.770" I 17" TBG, 29#, L -80 TCII, .0371 bpf, ID = 6.184" H 7955' 1 1 79' I-1 7" FULL MULESHOE WLEG, ID = 6.184" I 1 7959' MD H 7 -5/8" TBG STUB (02/19/06) I 7 -5/8" TBG, 29.7 #, NT -95, .0459 bpf, ID = 6.875" H 7992' I 7992' 1- -17 -5/8" X 7" XO I ►mot ►� 7993' H 9 -5/8" X 7" BKR SABL PKR 1 L 8008' H 7" HES RN NIP, ID = 5.5" I I7" TBG, 26#, L -80, .0383 bpf, ID = 6.276" H 8017' 1 1 8017' 1 -17" TUBING TAIL WLEG I ►MI g 8145' - 19 -5/8" X 7" BKR SB -2 PKR I 8160' H7" BKR SHEA ROUT SUB, ID = 4.843" I 17" TBG, 29 #, L -80, .0371 bpf, ID= 6.184" I-J 8161' 1 ■ 1 8161' F-1 7" TUBING TAIL I I TOP OF 7" LNR H 8255' 1 1 8146' H ELMD TT LOGGED 09/26/79 1 1 9 -5/8" CSG, 47 #, N-80, ID = 8.681" H 8569' 1 • PERFORATION SUMMARY I REF LOG: BHCS ON 09/20/79 ANGLE ATTOPPERF: 39 @ 9045' I Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 4 9046 -9119 0 03/02/87 I 3 -3/8" 4 9137 -9259 0 03/02/87 3 -3/8" 4 9281 -9352 0 03/02/87 3 -3/8" 4 9365 -9387 0 03/02/87 I 3 -3/8" 4 9413 -9471 0 03/02/87 3 -3/8" 4 9485 -9521 0 03/02/87 3 -3/8" 4 9534 -9559 0 03/02/87 3 -3/8" 4 9570 -9580 0 08/18/80 1 PBTD H 9627' 1 ••••■ 17" LNR, 29#, N-80, .0371 bpf, ID = 6.184" 1-1 9670' • • •• ' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/26/79 ORIGINAL COMPLETION 11/20/07 DSMISV TREE C/O (10/30/07) WELL: WGI-03 11/16/97 RWO 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE PERMIT No: '1790490 03/19/06 N4ES RWO API No: 50- 029 - 20385 -00 03/23/06 DRC/TLH DRLG DRAFT CORRECTIONS SEC 11, TI1N, R14E, 58.42' FEL & 2446.15' FNL 03/29/06 DAV /PJC NIP CORRECTION @ 2212' 04/01/06 JRP/PJC PULL PLUG @ 2212' BP Exploration (Alaska) • TREE= '6 -3/8" CAMERON SAFETY NOTES: WELL REQUIRES A SSSV. POST 2006 AE TUA OR= BAKER I_03 ST B. /CLASS G KB. ELEV = 49' Proposed RWO LARC BF. ELEV = ��� KOP = 3150' 1.4 .0 Max Angle = 42 © 9600' ■.i , Datum MD = N/A o.� �4 Datum TVD = # ` #: 2208' H9-5/8" HES ES CEMENTER, ID = 8.861" ■•o I.�• ii i 4 -2212 H 7' 61 [ 6000' 9 -5/8" CSG, 47 #, L -80 TCII TIEBACK, ID = 8.681" H 0' - 2223' , �� A -2223 H7' X7-68' 0 =6184' I 13 -3/8" CSG, 72 #, N -80, ID = 12.347" I--I 2723' 7 - 6 8 ' II:Q 2 9 7 # , LEO F Q .C)1531# D=6875' — - 7 , 8 3 s N - 7 , 8 - 7 -56 XT XO X6184' I I —7,846' —f" HES I-t NIP, IU = 5.963" I Minimum ID = 4.843" @ 8160' X I — 7,877' H9 -5/8" X 7" BKR S -3 PKR, ID= 6.080" I BAKER SHEAROUT SUB I _7 H7" HES RN NIP, ID= 5.770" I I 7" TBG, 29 #, L -80 TCII, .0371 bpf, ID = 6.184" H - 7,955' I 7 — 7' R1L 1=6184' � i -ow i dl.2 a i UM tUU iaiUni I 7 -5/8" TBG, 29.7 #, NT 95, .0459 bpf, ID = 6.875" 1 7992' l 7992' I-17-5/8" X 7" XO I 7993' H9 -5/8" X 7" BKR SABL PKR I I I 8008' 1-1 7" HES RN NIP, ID = 5.5" I 7" TBG, 26 #, L -80, .0383 bpf, ID = 6.276" I-1 8017' I / \ 8017' 1-17" TUBING TAIL WLEG I g 8145' H9-5/8" X 7" BKR SB -2 PKR I — 8160' 1-17" BKR SHEA ROUT SUB, ID = 4.843" I 7" TBG, 29 #, L -80, .0371 bpf, ID = 6.184" I—I 8161' I / \ 8161' 1-17" TUBING TAIL I TOP OF 7" LNR H 8255' I I i 8146' H ELMD TT LOGGED 09/26/79 I 9 -5/8" CSG, 47 #, N-80, ID= 8.681" N 8569' I 4 • PERFORATION SUMMARY I REF LOG: BHCS ON 09/20/79 ANGLE AT TOP PERF: 39 © 9045' I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 4 9046 -9119 0 03/02/87 I 3 -3/8" 4 9137 -9259 0 03/02/87 3 -3/8" 4 9281 -9352 0 03/02/87 3 -3/8" 4 9365 -9387 0 03/02/87 I 3 -3/8" 4 9413 -9471 0 03/02/87 3 -3/8" 4 9485 -9521 0 03/02/87 3 -3/8" 4 9534 -9559 0 03/02/87 3 -3/8" 4 9570 -9580 0 08/18/80 PBTD H 9627' I ••••■ 181 A ., 7" LNR, 29 #, N-80, .0371 bpf, ID = 6.184" H 9670' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/26/79 ORIGINAL COMPLETION 11/20/07 DSM/SV TREE C/O (10/30/07) WELL: WGI-03 11/16/97 RWO 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE PERMIT No: 1790490 03/19/06 N4ES RWO API No: 50- 029- 20385 -00 03/23/06 DRC/TLH DRLG DRAFT CORRECTIONS SEC 11, T11 N, R14E, 58.42' FEL & 2446.15' FNL 03/29/06 DAV /PJC NIP CORRECTION @ 2212' 04/01/06 JRP /PJC PULL PLUG @ 2212' BP Exploration (Alaska) • • WELL LOG _ s TRANSMITTAL PROAcriVE Diagnostic SERVICES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2 -1 i` t°;' O 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. ° g -64(9 Attn: Robert A. Richey 130 West International Airport Road 906Vei Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Leak Detection - WLD 29 -Nov-10 WGI -03 BL / EDE 50 -029- 20385 -00 2 ) 7 k„; Signed : Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PRONE: (907)245 -8951 FAx: (907)245 -88952 E-MAIL : pdsanchorage nlemoryIoq.cOrn WESSITE : vvww.memoryiochcom C:\Documents and Settings\Diane WilliamsTesktop \Transmit BP.doo, • MEMORANDUM TO: Jim Regg ~~~~~ L~ ~ l 6 ~ C ~ P.I. Supervisor FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, Apri107, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) II1C WGI-03 PRUDHOE BAY UNIT WGI-03 Src: Inspector NON-CONFIDENTIAL Reviewed Bye. P.I. Suprv ~~ Comm Well Name: PRUDHOE BAY UNIT WGI-03 API Well Number: 50-029-20385-00-00 Insp Num: mitJCr100208160501 Permit Number: 179-049-0 Rel Insp Num: MITOP000002940 Inspector Name: John Crisp Inspection Date: 2/5/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well WGI-03 " Type Inj. CT' TVD~ 7184 ~ IA 780 4450 ' 4220 4160 ' P.T.D 1790490 TypeTest SPT Test psi 1796 OA 0 0 0 0 Interval REQvAR p/F P - Tubing 2s6o 2sso 2sso 2sso , Notes: 3.3 bbls pumped for test. No problems witnessed. OA cemented to surface. ~y },~ ~~ ~' .. Wednesday, April 07, 2010 Page 1 of 1 0 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg @alaska.gov; phoebe.brooks @alaska_gov: tom.maunder@alaska.gov; doa .aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT I PAD: Prudhoe Bay / PBU / WGI pad DATE: 02/05/10 OPERATOR REP: Torin Roschinger AOGCC REP: John Crisp �. Packer Depth Pretest Initial 15 Min. 30 Min. W Type Inj. G TVD 7,184' Tubing 2,560 2,880 2,880 2,880 Interval V P.T.D. 1790490 Type test P Test psi 1796 Casing 780 4,450 4,220 4,160 P/F P Notes: MIT -IA to 4450 psi for 2 -year AA compliance testing OA 0 0 0 0 with tubing loaded. Well WGI -08 Type Inj. G TVD 7,603' Tubing 3,700 3,700 3,700 3,700 Interval 4 P.T.D. 1900490 Type test P Test psi 1900.75 Casing 240 2,500 2,500 2,520 P/F P Notes: MIT -IA to 2500 psi for 4-year compliance testing OA 0 0 0 0 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes 0 = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle 1= Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover I W = Water D = Differential Temperature Test O = Other {describe in notes) MIT Report Form . 8FL 11/27/07 MIT PBU WGI-03 08 02- 05 -10xis WGI-03 (PTD# 1790490) Reques~r AOGCC MITIA extension • Page 1 of 2 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, January 11, 2010 11:45 AM ~~~, ~ ~ t i I ~ ~ ~ To: NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA); ~A AOGCC Prudhoe Bay Subject: RE: WGI-03 (PTD# 1790490) Request for AOGCC MITIA extension Thank you. I appreciate the TIO plot sent with the earlier email which indicates there has been no change in the IA repressure rate, which remains very slow. Based on the requirements of AIO 4E.027 -namely submittal of a monthly TIO pressure plot, and requirement for immediate shut-in and notice to the Commission if there is any change in the well's mechanical condition - I think the best approach is to delay the 3700psi MIT until repairs are completed (I don't see any particular value in testing to the lower pressure}. Please note that this is a one time exception and will not change the anniversary due date for future MITs at PBU WGI-03. If repairs to the NGI lines take longer than mid-February to complete, please notify us for additional review; otherwise, notify the Commission Inspector on the Slope for opportunity to witness the AIO 4E.027-complaint MIT. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 Jn~ ~ ~~ 2Q~ From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Monday, January 11, 2010 11:27 AM To: Regg, James B (DOA); NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: RE: WGI-03 (PTD# 1790490) Request for AOGCC MITIA extension Jim, The work started 11/19/09 and should be complete mid-February. The gas constraint is due to the NGI wells being down for lines repairs. The amount of production everyday is dependent on how much gas we inject. When the gas injectors go down there is no place to put all the gas being produced so high GOR producers have to be shut-in. This is what we call being "gas constrained." The concern is that if WGI- 03 is shut-in, oil production will be impacted further. I hope this helps. Torin From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, January 11, 2010 10:52 AM To: NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: RE: WGI-03 (PTD# 1790490) Request for AOGCC MITIA extension When did work start on NGI lines, and when is work expected to be completed? Please explain the "present gas constraint". Jim Regg ./ 1/11/2010 WGI-03 (PTD# 1790490) Reques~r AOGCC MITIA extension ~ Page 2 of 2 AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Sunday, January 10, 2010 4:47 AM To: Regg, James B (DOA); Brooks, Phoebe L (DOA) Subject: WGI-03 (PTD# 1790490) Request for AOGCC MITIA extension Jim/Phoebe, Well WGI-03 (PTD #1790490) is currently due for UIC compliance testing on 01/17/10. WGI-03's Administrative Approval (4E.027) states that the MITIA is to be performed to the maximum anticipated injection pressure which is around 3700 psi. Taking the MITIA to these pressures will require the well to be secured which creates a challenge with the present gas constraint. We are currently undergoing flowline repairs that support NGI-Pad and will continue over the next couple weeks. I am asking permission to follow the AOGCC MIT guidelines and pressure test WGI-03 to .25psi/ft x TVD of the packer or forgo the witnessed MITIA until the NGI lines are repaired. This will help reduce the impact of having to shut-in another gas injector. Please advise how you would like us to move forward. Any suggestions will be greatly appreciated. I have attached the TIO plot and AA for your reference. «WGI-03 TIO Plot 01-09-10.doc» «WGI-03 Admin Approval aio4e-027.pdf» Please call with any questions Thank ou ~ ~°'~~~~` ~~ Y Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 1/11/2010 PBU WGI-03 (PTD # 1790490) TIO Plot AA 4E.027 for Tx1A comm a,DOo a,DDD ~ ~d~~~ s 2,000 1,000 10J1N09 10./17!09 10!24!09 10!31!03 11/07!09 11 /1Ci09 11!21/09 11!28!09 12f05J09 12J12/D9 12/19!09 12126,'09 D1J02J10 01!09!10 -~ Thg --E-- IA -~ OA OOA -+ OOOA 0n S I~IfElL LOG TRAIVSMlTTAL ProActive Diagnostic Services, Inc. U To: AOGCC Christine Mahnken 333 W. 7th Ave suite ~ 00 Anchorage, Alaska 99501 (907j 793-1225 ~~~~ ~~~ ~ ~ zaps RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspecton~Caliper / M7T) The technics! data listed below is being submitted herewrth. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastuflca LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ~~. tag -cS~l9 *~ r59 33 ProActive Diagnostic Services, Inc. Attu:.-Robert-A.- Riche 1"SO West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Leak Detectection - WLD 04Fetr08 2) WGI-03 Signed Print Name: (r~ (,j,~,,,,~~~ „- /~fc~lt~,~ - Y ~. ~ _. Date a= ~ ~~ '4` i~1(? PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD Sufl'E C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)2458952 E-alAi~ : pdsanchoragela rrtemorylog.com WEBSITE : www.memmr/lop.~om D:1Master_Copy_00_PDSANC•ZO~oc\Z Word\Distnbution\Tcansmittal_Sheets\Transmit_Otiginal_New.doc 1 EDE 50-029-20385-00 • MEMORANDUM To: Jim Regg ~~~ (~`Z~~' ~~~`~ P.I. Supervisor I FROM: Chuck Scheve Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 23, 2008 SGBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC W G [-03 PRUDHOE BAY UNIT WGI-03 Src: Inspector NON-CONFIDENTIAL Reviewed B~ P.I. Suprv--~8~ i ~l ~~ Comm Well Name• PRUDHOE BAY UNIT WGI-03 Insp Num: mitCS080ll8072318 Rel Insp Num: API Well Number: 5 0-0 29-2 03 8 5-00-00 Permit Number: t79-o49-0 ~ Inspector Name: Chuck Scheve Inspection Date: 1il~noos Packer Depth Pretest Initial 15 Min. 30 14Iin. 45 Min. 60 Min. Well i WGI-o3 Type Inj. I N ~ TVD I 7184 ~ IA ~ 400 i 4460 4360 4320 ~ ~ I P T ~ 1790490 iTypeTest f sPT j Test psi ~~~ 1796 I OA ~~ o ! o~ o ~ o '~ Interval OTHER p/F P / Tubing I 37s i 26so z63o ~ z63o Notes' Test performed for AA request. A plug had been set in the tubing tail and pressure applied to the tubing to prevent collapse. ~~~VR FEB ~ ~ 2~Q~ Wednesday, January 23, 2008 Page 1 of ] WGI-03 (PTD 1790490) Plan ford Page 1.9.f~ Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, January 23, 2008 12:31 PM ~~.~ ~IZ~I~~ To: 'Engel, Harry R' Cc: Rossberg, R Steven; NSU, ADW Well Integrity Engineer; NSU, ADW Well Operations Supervisor; Cismoski, Doug A; Julian, Jennifer Y; Senden, Leslie B; Bill, Michael L (Natchiq); Daniel, Ryan Subject: RE: WGI-03 (PTD 1790490) Plan forward You may continue injecting in PBU WGI-03 while pursuing the administrative approval. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 *Ir~~ "'' JHi~ & `~ ~UQU From: Engel, Harry R [mailto:Harry.Engel@bp.com] Sent: Tuesday, January 22, 2008 5:15 PM ~- - --- - To: Regg, James B (DOA) Cc: Rossberg, R Steven; NSU, ADW Well Integrity Engineer; NSU, ADW Well Operations Supervisor; Cismoski, Doug A; Engel, Harry R; Julian, Jennifer Y; Senden, Leslie B; Bill, Michael L (Natchiq); Daniel, Ryan Subject: WGI-03 (PTD 1790490) Plan forward Jim- This is a follow-up to our telephone conversation today regarding the plan forward for WGI-03. Summary WGI-03 is a GPB dedicated gas injection well. The well exhibits minor tubing x inner annulus re- pressurization of approximately 20 psi/day. The well is managed with pressure bleeds approximately every two months. The well has 2 barriers, including the tubing and production casing. The following pressure tests have been completed; > January 17, 2008, AOGCC MIT-IA passed to 4460 psi > January 18, 2008 PPPOT-T passed to 5000 psi, PPPOT-IC passed to 3500 psi. The plan forward is to continue diagnostic testing by running a Leak Detection Log and prepare a request for Administrative Approval. As we discussed, the well meets BPXA's internal operating requirements and we believe the well is safe to operate while we evaluate diagnostic testing results and prepare the request for Administrative Approval. Please respond with your approval to proceed with this plan. Regards, Harold R. Engel (Harry) Engineering Team Leader Integrity Management, Alaska Drilling & Wells 907-564-4194 offce 1/23/2008 WGI-03 (PTD #1790490) Notific~n of periodic bleeds Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Vic'-t--> f ? . ~~ (C7 Sent: Friday, December 21, 2007 11:34 AM '~ ( t To: Regg, James B (DOA) Cc: Engel, Harry R; NSU, ADW Wl Tech; NSU, ADW Well Integrity Engineer; NSU, ADW Weil Operations Supervisor Subject: RE: WGI-03 (PTD #1790490) Notification of periodic bleeds Hi Jim. Thank you very much for this guidance. i agree that it is difficult to determine absolute requirements so we will continue to notify you and discuss each well on an individual basis. As for WGI-03, we'll begin testing and request an Administra#ive Approval. Thank you, Anna Dube From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, December 21, 2007 11:28 AM To: NSU, ADW Well Integrity Engineer Subject: RE: WGI-03 (PTD #1790490} Notification of periodic bleeds L~~:>~~R~~~ SAN ~ ~ zaos Anna -Thank you for the notice on WGI-03. Workover done Feb-Mar 2007 {appears to have resolved the IAxOA communication; some indication of TxIA now. After reviewing the TIO pressure data, I believe it would be appropriate to request an admin approval for continued injection in PBU WGl-03. As discussed yesterday, there may be some wells that have an indication of pressure communication (infrequent pressure bleeds, stow repressurization to a stabilized pressure, etc.) that we can just monitor through the monthly weld integrity report you send. 1 do not have any absolute guidance {pressures, bleed frequencies} to offer, so suggest you contact us when you see these and we will make the decision about AA versus monitoring via monthly report. One example of a situation for monitoring instead of an AA would be a scheduled workover (near-term) to repair the communication. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSU, ADW Well Integrity Engineer [mailta:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Thursday, December 20, 2007 11:30 AM To: Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; NSU, ADW WI Tech Subject: WGI-03 (PTD #1790490) Notification of periodic bleeds Hi Jim, Attached is a TIO plot for WGI-03 (PTD #1790490). As we discussed this morning, this well is bleed approximately every two months. Please let us know if you would like to add this well to the Monthly Injection Report and monitor for increased repressurization or if we should submit a request for Administrative Approval. «WGI-03 TIO PIot.BMP» 12/21 /2007 WGI-03 (PTD # 1790490} Notific~n of periodic bleeds Page 2 of 2 Thank you, ,~nna ~Du6e, ~'.~ Well Integrity Coordinator GPB 11<lells Group Phony: ~sil~} 659-5'lil2 Pager: {sill) 659-51i}0 x115 12/21 /2007 ~,aaa x,000 2,000 I~' tv1AR5'P 1,000 4 12~20~000 .,._.... •~lA~ AA TtY4 At_i _ -~ Tbg -~- IA -~ OA OOA °~ OOC~ 211$C200~ 4l20~1007 6~0l~007 $/202007 10~0F~007 1 Zt~uF1UU! MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation 'Commission TO: Jim Regg 0, ~ ~é¿Lf 'J l'cI P.I. Supervisor '! ( . \ l DATE: Wednesday, May 17,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI-03 PRUDHOE BAY UNIT WGI-03 q,D~~ \1 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ..:::113Þ..:- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT WGI-03 API Well Number 50-029-20385-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060517071159 Permit Number: 179-049-0 Inspection Date: 5/16/2006 ReI Insp N um Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I WGI-03 ¡Type Inj. : G !TVD , I 7184 IA I 820 3000 I 2980 2980 I i I . -t--- I 1790490 ITypeTest ! SPT ! Test psi , ! P.T. 1796 OA i 0 0 i 0 ! 0 i WRKOVR p Tubing i 3700 , 3700 3700 3700 Interval PIF I ! Notes Pretest pressures were observed and found stable. Well demonstated good mechanical integriy. (~t'ifÀit.~"-¡~(j J.U· ï\j '1 s¡ 20GB \;;,;7V,"j11~:'Ç(.;;¡.;",. ~'.,:.;.. '"' Wednesday, May 17,2006 Page 1 of 1 STATE OF ALASKA '1¡t¡J~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~ . ~ ~jl. I 0 l{ iigt1l 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. ress: 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): o Suspend ~ Repair Well ~ Pull Tubing 99519-6612 30' 78' 2723' 8569' 9672 feet 8577 feet 9627 feet 8543 feet Size 20" 13-3/8" 9-518" 7" 1415' 9046' - 9580' 8105' - 8509' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): I) 9, 7-GOG ¡h' '-- o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Other o Re-Enter Suspended Well o Time Extension 4. Current Well Class: o Development 0 Exploratory o Stratigraphic ~ Service umber: 179-049 6. API Number: 50-029-20385-00-00 9. Well Name and Number: PBU WGI-03 10. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Plugs (measured) Junk (measured) None None MD Burst Collapse TVD 78' 2723' 8569' 1530 4930 6870 520 2670 4760 78' 2723' 7724' 8255' - 9670' 8160 7020 7468' - 8575' ~,r"!À1fJ1.'~^~;;;:t i..:'1w'~ "" \:. );1;0.;,.' r ;, 7-5/8",29.7# x 7", 26# I L-80 I NT95 29# 9-5/8" x 7" Baker 'SB-2' packer; 9-5/8" x 7" Baker 'SABL' packer; 9-5/8" x 7" Baker 'S-3' packer 7955' & 7959' - 8017' & 8145' - 8161' 8145'; 7993', 7907' RBDMS 8Ft MAY () 1 2006 Treatment description including volumes used and final pressure: Cut and pull 9-5/8" Casing from 2223', run 9-5/8" Tieback to surface. Cement wi 150 Bbls (720 sx at 1.17ft3/sx) of Gasblok out ES Cementer located at 2208'. 13. Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl o Copies of Logs and Surveys run ~ Daily Report of Well Operations ~ Well Schematic Diagram Re resentative Dail Avera e Production or In'ection Data Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure 15. Well Class after proposed work: o Exploratory 0 Development ~ Service 16. Well Status after proposed work: o Oil 0 Gas 0 WAG ~ GINJ 0 WINJ 0 WDSPL est 0 my now edge. Sundry Number or N/A if C.O. Exempt 306-008 17. I hereby certi t at t e oregoing is true and correct to t e Contact David Reem, 564-5743 Printed Name Terrie Hubble Title Technical Assistant CH{'Z-7 I Prepared By Name/Number: Date ¡DV:JTerrie Hubble, 564-4628 Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: Spud Date: 9/5/1979 End: 3/20/2006 2/512006 09:00 - 10:30 1.50 RIGD P PRE Lower & Scope down derrick. RID equip. 10:30 - 11 :30 1.00 RIGD P PRE Finish RID & prepare to move. 11 :30 - 16:00 4.50 MOB P PRE Move rig off WGI-04. P/U herculite & mats. Clean around wellhead. Move over to WGI -03. Wellhead high. Prep location & build up wI gravel & matting boards. 16:00 - 17:00 1.00 MOB P PRE Moving truck broke down. Wait on 2nd truck to finish move. 17:00 - 21 :00 4.00 MOB P PRE Spot in Rig sub over wellhead. Spot in pipe shed & pits. Begin rigging up. 21 :00 - 23:00 2.00 RIGU P PRE Raise & scope up derrick. Con't R/U equip. 23:00 - 00:00 1.00 WHSUR P DECOMP R/U & bleed off hanger void. Check annulus & tree pressure. Gauges showing 0 psi. 2/6/2006 00:00 - 01 :00 1.00 WHSUR P DECOMP Open needle valves on annulus & tree to verify well dead. Annulus blew down & died. Wellhead blew down to very gentle blow & did not completely die. Possible BPV leak? 01 :00 - 04:00 3.00 WHSUR P DECOMP P/U lubricator & pull BPV. Pressure bled off, well dead. Inspect same. Re-Install BPV & blanking plug. Test plug to 4000 psi. 04:00 - 06:00 DECOMP N/D tree & adapter flange. 06:00 - 06:30 DECOMP Service rig. Inspect derrick. 06:30 - 09:00 DECOMP N/U test spool & BOPE. Install 2 nd annular valve. 09:00 - 09:30 DECOMP R/U BOP test equip. 09:30 - 10:00 DECOMP Pressure test BOPE. Found HCR Choke leak. Blow down lines. Drain BOP stack. 10:00 - 13:30 3.50 DECOMP Change out HCR Choke Valve. Load & strap 31/2" DP. 13:30 - 00:00 10.50 DECOMP Pressure test BOPE as per BP/AOGCC requirements. John Crisp wI AOGCC witnessed test. LP 250 psi, HP 4000 psi. Annular - LP 250/3500 psi. 217/2006 00:00 - 00:30 0.50 BOPSU P DECOMP Finish testing BOPE. RID test equip. Blow down lines. 00:30 - 02:30 2.00 WHSUR P DECOMP P/U lubricator & pull Blanking plug & BPV. UD lubricator. No pressure recorded on tubing. 75/8" x 9 5/8" had 70 psi, & blew down to 0 psi. 02:30 - 03:30 1.00 FISH P DECOMP P/U BHA #1 as follows to cut 7 5/8" tubing. 5 1/2" OD multi-string cutter wI blades set to cut maximum 8", 43/4" Oil Jars. 9* 4 3/4" Drill Collars. TL = 291.46'. 03:30 - 07:00 3.50 FISH P DECOMP P/U 3 1/2" drill pipe 1x1 & RIH wI BHA # 1. 07:00 - 08:30 1.50 FISH P DECOMP No returns thus far. Line up & circulate down DP & up 7 5/8" tbg @ 4 1/2 bpm 11350 psi, taking gas cut returns thru choke to tiger tank, 250 bbls total pumped. RID circ head. 08:30 - 12:30 4.00 FISH P DECOMP PJSM. Continue to RIH picking up DP 1 x 1. Kelly up on jt # 242. 12:30 - 13:30 1.00 FISH P DECOMP PJSM. 125K up wt, 11 OK down, 116K rotating wt. WI 21' of kelly in the hole, cutter blades positioned @ 7960', rotating @ 50RPM I 3000 ft Ibs of torque, bring on pump to extend cutter blades, increasing pump rate to 5 bpm 11290 psi. After 10 - 15 minutes, pump pressure has decreased to 1050 psi. Monitoring 75/8" x 9 5/8" II A pressure, but observed no pressure increase in IIA pressure. 13:30 - 14:30 1.00 FISH P DECOMP Line up II A thru choke to tiger tank. Close annular preventor & pump down DP @ 3 bpm wI choke closed, pressuring up to 1500 psi on 7 5/8" & DP. No indication of pressure increase on IIA. Open choke & observe 200 psi drop in pressure on DP & 7 5/8", but no flow up IIA to tiger tank & no pressure increase on IIA gauge. Bleed all pressure & open annular preventor. Printed: 3/20/2006 12: 1 0:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: Spud Date: 9/5/1979 End: 3/20/2006 217/2006 14:30 - 15:00 0.50 FISH P DECOMP PJSM. Engage rotary table @ 50 RPM. See some torque increase over the 3000 ft Ilbs, indicating blades may be extended & cut may exist. Bring on pump @ 5 1/2 bpm 11325 psi. Observe flow increase & see indications of medium amounts of gas in returns. Shut down rotary table & pump & close annular preventor. 15:00 - 16:00 1.00 FISH P DECOMP PJSM. Line up to take returns thru choke to tiger tank & circulate down DP @ 4 1/2 bpm, taking returns up 7 5/8" tbg to tiger tank....very milky gas cut fluid coming back. CBU. Monitor well, well stable. 16:00 - 16:30 0.50 FISH P DECOMP PJSM. Engage rotary table @ 50-60 RPM. Bring on pump @ 5 3/4 bpm 11600 psi. See torque increase to 3500 - 4000 ft Ilbs. See pressure drop to 1375 psi .... classic cut signs. Disengage rotary table, slack off wI pump on & take wt ...1 OK. Shut down pump, pick up 15' to retract blades, bring on pump @ 2 1/2 bpm @ 500 psi & slack off wI blades extended, take weight @ same spot... 7960' DPM .. indicating good cut. 16:30 - 17:00 0.50 FISH P DECOMP PJSM. Close annular preventor & pressure up 31/2" DP & 7 5/8" to 2500 psi. Shut down pump. pressure holding ...pressure fluctating, (1000 psi), as it stabalizes indicating pressured up against a gas column .... , no pressure increase at IIA gauge on surface, some small amount of gas coming from IIA maybe 5 psi. Unable to circulate up I/.A from cut. 17:00 - 21 :00 4.00 FISH P DECOMP PJSM. Heat up brine in pits & circulate down 7 5/8" & up DP to heat up possible plug in 7 518" x 9 5/8" annulus. Order heated seawater. Take on heated seawater and begin circulating. Circulating @ 1.5 bpm 1150 psi. Temperature of water going into well @ 100 degrees with 90 degrees returns. 21 :00 - 22:30 1.50 FISH P DECOMP Little Red Services on location. PJSM. RU Little Red to prepare to pump hot diesel down the IA. Pre-heat diesel to ensure hot fluids in IA if it locks up. Returns from seawater circulation now at 100 degrees. Stop circulating hot seawater down 7 5/8" and pressure up down DP to see if any change in communication to IA pressure. Monitor lAP. No response in IA. 22:30 - 22:45 0.25 FISH P DECOMP Begin pumping down IA with hot diesel. Resume circulation of hot seawater down 7 5/8" up the DP. Little Red bringing up pump rate in increments of 0.5 bpm with zero pressure seen in IA. Bring up pump rate to 2 bpm witih 0 psi. See pressure increasing after 5 bbls away. Pressure up to 2500 psi with 8 bbls away and down on pump. Stop seawater circulation to monitor if any returns up DP. 22:45 - 00:00 1.25 FISH P DECOMP Pressure bleeding down to approximately 1800 psi after 5 minutes. Bump pressure back up to 2500 psi and monitor. Continues to bleed to about same pressure in same amount of time. Continue to bump back up. On third attempt, bled down to 1300 psi in about 8 minutes. It took 1 bbl to bump back up to 2500 psi. Appear to be making head way. 2/8/2006 00:00 - 04:30 4.50 FISH N STUC DECOMP Continue circulating hot seawater down 7 5/8" and up DP to try and thawlwarm up well bore. Seawater returns at 100 degrees. Continue pumping hot diesel (about 75 degrees) down IA bleeding and bumping up to 2500 psi. 04:30 - 05:00 0.50 FISH N STUC DECOMP Shut down Little Red Services. Stop circulation of hot seawater. Blow back lines and prepare to begin POOH while Printed: 3/20/2006 12: 1 0:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: Spud Date: 9/5/1979 End: 3/20/2006 standing back DP. POOH with BHA # 1 (Cutter assembly) and standing back BO stands of DP. PJSM. UD multi string cutter. Inspect blades, OD of extended bladses approximately 6.B75". lost 3/4" apiece off of (2) blades & 1" off the 3rd. PJSM. Pick up spear. Close blind rams & attempt to circulate down 7 5/B" & up IIA. See pressure increase on IIA to 350 psi, bleed to tiger tank & observe no more pressure increase. PJSM. Drain stack, BOLDs & spear pup jt below hanger. Work up 280K, seeing hanger come free initally @ 225K, and after that coming off seat @ 1BOK. W/100K overpull @ 280K up wt, 21" of stretch. Reland & attempt to establish circulation down 7 5/B" & up the 7 5/B" x 9 5/B" I/A. Pressure up to 3000 psi, seeing some incrtease in IIA pressure to 400 psi...., (slowly increasing as before....not due to expansion), bled off pressure on the IIA thru the choke to the tiger tank...., pressure did not come back up. Go through this process (3) times without seeing pipe come free or establishing communication between IIA & 7 5/B" tubing. STUC DECOMP PJSM. Pick up multi string cutter assembly to cut 7 5/B" tubing @ 4000'. STUC DECOMP RIH wI cutter assembly on 3 1/2" DP. STUC DECOMP PJSM. Pick up kelly. 74K up wt, 72K down wt, 72K rotating wt. Slack off 11' in on kelly wI 39 stands DP in hole..., cutter @ 4000'. Bring on pump @ 3 - 4 bpm 1700 psi to cause jars to extend. Engage rotary table @ 60 RPM 11000 ftllbs torque & bring on pump to 5 1/2 bpm @ 1400 psi. See pressure drop 300 psi to 1100 psi indicating cut made, continue for another 5 minutes. Disengage rotary table & shut down pump. Do not move pipe. No increase on IIA pressure during cutting ops. Attempt to break circulation, pumping down DP & 7 5/8" tubing, taking returns up IIA, no good. Same as other times ...., after achieving 3000 psi on 7 5/B" , some pressure increase slowly on IIA, bleed off same & no more increase. Bleed off all pressure. Engage rotary table @ 60 RPM, bring on pump @ 6 bpm/1050 psi...looks like cutter blades are extended, by pass is open & cut is made. Rotate to ensure cut is made for (15) minutes. Disengage rotary table, kick out pump, pick up 10', bring on pump @ 2 bpm I 300 psi & slack off. Set 25K on cut area @ 4000', definite indication of good cut. Increase pressure on 7 5/B" to 3500 psi, unable to break circulation up IIA, bleed off all pressure. PJSM. Stand back kelly & POOH wI cutter assembly. On surface with cutter assembly. Inspect knives and worn down 1" each. Good indication of cut. Lay down assembly. MU and PU spear assembly. PJSM. Check all lines and ensure that any returns from IA will be diverted to tiger tank. Close annular preventor. Latch onto tubing hanger and begin to pull on pipe. Tubing hanger unseated at 212K up weight. Pull up to 225K and noticed 9" of stretch. Work pipe up and down with no change in stretch. Pull up to 250K and got 15" of stretch. Work pipe again with no 2/8/2006 04:30 - 05:00 0.50 FISH N STUC DECOMP 05:00 - 09:00 4.00 FISH N STUC DECOMP 09:00 - 10:00 1.00 FISH N STUC DECOMP 10:00 - 10:30 0.50 FISH N STUC DECOMP 10:30 - 12:30 2.00 FISH N STUC DECOMP 12:30 - 13:30 1.00 FISH N 13:30 - 16:00 16:00 - 17:00 2.50 FISH 1.00 FISH N N 17:00 - 1 B:30 1.50 FISH N STUC DECOMP 1 B:30 - 19:30 1.00 FISH N STUC DECOMP 19:30 - 22:00 2.50 FISH N STUC DECOMP Printed: 3/20/2006 12: 1 0:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 2/5/2006 3/20/2006 Spud Date: 9/5/1979 End: 3/20/2006 2/B/2006 19:30 - 22:00 2.50 FISH N STUC DECOMP change. Work up to 275K and got 22" of stretch. 22:00 - 00:00 2.00 FISH N STUC DECOMP Re-seat tubing hanger and lay down spear assembly. Call out Little Red Services. Pump down DP to pressure up IA and see if we can achieve circulation. At 1700 psi pump pressure, IA pressure began to climb. IA pressure climbed to 110 psi. Stopped pumping and lined up to take returns to tiger tank and opened choke. Resume pumping and increased pump pressure to 3500 psi with 0 psi on the IA the whole time. Needle valve on IA showed small trickling of diesel returns with pump pressure at 3500 psi. 2/9/2006 00:00 - 01 :30 1.50 FISH N STUC DECOMP Blow down lines and prepare to PU landing joint. 01 :30 - 02:30 1.00 FISH N STUC DECOMP PU landing joint with TIW valve to be able to pump down it while working pipe. Screw landing joint into tubing hanger and close annular bag. PU to 175K to unseat hanger. Come online with pump to 500 psi with no change in IA pressure or weight. Increase pump pressure to 1000 psi and observed loss of 5K on weight. Increase to pump pressure of 1600 psi and notice loss of 9K total. No change in IA pressure. Bump weight back up to 175K and bled back to 170K. Bump back up to 175K and holding. Still no circulation or free pipe. Work tension in 5K increments up to 200K with no change in IA pressure or able to establish circulation. 02:30 - 03:30 1.00 FISH N STUC DECOMP Blow down lines and RD landing joint assembly. PJSM with Little Red Services and discuss circulation plan. RU Little Red to pit #3 to have them heat up seawater to 130 degrees. Prepare rig floor to RIH with muleshoe on bottom, 3 stands of DCs and 39 stands of DP. 03:30 - 06:00 2.50 FISH N STUC DECOMP RIH with open ended configuration to +1- 4000' to rev circulate 130 degree seawater. 06:00 - 17:00 11.00 FISH N STUC DECOMP PJSM. Reverse circulate 130 degree seawater @ 2 - 3 bpm, getting 105 degree returns. Continue heating sewater wI rig stearn coils while circulating. Rig up Little Red Hot Oil on fA & pump 120 degree diesel down IIA, seeing pressure increase to 2000 psi, then broke back. Pressure is leaking by Tubing hanger. RILDs. Still leaking by, (slowly). Seals on tubing hanger worn due to working pipe on previous operation. Have Hot Oil maintain 1500 psi on IIA while reverse circulating hot seawater. At 11 :00, 14:00, & 17:00 hrs, close in & pressure up 75/8" tbg to 3500, bleed pressure off of IIA. Close choke & observe pressure build back each time...., pressure building back progressively quicker. After 2 - 3 pressure ups & bleed backs, hold 3500 on tbg & pressure up IIA to 3000 wI Hot 011 & bleed back tubing to 500 psi fairly quickly. Resume reverse circulating 130 degree seawater down 7 5/B" x 31/2" & up DP while maintaining 1500 psi on IIA wI 120 degree diesel from Hot Oil. 17:00 - 19:30 2.50 FISH N STUC DECOMP Continue reverse circulating 130 degree seatwater @ 4 bpm I 400 psi. Little Red Services still pumping hot diesel down the IA to 1500 psi. Returns are between 100 and 105 degrees consistently. 19:30 - 23:00 3.50 FISH N STUC DECOMP PJSM with Little Red and Nabors night crews. Close in and pressure up 7 5/B" tubing to 3500 psi and bleed the IA pressure to zero. Close choke and observe IA pressure build up. Bleed Printed: 3/20/2006 12: 1 0:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: Spud Date: 9/5/1979 End: 3/20/2006 2/9/2006 19:30 - 23:00 3.50 FISH N 23:00 - 00:00 1.00 FISH N STUC DECOMP IA pressure to zero. Did this three times with the following average results: After 5 mins Tbg pressure = 3000 psi and IA pressure = 1500 psi. After ten mins Tbg pressure = 2500 psi and IA pressure = 1900 psi. When IA pressure bled to zero, average tubing pressure dropped to 1 BOO psi. Bled all lines and pressured up IA with Little Red to 3000 psi while pressured up tubing to 3500 psi. Bled tubing to 500 psi quickly and IA pressure came down to 2250 psi. Blow down all lines and align to resume reverse circulation of 130 degree seawater while maintaining 1500 psi on the IA with hot diesel being pumped by Little Red. STUC DECOMP Continue reverse circulating 130 degree seatwater @ 4 bpm I 400 psi. Little Red Services still pumping hot diesel down the IA to 1500 psi. Returns are between 100 and 105 degrees consistently. STUC DECOMP Continue reverse circulation of 130 degree seawater while maintaining 1500 psi on IA with hot diesel. STUC DECOMP Close in and pressure up 7 5/B" tubing to 3500 psi and bleed the IA pressure to zero. Close choke and observe IA pressure build up. Bleed IA pressure to zero. Did this three times again with similar results from before. Attempted to establish circulation down 7 5/B" up the IA with the choke open to the tiger tank. Tubing pressured up to 3000 psi at 1 bpm with no returns up the IA. STUC DECOMP Resume reverse circulation with 130 degree seawater down 7 5/8" up the DP. Continue pumping hot diesel down the IA at 1500 psi with Little Red. STUC DECOMP PJSM. Pressure up on 7 SIB" tubing to 3500 psi wIllA shut in against choke. Observe fA pressure increase to 950 psi. Bleed off IIA to tiger tank. Close in & observe slow pressure build up on I/A. Flow rate up IIA approximately 1/10 bpm. WI 3500 psi on 7 5/B" tubing, pressure up wI Hot Oil down II A to 3000 psi. No pressure increase on 7 SIB" tubing. Bleed tubing to 500 rather quickly wIllA pressure dropping to 2400 (+ -). Unable to break good circulation through (suspected) ice plug. STUC DECOMP Resume reverse circulating 130 degree seawater, getting 100- 105 degree returns. STUC DECOMP PJSM. POOH w/3 1/2" DP, DCs & mule shoe. STUC DECOMP PJSM. BOLDs on tbg hanger. M/U circulating head on landing joint. Torque all connections. M/U 7" BTC landing joint in tubing hanger & torque to 5000 ftllbs. Oil landing joint & close annular preventor. Pull on 7 51B" tbg, working up to 250K...., no movement...., tubing hanger not coming off seat. Verify lock downs are backed all the way out. Pull again to 250K wI no movement on pipe. Pressure 7 5/8" tubing to 2500 psi & observe hanger pop free. Work tubing to 250K & pressure tubing to max of 3200 psi, seeing flow up II A @ approximately 1/10 bpm. Max stretch on tubing = 32" wI 250K pull & 3000 psi on tubing. This equates to approximately an strtaight pull of 350K (+ -). Work several times in this fashion without making any progress. Consult wI town & opt to punch holes in tubing pups directly above Camco BAL-O SVLN @ 2230'. Bleed all pressure & UD landing joint. 2/10/2006 00:00 - 03:00 3.00 FISH N 03:00 - 04:00 1.00 FISH N 04:00 - 07:00 3.00 FISH N 07:00 - 07:30 0.50 FISH N 07:30 - OB:30 1.00 FISH N OB:30 - 10:30 10:30 - 13:30 2.00 FISH 3.00 FISH N N Printed: 3/20/2006 12: 1 0:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: Spud Date: 9/5/1979 End: 3/20/2006 2/10/2006 13:30 - 14:30 1.00 FISH N STUC DECOMP RILDS on tubing hanger. Blow down surface lines. RD landing joint. Call Schlumburger E-line. 14:30 - 20:00 5.50 FISH N STUC DECOMP Little Red Service pumping neet methanol down the IA at 1500 psi. RD flow nipple and RU perf flange for E-line. Release Little Red Services at 1 B:OO hrs. Wait on Schlurnburger E-line. 20:00 - 00:00 4.00 FISH N STUC DECOMP E-line arrives on location. Begin spotting equipment and check in with rig. PJSM with E-line and rig personnel. RU E-line surface equipment. Pressure test to 500 psi. 2/11/2006 00:00 - 01 :00 1.00 FISH N STUC DECOMP Continue RU of Schlumburger E-line 01 :00 - 02:30 1.50 FISH N STUC DECOMP RIH with E-line to 7" Camco Bal-O SSSV @ 2230'. Tie into tubing tally via SSSV and pup joints above and below it. Tie-in using CCL and shoot 10' of tubing punch holes from 2219'-2229'. CCL to top shot = 5.6'. Top shot @ 2219.6'. Stop depth = 2214.0'. A 51b tension drop was seen and a bobble was felt on the line indicating detonation. POOH with E-line into the lubricator. Close blind rams, break off lubricator and inspect tool for shots fired. All 1 0' of shots fired. 02:30 - 04:30 2.00 FISH N STUC DECOMP Attempt circulation into IA by pressuring up 7 SIB" with blind rams closed and IA open to tiger tank. Bring pump online @ 1 bpm and pressure in 7 5/B" climbing. No pressure response seen in IA. Tubing pressured up to 3500 psi with no returns to tiger tank. Bleed tubing and IA pressures to zero. Close choke to tiger tank and pressure up against choke to 3500 psi on the tubing. Down on pump at 3500 psi on the tubing, IA pressured up to 5BO psi. After ten minutes, the IA pressured up to 1200 psi and the tubing had bled off to 3000 psi. Repeated the pressure up and bleed with same results after ten minutes. Bleed tubing and IA to zero. Close choke and pressure up to 3500 psi on the tubing again and monitor liquid flow back rate. Filled 5 gallons in one minute = .1 bpm. Bleed down tubing and IA to zero. 04:30 - 06:00 1.50 FISH N STUC DECOMP RD Schlumburger E-line. RD perf flange and NU adapter and flow nipple. 06:00 - 06:30 0.50 FISH N STUC DECOMP PJSM. Close blind rams & pressure up on 7 5/B" tubing, taking returns up 7 5/B" x 95/8" annulus, thru choke to tiger tank. WI 3500 psi on tbg, close in choke & monitor return rate ... approximately 5 gallons warm diesel returns up IIA in 105 seconds. Keep 3500 psi on tbg, wI choke open to tiger tank. Monitor return rate as described above wI no significant change. 06:30 - OB:30 2.00 FISH N STUC DECOMP PJSM. Bleed all pressure, open blind rams & M/U 7" Btc landing jt in tbg hanger wI circulating head affixed to the top thereof. Pressure up on tbg to 3500 psi, taking returns up IIA, thru choke to tiger tank, as before. Warm (90 degree) diesel returns at the rate of 5 gallons every 90 seconds wI 3500 psi on tubing. Continue to circulate to tiger tank, holding 3500 - 4000 psi on the tubing. No siginificant change in return rate over this period of time. OB:30 - 12:30 4.00 FISH N STUC DECOMP PJSM. BOLDs. Bleed pressure & pull 250K on hanger, did not come off seat. Pressure tubing to 2500 psi & observe hanger coming off seat. Reland & pressure to 3000 psi, seeing return rate of 5 gallons 190 seconds..warm diesel. Pick up to 225K wI 3000 psi on tubing & observe return rate stop entirely, then Printed: 3/20/2006 12: 1 0:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: Spud Date: 9/5/1979 End: 3/20/2006 2/1112006 OB:30 - 12:30 4.00 FISH N STUC DECOMP slowly resume after a few minutes. Continue to pressure tubing to 3500 psi wI 225K up wt on tubing until return rate is @ 5 gallons I 90 seconds. Work pipe in this manner, seeing warm (90 - 95 degree) diesel returns turn to warm methanol returns and finally to warm (90 - 95 degree) seawater returns. Continue circulating & working pipe in this manner with no significant increase in return rate. 12:30 - 15:00 2.50 FISH N STUC DECOMP PJSM. Bleed all pressure & line up to reverse circulate, pumping down IIA & taking warm (90 - 95 degree) 1% KCL returns thru choke to tiger tank. Pressure up to 3500 psi & see return rate of approximately 5 gallons every 100 seconds. Continue in this manner, working pipe occasionally to 225K. No siginficant increase in return rate & no sign of pipe moving down hole at stuck point during any of the afore mentioned operations. Strongly suspect SSSV @ 2230' is the stuck point. 15:00 - 22:00 7.00 FISH N STUC DECOMP PJSM. Line up to circulate the long way.... down the 7 5/8" tbg & up the IIA, taking warm KCL returns to the tiger tank. Call out Schlumberger E-Line to perform a freepoint log & subsequent cutting operation in the 7 5/8" tbg. Now showing some increase in return rate, warm seawater up to 5 gallons in 45 seconds. At 20:30, observed return rate of 5 gallons in 1 BO seconds with open choke to tiger tank and 3500 psi on the tubing. Returns were seawater with temperature of B5-90 degrees. 120 bbls of returns observed in the tiger tank. 22:00 - 00:00 2.00 FISH N STUC DECOMP Schlumburger E-line on location. PJSM. RU E-line to landing joint via 7" to 4 1/2" IF crossover. MU tool #1 on E-line which is the freepoint logging tools. Attach elevators to landing joint to be able to pull tension on pipe for logging. Obtain weight parameters for free point, 60K overpull with 11" of stretch. Set slips on pipe. Blow down lines and bleed both tubing and IA pressures to zero. Continue RU E-line. Total bbls in tiger tank from circulation at 00:00 = 133 bbls. 2/12/2006 00:00 - 01 :30 1.50 FISH N STUC DECOMP Continue RU of E-line. 01 :30 - 03:00 1.50 FISH N STUC DECOMP RIH with E-line and freepoint tool. Stop at 1000' to calibrate tool in free pipe. Pulled 250K twice and got 13" of stretch measured on the drill floor. Neutral weight was observed to be 1 BOK. Continue RIH. 03:00 - 05:00 2.00 FISH N STUC DECOMP Tie into SSSV nipple and tubing tally using casing collar locator. Stop at 2265' which is in the middle of the first full joint below the SSSV nipple to check for free pipe. PU 250K and tool indicated B7% free. Schlumburger guarantees anything above BO% to be free pipe. Slack off to 180K and RIH to 2990'. PU to 250K and tool indicated B 1 % free. Slack off to 180K and RIH to 3900' (100' above second cut). PU to 250K and tool indicated 52% free. Slack off to 1 BOK and POOH to 3497'. PU 250K and tool indicated 72% free. Slack off to 180K and POOH to 250B'. PU 250K and tool indicated 91% free. Suspect the higher percentage free due to working of pipe during free point logging sequence. 05:00 - 07:00 2.00 FISH N STUC DECOMP POOH with E-line and free point tools. 07:00 - 07:30 0.50 FISH N STUC DECOMP Pre job safety meeting wI Schlumberger wI regard to runnig chemical cutter. Pull to 225K, (hanger unseated @ 175K), and slack back off to 120K...approximately 50K over projected up Printed: 3/20/2006 12: 1 0:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: Spud Date: 9/5/1979 End: 3/20/2006 wt, set slips & M/U collar clamp on 7" landing joint. RIH wI (2) strand string shot, CCL & gamma. Scan mechanical cut @ 4003', looked good. Shot string shot from 2500' - 2512'. POOH wI Eline. UD string shot running tools & M/U chemical cuttig tools....had to call to shop & get replacement part for cutter. RIH wI S.93" OD chemical cutter, CCL & gamma to cut 7 5/B" tubing. PT pack off to 1000 psi, OK. Tie in, make S' correction, (add S'), and make cut @ 2S10' ELM. Good indication of cut at surface. Line up & bring on rig pump @ S bpm 1400 psi, circulating seawater down 7 SIB" tubing @ 5 bpm, taking full returns up 7 SIB" x 9 5/B" annulus thru choke to tiger tank. Circulate 7S bbls, shut down & monitor. Tbg & IIA dead. POOH wI chemical cutter, no hangups. STUC DECOMP On surface with E-line chern cutter. RD E-line. Pull on 7 SIB" and still not free. Unseat hanger with 175K pull. PU to 2S0K and still not free. RU TIW valve on 7 5/B" to pump down through cut into IA against closed choke to pressure up wellbore and try to get some hydraulic upforce help. Pressure up well to 1000 psi and still not coming free. RD TIW and line up to pump down IA to pressure up well bore to a higher pressure (worried about TIW and hose on 7 5/B" if pressure up too high and comes free). Pump down IA and pressure up wellbore to 3000 psi with 250K on the pipe. Pipe weight slacked off to 175K. Bump up to 200K and still not free. Line up to reverse circulate EP mudlube down to cut depth of 2510'. Spot EP mudlube pill (42 bbls down IA to cut depth) and work pipe. Still not free. Consult with town and decision made to mechanically cut above SSSV nipple. STUC DECOMP Maintain 200K on 7 518" while waiting on Baker to re-dress 7 SI8" cutter with B 1/4" knives. STUC DECOMP MU 7 SIB" Cutter Assembly with 81/4" knives. Land tubing hanger. RILDS. RU to run 3.S" DP. Cut depth = 2200' +1-. Do not want to cut in the 10' pup above the nipple because the pup has been shot with tubing punch holes. STUC DECOMP RIH with cutter assembly, 3 stands of DCs, 20 stands of 3.S" DP and a single joint to locate SSSV nipple. PU Kelly and RIH 10' to locate min ID across SSSV nipple. Come online with the pump to extend knives @ 2 bpm I 200 psi. At 19' of Kelly in the hole, stacked out 5K. Down on the pump. POOH and lay down single joint of DP and re-attach Kelly. Cut depth will be 2199' and BHA length = 2B2.36', 20 stands of DP = 1896.S3. Therefore need to RIH with 20.1' of Kelly to find cut depth. STUC DECOMP Up weight = 47K and down weight = 47K. RIH to 20' of Kelly. Start rotation of pipe @ 50 RPM and about B50 ft-Ib of torque (45 amps). Come online with the pump and walk up in 100 psi increments. Reach pump rate of 6 bpm 11150 psi and about 1BSO ft-Ib of torque (90 amps). After S mins of rotation with pump on, saw pressure drop of 4S0 psi to 700 psi. Original torque value returned (45 amps). Continue rotation with pump on for 20 minutes to ensure cut and try to give best shot at cutting control lines. Down on rotation and stack out 20K of weight on cut, dropped 2'. Good indication of cut. 2/12/2006 07:00 - 07:30 O.SO FISH N STUC DECOMP 07:30 - 11 :30 4.00 FISH N STUC DECOMP 11 :30 - 1S:00 3.S0 FISH N STUC DECOMP 15:00 - 1 B:OO 3.00 FISH N STUC DECOMP 1 B:OO - 21 :00 3.00 FISH N 21 :00 - 22:30 1.50 FISH N 22:30 - 00:00 1.S0 FISH N 2/13/2006 1.50 FISH 00:00 - 01 :30 N 01 :30 - 02:30 1.00 FISH N Printed: 3/20/2006 12: 1 0:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 2/5/2006 3/20/2006 Spud Date: 9/5/1979 End: 3/20/2006 2/13/2006 02:30 - 04:30 2.00 FISH N STUC DECOMP POOH with cutter assembly, DCs and 3.S" DP. Cut and slip drilling line. Contine POOH. 04:30 - 05:30 1.00 FISH N STUC DECOMP UD cutter assembly, nothing amiss there. OS:30 - 07:00 1.S0 FISH N STUC DECOMP M/U landing joint & circulating head, pull to 9SK, hanger popped free & wt dropped back to 7BK, tubing free. Circulate 80 bbls @ S bpm I 350 psi, no gas, well stable. 07:00 - OB:30 1.S0 BOPSU P DECOMP PJSM. WI landing jt made up to hanger, C/O pipe rams from 3 1/2" x 6" VBRs to 7 SIB". Body test to 4000 psi, OK. OB:30 - 09:00 I O.SO FISH P DECOMP PJSM. Rig up Schlumberger spooling unit. 09:00 - 16:00 I 7.00 FISH P DECOMP PJSM. POOH w/7 SIB" STL tubing & dual control lines. Control lines hanging up from time to time, unable to pull wI spooler and have to assist wI hydraulic tugger. Recovered (4) out of a possible (5B) stainless steel control line bands. Control line appears to have been cut by multi string cutter, no apparent stretching from overpull. Recovered 54 full jts & 17.8B' of cut off jt. 16:00 - 21 :30 S.SO BOPSU P DECOMP PJSM. Set test plug & CIO pipe rams to 31/2". Having trouble with leak-by on test plug. Work issue to pressure test against rams. Found square-shouldered rubber element below test plug which was preventing a good test. Suspect it came from tubing hanger being worked. Pushed rubber downhole to properly seat test plug. Also recovered 8 more stainless steel contolline bands from tubing spool. We now have recovered 12 out SB bands. Pressure test rams to 4000 psi for S mins. Good test. RD test equipment and drain BOPE. Pull test plug. Baker on location with reverse-circulating basket. Change out elevators. 21 :30 - 23:00 1.50 CLEAN C DECOMP MU and PU reverse-circulating basket (BHA #4) which consits of : XO, DCs, XO, Super Jars, Bumper sub, XO sub, Bit sub, 7.87S" Reverse Circulating Basket and B.S" Head. 23:00 - 00:00 1.00 CLEAN C DECOMP RIH with cleanout assembly and 3.S" DP. Will utilize 19 stands and a double to get to required tag depth of 2201' (top of 7 SIB" stub). 2/14/2006 00:00 - 01 :00 1.00 CLEAN C DECOMP Continue RIH with reverse circulating clean out basket to top of 7 S/8" tubing stub @ 2202'. 01 :00 - 02:00 1.00 CLEAN C DECOMP Stop just above tubing stub with 19 stands and a double of DP. Up weight = SBK, Down weight = 5BK, Free rotation weight = 60K. Go 3' in on Kelly and come online with pump @ 2 bpm I 200 psi and drop ball to enable reverse circulation. Ball seated. Raise pump rate to 6 bpm 11300 psi. Without rotating work string go down and tag @ 2199', stack 2K. PU and start rotation at 20 RPM and 8S0 ft-Ib of torque (4S Amps). Drop back to 2199' and saw torque increase to 3000 ft-Ib (1S0 Amps). Stop rotation and PU S'. Start rotation again and begin RIH. Making hole to 2200'. No more increase in torque or pump pressure. PU 4' and RIH again to tag and make it to 2200' again (26' of Kelly in). Sit there and reverse circulate for 10 minutes. Down on pump. Blow down lines. Remove Kelly. 02:00 - 03:30 1.S0 CLEAN C DECOMP POOH with cleanout assembly while standing back DP and DCs. 03:30 - 04:00 O.SO CLEAN C DECOMP On surface with BHA. Cleanout subs full of junk. Break off BHA and inspect subs and fingers. Removed 31 more bands of stainless steel control line bands, about S' more of control line Printed: 3/20/2006 12: 1 0:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: t~Phåse I DECOMP I DECOMP I DECOMP I WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 2/14/2006 03:30 - 04:00 04:00 - 05:15 05: 15 - 06:00 0.50 CLEAN C 1.25 CLEAN C 0.75 CLEAN C 06:00 - 07:30 1.50 CLEAN C DECOMP 07:30 - OB:30 1.00 CLEAN C DECOMP I OB:30 - 09:30 1.00 FISH C DECOMP 09:30 - 11 :00 1.50 FISH C DECOMP 11 :00 - 20:00 9.00 FISH C DECOMP 20:00 - 21 :30 21 :30 - 22:00 1.50 FISH C DECOMP 0.50 FISH C DECOMP 22:00 - 22:30 0.50 BOPSU DECOMP 22:30 - 00:00 1.50 BOPSU DECOMP 2/15/2006 00:00 - 01 :30 1.50 BOPSU P DECOMP 01 :30 - 07:30 6.00 BOPSU P DECOMP 07:30 - 10:30 3.00 FISH C DECOMP Spud Date: 9/5/1979 End: 3/20/2006 and about 6 pieces of rubber. We have now recovered 43 total bands of the 58 in the well. Re-make up BHA and RIH with same cleanout assembly. Tag without circulation or rotation at same depth of 2200' (26' of Kelly). PU and bring pump online at 6 bpm 11300 psi. RIH and tag at 2200' again. PU 4' and bring on rotation at 20 RPM and 850 ft-Ib of torque (45 Amps). RIH and torque spiked at 2200' to 1BOO ft-Ib (90 Amps) and then dropped back to 1000 ft-Ib (60 Amps). Sit on bottom rotating and circulating for 10 mins. Down on pump. Blow down lines. Remove Kelly. POOH with cleanout assembly while standing back DP and DCs. PJSM. Break down BHA, inspect basket, recovered approximately (4) more stainless steel bands & (3) pieces of rubber. (11) stainless steel bands still unaccounted for. PJSM. Pick up fishing BHA including, mule shoe, pack off, type "B" spear, (LH release), stop sub, bumper sub, jars, (9) 6 1/4" DCs, & accelerators...OAL = 323.77'. PJSM. RIH wI fishing BHA on 3 1/2" DP. PJSM. M/U kelly on jt # 59. 61 K up wt, 61 K down wt. Set down 15K 22' in on kelly...stop sub @ approximately 2200'. Over pull to 150K & commence jarring, working up & ultimately jarring @ 200 - 210K, & subsequently straight pulling to 250 - 260K wI no measureable upward movement of fish. Bring on pump @ 4 bpm 1200 psi while continuing with jarring operation. Continue jarring and working pipe with no luck. Attempt to release spear and not able to due to free rotation of fish downhole. Not able to get spear to make its 1/4-1/2 turn to the left to release. Spear came loose from fish (?) and begin POOH with BHA, DCs and DP. Stand back DCs and 29 stands plus a double of 3.5" DP. On surface with BHA. Spear recovered along with 20' tubing Stump from mechanical cut and 10' pup below it. The 10' pup had dimples from the tubing puncher but no holes. We backed out from the crossover just above the SSSV nipple. Break off BHA and lay down in pipe shed. Now have the 7 5/B" x 7" XO Box looking up. MU and set test plug. Close rams to secure well. PJSM. Begin changing out Hydril Annular Preventor in preparation for BOPE test. Preventor was worn and stripped during fishing operations. Continue changing out of Hydril Annular Preventor. Call AOGCC to give them 2 hours notice for upcoming BOPE test. Witnessing of BOPE test waived by John Spaulding. Begin pressure testing of BOPE per BP/AOGCC requirements to 300 psi low and 4000 psi high. Components tested were: Choke Manifold Valves 1, 2/3, 4, 5/6, 7, B 19, 10/11 113 , Manuals Kill and Choke, HCRs, 3 1/2" Pipe Rams, Annular Preventor. Accumulator and Kelly. Completed Weekly BOP Test. Rig down test equipment. Blow down Lines. Pull Test Plug. Discuss a plan forward with Anchorage Engineering to address next Fishing Operation. Order out needed tools to complete Printed: 3/20/2006 12:10:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: Spud Date: 9/5/1979 End: 3/20/2006 2/15/2006 07:30 - 10:30 3.00 FISH C DECOMP next BHA. 10:30 - 11 :30 1.00 FISH C DECOMP Make up BHA #7 as follows: B 1/2" x 31/2" Packer Mill, Bit Sub, 8 1/2" String Mill, Bumper Sub, Super Jar, B.44" Stabilizer, XO sub, Drill Collars. XO, Accelerator, XO. 11:30 - 13:30 2.00 FISH C DECOMP TIH with BHA #7 and 3 1/2" Drill Pipe (59 Jts). Check all 3 1/2" Drill Pipe connections on the TIH 13:30 - 15:30 2.00 FISH C DECOMP Pick-up Kelly. PUW=62K, SOW = 60K, ROW = 62K. Dry tag at 2,229'. Bring pump on line at 4 bpm/2S0 psi, RPMs = 60, Torque = 2,000 ftllbs (100 Amps). Pick-up to 2,191'. Wash and rotate back to 2,229' with no problems. Set back Kelly and make connection. Bring Pump on line at S bpm/300 psi. RPM = 60. Amps = 100. Tag again at 2,229'. Milled down to 2,931.S'. WOM = 4 - 6K. Steady and smooth milling then unable to make further progress as expected due the Fish spinning at down to next cut at 2,510'. No fluid loss. No cuttings in returns (?). Pressure test 9 SIB" Casing at 2,000 psi for 3 minutes. OA pressure remained at 100 psi during test. Good. Set back Kelly. 15:30 - 1 B:OO 2.50 FISH C DECOMP POOH with 31/2" Drill Pipe and BHA #7. Stand back DP and DCs. Lay down BHA. Clear and clean Rig Floor in preparation for next runs. 1 B:OO - 19:30 1.S0 FISH C DECOMP PU and MU BHA #B as follows: Bull nose, 7" Itco Spear wI 6.095" Grapple, Spear Extension, B.625" Stop Sub, XO, Bumper Sub, Super Jar, XO, Drill Collars, XO, Accelerator, XO. 19:30 - 21 :00 1.50 FISH C DECOMP TIH with BHA #8 and 20 stands of 31/2" DP. 21 :00 - 00:00 3.00 FISH C DECOMP PJSM. MU Kelly on jt # 60. 60K up wt, 60K down wt. Set down 5K 21' in on Kelly...Stop Sub @ approximately 2232' which is where the milling operation had stopped. This puts the Grapple on the Spear in the 5.937" ID Bore through the Nipple. Over pull to 150K and commence jarring. Overpull to 200K and jars setting off at 1B5K with subsequent weight of 17SK after jarring. No free pipe. Consult with town engineer and decision made to continue jarring until morning. 2/16/2006 00:00 - 04:30 4.50 FISH C DECOMP Continue jarring on Fish @ 2232'. Try pumping down at 6 bpm I 400 psi with no joy. Also attempt to "rock" the Fish up and down with no joy. No travel up or down noticed. Only "movement" at free weight of 60K is 31" of travel for the Accelerator and Bumper Sub. No free rotation of Fish either. All indications point to being completely stationary and stuck in place. 04:30 - 07:00 2.50 FISH C DECOMP Disengage Spear and stand back Kelly. TOH with Spear BHA and 20 stands of DP. Stand back DP and DCs. Decision made to re-run Milling Assembly. 07:00 - 07:30 0.50 FISH C DECOMP Lay down BHA #10. 07:30 - 09:00 1.50 FISH C DECOMP Discuss plan forward with Anchorage Engineering. Make-up BHA #9 as follows: B 1/2" x 3 3/4" Packer Mill, Bit sub, B 1/2" String Mill, Super Jar, B.44" Stabilizer, XO, Drill Collars, XO. 09:00 - 10:00 1.00 FISH C DECOMP TIH with BHA #9 and 3 1/2" Drill Pipe (60 Joints, 23.BS' 3 1/2" DP PJ). Tag top of fish at 2,232'. 10:00 - 00:00 14.00 FISH C DECOMP Pick-up Kelly. PUW = 62K, SOW = 60K, ROT = 60K, RPMs 60 - BO, Torque = 2,000 ftllbs (50 - 100 Amps), Pump rate = 5 bpm/400 psi, WOM = 4K - lOK. Begin Milling on Fish and Casing obstruction at 2,232'. Consult with town engineer and Printed: 3/20/2006 12:10:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: CO~T~ha C I DECOMP I C i I DECOMP I I I I WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 2/16/2006 10:00 - 00:00 2/17/2006 00:00 - 04:00 04:00 - 05:30 05:30 - 06:00 14.00 FISH 4.00 FISH 1.50 FISH C DECOMP O.SO FISH C DECOMP 06:00 - 07:00 1.00 FISH C DECOMP 07:00 - 09:30 2.50 FISH X RREP DECOMP 09:30 - 10:00 0.50 FISH C DECOMP 10:00 - 10:30 0.50 FISH C DECOMP 10:30 - 12:00 1.50 FISH C DECOMP 12:00 - 12:30 0.50 FISH C DECOMP 12:30 - 14:00 1.50 FISH C DECOMP 14:00 - 15:30 1.S0 FISH C DECOMP 1S:30 - 17:00 1.S0 FISH C DECOMP 17:00 - 1 B:OO 1.00 FISH C DECOMP of 35 Spud Date: 9/5/1979 End: 3/20/2006 decision made to keep milling until morning time and then attempt to spear Fish. At 20:00 hrs, made about 3' of hole. At 22:30 hrs, had made about 4-1/2' of hole. Continue Milling on Fish. As of 01 :00 hrs had made 6' of hole (23' of Kelly in). Kick up pump rate to 6 bpm 1400 psi and notice some metal shavings across Shale Shaker. POH about a joint of Drill Pipe and ream the hole back to 23' of Kelly in = 6' of hole. Do this a couple of times to ensure we are getting all metal shavings to bottom and circulated out. Continue milling operations with 10-12K WOM. Pump high-vis sweep to clean out well bore - noticed metal shavings, some rubber and some cutting returns but not much. Did have one piece of teflon seal (from tubing string) come back. At 04:00 hrs, we had 24.S' of Kelly in the hole = 7.S' of hole. Distance between two Mills approximately 6.5' which means we got the Upper String Mill about l' into the orginalleading edge of the Packer Mill. Both Mills are B 1/2" OD. Down on milling. Set back Kelly and begin to POOH with BHA and 20 stands of 3.5" DP. Stand back DP and DCs in preparation for next run. On surface with BHA #9 (Milling Assembly). Inspect Packer Mill and Upper String Mill. Packer Mill has about 1/2" wear on bottom. Original distance from bottom of BHA to bottom of Packer Mill was 1.7S', after milling it was 1.81 '. The bottom of the Packer Mill has a 2-step wear profile on it with the heaviest wear towards the OD of the Mill. The Upper String Mill has signs of "polishing" on the OD of it. Break apart BHA components and lay down in Pipe Shed. Make-up BHA #10 as follows: Bull Nose, 7" Itco Spear with 5.970 Grapple, B 1/2" stop Sub, XO, Bumper Sub, Super Jar, XO, Drill Collars, XO, Accelerator, XO. Stop Operations to trouble shoot and repair electrical problem with Derrick Lights. TIH with BHA #10 and 31/2" drill Pipe (60 Joints, 23' DP Pup Joint). Pick-up Kelly. Tag TOF at 2,244' stop sub depth. Attempted severat times to plant Spear w/5.970" Sprial Grapple. Bring Pump on line a 6 bpm/400 psi. Attempt several more times to plant Spear. No-Joy. Set back Kelly. POOH to inspect Grapple. Lay down BHA #10. The S.970" Grapple appears new (clean). No sign of any attempt to "bite". It appeasrs that the SSSV has been competly milled away. Re-dress Spear with a 6.767" Spiral Grapple to "catch" the I.D. of 7 5/B" 29.7 Iblft Tubing. TIH to top of Fish @ 2246'. TIH with 20 stands of 3.S" DP, a 23.BS' pup joint and BHA. PU Kelly and latch onto Fish. Attempt to Jar free but no- joy. Continue to work Fish. TOH with BHA #10 and 3.S" DP to add Packoff and force circulation through chemical cut at 2510' ELM. Stand back DP and DCs. BHA on surface. Add 7 5/B" Packoff to workstring just below the Spear. Troubleshoot Derrick Lights again. Found to be Printed: 3/20/2006 12:10:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: Spud Date: 9/5/1979 End: 3/20/2006 2/1712006 17:00 - 1B:00 1.00 FISH C DECOMP unplugged - no repairs needed. 1B:00 - 19:30 1.50 FISH C DECOMP TIH with BHA #11 (same Assembly with Packoff) to top of Fish @ 2246'. TIH with 20 stands of 3.5" DP, a 23.B5' pup joint and BHA. PU Kelly and re-Iatch onto Fish. Attempt to Jar free but no- joy. Continue to work Fish. Bring on circulation at 6 bpm I 310 psi through the chemical cut and up the IA. 19:30 - 21 :00 1.50 FISH C DECOMP Pump high-vis sweep down the DP and up the IA in hopes of cleaning up the Wellbore. Still pumping at 6 bpm 1310 psi. No significant metal returns noticed, only small shavings of metal. Continue jarring on Fish. 21 :00 - 00:00 3.00 FISH C DECOMP PJSM. RU to start pumping 140 degree fresh water from Veco Tanker directly into Wellbore. Rigged up to take returns to Tiger Tank. Swapping wellbore down to 2510' ELM to clean fresh water in preparation for downhole video to be run. Pumping at 3 bprn 1150 psi. After about 180 bbls pumped, noticing cleaner returns on surface. Continue pumping hot fresh water into Wellbore and jarring on Fish. 2/18/2006 00:00 - 02:30 2.50 FISH C DECOMP Continue circulating 140 degree fresh water into Wellbore to clean it up in preparation for video logging. Returns from well with fresh water = 29.15 Nephelometric Turbidity Units. Clean out Rig Pits and fill with new, clean seawater. Continue jarring on Fish attempting to get some movement. 02:30 - 04:30 2.00 FISH C DECOMP Set back Kelly. TOH with BHA #11 (Spear) and 20 stands of 3.5" DP. Stand back DP and DCs. Clear and clean Rig Floor. 04:30 - 06:00 1.50 FISH C DECOMP On surface with BHA #11. Break apart BHA components and lay down the same. Begin MU of Mule Shoe to run open-ended into Well bore for circulation of Borough Water. 06:00 - 07:30 1.50 EVAL C DECOMP TIH with 3 1/2" Mule Shoe, 3 Stands of 43/4" Drill Collars, and 3 1/2" Drill Pipe (124 Jts). Park Mule Shoe at -4,200-ft. 07:30 - 12:00 4.50 EVAL C DECOMP Cilrculate and condition Well squeeky clean with Brough Water for final preperation to run Video Camera Log. Final return sample = 2.19 Nephelometric Turbidity Unts. 12:00 - 14:00 2.00 EVAL C DECOMP POOH with 3 1/2" Drill Pipe, Drill Collars, and Mule Shoe. 14:00 - 1B:00 4.00 EVAL C DECOMP RU Halliburton E-line and RIH with Downhole Video Camera. Make stops at top of Fish @ 2246', chemical cut @ 2510' and mechanical cut @ 4000'. POOH and RD Halliburton. 1 B:OO - 20:00 2.00 EV AL C DECOMP RD Shooting Flange and RU Flow Nipple. Consult with Anchorage Engineering and decision made to re-cut with B 1/4" Knives down at 7906'. Re-dress Cutting Assembly and ship Stabilizer out to Rig from Baker shop. 20:00 - 20:30 0.50 EV AL C DECOMP PJSM. PU and MU BHA # 12 which consists of: 5 1/2" OD Multi-string Cutter with 8 1/4" Knives, XO, 63/4" OD Stabilizer and 9- 4 3/4" DCs. BHA length = 2B6.69' to the Knives. 20:30 - 23:00 2.50 EVAL C DECOMP Begin TIH with BHA #12 and 80 stands of DP plus a double. Cut depth will be 7960' which is depth of original cut. 23:00 - 00:00 1.00 FISH C DECOMP PU Kelly. Up weight = 125K Down weight = 10BK. Need to go in 26' with the Kelly to get the Knives to 7960'. About 15' of Kelly in the hole start noticing weight bobbles that may indicate pushing something downhole. Suspect it could be some of the stainless steel control line bands. At 24.5' Kelly in the hole (795B.5' Knives depth), stack weight. The distance from the bottom of the BHA to the Knives is 1.5' which puts the bottom of the BHA at 7960'. PU and bring on rotation to try and get Printed: 3/20/2006 12:10:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: Spud Date: 9/5/1979 End: 3/20/2006 DECOMP past 24.5' of Kelly - Unsuccessful. Suspect we are sitting down i on a full cut that has shifted the 7 5/B" and not allowing us to fall through. Consult with Anchorage Engineering and decision I made to come up hole and re-cut at 4000' with the B 1/4" Knives. 2/19/2006 00:00 - 02:00 2.00 FISH C DECOMP Set back Kelly and lay down 2 single joints of 3.S" DP. POOH to target depth of 4000'. Stand back 41 stands of 3.5" DP. 02:00 - 03:00 1.00 FISH C DECOMP PU and MU Kelly. UW = 75K, DW = 74K. Bring pump online to extend Knives. Pump rate = 3 bpm I 300 psi. Come down hole to locate previous cut, should be about 19' of Kelly in the hole. No location of previous cut made. PU and bump up pump to 4 bpm 1600 psi. Come down and still no joy locating the cut. PU and bump up to 6 bpm 11S00 psi to ensure extension of Knives and drop to 5 bpm 11000 psi. Still no joy in locating of cut. PU and bump pump rate to 6 bpm / 1S00 psi. Again, nothing on location. Decision made to cut at 19' of Kelly in the hole. 03:00 - 03:30 0.50 FISH C DECOMP Bring on rotation of DP at 60 RPM with about 1750 ft-Ib of torque (75 Amps). Bring on the pump and walk it up slowly to extend Knives. At about 300 psi pump pressure, the torque increased to 90 Amps. Up to 6 bpm 11400 psi and 2000 ft-Ib of torque (100 Amps). Stack some weight on Knives while cutting and torque increased to about 2500 ft-Ib (120 Amps) and pump pressure dropped to 1000 psi. All of a sudden string took a torque kick up to 4500 ft-Ib (200 Amps) and pump pressure spiked to 1500 psi. Down on rotation and pump. Begin rotation and pumping again in same spot. Pumping at 5 bpm 1950 psi with 60 RPM. Cut for 30 minutes total and pump pressure at end of that time was 7S0 psi. 03:30 - 04:00 0.50 FISH C DECOMP Down on rotation. Stack 20K on cut just made - Good indication of cut. Shut off pump and PU S' past the cut. Bring the pump back on at 3 bpm I 500 psi and RIH to find the cut. The Kelly travelled 19' in and began to stack weight. Stacked 20K again on the cut again - Good indication. 04:00 - 05:30 1.S0 FISH C DECOMP Blow down lines. Set back Kelly. TOH with BHA # 12 and 39 stands of 3.5" DP. Stand back stands of DP and DCs in preparation for next run. OS:30 - 06:00 0.50 FISH C DECOMP On surface with BHA # 12. Inspect Knives for evidence of wear and successful cut. Break apart BHA #12 and lay down its components. Clean and clear Rig Floor. 06:00 - 06:30 0.50 FISH C DECOMP Make-up BHA #13 as follows: Mule shoe, Pack-Off, Itco Spear w/6.767" Sprial Grapple, Stop Sub, XO, Lubricated Bumper Sub, Oil Jar, XO, 6 1/4" Drill collars, XO, Intesifier, XO. 06:30 - 07:30 1.00 FISH C DECOMP RIH with BHA #13 and 3 1/2" Drill Pipe. Stop at -1,200' for Rig service. 07:30 - 09:00 1.50 FISH C DECOMP Stop to Cut and Slip Drilling Line. 09:00 - 10:00 1.00 FISH C DECOMP Resume RIH with BHA #13 and 31/2" Drill Pipe. Pick-up Kelly (60 Joints, 23' Pup Jpint, and 13' Kelly). PUW = 62K. Tag top of Fish at 2,246'. Plant Spear. Pull Fish free with Much-Joy. PUW now 11 OK. 10:00 - 11 :00 1.00 FISH C DECOMP Set back Kèlly. POOH with 3 1/2" Drill Pipe and BHA #13. Top of 7 SIB" Tubing Fish to surface. 11 :00 - 11 :30 0.50 FISH C DECOMP Lay down BHA #13. 11 :30 - 12:00 0.50 FISH C DECOMP Change equipment to handle and lay down 7 SIB" Tubing. Printed: 3/20/2006 12: 1 0:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: Spud Date: 9/5/1979 End: 3/20/2006 2/19/2006 12:00 - 13:30 1.50 PULL C DECOMP Single down 7 5/8" Tubing (43 Joints) and a 23.10' Cut-Off Stub in Pipe Shed. Inspect attempted Chemical Cut Joint (see pictures). Joint was only severed -30%. 13:30 - 14:00 0.50 FISH C DECOMP Change equipment to habdle 3 1/2" Drill Pipe. 14:00 - 00:00 10.00 FISH X WAIT DECOMP Suspend Opertations while monitoring Wind Speed. Present conditions are 30 - 40 mph steady with gusts at 50 mph plus. Unable to safely run empty Traveling Blocks up Derrick to latch Drill Pipe and TIH. Hold Weekly Safety Meeting for Day-light Crew. Maintain and service Rig. 2/20/2006 00:00 - 02:00 2.00 FISH X WAIT DECOMP Winds still gusting to 50 mph with 30-40 mph steady. Conditions still not safe for running Traveling Blocks up and down Derrick to trip in hole with Drill Pipe. 02:00 - 02:30 0.50 FISH C DECOMP Assess weather conditions with company man, tourpusher, driller and derrickrnan. Winds have died down to about 25 mph and the direction has changed. Decision made to resume operations. MU BHA #14 as follows: 5 1/2" OD Multi-String Cutter with B 1/4" Knives, XO, 6.75" OD Stabilizer and 9 DCs. OAL = 2B6.69' to the Knives. 02:30 - 04:30 2.00 FISH C DECOMP TIH with BHA #14, BO stands of 3.5" DP and two singles. 04:30 - 05:30 1.00 FISH C DECOMP MU Kelly. UW = 125K, DW = 10BK. RIH and stack weight at 23' of Kelly. (puts bottom of tool at previous cut depth of 7960'). PU 4' and come online with pump to rate of 3 bpm I 600 psi to extend Knives. RIH and stack weight at same depth. Down on pump and PU 3'. RIH to 22' of Kelly in the hole and begin cutting process at 7,95B'. Start rotation at 60 RPM and approximately 2200 ft-Ib of torque (120 Amps). Rotation weight = 114K. Begin to walk pump rate up to 4 bpm 11050 psi. Torque increased to about 3000 ft-Ib (150 Amps). After B minutes the pressure dropped to 930 psi. Cut for total of 30 minutes. Down on rotation and PU 3'. RIH with Knives extended with pump at 3 bpm I 600 psi and stack 20K at cut depth. Down on pump. Blow down lines. Set back Kelly. 05:30 - 09:00 3.50 FISH C DECOMP Lay down 2 singles of 3.5" DP and TOH with BHA # 14 and BO stands of 3.5" DP. Stand back DP and DCs. 09:00 - 09:30 0.50 FISH C DECOMP Lay down BHA # 14. Inspect Knoves. Normal expected wear. Good indication the Knives were fully extended. 09:30 - 10:00 0.50 FISH C DECOMP Make-up BHA #15 as follows: Mule Shoe, PAck-Off, Itco spear w/6.767" Spiral Grapple, Stop Sub, XO, Lubercated Bumper Sub, Bowen Oil Jar, XO, Drill Collars, XO, Intensifier, XO. 10:00 - 12:00 2.00 FISH C DECOMP RIH with BHA and 3 1/2" Drill Pipe (116 joints). PUW = 7BK. SOW = 75K. Pick-up Kelly. Plant Spear in top of 7 518" Tubing Fish at 4,000'. Pull Fish free with no problems at the re-cut at 7,95B'. PUW = 195K. 12:00 - 13:30 1.50 FISH C DECOMP Circulate and condition Well bore with Sea Water at 5 bpm/600 psi. 13:30 - 15:30 2.00 FISH C DECOMP Set back Kelly. Start to POOH with 3 1/2" drill Pipe, BHA, and 7 SIB" Tubing Fish. 15:30 - 16:00 0.50 FISH C DECOMP Stop to circulate and condition. Well sightly out of balance. Circulate with Sea Water. Had several barrels of white foamy fluid (no gas) in returns. Shut down Pump. Monitor Well dead and once again static. 16:00 - 1 B:OO 2.00 FISH C DECOMP Continue POOH with 3 1/2" Drill Pipe 1 B:OO - 23:30 5.50 FISH C DECOMP On surface with Spear and 7 SIB" Tubing Fish. Pull out Spear Printed: 3/20/2006 12: 1 0:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: Spud Date: 9/5/1979 End: 3/20/2006 2/2012006 18:00 - 23:30 5.50 FISH C DECOMP from Fish and lay down BHA components. Inspect Stump from 4000' and notice first cut was off-set. RU to handle 7 5/B" and single down the Tubing to the re-cut @ 7960'. POOH with 7 5/B" Tubing. 23:30 - 00:00 0.50 FISH C DECOMP On surface with 7 SIB" Stub from cut at 79SB'. Cut looks really good. The joint that was cut was Joint #99 of 7 5/B" Tubing from the 4000' cut. Stub lenght = 37.S0'. RD 7 SIB" Handling Equipment and RU 3 1/2" Handling Equipment. Clear and clean Rig Floor. 2/21/2006 00:00 - 02:00 2.00 FISH P DECOMP Continue with RU of 31/2" Handling Equipment. Break down BHA # 1S Itco Spear. MU BHA # 16 as follows: Mule Shoe, XO, 7 5/B" Type B Spear, Spear Extension, XO, Spear Extension, Spear Extension, Stop Sub, Bumper Sub, Super Jars, XO, 9-DCs, XO, Accelerator, XO. 02:00 - 02:30 0.50 FISH DECOMP Make-up BHA #16 as follows: Mule shoe, XO, Type "B" Spear, Entension, XO, Extension, Extension, Stop Sub, Bumper Sub, Super Jar, XO, Drill Collars, XO, Accelerator, XO. 02:30 - OS:30 3.00 FISH P DECOMP TIH with BHA # 16, BO stands of 3.S" DP and a 31.95' single of DP. PUW = 139K. SOW = 113K. Pick-up Kelly. ROTW = 12SK. OS:30 - 11 :00 5.50 FISH P DECOMP Tag top of 7 SIB" Tubing Stump at 7,95B' (with Mule Shoe). Had to circulate and work get deeper to plant Spear. Plant Spear. Jar on K-Anchor 10 times and then rotate 1B turns. All 1 B turns came back. Again, jar 10 times and rotate 1 B turns. All 18 turns came back. Pulled up to un-load Jars for the next cycle, lost "bite". Unable to go back down. Pulled up hole but dragging. Go back down freely. Pull up hole again, but still dragging and trying to pull tight. Bring pump on line and circulate while trying to pull up hole. Can pull up hole with pump on, but not with pump off. Mix extra heavy Hi-Vis Sweep (24 bbls) and circulate back to surface at rnax Pump rate (6.7 bpm/1 ,300 psi). Monitor returns across Shaker. Gel Sweep clean. Pump 9 Singles out of the hole and lay down in Pipe Shed. Pick-up Kelly. Rotate, pump, and work to "shake" junk free. Now able to pull with no problem. Set back Kelly. Install Head Pin and circulate Well with Charge Pump. Secure Rig. Weather conditions now Phase 3. 11 :00 - 00:00 13.00 FISH N WAIT DECOMP Hold Safety Meeting with Crew and discuss Phase 3 condition and guidelines. Maintain Rig. 2/22/2006 00:00 - 06:00 6.00 FISH N WAIT DECOMP Continue to WOW. Entire North Slope still in Phase 3 Conditions. Well is secure. Continue to maintain Rig and equipment. 06:00 - 06:30 0.50 FISH N WAIT DECOMP Now at Phase 2 Weather Conditions. Will resume planned operations once Crew change-out has been completed. 06:30 - 10:00 3.50 FISH P DECOMP POOH with 3 1/2" Drill Pipe and BHA #16. 10:00 - 10:30 0.50 FISH P DECOMP Lay down BHA. Recovered "un-expected" Fish. Fish = 3.14' section of the first full Joint of 7 5/B" Tubing and 3.96' of the (9.51' 7 5/B") Pup Joint. Also recovered two -B" pieces of mashed flat Control Line. The Friction Blocks below the Type B Spear Slips have been gouged and scored bad on posibile junk inside the 7 5/B" Pup Joint Stump. 10:30 - 12:30 2.00 CLEAN C DECOMP Clear and clean floor. Discuss plan forward with Anch Eng. Bring next BHA to Floor. Make-up BHA #17 as follows: B 1/2" Printed: 3/20/2006 12: 1 0:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: Spud Date: 9/5/1979 End: 3/20/2006 2/22/2006 10:30 - 12:30 2.00 CLEAN C DECOMP Shoe, 7718" Reverse Junk Basket, Bit Sub, XO, Bumper Sub, Super Jar, XO, Drill Collars, XO. 12:30 - 14:00 1.50 CLEAN C DECOMP TIH with BHA #17 and 3 1/2" Drill Pipe (241 Joints). PUW = 140K. SOW = 104K. Pick-up Kelly. ROTW = 120K. 14:00 - 16:00 2.00 I CLEAN C DECOMP RIH. Tag (solid) at 7,959' (expect solid tag 7,965'). Circulat I Drill Pipe volumne (52.5 bbls). Break-out Kelly. Drop 7/B" Ball. Make-up Kelly. Circulate ball on seat. Bring Pump on line at 5 bpm/925 psi. Wash and rotate at at 40 - 80 rpm with 150- 275 Amps. Keep tagging at same spot. Unable to make any further hole. Set back Kelly. 16:00 - 19:30 3.50 CLEAN C DECOMP TOH with BHA #17 and 241 joints of DP. Stand back DP and DCs. 19:30 - 20:30 1.00 CLEAN C DECOMP On surface with BHA #17. Break apart BHA and inspect junk basket. Recovered 3 pieces of stainless steel control line (about 2' if stretched out) and 1/2 of a stainless steel control line band. Lay down BHA components. 20:30 - 21 :30 1.00 BOPSU P DECOMP Rig Up Test Equipment in preparation for BOPE test. 21 :30 - 00:00 2.50 BOPSU P DECOMP Pressure test BOPE per BP/AOGCC requirements to 300 psi low and 4000 psi high. The right to witness the test was waived by Lou Grimaldi. Components tested were: Blind Rams and Valves 1 and 2 - good; Valves 3,4,5 - good; Valves 6,7,8 - good; Valves 9 and 10- good, Valve 11 - good; Valve 13- good; HCRs Choke and Kill - good; Manuals Choke and Kill - good; 31/2" Pipe Rams - good. 2123/2006 00:00 - 03:30 3.50 BOPSU P DECOMP Continue testing of BOPE per BP/AOGCC testing requirements. Accumulator - good; Upper and Lower Kelly - having problems with the Kelly and TIW valve. Begin to diagnose Kelly and look for possible leaks. All valves replaced with new ones and still not testing. Suspect Test Pump is the problem. 03:30 - 04:00 0.50 CLEAN C DECOMP PU and MU BHA #1B as follows: 5 7/B" Shoe, 5 5/B" Reverse Jet Basket, Bumper Sub, Super Jar and 6 Drill Collars. 04:00 - OB:30 4.50 CLEAN C DECOMP TIH with BHA #1B and 3 1/2" Drill Pipe (244 Jts, 23' Pup Jt). Pick-up Kelly. PUW = 129K. SOW = 104K. ROTW = 115K. 08:30 - 10:30 2.00 CLEAN C DECOMP Tag top of 7 5/B" Pup Joint ( ID 6.750") Stump at 7,962' (expected tag was 7,965'). Bring Pump on line at 5 bpm/1700 psi. Kick in Rotary Table at slow RPMs and work to get 5 7/B" Shoe inside Stump. After 6 minutes, Shoe fell inside. Continue to rotate and wash down to 7,967'. Unable to get any deeper. PUH and out of Stump. Tried three more time to get back into Stump with no-joy. Attempts were made at different RPMs and pump rates. Shoe wants to grab and jump. Concerned about further damage to top Stump. Pick-up off Stump and circulated while confer with Anch Eng on plan forward. Dropped Ball and continued to circulate ball on seat. Worked Reverse Junk Basket to attempt to pick-up any junk pieces. 10:30 -11:00 0.50 CLEAN C DECOMP Set back Kelly. Blow down Lines. 11 :00 - 13:30 2.50 CLEAN C DECOMP POOH with Drill Pipe and BHA. 13:30 - 14:30 1.00 CLEAN C DECOMP Lay down BHA. Inspect 5 7/B" Shoe. Shoe was severaly worn üunked out) for no longer then it was rotated or for the amount of weight ran on it. Empty Junk Basket. Recovered 2 pieces from one of the Shoes ran on one of the BHAs in the past. Printed: 3/20/2006 12: 1 0:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: Spud Date: 9/5/1979 End: 3/20/2006 2/23/2006 13:30 - 14:30 1.00 CLEAN C DECOMP Clear and clean floor. 14:30 - 15:30 1.00 FISH C DECOMP Make-up BHA #19 as follows: 53/4" Bull Nose, 7 5/B" Tri-State Type "B" Spear, Stop Sub, XO, Bumper Sub, Super Jar, XO, Drill Collars, XO, Intensifier, XO 15:30 - 19:00 3.50 FISH C DECOMP TIH with BHA #19 and 31/2" Drill Pipe Tag up on top of cut pup jt @ 7959'. 19:00 - 20:00 1.00 FISH C DECOMP Space out wI 24' DP pupjt. Attempt to engage tubing stub wI spear. No good. UD 24' pup & P/U 5'+10' pup. Work down wI kelly & rotate. Attempt several times to get spear engaged. No good. No torq, appear to be turning on junk on top of stub. P/U wt = 144K, SIO wt = 107K, Rot wt = 125K. 20:00 - 11 :30 15.50 FISH C DECOMP UD DP pups & set back kelly. Blow down lines. POOH & stand back 31/2" DP. Had up to 25K drag while pulling 1st 65', then dropped off to P/U Wt. 11 :30 - 00:00 12.50 FISH C DECOMP UD spear assy. Inspect bull nose. Appeared to run on junk. 2/24/2006 00:00 - 01 :00 1.00 FISH C DECOMP M/U BHA # 20 to clean out tubing pup as follows: 5 5/8" Window Mill, Bit Sub, 6.75" String Mill, XO, 2 Boot Baskets, Bit Sub, Bumper Sub, Jars, XO, 9 * 61/4" DCs, XO. TL = 313.91'. 01 :00 - 03:00 2.00 FISH C DECOMP RIH wI BHA # 20 on 3 1/2" DP. 03:00 - 06:00 3.00 FISH C DECOMP P/U kelly & break circulation 4BPM @ 600 psi. Tag up @ 7959' Mill & clean out tubing pup from 7959 to 7966'. P/U Wt = 150K, SIO Wt = 107K, Rot Wt = 125K. 60 RPMs, 3.5-BK Torq., WOB 2K. Work string up & down wlo rot & circulating to insure tubing is clear. 06:00 - 06:30 0.50 FISH C DECOMP Continue to work String Mill in and out of the top of the 7 5/8" Stump at 7,959'. Now able to pass through without rotating. 06:30 - 07:00 0.50 FISH C DECOMP Set back Kelly. Blow down Lines. 07:00 - OB:30 1.50 FISH C DECOMP Stop to cut and slip Drilling Line. OB:30 - 11 :00 2.50 FISH C DECOMP POOH with 3 1/2" Drill Pipe and BHA #20. 11:00 - 12:00 1.00 FISH C DECOMP Lay down BHA. Inspect Mills. String Mill has normal expected wear on the side. Window Mill had a circuluar ring pattern -4" in diameter on the outer edge of the face. Empty Boot Baskets. Recovered some fine metal cuttings and iron sulfide looking dirt. - 2 gals total. 12:00 - 13:00 1.00 FISH P DECOMP Clear and clean Floor. Make-up BHA #21 as follows: 5 3/4" Bull Nose, 7 5/B" Type "B" Spear, 8 1/B" Stop Sub, XO, Bumper Sub, Super Jar, XO, Drill Collars, XO, Intensifier, XO. 13:00 - 15:30 2.50 FISH P DECOMP TIH with BHA #21 and 31/2" Drill Pipe (241 Joints, 14.70, and a 5.BB Pup Joint). PUW = 142K. SOW = 104K. 15:30 - 16:30 1.00 FISH P DECOMP Pick-up Kelly. Bring Pump on line at 3.25 bpm/400 psi. PUW = 145K. SOW = 11 OK. Enter top of 7 5/8" Stump at 7,959' with no problems. Plant Spear down to Stop Sub (7'). Pick-up to set Spear. However, it appear the K-Anchor is free (?). Pull 15K over with chatter and drag for -1-ft. Then weight falls back to normal PUW. Do again with same results. Set back down and rotate to the right to make sure Spear is in the "catch position". Pull up again with chatter and 10K over-pull. Weight back to normal. Have K-Anchor or unable to get Slips to bite (?). Set back Kelly. Drain and blow lines. 16:30 - 20:00 3.50 FISH P DECOMP POOH & stand back 31/2" DP. 20:00 - 21 :30 1.50 FISH P DECOMP Stand back & inspect BHA.Spear assy had No recovery. 1 slip section showed peeled off piece of metal. 21 :30 - 22:00 0.50 FISH P DECOMP Install 3 ' extension in spear assy. BHA # 22 Printed: 3/20/2006 12:10:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: Spud Date: 9/5/1979 End: 3/20/2006 2/24/2006 22:00 - 00:00 2.00 FISH P DECOMP RIH wI BHA #22 on 3 1/2" DP. 2/25/2006 00:00 - 00:30 0.50 FISH C DECOMP Con't to RIH wI BHA #22 on 3 1/2" DP. 00:30 - 02:30 2.00 FISH C DECOMP P/U 2 DP pups, kelly & break circulation. 3 BPM @ 2BO psi. Circulate down into tbg pup & bottom out @ 7968'. Made additional 1.5' from previous run. P/U to 75K over & jar on fish. after jar fires spear comming free from fish. Repeated several times wI same result. Spear slips not getting solid bite on tubing pup. P/U & appled torq to fish. Attempted 2 times 1st wI 13 turns & 300 amps & 2nd wI 15 turns & 320 amps. No movement in K-anchor. P/U Wt = 144K. SIO Wt = 109K, Rot Wt = 125K. 02:30 - 06:00 3.50 FISH C DECOMP POOH wI BHA #22 & stand back 3 1/2" DP. 06:00 - 07:30 1.50 FISH C DECOMP Inspect BHA. The Drag Blocks on the Spear assembly were being swedged into the 7 5/B" x 7" (I.D. = 6.21B") XO Box. We were only getting a friction bite on Fish. Slips on the Spear are unable to bite the 7 51B" Stump for some unknow reason (not because of the drag blocks). Inspection of the Spear also showed that the spear was still in the "catch position". Lay down BHA. Discuss plan forward with anch Eng. clear and clean Floor. 07:30 - 08:00 0.50 CLEAN C DECOMP Make-up BHA #23 as follows: B 1/2" Bit, Boot Basket, Boot Basket, Casing Scraper, XO, Bumper Sub, Oil Jar, XO Drill Collars, XO. OB:OO - 10:30 2.50 CLEAN C DECOMP TIH with BHA #23 and 31/2" Drill Pipe (242 Jts). PUW = 140. SOW = 101K. Tag top of 7 5/8" Stump (lightly) at 7,959'. Puick-up 2'. 10:30 - 13:00 2.50 CLEAN C DECOMP Mix and reverse in with a 33 bbl Hi-Vis Sweep. Continue to reverse circulate Well at 5.1 bpmlBOO psi. Recovered Sweep and saw no soilids, cuttings, or junk pieces. Total bbls pumped behind the Sweep = 615. 13:00 - 16:00 3.00 CLEAN C DECOMP POOH with 31/2" Drill Pipe and BHA #23. 16:00 - 16:30 0.50 CLEAN C DECOMP Lay down BHA. Empty Boot Baskets. Both baskets were empty. Clear and clean Floor. 16:30 - 17:00 0.50 CLEAN C DECOMP Make-up BHA #24 as follows: 57/8" Reverse Circulating Junk Basket, 3 1/2" Drill Pipe Pup Joint, Double Pin XO, Boot Basket, Boot Basket, Bit Sub, Bumper Jar, Oil Jar, XO Drill collars, XO. 17:00 - 20:30 3.50 CLEAN C DECOMP TIH with BHA #24 and 80 stands of 3 1/2" drill Pipe. 20:30 - 00:00 3.50 CLEAN C DECOMP P/U single DP & kelly. Break circulation. 6 BPM @ 1550 psi. Wash down & tag up @ 7962'. ream thru tight spot & continue down, tag up hard @ 7968'. Mill from 7968 to 7970'. Last 30 min made no footage. P/U Wt = 145K, SIO Wt = 10BK, Rot Wt = 125K. 60 RPMs, WOB 4-6K, Torq 4.5 - 6K. 2/26/2006 00:00 - 00:30 0.50 CLEAN C DECOMP Finish milling down to 7970'. Have not made progress for last 30 min. Set back kelly, Blow down lines. 00:30 - 03:00 2.50 CLEAN C DECOMP POOH & stand back BO stands of 31/2" DP. 03:00 - 04:30 1.50 CLEAN C DECOMP POOH wI BHA & inspect same. Shoe worn smoothe & body of Tool scarredfrom junk. Empty RCJB. Recovered 2" x B" pc of steel tubing. Pcs of SS bands, twisted up SS control line, Steel cuttings, & chunks of rubber. Empty 2 boot baskets & recovered 1/2 bucket of iron sulfide & black carbonaceous material. Ilnstall new shoe on RCJB & Re-run BHA. 04:30 - 06:00 1.50 CLEAN C DECOMP RIH w/6 1/4" DCs & stands of 31/2" DP. Printed: 3/20/2006 12: 1 0:24 PM .. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 2/5/2006 3/20/2006 Spud Date: 9/5/1979 End: 3/20/2006 Lub Rig. Inspect Derrick. C Finish TIH with BHA #25 and 31/2" Drill Pipe (241 Joints). Pick-up Kelly. PUW = 147K. SOW = 108K. Tag tight spot again at -7,962'. However, fell through. Continue down to top of Junk at 7,970'. Mill and wash through Junk from 7,970' - 7,973' at 60 - BO RPMs, 230 - 290 Amps (5,000 - 9,000 ftllbs Torque). Pump rate 6.0 bpm/1600 psi. Made fast hole from 7,973' - 7,975'. This depth puts us close to the top of the Prong. 12:00 - 15:00 3.00 CLEAN C DECOMP POOH with 31/2" Drill Pipe and BHA #25. Inspect Shoe = normal wear. 15:00 - 16:00 1.00 CLEAN C DECOMP Lay down BHA 25. Empty Reverse Circulating Junk Basket. Recovered two hand-fulls of Control Line pieces and SS Band pieces. Also a large piece of rubber. Empty Boot Baskets and recovered 3 gals of Iron Sulfide black looking dirt. Re-dress Reverse circulating Junk Basket for final clean-out to swallow the Prong down to Plug body and hopefully pull Prong with a friction catch in Basket fingers. 16:00 - 19:00 3.00 CLEAN C DECOMP TIH with BHA #26 and 31/2" Drill Pipe. RIH BO stans + 1 single. P/U kelly. 19:00 - 20:00 1.00 CLEAN C DECOMP Break circulation thru RCJB @ 7975'. 6 BPM @ 16BO psi.Circulate & wash down from 7975 to 7981'. Tagged up solid on TIP @ 79B1'. 20:00 - 21 :30 1 .50 CLEAN C DECOMP Circulate bottoms up, 6 BPM @ 16BO psi. No gas to surface. Well Dead. 21 :30 - 23:00 1 .50 CLEAN C DECOMP Set back kelly. Blow down lines. POOH wI Bha & 31/2" DP. 23:00 - 00:00 1.00 KILL C DECOMP Pulled 26 stands of DP. Well started to flow. Close annular preventor. Notified S. Rossberg, AOGCC ( Lou Grimaldi) & Pad operator. Monitor well. After 30 min. SIDP = 220 psi, SICP = 390 psi. 2/27/2006 00:00 - 03:30 3.50 KILL C DECOMP Circulate well thru gas buster. Pumped 4 BPM 1775 psi. CP 1260 psi. pumped 425 bbls. Lost 46 bbls while circulating. SID & monitor well. Well bled down to DP 40 psi, CP 110 psi in 45 min. 03:30 - 04:30 1.00 KILL C DECOMP Con't to circulate well. 5 BPM. DP = 1050 psi, CP = 120 psi. Lost 3 bbls while circulating. Pumped total of 210 bbls. SD & monitor well. DP = 60 psi, CP = 90 psi. 04:30 - 06:00 1.50 KILL C DECOMP Bull head 30 bbls down DP. DP = 2000 psi, CP = 19BO psi. In 15 min, DP = 620 psi, CP = 700 psi. Found leak in mud manifold valve. Bled off & repaired same. 06:00 - 07:30 1.50 KILL C DECOMP Attempt to Bullhead through PRN Plug (with Prong removed). Pressured up to 2,00 psi. Plug may now be "plugged". Continue to Monitor Well. Develope a plan forward. Casing pressure 1,560 psi. Drill Pipe pressure = 1,500 psi. 07:30 - 09:00 1.50 KILL C DECOMP Monitor Well. With BHA at 5,450' circulate and condition Well with Sea Water through choke and Gas Buster. It took 47 bbls to displace gas column from annulus. 09:00 - 09:30 0.50 KILL C DECOMP Monitor Well. Well static with fluid level dropping slightly. 09:30 - 10:00 0.50 KILL C DECOMP Trip back to just above the 7 5/B" Stump at 7,959' with no problems. 1 0:00 - 16:00 6.00 KILL C DECOMP Attempt to circulate and condition Well with Sea Water through Choke and Gas Buster at 4 bpm/900 psi. However return were unstable {several rapid pit gains, pit losses, and solid gas Printed: 3/20/2006 12: 1 0:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 2/5/2006 3/20/2006 Spud Date: 9/5/1979 End: 3/20/2006 2/27/2006 10:00 - 16:00 6.00 KILL C DECOMP returns). Second attempt ot circulate out gas was even more I unstable. It is suspected the gas from below the PRN Plug is continuing to infiltrate the fluid as it "turns the corner". Discuss plan forward with Anch Eng. Shut in Well. Calculate and order out Kill weight Brine (10.9Ib/gal). 16:00 - 1 B:OO 2.00 KILL C DECOMP Well is secure. Continue to monitor Well while waiting on Brine to arrive on location. Discuss a more detailed plan forward with Anch Eng. 1 B:OO - 00:00 6.00 KILL C DECOMP Wait on 10.9 ppg brine. Monitor well. SIDPP decreased from 450 psi to 130 psi. & SICP decreased from 1340 psi to 1180 psi in 6 hours. Clean pits, 1 st load of 10.9 brine unloaded in pits, 2nd load unloading & 3 rd load on the way. 2/2B/2006 00:00 - 01 :00 1.00 KILL C DECOMP Unload 10.9 ppg bring. Monitor well. SIDPP decreased from 100 psi to 70 psi. & SICP pressure decreasaed from 11 BO to 1170 psi. 01 :00 - 04:00 3.00 KILL C DECOMP Open well, circulate thru gas buster & kill well. pump @ 3 BPM. DPP increased from 4BO to 670 psi. CP decreased from 1220 to 20 psi. Pumped total of 560 bbls. SID, well dead. 04:00 - 05:00 1.00 KILL C DECOMP Open annular & monitor well. Well dead. Fluid level dropped approx 1/2 bbl in 45 min. 05:00 - 08:00 3.00 KILL C DECOMP Circulate hole volume. 3 BPM @ 600 psi. OB:OO - OB:30 0.50 KILL C DECOMP Monitor well, well stable. OB:30 - 11 :30 3.00 CLEAN C DECOMP PJSM. POOH w/3 1/2" DP. Well not taking or giving back any fluid. 11 :30 - 12:30 1.00 CLEAN C DECOMP Stand back collars, UD reverse circulating basket. Recovered approximately (1) cup control line pieces & equalizing prong. Prong in good shape. 12:30 - 13:30 1.00 CLEAN C DECOMP Clear I clean rig floor. 13:30 - 14:00 0.50 CLEAN P DECOMP PJSM. M/U Halliburton 9 5/B" ret bridge plug. 14:00 - 17:00 3.00 CLEAN P DECOMP PJSM. RIH wI bridge plug on 3 1/2" DP, (251) jts total. 118K up wt, 92K down wt. 17:00 - 19:00 2.00 CLEAN P DECOMP Space out & set RBP @ 7934'. RlU & test RBP to 1000 psi for 15 min. Tested Good. 19:00 - 20:00 1.00 CLEAN P DECOMP UD 10 singles. Pull & stand back 10 stands. 20:00 - 21 :00 1.00 CLEAN P DECOMP Cut & slip B4 ' of drilling line. 21 :00 - 23:30 2.50 CLEAN P DECOMP Con't to POOH & stand back 31/2" DP & 6 1/4" DCs. UD RBP setting tool. Clear & clean rig floor. 23:30 - 00:00 0.50 CLEAN P DECOMP Nipple down flow nipple. 3/1/2006 00:00 - 03:00 3.00 CLEAN P DECOMP Hold PJSM. R/U shooting nipple. R/U SWS E-line equip. 03:00 - OB:30 5.50 EV AL P DECOMP RIH wI USIT & log from 7900'. Log showed top of good cement @ approximately 2300', wI some spotty sections above to absolute cement free area above 1B70'. OB:30 - 12:00 3.50 EVAL P DECOMP PJSM. Rig down Schlumberger E line. Rig up flow riser & drip pan. 12:00 - 12:30 0.50 EVAL P DECOMP PJSM. Rig up floor to run DP. Pick up Halliburton RTTS. 12:30 - 14:30 2.00 EVAL P DECOMP PJSM. RIH wI Halliburton RTTS. WI (70) jts in the hole, set RTTS @ 2210'. Up wt = 37K, down wt = 37K. 14:30 - 15:30 1.00 EVAL P DECOMP PJSM. Bleed OIA to 0 psi & apply 0 -600 psi gauge on O/A. M/U head pin & pressure test 9 5/B" casing from 2210' - 7934' @ 4000 psi 130 minutes, good test. Monitor OIA & surface equipment during test, no indication of communication to the 01A. Bleed off all pressure. 15:30 - 16:30 1.00 EVAL P DECOMP PJSM. POOH w/3 1/2" DP & RTTS. Printed: 3/20/2006 12: 1 0:24 PM Legal Well Name: WGI-03 Common Well Name: WGI-03 Spud Date: 9/5/1979 Event Name: WORKOVER Start: 2/5/2006 End: 3/20/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/20/2006 Rig Name: NABORS 4ES Rig Number: Date 3/112006 16:30 - 17:00 O.SO P DECOMP UD RTTS. M/U RBP & setting tool. 17:00 - 19:00 2.00 EVAL P DECOMP RIH on 31/2" DP. 42 stands + 25' of single DP. 19:00 - 21 :00 2.00 EVAL P DECOMP Space out & set RBP @ 4017', middle of rubber. Top of tool @ 4013'. Pressure up & test BP to 1000 psi for 30 min. Charted same. Pull 1 stand. Dump 2100# of sand on top of RBP. (Calc 50' of fill) RIH & tag fill @ 396S'. 21 :00 - 23:00 2.00 EVAL P DECOMP POOH w/3 1/2" DP. Stand back same. UD setting tool. 23:00 - 00:00 1.00 EVAL P DECOMP Clear & clean rig floor. R/U to perform weekly BOP test. 3/2/2006 00:00 - 01 :00 1.00 EVAL P DECOMP M/U running tool. Set test plug. R/U test equip. 01 :00 - 06:00 5.00 EVAL P DECOMP Test BOPE as per AOGCC/BP requirements. LP 250 psi. HP 4000 psi. Annular 3S00 psi. Jeff Jones wI AOGCC waived witnessing BOP test. No failures. 06:00 - 07:00 1.00 EVAL P DECOMP PJSM. Pull test plug, rig down test equipment. 07:00 - OB:30 1.50 EVAL P DECOMP PJSM. Pick up Baker multi stirng cutter wI blades that open to max OD of 11". OB:30 - 11 :00 2.50 FISH P DECOMP PJSM. RIH wI multi string cutter on 3 1/2" DP. Kelly up on jt # 69. DP + BHA = 2190'. Establsih parameters. 42K up wt, 42K down. 11 :00 - 13:00 2.00 FISH P DECOMP PJSM. Take time to verify collars & identify 20' pup, (bottom @ 2323' DPM), just above top F.O. Position cutter @ 2200', (10' in on jt # 69). Line up OIA thru choke to tiger tank. ) psi on OIA & finish dipslacing well bore to 9.B ppg brine. 13:00 - 14:00 1.00 FISH P DECOMP PJSM. Commence rotating @ 60 - BO RPM 11S00 - 2000 ftllbs torque, (free spin). Bring on pump to 3112 bpm @ 550 psi, & observe torque climb to as much as 10,000 ft Ilbs, (briefly), then drop back to 4000 - 6000 ft Ibs. After 12 - 15 minutes of cutting time, torque has stabalized to just above freespin torque. Pressure @ 3112 bpm still hanging around 500 psi. 14:00 - 1S:00 1.00 FISH P DECOMP PJSM. Pull tooljoint to floor, close bag & pressure up 9 SIB" to 2000 psi to break circulation. Unable to get retruns initialy. Brought pressure on up to 2500 psi, & eventually see returns, (thick Arctic Pack). Circulate to brine returns. Spot (2) pills of (40) bbls heated brine wI (1) bbl Safe Surf O. 15:00 - 1 B:30 3.S0 FISH P DECOMP PJSM. Let pills soak. Down to (1) vac truck for support due to Code Black. Heat brine in pits to 120 degrees & send truck for more brine. 1 B:30 - 19:30 1.00 FISH P DECOMP Circulate out Artic Pack, start @ 4 bpm, 1420 psi & increase to 4.5 bpm @ 1610 psi. Pumped total of 200 bbls. 19:30 - 22:00 2.50 FISH P DECOMP Take on 290 bbls of 9.B ppg brine. Allow fluid to soak in annulus. 22:00 - 23:00 1.00 FISH P DECOMP Circulate out Artic Pack. Pumped 40 bbls of Safe-Surf "0" . displaced wI 100 bbls of 120 degree 9.B ppg brine. 5 BPM @ 2300 psi. annulus cleaned up. SID & monitor annulus. 23:00 - 00:00 1.00 FISH P DECOMP Open annular & circulate 9 S/8" casing & warm up inside fluid. SID. 3/3/2006 00:00 - 00:30 0.50 FISH P DECOMP RID circulating equip. Blow down lines. R/U to POOH. 00:30 - 01 :30 1.00 FISH P DECOMP POOH wI Multi-string cutting Assy. Stand back 3 1/2" DP. Inspect cutters. Good indication of cut. UD Cutting Assy. OD of cutter blades when opened still 11 ". 01 :30 - 02:30 1.00 FISH P DECOMP Clear & clean rig floor. P/U & set test Plug. 02:30 - 04:00 1.S0 BOPSU P DECOMP Change out rams for 9 5/8" casing. Perform body test. 2S0/4000 psi, OK. Charted same. 04:00 - 06:00 2.00 FISH P DECOMP P/U spear assy as follows: Engage spear into 9 5/B" casing. Printed: 3/20/2006 12: 1 0:24 PM ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: Spud Date: 9/5/1979 End: 3/20/2006 3/312006 04:00 - 06:00 2.00 FISH P DECOMP BOLDS. 06:00 - OB:OO 2.00 I FISH P DECOMP Unable to back out (1) lock down screw.... packing gland nut threads stripped ..., repair same. 08:00 - 09:00 1.00 FISH P DECOMP PJSM. Pull to 175K, see mandrel hanger come free. Work pipe up hole up to 8 -10', pulling up to 75K over. (up wt = 100K). Stacking out when going back down. 09:00 - 10:30 1.50 FISH P DECOMP PJSM. Line up & circulate & pull mandrel hanger to floor wI circulating @ 1 1/2 bpm @ 750 -850 psi. Pull mandrel hanger to floor. Rig up floor for 9 5/B" casing, break out & lay down Baker spear assembly, break out & lay down mandrel hanger, make up head pin to circulate. 1 0:30 - 13:30 3.00 FISH P DECOMP PJSM. Circulate & work pipe, initially unable to go down, but eventually work to being able to slack off while circulating. Circulating pressure dropped to 4 bpm @ 450 psi. Circulate to clean up heavy arctic pack wI some gas returns. 13:30 - 00:00 10.50 FISH P DECOMP PJSM. POOH wI 9 5/B" casing. NOTE: Slow trip due to casing coated wI arctic pack & average torque required to break each connection = 27,000 - 30,000 ftllbs, requiring some heating up to get each one to break. All required hammering to break connections. Centralizers on collars of jt # 5, 10, 15, 20, 25, 30, 35, 40, 46, 50, 54. Cut looks ragged as if pipe was in compression. Recovered 54 jts =2154.53' + Cut off jt = 17.05'. Pup & Hanger = 5.85'. Calc. depth to cut = 2199.43'. 3/4/2006 00:00 - 03:30 3.50 FISH P DECOMP Clear & clean rig floor. RID 9 5/B" handling tools. Took extra time to clean rig floor due to Artic Pack. 03:30 - 06:00 2.50 BOPSU P DECOMP Change rams for 31/2" DP. Test 250 14000 psi. & Chart same. 06:00 - OB:OO 2.00 BOPSU P DECOMP PJSM. Hinge seal in pipe ram door leaking hydraulic fluid. Set test plug & repar same. Pull test plug. OB:OO - 10:00 2.00 CLEAN P DECOMP PJSM. M/U B 1/2" bit & 9 5/B" scraper assembly. 1 0:00 - 11 :30 1.50 CLEAN P DECOMP PJSM. RIH wI scraper assembly on 31/2" DP. Soft tag 20' in on @ 2193'. 11 :30 - 12:30 1.00 CLEAN P DECOMP Pick up kelly. Establish parameters. 60K up wt, 60K down wt, 60K rotating wt. Bring on pump @ 4 1/2 bpm I 500 psi & rotate @ 60 RPM. Rotate & wash down to 2293', tag top of stub wI junk sub. 12:30 - 13:30 1.00 CLEAN P DECOMP PJSM. Pick up 3' & close bag. Reverse circulate @ 5 bpm I 600 psi, 3B9 bbls total, to clean retums. 14:00 - 14:30 0.50 CLEAN P DECOMP PJSM. Stand back kelly & POOH w/31/2" DP & scraper assembly. 14:30 - 16:00 1.50 CLEAN P DECOMP Set back 61/4" DCs. Breal out & UD Bit & Scraper Assy. 16:00 - 1 B:OO 2.00 CLEAN P DECOMP R/U to floor wI Washpipe handling tools. 18:00 - 20:00 2.00 CLEAN P DECOMP M/U BHA # 2B as follows: Shoe, 2 Jts Wash Pipe, Boot Basket, XO, Bumper Sub, Jars, XO, 9 * 6 1/4" DCs, XO. TL= 35B.95'. RIH wI same. 20:00 - 22:00 2.00 CLEAN P DECOMP RIH wI BHA # 28. Tagged up & took weight @ 2071'. 1B stands + 8' of stand 19. 22:00 - 00:00 2.00 CLEAN P DECOMP P/U kelly break circulation,3 BPM @ 250 psi. Wash & ream from 2071 to 2200'. Top of stub @ 2200' Con't to Wash & ream from 2200 to 2239'. Found connection @ 2223'. worked up & down for 45 min until washpipe will slide over wI no rotation or problems. P/U, SIO & Rot Wts = 55K. WOB 2-3K, Torq = 3-BK, 60 RPMs. Printed: 3/20/2006 12: 1 0:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS4ES Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: Spud Date: 9/5/1979 End: 3/20/2006 3/S/2006 00:00 - 00:30 O.SO CLEAN P DECOMP Finish working washpipe up & down thru 9 SIB" connection @ 2223'. Now able to slide over connection wlo rotation or taking weight. 00:30 - 02:00 1.S0 CLEAN P DECOMP Close bag reverse circulate well. 4 BPM @ 4S0 psi. Circulated out cement & Artic Pack. 02:00 - 03:00 1.00 CLEAN P DECOMP Set back kelly. Blow down lines. POOH wI Washpipe Assy. 03:00 - OS:OO 2.00 CLEAN P DECOMP Break out & UD Wash pipe assy. Inspect shoe, No damage just wear. Recovered 4.S" band of casing. Ragged piece from cut. Boot Basket contained cement & metal filings. OS:OO - 06:30 1.S0 CLEAN P DECOMP UD Wash Pipe handling equip. Clear & clean rig floor. 06:30 - 10:30 4.00 FISH P DECOMP PJSM. Rig up Schlumberger Eline. RIH wI 12', (3) strands string shot, tie in depth. Position string shot f/221B' - 2230' & fire, good indication at surface. POOH & rig down Eline. 10:30 - 12:30 2.00 FISH P DECOMP PJSM. Pick up back off assembly. 12:30 - 1S:30 3.00 FISH P DECOMP RIH wI back off assembly on 3 1/2" DP, filling each stand wI water. RIH wI 23 stands, up st = 61 K, down wt = 61 K. 1S:30 - 16:00 O.SO FISH P DECOMP PJSM. Pick up a single, make up headpin & position top of upper anchor @ 2212', top of bottom anchor @ 2234', (connection @ 2223'). Pressure up to 1200 psi to set bottom anchor, slack off SK & verify, continue up to 3S00 psi & set top anchor, slack off 30K, set rotary table slips & bleed pressure. Wait S minutes & pressure up to back off 9 SIB" connection @ 2223'. See pipe turn w/1S00 psi = 15,000 ftllbs of torque. Get 1/2 turn, bleed pressure & see next half turn go at 1200 psi = 12,000 ftllbs of torque. Turn total of (S) full turns, final cycles turning @ 600 - 700 psi. 16:00 - 17:00 1.00 FISH P DECOMP Drop dart. Pressure up & shear out circ. sub wI 2700 psi. Reverse out fresh water. 17:00 - 1 B:OO 1.00 FISH P DECOMP POOH wI Back off Assy. 1 B:OO - 20:00 2.00 FISH P DECOMP Break out & UD BHA # 29. 20:00 - 21 :00 1.00 FISH P DECOMP Clear & clean rig floor. 21 :00 - 22:30 1.S0 FISH P DECOMP P/U BHA # 30 as follows: Bull Nose, Spear Pack Off, Spear, Extension, Stop Sub, Bumper Sub. Jars, XO. TL = 36.41'. RIH wI same on 22 stands + double od 3 1/2" DP. 22:30 - 23:00 O.SO FISH P DECOMP P/U kelly. Break circulation & tag stump @ 2200' Engage spear into 9 SIB" csg 10'. P/U & ensure grapples holding. Slack off & make 6 full turns in pipe. P/U & csg stub is free. 23:00 - 00:00 1.00 FISH P DECOMP POOH BHA #30 & csg stub. 3/6/2006 00:00 - 01 :30 1.S0 FISH P DECOMP Break out & UD BHA # 30. Recovered 22.S' cut off section of 9 SIB" casing. Cut looked Good. Pin end looks good, no damage or swelling. Did not see any indication (scratchesloxidation etc) of a centralizer on the pin end. UD same. 01 :30 - 04:30 3.00 BOPSU P DECOMP Change out pipe rams for 9 SIB" casing. Test BOP body 2S0/3S00 psi. Had leak & needed to re-dress plug to get seal. test good & Charted same. 04:30 - 06:30 2.00 CASRE INTERV Clear & clean rig floor. R/U floor & casing torque-turn tools to run 9 SIB" tie-back string. 06:30 - 07:00 O.SO CASRE INTERV Pre job meeting wI all parties with regard to running 9 S/8" premium thread casing. Emphasis on not getting in a hurry, proper torque, hand & body positioning & pipe handling. 07:00 - 11 :30 4.S0 CASRE P INTERV Pick up & make up triple connect 9 SIB" screw in sub, HES baffle collar wI plug in place, 9 SIB" pup jt, HES ES Cementer, XIO jt & 9 S/8" 47#, L-BO, TCII casing. All connections below Printed: 3/20/2006 12:10:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3/6/2006 1S:30 - 16:30 INTERV INTERV INTERV 16:30 - 1B:00 1.S0 P INTERV 1 B:OO - 22:30 P INTERV 22:30 - 23:00 P INTERV 23:00 - 00:00 1.00 REMCM P IINTERV 3/7/2006 00:00 - 01 :30 1.50 REMCM P INTERV 01 :30 - 02:00 O.SO REMCM P INTERV 02:00 - 03:30 1.50 REMCM P INTERV WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES r~m- TOIH_ 07:00 - 11 :30 I 4.S0 CASRE I I I 11 :30 - 12:30 I I 12:30 - 1S:30 I 03:30 - 04:00 O.SO REMCM P INTERV 04:00 - 07:00 3.00 BOPSU P INTERV 07:00 - OB:30 1.S0 WHSUR P INTERV OB:30 - 10:30 2.00 WHSUR P INTERV 10:30 - 1S:00 4.S0 WHSUR P INTERV 1S:00 - 16:00 1.00 WHSUR P INTERV 16:00 - 1 B:OO 2.00 WHSUR P INTERV 1 B:OO - 22:00 4.00 WHSUR P INTERV Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: Spud Date: 9/5/1979 End: 3/20/2006 X/O Baker Locked. All 9 SIB" TCII connections torque turned to 17,SOO ftllbs using Jet Lube Seal Guard thread dope. Filling pipe every jt. WI 23 jts in the hole, note pipe is filling from wellbore...., plug is off seat. PJSM. Make up circulating head on Jt # 23. Break circulation to pump HES plug back on seat. Work up to 6 bpm @ 200 psi, & observe plug go on seat. Pressure up to 700 psi & observe pressure bleeding off @ 100 psi in S minutes. Bleed off all pressure. Continue in hole wI 9 S/8" casing, torque turning each connection to 17,SOO ftllbs as described above. w/S3 jts in the hole, 99K up wt, 99K down wt. M/U head pin & pressure up on 9 SIB" casing to SOO to verify plug on seat prior to screwing into collar @ 2223'. Break out head pin, M/U jt # S4 & get freespin torque of 1200 ftllbs. WI 33' in on jt #S4 observe torque beginning to increase & weight increasing indicating threads making up. Achieve final torque of 12,000 ftllbs w/11-12 turns achieved. Work pipe & apply 12,000 ftlbs wI no significant turning. Call it good. Pull test to 2S0K, OK. Pressure up to 2000 psi for (S) minutes, observe no bleed off. Attempt to pressure on up to 2600 psi & observe ES Cementer open @ 2200 psi, full returns. PJSM. Circulate @ 6 bpm, 2S0 psi while waiting on cementers. RID casing tools. Circulate well @ 3 BPM @ 1S0 psi. R/U cementers & spot in trucks. Wait on lab results for cement blend. Hold PJSM & review cementing procedure & personnel assignments. Batch mix Gasblok Latex cement slurry. Con't to batch up 1S0 bbls of Gasblok cement. Pressure test lines to 4000 psi, OK. Pump 5 bbls of fresh water. Pump 1S0 bbls of Gasblok (777 sX), 1S.8 ppg, 1.17 ft3/sx. @ 6 BPM, 610 psi. Drop Plug & wash down w/S bbls of FW. Displace plug w/1S7 bbls of 9.8 ppg brine. pumped @ 7 BPM 1200 psi. Slowed down to 2 BPM @ 82Spsi. Bumped plug & closed ES cementer w/1S00 psi, Pressure up to 220 psi & held fpr 2 min. Bled off & no flow back. PD @ 0300 hrs. Had in excess of 18 bbls cement to surf. CIP @ 03:00. Blow down lines, Wash up & RID cementing equip. Drain stack. N/D BOPE. Cement @ 7S0 psi @ 5:30. PJSM Center pipe in wellhead & set 9 SIB" emergency slips wI 190K, (up wt = 100K). PJSM. Set up Wachs casing cutter & cut 9 SIB" casing, UD cut off section. PJSM. Center 9 SIB" casing in wellhead & install 9 S/8" primary pack off. RILDs. Install secondary packoff, unable to install, consult town, opt to go with McEvoy tbg spool & secondary pack off. PJSM. Get McEvoy equipment headed this way. N/D Vetco Grey spool & chnage out pipe rams to 31/2" x 6" VBRs. Wait on new Spool. Cut & dress 9 SIB" casing. N/U new McEvoy 13S/8" x 13 SIB" SM Spool. Printed: 3/20/2006 12:10:24 PM ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: Spud Date: 9/5/1979 End: 3/20/2006 Pressure test pack off to 3BOO psi. Bleed off 100 psi in 10 min. Last 20 min held @ 3700 psi. Good Test. 23:00 - 00:00 1.00 INTERV N/U BOPE. 31812006 00:00 - 02:00 2.00 INTERV Con't to N/U BOPE. Install 2nd annulus valve. 02:00 - 04:00 2.00 INTERV Set test plug & test BOP body & breaks. Test plug leaked & had to re-set & run in all lock down bolts to get test. 250/4000 psi. 04:00 - 04:30 0.50 WHSUR P INTERV Pull Test plug. P/U & install Wear Bushing. 04:30 - 06:00 1.50 CLEAN I P INTERV M/U BHA #31 as follows: B 1/2" Bit, 2 * Boot Baskets, Bit Sub, Bumper Sub, Jars, XO, 9*61/4" DCs, XO. TL = 306.74'. 06:00 - 07:30 1.50 CLEAN P INTERV PJSM. RIH w/3 1/2" DP & BHA. Soft tag @ 2171'. 07:30 - 10:30 3.00 CLEAN P INTERV PJSM. Pick up kelly on jt #59 & establish parameters. Up wt = 57K, down wt = 57K rotating wt = 5BK. Bring on pump @ 5 1/2 bpm. Rotate @ BO -100 RPM. Off bottom torque = 1500 ftllbs. Mill medium soft to 2200', hardened up a bit then see top plug @ 220B', (6' in on jt #60). Mill top plug w/5 -10K WOB. Through bottom plug @ 10:30. 10:30 - 11 :30 1.00 CLEAN P INTERV CBU @ 5112 bpm 1350 psi. Clear Iclean rig floor. Ran hose down through OIA valve & sucked out 2' -3' of water out of 9 5/B" x 13 3/B" annulus wI trash pump, saw thick cement returns. 11 :30 - 14:00 2.50 CLEAN P INTERV POOH w/3 1/2" DP & BHA. UD BHA. 14:00 - 15:00 1.00 CLEAN P INTERV PJSM. Close blind rams & open OIA valve. Pressure up 95/B" casing from surface to 4017' & close in OIA valve. Pressure bled 100 psi in 1 st 15 minutes & 30 psi in 2nd 15 minutes, test is good. Open OIA valve & observe no indication whatsoever of any pressure release, air or fluid. 15:00 - 16:00 1.00 CLEAN P INTERV Drain BOP stack. M/U BHA # 32 as follows: . 16:00 - 21 :00 5.00 CLEAN N RREP INTERV Pull Wear Bushing. Install Test plug. Change out Ram door on drillers side of BOP. Body test breaks. 250/4000 psi. Pull test plug. Set Wear Bushing. 21 :00 - 23:00 2.00 CLEAN P INTERV RIH wI BHA #32 on 31/2" DP. 38 stands + single. 23:00 - 00:00 1.00 CLEAN P INTERV P/U kelly. RIH & dry tag @ 3956'. Break circulation & work junk basket down from 3956-61 '. Wash over junk. Had very high circulating pressure from apparent plugged jet. 2-31/2 BPM @ 1500-3500 psi. 70 RPMs, 2-4K torq.. P/U Wt = BOK, SIO wt =75K, Rot Wt = 77K. 3/9/2006 00:00 - 00:30 0.50 CLEAN P INTERV Finish Reverse circulating wI junk basket. to 3961'. P/U Wt = BOK, SIO Wt = 75K, Rot Wt = 77K. 2 -3 1/2 BPM @ 1500-3500 psi. Made total of 5'. Good indication of junk pick up. Jets showing some blockage. 00:30 - 03:00 2.50 CLEAN P INTERV Start to break kelly. Well back flowing. & not drainning. ( Plugged jets) & well out of balance from 10.9# fluid below 2200'.. Mix & Pump 10# pill. No good. Circulate well & even out weight to 9.8 ppg. Save 10.9 PPG fluid. As circulating Jet unpluggging. Final circulation rate @ 5 BPM @ 2500 psi. 03:00 - 05:00 2.00 CLEAN P INTERV POOH wI RCJB Assy on 31/2" DP. 05:00 - 06:00 1.00 CLEAN P INTERV Break out RCJB & inspect same. 2 of 3 jets were plugged wI cmt & metal debris. Recovered rubber & cement small arnt of metal. Break out boot baskets, clean & empty. 2 gallons of cement wI some pieces of float equipment in baskets. 06:00 - 07:00 1.00 CLEAN P INTERV PJSM. M/U Reverse circulating junk basket assembly 07:00 - 09:00 2.00 CLEAN P INTERV RIH wI RC/JB assembly. Printed: 3120/2006 12: 1 0:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 2/5/2006 3/20/2006 Spud Date: 9/5/1979 End: 3/20/2006 3/912006 109:00 - 10:00 1.00 CLEAN P INTERV PJSM. Kelly up on jt # 115. Up wt = 79K, Down wt = 74K, Rotating wt = 77K. Dry tag 20' in on kelly @ 3963'. Pick up & bring on pump @ 5 3/4 bpm @ 1700 psi & attempt to wash down without rotating, unable to. Pick up & kick in rotary table @ 60 -BO RPM, 2000 ftllbs torque, (off bottom), & mill on junk while pumping @ 3 bpm I SOO psi., 2 - 5K WOB. After 5 minutes of this, bring pump up to 6 bpm 12000 psi, then pick up, kick out rotary table & attempt to wash down. Repeat this process B-1 0 times. Attempt to wash down (1) time while rotating & pumping @ 5 1/2 bpm @ 1700 psi, putting 10K WOB, obvious solids in the hole. Suspect cement fell in form 9 SIB" x 133/8" annulus after cutting I pulling 9 SIB" casing @ 2200'. Final depth = 30' in on kelly @ 3973'. 10:00 - 12:00 2.00 CLEAN P INTERV PJSM. POOH w/3 1/2" DP & RCIJB assembly. 12:00 - 13:00 1.00 CLEAN P INTERV PJSM. Stand back collars & break down reverse circulating basket. Recovered numerous chunks of cement & (2) smallish aluminum pieces. Opt to go back in wI B 1/2" rock bit. 13:00 - 14:00 1.00 CLEAN P INTERV PJSM. Pick up B 1/2" rock bit wI jets removed, (2) junk subs, bit sub, bumper sub, oil jars, xIo, (9) 6 1/4" DCs & xIo. 14:00 - 1S:30 1.50 CLEAN P INTERV RIH wI cleanout BHA on 3 1/2" DP. 1S:30 - 15:30 24.00 CLEAN P INTERV PJSM. Kelly up on jt #115. 79K up wt, 74K down, 77K rotating wt. Bring on pump @ 2 -3 bpm 1400 psi & mill from 3973' - 3980' w/2 -5K WOB, rotating @ BO - 100 RPM. Kick out rotary table, pick up & bring pump rate up to 6 bpm 11100 psi & able to wash down with no resistance to 4006', (top of bridge plug @ 4013'). 1S:30 - 17:00 1.50 CLEAN P INTERV PJSM. Pump (30) bbls Hi Vis sweep @ 6 bpm 11100 psi. See some cement & sand in returns, circulate to clean returns. 17:00 - 19:30 2.S0 CLEAN P INTERV PJSM. Reverse Circulate 40 bbl Hi-Vis @ 6 bpm 11300 psi wI bit @ 4006'. 19:30 - 20:30 1.00 CLEAN P INTERV POOH wI Clean out BHA on 3 1/2" DP. 20:30 - 22:30 2.00 CLEAN P INTERV Break out BHA & UD same. Empty junk baskets. Recovered 2 gals. of cement & a few small pieces of metal. Clear & clean rig floor. 22:30 - 23:30 1.00 CLEAN P INTERV P/U & M/U running tool. Pull Wear Bushing. Re-dress & set test plug. UD running tool. 23:30 - 00:00 O.SO BOPSU INTERV Begin testing BOPE as per AOGCC I BP requirements. 3/10/2006 00:00 - 04:30 4.S0 BOPSU INTERV Test BOPE as per AOGCC/BP requirements. No failures. LP 2S0 psi, HP 4000 psi. BOP test witnessing waived by Chuck Sheve wI AOGCC. 04:30 - 05:30 1.00 BOPSU INTERV Blow down lines. Drain stack. RID test equip. Pull test plug. Install Wear Bushing. 05:30 - 06:30 1.00 FISH P INTERV P/U BP retreiving tool. 06:30 - 09:00 2.50 FISH P INTERV PJSM. RIH w/3 1/2" DP, tag sand top @ 4006'. 09:00 - 09:30 0.50 FISH P INTERV PJSM. Reverse circulate @ S 1/2 bpm 11200 psi down to 4011' wI 9.B ppg brine to clean returns. 09:30 - 10:30 1.00 FISH P INTERV PJSM. Circulate 10.9 ppg brine around, displacing out the 9.B ppg brine. 10:30 - 11 :00 0.50 FISH P INTERV PJSM. Reverse circulate down to top of Halliburton 9 S/8" RBP. Confirm latched up w/1 OK overpull & reverse out sand to clean returns, 55 bbls. 11 :00 - 12:00 1.00 FISH P INTERV PJSM. Pull to 90K, then set down 20K on RBP, turn to the right & hold torque & pick up to 90K, (15K over up wt). Wait a few to Printed: 3/20/2006 12:10:24 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 2/5/2006 3/20/2006 Spud Date: 9/5/1979 End: 3/20/2006 3/1 0/2006 11 :00 - 12:00 1.00 FISH P INTERV let rubber elements relax. Repeat several times. Pick up to 95K & observe bridge plug release. Work up & down a few times & break off head pin. Well stable. 12:00 -14:00 2.00 FISH P INTERV POOH. Stand back DP. 14:00 - 15:00 1.00 FISH P INTERV UD Halliburton bridge plug. Recovered (3) fair sized pieces of aluminum in retrieving tool. M/U retrieving tool to fetch bridge plug @ 7934'. 15:00 - 18:00 3.00 FISH P INTERV RIH wI bridge plug retrieving BHA on 3 1/2" DP. 1B:00 -19:00 1.00 FISH P INTERV Reverse circulate at 5 bpm 11350 psi to clean up any sand or debris around plug. Pumped a total of 1 B3 bbls. 19:00 - 20:30 1.50 FISH P INTERV Latch onto RBP. Up weight = 137K Down weight = 95K. Stack 25K on fish to ensure latched onto fishing neck. Turn to right holding torque and begin to pick up to unseat plug. Wait a little to allow elements to relax. Fill up stack with brine to monitor well dead - good. Work plug up and down to ensure plug is engaged and that slips are fully released. TOH with 1 single joint of DP and a pup. 20:30 - 00:00 3.50 FISH P INTERV Circulate bottoms up 1.5x at 4 bpm 1750 psi. 3/11/2006 00:00 - 01 :00 1.00 FISH P INTERV Continue circulating bottoms up at 4 bpm I 750 psi. Pumped a total of 730 bbls. Montior well dead - good. 01 :00 - 03:00 2.00 FISH P INTERV PJSM. TOH with BO stands of 3.5" DP and DCs with Halliburton pulling tool and RBP that was set @ 7934'. Monitored pit gainlloss to ensure we were not swabbing the well while TOH. Stand back DP and DCs. 03:00 - 06:00 3.00 FISH P INTERV On surface with RBP. Retrieved plug body but appear to have lost both (2) rubber elements downhole. Break down and lay down Halliburton plug and retrieving tool. Discuss plan forward due to large rubber elements now needing to be fished out of hole. Decision made to run B 1/2" OD Jet Basket down to top of tubing stump. MU BHA #34 and open up pipe rams to start TIH. Noticed rubber element floating on top of fluid column. Recovered total of 1 full element and about 75% of 2nd element. Decision made to go back in with 5 7/8" Jet Basket. Break down BHA and re-make up BHA #34 as follows: 5 7/8" Reverse Circulating Basket, 1 jt of DP, Sub, Boot Basket, Boot Basket, Bit, Bumper Sub, Jar, XO, 9 DCs and XO. 06:00 - 09:30 3.50 CLEAN P INTERV Begin TIH with BHA #34 and BO stands of 3.5" DP and DC's to plug body at 79B1'. BO stands. 09:30 - 11 :00 1.50 CLEAN P INTERV PJSM. Pick up 24' DP pup jt. Kelly up. Establish parameters. 147K up wt, 104K down wt, 120K rotating wt. Bring on pump @ 6 bpm 12000 psi & wash down to 5' in on kelly, (7960'), & take weight. This is the top of the 7 5/B" tubing stub above the packer. Pick up & kick in rotary table @ 25 RPM & rotate down thru stub. Kick out rotary table & wash on down to a final depth of 79B2' DPM. (27' in on kelly). Contact plug in 7" RIN Nipple. Pick up & wash back down a few times, pick up above stub & had to rotate back through once more. Wash to plug one final time, set down 15K pumping @ 6 bpm 12000 psi throughout the operation. 11 :00 - 14:00 3.00 CLEAN P INTERV PJSM. POOH w/3 1/2" DP & cleanout BHA. 14:00 - 16:00 2.00 CLEAN P INTERV PJSM. LID drill collars. Break out & UD RC/JB. Recovered 10 -15 pieces of broken up control line & band parts. 16:00 - 1 B:OO 2.00 RUNCO RUNCMP RU Test Equipment and remove Wear Ring from Spool. Install Printed: 3/20/2006 12: 1 0:24 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: Spud Date: 9/5/1979 End: 3/20/2006 Test Plug. Change out Pipe Rams to 7 5/B". Pressure test to 250 psi low and 3500 psi high - good test. RD Test Equipment. Pull Test Plug. Clear and Clean Rig Floor in preparation for RU of GatorHawk. PJSM with Nabors, GatorHawk, Vam and Baker to discuss procedure and risk assessment of RU GatorHawk and Torque Turner. RU GatorHawk and Torque Turner. Ensure all spacing on Rig Floor is adequate to complete job safely. PJSM with Nabors, GatorHawk, Vam and Baker to discuss running of the 7 5/B" Completion. Begin running 7 5/8" Completion as per procedure. Baker Lok'd all connections below the Packer and the XO's above and below the "R" Nipple. Having problems with square shoulder collars hanging up in the Tubing Hanger with each joint of Tubing being run due to mis-alignment of Wellhead I BOP Stack I Rig. Stop to diagnose and mitigate problem but still hanging up. Proceed slowly with running of 7 5/B" Tubing. All 7 5/B" Tubing connections are being pressure tested with Nitrogen to 3BOO psi with GatorHawk. The make-up torque of the connections is 14,450 ft-Ib and being confirmed with Torque Turn. Had (1) connecdtion fail the gator hawk test...#76..., backed it out, cleaned & inspected threads, remade up & retested, OK. Continue in. INTERV Continue TIH with 7 5/B" 29.7# L-BO Vam Top HC Tubing. GatorHawking all connections and Torque Turning to specifications. Baker Lok'd the connections above and below the "DB" Nipple. Damaged the Threads on Joints #155 and #156 and replaced them. Continue TIH with rest of Tubing. Tag up 6" in on jt # 197. INTERV PJSM. UD Jts # 197, 196 & 195. Jt 196 is 39.83'. M/U (2) space out pups, 2.16' & 9.46'. M/U Jt # 195. M/U hanger & landing jt. 222K up wt, 167K down. Ensure LDs are backed out. INTERV PJSM. Drop rod I ball assembly. Pressure up on tubing to 4000 psi to set packer & test tubing. Testing 7 5/B" tubing from surface to rod ball assembly in RIN Nipple @ 7935'. Pressure bled 40 spi in 1 st 15 minutes & 10 psi in 2nd 15 minutes, good test. Bleed tbg to 1500 psi & pressure up on IIA wI diesel to 4025 psi from surface to top of packer @ 7910'. Pressure bled 20:30 - 21 :00 RUNCMP 21 :00 - 23:00 2.00 RUNCMP 23:00 - 00:00 1.00 RUNCMP 3/12/2006 00:00 - 00:00 24.00 RUNCMP 3/13/2006 00:00 - 06:00 6.00 RUNCO 06:00 - 07:00 1.00 RUNCO 07:00 - OB:OO 1.00 RUNCO INTERV OB:OO - 09:30 1.50 RUNCO INTERV 09:30 - 11 :00 1.50 RUNCO INTERV 11 :00 - 11 :30 0.50 RUNCO INTERV 11 :30 - 12:00 0.50 RUNCO INTERV 12:00 - 14:30 2.50 RUNCO PJSM. Land tubing. RILDs. UD landing jt. PJSM. Rig down floor, LID Gator Hawk equipment & torque turn equipment. Rig up to circulate well. PJSM. Reverse circulate 95 bbls of 125 degree seawater wI corrosion inhibitor. Final circulating pressure, 3 bpm @ BOO psi. Close IIA valve. PJSM. Rig up Little Red Hot Oil Services & pressure test lines @ 2000 psi, OK. Open IIA valve & reverse circulate 50 degree diesel @ 3 bpm down IIA, taking 10.9 ppg brine returns up 7 5/8" tubing to pits. Final circulating pressure, 3 bpm @ 1300 psi. 45 bbls pumped. Printed: 3/20/2006 12: 1 0:24 PM It Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 2/5/2006 3/20/2006 Spud Date: 9/5/1979 End: 3/20/2006 3/13/2006 60 psi in 1st 15 minutes & 20 psi in 2nd 15 minutes, good test. I Bleed all pressrue off of I/A, then bleed all pressure off of tubing. Monitor well, well stable. 14:30 - 17:00 2.50 RUNCOt INTERV PJSM. Rig up Schlumberger Slickline, Rig down Little Red Hot Oil Services. 17:00 - 20:00 3.00 RUNCO INTERV RIH with Slickline to pull Ball and Rod from RHC-M at 7931'. Pull Ball and Rod successfully with no problems. RIH with Slickline to pull RHC-M plug body - pulled successfully. On surface with Slickline. 20:00 - 21 :00 1.00 RUNCO INTERV PJSM. RD Schlumburger Slickline. Clear and clean Rig Floor. 21 :00 - 21 :30 0.50 FISH P INTERV PJSM. Drill Site Maintenance on location to install Two-Way Check Valve in preparation for changing of Pipe Rams. Two-Way Check installed with T-Bar with no problems. 21 :30 - 23:00 1.50 FISH P INTERV Change out Pipe Rams from 7 5/8" to 31/2" for upcoming BHA with DP run. Pressure tested Pipe Rams to 300 psi low and 4000 psi high - good test. Pull Two-Way Check with Lubricator and RD Drill Site Maintenance. 23:00 - 00:00 1.00 FISH P INTERV PJSM. PU and MU BHA #35 as follows: GS Hydraulic Spear, XO, Bumper Sub, Super Oil Jars and Pump Out Sub. OAL = 24.B1 '. Make up BHA with one single joint of DP. 3/14/2006 00:00 - 04:30 4.50 FISH P INTERV Begin TIH with BHA #35 (GS Spear) and 251 jts of DP (BO stands plus 11 singles). After all 80 stands of DP in the hole, cut and slip Drilling Line. Continue TIH while PU single joints of DP from Pipe Shed. 04:30 - 07:30 3.00 FISH P INTERV PU Kelly. UW = 112K and DW = 100K. Start pumping 10.9 ppg @ 3.5 bpm I 2150 psi to wash down to Plug Body and tag. Having trouble getting into original Tubing Stump @ 7959' (4' Kelly in). Rotate to get into original 7518" Tubing and continue RIH. Tag Plug Body with 29' Kelly in. Attempt to latch but no signs of having the Plug. No change in pressure noted. Well not on a vacuum and cannot bullhead into the formation. Make several more attempts to latch up without apparent success. 07:30 - 10:30 3.00 FISH P INTERV PJSM. Stand back kelly & POOH w/3 1/2" DP & GS standing back DP. 10:30 - 12:30 2.00 FISH P INTERV On surface with BHA #35 GS Spear. Inspect Spear and noticed that there was damage to the Keys, missing about (7) of them. Lay down Spear and decide to run a Reverse Circulating Basket small enough to get inside Plug Body. Make up BHA #36 as follows: 3 5/B" Reverse Circulating Junk Basket, XO, Boot Basket, Boot Basket, XO, Bumper Sub, Oil Jar and Pump Out Sub. 12:30 - 15:30 3.00 FISH P INTERV TIH with BHA #36 on 251 jts of 3.5" DP from the Derrick. 15:30 - 16:30 1.00 FISH P INTERV MU Kelly. UW = 115K DW = 101 K. Come online with Pump at 4 bpm 11600 psi and wash and rotate down through junk on top of Plug. Rotation set at 15 RPM. Made hole from 79B2'- 79B4'. 16:30 - 20:00 3.50 FISH P INTERV Stand back Kelly. TOH with BHA #36 while standing back DP. 20:00 - 21 :00 1.00 FISH P INTERV On surface with BHA #36. Break down BHA and inspect Jet Basket and both Boot Baskets. Recovered about (5) Keys, pieces of broken and flattened Control Line and pieces of Control Line Bands. Both Boot Baskets were completely filled with metal shavings I cuttings. Decision made to re-run same BHA for another clean-out run. Printed: 3/20/2006 12: 1 0:24 PM - Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 2/5/2006 3/20/2006 Spud Date: 9/5/1979 End: 3/20/2006 3/14/2006 21 :00 - 23:15 2.25 FISH P INTERV TIH with BHA #37 (same as BHA #36) on 251 joints of 3.5" DP from Derrick. 23:15 - 00:00 0.75 FISH P INTERV MU Kelly. UW = 11 BK DW = 96K. Come online with Pump at 4 bpm 11600 psi and wash down to top of Plug. Stack out completely at 16' Kelly in the hole = 7984'. PU and drop back down to re-tag, tagged at 16' Kelly in again. Repeat one more time. Sit on bottom circulating for 30 minutes. PU and RIH to 15' Kelly in which is one foot from bottom and rotate 10 times with 2000 ft-Ib of torque. PU and RIH to tag again and reached 16' of Kelly again. 3/15/2006 00:00 - 03:00 3.00 FISH P INTERV Stand back Kelly and begin TOH with Circulating Basket BHA and 251 joints of DP. Stand back DP in preparation for Spear. 03:00 - 04:00 1.00 FISH P INTERV On surface with BHA #3B. Break down BHA and inspect Jet Basket and both Boot Baskets. Recovered about (2) more pieces of Keys, pieces of broken and flattened Control Line and pieces of Control Line Bands. Both Boot Baskets were completely filled with metal shavings I cuttings again. Due to full Boot Baskets, decision made to re-run same BHA for another clean-out run. 04:00 - 07:00 3.00 FISH P INTERV TIH with BHA #39 which is identical to previous. TIH BHA with 251 joints of 3.5" DP from Derrick. Stop at -7,96B'. 07:00 - OB:OO 1.00 FISH P INTERV Pick-up Kelly. Bring Pump on line at 4.0 bpm/1200 psi. PUW = 122K. SOW = 98K. Tag Plug body at 7,9B4'. Wash down to 7,9B4.5'. Work Jet Basket several time. Unable to get any deeper. Set back Kelly OB:OO - 10:30 2.50 FISH P INTERV Trip out with 3 1/2" Drill Pipe and BHA. 10:30 -11:30 1.00 FISH P INTERV Lay down BHA. Jet Basket was empty. Clean Boot Baskets and recovered - 1 gal of sand and metal cuttings. 11:30 -12:00 0.50 FISH P INTERV Make-up BHA #40...5" GS Spear. 12:00 - 14:30 2.50 FISH P INTERV Trip in with BHA #40 and 31/2" Drill Pipe. 14:30 - 16:30 2.00 FISH P INTERV Attempt to enter Tubing Stump at 7959'. Lay down Joint #251 and PU a 9.94' Pup Joint. MU Kelly and work down 27' of Kelly in the hole (7978' which is 6' higher than last tag). Bring on pump at 3 bpm 11400 psi and stacked out 15K at same depth of 797B'. Drill Pipe then packed off preventing circulation. 16:30 - 1B:00 1.50 FISH P INTERV Stand back Kelly. Drop Dart to open Pump Out Sub. Re-make up Kelly and work the BHA down to 797B'. Shear out the Drain Sub. Stand back the Kelly and lay down the Pup Joint. 1 B:OO - 21 :00 3.00 FISH P INTERV TOH with BHA and DP while standing back DP in the Derrick. 21 :00 - 22:30 1.50 FISH P INTERV On surface with BHA #40. Inspect Spear and no nòticeable damage noticed. The Running Tool for the BHA was plugged off completely with sludge (dope, fines, sand). Boot Baskets had one piece of rubber but nothing else. The Magnets had metal shavings on them. Discuss plan forward with Anchorage Engineering and decide to re-run the BHA. BHA #41 made up as follows: GS Spear, XO, 5 51B" Stabilizer, XO, Boot Basket, Boot Basket, XO, Magnet, Bumper Sub, Jar and Pump Out Sub. 22:30 - 00:00 1.50 FISH P INTERV TIH with BHA #41 and 3 1/2" Drill Pipe. 3/16/2006 00:00 - 01 :00 1.00 FISH P INTERV Continue TIH with BHA #41 (GS Spear) on 3.5" Drill Pipe. 01 :00 - 06:30 5.50 FISH P INTERV MU Kelly. Bring pump online at 3 bpm 11350 psi. Slowly work Kelly into the hole. Slid right into Tubing Stump. Stop every 5' and circulate for 5 minutes to ensure cleaning the way for the Printed: 3/20/2006 12: 1 0:24 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: Spud Date: 9/5/1979 End: 3/20/2006 3/16/2006 01 :00 - 06:30 5.50 FISH P INTERV Spear. Taking weight at 27.5' Kelly in. POH and RIH again and taking weight at same depth. Need 29' Kelly in to get to 79B4'. Pump pressure increased to 2500 psi for a second and then dropped back down. Lower Pump rate to 1 bpm I 200 psi and RIH to 29' Kelly in stacking 10K. POH and increase pump rate to 3 bprn 11400 psi. RIH to clean well three times each getting down to 29' Kelly in. Pump pressure increased to 1500 psi. Attempt to latch Plug. Pull Kelly out of hole and close Annular. Pump down Kill Line to attempt to bullhead. Pressured up immediately to 500 psi. Bleed pressure off. Continue to work Spear and attempt to latch Plug - No Joy. 06:30 - 09:30 3.00 FISH P INTERV Trip out with 31/2" Drill Pipe and GS Spear. Spear was jammed in the release position. 09:30 - 10:00 0.50 FISH P INTERV Clean Boot Baskets and recovered -1 1/2 gal of sand and metal fillings. Lay down remaining BHA. discuss plan forward with Anch Eng. Order out Mill and Motor. 10:00 - 11 :00 1.00 FISH P INTERV Clear and clean Floor. Service Rig. 11 :00 - 12:30 1.50 FISH P INTERV Continue to clean and maintain Rig while waiting for next BHA to arrive on location. 12:30 - 14:00 1.50 FISH P INTERV Make-up Mill and Motor BHA as follows: 3.060" Metal Muncher Junk Mill, XO, XO, 3-Blade Stabilizer, Motor, XO, 4-Blade stabilizer, XO, Hyd Disc, DBPVs, XO, 3 Stands of 31/2" Drill Pipe, Bumper Sub, Pump-Out Sub. 14:00 - 1 B:30 4.50 FISH P INTERV Trip in with Mill I Motor and 3 112" Drill Pipe. 1 B:30 - 00:00 5.50 FISH P INTERV 251 Joints of DP and BHA in the hole. PU Joint #252 which is joint we will use for getting to Plug Body to mill. UW = 120K DW = 90K. Bring on pump to obtain various pump rates: 1 bpm 1240 psi, 2 bpm 1620 psi, 2.7 bpm 11150 psi. Shut pump down and RIH to dry tag. Slid right into Tubing Stump with no problems. Tagged @ 16.5' in which is 797B'. POH 5' and bring the pump on to a rate of 2.7 bpm 11150 psi. UW and DW have not changed. RIH to start milling on top of Plug Body. Pumped 4B bbl high-vis sweeps while milling. Encountered Plug Body at 22' in which is 79B4'. Continue to slowly work Mill past the Plug Body and keep pumping the high-vis sweep Pill. Monitor well for change in fluid level. 3/17/2006 00:00 - 03:00 3.00 FISH P INTERV Continue working Mill down through Plug Body. At 01 :30 hrs, began to lose fluid. Lost a total of 63 bbls in 1 hour.....from 02:30 to 03:00 saw no loss of fluid. 03:00 - 06:30 3.50 FISH P INTERV Stacking weight with no hole being made with Mill. PU a whole joint of Drill Pipe and close the Annular on the Drill Pipe. Attempt to bullhead down the Kill Line into the Well. At 0.5 bpm, the pressure increased to 1050 psi - No joy. Continue to try and mill and observe fluid losses. As of 04:00 am, total fluid loss = 79 bbls. No more fluid losses. Unable to stall out Motor. Unable to make any further hole. 06:30 - 07:00 0.50 FISH P INTERV Pull above top of 7 SIB" Tubing Stump. Drop Dart and open Pump-Out-Sub. Attempt to bullhead 10.9 Iblgal Brine at 3,000 psi. No-Joy. 07:00 - 09:30 2.50 FISH P INTERV Trip out with 3 1/2" Drill Pipe and Mill/Motor assembly. (Lost 10 bbls of fluid on TOH). 09:30 - 10:30 1.00 FISH P INTERV Lay down BHA. Mill had very little wear on it. The 3-Blade stabilizer also showed no wear on the brass pads that the Printed: 3/20/2006 12: 1 0:24 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 2/5/2006 3/20/2006 Spud Date: 9/5/1979 End: 3/20/2006 3/17/2006 09:30 - 10:30 1.00 FISH P INTERV stabilizer had "No-Go'ed" on the top of the Plug. 1 0:30 - 15:30 5.00 FISH P INTERV Clear and clean Floor. Discuss plan forward with Anchorage Engineer. Order out next BHA. Continue to maintain Rig and monitor Well while waiting on machine shop work to modify next BHA. Keeping constant hole full with Charge Pump. (Loss rate = 4 bph). 15:30 - 16:30 1.00 FISH P INTERV Make up BHA #43 as follows: Itco Spear custom made for PRN Plug, XO, Stabilizer, Bumper Sub, Oil Jar and Pump Out Sub. OAL = 27.93'. 16:30 - 19:30 3.00 FISH P INTERV TIH with 251 joints of 3.5" DP from Derrick. 19:30 - 21 :00 1.50 FISH P INTERV PU Kelly. Bring pump online at 3 bpm I 520 psi. Increase pump rate to 5 bpm 11500 psi. UW = 122K DW = 95K. Start RIH with Kelly. Stacked 15K at 5' Kelly in the hole = 7964'. Work string past that depth to 10' Kelly in the hole. Continue to work BHA down in 5' increments circulating for 5 minutes at each stop. Pump pressure decreased by 150 psi. Sat down on Plug Body with 26' of Kelly in the hole (79B5') and 15K weight down. Monitor well when picking up on Plug. Plug appears to be stuck. Pull up to 225K and jar attempting to pull Plug free. Continue to jar Fish. 21 :00 - 23:00 2.00 FISH P INTERV Jarred the Plug free! Lost fluid level in the Tubing. Line up to fill Tubing down the backside with seawater. Stand back the Kelly and begin pumping seawater. Pumped a total of B6 bbls to fill the hole up. Continue to pump seawater to maintain hole full @ 3.4 bpm I 90 psi. At 22:00 hours, drop the Dart to shear the Pump Out Sub and drain the Drill Pipe volume. 23:00 - 00:00 1.00 FISH P INTERV The well is drinking 4 bbls I 6 minutes. Continue to fill well up with the charge pump. Line up to pump down the Drill Pipe to shear the Pump Out Sub. Pressure increased to 1800 psi and sheared. It took 4.5 bbls to catch fluid which equates to 700' of fluid level. Blow down line. TOH three single joints of Drill Pipe and lay them down. This was done to ensure we got through the RN Nipple. Continue to monitor well and fill with the charge pump. At 23:30 hours, the drinking rate is 4 bbls 17 minutes. Go on constant hole fill monitoring loss every five minutes. At midnight, have pumped a total of 217 bbls of seawater into the well. 3/1 B/2006 00:00 - 01 :00 1.00 FISH P INTERV Continue monitoring well. Unload seawater from vac truck to pits. Prepare to TOH. 01 :00 - 04:00 3.00 FISH P INTERV Begin TOH with BHA and 24B joints of DP. Stand back Drill Pipe. 04:00 - 05:00 1.00 FISH P INTERV On surface with BHA #43. Recovered the Plug latched onto the Spear (with Tears of Joy). Inspected the Plug and noticed some damage on top from where the Mill may have caught the top of the Fish Neck. Break apart BHA and lay down BHA components. Total barrels pumped into the well at this point is 2BB barrels. 05:00 - 06:00 1.00 BOPSU P INTERV Clear and clean Rig Floor. Set Two-Way Check with Cameron in preparation for weekly BOPE test. Rig up test equipment. 06:00 - 09:00 3.00 BOPSU P INTERV Test BOPE per BP/AOGCC requirements at 250/3500 psi. Good test. State's right to witness test, waived by L. Grimaldi. 09:00 - 09:30 0.50 BOPSU P INTERV Blow down lines. Rig down test equipment. 09:30 - 10:30 1.00 BOPSU P INTERV Wait on Drill-Site Maint to arive on location. Phase II Printed: 3/20/2006 12: 1 0:24 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 2/5/2006 3/20/2006 Spud Date: 9/5/1979 End: 3/20/2006 conditions. Pick-up Lubricator and pull TWC. Lay down same. Well on slight vacuum. Fill Well with Sea Water. 52 bbls = - 1,725' Static fluid level. Monitor Well and observed a gradual drop in fluid level. Pick up 2 7/B" Mule Shoe. Trip in with 3 1/2" Drill Pipe from Derrick. All Drill Pipe in the hole. Begin to TOH and single down Drill Pipe in the Pipe Shed. Keeping the well full filled with seawater as we are laying down the Drill Pipe. Little Red Services arrive on location at 1 B:30 hours. Schlumburger Slickline arrive on location at 19:30 hours. Clear and clean Rig Floor. ND Flow Adapter and NU Shooting Flange. PJSM with Nabors, Schlumburger Slickline and Little Red Hot Oil. Discuss RU procedures and hazards associated with them. RU Schlumburger Slickline to Shooting Flange. RU Little Red to Spool in the Cellar. Continue RU of Slickline and Hot Oil. Pressure test all Lubricator connections to 500 psi to ensure proper make-up of all connections - good test. Begin pumping 100 bbls of hot diesel down the Tubing with Little Red Hot Oil. Blind Rams closed to isolate Slickline toolsting. Pumped freeze protect at 4 bpm. Highest pressure seen was 1500 psi. It took 35 bbls to catch fluid which puts the static fluid level at 763'. RUNCMP Open Blind Rams and start RIH with Plug Body for DB Nipple at 2211' with Slickline. SFAL RUNCMP Slickline operator had problems with toolstring and parted wire at the unit. The unit had just come out of maintenance and he pulled on toolstring to ensure the load cell was working. That is when the wire parted. Rig Crew packed off on wire at Rig Floor to ensure we would not lose toolstring down hole. Toolstring was caught by Packoff and Tubing Profile. Pull the toolsting out of the hole and close Blind Rams to secure well. Cut wire and re-make up toolstring. Attach load cell to Sheave at top of Skate. Wait on Slickline PE and Schlumburger Supervisor to arrive on location to investigate incident prior to continuing operations. RUNCMP Repairs to equipment completed. Operations resume with a PJSM and a review of the plan forward with ALL. RUNCMP Pick-up Lubricator and pressure test to 500 psi. Open Well. WHP = 120 psi. RIH and set Plug in 7" DB-6 Nipple at 2,211 '. Good set. POOH. Pick-up Prong. Open Well. WHP = 1BO psi. RIH and attempt to set Prong. No-Joy. POOH. Re-pin setting tool. Open Well. WHP = 2BO psi. RIH and set Prong in Plug body. Last observed WHP = 370 psi (when the Prong was set). Pull up hole and park setting tool. Slowely bleed WHP down to 290 psi and shut in. Monitor. Continue POOH and rig S-line off Well. RUNCMP Bring Lil' Red on line with diesel to pressure test Plug at 1.0 bpm/450 psi. Bump rate to 1.5 bpm/550 psi. With 19 bbls pumped pressure increased to 1600 psi. Reduce rate and walk 3/1 B/2006 11 :00 - 12:00 1.00 KILL P INTERV 12:00 - 15:30 3.50 FISH P INTERV 15:30 - 21 :00 5.50 FISH P INTERV 21 :00 - 22:00 1.00 FISH P INTERV 22:00 - 22:15 0.25 FISH P INTERV 22:15 - 00:00 1.75 FISH P INTERV 3/19/2006 00:00 - 02:00 2.00 RUNCO RUNCMP 02:00 - 02:30 0.50 RUNCO RUNCMP 02:30 - 03:00 0.50 RUNCO 03:00 - 06:00 3.00 RUNCO 06:00 - OB:30 2.50 RUNCO 08:30 - 12:00 3.50 RUNCO 12:00 - 12:30 0.50 RUNCO Printed: 3/20/2006 12: 1 0:24 PM . ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-03 WGI-03 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/5/2006 Rig Release: 3/20/2006 Rig Number: Spud Date: 9/5/1979 End: 3/20/2006 3/19/2006 12:00 - 12:30 12:30 - 14:30 0.50 2.00 Ico~~ RUNCO~ II RUNCOf . I BOPSUR P I BOPSU~ P RUNCMP RUNCMP pressure up to 3460 psi. Monitor. Lost -20 psi in 5 minutes. Flow Well back through choke. Well flowing gas and gas cut diesel. Finally bled down to 0 psi. Monitor Well. Set and test TWC. Released Lil' Red and SWS Sline-Unit. Nipple down BOP Stack. NU Tree and pressure test to 300 psi low and SOOO psi high for 30 minutes. Good test. Bleed down tree and prepare to pull Two-Way Check. PU Lubricator and pull Two-Way Check with Drill Site Maintenance. Monitored well for any trapped gas underneath the valve. There was 1200 psi underneath the TWC. Install BPV. Lay down Lubricator. Secure Cellar. RDMO. Waiting on trucks to initiate Rig Move. Nabors 7ES and 9ES are both tie-ing up trucks. Release Rig at 03:00 hours on 3/20/2006. 14:30 - 15:00 1S:00 - 21 :00 0.50 6.00 RUNCMP RUNCMP 21 :00 - 00:00 3.00 BOPSU P RUNCMP 3/20/2006 00:00 - 03:00 3.00 BOPSU N WAIT RUNCMP Printed: 3/20/2006 12: 1 0:24 PM ~ lREE = WELLHEAD = ACìUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVO = "" GRAY GRAY AXELSON 49' 31S0' 42 @ 9600' NlA 9-S/8" CSG, 47#, L-80 TCII TIEBACK, 10 = B.681" I 113-3/8" CSG, 72#, N-80, 10 = 12.347" 1 7-S18" TBG, 29.7#, L-BO IPC, .0459 bpf, ID = 6.875" --i 7875' Minimum ID = 4.843" @ 8160' BAKER SHEAROUT SUB IT' TBG, 29#, L-80 TCII, .0371 bpf, 10 = 6.184" H 7955' 7-S18" TBG, 29.7#, NT-9S, .0459 bpf, 10 = 6.87S" I 7992' OATE 09126179 11/16/97 03/19/06 03123/06 03129/06 04/01106 17" TBG, 26#, L-80, .0383 bpf, 10 = 6.276" I 8017' 17" TBG, 29#, L-80, .0371 bpf, 10 = 6.184" I TOPOF 7" LNR I 19-518" CSG, 47#, N-80, ID = 8.6B1" I ÆRFORA TION SUMMARY REF LOG: BHCS ON 09/20179 ANGLE AT TOP ÆRF: 39 @ 904S' Note: Refer to Production OB for historical perf data SIZE SPF INTERVAL Opn/Sqz OA TE 3-3/B" 4 9046-9119 0 03/021B7 3-3/B" 4 9137-9259 0 03/02/B7 3-318" 4 92B 1-9352 0 03/021B7 3-318" 4 9365-9387 0 031021B7 3-318" 4 9413-9471 0 03/02/B7 3-3/8" 4 9485-9S21 0 03/02/B7 3-3/8" 4 9S34-9S59 0 03/021B7 3-3IB" 4 9S70-9580 0 08118/80 PBTD 17" LNR, 29#, N-BO, .0371 bpf, ID = 6.1B4" 962T 9670' REV BY COMMENTS ORIGINAL COM PLETION RWO N4ES RWO ORClTLH ORLG DRAFT CORRECTIONS OA V IPJC NIP CORRECTION @ 2212' JRPJPJC PULL PLUG @ 2212' DATE WGI-03 SAFETY NOTES: POST 2006 RWO, 4' GAP BETWEEN 7" MULE SHOE & 7-5/S" TBG STUB. OA IS FULLYCMT'D TO SURFACE w /CLASS G LARC 22' -17" X 7-S18" XO, 10 = 6.1B4" I 2201' 2208' 2212' -17-S18" X 7" XO, 10 = 6.184" I -19-S/B" HES ES CEMENTER, ID = B.B61" -11" CAMCO 08-6 NIP, ID = 6.000" I -17" X 7-5IB" XO, ID= 6.184"1 7875' -17 -S/8" X 7" XO, ID = 6.184" 1 7886' -f 7" HES R NIP, ID = S.963" I 7907' -19-518" X 7" BKR S-3 PKR, 10 = 6.0BO" 7931' -17"HESRNNIP,10=S.770" I 7955' -17" FULL MULESHOEWLEG, ID = 6.184" 7959' MD -17-S/8" TBG STUB (02119106) I 7992' -i 7 -SI8" X 7" XO I 7993' -1 9-S18" X 7" BKR SABL PKR I -17" HES RN NIP, ID = 5.5" 8017' -1 7" TUBING TAIL WLEG I -19-518" X 7" BKR SB-2 PKR I ., 7" BKR SHEAROUT SUB, ID = 4.843" "7" TUBING TAIL I H ELMD TT LOGGED 09/26/79 I REV BY COMMENTS PRUOHOE SA Y UNIT WELL: WGI-03 ÆRMIT No: "1790490 API No: SO-029-203BS-00 SEC 11, T11 N, R14E, S8.42' FEL & 2446.15' FNL BP Exploration (Alaska) WG 1-04 and WG 1-03 workovers ') , l1'l-·é):4-' ) Subject: WGI-04 and WGI-03workovers From: "Reem, David C" <ReemDC@BP.com> Date: Mon, 30. Jan 200613:51:53 -:0900 "to,:.;)J\llnt()n'Îf.l.lbørt.·~ll1t(jn..2auÞ~I1@ádrnin,.staté.äk;us> Winton, referencing Sundry number 305-392 (WGI-04) and 306-008 (WGI-03), our original intent was to cement in our new 9-5/8" casing tie-back to surface. However, in an effort to allow some flexibility for a future rig sidetrack where the 9-5/8" would be cut and pulled to allow a 12-1/4" BHA to cut the sidetrack window in the 13-3/8" casing, we are now planning on only cementing in the bottom -500' of new 9-5/8" casing. Test pressures, etc remain the same as in the Sundry application. Should you have any questions regarding this slight change in scope, please call. Thanks. Dave Reem WeJlslWorkover Engineer 564-5743 (w) 632-2128 (c) ~ÇANNED JAN 3 1 2006. 1 of 1 1/30/2006 3: 12 PM . STATE OF ALASKA _ AlA~ Oil AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS RECE'VED . ,,^^t" 1. Operations Abandon D Repair Well D Plug Perforations 0 StimulateD Utfl'6r I':' L.UVV Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Ext~nsio~~ Cons. cormiISion Change Approved Program D Operat. Shutdown D Perforate D He-enter AI.Q9A1 ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill '''''''TnJ'''. Name: Development D Exploratory D 179-0490 3. Address: P.O. Box 196612 Stratigraphic D Service p¡ 6. API Number: Anchorage, AK 99519-6612 50-029-20385-00-00 7. KB Elevation (ft): 9. Well Name and Number: 30 KB WGI-03 8. Property Designation: 10. Field/Pool(s}: ADL-028302 Prudhoe Bay Field/ Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 9672 feet Plugs (measured) 8008 TT true vertical 8576.68 feet Junk (measured) None t'i:f.;{:' ~l'~ß' ,',. ~ Effective Depth measured 9627 feet {.'j' ,'t, iv' i¡,r;;L <t- O Q) true vertical 8543.34 feet Casing Length Size MD TVD Burst Collapse Conductor 78 20" 94# H-40 25 - 103 25 - 103 1530 520 Surface 2699 13-3/8" 72# N-80 24 - 2723 24 - 2722.93 4930 2670 Production 8546 9-5/8" 47# N-80 23 - 8569 23 - 7724.04 6870 4760 Liner 1415 7" 29# N-80 8255 - 9670 7468.38 - 8575.2 8160 7020 Perforation depth: Measured depth: 9046 - 9119 9137 - 9259 9281 - 9352 9365 - 9387 9413 - 9471 9485 - 9521 9534 - 9559 9570 - 9580 True Vertical depth: 8105.16 - 8161.77 8175,66 - 8268.87 8285.47 - 8338.73 8348.46 - 8364.93 8384.38 - 8427.62 8438.03 - 8464.75 8474.4 - 8492.94 8501.1 - 8508.51 Tubing: (size, grade, and measured depth) 7" 26# L-80 22 - 24 7-5/8" 29.7# NT -95 24 - 2229 7" 26# L-80 2229 - 2235 7-5/8" 29.7# NT-95 2235 - 7992 7" 26# L-80 7992 - 8017 7" 29# L-80 8145 - 8161 Packers and SSSV (type and measured depth) 7" Baker SABL-3 Packer 7993 7" Baker SB-2 Packer 8145 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft .IAN 182006 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure I Tubing pressure Prior to well operation: 0 0 319984 450 I 3858 Subsequent to operation: 0 0 SHUT-IN 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory D Development D Service p¡ Daily Report of Well Operations X 16. Well Status after proposed work: Oil C Gas C WAG C GINJ p¡ WINJ C WDSPL C 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal p'"1ed Nam, s:~a;"" V"lal _ ~ Title Data Mgmt Engr Signatu~7h :J!:¡l Phone 564-4424 Date 1/13/2006 Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only e e WGI-03 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 12/6/2005 T/I/O= 2700/400/320 (SECURE WELL) *** JOB POSTPONED due to weather *** 12/6/2005 *** WELL ON INJ *** (secure well) ATTEMPTED TO SECURE WELL. JOB SUSPENDED DUE TO HIGH WINDS. NOTIFY DSO HE CAN PUT THE WELL ON INJECTION *** WELL LEFT SHUT IN *** 12/7/2005 T/I/0=2300/340/320 Well Kill for Slickline [Secure Well] Pumped 10 bbls neat meoh, 765 bbls 1 % KCL, 115 bbls 60/40. FWP's=0/300/320 12/7/2005 **** WELL SI ON ARRIVAL **** (secure well, Up) DRIFTED W/ 6.03 G-RING TO TOP OF 7" MCX @ 2210' SLM PULLED 7" MCX ON CAMCO CARRIER (SER# BP-706 W/ 2.50 BEAN) BRUSHED RN NIPPLE W/ 7" BLB & 5.25 G-RING @ 7970' SLM *** JOB IN PROGRESS/ CO NT ON 12-08-05 WSR *** 12/8/2005 *** CONT FROM 12-07-05 WSR *** (secure well, Up) SET 7" PRN PLUG BODY & PRONG IN RN NIP @ 7976' SLM, PLUG DID NOT HOLD, PULLED PLUG BODY & PRONG, PRONG WAS NOT COMPATIBLE W/ PLUG BODY, BRUSHED NIPPLE AGAIN W/ 7" BLB & 5.25 G-RING, DRIFTED W/ 3.80 CENT, TEL & SAMPLE BAILER, LOC TT @ 8148' SLM- 8146' CORR ELMD, TAG TD @ 9524' CORR ELMD (478' OPEN PERFS, 56' FILL). STANDBY FOR PUMP TRUCK TO LOAD & KILL WELL *** JOB IN PROGRESS/ CO NT ON 12-09-05 WSR *** 12/8/2005 T/I/0=2550/2100/300 Well Kill for SSV repair. Pumped 10 bbls 60/40 methanol, 115 bbls 1 % inhibited KCL, Continued to 12-09-05, Still pumping KCL 12/9/2005 Continued from 12-8-05 T/I/0=2550/2100/30 Assist SWS with well kill for SSV repair. Finish pumping 461 bbls 1 % Inhibited KCL, 115 bbls 60/40 methanol to freeze protect tbg. FWHP's=0/700/140 12/9/2005 *** CONT FROM 12-08-05 WSR *** (secure well, Up) SET 7" PRN PLUG BODY & PRONG (PRONG 93" OAL 1.75 F.N, PRONG BODY 1.875 0.0, 3.72 CENT 48" BELOW F.N) SET @ 7976' SLM. BLED TBG & IA TO 0#, PLUG HOLDING. RDMO. *** NOTE HEAVY WALL F.N ON PLUG BODY, PULLS W/ 51/2" GS *** *** DSO NOTIFIED, WELL SECURE W/ TTP *** 12/10/2005TI0 = 650/350/320. Temp = SI. Bleed WHP's < 500 psi (Secure Well). Wing valve SI. TBG FL @ 900'. Bled TBGP from 650 psi to 560 psi in 45 mins and then went from gas to fluid. lAP increased during bleed from 350 psi to 490 psi, OAP decreased from 320 psi to 300 psi. IA FL @ 120'. Continued TBGP bleed, mostly fluid (bled for 30 mins). TBGP & lAP continued to increase. SI lateral valve on flow line just behind the well house (flow line = 640 psi). resumed TBGP bleed (for 30 mins). TBGP & lAP continued to increase (T/I = 650/630). Flow-line pressure unchanged. Called for swab valve to be serviced. 8 bbls total fluid bled from TBG. Monitored 30 mins. Flow-line pressure = 640 psi. Control line pressure = 650 psi. B/L = 1050 psi. During monitor TBGP increased 20 psi & lAP increased 30 psi. FWHP's = 670/660/300. e e 12/11/2005 T/I/0=1100/480/300 Temp=S/1 Bleed WHP's < 500 psi (Secure Well) TBP is up 430 psi and lAP is down 180 psi from yesterday. Initial TBG FL= 2058' Bleed TBP to 950 psi in 1.75 hrs. Swapped to fluid at 950 psi and then increased to 1050 psi within minutes and did not change. (10 bbls to tank) lAP rose 650 psi to 1130 psi during tubing bleed. OAP is unchanged. Injection line shows 950 psi. Final T/I/0=1050/1030/300 12/15/2005 T/I/O = SSV/1360/270. Temp = SI. Monitor (post bleed). lAP increased 330 psi. OAP decreased 30 psi in 4 days. 12/19/2005 **** WELL SI ON ARRIVAL *** (pull, I&k, reset Up) PULLED 7" PRN PLUG BODY & PRONG ( REDRESSED PLUG), PUMP TRUCK LOADED & KILLED WELL, SET 7" PRN PLUG BODY @ 7974' SLM(SHEAR PIN FELL OUT OF R/T), PULLED PLUG BODY ( DID NOT RECOVER SHEAR PIN), RUNNING IN HOLE TO RESET PLUG BODY @ REPORT TIME. *** JOB IN PROGRESS/ CONT ON 12-20-05 WSR *** 12/19/2005 T/I/O= 2000/1700/330 Displace well for slickline; Pumped 5 bbls neat, 616 bbls Inhib. 1 % kcl down the tubing. Freeze protected tubing w/ 115 bbls 60/40 meth water. Final WHP's=175/830/340 12/20/2005 T/I/0=875/560/350 Assist slickine / MIT tubing to 3000 psi, FAILED (RWO) - Pressure tubing to 3000 psi w/61 bbls 60/40 meth/water. CMIT TxlA PASSED to 2000 psi. 1st 15 min test Tbg/IA lost 0/10 psi, 2nd 15 min test Tbg gained 20 psi and IA lost 0 psi. Bleed pressures down and hung tag. FWH P's= 100/720/300 12/20/2005 *** CONT FROM 12-19-05 WSR *** (reset Up) SET 7" PRN PLUG BODY & PRONG( PLUG BODY HAS O-RING W/ EXTRA PIECE PKG. PRONG 72" OAL W/ 2.313 F.N, 3.70 CENT 40" BELOW F.N) LRS PRESSURED UP ON PLUG TO 3000#, PLUG APPEARS TO BE HOLDING NOTE: PLUG BODY HAS HEAVY WALL F.N, USE 51/2" GS TO PULL. *** DSO NOTIFIED, WELL LEFT SI *** e e FRANK H. MURKOWSKI, GOVERNOR ALASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501'3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 \1q- ó L{-q Re: Prudhoe Bay, WGI-03 Sundry Number: 306-008 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this/O day of January, 2006 Encl. (,{Y.f /4/,1 "'0 ~ . STATE OF ALASKA Ðj7S e,¡O/,.6 REC I . ALASKA olL AND GAS CONSERVATION COMMISsfóN E VeD APPLICATION FOR SUNDRY APPROVAL JAN 0 ~ 7006 20 AAC 25.280 IIJ 4Æ- It 01 UJd(p 1. Type of Request: o Abandon o Suspend / 0 Operation Shutdown o Perforate o Other Anti¡\.ifGQ6 o Alter Casing II Repair Well 0 Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program II Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. o Development o Exploratory 179-049 / 3. Address: o Stratigraphic 131 Service / 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20385-00-00 ..- 7. KB Elevation (ft): 30' 9. Well Name and Number: PBU WGI-03 ,/ 8. Property Designation: 10. Field / Pool(s): ADL 028302 Prudhoe Bay Field / Prudhoe Bay Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9672 8577 9627 8543 8008 None Casino Lenoth Size MD ,/ TVD Burst Collapse ~trll~tur;:¡1 78' 20" 78' 78' 1530 520 ~..~- ,- 2723' 13-318" 2723' 2723' 4930 2670 .. 8569' 9-518" 8569' 7724' 6870 4760 I inør 1415' 7" 8255' - 9670' 7468' - 8575' 8160 7020 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: I Tubing MD (ft): 9046' - 9580' 8105' - 8509' 7-5/8· x 7" NT95/ NT80 / L-80 8017' & 8145' - 8161' Packers and SSSV Type: 9-5/8· x 7· Baker 'SB-2' packer; 9-5/8· x 7" Baker 'SABL' Packers and SSSV MD (ft): 8145'; 7993' r packer 12. Attachments: 13. Well Class after proposed work: ,/ 131 Description Summary of Proposal o BOP Sketch o Exploratory o Development 131 Service o Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: January 25, 2006 / OOil o Gas o Plugged o Abandoned 16. Verbal Approval: Date: o WAG 131 GINJ ' OWINJ o WDSPL Commission Representative: 17. I hereby ce ify that the foregoing is true and correct to the best of my knowledge. Contact David Reem, 564-5743 Printed Na David Reem ^ Title Drilling Engineer ~ I A~ ,. 1) 0. /(,10 I. Prepared By Name/Number: Sionature Phone 564-5743 Date Terrie Hubble, 564-4628 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: (::Jlo-tJ61( o Plug Integrity ~OP Test ~echanicallntegrity Test o Location Clearance Other: T ~ t- Bo~6 to 0 0 r~' RBDMS 8Ft .IAN 1 J 2U06 M~i;J~~~ . S"OO'q~"t Fo~ ¡ ;'~~~ 71h APPROVED BY I-/O-pb Approved By: ,J COMMISSIONER THE COMMISSION Date ./ Form 10-403 Revi~7/2!œ-1~ \. ~ Submit In Duplicate - ...01 & G3S Cons. CGm¡¡ÚS;¡;,,¡1 ORIGiNAL e e Well Status: Shut-in gas injector. Well has confirmed tubing x inner annulus and inner annulus x outer annulus communication. The well is secured with a tubing tail plug. /' Pr01ect: Retrieve existing 7.625",29.7#, L-80 IPC STL completion leaving the packer and tail-pipe. Cut and pull -2700' of 9-5/8". Tie-back in with 2700' of new 9-5/8", 47#/ft, L-80 TC-II casing and cement in place. Re-complete with 7.625", 29.7#/ft, L-80 Vam Top HC tubing, permanent packer with tail-pipe -2' above existing packer. Provide /' AOGCC field inspectors 24-hr notices as required to witness BOP tests and MITIA post packer setting. PRE-RWO . Set TTP in "RN" nipple to secure well (DONE). · Punch circ holes in 7-5/8" tubing I full joint above the packer. · Circulate the well over to seawater with diesel freeze protect. CMIT to 2000 psi to verify tubing tail plug integrity. MITOA to 2000 psi to verify 13-3/8" shoe ./' integrity. Set and test BPV in tubing hanger. RWO 1. MIRU workover rig. Circ out diesel freeze-protect and verify well is dead. Set TWC in tubing hanger and test. 2. ND tree, NU and fully test BOPE per BP and AOGCC regulations (250 psi low pressure test/4000 psi high pressure test (test the annular to 3500 psi). / 3. RIH w/multi-string cutter (dressed w/8.5" knives) and cut the 1 sl full joint of 7- 5/8" tubing above the packer. 4. Pull 7-5/8" tubing down to the cut. 5. Run 9-5/8" scraper to the 7-5/8" stub. 6. Run 9-5/8" USIT to locate top of cement in 9-5/8" x 13-3/8" annulus. / 7. Set 9-5/8" RBP -1500' below the TOC indicated on the USIT log. Spot 30' of sand on RBP. 8. Mechanically cut the 9-5/8" casing in the 1 sl full joint above the TOe. .,/ 9. Mobilize and circulate out all Arctic Pack from the 9-5/8" x 13-3/8" annulus. 10. Pull 9-5/8" down to the cut. 11. Run wash shoe and 13-3/8" scraper down to the 9-5/8" stub. Ensure wash shoe is able to get beyond the next 9-5/8" collar by -6'. Reverse circulate the well bore clean. 12. Back-off 9-5/8" casing stub. 13. ND BOP and tubing spool. NU BOP on casing head. Test same per step #2. 14. RIH with new 9-5/8", 47#/ft, L-80 TC-II casing, shoe-track and over-shot guide- sub. Screw into existing 9-5/8" casing. PT casing to -2000 psi. Pressure up to open ES-cementer. Verify communication up 9-5/8" x 13-3/8" annulus. 15. Pull 250K tension on 9-5/8" casing. Split stack below BOPs and install 9-5/8" emergency slips and primary pack-off. Slack off -lOOK to fully engage slips and energize pack -off. 16. Cement 9-5/8" in place with target top of cement = SURFACE. Close ES- cementer. / / e e 17. Split stack, cut 9-5/8". Set back BOPs. Make final dressing cut on 9-5/8" if required and NU tubing spool with secondary pack-off. NU BOPs. Test spool/BOPs to 4000 psi. 18. Drill out shoe-track down to sand top on RBP. PT casing to 4000 psi. ; 19. Retrieve upper 9-5/8" RBP. 20. Spear 7" stub and rotate k-anchor free from SABL-3 packer (this step maight be done directly after step #4). 21. Rill with reverse circulating junk basket(s) and clean off any debris on top of TTP set in original tail-pipe. POH and LDDP. 22. Rill with 7" WLEG, 7" 26#/ft L-80 tail-pipe, 7" x 9-5/8" L-80 S-3 packer, 7" crossed over to 7-5/8", 29.7#/ft, L-80, VamTop HC completion. Will have a 7" J DB-6landing nipple at -2100' for flapper-type safety valve installation after the rig moves off. 23. Tag top of existing SABL-3, P/U 2-3', reverse in packer fluid and freeze protection. Allow freeze-protect fluid to U-tube between tubing and inner annulus. 24. Set S-3 packer. MIT-T to 4000 psi, MIT-IA to 4000 psi. / 25. Set BPV. ND BOP, NU and PT tree to 5000 psi. 26. RDMO. POST -RWO · Pull ball&rod from RHC sleeve. Pull RHC sleeve. · Pull TTP from the RN nipple. · Set A-I injection valve in DB-6 landing nipple. · Tie-in injection lines, re-set wellhouse and instrumentation. · POI. MIT-IA w/AOGCC witness. TREE = GRA Y WELLHEAÐ = GRA Y A ACTUA TOR = AXELSON . KB. ELEV = 49' BF. ELEV = KOP= 3150' 7" TBG,26#, .0383 24' \1ax Anfjle " '!2 @ 96(,0' bpf, 10 = 6.276" Datum MD ' N ,\ Datum 1V5·;···_·..······~~ I TOP OF 7-5/8" TBG~ 17-5/8" TBG, 29.7#, NT-95, .0459 bpf, 10 = 6875" I TOP OF 7" TBG I 17" TBG, 26#, .0383 bpf, 10 = 6.276" I ITOPOF 7-5/8" TBG I WGI-03 SAF.OTES: LDLNIDEO LOG OF 9/23197 INDICATES A LEA " HGR PUP & XO. 24' -17" X 7-5/8" XO I 2229' H 7 -5/8" X 7" XO I 2230' -17" CAM BAL-O SSSV NIP, 10 = 5.937" I 2235' -17"X7-5/8"XO 113-318" CSG, 72#, N-80, .1481 bpf, 10 = 12.347" I Minimum ID = 4.843" @ 8160' BAKER SHEAROUT SUB 17-5/8" TBG, 29.7#, NT-95, .0459 bpf, 10 = 6.875" I TOPOF 7" TBG I 7992' 7993' -17-5/8" X 7" XO I r' -19-5/8" X 7" BKR SABL PKR I 7" HES RN NIP, 10 - 5.5" PRN TIP (12/19/05) -17"TUBINGTAILWLEG I -19-5/8" X 7" BKR SB-2 PKR I -17" BKR SHEA ROUT SUB, 10 = 4.843" -17" TUBING TAIL I H ELMO TT LOGGED 09/26/79 I 1 PBTD I 9627' S017' 17" TBG, 26#, L-80, .0383 bpf, 10 = 6.276" I 17" TBG, 29#, L-80, .0371 bpf, 10 = 6.184" I ¡TOP OF 7" LNR I 8161' 8255' 19-5/8" CSG, 47#, N-80, 10 = 8.681" I ÆRFORA TION SUMMARY REF LOG: BHCS ON 09/20/79 ANGLEATTOPÆRF: 39 @ 9045' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA 1£ 3-3/8" 4 9046-9119 0 03/02/87 3-3/8" 4 9137-9259 0 03/02/87 3-3/8· 4 9281-9352 0 03/02/87 3-3/8" 4 9365-9387 0 03/02/87 3-3/8" 4 9413-9471 0 03/02/87 3-3/8" 4 9485-9521 0 03/02/87 3-3/8" 4 9534-9559 0 03/02/87 3-3/8" 4 9570-9580 0 08/18/80 1 7" LNR, 29#, N-80, .0371 bpf, 10 = 6.184" I 9670' OA TE REV BY COMMENTS 09/26/79 ORIGINAL COM PLETION 11116197 LAST WORKOVER 11/03/01 RN/TP CORRECTIONS 04/30/04 OA V/KA CORRECTIONS 06/02/04 JLA/KAK WAIVER SAFETY NOTE 12/09/05 ???/TLH PRN TTP SET OA TE REV BY COMMENTS 12113/05 RPl-VTLH WAIVER SFTY NOTE DELETED 12/31/05 ???/TLH PRN TTP RESET? (12/19/05) PRUDHOE BA Y UNIT WELL: WGI-03 ÆRMrT No: '1790490 API No: 50·029-20385-00 SEC 11, T11 N, R14E, 58.42' FEL & 2446.15' FNL BP Exploration (Alaska) TREE = WELLHEA~ = ACTUATOR = KB. EL.F.V = ...... ... -. ..... BF. ELEV = KOP= \1ax Annl!:! = DatulT1 MD = Datum GRAY GRAY AXELSON 49' 3150' 4/ @ OÔOO' N'^ 9-5/8", 47#/ft, L-80 TC-II tie-back from original TOC to surface, fully cemented. 113-3/8" CSG, 72#, N-80, .1481 bpf, ID = 12.347" I Minimum ID = 4.843" @ 8160' BAKER SHEAROUT SUB 17-5/8",29.7#, L-80, VamTop HC, ID = 6.875" 17" TBG, 26#, L-80, .0383 bpf, ID = 6.276" I IT' TBG, 29#, L-80, .0371 bpf, ID = 6.184" I TOP OF 7" LNR I evvGI-03 ProposeJt H 8017' 8161' 8255' 9-5/8" CSG, 47#, N-80, ID = 8.681" I 8569' ÆRFORA TION SUMMARY REF LOG: BHCS ON 09/20/79 ANGLEATTOPÆRF: 39 @ 9045' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 4 9046-9119 0 03/02/87 3-3/8" 4 9137-9259 0 03/02/87 3-3/8" 4 9281-9352 0 03/02/87 3-3/8" 4 9365-9387 0 03/02/87 3-3/8" 4 9413-9471 0 03/02/87 3-3/8" 4 9485-9521 0 03/02/87 3-3/8" 4 9534-9559 0 03/02/87 3-3/8" 4 9570-9580 0 08/18/80 I PBTD I 9627' 17" LNR, 29#, N-80, .0371 bpf, ID = 6.184" I 9670' DA TE REV BY COMMENTS 09126179 ORIGINAL COM PLETION 11116197 LAST WORKOVER 11/03/01 RNlTP CORRECTIONS 04/30/04 DA V /KA CORRECTIONS 06/02/04 JLA/KAK WArvER SAFETY NOTE 12/09/05 ???/TLH PRN TIP SET DA TE REV BY COMMENTS 12/13/05 RPH/TLH WArvER SFTY NOTE DELETED 12/31/05 ???/TLH PRN TIP RESET? (12/19/05) H 7" HES R NIP, ID = 5.963" 1 H 9-5/8" X 7" BKR S-3 PKR 1 HT' HES RN NIP, ID = 5.770"1 7993' 8008' 8017' 8145' 8160' - 9-5/8" X T' BKR SABL PKR I H 7" HES RN NIP, ID = 5.5" I H 7" TUBING TAIL WLEG I - 9-5/8" X 7· BKR SB-2 PKR I - 7" BKR SHEA ROUT SUB, ID = 4.843" PRUDHOE BAY UNrT WELL: WGI--03 ÆRMrT No: P.¡ 790490 API No: 50-029-20385-00 SEC 11, T11 N, R14E, 58.42' FEL & 2446.15' FNL BP Exploration (Alaska) RE: WGI-01 & WGI-03 Cancel Waiver e eptb ~ Irz'1- 041 Subject: RE: WGI-Ol & W6I-03 Cancel Waiver From: "NSU, ADW Well Integrity Engineer" <NSUADWWe1lIntegrityEngineer@BP.com? Date: Mon, 12 Dec 200520:36:4:2-0900 To: U, ~DW WeROperations:'Sµ "isor" <NSUADWwêÌtOþ,erationsSup,' ," 'or@BP.tdtn>", ;<GPB.,' : .. ~te;e::o,~~~e;~ .~~~~~~~~~ .. './S~n~~,:~Bi ¡âi .. pptlmlzatlon Engr" <GPBOpt~mlzatlOhEngr@BJ?com>, "Scb "yer, AI"-ç8ch ,,", ,', L@BP.com>,,)Æ'L~; ~~GPB, PSI DS O~s~ÿad" <61:8 'DSOpsLea:" p,~<?m>,jiTI1_reg~@adm' "åte.ak.us,~,;š':i *,inton ~qubert@adïRin.state.~;Ü " "0' ~c: "NSU, ADW Well Integrity, ,,', pW WI Tech" <NSUADW, ",'P.com>, "H Ii "'i'êr, Nicholas B" <~I~as.Frazíêr@BJ?a~: Hello all. WGI-01 and WGI-03 have been reclassified from Waiver to Trouble. Please call if you have any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.com L:j{~ Am., N p~ ,f;;. ::.D fl.!: .j~Ui.ß~' c.:'t.> ",. From: N5U, ADW WI Tech Sent: Monday, December 12, 20054:55 PM To: N5U, ADW Well Integrity Engineer Subject: WGI-01 & WGI-03 Cancel Waiver Joe, WGI-01 is a gas injector with a PC leak that can no longer be operated under the current waiver. WGI-01 requires an annual MIT-OA to 1.2 times estimated injection pressure, which is greater than 80% of the surface casing's rated burst pressure. WGI-03 is a gas injector with slow IAxOA communication that can no longer be operated under the current waiver. WGI-03 requires an annual MIT-OA to 1.2 times estimated injection pressure, which is greater than 80% of the surface casing's rated burst pressure. Thanks, Ryan Holt Well Integrity Tech. Pager 4236-786 Office 659-5524 1 of 1 12/13/2005 12:56 PM MEMORANDUM Jim Regg i?fi4 .5 / 16(~ P.I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission FROM: JCr DATE: Wednesday, May 12,2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI-03 PRUDHOE BAY UNIT WGI-03 TO: Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :íB..e s'llZidt- Comm NON-CONFIDENTIAL API Well Number: 50-029-20385-00-00 Insp No: mitJCrO40427204104 Inspection Date: 4/27/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: WGI-03 Type Inj. N TVD 7255 IA 700 4460 4370 4310 I P.T. 1790490 TypeTest SPT Test psi 4450 OA 340 2300 2280 2270 Interval Other (describe in notes) P/F 'P Tubing 860 2460 2450 2450 Notes: 2000 psi total was applied toTbg & OA before testing IA to 4460 psi. Dummy SSSV was installed before MIT. The control line & balance line tracked JA test pressure. The Operator performed second MIT to 4460 psi. The pressure was 4390 after 15 min. & 4350 after 30 min. I witnessed re pump ofJA from 4310 to 4460 for second MIT. Wednesday, May 12,2004 Page I of I n.\.<. .. '-H-V..} \~ ~ J..J IT ~ , 7V"T7V) '-Jet"' UIJ\.<\.<LVI V\'ILll "'IV"" H1.AVr1. ~Vlll... Anna - Please define what you mean by "trigger pressures" (don't confuse development well requirements per CO 492 with injection well requirements). In addition to notification, Commission regulation (20 AAC 25.402(£» states that any indication o£ pressure communication or leakage requires corrective action or increased surveillence (Commission discretion). Commission policy does not allow gas injectors to continue in operation with known leaks except in very rare circumstances; as such, a waiver approval from the Commission is unlikely. Please add Well WGI-03 to the monthly list of injectors BP reports to the Commission as having integrity concerns, and provide a timeline for completion of diagnostics and corrective action. Jim Regg AOGCC NSU, ADW Well Integrity Engineer wrote: Hi Jim and Winton, WGI-03 (PTD #1790490) is exhibiting slow IAxOA communication. Wellhead pressures are under trigger pressures at 3360/1090/840 and therefore the well is not considered a problem well at this time. Our plan forward for this well is to conduct an OA repressure test and evaluate the well for an IAxOA waiver. Please let us know if you have any questions. Thank you, Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 xl154 «WGI-03.pdf» 1 of 1 3/30/20042:21 PM Kn: W UI-Uj ~r 11.J tt 11':1U't':/U) Ui1:> ll~e;;¡;tUl- WIUl ;:)1UW lfiXVfi \....0... ~ ~. Hi Jim, Winton & Bob. Attached are completed MIT forms for MIT's conducted on WGI-03. All the MIT's passed. Current plans are to pull the TTP, re-set the SSSV and issue a waiver for slow IAxOA comm. Please call if you have any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, Work: (907) 659-5102 Mobile: (907) 943-1154 Pager: (907) 659-5100, xl154 Email: NSUADWWellIntegrityEngineer@bp.com (Alaska) Inc. «MIT PBU WGI-03 04-26-04.xls» -----Original Message----- From: NSU, ADW Well Integrity Engineer Sent: Friday, April 23, 2004 7:31 AM To: 'AOGCC Jim Regg (E-mail) '; 'AOGCC Cc: NSU, ADW Well Integrity Engineer Subject: RE: WGI-03 (PTD #1790490) Communication «MIT PBU WGI-03 04-27-04.xls» Winton Aubert (E-mail) I Gas Injector with Slow IAxOA Hi Jim and Winton, An OART has been conducted on WGI-03 (PTD#1790490) and confirmed IAxOA communication. The wellhead pressures remain under trigger pressures at 3750/400/350. Wellhead representatives have tested and confirmed the communication is not through the wellhead. A plug will be set this weekend to conduct MIT testing for a waiver. Results of the MITs will be sent once completed. In summary: 03/29/04: EM and voice mail notification to AOGCC regarding IAxOA communication - eval for waiver 04/21/04: OART - 500 psi/day communication 04/22/04: PPPOT-IC Passed Plan forward: 1. SL: Set TTP 2. FB: MITIA, MITOA 3. WIC: Eval for IAxOA waiver Please give me a call if you have any questions. Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 xl154 -----Original Message----- From: NSU, ADW Well Integrity Engineer Sent: Monday, March 29, 2004 12:25 PM lof2 4/28/2004 8:07 AM Kt'..: WLd-UJ (1' I U tt I l'JU4'JU) Lias Injector wIth Slow lAxOA Co... ~. ~ To: AOGCC Jim Regg ,J!:-mail); AOGCC Winton Aubert (E-illail) Cc: NSU, ADW Well Operations Supervisor; NSU, ADW Well Integrity Engineer; Rossberg, R Steven Subject: WGI-03 (PTD #1790490) Gas Injector with Slow IAxOA Communication Hi Jim and Winton, WGI-03 (PTD #1790490) is exhibiting slow IAxOA communication. Wellhead pressures are under trigger pressures at 3360/1090/840 and therefore the well is not considered a problem well at this time. Our plan forward for this well is to conduct an OA repressure test and evaluate the well for an IAxOA waiver. Please let us know if you have any questions. Thank you, Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 xl154 « File: WGI-03.pdf » Content-Description: MIT PBU WGI-O3 04-26-04.xls MIT PBU WGI-O3 04-26-04.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 , ----- - -- - --~----~--~~-~__~_~~n~ - ---- ~ -~ -- -- - --- - --- - - -- ------ ------~ -- ~------ - --- Content-Description: MIT PBU WGI-O3 04-27-04.xls MIT PBU WGI-O3 04-27-04.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 2 of2 4/28/2004 8:07 AM r-... ~. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; BobJleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us \2e.rq 4{vð/C4 OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / WGI Pad 04/26/04 Anna Dube M..Yi - OA Pretest Initial 15 Min. 30 Min. Tubing 2,050 2,150 2,150 2,150 Interval 0 IA 2,050 2,180 2,180 2,180 P/F P OA 1,150 4,450 4,420 4,410 Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT PBU WGI-03 04-26-04-3.xls ,r--.. /'., STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob]leckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us ~1 it I z,'a>1 04- OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay I PBU / WGI Pad 04/27/04 Anna Dube / Mellveson John Crisp MJ;r - ..::rA Pretest Initial 15 Min. 30 Min. 2,300 2,460 2,460 2,440 Interval 0 4,310 4,460 4,390 4,350 P/F P 2,280 2,280 2,280 2,280 Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT PBU WGI-03 04-27-04-2.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor Chair THRU: Tom Maunder P.I. Supervisor FROM: John Crisp Petroleum Inspector DATE: June 1, 2002 SUBJECT: Mechanical Integrity Tests BPX WGI 02;03,05 & 08 Prudhoe Bay Field Prudhoe Bay Unit NON- CONFIDENTIAL Packer Depth ' Pretest Initial 15 Min. 30 Mir~. ' ' W~llI 'WGl~2~:~lTypeln,.I G I T..V.D. 17545 I Tubingl 3550.I ~0 ! ~0 I ~'~ I'nterva'l 4 .P.T.p.I 1790430 ITypetestl P TestpsiI 1887 CasingI 470 2490 2475 24~0 PIF IP Notes: WellI wG',-03 ITypeln,.! G i i I' ~° I ~° I'nte~va'l 4, P.T.D.I 1790490 ITypetestl ' P TestpsiI 1814' Cas!ng 2190 2175 2175. PIF I P' Notes: Monitored )ressure for one hour to confirm stabilization. e,,I I*u 'n l P.I.D.I 1900250 lypete~t[ P 're~tpsiI 1~,50, Casing 220, 20~0 20~0 2000 I PIF I P Notes: Monitored )ressure for 45 minutes to confirm stabilization. P.T.D.~ 1900490 TypetestI P TestpsiI 1915 Casing 400 3560 2550 2540 PIF _P Notes: Insignificant pressure Ios~ of 20 psi. after 30 minutes. ' ' VVe."l I~,,e'ni. ! ~.v;o. I ,.~.~., ,~,,~es~, I I*u~'n° ' Notes: , Type INJ. Fluid Codes F = FRESH WATER tNJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus-Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4-- Four Year Cycle V= Required by Variance W= Test during Worko~r O= Other (describe in notes) Test's Details I traveled to BP's Prudhoe Bay Field to witness MIT's on WGI Pad. WGI-03 had starting pressure of 2550 psi. The first 20 minutes of 03's test the pressure dropped from 2550 to 2320 psi. The last 10 minutes of 03's test the pressure dropped from 2320 psi to 2190 psi. The Operator asked if I wanted to increase pressure back to 2500 psi on 03. I requested the Operator to monitor 03's test for another 30 minutes, w/o re-pressuring, to verify stabilization. The test pressures are recorded on the test form above. I witnessed no change on 05 until I tapped on the gauge after 30 minutes. I verified stabilization by witnessing no change in 05% pressure from 30 to 45 minutes. M.I.T.'s performed: 4 Attachments: Number of Failures: O Total Time during tests: 3 hrs. cc: MIT report form 5/12/00 L.G. MIT PBU WGI 06-01-02jcl.xls 6/4/02 MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas conservation Commission Julie Heusser, Commissioner TOm Maunder, ~.~~~ P. I. Supervisor~\ ! DATE: January 15, 2000 FROM: SUBJECT: jOhn Crispi Petroleum InsPeCtor Safety Valve Tests Prudhoe Bay Field WGI Pad January 15, 2001' I traveled to BP's Prudhoe Bay Field to witness Safety Valve System testing on WGI Pad~ . BP representative Bill Preston was in charge of SVS tests on WGI Pad. Testing was conducted in a Safe & efficient manner. Two failures were witnessed. WGI 06 surface & sub-surface valVes failed to hold DP. This well was shut in until rePaired & re-tested~ The AOGCC teSt report is attached for reference. I inspected wellhouses on WGI Pad during SVS tests. All are clean & in good shape. SUMMARY: I witnessed SVS tests on PBU WGI Pad. 8 wells, 24components tested. 2 failures witnessed. 8.3% failure rate. 8 wellhouses inspected. Attachments: sVs PBU WGI Pad 1-15-01jc cc; NON-CONFIDENTIAL SVS PBU WGI Pad l-I 5-0 ljc.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Bill Preston AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad:' Prudhoe Bay Field WGI Pad Separator psi: LPS HPS 1/15/01 3400 -- , . _ ~]n -- Well Permit Separ Set L/p Test Test Test Date oil, WAG, ~J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE WGI-01 1790310 3400 2900 2440 P P P GINJ WGI-02 1790430 3400 2900 2650 P P P GINj wGI-03 -1790490' 3400 2900 2350 P P P GINJ WGI-04 1790500 3400 2900 2350 P P P GINJ WGI-05 1900250 3400 2900 2500 P P P GINJ WGI-06 1900300 3400 2900 2460 P 4 9 GINJ WGI-07 1900400 3400 2900 2480 P P P GINJ WGI-08 19004901 3400 2900 2620 P P P GINJ Wells: 8 Components: 24 Failures: 2 Failure Rate: 8.3% [] 90 Day Remarks: WGI-07 shut in untill repaired & re-tested. STATE OF ALASKA ALASKA ,.,,L AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 []Operation Shutdown []Stimulate [] Pull Tubing []Alter Casing [] Repair Well [] Other 5. Type of well: [] Development I--I Exploratory [] Stratigraphic [~ Service 4. Location of well at surface 493' SNL, 1159' WEL, SEC. 11, T11 N, R14E, UM At top of productive interval 2472' NSL, 260' WEL, SEC. 02, T11 N, R14E, UM At effective depth 2570' SNL, 94' WEL, SEC. 02, T11N, R14E, UM At total depth 2447' SNL, 61' WEL, SEC. 02, T11N, R14E, UM [] Plugging [] Perforate 6. Datum Elevation (DF or KB) RKB - 49' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number WGI-03 9. Permit Number / Approval No. 79-49 397-123 10. APl Number 50-029-20385 11. Field and Pool Prudhoe Bay Field / Pr~d~h~,~y~ Pool REC~,, ~-- 12. Present well condition summary Total depth: measured 9672 true vertical 8576 Effective depth: measured 9627 true vertical 8542 Casing Structural Conductor 78' Surface 2674' Intermediate Production 8520' Liner 1415' feetfeetfeet JunkPlUgs(measured)(measured) 0J G J N,&,L JAr. i 22. 1998 feet Alaska 0il & Gas Cons. Commi~, Anchorage Length Size Cemented MD TVD 20" 330 sx Arctic Set 78' 78' 13-3/8" 4680 sx Arctic Set II 2723' 2723' 9-5/8" 500 sx Class 'G' 8569' 7724' 7" 400 sx Class 'G' 8255' - 9670' 7468' - 8574' Perforation depth: measured true vertical 9046'-9119', 9137'-9259', 9281'-9352', 9365'-9387', 9413'-9471', 9485'-9521', 9534' -9559', 9570'-9580' 8103'-8159', 8172'-8264', 8281'-8335', 8344'-8361', 8381'-8424', 8435'-8462', 8472' -8491', 8499'-8507' Tubing (size, grade, and measured depth) 7-5/8" x 7", 29.7#/29#, NT-95/NT-80/L-80 from 22' - 8017'; 7", 29#, L-80, 8145' 8161' Packers and SSSV (type and measured depth) 9-5/8" x 7" Baker SABL packer at 7994'; 7" Camco BaI-O SVLN at 2230' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run I--I Oil I--] Gas [~ Suspended [] Daily Report of Well ~ns 17. I hereby certify that¢ for.~ng is, C~an~/root to the best of my knowledge' / Signed Dan Stole .~ry~.,?,.f~ ~ .,~./ Title Senior Drilling Engineer Prepared By Name/Number: Service Water & Gas Injector Form 10-404 Rev. 06/15/88 sion Date ///~/ /~ Terrie Hub/ble, 564f-~I628 Submit In Duplicat~~ Facility Date/Time 02 Nov 97 03 Nov 97 04 Nov 97 05 Nov 97 06 Nov 97 07 Nov 97 08 Nov 97 WGI 00:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-03:00 03:00-06:00 06:00-06:30 06:30-15:00 15:00-16:00 16:00-18:00 18:00-18:30 18:30-00:00 00:00-01:00 01:00-06:00 06:00-06:30 06:30-07:00 07:00-15:00 15:00-15:30 15:30-18:00 18:00-19:00 19:00-23:00 23:00-00:30 00:30-00:45 00:45-05:00 05:00-06:00 06:00-06:30 06:30-11:00 11:00-14:30 14:30-14:45 14:45-16:00 16:00-18:00 18:00-18:30 18:30-21:00 21:00-21:15 21:15-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-13:30 13:30-14:30 14:30-18:00 18:00-18:30 18:30-21:00 21:00-03:00 03:00-03:15 03:15-05:00 05:00-05:15 05:15-06:00 06:00-06:30 06:30-09:00 I . Progress Report Well WGI-03 Page 1 Rig Date 13 January 98 Duration 6hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 8-1/2 hr 3hr 1/2 hr 8-1/2 hr lhr 2hr 1/2 hr 5-1/2 hr lhr 5hr 1/2 hr 1/2 hr 8hr 1/2 hr 2-1/2 hr lhr 4hr 1-1/2 hr 1/4 hr 4-1/4 hr lhr 1/2 hr 4-1/2 hr 3-1/2 hr 1/4 hr 1-1/4 hr 2hr 1/2 hr 2-1/2 hr 1/4 hr 8-3/4 hr 1/2hr lhr lhr 5hr lhr 3-1/2 hr 1/2 hr 2-1/2 hr 6hr 1/4 hr 1-3/4 hr 1/4 hr 3/4 hr 1/2 hr 2-1/2 hr Activity Serviced Drillfloor / Derrick Held safety meeting Serviced Drillfloor / Derrick Held safety meeting Serviced Drillfloor / Derrick Held safety meeting Serviced Drillfloor / Derrick Held safety meeting Serviced Drillfloor / Derrick Rig moved 10.00 % Held safety meeting Rig moved 100.00 % Held safety meeting Rigged up Fluid system Held safety meeting Rigged up Fluid system Rigged down Surface tree /~- Rigged up BOP stack Held safety meeting Rigged up BOP stack Rigged up Lubricator Tested Annular preventor Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Circulated at 8024.00 ft Held drill (H2S) Laid down 27.00 ft of Tubing Rigged up sub-surface equipment - Retrievable packer Held safety meeting Tested BOP stack Rigged down BOP handling equipment Held drill (Spill) Circulated at 7880.00 ft Laid down 880.00 ft of Tubing Held safety meeting Laid down 2000.00 ft of Tubing Held drill (Kick while tripping) Laid down 5000.00 ft of Tubing Held safety meeting Rigged down Casing handling equipment Rigged up Lubricator Ran Drillpipe to 6500.00 ft (5in OD) Tested Kelly/top drive hose Ran Drillpipe to 7200.00 ft (5in OD) Held safety meeting Ran Drillpipe to 8026.00 ft (5in OD) 'Washed to 8135.00 ft Held drill (Kick while drilling) Circulated at 8097.00 ft Flow check Pulled Drillpipe in stands to 6200.00 ft Held safety meeting Pulled Drillpipe in stands to 0.00 ft Facility WGI Progress Report Well WGI-03 Rig Page Date 2 13 January 98 Date/Time 09 Nov 97 10 Nov 97 11 Nov 97 12 Nov 97 09:00-13:30 13:30-14:30 14:30-14:45 14:45-18:00 18:00-18:30 18:30-19:00 19:00-00:30 00:30-02:30 02:30-04:00 04:00-05:30 05:30-06:00 06:00-06:30 06:30-10:30 10:30-16:00 16:00-16:15 16:15-18:00 18:00-18:30 18:30-21:00 21:00-22:30 22:30-23:30 23:30-03:00 03:00-03:15 03:15-06:00 06:00-06:30 06:30-08:00 08:00-09:00 09:00-09:30 09:30-10:30 10:30-15:00 15:00-18:00 18:00-18:30 18:30-19:00 19:00-22:30 22:30-23:30 23:30-03:45 03:45-06:00 06:00-06:30 06:30-07:30 07:30-09:00 09:00-12:00 12:00-12:15 12:15-15:30 15:30-18:00 18:00-18:30 18:30-21:00 21:00-23:30 23:30-06:00 06:00-06:30 06:30-11:30 11:30-12:15 12:15-15:00 15:00-16:00 16:00-16:30 16:30-18:00 Duration 4-1/2 hr lhr 1/4 hr 3-1/4 hr 1/2 hr 1/2 hr 5-1/2 hr 2hr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 4hr 5-1/2 hr 1/4 hr 1-3/4 hr 1/2 hr 2-1/2 hr 1-1/2 hr lhr 3-1/2 hr 1/4 hr 2-3/4 hr 1/2 hr 1-1/2 hr lhr 1/2 hr lhr 4-1/2 hr 3hr 1/2 hr 1/2 hr 3-1/2 hr lhr 4-1/4 hr 2-1/4 hr 1/2 hr lhr 1-1/2 hr 3hr 1/4 hr 3-1/4 hr 2-1/2 hr 1/2 hr 2-1/2 hr 2-1/2 hr 6-1/2 hr 1/2 hr 5hr 3/4 hr 2-3/4 hr lhr 1/2 hr 1-1/2 hr Activity Ran Drillpipe in stands to 8020.00 ft Circulated at 8020.00 ft Held drill (H2S) Rigged down BOP stack Held safety meeting Removed BOP stack Rigged up BOP stack Tested BOP stack Circulated at 8096.00 ft Circulated at 8090.00 ft Flow check Held safety meeting Pulled Drillpipe in stands to 0.00 ft Ran Drillpipe in stands to 8097.00 ft Held drill (Fire) Washed to 8100.00 ft Held safety meeting Circulated at 8100.00 ft Washed to 8101.00 ft Circulated at 8101.00 ft Pulled Drillpipe in stands to 0.00 ft Held drill (H2S) Ran Drillpipe in stands to 4000.00 ft Held safety meeting Ran Drillpipe in stands to 8100.00 ft Serviced Block line Functioned Jars Circulated at 8100.00 ft Pulled Drillpipe in stands to 0.00 ft Ran Drillpipe in stands to 7000.00 ft Held safety meeting Ran Drillpipe in stands to 8100.00 ft Washed to 8104.00 ft Circulated at 8100.00 ft Pulled Drillpipe in stands to 0.00 ft Ran Drillpipe in stands to 5000.00 ft Held safety meeting Ran Drillpipe in stands to 8100.00 ft Circulated at 8100.00 ft Pulled Drillpipe in stands to 3400.00 ft Held drill (Kick while tripping) Pulled Drillpipe in stands to 0.00 ft Ran Drillpipe in stands to 3000.00 ft Held safety meeting Ran Drillpipe in stands to 8126.00 ft Circulated at 8154.00 ft Pulled out of hole to 4000.00 ft Held safety meeting Laid down 4000.00 ft of 5in OD drill pipe Rigged up Logging/braided cable equipment Conducted electric cable operations Rigged down Logging/braided cable equipment Removed Wear bushing Installed Tubing handling equipment Facility WGI Progress Report Well WGI-03 Rig Page Date 3 13 January 98 Date/Time 13 Nov 97 14 Nov 97 15 Nov 97 16 Nov 97 18:00-18:30 18:30-19:00 19:00-21:00 21:00-01:30 01:30-06:00 06:00-06:30 06:30-14:30 14:30-18:00 18:00-18:30 18:30-22:00 22:00-03:30 03:30-05:00 05:00-05:30 05:30-06:00 06:00-09:30 09:30-10:30 10:30-18:00 18:00-18:30 18:30-22:30 22:30-00:30 00:30-04:00 04:00-04:30 04:30-06:00 06:00-08:30 08:30-14:30 14:30-16:00 16:00-18:00 18:00-18:30 18:30-19:45 19:45-21:00 21:00-21:30 21:30-01:30 01:30-04:30 04:30-06:00 06:00-08:00 08:00-10:00 10:00-18:00 18:00-06:00 Duration 1/2 hr 1/2 hr 2hr 4-1/2 hr 4-1/2 hr 1/2 hr 8hr 3-1/2 hr 1/2 hr 3-1/2 hr 5-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 3-1/2 hr lhr 7-1/2 hr 1/2 hr 4hr 2hr 3-1/2 hr 1/2 hr 1-1/2 hr 2-1/2 hr 6hr 1-1/2 hr 2hr 1/2hr 1-1/4 hr 1-1/4 hr 1/2 hr 4hr 3hr 1-1/2 hr 2hr 2hr 8hr 12hr Activity Held safety meeting Installed Tubing handling equipment Ran Tubing to 0.00 ft (7-5/8in OD) Serviced Tubing Ran Tubing to 1600.00 ft (7-5/8in OD) Held safety meeting Ran Tubing to 4000.00 ft (7-5/8in OD) Laid down 2100.00 ft of Tubing Held safety meeting Laid down 1900.00 ft of Tubing Ran Tubing to 0.00 ft (7-5/8in OD) Tested Tubing Held safety meeting Ran Tubing to 7-5/8in (30.00 ft OD) Ran Tubing to 30.00 ft (7-5/8in OD) (cont...) Held safety meeting Ran Tubing to 2268.00 ft (7-5/8in OD) Held safety meeting Ran Tubing to 6000.00 ft (7-5/8in OD) Ran Tubing to 6030.00 ft (7-5/8in OD) Ran Tubing to 6880.00 ft (7-5/8in OD) Held safety meeting Ran Tubing to 7200.00 ft (7-5/8in OD) Ran Tubing to 8017.00 ft (7-5/8in OD) Installed Tubing hanger Rigged up Tubing hanger Reverse circulated at 8017.00 ft Held safety meeting Reverse circulated at 8017.00 ft Set packer at 7999.00 ft with 4000.0 psi Tested Permanent packer Rigged down BOP stack Installed Wellhead integral components Tested Tubing - Via annulus and string Tested Tubing - Via annulus and string Rig moved 0.00 % Held safety meeting Held safety meeting STATE OF ALASKA ALASKA ~.,.L AND GAS CONSERVATION CO~,..vlISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [~]Alter Casing [] Repair Well [] Other 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 493' SNL, 1159' WEL, SEC. 11, T11 N, R14E, UM At top of productive interval 2472' NSL, 260' WEL, SEC. 02, T11N, R14E, UM At effective depth 2570' SNL, 94' WEL, SEC. 02, T11N, R14E, UM At total depth 2447' SNL, 61' WEL, SEC. 02, T11N, R14E, UM 5. Type of well: [--I Development I~1 Exploratory [] Stratigraphic [~ Service 6. Datum Elevation (DF or KB) RKB = 49' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number WGI-03 9. Permit Number / AppmvalNo. 79-49 397-123 10. API Number 50-029-20385 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 9672 true vertical 8576 Effective depth: measured 9627 true vertical 8542 Casing Structural Conductor 78' Surface 2674' Intermediate Production 8520' Liner 1415' feet Plugs (measured) feet feet Junk (measured) feet Length Size Cemented 20" 330 sx Arctic Set 13-3/8" 4680 sx Arctic Set II 9-5/8" 500 sx Class 'G' 7" 400 sx Class 'G' MD TVD 78' 78' 2723' 2723' 8569' 7724' 8255'-9670' 7468'-8574' Perforation depth: measured true vertical 9046'-9119', 9137'-9259', 9281'-9352', 9365'-9387', 9413'-9471', 9485'-9521', 9534' -9559', 9570'-9580' 8103'-8159', 8172'-8264', 8281'-8335', 8344'-8361', 8381'-8424', 8435'-8462', 8472' -8491', 8499'-8507' Tubing ¢ize, grade, and measumd depth) 7-5/8",29.7#, NT-75, STLto 2181';7",26# 2182'-2187';7-5/8",29.7#, NT-75, STL 2188'-8022';7",26#,8022'-8055';7",29#, L-80,8145'-8161' Packers and SSSV (type and measured depth) 9-5/8" x 7" TIW HBBP packer at 8027'; 7" Camco BaI-O SSSV at 2182' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 116. Status of well classifications as: I~] Copies of Logs and Surveys run/'~ I [] Daily Report of Well O,~eratio~s/Z I [] Oil [~] Gas I--] Suspended 17. I hereby certify that the~e,.goir~ i~'[~e and cor/~ect to.the besJ~ rna/~nowledge SIgned Dan Stoltzdue Senior Drilling Engineer Prepared By Name/Number: Form 10-404 Rev. 06/15/88 Service Water & Gas Injector Date f d/~/~'~' Terrie Hubble, 564-4628 Submit In Duplicate~ Progress Report Facility WGI Well WGI-03 Rig Doyon 16 Page 1 Date 16 October97 Date/Time 25 Jul 97 26 Jul 97 27 Jul 97 28 Jul 97 29 Jul 97 30 Jul 97 31 Jul 97 01 Aug 97 02 Aug 97 03 Aug 97 12:00-17:00 17:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-07:30 07:30-17:00 17:00-18:00 18:00-18:30 18:30-01:00 01:00-06:00 06:00-06:30 06:30-08:30 08:30-14:30 14:30-15:00 15:00-18:00 18:00-18:30 18:30-20:30 20:30-20:45 20:45-01:00 01:00-05:30 05:30-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-09:30 09:30-11:00 11:00-18:00 18:00-18:30 18:30-01:30 01:30-04:00 04:00-04:30 04:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-21:00 21:00-22:00 22:00-06:00 06:00-06:30 Duration 5hr 13hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2hr lhr 9-1/2 hr lhr 1/2 hr 6-1/2 hr 5hr 1/2 hr 2hr 6hr 1/2 hr 3hr 1/2 hr 2hr 1/4 hr 4-1/4 hr 4-1/2 hr 1/2 hr 1/2 hr lhr lhr lhr 1-1/2 hr 7hr 1/2 hr 7hr 2-1/2 hr 1/2hr 1-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 2-1/2 hr lhr 8hr 1/2 hr Activity Rig moved 100.00 % Serviced Drillfloor / Derrick Held safety meeting Serviced Drillfloor / Derrick Held safety meeting Serviced Drillfloor / Derrick Held safety meeting Serviced Drillfloor / Derrick Held safety meeting Serviced Drillfloor / Derrick Held safety meeting Serviced Drillfloor / Derrick Held safety meeting Serviced Drillfloor / Derrick Held safety meeting Serviced Drillfloor / Derrick Held safety meeting Serviced Drillfloor / Derrick Held safety meeting Rigged down Drillfloor / Derrick Rig moved 100.00 % Rigged up Drillfloor / Derrick Held safety meeting Rigged up Drillfloor / Derrick Fill pits with Brine Held safety meeting Removed Lubricator Circulated at 8075.00 ft Installed Internal BOPs Rigged up BOP stack Held safety meeting Rigged up BOP stack Held drill (Spill) Rigged up BOP stack Tested BOP stack Rigged up Tubing handling equipment Held safety meeting Removed Lubricator Removed Tubing hanger Circulated at 8075.00 ft Laid down 160.00 ft of Liner Rigged down BOP stack Held safety meeting Installed BOP stack Pulled Tubing on retrieval string to 28.00 ft Circulated at 8075.00 ft Laid down 480.00 ft of Tubing Held safety meeting Laid down 6000.00 ft of Tubing Held safety meeting Laid down 2000.00 ft of Tubing Installed Wear bushing Singled in drill pipe to 4056.00 ft Held safety meeting Facility WGI Progress Report Well WGI-03 Rig Doyon 16 Page 2 Date 16 October 97 Date/Time 04 Aug 97 05 Aug 97 06 Aug 97 06:30-13:00 13:00-14:00 14:00-15:00 15:00-18:00 18:00-18:30 18:30-20:00 20:00-01:00 01:00-06:00 06:00-06:30 06:30-10:00 10:00-10:15 10:15-15:00 15:00-18:00 18:00-18:30 18:30-19:30 19:30-06:00 06:00-06:30 06:30-08:00 08:00-09:00 09:00-13:30 13:30-15:30 15:30-16:30 16:30-19:30 19:30-01:00 01:00-04:30 04:30-06:00 06:00-06:30 06:30-07:00 Duration 6-1/2 hr lhr lhr 3hr 1/2 hr 1-1/2 hr 5hr 5hr 1/2hr 3-1/2 hr 1/4 hr 4-3/4 hr 3hr 1/2 hr lhr 10-1/2 hr 1/2 hr 1-1/2 hr lhr 4-1/2 hr 2hr lhr 3hr 5-1/2 hr 3-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr Activity Singled in drill pipe to 8075.00 ft Stung into Permanent packer Circulated at 8075.00 ft Pulled out of hole to 8075.00 ft Held safety meeting Pulled out of hole to 500.00 ft Ran Drillpipe in stands to 8126.00 ft Circulated at 8115.00 ft Held safety meeting Circulated at 8115.00 ft Held safety meeting Laid down 3300.00 ft of 5in OD drill pipe Pulled Drillpipe in stands to 4800.00 ft Held safety meeting Rigged up Pipe ram Ran Tubing on landing string to 4000.00 ft Held safety meeting Ran Tubing on landing string to 5850.00 ft Installed SCSSSV nipple assembly Ran Tubing on landing string to 8055.00 ft Installed Liner hanger Reverse circulated at 8055.00 ft Set packer at 8055.00 ft with 4000.0 psi Rigged down BOP stack Installed Wellhead integral components Rig moved 0.00 % Held safety meeting Rig moved 50.00 % R CE VED '~--" STATE OF ALASKA '-'~. ALASKA ~J~L AND GAS CONSERVATION CO,,,,dlSSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: []Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator 15. Type of well: ARCO Alaska Inc. I [] Development i-] Exploratory 3. Address F-~ Stratigraphic P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service Location of well at surface 493' SNL, 1159' WEL, SEC. 11, T11N, R14E, UM At top of productive interval 2472' NSL, 260' WEL, SEC. 02, T11N, R14E, UM At effective depth 2570' SNL, 94' WEL, SEC. 02, T11N, R14E, UM At total depth 2447' SNL, 61' WEL, SEC. 02, T11N, R14E, UM 6. Datum Elevation (DF or KB) RKB - 49' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number WGI-03 9. Permit Number 79-49 10. APl Number 50-029-20385 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 9672 feet true vertical 8576 feet Effective depth: measured 9627 feet true vertical 8542 feet Casing Length Size Structural Conductor 78' Surface 2674' Intermediate Production 8520' Liner 1415' Plugs (measured) Junk (measured) Cemented 20" 330 sx Arctic Set 13-3/8" 4680 sx Arctic Set II '3~'-'~ i,3 1997' '.~orage WD 78' 78' 2723' 2?23' 9-5/8" 500 sx Class 'G' 8569' 7724' 7" 400 sx Class 'G' &?.5~- ,6~3'1 ORISINAL Perforation depth: measured 9046' - 9119', 9137' - 9259', 9281' - 9352', 9365' - 9387', 9413' - 9471', 9485' - 9521', 9534' - 9559', 9570' - 9580' true vertical 8103' - 8159', 8172' - 8264', 8281' - 8335', 8344' - 8361 ', 8381' - 8424', 8435' - 8462', 8472' - 8491', 8499' - 8507' Tubing (size, grade, and measured depth) 7-5/8", 29.7#, NT-75, STL to 2181 '; 7", 26# 2182' - 2187'; 7-5/8", 29.7#, NT-75, STL 2188' - 8022'; 7", 26#, 8022' - 8055'; 7", 29#, L-80, 8145' - 8161' Packers and SSSV (type and measured depth) 9-5/8" x 7" TIW HBBP packer at 8027'; 7" Camco Bal-O SSSV at 2182' 13. Attachments [~] Description summary of proposal I--~ Detailed operations program [] BOP sketch 15. Status of well classifications as: 14. Estimated date for commencing operation October 21, 1997 16. If proposal was verbally approved Name of approver Contact Engineer Narne/Number: ~hri~ 17. I hereby certify that t~for, Signed Dan Sto,tz (,~ V/ [] Oil [] Gas [] Suspended Service Water & Gas Injector /,~ Date approved I/ Bfovj(n,]564-5582 Jim Smith, 564-5026 Prepared By Name/Number: .~o]n~ is true and/~orrec~to the Jaejst j:)fimy knowledge Title Senior Drilling Engineer Commission Use Only Terrie Hubble, 564-4628 Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test /..-"' Location clearance Mechanical Integrity Test ~ Subsequent form required 10- Nc)~_ Approval No. 397-123 Approved by order of the Commission Form 10-403 Rev. 06/15/88 drtginat Signed By David W. Johnston Commissioner Submit In Triplicate~ WGI-03 RE-WORKOVER SUMMARY Objective This well was worked over on the 30th July in order to increase the well's lagging injectivity by replacing the existing 7" tubing with 7-5/8" internally plastic coated tubing. The completion was successfully replaced with 7-5/8" tubing, and a 4,000psi test obtained prior to the rig leaving. Subsequently, however, while on injection, annular pressure build up while on gas injection was observed. A leak to gas was identified (sealing to liquid), and this gradually worsened to the point where the well now leaks to liquid. A video log was obtained and showed the leak to be a horizontal crack in the tubing hanger insert. The objective of this rig workover is to replace the leaking tubing hanger pup from the recently run completion and return the well to injection. Critical Well Information Existing 7-5/8" 29.04#, NT95HS ST-L Tubing 7" SSSV Landing Nipple: 2,210' MD TIW HBBP packer (6.165" ID): 8,027' MD Minimum ID (4.845" ID): 8,160' MD (Baker shear out sub) I.D. = 6.875" PBTD (7"): 9,627' MD XN nipple, 5.75" No-go Perforations: 9,046'-9,580' MD Pre-Riq Procedure . R/U coiled tubing and RIH. Circulate well to 9.6ppg NaCI brine (zero pressure on tubing and IA). Bullhead a 100bbl sized salt pill to the perforations (preceded by 50bbls 10ppg hi-vis NaCI brine spacer), followed by 50bbls 10ppg hi-vis NaCI brine spacer and 9.6ppg kill weight brine. Monitor well for losses. If losses are observed, re-treat until losses are zero. 2. R/U electric line and set an inflatable bridge plug in the remainder of the original 7" completion at 8150' MD (above the sized salt plug). Pressure test plug, packer, and 9-5/8" casing to 4,000psi from above. o RIH and set a 7" RHC plug in the well at 8,047' MD. Freeze protect to _+2,200' MD. Test plug and tubing to 4,000psi. Estimated BHP at 8,105TVD is 3,550psi (8.4ppg EMW). Note that at this point, the well will be theoretically overbalanced by 252psi. 4. Set BPV and test from below by pumping down the annulus and in through the leak. Remove wellhouse and flowlines, level pad, dig out cellar. Summary Ri.q Procedure 1. Test 9-5/8" packoff to 5000psi, and function lock down screws. 2. MIRU. Pull BPV. Monitor well for losses. If zero, set and test BPV. ND tree. NU BOP's. Set test dart (TWCV). Test BOP's. Pull test dart and BPV. . Spear tubing below the leak point and pull test on the tubing to establish the amount of stretch which can be achieved from the tubing. Rig will pull to derrick limit of 460klbs (90% of ST-L tubing connection limit). Slack off and re-seat tubing hanger. Pressure test annulus to determine packer integrity. . If packer integrity confirmed, repeat pull on the tubing to maximum of 460klbs and re-measure tubing stretch obtained. Re-seat tubing hanger, and pressure test annulus to deter:~ir~e ~a~.t~r~jrjt~'~. If any sign of packer movement or loss of integri~ is obse~ed, the rig will re~~~ ~i~ BOP's, tubin~packer will be retrieved, and a new completion run (skip to step 7.) .. WGI-03 Sundry Workover Procedure Page 2/2 . If sufficient stretch can be obtained to replace tubing hanger without requirement to cut/pull the completion AND packer integrity is still intact, ND BOP's and R/U tubing tongs and handling equipment over the wellhead (note this will be below the rotary table in the rig substructure). Engage tubing hanger with spear set at about 60' below the hanger and pull on 7-5/8" tubing. . Stretch tubing until emergency slips can be placed in the wellhead around the first joint of 7-5/8" tubing. Back-off leaking pup joint and tubing hanger, and replace with new pup joint/hanger. Retrieve emergency slips. Land tubing, N/U and test tree. Test tubing and annulus to 4,000psi. Set BPV and RDMO (note freeze protection will be performed immediately after the rig leaves by PE group unless timing is an issue). If stretch of the tubing is unsuccessful R/D equipment, N/U and test BOP's, and continue to step 7. IF TUBING CANNOT BE STRETCHED SUFFICIENTLY TO REPLACE THE TUBING HANGER . . . R/U wireline and retrieve 7" RHC plug from the well. R/U electric line and chemical cut the tubing as close as possible above the packer. Retrieve 7-5/8" completion from the well. M/U and RIH with milling assembly and mill/retrieve packer and tailpipe. M/U and re-run 7-5/8" NT-95HS ST-L completion with a replacement tubing hanger/pup (7' SSSV, a new 9- 5/8" x 7" packer, 7" tailpipe with XN nipple configuration and a 7" WLEG). This will be set _+30' above the packer remaining from the 1979 completion. No GLM's are required for this completion. NOTE: Drift tubing to maximum OD required post-rig. 10. Circulate well to NaCl brine. Tubing freeze protection will be performed by the PE group after the rig leaves unless there is a rig timing issue. Land completion, set packer, and test tubing to 4,000psi Test annulus to 4,000psi. 11. Set TWCV (BPV/test dart) and test from above. N/D BOP's. N/U and test tree. Pull BPV and test dart. Check well for flow. 12. Set BPV and RDMO. Prepared by: .~_~~ o ,q E.!/,~/~ ~, ,~ ~" "' Doyon 16 Ops Drlg'En[jr- - Chris Brown Doyon 16 Operations Drilling Engineer (Office) 564-5582 (Home) 346-3773 (Pager) 275-1835 Orfglnal KB. ELEV = 49' WGI-03 c;omplet~on Pad ELEV= 19' 7" tubing hanger '~' ---- ~ r- - 2,468, 7-5/8" x 7" crossover ,~ I i 7' SSSV @ 13-3/8", 68#, N-80 j % O k, +/- 2,210' BTC @ 2,723' 9-5/8', 47#, SOO 95 BTC from surface to 2306' 7-5/8", 29.04#, NT95HS ST-L plastic coated tubing 7'5/8" x 7" cr°ssover Z_~II I~ 9-5/8" x 7'packer (new) +/-8,055' 20'x 7" 26~ NSCC m 7" XN nipple, 5.5' No-go tailpipe w/7' WLEG I,~ j 7' tubing stub w/scoophead guide +/-8,075'~1~ ~ Top at +/- 8,135' . Top of liner ' 9,5/8" x 7' SB-2 @ 8,255' ~~ ~ packer at +/- 8,145' j 9-5/8', 47#/ft, (existing) N80, BTC @ 8,569' Perforations @ 9,046'-9,059' 9,059'-9,079' 9,079'-9,099' i 9,099'-9,119' 9,137'-9,147' 9,147'-9,165' 9,165'-9,195' 9,195'-9,219' 9,219'-9,259' 9,281 '-9,301' ~ 9,301'-9,321' 9,321'-9,352' ] 9,365'-9,375' 9,375'-9,387' 9,413'-9,433' l 9,433'-9,451' 9,451 '-9,471' I~ 9,485'-9,495' ] 9,495'-9,511' ] 9,511'-9,521' 9,534'-9,549' 9,549'-9,559' PBTD @ 9,627' ~ 9,570'-9,580' TD @ 9,672' J k 7', 29#, N80 BTC liner @ 9,670' DATE REV. BY COMMENTS 7-9-97 CJB Workover to replace tubing PRUDHOE BAY UNIT WELL:WGI-03 ; : : Odglnal KB. ELEV -- 49' WGI-03 Completion PadELEV= ~9' 7' tubing hanger -:' ---- ~ r- - ', -.J..~ o.~.°:' P~.~e~ ~ctto~ ~ · - ~ ~U _ ' ~ FO cementer e2,329' 7-5/8" x 7" crossover ~ ~ ~ o o o ~, ~ ~~ 7' sssv BTC from sudace to ~ 2306' I . 7-5/8", 29.0~, NT95HS ' ST-L plastic coated 6~ ,-~ tubing -: - 7-5/8" x 7" crossover ~ ~ ~o e~o ~ 9-5/8" x 7'packer (new) +/-8,055' ~~7' XN nipple, 5,5' N~go 20'x 7" 2~ NSCC ~ ~ ~ tailpipe w~' WLEG , I e ~ c~ ~ ' ~ I~ ~7" tubing stub w/scoophead guide +/-8,075' ~ Top at +/- 8,135' ~' · 9-5/8' x 7' SB-2 Top of liner ~o - o o ~' packer at +/- 8,145' ~ 8,255' ~~o ~ ~ (existing) ~ ~ ~ ~5/8', 47~, ~T4~~e~ + + N80, BTC ~ 8,569' ~ 2 ~,t ~' ~ (~ ~' Pedorations ~ g,~6'-9,059' ~o W, ee~ ~t).. , 4-. -~-, 9,059'-9,079' ~ 9,079'-9,099' ~ '~' '{' ~ g,099'-9,119' - +-~ 9,13~-9,14~ -~ ~,.' ~ 9,14~-9,165' 9,165'-9,195' ~. ~ ~-- ~ 9,195'-9,219' " ~~ 9,219'-9,~9' .. 9,281 '-9,301' ~ ~ 9,~1'-9,321' ~ ~ 9,321'-9,~E · (.,'} ~ 9,365'-9,375' .,3 ] 9,375'-9,~ 9,413'-9,~' ~ 9,451'-9,471' I ~0 ~ ' ' 9,~'-9,495' 9,495'-9,511' --- ~ 9,511'-9,521' + ~ ~ 9,~'-9,~9' ~~ 9,~9'-9,559' PBTD ~ 9,627' ~ ',~ ~ TD ~ 9,672' J ~ k 7', 29~, N80 BTC liner ~ 9,670' . . . DATE REV. BY COMME~S 7-9-97 ~B Wo~over to replace tubing pRUDHOE BAY UNIT WELL:WGI-03 DATE: 8/31/97 INJECTION WELL ANNULAR COMMUNICATION VERBAL NOTIFICATION OF AOGCC PER AREA INJF~TION ORDER #4 =,1._ " .... ..., -I'Ll ...... " · TIME: ] 4:15 hrs. NOTIFIED BY: David D. Smil.ll AOGCC CONTACT: Chuck Scheve REASON: Injection Well _WGI-03_ An~mlar Colnmunication Per Rt..fleT. nRcquirements of Area l.njec];!.on Order.,_.,. _. No. 4 Well WGI-03 is a Gas lnjcclion well t.l~at has developed limited Tubing x Inner Annulus communication, The well was recently worked over and it appears that a snmll gas leak has dcvelopct'l ]~igl~ i~ 1.he Tbg string, At. 1his time we suspect a small thread leak at tnw: of the T~bing joi,~ts. Pertinent inff~mmtion Is as foll~s: · Thc leak is small and appca,-s it') 1)e only to gas. · The leak is shallow above 200', and tl~s any significant failure at the well t~ead or near the smihcc wmfld still be conlrollcd by the SSSV. · ~1 other mccl~antcal integrily conqJo~mnts of the wcll are in excellent coildition due to lhc recent Rig workovcr conq)leted 8/6/97. · Thc wellhead, SSSV sysl.e:~n has illlilgrtty per testing all(l pressure monitoring. Planned Action: Sl Gas injection. Load well with SW, rcn~ovc ii~e pressure £rom thc lA m)(l maintain daily surveillance on the well 1.o assure ~1o addition)al loading is needed, Complete any additic,~al diagnoslic work thai c:im 1)¢ identified. Identify and generate a repair b, cc sro s : None required at this li~nc. '--gi'ihdr~-'Notici~'ficq'd itt il',i.q linni'?' YES .... NO ~roblem Well Spec.~allst q.~';;~ .... - ........ __ _ . Orig: Orig: Problem Well S1)ecialisl' cc: Wells Superintcnde~d, Wells Operations Slq)ervisor FSI DS Supervisor FSI Superinte~de~l DS WGI Engineer Alas~ .Oil .& Gas Cons, Cominis~,,. .'~" STATE OF ALASKA '-" ALASKA ...tL AND GAS CONSERVATION CO,v,,vIISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program []Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 493' SNL, 1159' WEL, SEC. 11, T11N, R14E, UM At top of productive interval 2472' NSL, 260' WEL, SEC. 02, T11N, R14E, UM At effective depth 2570' SNL, 94' WEL, SEC. 02, T11N, R14E, UM At total depth 2447' SNL, 61' WEL, SEC. 02, TllN, R14E, UM 5. Type of well: [--I Development [] Exploratory [] Stratigraphic [~Service 6. Datum Elevation (DF or KB) RKB = 49' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number WGI-03 9. Permit Number 79-49 10. APl Number 50-029-20385 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 9672 feet true vertical 8576 feet Effective depth: measured 9627 feet true vertical 8542 feet Casing Length Size Structural Conductor 78' 20" Surface 2674' 13-3/8" Intermediate Production 8520' Liner 1415' Plugs(measured) Junk (measured) Cemented ~5 ~5, B M~ 330 sx Arctic Set ~ ;~.*~ 78 4680 sx Arctic Set II 2723' 9-5/8" 500 sx Class 'G' 8569' 7" 400 sx Class 'G' 8255' - 9670' TVD 78' 2723' 7724' 7468' - 8574' Perforation depth: measured 9046' - 9119', 9137' - 9259', 9281' - 9352', 9365' - 9387', 9413' - 9471 ', 9485' - 9521 ', 9534' - 9559', 9570' - 9580' true vertical 8103' - 8159', 8172' ~ 8264', 8281' - 8335', 8344' - 8361', 8381' - 8424', 8435' - 8462', 8472' - 8491 ', 8499' - 8507' Tubing (size, grade, and measured depth) 7", 29#, L-80 at 8160' Packers and SSSV (type and measured depth) Baker SB-2 packer at 8145'; Otis RPB SSSV at 2210' 13. Attachments [] Description summary of proposal 4. Estimated date for commencing operation July 18, 1997 16. If proposal was verbally approved Name of approver Contact Engineer Name/Number: Chris Brown, 564-5582 17. I hereby certify that I/h~/o~go~~Cj~d Signed Dan Stoltz .... .. '-' [--I Detailed operations program [] BOP sketch Date approved il 5. Status of well classifications as: I--I Oil I--I Gas [] Suspended Service Water & Gas Injector Prepared By Name/Number: Terrie Hubble, 564-4628 correct to the best of my knowledge Title Senior Drilling Engineer Commission Use Only Date ~//~?.,~ JConditions o..,f~J3roval: Notify Commission so representative may witness J Approval No.~_~F~.-* ~ '* _ue(~ ~"~' ' Plug integrity BOP Test ~ Location clearance -- I Ik~3 ~(,.~'('~%~ Mechanical Integrity Test f Subsequent form required 10-/,/6~ I ~'~~ ORIGINAL SIGNED BY ' ' r Robert N Ohnstenson IA~'~e¥ 0rder of the Commission ' ' Commissioner Form 10-403 Rev. 06/15/88 Submit In Triplicate,~ ..- WGI-03 WORKOVER SUMMARY Objective The objective of this rig workover is to increase the well's lagging injectivity by replacing the existing 7" tubing with 7-5/8" internally plastic coated tubing. The seals will be pulled from the existing packer and a new or re- dressed assembly run and stabbed into the packer. Jewelry will remain 7" in size. Critical Well Information Existing 7", 29#, N80 Tubing I.D. = 6.184" 7" SSSV Landing Nipple: 2,210' MD Minimum ID (4.845" ID): 8,160' MD (Baker shear out sub) 7", 29#, N80, Liner I.D. = 6.184" PBTD (7"): 9,627' MD Perforations: 9,046'-9,580' MD New 7-5/8" 29.04#, NT95HS ST-L Tubing I.D. = 6.875" 7" SSSV Landing nipple: 2,210' MD 7" Packer, XN nipple, 5.75" No-go Pre-Ria Procedure 1. Test annulus to 3,500psi if not recently tested. 2. R/U slickline and drift tubing down to 9,000'. 3. R/U coiled tubing and bullhead a 100bbl sized salt pill to the perforations (preceded by 50bbls 10ppg hi-vis NaCI brine spacer), followed by 50bbls 10ppg hi-vis NaCl brine spacer and 9.6ppg kill weight brine. 4. RIH with chemical cutter on wire-line and cut tubing at first full joint above the packer seals at +_8,113' MD. . Circulate well to 9.6ppg NaCI brine (zero pressure on tubing and IA). Freeze protect to +_2,200' MD (if necessary). Estimated BHP at 8,105TVD is 3,550psi (8.4ppg EMW). Note that at this point, the well will be theoretically overbalanced by 252psi provided the brine column is not reduced by fluid moving into the formation after the well has been killed. 6. Set and test BPV. Remove wellhouse and flowlines, level pad, dig out cellar. Summary Ri.q Procedure 1. Test 9-5/8" packoff to 5000psi, and function lock down screws. 2. MIRU. Circulate well with 9.6 ppg NaCI brine. Set and test BPV. ND tree. NU BOP's. Set test dart (TWCV). Test BOP's. Pull test dart and BPV. 3. Pull 7" tubing from chemical cut made in pre-rig. Replace 9-5/8" packoff if necessary while pulling tubing. 4. M/U fishing assembly. RIH, retrieve seals, and POOH. If seals cannot be pulled, an overshot guide will be run as a contingency. WGI-03 Sundry Workover Procedure Page 2/2 . M/U and run new 7-5/8" NT-95HS ST-L completion with 7" SSSV, 9-5/8"x7" packer, 7" tailpipe with XN nipple configuration and a 7" WLEG. This will be set _+30' above the existing packer. No GLM's are required for this completion. NOTE: If the seals cannot be pulled, the completion will include an overshot guide instead of the WLEG. Drift tubing to maximum OD required post-rig. 6. Circulate well to NaCI brine/freeze protect tubing/annulus to +_2,200' MD. Land completion and test tubing to 4,200psi. 7. Set BPV/test dart and test from above. N/D BOP's. N/U and test tree. Pull test dart and BPV. Check well for flow. 8. Set BPVand RDMO. Prepared by: ~ ,/~-y'on 16 Ops Drlg Engr Chris Brown Doyon 16 Operations Drilling Engineer (Office) 564-5582 (Home) 346-3773 (Pager) 275-1835 ARCO Alaska, Inc. Post Office B~""~LO0360 Anchorage A. J 99510-0360 Telephone 907 276 1215 August 10, 1993 Ms. Joan Miller Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re' Outstanding Application Approvals Dear Ms. Miller: Per your 7/30/93 letter to Mr. James Cawvey, regarding the listed outstanding 10-404's (Report of Sundry Well Operations), the following summary is provided: Well 1-16: Approval fi 8-988, Approved 12-28-88. Report Sundry attached covering Reperforating work. -Tq- q3 31 -~<~ ~-~ 4) Well 3-16i: Approval # 9-740, Approved 8-23-89. Report Sundry attached covering Acid Stimulation, Squeeze, & Reperforattng work. Cement Well 3-16i: Approval fi 91-234, Approved 8-6-91. Report Sundry covering Perforatiing work was previously completed & sent to AOGCC 11/91. A copy of this Report is attached. : Well 5-18: Approval # 9-993, Approved 11-15-89. Report Sundry attached covering Initial Perforating work. Well 5-26:~Approval # 90-060, Approved 2-1-90. The approved Stimulation work for 2/90 was never~performed, Please ;cancePthis approval. Well 7-06:' Approval # 90-666, Approved 8-27-90. The approved Gas Shutoff work for 9/90 was never, performed. Please-cancel this approval. Well 11-2: Approval # 90-066, Approved 2-6-90. Report Sundry attached covering Tubing'Washes Reperforating work. Px E C E!VDE ARCO Alaska, Inc. Is a Subsidiary of Atlantic Richfield Coml~any AU G 1 9 199;~ Alaska 0ii & Gas Cons. CommisSi0~ Anchorage Ms. Joan M.iIler ~ August 10, i '.3 Page 2 %'b--\~L~ 9) 12) Well 11127: Approval # 9-750, Approved 8-24-89. Report Sundry covering Perforatiing work was previously completed & sent to AOGCC 9/89. A copy of this Report is attached. We 12-25: Approval # 92-01-9, Approved 2-4-92, The approved Pull Tubing work for 2/93 was never performed. Please cancel this approval. Well 15-8: Approval # 90-526, Approved 7-12-90. The approved Stimulation work for 8/90 was performed 3/91. The Report Sundry is attached. Well 15-10A: Approval # 90-463, Approved 6-19-90. The approved Pull Tubing work for 8/90 was never.performed. Please cancel this approval. Well LGI-4: Approval # 90-852, Approved 12-3-90. Re: the approved Stimulation/Reperforating work for 11/90' Since this is a Lisbume Well, reconciliation of this approval will be handled by the Lisbume Operations Group. I will notify the person responsible in the Lisburne group to handle this outstanding Report Sundry. WGI-3_: Approval # 8-76, Approved 2-10-88. Report Sundry attached covering Stimulation Treatment work. Sincerely, / John W. Peirce Engineering Aide jwP/o o Attachments cc. ¢c/d. L. Cawvey - (ARCO) - ATO- 1520 il M. Sloan - (BPX) - Drilling Dept. RECEIVED AUG 1 9 .]993 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA " ALASKA ~. AND GAS CONSERVATION CC~--'/llSSION /-~ REPORT SUNDRY WELL OPERATIONS' 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate ' / ,./~.'~'~ Pull tubing Alter casing Repair well Other (.~//~/'~ 5. Type of Well 6. Datum of elevation(DF or KB) Development 49 RKB fee~ I 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 Exploratory Strafigraphic Service 4. Location of well at surface 493' FNL & 1159' FEL, Sec. 11, T11N, R14E, UM At top of productive interval 2472' FSL & 260' FEL, Sec. 2, T11 N, R14E, UM At effective depth 2570' FNL, & 94' FEL, Sec. 2, T11N, R14E, UM At total depth 2447' FNL, & 61' FEL, Sec. 2, T11N, R14E, UM 12. Present well condition summary Total depth: REEEIVED AUG 1 9 199;5 Alaska 0il & Gas Cons. C0mmiss[0~ A.n. ch0r ge measured 9672 feet Plugs(measured) true vertical 8576 feet 7. Unit or Property Prudhoe Bay Unit 8. Well number WGI-3 9. Permit number/approval number 79-49/8-76 10. APl number 50 - 029-20385 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured 9627 feet true vertical 8542 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 78' 20" 330 sx Arctic Set 78' 78' Surface 2674' 13-3/8" 4680 sx Arctic Set II 2723' 2723' Production 8520' 9-5/8" 500 sx Class G 8569' 7724' Liner 1415' 7" 400 sx Class G 8255-9670' 7468-8574' Perforation depth: measured 9046-9119'; 9137-9259'; 9281-9352'; 9365-9387'; 9413-9471'; 9485-9521'; 9534-9559'; 9570-9580' true vertical 8103-8159'; 8172-8264'; 8281-8335'; 8344-8361'; 8381-8424'; 8435-8462'; 8472-8491'; 8499-8507' Tubing (size, grade, and measured depth) 7", 29#, L-80 @ 8160' MD Packers and SSSV (type and measured depth) Baker SB-2 Packer @ 8145' MD; Otis RPB SSSV @ 2210' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 174,000 210,000 Tubing Pressure 3900 3900 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Engineering Supervisor Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE 1022/4 JMV cc: SW, JWP WGI-3 STIMULATION TREATMENT DESCRIPTION OF WORK COMPLETED 2/13/88: MIRU CT & PT equipment to 4000 psi. perforation intervals at: Pumped a fullbore acid stimulation treating the open 9046 - 9119' MD (Z4) 9137- 9259' MD (Z3) 9281 - 9352' MD (Z2) 9365 - 9387' MD (Z2) 9413 - 9471' MD (Z2/1) 9485 - 9521' MD (Zl) 9534 - 9559' MD (Zl) 9570 - 9580' MD (Z l) Ref. Log: BHCS 9/20~79. Pumped: a) b) c) d) e) f) g) h) i) J) k) 14.3 71.4 59.5 59.5 35.0 14.3 35.7 bbls Xylene, nitrified w/1000 scf N2/bbl, followed by bbls 12% HCI w/additives, followed by bbls 12% HCI - 3% HF w/additives, followed by bbls 2% NH4CI Water, followed by bbls 2% NH4CI gelled w/HEC & 2500 N2/bbl, followed by bbls Xylene, nitrified w/1000 scf N2/bbl, followed by bbls 12% HCl w/additives, followed by 59.5 bbls 12% HCI - 3% HF w/additives, followed by 59.5 bbls 2% NH4CI Water, followed by 35.0 bbls 2% NH4Cl gelled w/HEC & 2500 N2/bbl, followed by 19.0 bbls Xylene, nitrified w/1000 scl N2/bbl, followed by I) 35.7 bbls 12% HCI w/additives, followed by m) 76.2 bbls 12% HCI - 3% HF w/additives, followed by n) 76.2 bbls 2% NH4CI Water, followed by o) 45.0 bbls 2% NH4CI gelled w/HEC & 2500 N2/bbl, followed by p) 19.0 bbls Xylene, nitrified w/1000 scf N2/bbl, followed by q) 35.7 bbls 12% HCl w/additives, followed by r) 76.2 bbls 12% HCI - 3% HF w/additives, followed by s) 76.2 bbls 2% NH4Cl Water, followed by t) 45.0 bbls 2% NH4Cl gelled w/HEC & 2500 N2/bbl, followed by u) 28.6 bbls Xylene, nitrified w/1000 scf N2/bbl, followed by v) 59.5 bbls 12% HCl w/additives, followed by w) 144.0 bbls 12% HCI - 3% HF w/additives, followed by x) 150.0 bbls 50/50 Methanol Water, followed by y) Shutdown. Rigged down. Returned well to gas injection & obtained a valid injection rate. RECEIVED AU G 1 9 1993 Alaska Oil & Gas Cons, Comrnissiop Anchorage ALASI~X OIL AND GAS CONSERVATION CO~I~IISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOFY: (907) 276-7542 July 30, 1993 Mr. James L. Cawvey Engineering Supervisor ARCO Alaska Inc P.O. Box 100360 Anchorage, AK 99510-0360 Re: Prudhoe Bay Unit, AOGCC Forms 10-403 and 10-404 Dear Mr. Cawvey, In making a review of well files we have found some files which contain approved Application of Sundry Approval forms (form 10-403) that have no subsequent Reports of Sundry Well Operations (form 10-404). Enclosed a list of the wells in question. To be in compliance with AS 20 AAC 25.280(d) of the Regulations, the form 10-404 is required to be filed with 30 days following completion of work. We would also appreciate notification of any canceled work So that the corresponding Application on file can be marked accordingly. Your help in directing the enclosed list to the appropriate responsible parties will be appreciated. Sincerely, Joan Miller Statistical Technician r(;'~ f~ir~l~.d cn r~.cy¢lc;t [),3r;~,, t) '¥' ." '.. PRUDHO~ BAY - ARCO Well No. DSl-16 DS3-16 DS5-18 DS5-26 DS7-6 DSll-2 DSll-27 DS12-25 DS15-8 DS15-10A LGI-4 WGI-3 Permit No. 78-8 79-93 89-76 89-113 78-14 81-128 86-148 83-166 84-155 88-85 88-13 79-49 Approval Date & No. 12-28-88, 8-988 8-23-89, 9-740 8-6-91, 91-234 11-15-89, 9-993 2-1-90, 90-060 8-27-90, 90-666 2-6-90, 90-066 8-24-89, 9-750 2-4-92, 92-019 7-12-90, 90=526 6-19-90, 90-463 12-3-90, 90-852 2-10-88, 8-76 Description Perforate 12-88 Perforate 8-89 Perforate 3 Q '91 Perforate 11-15-89 Stimulate 2-90 Gas shutoff treatment 9-90 Perf., stimulate, perform CTU cement squeeze 2-90 Perforate 3 Q '89 Pull tubing 2-93 ~ Stimulate 8-90 Pull tubing 8-90 Stimulate, perforate 11-90 Stimulate 2-88 STATE Of ALASKA ALASK~ ,.)Il AND GAS CONSERVATION COMM~_ ..,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension © Change approved program Fi, Plugging [] Stimulate '~ Pull tubing [] Amend order [] Perforate [] Other 5. Datum elevation (DF or KB) RKR 49' 6. Unit or Property name Prudhoe Bay Unit 7. Well number WGI-3 (34-2-11-14) 8. Permit number 7q-4q 9. APl number 50--029-20.~R5 10. Pool Sadlerochit 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360, Anchorage,' AK 99510 4. Location of well at surface 493'FNL & 1159'FEL, Sec. 11, T11N, RZ4E, UM At top of productive interval 2472'FSL & 260'FEL, Sec. 2, T11N R14E, UM At effective depth 2570'FNL & 94'FEL, Sec. 2, T11N, R14E, UN At total depth 2447'FNL & 61'FEL, Sec. 2, T11N, R14E, UN 11. Present well condition summary Total depth: measured true vertical feet 9672 feet Plugs (measured) 8576 feet RECEIVED Effective depth: measured 9627 feet Junk (measured) true vertical 8542 feet ~aska 0il & Gas Cons. C0mmiss[~ Anchorage Casing Length Size Cemented Measured depth True Vertical depth Conductor 78' 20" 330 sx Arctic Set 78' 78' Surface 2674' 13-3/8" 4680 sx Arctic Set II 2723' 2723' Intermediate 8520' 9-5/8" 500 sx Class G 8569' 7724' Liner 1415' 7" 400 sx Class G 8255-9670' 7468'-8574' Perforation depth: measured 9046-9119' 9137-9259' 9281-9352' 9365-9387' 9413-9471' 9485-9521', 9534-9559' 9570 9580' true vertical 8105-8161' 8175-8268' 8285-8338' 8348-8364' 8384-8427' 8437-8464' 8474-8492' 8500-8508' Tubing (size, grade and measured depth) 7" 29# L-80 @ 8160 'MD Packers and SSSV (type and measured depth) Baker SB-2 Packer @ 8145'/Otis RPB SSSV @ 2210'rqD 12.Attachments Description summary of proposal [] Detailed operations program BOP sketch [] 13. Estimated date for commencing operation February 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,¢~m,7¢,,~J~ Title Operations Engineerin~ Manager Date ¢~///~ Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI c'~- ~7 ~ Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy . Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 WGI-3/Stat16 J. M. Vitucci (265-6358) Submit in triplicate WGI 2 AND WGI 3 12% HCI-3% HF MATRIX ACID STIMULATION ARCO Alaska Inc. proposes to perform the following mud acid matrix acid stimulation on Wells WGI 2 and WGI 3: 1. MIRU slickline unit. 2. GIH w/gauge ring and perform a tag run to PBTD to ensure all perforations are clear of fill. POH and RD. 3. MI and RU pump trucks, transports, and N2 unit. 4. Stimulate the well as follows: A. 600 gals of xylene nitrified w/1000 SCF N2/bbl . B. 3000 gals of 12% HCl w/additives C. 2500 gals of 12% HCl-3% HF w/additives D. 2500 gals of 2% NH4CI water E. 100 bbls of foam consisting of 35 bbls of 2% NH4CI water gelled w/HEC polymer and 2500 SCF N2/bbl water F. 600 gals of xylene nitrified w/1000 $CF N2/bbl G 1500 gals of 12% HCl w/additives H. 2500 gals of 12% HCI-3% HF w/additives I. 2500 gals of 2% NH4CI water J. 100 bbls of foam ~consisting of 35 bbls of 2% NH4Cl water gelled w/HEC polymer and 2500 $CF N2/bbl water K. 800 gals of xylene nitrified w/1000 $CF N2/bbl L. 1500 gals of 12% HCl w/additives M. 3200 gals of 12% HCl-3% HF w/additives N. 3200 gals of 2% NH4CI water Q 128 bbls of foam consisting of 45 bbls of 2% NH4CI water gelled w/HEC polymer and 2500 SCF N2/bbl water P. 800 gals of xylene nitrified w/1000 SCF N2/bbl Q 1500 gals of 12% HCl w/additives R. 3200 gals of 12% HCl-3% HF w/additives $. 3200 gals of 2% NH4CI water T. 128 bbls of foam consisting of 45 bbls of 2% NH4CI water gelled w/HEC polymer and 2500 $CF N2/bbl water U. 1200 gals of xylene nitrified w/1000 $CF N2/bbl V. 2500 gals of 12% HCl w/additives W. 4800 gals of 12% HCl-3% HF w/additives X. 150 bbls of 50/50 methanol/water 5. RD and release equipment. Return well to injection immediately. ~.. 6. Test well for new injection Capacity. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C~MMISSION WELL COMPLETION OR RI=COMPLETION REPORT AND LDO 1. Status of Well Classification of Service Well Gas Injection OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE~ 2. Name of Operator / 7. Permit Number ARCO Alaska~ Inc. 79-49 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20385 4. Location of well at surface 9. Unit or Lease Name 493'FNL & l159'FEL, Sec. 11, TllN, R14E~ UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2472'FSL & 260' FEL, Sec. 2, TllN, R14E, UM WGI-3 (33-2-11-14) At Total Depth 1 1. Field and Pool 2447'FNL & 61'FEL, Sec. 2, TllN, R14, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 49' RKBI APL 28302 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 09/05/79 09/20/79 09/26/79I N/A feet MSL Single 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 9672'MD, 8576'TVD 9627'MD, 8543'TVD YES ~ NO [] 2210 feet MD] 1900' (Approx.) 22. Type Electric or Other Logs Run DIL/S?/BHCS/OR, ~DC/C~m/CA~/CC~,/O~ 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# Weld H-40 Surf 78' 30" 330 sx Arcticset Cmt 13-3/8" 72# Butt N-80 Surf 2723' 17¥' 4680 sx Arctic Set II Oat 9-5/8" 47# Butt N-80 Surf 8569' 12¼" 500 sx Class G Cmt & 95 7" 29# L-80 8255' 9670' 400 sx Class G Cmt 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) 9046-9119', 9137-9259' , 9281-9352' , 9365-9387' , 7" 8160' 8145' 9413-9471'~ 9485-9521' ~ 9534-9559' ~ 9570-9580' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8105-8161'~ 8175-8268' ~ 8285-8338' ~ 8348-8364', N/A 8384-8427' ~ 8437-8464', 8474-8492' 8500-8508'TVD 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Gas Injection Well Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BDt CHOKE SIZE GAS-OIL RATIO 3/5/87 24 TEST PERIOD I~ -. 158,178 ...... Flow Tubing Casing Pressure CALCULATED.Ira OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press- 3777 -- 24-HOUR RATE ~ __ i58~178 .... 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED AUG 2 61 o/ Alaska 0il & Ga~ Oons. Commlsslor~ ln~hnrnn~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Sadlerochit Base Sadlerochit 31. LIST OF ATTACHMENTS GEoLoGIc MA .B. KERS MEAS. DEPTH TRUE VERT. DEPTH .9045' 9591' 8104' 8517' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 32. I hereby certify that the-foregoing is (rue and correct to tl~e best of my 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 ~Or' in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a-separate form for each additional interval to be separately produced, showing"the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 STATE OF ALASKA ALA,...,A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate [] Plugging [] Perforate I~ Pull tubing [] Alter Casing [] Other © 2. Name of Operator ARCO Alaska~ Inc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 493'FNL & 1159'FEL, Sec. 11, T11N, R14E, UM At top of productive interval 2472'FSL & 260'FEL, Sec. 2, T11N R14E, UM At effective depth 2570'FNL & 94'FEL, Sec. 2, T11N, R14E, UM At total depth 2447'FNL & 61'FEL, Sec. 2, T11N, R14E, UM 5. Datum elevation (DF or KB) RKB 49' 6. Unit or Property name Prudhoe Bay Unit 7. Well number WGI-3 (34-2-11-14) 8. Approval number 670 9. APl number 50-- 029-20385 10. Pool Sadl erochi t Feet 11. Present well condition summary Total depth: measured true vertical 9672 feet 8576 feet Effective depth: measured 9565 true vertical 8497 Casing Length Size Conductor 50' 20" Surface 2695' 13-3/8" Intermediate 8541' 9-5/8" feet feet Plugs (measured) Junk(measured) Cemented 330 sx Arctic Set 4680 sx Arctic Set II 500 sx Class G Measured depth ~ue Vertical depth 78' 78' 2723' 2723' 8569' 7724' Liner 1415' 7" 400 sx Class G 8255-9670' 7468'-8574' 9046-9119' 9137-9259' 9281-9352' 9365-9387' 9413 9471' Perforation depth: measured 9485-9521', 9534-9559' 9570-9580' 8105-8161' 8175-8268' 8285-8338' 8348-8364' 8384-8427' true vertical 8437-8464' 8474-8492' 8500-8508' Tubing (~[~e, arade and measured depth) 7'' 29#, N-80, ABM, 8rd @ 8134' Packers and SSSV (type and measured depth) 9-5/8" Baker SB-2 Packer @ 8145'/0tis RPB SSSV @ 22.10' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 2/24/87 -- 129,571 .... Subsequent to operation 3/5/87 -- 158,178 .... Tubing Pressure 3759 3777 14. Attachments Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~ 15.1 hereby certify that the foregoing is true'and correct to the best of my knowledgeC;~-/v/:?~'"';~--"'t(:'7- ,/.~ - ~,~ Operations Engineering Manager Date ~//fo~. /'l / Submit in Dupli.cate/_.~ Form 10-404 Rev. 12-1-85 M. R. Olson (265-6810) WGI-3 Daily Report of Well Operations Add Perfs 3/1/87 PT surf equipment w/methanol. OK. Pumpin water w/surfactant, then methanol/water. Shut down pumping. RIH w/CCL/GR, and 12', gun #1, 3-3/8", 4 SPF, 120° phasing. Shoot 9375' - 9387'. Tag bottom @ 9458' POH - all shots fi~ed. Pumped in 50 bbls of methanol/water. PT. OK. RIH w/18', gun #2. Shoot 9433' - 9451' POH - all shots fired. Pumped in 130 bbls methanol/water. PT. OK. RIH w/20', gun #3. Shoot 9301' - 9321'. 3/2/87 POH - all shots fired. Pumped in 75 bbls of methanol/water. PT. OK. RIH w/20', gun #4. Shoot 9199-9219' POH - all shots ~ired. PT to 3000 PSI. OK. RIH w/gun #5. Shoot 9195-9199', 9046-9059'. POH - all shots fired. Pumped in 110 bbls methanol/water. PT to 3500 PSI. OK. RIH w/gun #6. Broke through small bridge - tagged bottom @ 9565'. Shoot 9147-9165' POH - all shots ~ired. PT to 3500 PSI. OK. RIH w/gun #7. Shoot 9079-9099' POH - all shots ~ired. PT 3000 PSI. OK. RIH w/gun #8. Shoot 9534-9549' POH - all shots ~ired. PT 3500 PSI. OK. RIH w/gun #9. Shoot 9495-9511' POH - all shots fired. ARCO Ata~'ka, Inc. P~ 0 ~ Box t Anchorage, ALaska 99.5t0 DATE' March 24, ~987 REFEREr-~CE' ARCO Cased Hole Final -25 2-27.-.87 Cemen~ EvaLu. ation N(I 2-28-8'7 I_og F'FC I ~9 o -)~_.o-~ F:'FC Loq WGI ~t S"-t-87 F'FC Log W6I ~S ~'-~-'8'7 PF:'C Log 5" 5" !5" DT e ~.s' ])res'~ D ~- e.~;.'..~ I)r es'~' HAVE A NICE F;.'. o '4' a n n e F:' e e ' ~ ":-- A T [.l- ~ 529 T R A N. $ :",: ,.,'° 7 t 8 t ~ (':'J P I:.; i- 0 v e d D 12 T R I B U T I 0 N of dai'a. :,~: C e n t: r a !. !::' i k e s' :~: F:' h i I. L i p s :I'~ Chev)-on F'B We !. I. I:: i les' D & M R & D · .-'"Ex 'l'ens i on Exp [ r-,'r a !' i on :,",: ~.~o.l'Li;o.,.~.~ . i i': ate:; -,,. I:':' X X 0 i'! '"' H a r a t' h o n :.": T e x a c o :,",: M o b i k ,"-'*, STATE OF ALASKA ALAS. _, OIL AND GAS CONSERVATION COM,,..,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other [] Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] 2. Name of Operator AR£~ Alaska, 3. Address Post Office Box 100360, Anchoraqe, AK g9510 4. Location of well at surface 5. Datum elevation (DF or KB) RKB 49' 6. Unit or Property name Prudhoe Bay Unit 7. Well number WGI-3 (34-2-11-14) feet 8. Permit number 493' S & 1159' W of NE cr, Sec. 11, T11N, R14E, UM At top of productive interval At effective depth At total depth 2447' S & 61' W of SE cr, Sec, 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 50' Sur~a~ - 2695' Intermedi ate 8541' Liner 1415' 2, T11N, R14E, UM 9672 feet 8576 feet 9627 feet 8543 feet Size 20" 13-3/8" 9-5/8" Plugs (measured) Junk (measured) 79-40 9. APl number 50-- 029-2f)3R.6 10. Pool Sadlerochit None None Cemented Measured depth 330 sx Arctic Set 4680 sx Arctic Set II 500 sx Class G True Vertical depth 78' 78' 2723' 2723' 8569' 7724' 7" 400 SX Class G 8255-9670' 7468'-8574' Perforation depth: measured 9059-9079, 9099-9119, 9137-9147, 9165-9195, 9219-9259, 9281-9301 9321-9351, 9365-9375, 9413-9433, 9451-9471, 9485-9495, 9511-9521, 9549-9559, 9570-9580 true vertical 8115-8131, 8146-8162, 8176-8183, 8196-8219, 8238-8268, 8285-831 8315-8343, 8348-8355, 8384-8399, 8413-8427, 8438-8445, 8457-8465, 8485-8493, 8501-8508 Tubing (size, grade and measured depth) 7", 29#, N-80, ABM, 8rd @ 8134' Packers and SSSV (type and measured depth) 9-5/8" Baker SB-2 Packer Fa R145'/f)ti~ ~PR SS.~V @ 221~)' 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch ~: i, . 13. Estimated date for commencing operation December 20, 1986 _ '.: .. 14. If proposal was verbally approved Name of approver Date approved 15. I hereb, y3certify that/t~e f~ego, j.pg is true and correct to the best of my knowledge Commission Use Only Date Conditions of approval Approved by Notify commission so representative may witness / Approval No. [] Plug integrity [] BOP Test [] location clearanc ~.l~h,,~,~,,,..,~ , q~ommissioner - the commission Date /~.~,,l ..~ O, Form 10-403 Rev 12-1-85 WJP (263-4511 ) Submit in triplicate WGI-3 Proposed Additional Perforations ARCO Alaska, Inc. proposes to add perforations within the Sadlerochit interval in Well WGI-3. The proposed perforation intervals are as follows' Existing Perforations Proposed Perforations 9046-9059 (13') 9059-9079 (20') 9079-9099 (20') 9099-9119 (20') 9137-9147 (10') 9147-9165 (18') 9165-9195 (30') 9195-9219 (24') 9219-9259 (40') 9281-9301 (20') 9301-9321 (20') 9321-9351 (30') 9365-9375 (10') 9375-9387 (12') 9413-9433 (20') 9433-9451 (18') 9451-9471 (20') 9485-9495 (10') 9495-9511 (16') 9511-9521 (10') 9534-9549 (15') 9549-9559 (10') 9570-9580 (10') TOTAL - 220' TOTAL - 156' Reference BHCS of 9/20/79 A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized for this work. All perforations will be made with hollow carrier type guns at 4 shots per foot. The well will be loaded with an appropriate fluid, the perforating performed, and gas injection resumed with the wellbore load fluid being displaced into the formation. No flaring is anticipated. · ! 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF N ] REL ] NE BOP EQU ] PMENI' ARCO 0il and Ga :~mpany Alaska Dis!.,,. Post Offic,,;- ~:~-',:× ,'-.'~'") Anchorage. Aias~;.-.*~ ~-3W'~;'i~; Telephone 907 277 502./ September 9, 1980 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Dr. Anchorage, AK 99501 ENG /I GEOL 2 3 GEO~ STAT TE~ STAT TE~ .... Subject: WGI - 1 (Permit no. 79-31) (Permit no. 79-43) (Permit no 79-49) WGI - 4 (Permit no. 79-50) Dear Si r' Enclosed please find our Sundry Notices of Subsequent Report, for the subject wells, detailing the individual well perfor- ating procedures. Very truly yours, P. A. VanDusen District Drilling Engineer PAV/sp Enclosures ..... ?""~ .0;.,, '" 0 ~c. '6// Form ,10-403 REV. 1-10-73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) WEL~GAS 0 OTHER Gas Injection 2, NAME OF OPERATOR Atlantic Richfield Company ~ ADDRrr~S OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At su trace 439' FNL, 1159' FEL, Sec ll, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 49' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20385 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. WGI - 3 10. FIELD AND POOL, OR WILDCAT >rudhoe Bay Field - Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 2, TllN, RI4E, UM 12. PERMIT NO. 79 - 49 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Perforate for injection (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all I~ertlnent details, and give pertinent dates, Including estimated date of starting any proposed work. Began per.f operations 8/14/80. Bled tbg and annulus pressure to 0. Set tree and test equipment and pressure test to 5000 psi, ok. Suspend opns while ~0 safety ball valve parts. Install wireline BOP's and lubricator and test same. Pulled dummy valve. Perf'd following intervals per GR/BHCS log 9/20/79 w/4 spf' 9570 L 9580, 9549 ~ 9559, 9512 J 9522, 9486 ~ 9496, 9452 ~ 9472, 9414 J' 9434, 9366 L 9376, 9322~-9352, 9282 ~ 9302, 9220 c~9260, 9166 -'~9196, 9138'~ 9148, 9100 -'"9120, 9060 )~ 9080. Run surface readout pressure recorders, flow well, SI well and pull recorders. Ran and set ball valve. Close valve & test, ok. Open valve, flow well for cleanup. SI well. Closed safety ball valve,~ Installed tree cap and tested same. Released well to CCP 1500 hrs, 8/20/80. *Tested safety valve, ok. TiTLE ., Di stri ct Drillinq Enq. (This space for State office use) I APPROVED BY CONDITIONS OF APPROVAL, IF ANY; TITLE DATE See Instructions On Reverse Side ARCO Oil and Gas Company Alaska Dis~--,~ · Post Office .)x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 1, 1980 Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re' WGI I- Permit No. 79-31 WGI 2 -" " 79-43 ~ WGI 3 - " " 79-49 WGI 4 - " " 79- 50 Dear Sir' Enclosed please find Sundry Notices detailing work and start dates plaqned for the above mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAV' ruo ARCO Oil and Gas Compa~y is a Div~si~-.f~ ~.' ;!:,~,1,~ ;~cb':, ',~.. ),.h.;' .. Form 10-403 REV. 1-10-73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals,) 5, APl NUMERICAL CODE 50-029-20385 6. LEASE DESIGNATION AND SERIAL NO, ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. OIL I'--! GAS r-] GAS INJECTION WELLI.--..J WELL OTHER Alaska 99510 11, T11N, R14E, UM 2. NAME OF OPERATOR Atlantic Richfield Company [ ADDR~S OF OPERATOR P. O. Box 360, Anchorage, 4. LOCATION OF WELL At surface 439'S & 1159'W of NE cr Sec. 13. ELEVATIONS (Show whether DF, RT, GR, etc~) 49' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. WGI - 3 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Fi eld-Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 2, TllN, R14E, UM 12. PERMIT NO, 79-49 sort, or Other Data NOTICE OF INTENTION TO.' FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Perforate for Injection SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR AClDIZING ABANDONMENT* (Other) (NOTE,' Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent ¢letell$, anti give pertinent dates, inclucting estimated date of starting any proposed work. ARCo 0il and Gas Company proposes to perforate selected intervals within the Sadlerochit for injection of produced gas. The perforated intervals will be reported on a subsequent report.' A 5000 psi. WP BOP/lubricator, tested to working pressure, will be used on all wireline work. The downhole safety vlave will be installed and tested upon conclusion of the job. The well will be flared to burn pit for clean up only after perforating. Estimated Start 8/10/80 Subsequent Work Itcportccl ' on Form No. 1_o-4O~'Datcd District Drilling Engineer T IT LE DATE 8/1/80 (This space for State office use) CONDITIONS OF APPROV.. Y.. COMMISSIONER TITLE DATE ~"'~--'~'- '~ '/ ~ ~""~'-~) ~,:-- ~ ,-,. ~, ~-. ~.Q~p~ved Copy Imtructions On Revere Side ~- Form 10-403 REV. 1-10-,73 Submit "intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) ~' o~L I---! GAS r-I GAS INJECTION WELL[~.J WELL I.~J OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, 4. LOCATION OF WELL At surface Alaska 99510 439'S & 1159'W of NE cr Sec. 11, T11N, R14E, UM 13- ELEVATIONS (Show whether DF, RT, GR, etc.) 49' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re I COAA '---] t~ES ENG .i 5, APl NUMERICAL CODE 50-029-20385 I 1 ENG ADL 28302 o. y3 EOq Prudh0e Ba,y Unit ' J STATTEC 9. WELL NO. , . WGI - 3 CONFER: ]0. ~ELO ~.D ~OL, OR W~ '~T Prudh0e BaS Fiel d-PrU'dhbe ~i ] P0 11. SEC., T., R,, M,, (BOTTOM HOLE OBJECTIVE) Sec. 2, T11N, R14E, UM 12. PERMIT NO. 79-49 3ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [~ PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Perforate for Injection SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE.' Report results of multiple completion on Well Cornl~letlon or Recompletion Report and Log form,) 15, DESCRIBE PROPOSED OR COMPLETED OPERATIONS (.Clearly state all Dertlnent details, and give pertinent dates, Including estimated date of starting any proposed work. ARCo Oil and Gas Company proposes to perforate selected intervals within the Sadlerochit for injection of produced gas. The perforated intervals will be reported on a subsequent report. A 5000 psi. WP BOP/lubricator, tested to working pressure, will be used on all wireline work. The downhole safety vlave will be installed and tested upon conclusion of the job. The well will be flared to burn pit for clean up only after perforating. Estimated Start 8/10/80 District Drilling Engineer TITLE DATE 8/1/8o (This space for State office use) BY ORDER O? T~-;~_ C:'~'~'~',~e~^~, roved cop), See Instructions On Reverse Sid~ 'ARCO Oil and Gar~ompany - . .. January 18, 1980 . · Re£erence- · .Enclosed are Magnet±c Tapes for the following ARCO -wells' ~ 9/20/79 - . . 6/lZ/79 D.S. 5-12 Z0/29/79 p.s ~z-4 10/8/79 Tape #57007 Tape #57002 Tape #60012 Tape #60030 Please sign and return the attached copy as receipt of data. K. J. Sahlstrom North Engineering --'1 co~ ! i-~ES ENG__ J --- .... j ~ C-~9L~L~ I 3 e~o~ I STAT Tm '._J ,STAT TEl3 I cONFER: FILF: · , , ,, TRANSMITTAL #023 DISTRIBLrFION North Geology P,&.~ Drilling Eng. Manager DaM Geology State of Alaska F~xxon ,Mobil Getty Phillips Sohio Marathon C1'~eta'on Noveinber 7, 1979 Reference: Enclosed are Open HOle Logs for the following ARCO wells, D.S.. 3.11 10/6/79 FDC--CNL Run 1 5" ,~, ,-t FDC/GG Run 1 5" " "' 'BHCS Run 1 2"& S" ,.: ,t DIL Run 1 2" & 5" ;: 10/7/79 CPL Run 1 5" D~C~ ~~ 10/6/79 RFT Run 1 5" - 9/20/79 CPL Run 1 5" Please sign and return the attached copy as' receipt of data. · K. J. Sahlstrom North Engineering TPANSiXETI'AL # 458 DISTRIB[fi'!ON North Geology Dri]_ling Eng. Manager R & D Geology State of Alaska ]~XXOI1 Mobil Getty SoM. o Marathon Phillips Chevron October 26, 1979 '; :' ';:':'*~"'Y/i ': ~': '":r/ .... · t.': .(..,. . · . ~'-.~..:\T -i'~ C .......... CONFER: FIr_F: 'Reference- Lnc!osed are Magnetic Tapes for the following ARCO wells ' D.S. 5-I0 11/12/79 ? Tape ~'~ 681 Ih-esser Atlas _?.S., 12~3 10/6/79 Tape # 672 " " /,' :,.,I r o ~ 10/6/79 Tape' ~ 673 " " Please and retu~ the attached receipt si~ ~ of data. ~ cop}.- tis North Engineering TP~KYS>,IITI'AL ¢i 43 9 - .. , ,~ '¢'.1 ;-:,.'.';: i J~i'..:i I 1 it,.:; October 23, 1979 Reference' Enclosed.are Open Hole Logs for.the following ARCO wells' 9/20/79 O~L P~m 1 2 & 5" (s~me log) ~ease sign and return the attached copy as receipt of data. K. J. SM~!strom North Engineering TR?uNSqlTFAL t? 428 i~] :~o~ ~t ,,eolog5- lh'5 -1.1. 5 ng Goo ] o51)' State of Alaska North PosJ 01rice ~ 330 Anchorage, A~aska 99510 Telephone 907 277 5337 OCtober 16, 1979 Reference' -En~!os~a are Open Hole Logs-for the fOllowing ARCO wells' ~' 9/20/79 CNL/FDC " FDC/GG ,, t., BHCS 2 " " DIL 2't & 5" D.S. 12--.3 9/9/79 CPL $"~ ~ease sign and return the attached copy as 'receipt of data.. K. J. Sahlstrom North Engineering Ti~.~SMITTAL # 407 DISTRIB!~'IOX North Geology ])tilling Eng. Manager R & D Geology State of Alaska ~YXOII ~!ob 5.1 -Getty Sohio },larathon Phillips Chevron ARCO Oil and Gas Company P:-:,I Offic,? ~'.< Y-_lr_,phone OO7 277 October 17, 1979 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 3-9, Permit No. 79-22 ermit No. 79-41 rmit No. 79-49 Dear Sir: DS 3-10, Permit No. 79-21 WGI #2, Permit No. 79-43 Enclosed please find a Completion Report for the above-mentioned wells. Very truly, yours, P. A. VanDusen District Drilling Engineer PAV:jh Attachments Oil and Gas Company is a P.:¥ision of Allanlic-Richfie'dCompar, y Form P--7 SUBMIT IN DUP~.,,,i'TE* STATE OF ALASKA (see other In- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* Other Gas Tn_it_etlon la. TYPE OF WELL: OIL GAS m~l WELL [~] WELL[__I DRY[~ b. TYPE OF COMPLETION: NEW WORK [~] DEEP- PLUG [---I DIFF. WELL['~ OVER I I EN D BACKI I RESER.F---] Other 2, NAME OF OPERATOR ARCO Oil and Gas Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, AK 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 493'S & l159'W of NE cr Sec ll, TllN, R14E, UM At top prod. interval reported below 2471'N & 260'W of NE cr Sec 2, TllN, R14E, UM At total depth 2447'S & 61'W of~E cr Sec 2, TllN, R14E, UM 13. DATE SPUDDED 114. DATET.D. REACHED 115. DATE COMP, SUSP, ORABAND. 9/5/79 I 9/20/79 I 9/26/79 18. TOTAL DEPTH, MD&TVD 119. PLUG BACK MD&TVDI20. IF MULTIPLECOMPL., 9672'MD 8576'TVDI 9~UMD 8543'TVDI 22. PRODUCING INTERVAL(S), OF THIS COMPLETION ~- TOP, BOTTOM, NAME (MD & TVD)* Top Sadlerochit 9044'HD 8103'TVD Base Sadlerochit 9595'MD 8519'TVD 5. APl NUMERICAL CODE 50-029-20385 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. WGI #3 (34-2-11-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe 11 . SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 2, TllN, R14E, UM 12. PERMIT NO. 79-49 21 . ROTARY TOOLS INTERVALS DR ILLED BY CABLE TOOLS All 23. WAS DIRECTIONAL SURVEY MADE Yes ~4. TYPE ELECTRIC AND OTHER LOGS RUN DIL/SP/BHCS/GR, FDC/CNL/CAL/CCL/GR 25. CASING RECORD (Report all strings set in well) Oil Pool CASING SIZE 20" 13-3/8" 9-5/8" 26. WEIGHT, LB/FT. /GRADEI 94# We lde~ H-40I 72# Butt / N-801 47# Butt I 80&95 I I I LINER RECORD DEPTH SET (MD) 78' ._2723' 8569' SIZE I TOP (MD) BOTTOM (MD) 7" I 8255' 9670' I 2~. PERFORATIONS OPEN TO PRODUCTION (interval, size and number) N/A SACKS CEMENT* 400 sx (i, l ass c, cmt_ HOLE SIZE I 30" 17-1/2" 4680'sx Arcticset II cmL 12-1/4" I 500 sx Cla,=;~ G CEMENTING RECORD AMOUNT PULLED 330 sx ^rcticset cmt 27. TUBING RECORD SCREEN (MD) DEPTH SET (MD) PACKER SET (MD) R1 6f')' R_ 14.E' 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) N/A IAM~UNq' ANI~KIND OF MATERIAL USED 30. DATE FIRST PRODUCTION N/^ PRODUCTION IPRODUCTION METHOD (Flowing, gas lift, pumping~size and type of DATE OF TEST. HOURS TESTED CHOKE SIZE PROD'N FOR I TEST PERIOD FLOW TUBING CASING PRESSURE CALCULATED OIL--BBL. PRESS. 24-HOUR RATE ~ I 31. DISPOSITION OF GAS (Sold, used for fuel vented, etc.) OI L--BB L. GAS--MCF. 1 GAS--MCF. IWELL STATUS (Producing or 'shUt'In) WATER--BBL. I GAS-OIL RATIO iWATER-BBL, lOlL GRAVITY-APl (CORR.) I TEST WITNESSED BY 32. LIST OF ATTACHMENTS Drilling History and Gyroscopic Survey 33. I hereby certify that the_foregoing a~d attached information is coynplete and correct as determined from all available records. ~y~, ~F~ District Drilling Engineer SIGNED TITLE *(See instructions and Spaces for Additional Data on Reverse Side) DATE 10/15/79 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: 16: 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. Items 20, and 22: If this well is completed for separate production' from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26: "Sacks Cement": Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, WATER AND MUD 35. GEOLOGIC MARKERS NAME MEAS. DEPTFt TRUE VERTi DE'I~TI None Top Sadlerochit 9044' 8103' Base Sadlerochil 9595' 8519' 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. None Drilling Hi story WGI #3 (34-1-11-14) API 50-029-20385, ADL 28302, Permit No. 79-49 Spudded well @ 1130 hrs 9/5/79. Drld 17-1/2" hole to 2736'. Ran & cmtd 13-3/8" 72# N-80 csg @ 2723' w/4680 sx Arcticset II cmt. Did 96 sx top job. Installed & tstd pkoff @ 2000 psi. NU & tstd BOP. Drld thru cmt & shoe + 10' new hole. Tstd form to 12.5 ppg MW equiv. Drld 12-1/4" hole to 8590'. Ran 9-5/8" 47# N- 80 & S00-95 csg w/-FS @ 8569'. Cmtd w/500 sx Class G cmt. Installed & tstd pkoff to 5000 psi. Tstd BOP to 5000 psi. Dwnsqzd 300 sx Arcticset I cmt thru lower FO. Pumped 230 bbls Arcticpk thru upper FO followed by 75 sx Arcticset cmt. Drld cmt, FS & 10' new hole to 8600' Tstd form to .65 psi per ft grad. Drld. 8-1/2" hole to 9672' Ran DIL/SP/BHC~/GR logs f/9666'-8569', FDC/CNL/CAL/CCL/GR f/9666'-8569', & ran CNL/~CL/GR f/8569'-2700'. Ran 7" lnr, top @ 8255', shoe @ 9670' & cmtd w/400 sx Class G cmt. Tstd l nr lap to 3000 psi. Performed WSO tst. Reversed out mud ,w/H20, displ H20 w/CaC12 Ran gyro from 9600'-sur. Ran 7" tbg, tail' set @ 8160 . ND BOP. Installed &'tstd tree @ 5000 psi. Displ tbg w/320 bbls diesel. Ran CNL/GR & CCL. Installed & tstd tree cap to 5000 psi. Press tbg to 3500 psi for long term tbg tst. Released rig @ 0900 hrs 9/26/79. A PETROLANE C, OMPA~ REPORT of SUB-SURFACE DiREC TiOi~A L SURVEY ,~ ~ ~. ~ ; AlCska Oi! ~, {~ ATLANTIC RICHFIELD COMPANY COMPANY W.G I. #3. WELL NAME PRUDHOE BAY, ALASKA LOCATION JOB NUMBER A979 D0002 TYPE OF SURVEY Directional Single Shot DATE 9-4-79 SURVEY BY Steve Ratcliff, George Wainscoat OFFICE ALASKA R E C; iD R D C) F' !i~ L.I F;: U EF. Y RF:'~.T.'I]iL.IE~ OF' CURUATL.!RE NE"Fi'.{C3iTI ' (2'.0 OIL AN:8 GAS , U B r'~ ...I,::. :(':", A Y ~ N 0 R ]" I"1 S L. 0 F:'I:: ~ : A S LJ R Ii!: B D R 'I; F' 1" l:l R 't; F:' 7' l l:!:. F:' T H rq N G L Iii: B .1: l~" ,::.~ ...... i..,' .... t ]: 0 N F:' E: E 'Y' .::I H :0 C 0 U R 8 E: t... Ii!: N G "[' [--t F:' E Ii:.' T T' R U E V [': R 'l" t E: A I... V Iii: R 'T' I C A I... I:;~ Ii!: :0 Ii." F:' T H S E: C:'i" I 0 N C': 0 I::' E: E "ir' F:' [:' E: T C 0 Mi::' U 'Y' A T :f: 0 N ' ' :[ N ii.'". 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E ................ = .'3. · 92 ..... 12.62 S 5.15 E -1C.37 12.91 S 5.42 F -10.56 ..................... ,,.....=-..-~- ........ -'_ 1..~ ,..2A ....... 1.2.27 S 6.65 E 11.84,.,e 7.x~., l! -8.93 Zl._&5_....£ ................ 7/.,.£.!i _.fi ................ 12.32 S 7.P/'_'. r -q.2:$ 13.11 S 9.50 E 2.._E L_ ...... l 1 ,_.,.u_ ............. -12..-z:,. _E ................... .-.Z.,.~ 'z.~ ~.33 S 14.96 E .2 .... -Z2L- ...... ~$9,q5 E 5 qq, N 1~.39 E !,.'ELl. ~(:',I-~ C'OP'PUT~TION DATE' FPUFI.,CF' !:':ny .cCE~:lal~E;EF, 25, 1979 . ,, .: ,, , ..... i~.Gr~.,_L_E.G .T..R-(IE: ...................... -~,..~ .... ~.E.A .................. C-.T;-O.R-:~-:¢: .............. -C--C,%LR~.E ' ' . . . · _, ,,. bO,e,S (];YEOSCOF'!C SURVE'Y JOE'; NUPi~iFR~... ,,aOS<,'-16qql,., ,. ' ..' ~'i '~ ' ~'" -~ -- ~ ' ~L.L.b~..~.,~U.-.~.+.I.~ ........ L.E~.+-..~ ........... ~... ~.~ ........ ET.. ............. ~ '. ' ~ . '....,: :.. ~ ~' . ..' . .. , . ,~ F/I S UF<I7 b VERTICt. L VERTICAL INCLINATION F:I RFCTI C;N SEVERITY R [. C I'At~iGULAR COGRDINATE. S [; E' P T t-i DEF' Th DEPTH DEG ¢.', 1 K: LEGREES F;EG/] (JO NOEI'H/SOUTH EAST/WEST ................ ~ .............................. ""'; ...... ~ ...... --~'~ i? .. ...'L'-: . ~ ....... . .... , ...... .,,.. o '::7' · ~., , ~00 ~O~a,Ta. ~ ~aa,..?a 5t~" N....'1,' 5C !,7C~ . ..... 31.5.0 ........... ~1.-~:~.~ IPbC 3197.27 3167.27 11 15 k 13.10 E 3.53 23.79 N 17.13 E ~:250 .5246.27 3216,27 11 37 N 17, O F 1,72 33,36 ~'. 19,70 E VERTICAL S£CT 1Li~,~ :5, '11.15 L& .,Z 5 .......... 27,96 37,86 3"¢'0....., ' .3344,06 .331~.~06 12 '.~ 2~,~:..' ~9'E~."~:':.:' : !.~9:.i' . 53,15. 58,76 ~'~(.;O 3392.7.3 . 3~62,7,.;. 13 flF; N 2'32 63,8.5 'N]~? ,35G..O ................... ~,4;.~ ~ ! ~.~1-7 ........ i-a .i;,i ~ .- 7 o_F i.._3.~ a~,.~;'O A.~L~6--~ 9.~..,.5 ~ ............ ..~(-60 .!Sa':,ll., 3~5,11.... 16 .n ......N 1.2,E9 F 2,88 ll:.,lO N NO,12 F_. 124,70 3700 3681,1A 3651,14 16 30 k 1,35 E Z',25 1~2,75 N 52,55 E 152,02 ...... 3~.66 ................ ~-77i,$~ 4~A~li~I ~ 59 ~ ~2a J ~,~a A~A~Qa a ~5 " . .......... 79fi0 38a,,...gq ' 3.:.,,:,,8'96 : ,.,3 ~.,~. 3.60 .....ell..lq...:,4 · .. al,DB ~ 216.67 AP.~) 3960,15 3930'15 P6 67 N 2' 5~ E' ' ' 1,9~ 252,I0'.N ' :'51,77 ~' 255,63 . , . . , , 416 O ............ 4-0 ~..~.:~ ~--~0-29 ~ ' ~ ~- ~'..~.*~*.~.~ ~..-~..-[ 2. 93 '" ~ ~ ' '' ........... ,~ ~, ,.,1 ............ 4;-{:6 4145,66 4115,06 1:3 16 ~ 16,39 E 3,96 327,15 N 63,1H E 330,q7 ) AZOS 42~5,65 fl205,65 ,;F. 6g F 11,19 E ~,16 36~,25 N 73,15 E fl~u~ ............. ~i.d.2l.,./~ A2~A~ ....... Z.~ ......... ~..~_ r~ 11~,~0 E = ~4 ql~",~ N P2 70 F' q20,11 4~.~0 44-07.90 ~377.90 ~4 24 1~ 9,6~ E 4.~3 ~67,71 ~ 92.5~ E 473,16 ~edd 44a~.9~ 4459.50 ~5 25 N ~i.50 E 1.20 52~,22 N 101,57 E 52~,64 z'70.~ :':~ =~ ~5~~ =~ ..... ~ N ~ z9 11u,69 E 5~6~7.~ ....... .............. ~- z-". ~-.m ....... ' ....... L,:~ E · 06 5 ~ 1 · 56 N ' .............. 4"~6 ~'l~' 92 470~ -' ........ ,22 '~4 zt6 N ?,50 E ,31 69A,86 N 127,9g. E 699,96 ,:r.~:_~ ..... ~_~.1..7...,.~.~ 47~.7.2a =4 ~:~ ~ a.6o E .48 751.2~ N 1~-/,02 ~ 756.3~ . Ng., ........ · ,...~ ~ ~ ~. .. . ....... ~ ............... tlCO 4899,30 A~Bg, ZO ~4 52 k 9,19 E ,29 ~.~7,~1 N 145,92 E ~12,8~ ~,::OiJ 4o81.35 4551.35 ~4 51 N 9. 0 E ,11 a6~.25 t,; 154.96 E 869,27 - - , ...~ .... ~ 1, 18 ~21,1O N 16t q~ 926,51 .............................. F~'O5 t. lq'3,Ye 511~,70 'Z6 9 N C,,~:9 E ,22 579,3~ N 174,fl9 E 984,73 ~::00. 522=.~,6=., ~193.. ,65 ~'1 39 N 17,3S _F -:',~8 1L'38,30 N 186,07 E JU ......... ~..P.,~.~.~..~ ..... ~ ..,1~ ~ ~'5 ~ 1=, O E 1,30 1098,7~ ~J i99,6fl E 11D5,95 ~;76d 5~79,7~ 53qg,7P '!9 16 N 13,30 E ,~2 116[;,12 N. 215,99 E 116~;~"~'~ ............. . .... ,..L RVE¥ lNG CoMP ~tY F' A GE. SPFRRY-~UH ~.!EiLL (~ I . " ANC~ORAGE~ ALASKA . . · · ' ' .~, .- c~ ~ ,, F' -~:, F~'E.~._2_~.L.i.?.Z.D ............ A 1 L ~, ;~.. 1 I C ~.I...LME._I~i,L.D ..... ~IE ~. F. - C.c~COPIC Si,I~VEY t~KLL w('.~I T~, C.O~",PUTATIDk DATE bOSS GYR '~ ......... F ~' ~ [L~ ~ ......... E.,..~_.L.I_., ..................... .. AL~.Sr',.~ ~.~,L~..~.~ '". .... :' " . - ~ '~ ~' '~ '.' t ~ F~ t)~. E' [, v L. R 1 I C ~ L PF P 1 P. i]EF 1ii VEPTICAL INCL I%ATI,.,N D E G P. ] N ~9 46 ~:6 21 , ,DO,..F;,i'LE6 , TO!AL, . [.1RECTION SEVERITY keg IALiGULAP COORDI. NATES VLRTICAL DEGDEE'S IDEO/1. OO t~ORlh/SOUTH EAST/[4EST SECTION L~._ 13.t~,.~..E .D~ ,1.~,,.:,::. D':'N" ,.'.. "2,'2~8~ E 1232 15 14,.6'9 E .85 I.'2~,'(~o3 2~4.63 E. 1,296.33 ~, ~_6._6 Q .__6L ........... 16.89 E 1.78 140f,.65 N 279.78 if 1,~23.q7 17.29 E 1.75 lq6~.h6 N 297.56 E lq83.94 FlO0 56P, 7 o74 5E57.74 F206 5767.36 g A 0 O . ,.9 1738 ~::700 6176 37 6146.37 35 12 ~ 1'1.~0 E .r~, · ~f~O[) 625A.26 6228.26 ~4 51 N 18.20 E ........... ~:,~.~,~ ........... ~.i~,~,.~ ~ ..... ~ ~.!_,[t. ~. ~ ~.~. z. ......~, .! 7 ~[. ~.~~_i~_6 ~ .8..~ 7('~00 6q22.98 6.392.9~ '~ 20 ,N 1~., 0 E .. ,1:9 !900 6A , 7100 6505.80 6475,80 33 fib N 17.60 E' .58 i95Z.99 ., .......... ZZ.O...Q ........ ~.1~ ,,, 655~.1G 3,:5 27h DJ 18. 0 E 7~00 6757,1q 6727.14 Z2 16 k la.~9 E .......... 75,QQ ............. :,kA~,E; ,.. 62'.12.,~2 ~1 ....3.~ ........ ~, 1~_~10 E ..... 7600 6':]27.23 6.397,2'.~ ~1 32 ~'; 20.29 E' .63 22b~'.79 7700 7C. 11.98 6,9E. 1.9~ ~2 F, 4 N 20.89 E 1.09 225~'.~7 ......... ,7~_~ 70~ .... 6 _. q5 ~t, ~.1 ,2~ 7900 717s.27 71q~,27 '~4 5,2 ~x 2~:.lG E 1.25 2~1.88 PGO0 7~6C.1C~ 7230.10 ~',,,,,17 k 22. ~ F_ .~2 2~1=...15 506,8~ 5 2~., 1 ! __E P..21.~Ji..~ ..... .541,75 E. 2267,29 568,q2 E 2320.33 603.97 E 2~31.2~ 622 ~3 · _. ~'.71 ~. 0 ....... ._Z3,_4_..L~5_,'. 7" 1 1,5" ' "' ..~._~,' R 2 '", 1 0 E O0 7422,99 7392.9F ~5 lq N 23.29 E .45 O0 7594.64 7474,E. 4 ~5 16 N 24.2G E .52 03 '1667.63 7637.63 ~5 5;, k 26.10 3U 774H.(:4 /71~,64 7~ 57 r,; 27,39 09 7909.97 7879.97 Z6 4~, N 29,79 E .74 ;.:4et-,. 75 r,, 644.~0 E 2546,46 2522,0 7 2574.91 2627.42 &67.66 E 26 (!zI ·p~- 69g,90 E 2661.71 714.95 F 2719.1'2 267 r..,. I48 2.732,24 2784 · 09 740.03 E 2776.P, 0 766.42 T 2834.7~. 7c!~, · 23 F 2H92.74 · 72 2 z¢, 823 ~g £ 2~ ~ . Rr, F'Ri;~Y-F..UI~ i~,iE'LL ,SUR. VEYI:t'~G C{~:4P;,t',y CO I'iFl.J T A T ]I' O r'~ D~TF ,CEPTE ME~E[;; 25, 1:9,79 PAGE GYROSCOPIC SURVEY NLJ l'ILi E R [5C$g-1 Gq'51 KIEbLY ~LJ,?,,H~PJG I:.LE.V. = 3[!.[~Ci FT FF /~ FI.:F:F. 2, V~.Rl ]C/~L VER'TICAL II~ CL ]' kA T1 C,K~ DIRFCTION SE'VERITY R ~. C1 ANGUL/~R COORDINATES VERTICAL D E ~:' T i-'. DEF Tt'i DEPTH DEG Mir; [DEGREES. DEGtlOO NOV, TH/SOUTH EAST/WEST SECTION ~6OO ~06~*.72 'RO'Z~,72 ]8 .33 "~ 31.20:'E'.' ".:': :'. 1.,49 ' 2~.91' N ."." '88~'56 E' 3C. 69.:97 .. 710. C .......... )!i..A_E,..Ai__~.,~Lz~..1- __ ],9'_ I'F~;__k ~0'¢~9_E_""_, .76 299~.7~ E' . 916.97 E' 31.3!.._t.2~ ...... c),.~.'0,5 ~22~._,.42 8193.~~., 40 H N =~, . 0 E 1.02 3~4c~.83.. N 94o,,.35 E 3193.71 .... , · ,:, ., 41 24 .2G E 1.3~ 5186.60 N 981.~0 E 3257.73 ............. ~,E,~ ..................... LZ.,.2.~....~..~_,~.~.~.....I .... ~1.. .~ ~ 2, ~q ' '¢' ~ · A ~ . 3 E :~Zpo .A cGoO a522,70 84'9'2,70. 42 !1 'k 27'.50..' E. '.. ,22 ". 3283,2'6.'N · i075'44' E ~,4.54.95 ' TH E t~Oi~I,,?i;F;T~,L FISPL. ACE¢~ED~T : (:ALCULATlO~'~ PRoCEEUPES A,~E ~A.'ZE:D' , FEET AT~,:"ORTH, 18 DE'fi,. 15 NIF:. EAST AT MD : 9672 WF'L.L WGI-~5 ~t.A ........... Eli I ~.L--.__,.~. ......................... ' ' , , 7,.i:,C, F..42P.gH 6392.98 1900.64 N q,3~.q,? E 577.02 187.01 ~fO5 726n.10 72~0~ .10 ..C~ql~, .1~.,, ~,~ 622.5~.., E 7~9.5~~ 16P.8~.~_ ........ S u..d ~ ............. ~E.~2.,2 ~'~ n ~~ ...... 29 ~ ~+. ..- . . ~ ............... Cf.,72 8576,05 85~6.05 zx26,1.5 '~ .1. n97'77 E IC~95.9r~ 164.67 ' · ~"' ~, , , ' ~"' . , .....~ . . . ~ . '.:,, . ' ..... T?.r ...CALEJJ. L~._T_iJL!,: PR&CEBLRES A~RF THE USE OF' T' HJ~_ EE D I.~.!E N SI.~LEA.L_..EAD I'Us_.-D..E_.EUR.V_&.I_URE. t~L]~Q.D.._ ........................ , 1 kUE SIJR- S E A 36 3!'!, .GO 130 130.,00 100.00 TcTAL O. 00 .5. b [:: O .0 0 · 25 ~ oC(, 1"536 1530.00 15OO.t.O lC30 1630.00 ' 16CO°DO ............... ]. . 7. _,~ ..0.. ......... LZ..~.O , 0 0 . 1700 · 0 0 1 1930 1230.00 1230.00 1 ~ 5 i..* iZ30.O0 1300.00 ll.q5 11.36 5.76 E .05 "' [!'~ E .uc, 5*lq E q,64 E .OS .. .oo ) · 0 (! .00 WILL N(;I-3, AL A.S~,.A SPEI'~.N.Y-SL.iN !~ELL SURVEYtN6 COFPANY PAGET 7 ANCHORA&E, ALA,~,,~A COMFUTATIOH DATE S E P T [ ~ ;,: E R 25 , ! 97 n d 0 [::: N U M E [ R [~ 0 S S - l 6451. ... :::. , , . 7 R l; [- S IJ [:: - ,S E A C' ...... DEF:'TF DE'PI'P" . .' ........... __ 1 ~ ~ ................ 19~ L' 1 53 [,}. ~0 1 50{i. 0 0 2 l'.3 u 203 3 · O~ 2 03[' · 3 g 2233 223C',, . ,00 ~3.30 2339,00 2300.00 TOTAL 2':-" 56 2C~3 0,,00 2900,0'3 ....... 3 Q~ k ...........3iZ,. O....Ln 0 3 Ci~ 8 · 0.. O. ..... 31.31 31 ,-f.. U. r}o 3100. "'- 33 ~23 t~. nO z2 .,'lC. ,.) 0 ................. Z_3.15 ......... ~.3.A_Q · e O .. 3 3 o 0. o ~ ..... ~- ~ 3,q 3430,00 34C. 0. f,O 3%42 '353ri. CO 3500.00 11.73 11 · 1..2 13.42 lO.Sq 11 .~ 30.i6 ?2°?3 .1.2"/_-.L3 f,,.. . 11.56 S 4.34 E 12.23 S 4.90 E 2., 9 ~ ',. 2. F.,:i. ," · 12.1_1_ ~ ......... _6 9! E S 7.56 .,cT. ¢., ,,, 7.64 E c ,c,;. n '~ E '" ,,' T'-'~ - -i"': '~: , :;: ,10,,~e E S 3, 13 E s 15..-'+ ,=-. E, N ].5.~1 F ;"; 18,. 75 E ~'.' 2 ~...3~,.. F N 3~,, O6'.E I"; ~, '/5 E , ~ '1.~ 3 ~. E .11 .11 ..:. ,2.5 ,65 1.Sb 12 · ~1 16.72 .94 1.80 2,20 2,89 ~,13 - ,7 bAY ~, , ,,, APCh.DRAGE~ .AL~,,:hA · [.i ATE ' ~' !'i'"...[ ........ [.Ji"~__.~'.~_'~_.''. ..................... ~_...~'! .... OF. ~:~.p,.~..Y o,:.fT ~,L, ER 24, 1::~? ............ COKPUIATIJN iSATL SEPTEFi!,ER 25 ~ 1579 dOE.' NUIV.,SER BriS$,-16451 ................ E[J,L,Y.._J~L![ti.I F, G b [ $ V, = 3 3 · C 0 F'T. .. . . ", . T F,. L' E ~ LI ~-~ - S..' E. A T 0 T A L \ t,, D~:P'TH;: PT'H]~ 'N~RTH.tSCUT EASTIWEST ':':DIFF '~ ................................. ~.~".57 3~3fi.00 3~OO.OO 194.77 N 52.~0 E 27.7~i 6.54 7966 3930.00 3900.00 23~.1~'~ N 51.26 E 3&.79 9.03 Zt , ' z ~ ~ , ~' q nq ~q ~ nr~ f,. ~ ~ q l : ~ c 4526 ~30.00 ~qO0.OO 482.63 L 95. lC E g6.7~ 1.9.17 ~ ~'. 93 ~ 7 ~ O, O O : ~ 70'0,0 ~ a 9 I. 28 L .127 ' 3~ E I ~.,3,6 . 21 ,'~'~7 ............. :"'"-="7 ...... : .............. ~ ........................... ~015 483g.0C ~8'0'~'00 760'.07 ' ':. ~35t.36 E '1&5,5] ... 21.87 :"' .................. %! 3.2 ......... ~..,~.~.&.o..,.~o_Q 49 ~ ~., e o a 2.a, 9 2 r~ 5~.35 533G.00 53~0'03 1120.62 N ", 7E, q 5~30,00 5~gO'.OO 1200.23 ~.~ 16G. 37 £ 172.7'1 E 2 0 ~, 70 :E · 223,54 'E . 24 3. RP, E 2g. 7.42 229.q2 2~3.L3 27~.02 21 .~__i ................................................................ 22,0[' 23.61 .) 24.99 27.76 .: 29.2 0 · 30.47' ~ 34 5~! 3&5.45 <" R "~': L L ,,:; J ~. V £ Y l N G C G N !:': A ['.,i Y P A G E ,:,,. F' [: R y -. ,':..] I.,! N ~ ,.. ""t . . ANChOPAOE, /~L. ASKA WI I,,L I,.'61-_,, '~ COI'~I:,"UTAT'ION ,LOATF , . · , : . · . . . _~ .... ", '~ '"', '"'" I ~:' ~.' . · r .:'[~~.:[.,:..L.~.~.L.L.,_.~. F ,:~ r:__:_~.~ ~ 00 O.F -S ~:~ :'~"L P'T U._:~:: :.: __ ............ N 39 ~, 1 .r.., ,:,, ,'7'73 .~. O0 5,709 · b J 1~ 3.P,. Dc.) (2 7'1 583 & .OO 5~0[~ .O G 1507.42 ~,~,,2 o o ~:~ 87 6339.00 E,,3qO.O O 1~,39.$7 7C 08 ~7;~ 3 O. O0 G~ OO. 00 1905.2 [J , ..' , : . . -, 7248 6630,00 660'0. O0 2032,26 N . 7367 6730'00 6700, ~3 O 2~'93.3o N 7[:,b3 6936.(~0 6S~O.dG 2210.7, F. ~ 772] 7033.00 7000.00 2269.23 :,~ ...... 7k .......... ~._~.~. 71L3 6~ ~33C.t~0 .N ~i ~ r .... . . _ ' ' ........ 7~'~~ 7~3G.00 72~G.~ 23~m.QO ~085 7330.00 7305.30 2~61,1~ N. ~,q'O'. ,~ 7: E: 616,96 19.84 5~1,3~ :E' ~ 37. ~9 18,9 3' 5~,33 E 673 *~:' 564.53 E [.91.3S l<q.1 ~ ..... ~ 61~,56 E. 7~3,12 21,83 6~1..56 E. 755,80 ' 22,68 66~.61 [ 778.b~ ~.~, 78 9.~6' E q' "' ':' z,.;, .54 27.q 8 1.06 E q. zt7.1 [, 23.62 ~ Z~. 0 .6 ¢:,[¢ ,, 22:"0fi".:"?:'" ". 5.91': 513',2 4 ~,91 E 557,27 21,7~ 9,97 E 578.56 21o2~ SP.,-ER.RY-,!;,UN WiL:LL: SURVEY'lNG C;{)MP~,~:¥ ANCiH_:RAGF,~ AL/~SKA CO!~F'UTA T I 0 t',~ DATE SEPTEM£,ER 25~ 1979 PAGE · I[ -I~P'~-~,IEO_I~LL~F~:' £E~L £,,~FN i~IL_EEEI_z £LLn-EF "'E'" ' ' ............................. ..................................................... ~- ..................................... £ .......... _.A--~£. _I. kt O,o.fj .... 822,0,0'2 3i'~5L~.63 N c,=._,2,1,::-' ~',.. "'~7C~,6i.. 2.9,9Zt. O.OI} 8300.[1.3 ,,'~13Q.zF,., ,,,~ ~9~.,qF.', f liJll.l",., 32.52 ....:.~-,~ .. ~. ,,. Z_(.. __~ _, ...... 1. ~..~ ~~L. ~-i.-...U-,: ......... ....... 1..~ ~--.:~ ' ' "' o,oo [~..SaO.OO 3289,13 k ,! 7a. 5.[:! E::.' 1[~79,1';5 :: '.' 3~.85 .. . . : · . ?. ... . . . · . .. CALCbLATI THE liEARES Ch PRr':rEp.,bN~'~' USC ..... ~ A LIt'..EAR INIFRFCLATION RETWEEN T 20 f:C,C;T ~"O (FF'O? RADIUS CF CLiRVATURE) F-'OINTS SPERK¥-~UN NELL SURVEYING C(.~t.~PA~Y PAGtL ]! VF."L.I. WGI-:5 .... A L ...b.. E,,":...A ...... ANr. EGRAG[~ AL SKA " - _r'i ........ _~.~L.~,_'L '._'_~'L,'"£.'_....--~.. CO ~'.!PUI AT I C, k DATE, SE: F'Tt='P[~ [R '25,~ 1'.979 ,IF..iB r. JU~.Et'~, F~<ISS-]6z+51 · , .............. .' . , · .... ,.i.i..: .. '...: :.'.' .. ,. , .. , ,. , , , . VALUES FOR SpEC]AL"SURVEY POINT~ HORIZONTAL SECTION SCALE" I"-' I000' ARCO (SPt~RRY--SUN) DRILL SITE NO. RADIUS OF CURVATURE GYROSCOPIC SURVEY SEPT. 28, 1979 TVO = 8576' TMD = 9672' 8400 8000 7600 7200 i 6800' 6400' ~0 5600' ~.00' 41100' 4400 4000, ~600' 3200 ALL DEPTHS SHOWN ARE TVO. 400 ~600 1200 VERTICAL SECTION SCALE: I"= I000' ARCO (SPERRY-SUN) DRILL SITE NO. WGI-~5 RADIUS OF CURVATURE GYROSCOPIC SURVEY -SEPT. 28, 1979 1600 2000 24O0 2800 ALL DEPTHS SHOWN ARE TVO. $~oo ',~400 ,5° ~oo .a,. 6800 / ,.<. ,..S F [:' re.,,, R y - ~., U N L: E L. L S I.I R V It'.'. Y I N G C ,..,'" t4 F' A I", Y P A G [ ! , , r: G I- 5 ,'~::. '.' ..... [!" ,5;EPTE '~r ER 25~ .......................... ~ ~-: ......... ~':~ ........................ . ,., '.., ,.:..~,'m" · .. ....................................... ~-R-~," ,~~,,'~ -.<-o,.ug~;;: ...... I [:." ~ S I~F, i::. EVCRTILAL V~RTICAL ]NCL ][,;ATICN [IRE. CTION DEPTN TJEPTH DEG UIk DEGREEc '300 300.00 .... .'?;; ANCPOP. AGE, ALASKA -30.i)0 .& i 270. 90 CO,'"PUTAT ION [SATE 1979 ............... ~ 0'-(} .................... ~'~e.~'~ ~ ~ = =,.~, , .., , - ..................... ].i-,be ............ ·- ~.~ I20¢ 1199,91 .ll&S.gl · . 0 15 1300 12~9.ql 1269'91 SEVEL I TY DEGtl. O0 g-A-~.-4]-F $.iJ.i4..V.[..¥. S gI-LI..g-'~.a [.;.a-....2-.~-..~ .... 1,..:i:] 'Z ri ........... cCSS GYF',OSCOPIC St. IRVLY d C', Ii' N U I': [:', E R B 0 S S - 1645 1 .~--.-~<: ..... .h-,E-k-k-¥-:-FrUC-.t4. ]:..~;.G---[-.L,, .~,..:.¥...,~---..=.-./-~, i'; ,.0 D--.F-T~-,-)/.., :..- T O-I-AL- ¢/'0') K'~'?~'//c/' t~ L g'fA hGLtLAR COOR[]INi~T£S VERTICAL kOR'[f.i/[. OUTH EAST/WESI SECT ~;.~N / ....... ( 2~.39 E .36 9.49 S ~ "i-. ": n E .., I ~; -:t-6-.,~-2.0 S .. ,.,. "" ' !~.57 S "~ 7.,. :. ~ ~ .' E:. ' .'33 . ~,~,~ 58,,29'E" .20 l[~.GO S 0 6 4 · 7 ['~ [7. -7,5q 5,4.4,--.E - - ............ ,,&.,..-g.7- ........... 5,64 -8.27 5.8,7 ~! -8,22 ...... 1- q. u, C ......... 4- ........ 1 .... -1~-%~-1. S. 27.~_. '2 1~,[,0 1499.9i 1~69.91 [:' 1~ ~:Z A7.39 W lf:S~ lq59.~1 1569.91 0 S ~ fi2.6~ ~ .......... t 7.~, 8 .............. faT, ~..,...9,t .... t~~,~ ~--~ ...... N. ? ~; 29...W. !8~0 17q9,91 17~9,51 ~ 5 S ~O,lO ~ 1960 I R')~.91 1869,91 6 9 S 8,10 W 21UU 2n9'~.90. ., 2~.~.,.qO ' 17 c,..25.10 22b0 21gq.gO 2169.50 (, 14 S 75. t~O 2~OC 2=c~ qO 23E9.90 O ~4 ['15(~ 50 2~ '~' 24 ~,~ 59.85 2~6~.89 ~ 25 N 59,50 ° 7 F~ L.:~. 2659,89 2569, 89 O ~.*~",. ,.~41 .1';. ,..c c~'b~ 27'c'.e7, 27&q.67 1 qu ,.~&m.~q... E ...... 2.%g0 ........... 2~5.~...g~ .... 2~~' 2..~.& --~' 39,59 E ZkO0 2q9~,53 29~$.53 5 ~ N 1.~,39 ~ -Pq .11 11,1~ S · 1~ 11.40 S ~28 .1,1:.~.O S · 26 11.5~ S ,15 1.1,~8 S E E E E ..%5 .25 .17 1.30 12 .... 2..Ii s ............. _i_,_&9_..,.E 12.62 S ~.,.13 E 12.91 S 5.42 F .... 1.,~.74 2 ............. &._..c2-2_. ~:- 12.27 S ~;.65 E' 11.8~ S 7.3~ E - 5i_,_g 2 ...... -10.t7 -10.5£, -IE..2A ......... -9.5& -8.93 L1 , ~ 5__£ ........... Z,.65_._F_ ................... .-._~ ,85 .... 12.32 S 7.8~. E -q.23 13.11 S 9.50 E ~ ~'- ," ,i . ..... L.1...,.~O_ .............._12.._z_S.,.. E- ................. .-. l,._~ 5 ...... 5.3.3 S Ie4.q£ E '-.3a SFE'F RY-f"'Uh~ ~![-:L..L. SL!f~VFYI, NG ANCHORAG~ ALASKA LiD P',':F !,' ^ y COk:FUTATIO% D~TE COF:P ~1~ Y P A 6 E. 2 . bOSS GYE ,~oCOF']CoURVF'Y dOl.!i NUP~H ....R n0SS-164~1 ~10 ........... 31.5 3 2 5 ........... J, RE CTANGULAR NOI:<I H/SOUTH INCLINA?ION K:IRFCTICN SEVERITY D[.G r,~ ;fx: DEGREE S [lEG/I. [IQ ~ .P I ~ q ;,..5..&_.~. '* ¢'3 23.79 N 1.72 33.36 ~', 3.349 21 ~0!~.~t 7 4 .~." .t.',~,q W' 'bO~8.TR 3,3G~. 78 7 St., N l'.SC W 3197,27 3167.27 1l 15 k 13.1n E 32~6.27 5216.27 11 57 ~; 17. 6 E CO[;RDI hATES VERTICAL EAST/WEST ..~°ECTlO?'~ ). 15.q9 E 5.0,1 15.3.2. E 11.15 1_5_..&2_.~ ................ ~ g - .7. 5 ........ 17.13 E 27.q6 l.q.70 E 37.86 ~406 3392.73 3';562,'73 13 A8 N zl.3.,, ............ F. %6r& ......... -,.,.34-&9, [~.-~~~7 ~ .... ~ .... 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N 174.49 F 1C38.30 N 186.07 E 1098.7q f,i i99.6q E 330.47 372.62 · '* ~_Q,._,.,!. ! ............ q73.1~ 5'''' c'~ Gq ,r....~ . 586.76 ~-.43.¢4., 699,96 756.3i; a12.gq 869.27 ~26.51 994.73 1 ;~4q. 31 ll,3fi.q5 ;'Y4 ............ '~!ELL .~,'6I-3 r:' P l..J,,r F, ['.': [ _.~'/~ Y 2, L A.S SFE. f~RY-SUN ~!ELL SURVEYTNG CONP ANCPORAGE, ALASKA COr,,PUTAT IOk DATE I ~ ':' S L; E~, e E A--_'.,: ~ OU~_]i E C O U R ~ E 0 0 G -L E 6 ~"E ~ SUk [[~ VLRIICAL VERTICAL INCLI%ATIGN EIRECTiON SEVERITY REC ]AktGULAR P[PTH [;EPTIi DEPTH DEG MIN DEGPEES UE'G/~O0 N~Rlfi/SOUTH , ¢1 O0 56~7.7q 5657.74 ~A 5 ~ 16,89 E 1,78 140~,65 N ¢'206 5767.36 5737.~6 ~6 21 ~ 17,29 E 1,75 lq6q,q6 N ................. FAGE · GYP, CSCC)PIC SURVEY NUMRE~ LOSS-1E, 451 ,. CQOEDINATES VERT'ICAL EAST/L4EST SECTION ) 279.78 E 1423,47 297°56 E 1~83.94 ,,.,~_Q. .............. 670U FRO0 .................... £..q~..U,.~ 7¢i60 7100 ..... 72.00.. 7300 7400 6176.37 6146.37 625a.2~ 622~.P6 6A22:..98 ' ,,':6,:392~98 6565.~0 6475'.80 .......... AS~S . 1 a .a55~ 6612 .~i6 66~2 6757.1~ 6727 ........... 75_0 Q ......... £.~&2., P.P . (~ ~ ~ P 7~,00 6'927.23 6~97 7700 7Cll .98 69~1 7 t', ~. ~ ............ .7..Q~, g ~ _~A ~. 6 , 7900 71 7U,. 27 71q8.27 ..... ~' 1..20 l=~.~' ............ ~ _ ~ .., . 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Z4 N 26.8q E · 1,09 ~q 52 f~ 22.10 E 1.25 ~h 17 k 22, .3 E ,~2 '~., .~t, N 23.10 E .74 · 62 265~,,.55 tl 489.64 E 2168.3f) ',i rq 210c' 52 N 506.89 F 2162.10 . ,~ . .. ,72 ~.-"..-.~-!,52 P,~ ~', ', ....... 9~ ............. _~.~..ff_? 1 L E ...... ,,~_~,_~,. 22b,C;.79 t',,! 54,1.75 E 2267.2.9 2:25~..47 N 560.q2 E 252rJ,&3 2'z09.51 P} 580 12 ~ 2=74.97 ..: ~ ........ ~ ~'. ....................... 2~E1.88 N 6(,0.97 E 2431.24 2~?:.15 fl 622.55 E 246L.75 r,. 644.~0 E 2546.46 N 23,25 E .45 N 24,20 E .52 N 25, .0 E__ k 26.10 E !,, 27.:59 E ,77 N 2c.'', il E .96 N 29,79 E .72 2522.07 N g67.66 2.574.91 ,~? 695.90 E 2661.71 2627.42 r,i 714,95 E ........ 2.Z..1__.c,,:,.1,? ......... 267,',,.68 N 740.03 E 2776.p, 0 2732.2~ N 765.42 E 283~.7~ 27~q.09 N 7~.2~ F 2R92.74 2~';zr"-.80,.~ N 82'*,.,.~6 E 2950.97_ t"f~,c:'l;f~Fr-) VKF,'I IC/~L VERTICAL, IkCL]LA'1iC, N P, IRFCTION SFVERITY r)[i. PT v: L)E.F T t,i DEPTH DEG I"! i~; DEGREES DEGtlO[} K .30'~.'~,9. E :. .76 N. ,.,,-'0. 0 E 1.02 N~,~5·20 E 1. FLi: C I'~NGUL/~R C'OOR [) ~ f'~ATE S VERTICAL NG~T'H/SOUTH EAST/~EST SECTION ') ,,' ~'~:i~ T.~:,N ~'~:'~-:-~-::'::":'"'~-~-,:F:~"~ ....... ' , ~,~'~,' ~ c;~s 's'z ' 3~'/+9.83 N 949.35 E 3193.71 ,5106.60 N 98]..G0 E 3257.73 .... 3,, :,)2.6 3 THE CALCULATION FEET AT ;',]ORTH, 18 DE'G. 1.5 NIN. EAST AT MD : 9672 0~.~ THE USE OF THR¢:E D1PiENSIONAL RADIUS OF' CLt,~VATURE METttO[:~. · .. ............................................ . ......... Ar',t CJ"i oF<AGE , A I..ASKA A ZL ~,, r:.'.'T' I C-. R.I £t:~E_I£.Lr.'. ................................................................... W i'- L, L '~' G I - '~ C {,~ ~,'~ F.' U 1' A T I 0 ,",: ri A T pr., t.!rzHO£ mAY SE PTE!,'i;-'..ER 25 ,~ 1'-)7~ ,,'.., L, A £.k.A SFE:RF'~,Y-SL~N ~,~ELL StJ~VE,~ING COMPANY. PAGE' , dOB tYUI',iE;ER F.,OSS-I[:.,'~51 ............... ...~.,,,.../: ~...~ ~: ........................... 7~,65 6~2P,9~ 6392.9~ 1900.6q N zt.'5.~.~? E 577,02 ~!['06 726n,10 72Z0.10 2qlF.15 N 622.5.'5 E 7.~;9.9~ "'672 ,~576,,D5 .85'4.6.B5 x":'26,15 ,~! 1097,77 1('.~95,~.~ . '.. . . ..,-, ,..,; ~ ... ~ . . . .. · · ...... . .Tt-.:.~.....C.ALCIJL^TI~.h: PRC£EI3LRES ARF F!.ASEI? Or,~ THE USE OF' THREE P l~.~?.O 1 162.8g -) .......... ~.T L.~ Lt,Ic ..... e,.~ c.ue.~_e~:, :I:~,' :! L!Et_L "',, GI -L'; CC' p r? II F, t~'Ci [ f,, A Y S £ A L A ° ........ ~,,:,., .,.. ,-.,.: -- , G T A L ') O. 00 ~, O C 0,0 0 N · 25 E · OC ,O 5 ~ ~ o .~ s ~, o.~ .:s:~ ~ ~ o.o..':.... ~ ~: s :...': .' ::: ~' . ': ~.3,.', ~ ~ ," ~ "' ~t' :::::::::::::::::::::::::::::::: ,..~ ' ,.o o ~ ~ .. 0 U .,. " ' ~ r ' ~ ~ ~ · ~ ' ~.,~ ,' ' ......... D3~ ................ :.~d,:.~O ..~i,~r! ............................ , ...... L_~: ~ :.U F; . ~:m~ ..... : ............... ~.~ ~t3~ (::30.0~ 600,60 ~.q3 S 1,85 E .6~ ,02 =C 73D O0 7oo.oa 6.flq ~ 2 91 E ,~6 ,G2 ~,.', e ~ ..... ~:-~ - ,-z ;g -' ;~ l( ~.l e ~ ~ ~ ' ~ ~so.oo '~o'.~ '~.,.~:s. ':. ::~ ,~ .oz ' . ' Io30,OO 1,~OO"OO '.':9.72 ~'''" ~,' . 4' 81' 'E ~ 08, .0 O .... · : , , , ~.., - , Oo .L~:. '~ ~ ~.:~ ~ e' .~ ....]_: ,'] ............. ,.~.~ ................................. ........ i~.v..,~..~ ........~ [, [~, ' ~ ..... ~ .................. 5.76 E .0.5 .00 5.&'9 E' .ut,. .O(t ']'. 5'1 ~+'a" · ~,6~ E )_ ?L ;'2 .......... ~.'. ~ 27.3. ~1.3 3,3 223n,00 5.0 .................. 2/.t.5~..,~.Q .... 30 ,..gS. 3S,OO ,00 2200. O~ 2':.590,. 00 ,,,"' ¢, 02&50.00 26eC,OC 11.~,6 ':' ............. ,_Z....- e6. .27~.~w_,.~ a ....... 1.2 · ~,q . ,.:j ?a30, gO 2 "'"" , 0 .... ~0 0 13,42 G 2c~30.00 290Li, O& lO,Sq S. ~ ................ 3.,_:,..3.. L~...,J.'LQ. ~ ~ 00 · ~,~ 2' · 16. $ 1.2-9~,..,"° _ ~"~ E ,0 0 12,~1',;~" 6,10 E 12~. 1.L_.~ ....... ~ ~ ~ E .. ,11 , O~ 11.73 S 7.56 7,6q E .11 .00 ~.O~ E .il. : 16~2 E · ,15 ,03 13,13 E .25 .10 ..... ~~.~ ;", 1~, 75 E. 3,'~5 1,80 N 3q, Off .E: b,~t~ 2,89 I.: q~,75 E 12,~I ~,l& .... 1,2.Z~SF~ ,,. 5J.~ E 16.72 4.11 .) WEL, L ;,.iG~-Y F'P~FPCF t:,AY · · . T F; U E .9 U [-~ - S E A T 0 T A L t.-, !,',, ~, P T H E: AS ~/W E:ST.""; FFE ~ £f',i CE,· '"fi'-£ 6 Ti 01)4 '. 7966 3930.00 3900.00 25fi.18 N 51.26 ~;, Z, 6.79 9.03 ~ , ............ ~., 3~,,,~.E ....... ~.~.~.._ ............. <..,~..~_~ .......... .~..~. . ................................ ~295 q2xO O0' ~65.50" E ' 65.69 "' lO,O~ "" ' ~, . · .... . .; ~' , . . . . ;.,,, , . . . . ~ 7 '" 0 6 g I. 2 8 ~015 6~.30. GO ~fiOO.8O 760,07 5 ] x '1 ~ ~5 n, O0 ~2~0 .... bO~C..aO, ~ 5r'oo.r',O~ ~ ,,.~7.'}~ [', ...... . ..,~'~O.OO 5~,;G ~' 1120.62" .., ~,,~ ~, 7 (., q bq3O.O0 5qgg.g~ 1200.25 f..~ .... :~r .......... ~.:~.~ ~ ~ ~ 9 . , , ~, qb. lO E N 105.7g E ',," 11 6..2.7 E k 1'2 7, :~ 8' E ,~'~ 13 ~.. 36 r.: ' ' .. ,. 96.76 19.17 1.19.;, 0 22,42 1q1.78 22.58 i~S.51 2i.a7 _ 2 ~, 7_.~:~,.L. 21. ~ i 22~.q2 2':2.6 C, ) 253. L3 23,61 278.02 P~.99 27,76 29.28 TRU[ S UiL~ -- S f., A TOI'Z~L I')EPTH OfF'TH '~E!:>T~ . .NCRTH/~OUT "c:. CORRECTION ,.. : , , 1507.q2 ~ 31,1.OF. E (~:27 8539.0j E,.SGO.Ob 1839.97 ?~ q18.91 E 7CO~ EqSO.OO 6q0~.06 1~05. ?[] ~ 433.97 ............. Z..1.2S ........... ~~.~__. ~ 5 ~ .0 · 0 ~ ~69. . ..... .:. ;... . .... ,., ..,-. , · ~ ' N 72~8 &630,00 6&Q.O,~O 2032 ,:.,6 7:567 67~0,00 6700.00 2,'"'c,,:~.=0 N 531,3q 7721 70=0,, . ~O,, 7000.00, 2269. . ~93 ;4 56 ~. r'3,, ,7~:&l ........ ~_~ "~ 71C ~ On 2'~5r c,O ~ 5A~..q7 7c'6= 7256. [~0 72n0.0~1 23g~.40 N 61~.56 ~ ._J ,. ~,. ~O~15 73:50.0~ 7305.90 2~61.1q k · 6~1.56' rr'7.27 21.71 E 57L,56 21 E, ~; 9 ~, 1.~. 2 0,62 E. ~1~ .S& 19.,8~ · , E: 637. ~9 18,93 E 673.2 L 17.35 E &.91.35 18.ltl E 7~5.12 21,83 E. 755,86.. 22,.68 E 778.b~ 22.78 T E L.!E SUB- SEA T ~I~''- F RTI.E_/U_ ..... ~ ...... T . ' ' ' ' '' · ~ .. ,~;.. ~ ~--'~'" ...... ~ · , . · , . ~"~'~'~''~T ..... ' .................................... nFPTH DFPTH DE.:PT~ · 'CORRE. CTION. '' : . ' , · . .. . . ....,,. "= q . ~ r,D " :..~;~ ~' .. .,.~ X: , . : ,,'. "':~.: ' ~ H '. . ~.'~.~ ~ ............... 7..5~.u.,a.fl ............. ~.~L.,.~ .............. ~.~ ...... L,.~..~.E ..... ~ ~_.~_~.~__: .... ~..~,,,..~_. ............ , ......... ~..~.~ .................. , ...................... '~.~1 ~330.0G ~,300.00 '31.30..~5 ~, ~9~.H6 E iOll. IZ 32.52 .. , . . ,.. u~2, 4 :~307.D9 N :.:lOe. 7.85:.E :1ut~7'66 7,~1 · ', . · . . . CALCULAT1Gh PRCr'ED.,URES USE THE I~EARFST 20 FC)(')T FiD (FRO'/ RADIUS CF CIjRVATIJRE) PO]NTS ~,~F' LI. WGI p r,' L.J r H ("., El i.:i ,'1 y ,. A,L,~.~_A ..... SFE'RRY-S/JN WILL SURVEYING' COI;~PAI~y ANCI,-IORAGE~ ~L/iiSKA · , ......................................... _INTFRPOL. ATED PAGE · B A T'L. iO_ Fi .. SJJ ~SI..Y.....,_S_E}':_? E ~'..[:L~B.._~5..1_..~...~j. 7.? .......... .. VALUES C.O"iPUI AT IC, k DATE SEFTFN[![.'.R '25~ 1979 ,JC[!~ t.!UMBi::t'~, E~]SS-16451 ........ ~L,Y =: ~...U.~A!,IJ>,,!~,.,...L..L.[ ~..~_.~. ...... 2~..'i,,,..~ U ..... E..T., .................. . FOR SFECiAL,.',SURVEY.:,P,OINT,S.. - - ~ .~-. ~ , . T i'.'~ U L S U t"~ - S E A r,',, F/~ $ UR [.C, V E: R T J_..C..~ L VE R T._LCA L RLCTANGULAR DEPTH DEP TH ' EP TH ?';5 95 P, 51 9.00 9¢, C ~.) F5 2 2.7 C 84 ?2,7 ".'. T C)T A L A T [:..'. S '. ..,2~0,°8 107'"~.~q E ¢~E, SAD ::;','_;8'~.26 :,~ 1075.~4 E SURVEY DEPTH L. HORIZONTAL SECTION SCALE = I"= I000' ARCO (SPERRY---SUN) DRILL SITE NO. WGI-5 RADIUS OF CURVATURE GYROSCOPIC SURVEY SEPT. 28, 1979 TVD = 8576' TMD = 9672' ALL DEPTHS SHOWN ARE TVO. 7600' ?200' 6800 6400' 6000 0 5600' ~.00' 4800' 4400' 4000 3600 3200 400 ~600 - 1200 VERTICAL SECTION SCALE; I"= I000' ARCO (SPERRY-SUN) ORILL SITE NO. WGI-$ RADIUS OF CURVATURE GYROSCOPIC SURVEY SEPT. 28~ 1979 - 1600 2000 2400 ~800 ALL DEPTHS SHOWN ARE TVO. O0 ,5° ° ~ 6800 .-~8000 TMD : 9672' ATL~..,IT'IC. PICHFIELD COiIPAI'.~Y ~', ..... :.~ r's,,-~ DATE OF ~,~IJRVEY SE'F'T'F~%F~ G~ ]97~.~ ......WGI ~ .......... ;WELL ....... : .............. ;,.: 0 · ;7:: ........ ~ 5 ~7 ' ;~ -'~ .............. ....... ~ .......... ,. :~':f'" '..,,-~ ~ ............... COt,;[,UT~T I ON ': ~: ....... : ........... ': ................ ; ........ [JA FI. : ........ :" '":: PiAGNET]C : : ..... -'v2'-":-2 M[JL i I E.,H OT : ......... : ...... 7:_ ......... SURV~.Y .:..;'.'._L...::~ ..................... '. ........ : P R U R ~ ~' ~' ~b ~ Y c.. .: ::::;, ....... AI.~gF~ ~;' ~: ........ KELLY BUSHING E, LE'.V : 30 O0 FT ':,c .~,: · TE(.IE SU~-SE'.A COUP,. 5[ COLIF~eE.,., DOG-L~'G., .. ,, TOTAL ';E A ' ................. nF'P I'H DEPTtt [)CF'TH CFG ~h ~EGREES PEG/lO0 N~E I'H/SOUTH E'AST/~EST ~E'CTTGN 200 200. 26! 2'6C 170.00 '. 0 30 2 3 O, c c~ ri I ~:' q, 13 · 99 b 2 (! ,5 fi 4.9 '3 1 C 626 625.",°..7 717 716 · 97, g ,'3. 9 a f~ ~... 96 595.9 ~5. O E 55, 0 E & 86.97 ,;,).,:'~ i;i 77A..96. ,..,r~ ~t5 .. 2O 0 E 77. O E g 31. O E C 30 G 2,5 ?.i 79. 0 E 3 (: 5 · 29 1..19 g: 2.=0 F 2.25 .z~6 1..96 S:' 3'1.2 E .30 2,59 S . ~ f ...................... ~ JYg'-E ............... %'V'~"F'"r. ................... '~";'~,"~,' ...................... .42 3.70 S b.09 E .35 3.~'.9 S 5.49 E 5.L~4 . A"g ................ AT'¥1-:"S'F ..... '~;%5'-'~ .............. =¢.~9'~' .......................... · 22 3.96 S 6 .67 .3.8~ S · 7.~5 E 7.~1 1SA,;J 153U. 9z+ 1 509.9z+ 0 1722 1721,9q 1691.5~+ I q07 1"} 06.93 1 A76.93 ? 1 ~ 7 21 e 6 · '~ .., = ,:n 1 ¢, 5.5 3 ~2gO 227'?.q2 22qq. P2 ?372 2371.o2 25~1.92 7'465 2A6fl .91 2~ q · ~] ' ...... P55~-- 2557.'~1 2527.~1 5 c, 61 · 0 ~' ..', , · 91 q. 0 3 % ,..~ p,q. ,..r' id .17 ~-.Oq . .45 N 7 ...6- ,. 7.~1 ....... / 7.67 f 7.52 7.66 ~ 7.51 7' ;L5"3- [-~- .................... 7'C.% ................ 7,63 E 7.5J a.ri5 E 7.'95 ,q"; '55-'F ....................... P ;; 'q 5 q.26 ~' ~.2n .. . ,., 1.0.53 E 10.51 12.01 F 12.02 12,39 E 12.3~ ...................................... mORI-?ONT4L DISOL,t, CEi4L~I',JT = 12.3.(~ rFE'I AT ?~OF:TH,, ;~7 DEG. 5'3 MI~'J. EAST AT Ml'l = 2736 ATL~ETIC RI'CH~IELE! COF',PANY DATE OF' ~U~VEY SFF'TE~qBER ~PL.]nHOE~.. ~'~.AY ~ '[PIF"~4~ER 7~ 197'~ UOF~ NUH~R MS-I6~46. AI,.~e,F~ KELLY BUSHING ELEV. IN~ERPQLAT'ED V~.L. UE'S'FOF: EVE'N ~500 FE'ET OF' NE'A~'URLD.., DEPTH T RUE' %U~J-SE~ T GT ~ [. fIEASt~REB VERTICAL VERTICAL R ~ CT~P.:GUL~t COORD]N~.TES ~4D-}VD VERTICAL "iS"t:"FY-~ ......... --" ....... OT'P~~ R--=---.---~-CP"Y~- ............ ~T"ff'fFWE5 LFt?F~'W'i~ ~'t-/"~FE"~ Y .......... 5'TFF'F~:'FE'CE ................ :'C-'O"~-F'E'E'Y'i"5)~ .............. :"'--': . O O. 0 ~ -~g, O 0 O. Oi] O. O 0 O, 00 ................ ~' 0"'6'~'~ ........................... ~"t~'~" ;" g =,~ .............. ~-'", 6"'::':-t~ .-"q ~:. ~ ............................... ~ .... · 'l ~-'"'--c,:. ..:, ..................... ~..~ · 1 6 '"-E ...................... · ~Fe~ ,. ................................................... . ~"':. ~ 2OOO 19°~,q3 1969.9~ 2 52 <'. 8.5~ ..... . ....... ,07 P7~&-, 2735.°1 2705.91 .z~.~, ;i 12.30 E .65 .0~ ................................................ THE CALCULATION PROC="DUFiEe ARE7 ~;~A~,r''' N : ,vi. 0 THE' USE OF Tt.,~F,~r,'F DI~'.~Ef~,'qlOI,,,AL_ RADIUS OF CURVATURE METHOD, t,~.,"'CHOP, AC.E, ALASK,~ '" ~,TLt'.,t!T]C RIC~iFIELD COFtPANY gATE oF SURVEY SE["TEt-!BEP &, 1973 WGI diLL l'JO. Z CF~i'PUTATIC, h BI',T~ PmLJDM3: ,~/f,Y cji F"TEPiUFR 7, ].57a JOE! ~tUMBER MS-]8446 ,~.I..Ac'K~..; KELLY BUStt]NG ~rLL. V. -- zO.. .gO FT. IFJT,':"RPOLATE[~ V.:LIJF'.S FOR FV.F.i'] 103 FEET OF SI,~t~-SFA DEFTH TRUr' %U F.~-S E A TF'T AL , ( l,'?E A SURE b VERTIC,~L VERTICAL Fi [' C T A ['C.'gU LA P C:O 0 P, D IN ~. T,[!'S ?9-T'VE VER, TI C/~L ['~EPT H DEPTH DEPTtl N Oi';'. TH / S OLtT!-~ EAST/ ~.i E.?.T D1FFEPENCE CORRECTION 0 3o00 -30.00 O, ~0 O. O0 O. 6~ 3,3 130 230 330 33~, ~30 430.60 400. 530 ,530 · O0 500. ',i,',O E .01 .00 1.2~ E .01 .' E, 30 .630.00 600.00 1,24 S 2.35 730 130.00 7,30.00 2.04 ,..:.':' 3.20 R30 P. 3n.O0,, .RO0,O0 2,75 .fi 4,1°,... 1030 1030. 9 O 0' O0 · 1000. 3 · 51 'S . 3°77 S ,~.71 5.36 E' .03 [ .US 1130 1130.30 1100.00 3.~,9 S 5.60 E .0~' .................. i_.2..:2 .................. :. .............. ,.Z:.. ........... ..2' , , · 1230 123 0.00 1200.0 ~ 3 .9. ,'~, ,.~'" --'"-~';"'z~-?-'"'~ ....................... ~ '~'5' 1330 1330.00 ].~O0.OO ,,'~.~2 S 7.q2 E .06 1430 ,01 ,01 ,01 .0'-5--=------ ...... : .................................... : ..................... . O"O 'j,: ........... · O1 1, lr"'30 : '1:530.00 1,500'00 3.c~ri g ':. 7.6G E 1,~,30 163"'.00,, 1600'00 ~.S4 "',.,:~ ' ,. 7.~6 E 1.730 1,'~ ,, .... , .... 7,.,~.00 1790.0/~ ~ ~1 7.~1 E ,O0 $IL, a~T]'C EIC~-~FiELD CC;,~,,~PANY DATE OF SURVEY SEPTEMBER 6, !,979 "~! G-I ....... ~'~'[-[ ..... "~ 5'"~ ...... 3 .............................................................................................. E'O'i:i'l"-[)'TT'.,"T'-}["(}"'i:,:'-" '" " DATL ~.LA.SK/~, KE"LLY P, USHII',~G ELEV. - 30.00 II"JTERPOLATED VALI.!ES Fr'.,'F:~ LTVEi'! 100 FEET OF .SU~,-SI::.'A bEFTH TRUE SU[:;- SEA 'T 0 TA L ~'I.,r. ASL~RE[) VERTICAL VERTICAL RF, CT'ANGUL/~,f< CC)C)RDI~J.&TES ~.qg-TVE~ VERTICAL "D""E'-~'-T H -- DE. PTH D, EPTH. I',~ORTt,tT~OUTH' EAST/WEST ('}I FFE,~EI'~C E ' 'CORRECTIOI~,~ · ,: 2[}30 203 ,'.). O0 2 C' 30 · 00 .-'2130 213,1 o 90 21 :]0. O 0 " ................ ~-~"3'~ ........ -~2 3 ~ · o o 2 2 O0 · o O 23=0., 2350.00 230r1.00,. ?q3O 2~30.00 2400.00 PgZ,~ 2630.00 2600.00 2730 273U.flO 2703.00 2.25 g F,.70 E' .07 .00 1.7~-J S 9.03 E .07 .00 1. ~? ? ,.:, ~", ~ .5 ~T ................... ;"~"'7 .0 ~' · 71 ,,..,~' 1 ~. 25., E · 0~.~ · 0 0 · 30 ~,~ 10.~6 E' .Oq .01 .'g-4 ~.~ l"-i'-',"'2"~F-"~'~ ....................................... T~J'O ................................. ;'6'-6 .q7 ~,.: 12.27 E' .09 .00 ......... · ~,5 ~ 12.30 ~, .'0'"~ ,00 TaE C. ALCUL;,TIOt',,! PPOCEDURES USE A LINEAF~ II,.IT'E.i~[:OLATIO~,,I ......................TH-E. '~1~ ,~ k _E-g T'-~ TM-':: '~ ..... ,:.u--FOOT~ .... ' ......... M L~----( F ~ (J ~'~' ...... ' ......... ~ .... ~'~'-I.].,'i'- '~""-"'?"or .... ~,'=13 .... F~ F~:TUR ~.. )-r ....... P .. I}.J'T'SO .......................................................................................... ........... T f; Li E. ,:> J E! _,..,c.. E A T 0 T A L r,~,E/~ ~ LJR £ D V .F..RT IC~L VERTICAL R [:.' C T A N (:;LIL A~' COOR[; ]NAT[TS 200 400 6OO 80O I000' 12o0 1400 160o 1800 2000 2200 2400 2600 TVD = 2736' TMD= 2736' VERTICAL SECTION SCALE: 1"=500' ARCO OIL 8, GAS DRILL SITE-WELL WGI-3 RADIUS OF CURVATURE MAGNETIC MULTI-SHOT SEPT. IDs 1979 ALL DEPTHS SHOWN ARE TVD. HORIZONTAL VIEW SCALE: I"= lOt ARCO OIL 8~ GAS DRILL SITE-WELL WG1-3 RADIUS OF CURVATURE MAGNETIC MULTI-SHOT SEPT. I0, 1979 CLOSURE S 89° 08'E TVD = 2736 TMD=2736' ALL DEPTHS SHOWN ARE TVD. .!.~T'~L~-~' ~1 I --~-~ SPERRY-SUN WELL SURVEYING COMPANY MAGNETIC MULTISHOT FIELD DATA AND TIME SHEET NO. 1 .. COUNTY/PARISH WELL NO. ! JOB NO. · DATE ~--~ ~/-.-~ ~(~ FIELD SURVEYED FROM ~' TO ~ FEET CLOCK NO. c~l ~- '" COMPASS SPA~ING J :g' FILM LENGTH' CALC. ~'/"~' j REMARKS: FRAME NO. ~ ? t FROM BOTTOM/TOP MAGAZINE NO. COMPASS NO. / ~ ~' '~' CENTRA~LIZER LENGTH OF COLLAR -~ TYPE COLLAR --~L'~ '' FIRST FLASH . ~) -r') o LAST FLASH MEASURED ~//////////////////~.~//////////// /////~.." //////~"//////////-/... // ///////.////X/'>-~ YES-NO OPERATOR ~ GO DEVIL STOP XSTEEL SUB IN RUN MEASURED OUT RUN IN RUN MEASURED OUT RUN IN RUN MEASUI~ED OUT RUN SURFACE TIME: DEPTH SURFACE TIME SURFACE TIME DEPTH SURFACE-TIME SURFACE TIME DEPTH SURFACE TIME . .~, ~_~- ' ~7- ~ff .... .. . · 01-2.03(4/76)5M '.2 (i: ] ~.~ } F~F,liE:l'cE b.J:Y .ALA'~F,A ,..P. R ¥',.r. SLtN I,~E LL,., UR.V £Y'I;.,, G COF;P A~,.Y C(:'.i,~FLJT~TiON DATE F~{-,NETIC NULTISHOT SURVEY SEFT£.PtE, ER 245 1979 ,JOb NUMBER NS-1,6,458 t~kE, D VFRI IC~,L VEHTICAL INCLI~ATION LIRECTICN SEVERITY RECI'ANGUL~R CO (',R DIN/~TE: S VERTICAL I.' DL: F' Tt'i B£PlH DE6 ~'] I I'.,: OEUREES i')EG/100 I',;URTHI$OUTH EAST/L, EST SECT I Oi..J , '* '~ N 2 E'' .,....,., ' 50.:.'.'N 805~'17 :E '":: ,..,, , .... . . ~,':, ~ 31 7779,89 '' .r..~ 7 2_.. 6 ....... FE';2 1 7g 31.. 75 7901.75 ,~', % 1 & ,r,; 0 {i 6. $ 979 ? 6.99 ~7 15 N 31. D E .26 2[-:61.86 N ~[% O ,". 31. 0 E .79 2911.57 N 8'~5.59'E · 863.12 E 8 ~2..99 E 29[~,7.26 36,45 -97 , [:, o .71 3177.08 N lOq6.Tq E ,k-',~, <i43E.q2 8q06'.92 42 30 N 29. D E .76 3232.81 ~j 1078.27 E 3%07.~1 ...... ~ ..... ,,. - ... -~ .......... ~ --, -, ......... :. . .,?. ::. : . ... ,.,: :. .... TF~E [ALCI. JLATIOi'i PROCEDURES ARE BA"S[_'; Oh! THE USE OF THRLE' DII,!E~,iSIONAL RADIUS OF CtJRVATURE METHOD. ' SP£RRY-SUN WELL SURVEYIN'G CONFAN¥ .. , · AN£HORA, GE~ ALASKA .... A IL A L.]' I C.L.k.i.C i.i.F~LL~_L e M P ~ N Y . . Wf~:I 'I'3 COP'PUTATION DATE t'P IJ['~I.,[,E ~:AY SEPTE~JER 2q ~ 1979 ~L ~ S~Ll ........ . ................. dOB NU~.'~EER HS-16~50 K ELLL.Y_._~:~..LNG_£~,E~.~,_~_~Q..,~iL_._F...T .,, .................. .................................................... T r,) t E R P O L/~ I £ D. _~./~J_~£.S._f'_.~_,L [JL~.~ l .n 6 O _f: E E 'T' O F M E A ,S L! R E" D P £; P T Fi :.?..:'..i...' T ;), U 4. qUB - S E A TN T A L ,ri. F P T t-~ D E P T Ft NCR T H / S (i U T H.. .'.":' E. CT iON 2.1.1.6..,98.N .. .'TB._O.94:E . ' ".'B34,60 3267,1~ ¢,; ~1097.$0 E 1062.3& 22,~'~.$8 .... ,45.78 N 1140.61 E 105~7.57 35.19 · THF CALCULATION PfiC, CEDU~ES: ~,RE. BASED ON THE,, USE' '.CF,:...THREE.i,.L,.D I F'~EN.$~L~NAL RA D.I'U$ OE. 'CUR,V A'T'UR E ,,ME. TH(DD. ..... ::," 'S" .) S['>IE.DRY-SUFI ~,!E'LL SURVEYING CO. PP ANY' ' PAGE ... ANCHORA6E~ ALASKA . ' . HGI ,~Jf, COKPbTATiON DATE' PJ'.'Ltgf.~C~L ~':~.AY SEF:TEMBER 24~ 1979 dO[~ NU~E:ER MS-1.6~50 9 t'" P t I-'! DEPTh SLIB- SE A 'TO T ~ L -,~ I ·o i.'F ~'E'~? ~R"~ [' C. T.:.' ~ ::::.'i':" .:':'" ~ '.: : ,~ ~:: ,? , , ............................ ~,_.~ .......... z.z..~ a..rJ.~ ........ : .... z~.-:~,~ ...... : ................ ~.z~.~......~.~..:..~._,-.~.~:~.'.~.~m,--:~:_. _z~.~'"~::...,.. ~:~.__:,[,.._.:: , ......... ,,-: ............ :: ............. F~;~9 7736.00 7700.00 2731.21 N '787.8fi E ~Y.ll 23.22 ' ' .~ ' 25, 6 ~ z e, 7~', ~ c. oo 2.~:s ~ ~' 7 2 : ~ ~; ~::..:':[:.::L.:::::.:~:.::.;::'::~.~.:..~.:, , ~ . , , ~ .. ~, ' ', ~; s~ ~, o ~ ~. ~ o ,:'~ ~ ~ o ':,~ o. ~ ~ ~ ~· s ~ ~:~ s~ S ~' ~ ',~ 0,':', ·" . :, . , · . : , , . " ' ': "' ' ~= ' ~ ' ,9 '" , , .............. . "2~ 7~ ............... a.Z a.&.~,a :.,:~.~.,l.~_,_...: ........ ~_9.~.,..Q .... N :__-_.,,~A.h~ E ,~.I..~,~_L-- ~,6,..Z ~205 ~',2~,0.~0 82(:~0.~0 3070.18 ~; 9fl6.31 E ~75.26 ~1.a4 ..... 9~.,7,,~ ..................... ~l..a_~g~ ......... ~A.&Q,,,~.~ .... .~n'9] ~. r,, [ ' ~ ~.~_..,..~_~_~_ ..,~6 ...... .i..~L.,..Z.~.E .......... ~,~2,~..~,~.!Z ....... ~.~_ CALCL;L~I'~N F'.~CC'EDURES USE A LII,:EAF, INTERPOLATION fiFTUE[:.'I',; ThE t',EAhEST 2G FOOT MD (FPO!-' R~PlLJS OF CURVATURE) FOINT$ HORIZONTAL VIEW ARCO OIL ~ GAS W.G.I. 3 RADIUS OF CURVATURE MAGNETIC MULTI-SHOT SCALE I"=~_OO' SEPT. ~_6~ 1979 TIE IN AT 8542 TMD TVD = 8575' TMD = 9673' ALLARE DEPTHSTvO SHOWNI VERTICAL SECTION ARCO OIL ~ GAS W.G.i. 3 RADIUS OF CURVATURE. MAGNETIC MULTI- SHOT SCALE I"= ?-00' SEPT. ?-6 ~ 1979 TIE IN AT 854?. TMD 8000 · 8400 ALL DEPTHS SHOWN J ARE TVD TVD = 8575' TMD = 9673' SPERRY-SUN WELL SURVEYIN:-~OMPANY MAGNETIC MULTISHOT FIELD DATA AH~, I'IME SHEET HO. 1 COMPANY ~"'~"L/"~ J~"~[ ~ ~ ~ ~ ~[ ~t~ ~o~~.~y DATE ~.~ '~ ~ ~.I ~ t~ STATE ~~ ~ ~ COUNTY/PARISH ~O~ %~ FIELD ~ ~~ ~~ LEASE %W~ WELL NO. ~ SURVEYED FROM ~'~ TO ~~ FEET CLOCK NO. ~ J~ FRAME NO. ~i ~GAZINE NO. ~ ,COMPASS NO. q~ CENTRALIZER ~ COMPASS SPACING J~,~ FROMBOTTOW~ ~1~ LENGTH OF COLLAR J J~- ~ TYPE COLLAR ~~ FILM LENGTHCALC. ~-~ MEASURED ~-~~ FIRST FLASH 3 O--O LAST FLASH ~--~O REMARKS: ~t[~ ~[(~T--iO-~-~(~m~T'd~~ ~ ~~~. IS. ~,~ ~O~ /~/ /////////// /////~'~ ~ // /// /// '-//~///?~,,///////////... // ///////.////x/~ / / STO. STEEL SUB MAGNETS ~ COMPASS X STEEL SUB YES-NO IN RUN MEASURED OUT RUN IN RUN MEASURED OUT RUN IN RUN MEASU~IEI~ OUT RUN SURFACE TIME DEPTH SURFACE TIME SURFACE TIME DEPTH SURFACE TIME SURFACE TIME DEPTH SURFACE TIME . · ~ I0~ ~-~ ~ - ~,:,TE 101-2.03(4/76)5M e Post Office -Box 380 Anchora-'''-''''~'-,~t'--.. .,,:._,,,. 9.9.510 Telepho:~ 907 277 '7,.637 October 15, 1979 Reference, - Enclosed are Cased Hole Logs for the following ARCO wells' D.S, 1-15 9/20/79 Spinner .5" D.S, 2-11 9/25/79 " 5" p.s. s-6 s/19/79 " s'-' D,S. 5-i7 9/28/79 " 5" p.s. 7-1 7/s/79 " 5" · ~-3 9/23/79 CNL 5" 9/16/79 " 2 a 5" ~4~ease sign and return the attached copy as receipt data, · · K. J.'S~hlstrom North Engineering TKANSMITTAL # 398 I) ISTI(-I. l~,[i'i'ION North Geology I)r:i ]. 1 trig Eng. ).ianager R & I') Oeo]ogy State of Alaska ]~XXOl't Mob i ] (;ettv Sohio I'hill :i.i)s Chevron North Alaska District Post Office,"~"~× 380 Anchorage, .:as!ca 99510 Teiephone 907 277 5537 October 8, 1979 Reference: Enclosed is Directional Survey for the following .~RCO wel 1 ..' C I' co -"1 J_.~f.--~Y'T :'"'"'~ - _GEOL G~Ou ..s GEOl. STAT T~C STAT TFC ~ CONF~R~ Fl! F: ~//Piease data 9/4/79 Directional Single Shot Eastman l.~,~ipstock sign. and return the attached copy as receipt of K, J, Sahlstrom North~ngineering . . TRANSMI'TTAL # 397 DISTRIBUTION North Geology Drilling ~ng. Manager R & D Geology State o£ Alaska Mobil Getty Sohio Marat]~on Phillips Chevron .. 'i-,':i-::p!~:~:,:: .'-:"-.-" :!;"-" [:?2;' Octobez o, 1~,79 F. nc]osed a~-e Directional Surveys for the fo]lowing ARCO we-! i s: , - -, 9/1]/79 Gyroscopic Scient.:i_£Jc ]')]ri '1.] lng Con~roJs ~9 9/24/79 " Sperry-Sun i'//~!-~! 5 9/21/79 ~,iagnetic Hu]_tis]~o'~ Sper'r'y-Sun ~ease s:'-- and rettn~ the a~acl~,.fl copy as receipt of da-La.' K. J. Sah]strom North Euffineerin2 TK&NSSiITI'AL # 389 .. l)i SD',] !~,[ i'i' 1 ()N '].ins. ¢.!?,:',.age r Goo] SI:ate of Alaska Nor!h American Producing Division North Alask-'"~]strJct Post Office .... x 380 Anchors, ga, Alaska 99510 Te!aphor, a 907 277 5-.S3F September 17, 1979 -Reference' f. .... I-com~...~ i -corm I COreM I RFS eNO__! I ~ I ~'eN~ ~4 ENG ~- J GEOL ~ STAT TEC _ J STAT TEC I CONFER: :ILF: -Enclosed is a Directional Survey for the following'ARCO well' lle#3 9/6/79 ~,bgnetic ~-~ltishot ase sip and return the attached copy as receipt of data. Very truly yours, K. J, Smhlstrom North Engineering T_PCdNSMITFAL # 339 DISTRIBIJ~FION :~or un Geology Exxon D~-4 ] ] ino ,, , .... o mooi] ~g. b~anager Getty R & D Sohio Geology ~,brathon State of Alaska Phillips D & M Chevron Alaska Oil and Gas Conservation C~ssion Hoyle H. Hamilton C~ssioner Ben H. L~onran ~ ~ Petroleum Inspector September 11, 1979 B.O.P.E. Test - ARCO's WGI#3, Sec.2, TllN, R14E, UM Prudhoe Bay Unit ....Wedne~a~, Septem~ r 5 - I departed my hcme at 5:00 PM for a 5:30 PM shc~up and 6:30 PM departure via Wien Flt. #19 for Deadno~e arriving via Fairbanks at 8:55 PM. I proceeded to ~I~3 where 13 3/8" surface pipe was being run. Weather: +41°F, misting rain, light ~hnd. Thursday, September 6 - Inspection of Placid Oil's Prudhoe Bay State #1 was ccmpleted at 5:30 PM, the subject of a separate report. ~riday, Sept~ 7 - B.O.P.E. tests on ARED's WGI-#3 began at 3:30 AM and were ccmpleted at 6:00 AM with results attached. I departed Prudhoe Bay via ARCD d~arter at 1:00 PM arriving in Anchorage at 2:30 PM and at my hc~e at 3~00 PM. In su~r~, I witnessed successful B.O.P.E. test on AROD's WGI#3. Alaska Oil and Gas Conservation Commission Field Inspection of Blowout Prevention Equipment Inspector Date ~- '~- '7 ~ Operator Location: Sec ~P. T//.~R,f_gZ~M 0;~4 Drilling Contractor_ _~.~-~,./~ Rig #/~/ Location, General Well Sign_ General Housekeeping. Reserve pit Rig .. BOP}'.; Stack I No.J. Te:~t Pressure Annuta r Pil;e Rams Blind Rams Choke Line H.C.R. V~ Kill Line Check Val ACCUMULATOR SYSTEH__ Full Charge Pressure ~'~7~ff psig Pressure After Closure /.~-~D p$ig Full Charge Pressure Attain in' /. min~Osec, Remote Controls Kelly and Floor Safe~y Valw',~, Upper Kelly Lower Kelly / Bali Type / Inside BOP, / / Test Pressure ~--o~o Choke Manifold. No. Valves ~ No. flanges /2~> Adjustable Chokes Test Pressure Test Pressure / Test Pressu tiydrauically ol)erated choke / days and · est Results: Failures Repair or Replaceraent of failed equipment Inspector/Commission office notified. ! - Test Time //~h rs. to be made within Dis tribut ;' :,..'~ orig. - AO&(;CC cc. - Operator cc - Supervisor August 1, 1979 Re: Prudhoe Bay Unit WC-I #3 Atlantic Richfield Company Permit No. 79-49 Sur. Loc.: 493'S & 1159'W of NE cr Sec 11, TllN, R14E, UM. Bottomhole Loc.: 2680'S & 0'E of NE er Sec 2, TllN, R14E, UM. Mr. P. A. VanDusen District Drilling Engineer ARCO Oil and Gas Company P. O. Box 360 Anchorage, Alaska 99510 Dear Mr. VanDusen: Enclosed is the approved application for permit to drill the a ~bove referenced well. ~{ell samples, core chips and a mud log are not required. A directional survey is required. If available, a tape containing the d. igitized Io~ information on ail logs shall be submitted for copying except experimental logs, velocity surveys and dipmeter surveys. I~any 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 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may ~ 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. Mr. P. A. VanDusen Prudhoe Bay Unit WGI %3 -2- August 1, 1979 Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill, To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office a~equate advance notification so that we may have a witness present. Very truly yours, F. Oy$e ~. Hamilton Chairman of ~.¥ ORDER OF TH~ CO~%~,~I_SSJO~L Alaska Oil & Gas conservation comm~saion Enclosure Cc- Department of Fish & Game, Habitat Section w/o encl. Depar~ent of Environmental Conservation w/o/encl. Department of Labor; Supervisor, Labor Law Compliance Division w/o encl. ARCO Oil and Gas._,..Company Alaska Re~.~ Post Office .,ox 360 Anchorage. Alaska 99510 Telephone 907 277 5637 July 24, 1979 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject' WGI #3 WG I #4 Dear 'Mr. Hamilton.: Enclosed is our Application for Permit to Drill, the $100 filing fee, and the required survey plat for the above-menl~ioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAV: cs Enclosures ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form 10-401' REV. 1-1-71 la. TYPE OF WORK STATE OF ALASKA SUBMIT IN TRI, .rE (Other instructiom on reverse fide) OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN DRILL r'~ DEEPEN [--] b. TYPE OF WELL OIL GAS WELL [~ OTHER WELL F-] Gas Injection 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.0. Box 360 Anchorage, Alaska 995]0 SINGLE~ MULTIPLE [--3 4. LOCATION OF WELL Atsurface & Alaska 0il & G:~s i,,~i:j~ ~u~,,,,lis~,tt 493' S & 11 59' W of cr Sec 11, T11 N, R14E, UM. Anchorage At pro osed rod. zone (~ 26~0'~ & 0'E of cr Sec 2, TllN, RI4E, UM 13. DISTAlqCE IN MILES ~ DIRECT~ONZFROM NEAI~F_ST TOWN OR POST OFFICE* 9 miles North of Deadhorse, Alaska API #50-029-20385 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7.IF INDIAN, ALLOTTEE OR TRIBE NAME 8.UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. WGI #3 10. ,FIELD ~,ND POO~,_OR vruanoe uay w~¥%~rd Prudhoe 0il Pool SEC., T., R,, M., (BOTTOM HOLE OBJECTIVE) Sec 2, TllN, R14E, UM 12. 14. BOND INFORMATION: nE Statewide Su~ctyand/orNo. Federal Insurance Co. #80ll-38-40 ~anount $1 00,000 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, ff any) 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. :. 2680, .. 170Q' 16. No. OF ACRES IN LEASE 2560' 19. PROPOSED DEPTH 9640' MD, 8609'TVD 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 49' RKB 23. PROPOSED CASING AND CEMENTING PROGRAM 17. NO.ACRES ASSIGNED TO THIS WELL 8O 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START September 1, 1 979 SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SE'FI'lNG DEPTH Quantity of cement 32" 20" 94 H-40 80 250 sx. PF II to surface 17-1/2" 13-3/8" 72 MN-80 2700 Circ to 5urface-approx 5500 sx 12-1/4" q-.q/R" 47 g0&95 8800 +1000' cmt column on first staae nlllq 3013 q× on qocnnd qtaao 8-1/2" 7" 29 N-80 9640 Approx 350 'sk ..... Atlantic Richfield Company proposes todirectionallydrill this well to ±9640'MD (±8609'TVD) to produce the Sadlerochit zone. Logs will be run across, selected intervals. A diverter system will be used on the 17½" hole (sketch attached). A 13-5/8" 5000 psi RSRRA BOP stack wll be used thereafter to TD. The BOP equipment will be pressure tested each week & operationally tested each trip. A string of 7" 29# N-80 tubing, packer & necessary pro- visions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. Selected intervals within the Sadlerochit will be perforated and reported on a subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be used on all wireline work. The downhole safety valve will be installed and tested upon conclusion of the job. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. ff proposal is to drill or deepen directionally, give pertinent data on subs'~face locations and measured and true vertical depths. Give blowout preventer program. SIGNED.~*~* 4.24' I hereby certify tha~ge~Foregoing is True and Correct DATE 7/18/79 TITLE District Drlg. Engr. (This space for State office use) SAMPLES AND CORE CHIPS REQUIRED [] YES ~NO mREcrtONAL StmVEY REQUIRED )8~.s [] NO CONDITIONS OF APPROVAL, IF ANY: MUD LOG [] YES ~!~k,NO OTHER REQUIREMENTS: ~LP.I. NUMERICAL CODE ._~'o - o z rd- 2 oj g.5- PERMIT NO. 7~-- ~"~ APPROVAL DATE r/ ' ~ . - --~~~.--e-~ *See Instruction On Reverse Side BY ORDER OF THE C;vr~'a~.~v,~ August 1, 1979 DATE. 8/1/79 SURFACE DIVERTER SYSTEM 3 · 2. 3. 4. 20" Bradenhead 20" 2000 psi drilling spool 20" 2000 psi annular preventer 6" butterfly valves Protracted Section Line 1209 1184 1159 No. 4 1154 -~ CERTIFICATE OF SURVEYOR I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OFALASKA AND THAT THIS PLAT REPRESENTS AN. AS-BUILT SURVEY MADE BY ME OR UNDER MY SUPER- VI_~ION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. DATE -- SURVEY'OR -- AS-BUILT WELL No. I LAT 70° 19'42:.634" LONG. ' 148 °29' 58,597" I;5°26' WELL No. 2 LAT. 70° 19'4 1.476" LONG. 148029. 57.861" WELL No. 3 Z: a: LAT. 70° 19'40.321" LONG. 148°29~57.133" 2: I II 12 WELL No. 4 LAT. 70° 19' 39.170" 0 I II LONG. 148 29 56.399 r Y 5 972 0O2.90 X 684 985.72 Y 5971 885.82: X 685 OI 3.80 Y 5 971 769.08 X 685 O41.62 Y 5971 652.66 Y 6~5 069.67 Chonqed title REVISION ARCO No. AFE HVL No. ATLANTIC RICHFIELD CO. AS-BUILT WEST INJECTION SITE. WELLS 1,2,3 ~4 LOCATED IN PROTRACTED SECTION I I, T II N, R 14 E, U.M.t ALASKA PREPARED BY HEWlTT V. LOUNSBURY 8~ ASSOC. 72;5 W. 6TH. AVE.~ ANCHORAGE~ ALASKA DATE JUNE 1979 SCALE I"= CHKD. BY GDD FLD BOOK SURFACE DiVERTER SYSTEM 20" Bradenhead 20" 2000 psi drilling] spool 20" 2000 psi annular preventer 6" butterfly valves le CHECK LIST FOR NEW WELL PERMTTS Ck~pany Yes No the permit fee attached Is .......................................... 2. Is w~ll to be lOCated in a defined pool ............................. /~/< Remarks Lease & Well No. ,P~L~ Item Approve Date (1) Fee 3 Is registered survey Plat attached e e e ® 0 10. 11. 12. 13. 14. 15. 16. Is ~11 located proper distance frcm property line .................. /~ Is well located proper diStance frcm other w~lls ........ , ........... Is sufficient unde~icated acreage available in this pool ........... Is w~ll to be deviated ' ~/<. IS operator .the only affected party ..... ............................ Can permit he approved before ten-day ~it ..................... '. ,... Does operator have a bond in force .................. ' ................ Is a conservation order needed ...................................... Is administr tive approval needed Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... ~ (2) Loc. (3) mmtn. ~ . /¥ lq 17. Will surface casing protect fresh w~ter zones ....................... 18. 19. Will all casing give adequate safety in collapse, tension and burst.. {~.'~ Does BOPE have sufficient pressure rating - Test to ~ o psig .. ~;~__ Approval Reconmended: Additional Requirements: Geology: Engineering: Well Histow File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPE .N. DIX~ No Special'effort has been made to chronologically organize this category of information. .o DRESSER ATLAS T16 TAPE FORMAT _.~ -- !~E LAjZi6__TAPE_~T_ CONSISTS OF A HEADER RECQBD CONTAIN_lNG PERTINENT __I BELOW)__JEOLLO_~£D_ BY_ _~HE. DATA RECORDS , _ . _ ·OF IB_~_~O!.NT. ~MP_LES (AS. DEFINED BY THE HEADER RECORO) OF EACH CURVE, THE DATA FOR .Ct!g.V.E ! .... I_~ EOL_b~OWED. BY THE D~A ........... HE A~6RD SIZE_~HAY. BE COMPUTED BY THE FOLLOW~EQU6TION: WHERE. FEET = NUMBER OF SAMPLES OF EAC~ CURVE PER RECORD(~,E~ · F~ELD F~ELD DESCRIPTION POS~T~ON CHAR, ~ .OF BYTES* · ~ EPILOG CORPUTAT~ON NUMBER 1 ~ ..... FP ......... _ _ __ ................... 5 ..... 8~ . AN 80 · 3 UELL NA~E 85 16ff AN .... _ .... ~ ~ ......... _ ...... _ .. _ . p · 5 FILLER 167 168 .... 169 2~8 AN_ 80 * · 7 TAPE STARTING DEPTH 2~9 ....... ~_5~2 ............FP .......... ~ ..... *. ~' - 253 256 FP ~ __* · 9 DATA LEVEL SPACING 257 260 FP ~ * ER''' ......... · ~-:~.~ ~ ~A69~:/--. ~276 ' 8 * Ecg NUMBER 673 ~~, ~ " ~ ....................... 3 CURVES : :G ~L'~ ' ' .. -- LEVEL SPACING 0.5000 12 PLE~ ~.'EC '. '. i :::: ;: PAGE ARCO OIL AND GAS----.WGL.~ - _ 716 LI~A-RY DcC~675 PRUDHOE BAY---11-llN-l~+E .... NORTH SLOPE, ALASKA ....... CCL GR CNL ................... ..... 7:~8_ca_~o ~o_.oo _. o.2a ~5.oo _ -_ 7~.oo- ~ _~50 0.00 _,0.0~ q5~O0 _7~,50 , _0.09 __-0.25 ~5.00 ............................. 7as:,5o o,o~ _-o., sa -'- ~ ~'~ .......... ........ 738i_.50 ~__0. O0 0.~ ~5.00 7385,50 0.00 -0.05 ~5,00 7386.50 0,00 0.07 ~5,00 - 7-~ : ................... 7~87.50 0.00 0.~9 _~ ~_~.00 .:'- 738~5_0 0,00 0,22 ~5.00 7389,50 0.00 0,20 ~5.00 .-'- --o. - :-.-' ......... 7~5,50 0,00 rO,..~l ~5,00 . 7s~.:o ~.oo -~.~o ~,oo '- .. ' ............... _ 7~98,00 . .0',00 ',.-'0-27 .'00 _ 7398.50 0,00 -0.39 ~5,00 .... 7399.50 0,00 -0.~8 ~5,00 7~00,50 0,00 ~7,91 7~01,50 0.00 ~7,~8 ~3,50 .....: -- 7'.~ O~-':Y--:~:: :.0' OD -:--- '-~- -~.~'~~-'6~ 7ff02,50 0,00 ~,92 7~:. so o.oo ~7.9a ~,5o .................................... PAGE 2 CCL GR CNL ........................................... ~ 7~0_~. o 0 ___~0 ~ ~5.~5 35.~7 ......................... ~:~ oo ~o. :~ ~5, ~0 .... - ............................... 7~OA.O0 -O,Off ~6,05 35,69 ~~-~~ ~ :: :s ::~::~.: :: :>:::: :::~: : :: :: : ::: ~ ..................................... ..,.~ :: ::: :: ............ 7~~ -o.o~ ~7,~ 37.~ ......................... 7~I~,oo .-o..0~ ~5,~7 3a.18 ................................ 7~zz,oo -o,o~ ~,a~ ~6,~ ..................... 7~2,00 -0,0~ ~.~9 36.~0 ...................................... 7.z ,oo -o.o. ................................... 7~,oo -o.o~ ~.oo ~s.~ ............ 7~.oo -o.o~ ~l.e5 34.35 ~--~' 7-~i : ............................................. ~-~--~ . 7~21,00 -0,0~ ~6,63 35,~0 7~22.00 -0.0~ ~q.29 ~.72 .......................... '0.~.0.~:. · · ..~'.~, · ~ '~3,:.61~.. , ~ 7~23.00 -0,0~ ~5.37 3~.06 ~-~~-:::::'7'~ ............. ~ ............................. 7~25.00 -0,02 ~,78 ~6.~7 .......... 7426,00 -0,05 39,12 38.03 7~27.00 -0.39 39.22 38,66 7~28,00 -0,9~ ~0,59 $5,99 7q29,00 -0,0~ $9,80 35,1~ ................ _ ~ ...... YqSO,O0 '0,0~ 44,5~ PAGE 3 PRUDHOE BAY---ll-llN-l~E .... NORTH SLOPE~ ALASKA CCL GR CNL .__ %q3~, ~ __~Q5 g7,02 36.39 SS_SS ~ ~__ ~ 3:~, 5~ .... 9.5 35,32 7~37,50 -O.Oq qT.ql 37.0~ 7~38.5o -o.o~ ~5,z7 3~.9z 7q39.50 -0.0~ q~,29 32.98 7.~:~0,00-- ~0,0~-.: ~5,76~ .'. 33,31 7qqG,50 -O,Oq qq.78 32,01 7qq7,50 -O.Oq q6.05 32.9q 7qq9.50 -O.Oq qq,59 7~o.~o -o.o~ ~.~ ~.~5 _ _ -~ .............................. 7N51,50 -O,ON ~2,63 35,32 .......... = ~] .......... SY'S ..... ]-'S ..... i-i ........ 7452.50 -0.04 42.~ 3~.q6 ................- ~? = ..... ~00 .'---~?]]--0,0~.:. .....' ~-'34',02 ~--] -] ..... ]] ..... ]-].- ......................... 7q53.50 -O.Oq 44.10 3~,98 ....... ~ ..... ~gg .......................... . .......... 7~5~.50 -0,04 7q55,50 -0,0~ 45,95 35.57 ......... ~-- 6- .... S-'~ ...................................... PAGE 4 ..... _P_R~_U_D_H_QE__B_AY-__-_-_~:~-!_IN-14E--_--NORTH SLOPE, AJ~A_SKA CCL GR CNL .~ .... ~.:~---~~ :::,:~:,,::::::~-- : : :~: ,., ,~ :: ~F~~'-~' ~ ....................................... ....... ? q'.SZLO_O_____~__-- 0, 0~5 q 7 · 5 ! 3 5- 2. q: 7~60o00 -O°Oq, q3,80 34.24 7q63.00 -O.Oq ~q.59 33.80 7~6q.00 -O,Og ~6.05 35.10 7q65.00 -O.Og ~5,56 35,80 7q66,00 -0,0~ q~,g~ 36.06 7472.00 -0.0~ ~5.GG ~2.~l 7473.00 -0.0~ ~3.80 ~.5~ 747~,00 =0.0~ 44,59 7q75,00 -O,Oq qq.88 ~.09 ............................................. -o.o2 7~77,00 -O,Oq ~,90 ~5.2~ 7q78.00 -0,02 ~2.93 35.28 7~79.00 -0.0~ ~.80 7~80.00 -0.0~ ~2.~ 5~.09 ~~~ ~~:: ....................... : ~.:~ :: ~:. L' -: '. ~ :.: ::::: :::: ::: : : 7~81.00 -0.0~ ~1,76 55,~1 _ . PAGE 5 . . PR_U_BHO_E B~AY---II-llN-I~E .... NORTH SLOPE,_._~_A_I_A~_KA CCL GR CNL .............. 7q'82. 50 'O,Oq' ~7,12 55-80 :: ......F-_.-.-..- ......... 7~.~s.5o -o.o~ ~5.~7 ~G.~2 ............... ~ ..... ."-~.'."-ii - . ...... ?~B~.~o _..,o, o~ ~.BG ~.~B ........................... ~D_.so -o.o~ ~G._~ ~,~.Bo --'--;-~___'_ ;_i ....................... ~ ~__~L_~_ "';.~ _ ~.'ii ?4BG.~O -O.~G ~.~7 ~.S~ ........................ : CS-C--C7 ............ ~ -~-~-. C-' .. -'. ........................ -~_~ 7~88.50 -0.05 ~6.2~ ~.65 ........................... 7~89.50 -0.0~ ~5.q6 ................................ 7~90.50 -0.0~ ~q.~9 B~.91 ................................ 7~91.50 -0.0~ ~6.95 5~.95 -~T:--~ ............................................. ~ -~"-S; ~ --~~9~.50 '0' ~'~I6 ' ~.~7 ~..;.~,,.....~: o. : ................ 7~9~,50 -O.Oq q~,O0 35.8~ 7~99.50 -0,0~ ~3,32 36.8~ ~ '~0~-..0.0 '. 7500.50 -0.0~ ~-.59 ~5.95 ..~:~;~ .:~0.~..-~...~-~ .. ~ ~ ;~.T.~,~ "::~..~.~: ?~:~ :~ ~ ........................ 75o~.5o -o,o~ ~.s9 ~5.~7 --~T?:~:: ......................... 75o~.~o -o.o~ ~.oo ~5.e~ ............................ 7503.50 -0.0~ ~2.85 ~5.5~ 7504,. ..'~ 750q.50 -O.Oq q~.32 -----~--~ ............................................. ~5os.so -o.o~ ~.os ~.ea 7506.50 -0,0~ ~5,~2 ~-~ ~ ~ ~ ....~ -~?~? ?~. ...... ? ........................... ~ ........................... ~, 0 O ' - 0 · 0:~. ~ '54:,.50 .. PAGE 6 PRUDHOE_BAY--,I~-I~N-lq-E .... NORTH SLOPE, ALASKA CCL GR CNL ---~~'--~~--~ ~~~~~,,, ,:::; ,, , - ........................... · 5.0 · : .--..0 !so~oo _.. -o.o_~_~5.~.7 -rslo.oo ~o.o~ ..... 751~~o .~o~_ ~,~O -~!.' S~ .................... 7513,00 -0.0~ ~,59 31,83 ~7 ~~~ .. /~' '_.' ................ /-" 751~,00 -0.0~ ~5.56 31.87 ~ ....................... 7515,00 -0,0% %~,32 _ . - ................. 7516,00 -0,0% %~,61 ~5,76 ~ ~ : .~,,~.... :..:~.... ~.~:....:.:.. ~ ~: ....................... 7517,00 -0, )~ %~,ql ~%,g6 ~ ~. ...................................... -- -~ - __ ............... 752~.oo -o.o~ ~.~ ........... 752..oo -o.o~ ~7.~o ,~.~, 7525,00 -0,0~ ~3,80 33,2~ ;~-: 7526,00 -0.0~ ~,20 33,57 ........................... . ~ . 7527.00 -0.0~ ~5.27 33.87 7528.00 -O.Oq qq.59 33.65 .~ ,~0~7~--'~...' ?..~....., ~ .... :~'~ : - ........................................ 7529.00 -0.0~ ~1.56 32.72 7530.00 -0,0~ ~g,39 32.05 7531,00 -0,0~ ~3.12 32,39 7532.00 -0,0~ %1,~6 32,01 ---~:~?:~,~ ............................ PAGE PRUDHOE_BAY---1!-llN-lq-E .... NORTH SLOPE, ALASKA CCL GR CNL 75_s~. 5o -o.o4 ,+2 .,+,+ ~.39 753q,. 50 -0. Oq- 41.q-6 Z53"~. 50 -0,04 ~0.68 52.61 753~~2 33,28 7538.50 -0.04 43.02. 31__.90 7539.50 -0.04 43.90 31.16 75u, 0.50 0.02 q-4.00 32°76 I ~.~ :' - O~q:'. '. !.5i5~ -...' 3~:.-1 75q-2.50 -0.04 q-q-. 59 .-32.76 ~ ~- ... · .'~:.. ,.. ~, ~,~:~...~ ::.~.~'~]~i ~ ~ ~:~ ~ -~']i~::]~-T~?::."~:~.~''':'''-~:~.~__:_.~. ~ ?Sq-B.50 -O.Oq- 39.2,2 35.q-7 75q. 9.50 4.2.9_ ,.st::,. 32 7550.50 -o.o4 45.~.7 37.a4 755~,50 -0,04 q. 5,5G :38.10 '~ .. .5 , -- 7553.50 -0.04 ~2,95 56,15 7554,50 -0,02 q-3.51 :37.06, 7555.50 -o.o~ ~.6~ 7556.50 -0.0~ q-3.51 .35.84 75D7,50_ -0.0~ q. 5.07 :35.2/, 0.0:7- ........................................ PAGE ......... _A _I_L _A__ t~- _ ...... .7~_6._LIBRARY _ DCC¢~673 CCL GR CNL ......... 7_55 9_, O_Q -.0_. 75&Q,O0 ~O,Oq. q-5,66 .......... 75_6&,00 -0, Oq- q-q, O0 35,28 7563,00 -0.04 ~q.78 ~5,5~ 75B~.00 -0.0~ ~6,~ ~6,7~ 7565.00 -0,0~ g7,02 S7,05 7566,00 -0,0q ~6,5~ ~6.~2 -756&'50 ~-0.0~- · 7567.00 -0.0~ 7568,00 -O.Oq ~2.9~ ............. 757~.00 -0.05 39.ql 33.~1 ................ -::--]-T.~'7~7~ ...... ,50 ..... -_'-'0,07 -~--~ "' ~ ~0.,618~--~-~ -~ '' ~-~'~'~',05 ?'-~- .................................................... - 7575.00 -0.22 ~2.05 32.68 575,50. 0 7576.00 0.27 ~.00 $1.50 7577,00 -0,0~ ~5,66 .____. 757~,00 -0.0~ ~8,78 32,91 7579,00 -0,0~ ~9,76 11 000000 77:71777'?77 000000 11 000000 7777777777 000000 1111 O0 O0 77 O0 O0 1111 O0 O0 77 O0 O0 11 O0 0000 77 O0 0000 11 O0 0000 77 O0 0000 11 O0 O0 O0 77 O0 O0 O0 11 O0 O0 O0 77 O0 O0 O0 11 0000 O0 77 0000 O0 11 0000 O0 77 0000 O0 11 O0 O0 77 O0 O0 11 O0 O0 77 O0 O0 111111 000000 77 000000 111111 000000 77 000000 '77?777777? 77'7'7777777 77 77 7'7 77 77 77 77 77 77 77 77 77 5555555555 7777777777 000000 000000 5555555555 7777?77777 000000 000000 55 77 O0 O0 00 O0 55 77 00 O0 O0 O0 555555 77 O0 0000 O0 0000 555555 77 O0 0000 O0 0000 55 77 O0 O0 O0 O0 O0 O0 55 77 O0 O0 O0 O0 O0 O0 55 77 0000 O0 0000 O0 55 77 0000 oo 0000 O0 55 55 77 O0 O0 O0 O0 55 55 77 O0 O0 O0 O0 555555 77 000000 000000 555555 77 000000 000000 '? 777 777777 7 '777 '7 '7 '77 77 7'7 7 '7 77 7'7 77 '77 7'7 7 '7 77 '77 77 77 MONITOR*START*st~sUSERiKL10E34PChb JUL[10!0'?'570~71'79. *S~ART,*JOB SHIP SEQ, ,,:~848 [)ATk, 20-DEC-79 02:0b:53 *START* USER PCA.[. [10'~07,57007] JUB SHiP SEO 3848 DATE 20-DEC-'79 02:06:5.3 MONITOR 8W8 ,KLlOE34 JIJL~ '79. *STAR!']?* ' ( RR~gRRRR Illlll RR RR I1 RR R~ I1 RR RR i1 RR RR Ii RMRRRRRh I1 RRRRRRRR 1I RR RR ii R~ RR ii RR RR I1 RR RR 1I RR RR Illiii RR RR I111II t¥ YY Y¥ 000000 000000 11 000000 000000 11 00 O0 O0 O0 1111 O0 O0 O0 O0 1111 O0 0000 O0 0000 11 O0 0000 O0 0000 11 00 O0 O0 O0 00 00 11 O0 O0 O0 O0 O0 O0 11 0000 O0 0000 O0 11 0000 O0 0000 O0 11 O0 O0 O0 O0 11 O0 O0 O0 O0 11, 000000 000000 Illl 000000 000000 1111, 1.1 1,1 *START* USER PCA6 [10707,5700'7] dOB SHIP $~(} MONITOR SWS KLiOE34 JUL-79. *START* ' f"iLE: DS~KB:VERIFl.001<057>[,10707 57007j cREATED: PRINTED: 20-DEC-79 0~I0~I1,,1 OUgUE 8~l,'tCngS: /~"]hE:FORT / OPIgS:I /SPACING:I /LI~iT:76 /FOR~SINORNA6 3848 [)ATE 20;DEC-79 0:2:06:53 20-DEC- 19 02:0,4:24 SCHLUMBERGER COMPUTING CENTER 1071)7,57007 REEL HEADER LENGTH: 132 BYTES REEL NAME: P.C.A.L. SERVICE NAME: EDiT REEL CONTINUATION NUMBER: 0! PREVIOUS REEL NAME: C[]MME;NTS: LIS FORMAT CUSTOMER TAPE DATE: 79/12/20 TAPE HEADER LENGTH: 132 BYTES TAPE NAME: 57007 DATE: 79/1,2/20 SERV1CE NAME: EDiT TAPE CONTINUATION NUMBER: O1 PREVIOUS TAPE NAME: C[]MMENTS: UNIQUE WELL iDENTiFiCATION NUMBER IS 50-029-20385 TAPE COMMENTS CASING-DRILLER 9.875~i~8569/BIT SiZE 8.5/TXPE FLUID I.~IGNOSULP"UNAT'k/ DENS 10.6/ViSC ]4./PH il.O/FLUID ,LOSS 5.4 ML/RM 0.95(~'72 ~."/ RMF" 0.70@62 ~'/RMC ,N-A/ EOF FILE HEADER LENG'I'H: b2 BYTES FILE NAME: EDiT .001 MAXIMUM PHYS1CAL RECORD LENGTH: PREV1OUS F1LE, NAME: 1024 ~ETE$ WELL SITE I.NFURMATION RECGRD LENGTH Ct]MPAN WELL: FIELD: RANGE: SECTION COUNTY STATR: 184 B~TkS ATLANTIC HICHFiELD COMPANY WGI - 3 PRUDH.flE 11N 11 N. SL.[JPR ALASKA DATA f'[JRMA~I' 6?5CiFICATI[JN LENGTH: 610 SYTES ENTRY BLOCKS: ~YPE 0 SIZE REP CODE EN'I'R Y 1 66 0 DA~I'UM SPEC,iFICATION BLlOCKS: E,NTRY ,IC TIi:30L SVORD~ UN,ITS API ,API APi APi FI[,E# SIZE EXP p,R, OC SAM ,F~,,EP DEPT SHIFT 1 DEPT 2 SP Di, b 3 I L O D I b 4 IbM DiLl 5 LLBU Dlb 6 GR DIL 7 DT DiLl 8 GR CNIa 9 Chb~ CNb 10 DHHO 1~ DC 1, 1 NPH1 CNb 12 RBOB CNL 1,3 NRA"I' CNL 1 'q N C N,LI C N b 15 FCNL CNb F T () 0 0 0 0 q 0 0 I 68 0 0 ~ V 7 1, 0 0 0 4 0 0 1 68 0 0 OHMM 7 12 46 0 0 4 0 0 I 68 0 0 (]HMM 7 12 44 0 0 4 0 0 1 68 0 0 0 H M ~ ~7 22 8 0 0 4 0 0 1 68 0 0 GAP I,'7 31 ,32 0 0 4 0 0 I 68 0 0 U $ / 1~ ....7 52 32 0 0 4 0 0 1 68 0 0 GAPI 42 31 32 0 0 4 0 0 1, b8 0 0 I, N 4:2 28 1 0 0 4 0 0 1 O 8 0 0 G/C3 42 ,~,4 0 0 0 4 0 0 I 68 0 0 PU 42 68 3 0 0 4 0 0 1, 68 0 0 G/C3 42 35 1 0 0 4 0 0 1 68 0 0 C/C 42 42 I 0 0 4 0 0 1 68 0 0 C P S 42 ,34 92 0 0 4 0 0 1 68 0 0 CPS 42 :i{4 9'~ 0 0 4 0 0 I o8 0 0 S ' L , DEPTH 9582.000 9600,000 9500.000 9400.000 9,300.000 9'200.000 9100.000 9000.000 8900.000 8800.000 8700.000 MN~MON lC SP GR DRHO NCNb SP GR NCNL SP GR DRHU NCNb SP GR DRHO NCNL SP GR DRHO NCNL SP GR D R H O NCNL D R H O NC N b SP GR DRHO N C ,N 6 SP GR DRBO NCNL SP GR DRHO NCNb SP GR DRHO NCNb VALU -969. 151. O. 2150. -32. 140. 0. 2456. -65. 65. O. 3352. -33. 116. 0. 2250. -118, 31. O. 4612. -127. 29. '00 5260. -105. 37. '0. 4412. -77. 74. '0 · 2996. -52. 413. '0. 1766. -3"7. 261. 2096. -33. 22'1. 0. 1903. 250 875 043 000 469 250 009 000 5OO 75O OO2 000 438 563 021 000 375 578 004 000 250 1,41 014 000 625 531 01,4 000 375 375 01,3 000 500 000 008 000 188 500 010 000 500 125 032 000 MN KMON lC 1LD DT NPH I iLO DT NPHI ["'C Nb ILD DT NPH 1 ~CNL ILD DT NPH I ~CNL 166 DT N P H I FCNb 166 DT NPH i PC Nb ILD DT NPHI ~"CNL I. LD DT NPHI BCNL I 6 D DT N P H I F C N L I L D DT NPHI F C N b ILD DT NPHI FCNL VALU -999. 81. 31. 747. . 35. 827. 33. 96. 20. 1676. . 83. 34. 708. 60. 88. 12. 2908. 187. 89. 10. 3710. 77. 100. 13 2676: 26. 110. 2'7. 1194. . i 00. 43. 510. . 99. · 37. 643. . 105. 36. 594. 250 000 445 000 {44 750 400 5O0 125 375 508 000 762 375 033 000 ] 75 000 891 000 750 75O 498 000 063 000 O0 297 375 295 0 O0 1,19 563 799 250 203 375 6,46 500 043 188 572 500 MmEMONIC ILM GR 16~ 1LM GR IbM RHU8 I bM i LN GR R H O B 1 bM GR R,.HOB 1 bM GI~ R H O B GR l L M GR VALUE, -999.250 151.875 2.00'7 4.4~1 140.250 2.502 28.297 05.750 2.299 5. 543 11b.563 2.732 64.750 31.578 2.260 95.500 29.141 2.215 28.009 3'7.531 2.258 22.1,88 74.375 2.1,43 2 · 246 413. 000 2.5 31 8.508 201.500 2.371 5.156 221.125 2.426 MNEMONIC 668U CAb1 NRA'£ 6680 CALl NRAT bbSU CAb1 N R A T 668U CALL NRAT ,5680 C A,bl N RAT 6680 CALl N R A, T 6L8U CALl NRAT 668U C A :6 ,i N ,R A T 6680 C A,bl ,N R A T 668U C,AbI NBAT' b b 8 U CALl N R A T VAbU5 -999.250 9.805 2.941 5.375 9.82~ 3.1~0 31.328 8.625 2.11'1 7.168 9.b02 3.006 125.188 8.477 l.bO0 1, 3O. 500 8.531 i .443 55.281. 8.570 1.050 24.375 9.031 2.605 4.148 10.154 3.552 1,3.703 9. '72 '7 3.27 5 b.352 10. (,) O 0 3.2~0 DEPTB 8600.000 8500.000 8400.000 8300.000 8200.000 8100.000 8000.000 7900.000 7800.000 7700.000 7600.000 MNEMONIC SP GiRl DRHO NCNL GR DRHO N C ,N L 8P DRHU ,N C N L DRHO NCNL DRHO NCNb SP DRH(] NCNb SP DHHO NC NL GR DRHO NCNb GR DRHO NCN5 SP GR DRHU NCNb SP GR DRHO NCNb VALUE -28.688 97.625 -0.012 2938.000 -969.250 100,750 -0.609 1419.000 -969.250 -999.250 -0.516 1549.000 -969.250 -999.250 -999.250 1481.000 -969.250 -999.250 -999.250 16'74.000 -969.250 -999.250 -999.250 1836.000 -969.250 -999.250 -999.250 1751.000 -969.250 -999.250 -999.250 1791.000 -969.250 -999.250 -999.250 1606.000 -969.250 -999.250 -999.250 1698.000 -969.250 -999.250 -999.250 1568.000 ,MN EMU N IC iLO DT NPHI, 8'CNL I. LD DT NPHI FCNL ILD DT NPHI lbD DT NPHI ~'CNL iLD DT NP.Hi FCNb I. LD DT NPH I 8'C Nh I lad DT NPH1 ~CNb ILD DT NPH1 t.'CNL ILD DT NPHI iLD DT N PH 1 ~CNL ILD DT NPHI V A, L I,l E 8.055 84.750 2b.904 '1142.000 -999.250 -999.250 51.855 350.500 -999.250 -999.250 40.820 422.500 -999.250 -999.250 42.1,88 388.250 -999.250 -999.250 50.439 437.750 -999.250 -999.250 33.154 547.000 -999.250 -999.250 35.791 511.500 -999.25O -999.250 32.813 550.000 -999.250 -999.250 37.256 477.000 -999.250 -999.250 36.865 523.500 -999.250 -999.250 37.061 475.000 GR ILg R H [) b 1 L M R f4 t:.) B 1LM GR H H 0 B ILg H H (] B GR ~HOB IbM ~HLlS ILM GH VALUE 8.578 97.b25 2.ELl -999.250 100.750 2.291 -'999.250 127 . 438 2.3 '73 -999. 250 125.8 '75 -999. 250 -999.250 24.313 ,- 250 -999.250 '73.000 -999.250 -999.250 69.938 -999.250 -999.250 79.125 -999.250 -999.250 b7.938 -999.250 -999.250 65.750 -999.250 -999.250 71.b88 -999.250 M O N I C bLEU A,L :t RAT LL 8 U CALl N R A T 6680 CALl NRAT L.L 8 U C A L i N R A LLSO CALl NRAT bLSU CALI 6680 CALl LLBU CALl NRAT 6680 CALl NRAT bbSO CALl 6680 CAbI NRAT VALUE 1'1.219 10.031 2.65b -999.250 8.688 4.246 -999.250 8.719 3.b41 -999. 250 -999. 250 3. '717 -999.250 -999.250 4.168 -999.250 -999.250 3.221 -999.250 -999.250 3.367 -999.250 -999.250 3.203 -999.250 -999.250 3.445 -999.250 -999.250 3.424 -999.250 -999.250 3.43b DEPTH 7500.O0O 7400.000 7300.000 7200.000 7100.000 "7O00.000 6900.000 6800.000 6700.000 6600.000 6500.000 MNt~MON 1C SP GR DRHO NCNb SP GR DRHO NCNb SP GR DRHO NCNb SP GR DRHU NCNb SP GR DRHO NCNb SP GR DRHO NCNb SP GR DRHO NCNb GR DRHO N C N L SP [) R H O NCNb SP GR DRRO NCNb SP GR DRHO N C .N b V,AL -909 -999 -999 1561 -969 -999 -999 1574 -969 -999 -999 1482 -969 -999 -999 1434 -909 -999 -999 1, 306 -969 -999 -999 1383 -909 -999 -999 1252 -969 -999 -'999 1557 -969 -999 -,999 1287 -969 -999 -999 1526 -969 -999 -999 1441 UE .25O ·250 ·250 .000 .250 .250 .250 .000 .250 ·250 .250 .000 .250 .250 .250 .000 ·250 .250 .250 .00O .250 .250 .250 .000 .25O .250 .250 .000 .250 .250 .250 .000 .25O .250 .250 .000 .250 .250 .250 . O00 .250 .250 .250 .000 N N LM~.JN IC ILD DT NPMi ILO DT NPH 1 ~CNL iLO DT NPMI f CNL lED DT NPHI ~"CN L DT NPH1 ~ CNL 1LD DT NPH1 fCNb iLD DT NPH I ~'C N L 1LD DT NPH I ,[;" C NL ILD DT N P H i l.'CNb iLO ,DT NPHI FCNL 1LD D T N P H I F C N L VAL -999 -999 41 -999 -999 43 433 -999 -999 36 494 '999 -999 478 -999 -999 34 398 -999 -999 40 413 -999 -999 4:2 373 -999 -999 47 421 -999 -999 39 3,38 -999 -999 41 433 -999 -999 39 437 UE .250 .250 .016 .250 .250 ·250 · 45'7 ·LO0 .250 .250 ·670 .000 · 25O .250 .~j80 . 00 .25O .250 50 · 250 .250 .13'7 .500 .250 .250 . 2,36 .750 .250 .250 .119 . 750 .250 .250 . 89.3 .000 .250 .250 · 309 .500 · 250 .250 .8,44 .000 M N k ~10 N 1 C IbM GR 1 L M G~ IbM GR RiiOD G.R ibm GR GR RH[]B l b,tv{ GR R H [.).$ GR GR H ,H U S 1 L M GR R H 0 S GR R ,H (')B VAbUL -999.250 74.125 -999.250 -999.250 61.094 -999.250 -999.250 64.250 -999.250 -999.250 55.063 -999.250 -999.250 61.125 -999.250 -999.250 68.625 -999.250 -999. 250 6~.656 -999 · 250 -999.250 ,41.281 -999.250 -999.250 69.938 -999.250 5 -999.250 -999.250 46.375 -999.250 bhSU CA6I N LLSU ALI R A i' bUSU CAol NRA'I' CALl NRAT bbSO CALl ,N R A T LLSU CALl NRAT C A b I N R A T LLSU CALl. NRA"I' L l., 8 O CALl N R A T LI.,SU C A. h 1 NRAT L k, 8 U C A L 1, N R A '1" VALU~ -999.250 -999.250 3.~54 -999.250 -999.250 3.7~? -999.250 -999.250 -999.250 -999.250 3.279 -999.250 -999.250 3.275 -999.250 -999.250 3.604 -999.250 -999.250 3.72 1 -999.'250 -999.250 3.988 -999.250 -999·250 3.592 -999.250 -999.250 3.6'10 -99'9.250 -999.250 3.590 DEPT~ 6400.000 6300.000 6200.000 6100.000 6000.000 5900.000 5800.000 5700.000 5600.000 5500.000 5400.000 MN.E~}ON lC SP GR D R,H 0 SP GR DRHO NCNb SP GR DRHO ,bi C N L SP GR DRHO N C N L 8P GR D R H ti NCNL SP DRHO NCNb SP GR DRHO NCNb 8P GR DRHO NCNB SP GR DRHO NCNb SP DRHO NCNL SP GR DRHU NCNb VAL LiE: -969,250 -999,250 -999,250 1606.000 -969.250 -999.250 -999,250 1207.000 -969.250 -999.250 -999.250 1590,000 -969,250 -999.250 -999.250 1654.000 -969.250 -999,250 -999.250 1370,000 -969.250 -999,250 -999.250 1,344.000 -969.250 -999,250 -999,250 1322.000 -969.250 -999.250 -999.250 1425.000 -969.250 -999.250 -999.250 1303.000 -969,250 -999.250 -999.250 1491.000 -969.250 -999.250 -999.250 1387.000 ¸MN E N {] N i C D T 16 D DT NPH1 ~CNb ILD DT NPHi F C N L ILL UT N P H I ~"CNL ILD DT NPHI F'CNL ILD N P H I F'CNL ILl) DT NPHi FCNL ILD DT NPHI ~CNL ILD DT NPHI ~'CNL ILD OT NPHi fCNL ILL DT NPNI f'CNb VAL -999 -999 39 ,465 -999 '999 43 321 -999 -999 36 438 -999 -999 493 -999 -999 43 .366 -999 -999 47 340 -999 -999 46 326 -999 -999 39 4.36 -999 -999 44 374 -999 -999 47 344 -999 -999 49 408 U E .250 . '750 .250 .250 .262 . '750 ,25O .250 .816 .0 O0 ,250 .250 .035 .000 .250 .25O .799 .50O .25O .250 .021 ,000 .25O .250 .582 .500 .250 .250 . .~ 55 .000 .250 .250 .629 .500 .250 ,250 .510 .250 ,25O .250 .072 .000 M N E; M 0 N I C GR 1 GR ILM 1 LM GR RHOB GR RHOB ibm RHUB 1 BM GR ILM GR RHUB IbM GR ILM GR RHUB VALUE -999.250 36.469 -999,250 -999.250 54.156 -999,250 -999.250 46.406 -999.250 -999.'250 2~.813 -99 .250 -999,250 4'7.313 -999.250 -999.250 '77.063 -999.250 -999.250 51.469 -999.250 -999.250 2~.688 -99 .250 -999.250 32.031 -999.250 -999.250 57.409 -999.250 -999.250 g6.625 -999.250 M N E; tvl 0 N i C 668U CALl NRA".[' LbSU C AB I N R, I 6L8U C A61 N R A T 6680 CAL,1, NR.AT 6680 CALl N R A T ,6 b 8 U CALl N R A T 668 O CA6I N ,ti A 1' L68U CA6£ NRA'i' 668U CALl NRA1' L~,SU CALl N~AI' 6680 CALl N R A T -999.250 50 -999. 250 -999.250 3.7 '75 -999.250 -999.250 3,422 -999.250 -999.250 3.381 -999.250 -999.250 3.805 -999.250 -999.~50 3. 80 -999.250 -999.250 3.95'7 -999.250 -999.250 3.501 -999.250 -999.250 3.852 -999.250 -999.250 4.008 -999.250 -999.250 4.094 D~P~ 5300.000 5200.000 51,00.000 5000.000 4900.000 4@00.000 4'700.000 4600,000 4500.000 4400.000 4300.000 MN F:MUN IC DRHU NCNL GR DRHU NCNL SP GR DRHO NCNL SP GR DRHO NCNL SP GR DRHU NCNL SP GR DRHO NCNL 8P GR D R H 0 NCNb GR DRHO NC N L SP (;Iq D.RHO NCNL GR DRHO NCNL SP D Iq .H 0 NC.NL VALUE -969,250 -999.250 -999,250 1.i14.000 -969.250 -999.250 -999.250 1432,000 -969.250 -999.250 -999,250 1491,000 -969,250 -999,250 -999.250 1032.000 -969.250 -999.250 -999.250 1238.000 -969.250 -999.250 -999.250 1327.000 -969.250 -999.250 -999.250 1482.000 -969,250 -999,250 -999,250 1352,000 -969,250 -999,250 -999,250 12,35.000 -969.250 -999,250 -999,250 1126,000 -969,250 -999.250 -999,250 1138.000 MNk, MLJN lC ILL DT NPH I ~ CNL iLD DT NPH1 ~'C NL ILD DT NPH1 ~CNL ILL DT NPHI ~'C Nh ILl) DT NPHI FCNL ILL DT NPMi [~'C N h 1 LD D~ N~H1 ~'CNL iLD DT N P H I ['CNL 1PD DT NPH I ~ICNb ILD DT NPH I I~'C NL ,I LD OT NPH1 ~'CNL VAL -999.250 -999.250 48,730 390.000 -999.25O -999.250 42,578 411.500 -999.250 -999.250 42.627 ~26.000 -999.250 -999.250 bS.066 213.000 -999,250 -999,250 55.615 293.250 -999,250 -999,250 42,578 388.500 -999,250 -999.~50 46.484 ]91.000 -999.250 -999.250 44.385 342.000 -999.250 -999.250 43,896 341.250 -999.250 -999.250 58.203 228.500 -999.250 -999.250 49,658 292,500 biNkMiJN lC VALUE -999.250 24.938 -999.250 -999,250 27.206 -999.250 -999,250 33.500 -999.25O -999.250 22.53! -999.250 -999.250 49,094 -999.250 -999.250 55.500 -999,250 -999,250 45.344 -999.250 -999.250 48,1.88 -999,250 -999,250 34,4~8 -999,250 -999.250 53.025 -999.250 -999.250 40,625 -999,250 MN I~ M t3iq lC LLSU CALl N RAi' b.b8 O CAUl NRAI" LLSU CALl NRAY LLSU C,AL 1 NRAT bbSU C A L .I. NRA'f bL8U CALl NRA~.r L, L8U CALl, a R A T ,b L 8 U C A ,b 1 N RAT bL8U CALl, NRA L L 8 U CAL 1 N ,R A T LLSU CALl, N R h T VALUL -999.250 -999.250 4.074 -999.250 -999.250 3.740 -999.250 -999.250 3, 740 -999,250 -999.250 5 .-13 '7 -999,250 -999,250 4.45 3 -999.250 -999,250 3.738 -999,250 -999.250 3,951 -999,250 -999.250 3,838 -999,250 -999,250 3.811, -999.250 -999.250 4,59 -999,250 -999.250 4,125 DEPTH 4200.000 4100.000 4000.000 3900,000 3800.000 37 00.000 3600. 000 3500.000 3400.000 3300.000 3200.000 M N E M 0 N I C 8P GR DRHO NCNb SP GR DRHO NCNL SP GR DRHO NC NL SP GR [)RHO NCNb SP GR DRHO NCNb SP GR ,DRHU NCNL SP GR DRHO NCNb SP GR DRHU NCNb SP GR DRHO NCNL SP GR DRHO NCNL GR DRHO NCNL V AL UE -969.250 -999.250 -999.250 1330.000 -969.250 -999.250 3 81000 -969,250 -999,250 -999,250 1369,000 -969.250 -999.250 -999.250 1,284.000 -969.250 -999.250 -999.250 1433.000 -909.250 -999.250 -999.250 1183.000 -909.250 -999.250 -999.250 1315.000 -969.250 -999.25O -999.250 1398.000 -969.250 -999.25O -999.250 1322.000 -969.250 -999.250 -999.250 1322.000 -969.250 -999.250 -999.250 1.372.000 EMON lC ILD DT N P H i [~'CNL 1 LD DT N P H i i~'C N .1., I b D DT N P H i ~'C N L ILD DT NPHI ~'CNL 1, LD DT N P H 1 FCNb ,lbD DT NPHi, ~CNb ILD DT NPHI ~CNL I LD DT NPHI ~CNL lbD DT NPHi ~'CNL ILD DT NPHi P'CNL ILD DT NPH1 ~"CNL V A L l,j E -999.250 -999.250 48.242 373.000 -999. 250 -999.250 4"1 852 34 12so -999.250 -999.250 46.1,91. 412.250 -999.250 -999.250 45.752 325.000 -999.250 -999.250 54.199 310.750 -999.250 -999.250 46.826 315.500 -999.250 -999.250 54.932 297.250 -999.250 -999.250 47.461 377.000 -999.250 -999.250 45,117 362.000 -999.250 -999.250 50.879 283.250 -999.250 -999.250 50.195 284.000 NNENON iC I bM RfiOB I b M GR I6,M GR RHOB ILM GR RHOB I bM tk,HUB I b M R H (3 B GR 16M GR RHUW ibm IbM BHOB GR 'V,A, LUE -999,250 48.063 -999.250 -999.250 ,31.984 -999.250 -999.250 45.1,56 -999.250 -999.250 37.06,3 -999.250 -999,25'0 61,281 -999.250 -999.250 48.906 -999.250 -999.250 45.906 -999.250 -999.250 38.503 -999.250 -999.250 37.313 -999.250 -999.250 47.656 -999.250 -999.250 49.156 -999.250 M N g M (,,1N 1 C L :6 8 U C A.6 l N R A T 668 U C AL1 N R A T b68'U C A,B 1 N R A 'f 6 68 U CALl. N R A T 6hSU CAbl NRAT 668U C A61 N R A T b,68U CALl NRAT 668U CALl NRAT bLSU CALl NRAT L68U CALL NRA'[ 6hBu CAb1 NRAT VAbUg -999.250 -999.:250 4.051 -999.250 -999.250 4.027 -999.250 -999.250 3.938 -999.250 -999.250 3.914 -999.250 -999.250 4.3'75 -999.250 -999.250 3.971 -999.250 -999.250 4.414 -999.250 -999.250 4.004 -999.250 -999.250 3.871 -999.250 -999.250 4.195 -999.2b0 -999.250 4.150 DEPTH 3100.000 3000.000 2900.000 2800.000 2'700,000 2686.000 MNLMON1C SP GR DRHU NCNB 8P GR DRhO NCNL SP GR DRHO NCNL SP GR DRBO NCNB SP GR DRHO NCNB 8P GR DRHO NCNB VALUE -969.250 -999.250 -999.250 1268.000 -969,250 -999,250 -999,25O 1352,000 -969.250 -999.250 -999.250 1419.000 -969.250 -999.250 -999.250 1451.000 969 50 "999:~.50 -999.250 1209.000 -969.250 -999.250 -999,250 1228.000 MN LMtJN lC lhD DT NPH I fCNB DT NPHI ~CNL NPHi ECNL DT NPHI fCN~ iUD DT NPHi f'C Nb NPH I ~'CNL V -9 -9 3 -9 -9 3 -9 -9 -9 -9 3 -9 -9 2 -9 -9 2 AbUE 99.250 99.250 49.121 60,000 99,250 99,250 50,.~42 21,750 99,250 99,250 48.145 54.750 99.250 99.250 52.197 38,500 99,250 99,250 68.213 09,625 99.250 9g.250 63,818 58.500 MNkM{]N iC IbM RM(Jk~ IBM MM[lb IBM GR I~HDb ILL1 GR RH(]E GR RH(]B VALUE -999.250 44.81'3 -999,250 -999.250 40.375 -999.250 -999.250 27.406 -999.250 -999.250 32.500 -999.250 -999 250 18~203 -999.250 -999.250 28.391 -999,250 M NSIvlCim lC bl,SU CALl NRA £ LUSU CALl N RA'i' bLsU CALl N RA'f LLSU CALl N R A T LbSU CALl. NRA~I 668U CAbi N R A %' VAbU~ -999.250 -999.250 4,098 -999.250 -999,250 4.164 -999.250 -999.250 4.O43 -999.250 -999.250 4.266 '999.250 -999.250 5.145 '999.250 -999.250 4. 9012 SU,MMA,~' DJF DATA RE;CORDS NUMBER OF' REC,,L]RDS: 8'15 LENGTH 0~' RECORDS: 966 BYTES LENGTH OF LAST RECORD: 546 B'~TES ~" I h E T R,A i L E R ~b[,NGTH: 62 BYTES NEXT ["iLE NA{qk: 1024 OYTEiS E [1 F TAPE TRAILER LENGTH: 112 BYTES TAPE NAME: 5700'7 [)ATE: 79/1,2/20 SERV1CE NAME: TAPE CONTINUATION NUMBER: 01 NEXT TAPE NAME: COMMENTS: UNIQUE ~E]LL 1DENTIFICATIUN NUMBER iS 50-029-20~85
