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Home My WebLink About190-0307. 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-06 Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 190-030 50-029-22021-00-00 9240 Conductor Surface Intermediate Production Liner 8685 76 3450 8597 905 9212 20" 13-3/8" 9-5/8" 7" 8661 42 - 117 41 - 3491 38 - 8635 8349 - 9254 42 - 117 41 - 3491 38 - 8163 7914 - 8697 none 470 1950 4760 7020 none 1490 3450 6870 8160 8685 - 9156 7-5/8" x 7 x 4-1/2" L-80 36 - 8203 8206 - 8613 Structural 7" Baker S-3 Perm , 5-1/2"Baker FB-1 2212 / 2212 8080 , 8298 7678 , 7869 Bo York Operations Manager Dave Bjork Dave.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 202701 297680 35 35 3680 3653 324-071 13b. Pools active after work:PRUDHOE OIL 7" HXS-754 8080 / 7678 , 8298 / 7869 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 3:38 pm, Mar 27, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.03.26 13:38:27 - 08'00' Bo York (1248) WCB 2024-07-01 DSR-4/12/24 RBDMS JSB 040424 ACTIVITYDATE SUMMARY 3/3/2024 T/I/O= 2704/8/3 Gas Injector Tubing Wah (TUBING WASH/PICKLE) Pumped 10 BBLS 60/40 followed by 100 BBLS 180* Diesel down the TBG. Pumped 345 BBLS Fresh Water with .02% F-103 Surfactant, 2 hour soak, Pump 228 BBLS Fresh Water with .02% F-103 Surfactant for over flush. Pump 15 BBLS 60/40 down TBG for Meth Spear. DSO notified of well status. Well was put back on Gas Injection. FWHP's .25/2/2 Daily Report of Well Operations PBU WGI-06 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-06 Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 190-030 50-029-22021-00-00 ADL 0028302 9240 Conductor Surface Intermediate Production Liner 8685 76 3450 8597 905 9212 20" 13-3/8" 9-5/8" 7" 8661 42 - 117 41 - 3491 38 - 8635 8349 - 9254 42 - 117 41 - 3491 38 - 8163 7914 - 8697 none 470 1950 4760 7020 none 1490 3450 6870 8160 8685 - 9156 7-5/8" x 7 x 4-1/2" L-80 36 - 82038206 - 8613 Structural 7" Baker S-3 Perm , 5-1/2"Baker FB-1 7" HXS-754 8080 /7678 , 8298 / 7869 2212 / 2212 Date: Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com 904.564.4672 PRUDHOE BAY 3-1-2024 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 Samantha Coldiron at 2:00 pm, Feb 08, 2024 324-071 Digitally signed by Eric Dickerman (4002) DN: cn=Eric Dickerman (4002) Date: 2024.02.07 14:16:06 - 09'00' Eric Dickerman (4002) SFD 2/9/2024 DSR-2/13/24MGR13FEB24 10-404 *&:JLC 2/15/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.15 14:58:42 -06'00'02/15/24 RBDMS JSB 021524 Well Work Prognosis Well Name:WGI-06 API Number:50-029-22021-00 Current Status:Gas Injector Leg: Estimated Start Date:March 1, 2024 Rig:N/A Reg. Approval Req’d?10-403 Date Reg. Approval Received: Regulatory Contact:Carrie Janowski Permit to Drill Number:1900300 First Call Engineer:Dave Bjork Office: 907-564-4672 Cell: 907-440-0331 Second Call Engineer: Gas Injection Rate: ~290,000 Mscf/Day Injection Pressure: 3,650 psi Reservoir Pressure (Estimate): 3300 psi Program Objective(s): WGI-06 is a gas cap injection well that has demonstrated a decrease in injectivity. The well has not been water washed since 2020. 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 H2S Value N/A H2S Date N/A Work Desc AFE Date Engineer Phone Job Objective Pump Schedule Stage Fluid Type Pump Into Vol (bbls) Rate (bpm)Max Pres (psi) 1 Spear Methanol / Water TBG 10 1-3 2500 2 Solvent Diesel TBG 100 1-3 2500 3 Over-Flush Fresh Water TBG 600 see below 1800 4 Spear Methanol / Water TBG 15 1-3 1800 5 6 7 Detailed Procedure David Bjork (907) 564-4672 Well WGI-06 GI Water Wash 01/28/24 Increase well injectivity by performing a water wash. -Use 2 full uprights of fresh water mixed with 0.02% F-103 surfactant. Use 100 bbls of diesel from COTU. -Heat diesel to ~120*F -Order FreshWater to be at ~160*F -Freeze Protect contingent on WSL and ambient temp/seasonal pumping 1.) 10 bbl 60/40 MeOH/water spear 2.) 50 bbls COTU diesel (heated to ~120 deg F)at ~1 to 3 bpm. 3.) Pump 600 bbls of fresh water with 0.02% F-103 surfactant per following: a.) Pump 345 bbls of fresh water with 0.02% F-103 surfactant at ~5 bpm. Max pressure during this pumping can reach 1800 psi. Once 345 bbls has been pumped, shut-down pumps and let diesel soak across perfs for 2 hours -this should allow ~ 50 bbls of diesel to be pumped into perfs and a remaining 100 bbls to soak outside the perfs. b.) After 2 hour soak time, resume pumping at max rate/pressure (whichever is hit first) for next 255 bbls of fresh water with 0.02% F-103 surfactant. 4.) 15 bbls of 60/40 MeOH/water freeze protect. 5.) RDMO. Return well to gas injection. if well isnt going to be POI then FP See ~ pumping time schedule and notesbelow COTU diesel has xylene impurities left, treat with proper safety precautions Clear Well Work Prognosis Pump Time Fluid type vol (bbls)rate (bpm)Time (min) time (hours) methanol 10 1 10 0.17 diesel 100 1.5 67 1.11 FW flush 345 5 69 1.15 Soak 2.00 FW flush 255 5 51 0.85 methanol cap 15 1.5 10 0.17 5.44 Soak Time of Diesel/Xylene 1 2 Diesel/Xylene Notes Note 1 Note 2 Note 3 Hot fluids recommended: Note 1 Fresh Water and Surfactant Notes Note 1 Tubing has gas in it prior to pumping, any fluids pumped first will free fall. Soak time - keep at a minimum of ~2 hours; xylene works best with longer soak times (at least on asphaltenes) SBG treatments have a 3 hour soak time as well (just an FYI) Soak time is really a time for diesel/xylene to seep through the perfs vs pushing/rushing through Max pump rates creates turbulence and has contact with the tubing walls. Also cuts down on time Use COTU "diesel" only in these treatments if available. See Craig Graff explanation below. COTU technically can’t make diesel. On good days it can make Jet A or Heating Oil. Neither meet the specs for diesel. The reason they are different is that they have a lot more aromatics and sulfur in them than diesel. Road diesel and ULSD have most of those bad components taken out, which means that they can only dissolve straight chain hydrocarbons (paraffins), and not aromatics. These will make asphaltenes precipitate instead of cleaning them up.COTU “diesel” has enough things like xylene and toluene left in it to make it a pretty good solvent even for asphaltenes. A real refinery would take all of those out to be sold for higher margins in other products. If COTU "diesel"is not available, use other available diesel and xylene at a 50/50 mixture. As you read diesel in instructions below, can substitue with diesel/xylene If xylene is used for a 50/50 diesel/xylene mixture, heated xylene to 80 deg F or higher, use pump rates of 1 to 1.5 bpm. Injectivity results have improved when all fluids pumped are at warmer temps 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-06 PRUDHOE BAY UNIT WGI-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 WGI-06 50-029-22021-00-00 190-030-0 G SPT 7666 1900300 1916 3574 3576 3576 3573 65 88 87 88 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-06 Inspection Date: Tubing OA Packer Depth 115 2498 2475 2475IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS230623161526 BBL Pumped:2.3 BBL Returned:2.8 Thursday, July 27, 2023 Page 1 of 1             Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:190-030 6.50-029-22021-00-00 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 9240 9212 8661 8067 none none 7666 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 75 20" 42 - 117 42 - 117 1490 470 Surface 3450 13-3/8" 41 - 3491 41 - 3491 3450 / 5020 1950 / 2260 Intermediate 8597 9-5/8" 38 - 8635 38 - 8163 6870 4760 Production Perforation Depth: Measured depth: 8685 - 9156 feet True vertical depth:8206 - 8613 feet Tubing (size, grade, measured and true vertical depth)7" 26# L80 x 4-1/2" 12.6# L80 8067 7666Packers and SSSV (type, measured and true vertical depth) 7" Baker S3 Packer Liner 905 7" 8349 - 9254 7914 - 8697 8160 7020 12. Stimulation or cement squeeze summary: Intervals treated (measured): 5 bbls 50/50 methanol water, 50 bbls 120-deg diesel, 352 bbls .02% F-103 in fresh water, 228 bbls of .02% F-103 in fresh water, 2 bbls 50/50 methanol water Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0035810 34710 0 0 0 0 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: 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 measured8685 Sundry Number or N/A if C.O. Exempt: 320-217 5-1/2" Baker FB-1 Perm Packer 8298 7869 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Water Wash Operations shutdown Change Approved Program 5 8685 - 9156 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-06 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 36 - 8203 / 8298 - 8363 36 - 7786 / 7869 - 7926 7" HXS-754 SSV 2212 2212 By Jody Colombie at 9:09 am, Aug 07, 2020 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.08.06 18:50:39 -08'00' Bo York SFD 8/10/2020 8335 - 9240 DSR-8/7/202010AUG2020 SFD 8/10/2020RBDMS HEW 8/7/2020 ACTIVITY DATE SUMMARY 7/16/2020 T/I/O= 2700/66/55 Temp= 120* LRS Unit 76: Tubing Wash/Pickle. Down Tubing: 5 bbls 50/50 50 bbls 120* diesel 352 bbls FW w/ .02% F-103 surfactant 2 hr soak 228 bbls FW w/ .02% F-103 surfactant 2 bbls 50/50 DSO notified to POI. SV WV= closed MV SSV IA OA = OTG. Final Whp's=50/35/30 Daily Report of Well Operations PBU WGI-06 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:190-030 6.API Number:50-029-22021-00-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Field/Pools:9. Well Name and Number: ADL 028302 Property Designation (Lease Number):10. 8. PBU WGI-06 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 GSTORWAG 5 SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 9240 Effective Depth MD: 11. 7/13/2020 Commission Representative: 15. Suspended Contact Name: Brown, Don L. Contact Email: browd2@BP.com Authorized Name: Brown, Don L. Authorized Title:Petroleum Engineer 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:Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft): Size Total Depth MD (ft):Total Depth TVD(ft): 8685 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 2212 / 2212 Date: Liner 905 7"8349 - 9254 7914 - 8697 8160 7020 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 41 - 3491 41 - 3491 14. Estimated Date for Commencing Operations: BOP Sketch 42 - 117 Structural 6870 Proposal Summary 13. Well Class after proposed work: 7" Baker S-3 Perm Packer %DNHU)%3DFNHU 7" HXS-7546669 8685 - 9156 8206 - 8613 Tubing Size: 7-5/8" 29.7# x 7" 26# 4-1/2" Production 9212 8661 None None 42 - 117 470 13-3/8" 9-5/8" Contact Phone:+1 9075644675 Date: 4760 76 149020"Conductor 1950 / 2260 GINJ 5 Post Initial Injection MIT Req'd? Yes No Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 3450 3450 / 5020 Intermediate 8597 38 - 8635 38 - 8163 Address:P.O. Box 196612 Anchorage, AK 99519-6612 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. L-80 36 - 8203 / 8298 - 8363 By Samantha Carlisle at 1:56 pm, May 28, 2020 320-217 Brown, Don L.Brown, Don L. 2020.05.28 13:17:43 -08'00' 10-404 DSR-5/28/2020MGR28MAY20DLB 05/29/2020 XYesquired? Comm June 1, 2020 dts 6/1/2020 JLC 6/1/2020 RBDMS HEW 6/4/2020 10-403 Sundry Application for Well PBU WGI-06 PTD #190-030 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Expected Start Date: July 13, 2020 Current condition of well: Gas Injection Well, Operable, Online: Gas Injection Rate:251351 Mscf/Day Injection Pressure:3611 psi Reservoir Pressure (Estimate):3500 psi Program Objective(s): WGI-06 is a gas injection well with a slightly decreased injectivity over the past 5 years. The well has been subject to successful water washes in the past (Oct 2014 and August 2018) and are designed to dissolve salts and asphaltenes in the tubing and formation. The objective is to subject the well to another tubing water wash to once more increase injectivity and perform general maintenance on Gas Injection Wells. Proposed Program: Pump diesel followed by Fresh Water and Surfactant as per attached pumping template. 10-403 Sundry Application for Well PBU WGI-06 PTD #190-030 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Pump Schedule: 10-403 Sundry Application for Well PBU WGI-06 PTD #190-030 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Wellbore Schematic: MEMORANDUM State of Alaska Depth Alaska Oil and Gas Conservation Commission wcl-o6 DATE: Wednesday, June 12, 2019 TO: Jim Regg �(7 P.1. Supervisor `�e�� I f(jf 1(� SUBJECT: Mechanical Integrity Tests TVD BP EXPLORATION (ALASKA) INC. PTD 900300 WGI-06 FROM: Guy Cook PRUDHOE BAY UNIT WGI-06 Petroleum Inspector 1916 IA BBL Pumped: Ste: Inspector 2.2 OA Reviewed By: 4YRTST P.I. Supry ;Is2 NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT WGI-06 API Well Number 50-029-22021-00-00 Inspector Name: Guy Cook Permit Number: 190-030-0 Inspection Date: 6/7/2099 Insp Num: mitGDC190608161603 Rel Insp Num: Notes: Job was completed with a triplex, bleed trailer and calibrated gauges. ' Pretest Initial 15 Min 30 Min 45 Min 60 Min 1601 i9u1 3603 3603 3604 ' 3300 2492 2486 2486 54_ 62 63 ' 6464 Wednesday, June 12, 2019 Page 1 of I Packer Depth We wcl-o6 Type Inj G TVD 7666 Tubing PTD 900300 Type Test SPT ITest psi 1916 IA BBL Pumped: 2.2 BBL Returned: 2.2 OA Interval _ -- 4YRTST WIF P _. Notes: Job was completed with a triplex, bleed trailer and calibrated gauges. ' Pretest Initial 15 Min 30 Min 45 Min 60 Min 1601 i9u1 3603 3603 3604 ' 3300 2492 2486 2486 54_ 62 63 ' 6464 Wednesday, June 12, 2019 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Thursday,July 02,2015 Jim Regg P.I.Supervisor � 1 Zlts SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC WGI-06 FROM: Jeff Jones PRUDHOE BAY UNIT WGI-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT WGI-06 API Well Number 50-029-22021-00-00 Inspector Name: Jeff Jones Permit Number: 190-030-0 Inspection Date: 6/13/2015 Insp Num: mitJJ150616075122 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well WGI-06 Type Inj G ,T`1D 7666 Tubing 3515 3558 3560 3555 PTD 1 1900300 ' 'Type Test SPT Test psi f916 IA 117 2504 2495 2467 Interval f4YRTST P/F I OA 94 108 - 110 111 Notes: 1 well inspected,no exceptions noted Test result determined to be inconclusive per J.Regg Tit ltd e ��ISla(,z� SGANPIEU . . €E :3 r:r 1 Thursday,July 02,2015 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,July 02,2015 P.I.Supervisor ' \1�i. 71t/6 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC WGI-06 FROM: Jeff Jones PRUDHOE BAY UNIT WGI-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 56C-- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT WGI-06 API Well Number 50-029-22021-00-00 Inspector Name: Jeff Jones Permit Number: 190-030-0 Inspection Date: 6/13/2015 Insp Num: miUJ150616075530 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Weill WGI-06I)Type Inj G -TVD 7666 • Tubing 3560 3568 - 3564 _ 3559 - 3562 • r PTD 1 1900300 - Type Test SPT Test psi 1916 - IA 38 2503 , 2500 . 2518 2528 Inter Val 1,4YRTST IPF I OA 93 107 109i 110 111 Notes: 2nd attempt to witness MIT on this well today.Test result determined to be inconclusive per J.Regg --- -.A- fre55 i tT•2. a iC -f-L) SIC MAV3/4EV Thursday,July 02,2015 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: gg ��/q DATE: Wednesday,June 17,2015 Jim Re 75 P.I.Supervisor ( 14SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC WGI-06 FROM: Jeff Jones PRUDHOE BAY UNIT WGI-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry.�- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT WG1-06API Well Number 50-029-22021-00-00 Inspector Name: Jeff Jones Permit Number: 190-030-0 Inspection Date: 6/13/2015 Insp Num: mitJJ150616080734 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well WGI-06 - Type Inj G TVD 7666 - Tubing 3588 3557 - 3558 _ 3544 PTD 1900300 -1''Type Test SPT Test psi 1916 ' IA 479 2503 2451 - 2436 Interval 4YRTST PAF P V OA 98 106 - 105 103 _ Notes: 2 BBLS diesel pumped 3rc SCANNED Wednesday,June 17,2015 Page 1 of 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS' Scanned by: Beved~/,~./r.~Vincent Nathan Lowell TO RE-SCAN Notes: ~ 3 ~-~~ Re-Scanned by: Beverly Bren Vincent Nathan Lowell Date: Isl NOTScanned.wpct �' � I%yk THE STATE LI c'. a O1 /�� /_-`.� •1..'fid, o f f Tr 4, ,f-N�f ! ' 5�F`ry = `' 7;Ti-o— --- — 333 Vdesi Seventh Avenue GOVERNOR SEAN PARNE1,I, Anchorage, Alaska 99501 3572 r Main: 907.279.1433 LLA�s�� Fox. 907.276.7542 p JUL 2 sato 2 2Q�� Javier Farinez GPB GDE Lead PE 3° BP Exploration (Alaska), Inc. I 0 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU WGI-06 Sundry Number: 314-216 Dear Mr. Farinez: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this J(J -day of April, 2014. Encl. RECEIVED s STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR 0 3 2014 APPLICATION FOR SUNDRY APPROVALS �� 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Water Wash L • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ %. 190-030-0 • 3.Address: Stratigraphic ❑ Service 0 • 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-22021-00-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU WGI-06 . Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028302 • PRUDHOE BAY, PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9240 8685 • 9212 8661 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 39-119 39-119 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 8597 9-5/8"47#L-80 38-8635 38-8163.14 6870 4760 Production None None None None None None Liner 905 7"29#L-80 8335-9240 7901.57-8685.38 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths 7"Camco A-1 SSSV 2209',2208.91' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑ Exploratory ❑ Development ❑ Service ❑✓ - 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ Q ' WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true a , •rreGt to the best of my knowledge. Contact Javier Farinez /J Email Javier.Farinez@BP.Com Printed Name avier F.' ez Title GPB GDE Lead PE ' Signature Phone 564-5043 Date 4 /2_,/I LI Prepared by Garry Catron 564-4424 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. �j`Lk- 2\ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS MAY 1 0 2014 Spacing Exception Required? Yes ❑ No Ille Subsequent Form Required: D G 4 //� APPROVED BY Approved by: ' COMMISSIONER THE COMMISSION iDate: y--/0-/4/Form 10-403 Revised 10 2012 GRell li a I I for 12 months from the date of approval. Submit Form nd Attachments in Duplicate 1^'-F 4! 14- .0G 17/ .0p000Ln0000 Cp ao ao ao Cn ao 0O ao 00 0 = J J J Y J J J N Q O 0 0 0 0 0 0 0 0 Cd f` C`CO N CO CC) — O 0) W O N d) O ti N O N V' U y 0 0 0 0 0 0 0 0 0 0) ti CO N CC) CO 0) 0) • Tr CO — O N Nt CO CO CO CO CO 0 M N. CO CO CO a) N m tMO co") (3) — N- N 00) O CO 1 N. 0) CC) a Co Co M O ~ 0) CO 0, � 0) 00) CO '- Cr) O N- C) COONCr) N. N - - - E p a1 O Q ' 00D N C') ao Co N- O C3) _j - P . C Q 0 CO N QF— 0) CO M N- 0) COCO 0)) M U Q CO M N- M00) (N N M • • ID 0 0 0 CX) LO CO CO CO "T 0J Y a J J J N 0 co 4t N 4t CO CO CO • N N 0) - N 00 OO N O (C) M M (V 0 0 O to co ,1 T- 115 0 CO IO C Co � O CNI M 0) CO N. CU co 0) M ' LO N i J W CC Q c W O a ceu_ Z Z Z Z_ Z W W cC cc00 m c-m ZDDDDDD 00ZJfn (/) HF- I— F- 1 Perforation Attachment ADL0028302 Well Date Perf Code MD Top MD Base TVD Top TVD Base II WGI-06 5/26/11 BPP 8685 8738 8206 8252 WGI-06 5/26/11 BPP 8782 8844 82908344 _ WGI-06 5/26/11 BPP 8849 8884 8348 8378 WGI-06 5/26/11 BPP 8889 9049 8383 8521 WGI-06 5/26/11 BPP 9062 9085 8532 8552 WGI-06 5/26/11 BPP 9091 9097 8557 8562 WGI-06 5/26/11 BPP 9101 9126 8566 8587 WGI-06 5/26/11 BPP 9130 9136 8591 - 8596 WGI-06 5/26/11 BPP 9140 9156 8599 8613 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0028302 Well Facility Type MD Top Description TVD Top WGI-06 SSSV 2209 7" Camco A-1 SSSV 2209 WGI-06 PACKER 8077 7" Baker S-3 Packer 7675 WGI-06 PACKER 8298 5-1/2" Baker FB-1 Packer 7869 TREE=• 6-3/8"CAMERON WELLHEAD= MCEVOY Si NOTES: WELL REQUIRES A SSSV. DO NOT ACTUATOR= BAKER C WGI-06 PRF_EMERGENCY OA O FIELD FUEL ABOVE 3000 PSI. NEEDED FOR KB.ELEV= 60' BF.ELEV= , i KOP= 4000' 13-3/8"CSG,68#, — 71' 'I— Max Angle= 31°@ 9200' K-55,ID=12.415" Datum MD= N/A I I 2199' —7"CAMCO DB-6 NIP, ID=6.00" Datum TVD= 8800'SS 13-3/8"CSG,68#, L-80,ID=12.415" H 3491' , 7-5/8"TBG-IPC,29.7#,L-80 VAM TOP HC, H 7979' 1 .0459 bpf,ID=6.875" .....—.------- -1-17"8036' OTIS R NIP,ID=5.963" X 8067' H 9-5/8"X 7"BKR S-3 PKR, ID=6.00" Minimum ID = 3.725" @ 8350' 4-1/2" OTIS XN NIPPLE ' 8101' —17"OTIS R NIP, ID=5.963" ' 8172' H 7"OTIS RN NIP, ID=5.770" 7"TBG,26#,L-80 TCII, .0383 bpf, ID=6.276" H 8190' I-- —I 8190' —7"WLEG,ID=6.276" 8298' H 9-5/8"X 5-1/2"BKR FB-1 PERM PKR 8302' H BAKER SEALBORE EXTENSION 8312' H BAKER MILLOUT EXTENSION \ / 8318' H 7-5/8"X 4-1/2"XO, ID=3.995" TOP OF 7"LNR —{ 8335' ill 4-1/2"TBG,12.6#,L-80, .0152 bpf, ID=3.958" H 8363' 8350' H4-1/2"OTIS XN NIP,ID=3.725" 8362' H4-1/2"BKR SHEAROUT SUB 8363' I—4-1/2"WLEG,ID=3.958" 8348' —ELMD TT LOGGED 05/31/90 9-5/8"CSG,47#,L-80,ID=8.681" H 8635' L PERFORATION SUMMARY I REF LOG:FINAL CNP ON 03/13/90 ANGLE AT TOP PERF:30 @ 8685' Note:Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8685-8738 0 05/30/90 3-3/8" 4 8782-8844 0 05/30/90 I 3-3/8" 4 8849-8884 0 05/30/90 3-3/8" 4 8889-9049 0 05/30/90 3-3/8" 4 9062-9085 0 05/30/90 I 3-3/8" 4 9091-9097 0 05/30/90 3-3/8" 4 9101-9126 0 05/30/90 3-3/8" 4 9130-9136 0 05/30/90 I 3-3/8" 4 9140-9156 0 05/30/90 PBTD — 9212' .. ..../ 7"LNR,29#,L-80,.0371 bpf,ID=6.184" —1 9240' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/18/90 ORIGINAL COMPLETION 04/08/11 RCT/PJC PULL PXN PLUG(04/05/11) WELL: WGI-06 05/08/90 LAST WORKOVER 04/29/11 RCT/PJC SET PXN(04/10/11) PERMIT No: 1900300 12/16/10 DOYON141 RWO 06/01/11 RCT/PJC PULL PXN(05/27/11) API No: 50-029-22021-00 12/27/10 ?/JMD DRLG DRAFT CORRECTIONS 06/15/11 DB/JMD CORRECTED PKR ID @ 8067' SEC 11,T11 N, R14E,728'FNL&1109'FEL 01/04/11 MBM/PJC FINAL DRLG CORRECTIONS 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1,3,DBR,LHD,tAZ 01/15/14) General Information Well Name: WGI-06 Well Type: Injector API Number: 500292202100 Well Activity Classification: Conventional 4 Activity Description: Water Wash Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR,bopd: Job Type: Water Wash Estimated Cost, SM: AWGRS Job Scope: PARAFFIN/ASPHALTENE REMOVAL Other regulatory requirements? Sundry Form 10-403 Required? Yes Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Javier Farinez Contact numbers: 907-564-5043 907-947-5722 Well Intervention Engineer: Contact numbers: Lead Engineer: Javier Farinez Contact numbers: 907-564-5043 I 907-947-5722 Date Created: March 25,2014 Revisions(date,who,what changed): Current Well Status Information Recent WT or Inj Rate&Pressure 3/24/2014 N/A N/A 250.MMscfpd N/A N/A N/A 3,400 psi Current Status: Operable If inoperable or under evaluation, why? N/A Recent H2S (date,ppm) N/A 0 ppm iMaximum Deviation(angle and depth) 31° 9,200'MD Datum depth,ft TVDss 8,800'TVDss Minimum ID and Depth 3.725"©8,350' Reservoir pressure(date,psig) N/A 3,300 psi Reservoir temperature,F 134°F Shut in wellhead pressure 2,420 psi Known mechanical integrity problems(specifics) None Last downhole operation(date,operation) 7/20/2013.Integirty Test Most recent TD tag,(date,depth,toolstring OD) 5/26/2011.TAG TD @ 9121'SLM/9147'ELMD(CORRECTED),—9'OF FILL ABOVE BOTTOM PERF Comments,well history, Improve injectivity by dissolving salts and possibly asphaltenes in the tubing and formation. Diesel/Xylene washes have been used V. background information,etc: successfully in the past on the NGI/WGI/AGI gas injectors to improve injectivity. Well Intervention Details Suspected Well Problem: Oragnic deposition Specific Intervention or Well Objectives: 1 Increase well injectevity by cleaning the tubing and perforations 2 3 Key risks,critical issues: Mitigation plan: 1 2 3 Summary Step Service Line Activity 1 F Pump Water Wash as per schedule form 2 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) Expected Production Rates: BOPD MMSCFD BWPD FTP(psi): Choke setting: Post job POP instructions: Bring back well to injection Attachments- include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: • • L . C SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 ►7�1 PHONE (907) 279 -1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 4E.008 CANCELLED Mr. Doug Cismoski Wells Intervention Manager BP Exploration (Alaska) Inc. 21114 P.O. Box 196612 Anchorage, AK 99519 -6612 RE: Cancellation of Administrative Approval AIO 4E.008 Prudhoe Bay Unit WGI -06 (PTD 1900300) Prudhoe Bay Oil Pool Dear Mr. Cismoski: Pursuant to BP Exploration Alaska Inc. (BPXA)'s request dated February 20, 2012 the Alaska Oil and Gas Conservation Commission (AOGCC) hereby cancels Administrative Approval AIO 4E.008, which allows continued gas injection in Prudhoe Bay Unit well WGI -06. This well exhibited tubing by inner annulus communication that was manageable with period pressure bleeds. BPXA did not at the time propose repairing the well to eliminate the problem. The AOGCC determined that gas injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. On December 18, 2010, BPXA completed repairs to the well by replacing the production tubing. AOGCC witnessed a passing mechanical integrity test on May 13, 2011 for Prudhoe Bay Unit WGI -06. Well pressures monitored daily and reported to the AOGCC monthly as required by AIO 4E.008 confirm the tubing -inner annulus communication has been eliminated. Based on the information provided, Administrative Approval AIO 4E.008 no longer applies to operation of this well. Instead, gas injection into Prudhoe Bay Unit WGI -06 will be governed by provisions of the underlying AIO No. 4E. DONE at Anchorage, Alaska and dated February 28, 2012. PO sxn °' 4 _ Daniel T. Seamount, Jr. Cathy ' . Fo rster Jo °' Chair, Commissioner Commissioner Commissioner +a • • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, February 06, 2012 4:45 PM To: 'AK, D &C Well Integrity Coordinator' Subject: RE: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for January 2012 This is to memorialize my decision regarding reporting requirements for 5 injectors as discussed with you earlier today: PBU NGI -11 (PTD 1770800); PBU AGI -08 (PTD 1930330) Weekly reporting may be discontinued based on passing MITs (1/7/12 for NGI -11; 2/5/12 for AGI -08). Intent as 1 communicated to Ryan Daniel on 1/20/12 was that weekly reporting was interim step while waiting for diagnostics (suspended due to extreme cold temps); TIO pressures should continue to be reported on monthly injection well integrity report for both wells until decision is made regarding need for Administrative Approval. PBU AGI -05 (PTD 1930020) Weekly reporting (see NGI -11) may be discontinued based on stabilization of annuli pressures that began last week of December 2011. This well can also be dropped from the monthly injection well integrity report at this time. (Pit (PTD 190030) e "--- Existing Admin Approval (AIO 4E.006) should be canceled based on completion of workover. AOGCC will evaluate the need for a new Admin Approval for the shallow setting depth of packer associated with approved repair. PBU W -44 (PTD 1891000) Well may be removed from the monthly report based on passing MITIA (4/12 -11), no leak found with LDL (6/26/11), and stabilized annuli pressures exhibited during past 90 days while on injection.. Jim Regg FEB 1 3 al AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWeIIIntegrityCoordinator (abp.com] Sent: Sunday, February 05, 2012 10:09 PM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy 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 January 2012 Jim, Phoebe, and Guy, Attached is the January 2012 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. 1 • • «AOGCC In' Report 02 -12.zi » 1 p p Notes on wells: Added to Report: 11 -38A (PTD #1982160) Added per requirement of AA 4E.040 issued January 9, 2012. Taken off Report: MPC -10 (PTD #1850150) Was being evaluated for TxIA communication. IAP stabilized and well returned to Operable status. Please call with any questions or concerns. Thank you, Mehreen Vazir t. 'ilternate. {. urald Adttrp /t)°) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com 2 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 444 [cio- o 3 0 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission v 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of WGI Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from WGI that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • 1 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) WGI Date: 09115111 Corrosion Initial top of Vol. of cement Final top of Cement top Corrosion inhibitor/ I Well Name PTD # API # cement pumped cement off date inhibitor sealant date WGI 1790310 500292036900 Sealed conductor NA NA NA NA NA WGI -02 1790430 500292037900 Sealed conductor NA NA NA NA NA WGI-03 1790490 500292038500 Sealed conductor NA NA NA NA NA WGI-04 1790500 500292038600 Sealed conductor NA NA NA NA NA WGI-05 1900250 500292201500 Dust Cover NA NA NA NA NA WGI-06 1900300 500292202100 0.3 NA 0.3 NA 3.4 9/152011 WGI -07 1900400 500292203100 0.3 NA 0.3 NA 3.4 9/15/2011 WGI-08 1900490 500292203800 0.3 NA 0.3 NA 3.4 9/1512011 WGI -09 2061460 500292332700 _ 1.3 NA 1.3 NA 10.2 _ 9/15/2011 • • Pry( WG_ Regg, James B (DOA) p Th Igo - 030 From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] Sent: Friday, December 30, 2011 5:54 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: WGI -06 (PTD #1900300) AA Cancellation Post Rig Workover to Mitigate TxIA Communication Attachments: WGI -06 TIO 12- 30- 11.doc; WGI- 06.pdf; WGI -06 AA Approval 4E.008 05- 31- 06.pdf Tom, Injector WGI -06 (PTD #1900300) has an active Administrative Approval 4E.008 dated 05/31/2006 for slow TxIA communication. A rig workover has been performed to mitigate the TxIA communication. After the rig workover, an AOGCC witnessed MIT -IA to 4000 psi passed on 05/13/2011. An MIT -T against a plug at 8350' MD was also performed on 05/13/2011 in order to confirm integrity of the 9 -5/8 "casing between the packers at 8067' MD and 8298' MD at the request of Mr. Guy Schwartz. \. r i. � e �s � �e •- i�j ec;A-t �w � ss�ii b J d �1 r - i �1 e BP will pursue a cancellation request for the existing AA for TxIA communication. Will an active AA be required for well WGI -06 conditioning the MIT -T against the plug on an ongoing basis? BP will pursue a new AA pending your response. Attached are TIO plot, wellbore schematic and existing AA for reference: «WGI -06 TIO 12- 30- 11.doc» «WGI- 06.pdf» «WGI -06 AA Approval 4E.008 05- 31- 06.pdf» Thank you, Mehreen Vazir (11/e•r irate: (Ter<i1 J ;41ru jr/ n ) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com FED jc ui From: AK, D &C Well Integrity Coordinator Sent: Monday, May 16, 2011 5:27 AM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; Schwartz, Guy L (DOA)'; AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Chiwis, Robert Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C) Subject: OPERABLE: Injector WGI -06 (PTD #1900300) Tubing Integrity Restored with Rig Workover All, Injection well WGI -06 (PTD #1900300) passed a AOGCC witnessed MITIA to 4000 psi on 05/13/2011 after a rig workover was performed to mitigate IA repressurization. The passing MITIA confirms the existance of two competent barriers in the wellbore. The well is reclassified as Operable. Thank you, 1 • • Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 2 PBU WGI -06 PTD # 1900300 12/30/2011 TIO Pressures Plot We0_ W51 -06 4000- - • 3.000 t Tbp —IV-IA 2.400 - ---& oa. ooa + 000A On 1,000 - • 05 , 07/11 05/21)11 00 /04111 00 /10 /11 07/02/11 07/16/11 07/30/11 08/13/11 08/27/11 09/10/11 09/24/11 10/08111 10/22/11 1145111 11/19/11 12103/11 12/17/11 TREE = 6 -3/8" CAMERON • WELLHEAD = MCEVOY SAFETY N : WELL REQUIRES A SSSV. DO NOT ACTUATOR = BAKER C WG1-06 EMERGENCY FIELD FUEL GAS"*" *""NEEDED FOR KB. ELEV = 60' — KOP l t I 4000' 13 -3/8" CSG, 68 #, H 71' F I Max Angle = 31° @ 9200' K -55, ID = 12.415" Datum MD = N/A ' I 2199' H7" CAMCO DB -6 NIP, ID = 6.00" I Datum TV D = 8800' SS 13 -3/8" CSG, 68 #, L -80, ID = 12.415" H 3491' 1-Al 111 7 -5/8" TBG -IPC, 29.7 #, L -80 VAM TOP HC, H 7979' I .0459 bpf, ID = 6.875" ® , ,,, ..- ---") 8036' (-I 7" OTIS R NIP, ID = 5.963" I z S i 8067' H 9 -5/8" X 7" BKR S -3 PKR, ID = 6.00" I Minimum ID = 3.725" @ 8350' 4-1/2" OTIS XN NIPPLE 1 1 I 8101' H r OTIS R NIP, ID = 5.963" I ® ( 8172' I-17" OTIS RN NIP, 10 = 5.770" I 7" TBG, 26 #, L -80 TCII, .0383 bpf, ID = 6.276" H 8190' I i I 8190' I WLEG, ID = 6.276" 1 g 8298' H9 -5/8" X 5 -1/2" BKR FB -1 PERM PKR I 8302' -I BAKER SEALBORE EXTENSION I 8312' 1-1 BAKER MILLOUT EXTENSION I / 8318' H7-5/8" X 4-1/2" XO, ID = 3.995" I ITOPOF7" LNR H 8335' I ill I 8350' H4 -1/2" OTIS XN NIP, ID = 3.725" 8362' I- 14 -1/2" BKR SHEAROUT SUB I I4 -1/2" TBG,12.6 #, L -80, .0152 bpf, ID = 3.958" H 8363' I 8363' I-I -1 /2" WLEG, ID = 3.958" 411 ■ I 8348' H ELMD TT LOGGED 05/31/90 I 19 -5/8" CSG, 47 #, L -80, ID = 8.681" H 8635' PERFORATION SUMMARY I REF LOG: FINAL CNP ON 03/13/90 ANGLE AT TOP PERF: 30 @ 8685' Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 4 8685 -8738 0 05/30/90 3 -3/8" 4 8782 -8844 0 05/30/90 I 3 -3/8" 4 8849 -8884 0 05/30/90 3 -3/8" 4 8889 -9049 0 05/30/90 3 -3/8" 4 9062 -9085 0 05/30/90 I 3 -3/8" 4 9091 -9097 0 05/30/90 3 -3/8" 4 9101 -9126 0 05/30/90 3 -3 /8" 4 9130 -9136 0 05/30/90 3 -3/8" 4 9140 -9156 0 05/30/90 I PBTD H 9212' , 14 ,1 0 , , A'1 17" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" H 9240' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/18/90 ORIGINAL COMPLETION 04/08/11 RCT /PJC PULL PXN PLUG (04/05/11) WELL: WGI-06 05/08/90 LAST WORKOVER 04/29/11 RCT /PJC SET PXN (04/10/11) PERMIT No: '1900300 12/16/10 DOYON141 RWO 06/01/11 RCT/ PJC PULL PXN (05/27/11) API No: 50- 029 - 22021 -00 12/27/10 ? /JMD DRLG DRAFT CORRECTIONS 06/15/11 DB /JMD CORRECTED PKR ID @ 8067' SEC 11, T11N, R14E, 728' FNL & 1109' FEL 01/04/11 MBM/PJC FINAL DRLG CORRECTIONS 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) 1 MEMORANDUM • State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, August 08, 2011 TO: Jim Regg P.I. Supervisor j e r? 11 it SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI -06 FROM: Bob Noble PRUDHOE BAY UNIT WGI -06 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry ' NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT WGI - 06 API Well Number: 50 029 - 22021 - 00 - 00 Inspector Name: Bob Noble Insp Num: mitRCN110711135632 Permit Number: 190 - 030 - Inspection Date: 7/10/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. f — Type ype Inj. G TVD ' 7666 IA 260 2540 2540 2540 - Well P.T.D 1900300 • TypeTest_i_SPT I Test psi 2540 j OA 150 270 270 270 Interval INITAL _ P/F P Tubing 3500 3500 3500 3500 I_ — Notes: g■ r1. fet'a 4c+ 19/1 Monday, August 08, 2011 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 13, 2011 TO: Jim Regg 'P 14' n P.I. Supervisor �f SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI -06 FROM: Bob Noble PRUDHOE BAY UNIT WGI -06 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry -- NON- CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT WGI - 06 API Well Number: 50 029 - 22021 - 00 - 00 Inspector Name: Bob Noble Insp Num: mitRCN110711135632 Permit Number: 190 - 030 - Inspection Date: 7/10/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well WGI -06 - Type Inj. G TVD 7666 • IA 260 2540 - 2540 2540 - P. T. D 1900300 ;TypeTest SPT Test psi 2540 • OA 150 270 270 270 Interval 4YRTST P/F P , Tubing 3500 3500 3500 3500 Notes: !Ai,. • r€7 V` 1R (6 # , s ; ERA 46 oc ) JUL 1 201? Wednesday, July 13, 2011 Page 1 of 1 2Q2011 Not Operable Injector Repo Page 1 of 2 • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] Sent: Monday, July 04, 2011 4:44 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (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; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 2Q2011 Not Operable Injector Report Attachments: Not Operable Injector Report 2Q2011.zip Tom, Jim, Phoebe and Guy, Attached is the 2Q 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 202011.zip» *MAD JUL W Notes on wells: Removed from Quarterly Injection Report: 13 -09 (PTD #1811580): RWO repaired TxIA comm. On 04/30/11 END 3- 43/P -36 (PTD #1931700): Surface casing leak repaired with Brink platelets on 05/17/11 LGI -08 (PTD #1860570): Not Operable Producer that had been mismarked in BP system as a not operable injector thereby being generated to report MPF -92 (PTD #1981930): SI waiting for AOGCC MIT -IA that passed an AOGCC MIT -IA on 04/17/11 MPF -95 (PTD #1981790): SI waiting for AOGCC MIT -IA that passed an AOGCC MIT -IA on 04/17/11 P2 -16 (PTD #1931230): RWO repaired PC leak and TxIA comm. On 04/15/11 U -10 (PTD #1851970): TxIA comm. That was repaired with a tubing patch on 06/05/2011. Moved to Monthly Injector report pending AOGCC witnessed test i : - - -. WGI -06 (PTD #1900300): RWepaired TxIA comm. Well moved to Monthly Injector report pending AA ca lo Z -12 nce ( PT ati n #1891020): TxIA communication repaired with cement packer on 05/24/11. Added to Quarterly Injection Report: L -223 (PTD #2090990): MIT -IA failed on 05/01/11. MPS -07 (PTD #2020720): MIT -IA failed on 04/09/11 MPS -13 (PTD #2021140): Passed MIT -IA on 04/11/11. LTSI that requires AOGCC MIT -IA when put on production. V -227 (PTD #2091160): Exhibiting rapid IA repressurization. Classified as Not Operable on 06/20/11. 7/5/2011 Monthly Injection Report for GPB,•MA, Northstar, Milne Point & Endic000r May 2... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeII1ntegrityCoordinator ©bp.com] Sent: Sunday, June 12, 2011 5:14 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); AK, D &C Well Integrity Coordinator 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; Daniel, Ryan Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for May 2011 Attachments: AOGCC Inj Report 06- 11.zip Tom, Jim, Phoebe, and Guy, Attached is the May 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. « AOGCC Inj Report 06- 11.zip» Notes on wells: `{ Added to Report: WGI -06 (PTD #1900300): Moved from Quarterly Not Operable injection report to Monthly Injection Report after RWO Taken off Report: Y -24 (PTD #1861130): AA 3.023 cancelled on 5/27/2011 NGI -03 (PTD #1750610): Removed from report after being added for signs of IA represurization during proration 6/2010 Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 6/13/2011 Well WGI -06 Injection Plot Pressure vs. Rate TIO Plot o Well: WGI -060 ° o PTD #: 19003000 0 v v - Tbg AA: 4E.0080 0 IA Approval: 5/31/06E1 o OA Reason: Slow TxIA❑ 0 o 0 0 - - ❑ (.1 �, "' Monthly report a 4 -year MITIA 9/25/06 a 8 � IA P monitoring equipment — a 0 9 `" N Monthly Report w/flagged Y p 99 o IA bleeds❑ S § ❑ Tubing pulled and re -ran in December, ♦Last 90 days •Last Month r 2010. Passed AOGCC witnessed MIT -T o • , , , o j and MIT -IA to 4000 psi on 5/13/2011. 0 0 0 1 1 1 11/29/10 2/19/11 5/12/11 8/2/11 Injection Rate, MCFPD • Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 06/01/11 0 3,583 06/01/11 3,593 20 100 05/31/11 0 3,526 05/31/11 3,477 20 20 05/30/11 0 3,512 05/30/11 3,507 180 600 05/29/11 0 3,518 05/29/11 3,512 20 400 05/28/11 0 3,524 05/28/11 3,531 20 200 05/27/11 0 3,557 05/27/11 3,521 20 10 05/26/11 0 3,571 05/26/11 0 20 10 05/25/11 0 3,518 05/25/11 0 20 10 05/24/11 0 3,483 05/24/11 0 20 10 05/23/11 0 3,507 05/23/11 0 20 10 05/22/11 0 1,184 05/22/11 0 20 10 05/21/11 0 0 05/21/11 0 20 10 05/20/11 0 0 05/20/11 0 20 10 05/19/11 0 0 05/19/11 0 20 10 05/18/11 0 0 05/18/11 0 20 10 05/17/11 0 0 05/17/11 0 20 10 • 05/16/11 0 0 05/16/11 0 20 10 05/15/11 0 0 05/14/11 0 20 10 05/14/11 0 0 05/13/11 0 20 10 05/13/11 0 0 05/12/11 0 20 10 05/12/11 0 0 05/11/11 0 20 10 05/11/11 0 0 05/10/11 0 20 10 05/10/11 0 0 05/09/11 0 10 10 05/09/11 0 0 05/08/11 0 10 10 05/08/11 0 0 05/07/11 0 10 10 05/07/11 0 0 05/06/11 0 10 10 05/06/11 0 0 05/05/11 0 10 10 05/05/11 0 0 05/04/11 0 10 10 05/04/11 0 0 05/03/11 0 10 10 05/03/11 0 0 05/02/11 0 10 10 05/02/11 0 0 05/01/11 0 20 10 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 09, 2011 TO: Jim Regg R C P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI -06 FROM: John Crisp PRUDHOE BAY UNIT WGI -06 Petroleum Inspector Src: Inspector Reviewed By: Supry NON- CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT WGI -06 API Well Number: 50- 029 - 22021 -00 -00 Inspector Name: John Crisp Insp Num: mitJCr110517120224 Permit Number: 190 -030 -0 Inspection Date: 5/13/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well WGI -06 ';Type Inj. N TVD 7666 IA 20 4000 - 3970 , 3970 - P.T.D 1900300 TypeTest SPT Test psi 1916 - OA 0 0 10 10 Interval INITAL P/F P Tubing 2040 2620 2600 2600 Notes: Hot Oil rigged up on well pre injection for 4K test. 3.7 bbls pumped for test pressure. g ill Thursday, June 09, 2011 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 09, 2011 TO: Jim p � �� r / P.I. Supervisor ) //( SUBJECT: Mechanical Integrity Tests I BP EXPLORATION (ALASKA) INC WGI -06 FROM: John Crisp PRUDHOE BAY UNIT WGI -06 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT WGI -06 API Well Number: 50- 029 - 22021 -00 -00 Inspector Name: John Crisp Insp Num: mitJCr110517115754 Permit Number: 190 -030 -0 Inspection Date: 5/13/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well WGI -06 Type Inj. ' TVD 1 7666 _ IA T 0 180 160 140 H P.T.D 1900300 'TypeTest SPT Test psi 1916 ' OA 0 0 0 0 Interval INITAL p/F P / Tubing 200 4040. 3970 3960 Notes: Tubing test pre injection. They were rigged up on the well & thought it would be good to see any test on WGI. 6.8 bbls pumped for test. Tubing test with TTP. al JUN 1 3 ZUni Thursday, June 09, 2011 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 18, 2011 TO: Jim Regg (Reef � 5( Z l f ( P.I. Supervisor ( SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI -06 FROM: John Crisp PRUDHOE BAY UNIT WGI -06 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 0 NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT WGI -06 API Well Number: 50- 029 - 22021 -00 -00 Inspector Name: John Crisp Insp Num: mit3Cr110517115754 Permit Number: 190 -030 -0 Inspection Date: 5/13/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well wG1 -06 'Type Inj. N - TVD 7666 " IA o 180 160 140 1 900300 SP 1916 ' OA 0 0 0 P.T.D TypeTes Test psi � 0 Interval OTHER - P/F P ' Tubing zoo 4040 ' 3970 3960 - Notes: Tubing test pre injection. They were rigged up on the well & thought it would be good to see any test on WGI. 6.8 bbls pumped for test. Tubing test with TTP. Wednesday, May 18, 2011 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 18, 2011 TO: Jim Regg kC' (l `S l23/1/ P.I. Supervisor ( SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI -06 FROM: John Crisp PRUDHOE BAY UNIT WGI -06 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry l NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT WGI -06 API Well Number: 50- 029 - 22021 -00 -00 Inspector Name: John Crisp Insp Num: mitJCr110517120224 Permit Number: 190 -030 -0 Inspection Date: 5/13/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well WGI -06. Type Inj. N TV ' 7666 .- IA 20 4000 - 3970 3970 P T D I900300 TypeTest SPT Test psi 1916 OA 1 0 0 10 10 Interval OTHER pj P ' Tubing 2040 2620 2600 2600 Notes: Hot Oil rigged up on well pre injection for 4K test. 3.7 bbls pumped for test pressure. A 4E ,0022 "� " ; MI D MA Y 2 5 201 Wednesday, May 18, 2011 Page 1 of 1 OPERABLE: Injector WGI -06 (PTD #1900300) Tubing Integrity Restored with Rig Wor... Page 1 of 2 • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Monday, May 16, 2011 5:27 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Chivvis, Robert Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C) Subject: OPERABLE: Injector WGI -06 (PTD #1900300) Tubing Integrity Restored with Rig Workover All, Injection well WGI -06 (PTD #1900300) passed a AOGCC witnessed MITIA to 4000 psi on 05/13/2011 after a rig workover was performed to mitigate IA repressurization. The passing MITIA confirms the existance of two competent barriers in the welibore. The well is reclassified as Operable. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 �� ZOVi Pager (907) 659 -5100 Ext. 1154 �' -, From: NSU, ADW Well Integrity Engineer Sent: Friday, March 19, 2010 11:21 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA) <guy.schwartz @alaska.gov >'; 'Brooks, Phoebe L (DOA)' Cc: Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Area Mgr East (FSI /2 /COTU /Seawater); GPB, FSI OTL; GPB, FS1 DS Ops Lead; GPB, Wells Opt Eng; NSU, ADW Well Integrity Engineer; Quy, Tiffany; GPB, Optimization Engr; GPB, EOC Specialists Subject: NOT OPERABLE: Injector WGI -06 (PTD #1900300) Secured to evaluate balance /control line seals in wellhead All, Injection well WGI -06 (PTD #1900300) has been secured with a downhole plug. Attempts to change out the SSSV did not affect the rate of IA repressurization. Therefore a downhole plug was set to secure the well. The next step will be to evaluate the control and balance line seals in the wellhead. The well has been classified as Not Operable. Once the well is ready for injection again, another reclassification notification will be sent. Please let us know if there are any questions. Thank you, Anna Du6e, �. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659 -5102 7/5/2011 April 2011 AOGCC MIT Forms: NGI1(1750690), WGI -06 (1900300), END,4 (1861720), ... Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @bp.com] Sent: Tuesday, May 03, 2011 5:27 PM Qfq > /17(4 To: Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); Regg, James B (DOA) Cc: AK, D &C Well Integrity Coordinator Subject: April 2011 AOGCC MIT Forms: NGI -04 (1750690), WGI -06 (1900300), END 2 -34 (1861720), NS17 (2021690), P2 -28 (1950440), S -123 (2041370), V -100 (2010590), V -214 (2051340), W -42 (1880570), W- 44 (1891000), W -212 (2020660), Z -33A (1890050), MPF -92 (1981930) Attachments: April 2011 MIT Forms.zip Tom, Jim, and Phoebe, Please find attached AOGCC MIT forms for the following wells: GI -04 TD #1750690) ,/WGI -06 (PTD #1900300) END 2 -34 (PTD #1861720) NS17 (PTD #2021690) P2 -28 (PTD #1950440) S -123 (PTD #2041370) f V -100 (PTD #2010590) V -214 (PTD #2051340) W-42 (PTD #1880570) W-44 (PTD #1891000) W -212 (PTD #2020660) Z -33A (PTD #1890050) MPF -92 (PTD #1981930) MPF -95 (PTD #1981790) MPI -09 (PTD #2001030) MPS -07 (PTD #2020720) MPS -13 (PTD #2021140) «April 2011 MIT Forms.zip» Thank you, Mehreen Vazir (Altevv ?te: (,erald lvMtar'h)) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 90 7.659.51 02 Email: AKDCWeIIlntegrityCoordinator @BP.com 5/9/2011 • . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.recloOalaska.gov, doa.aogcc.prudhoe.bay alaska.gov; phoebe.brooksOalaska.aov ( v tom.maunderOalaska.00v OPERATOR: BP Exploration (Alaska), Inc. - ?irq / ? / ( FIELD / UNIT / PAD: Prudhoe Bay / PBU/ WGI DATE: 04/22/11 OPERATOR REP: Mehreen Vazir AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well WGI -06 Type Inj. N ` TVD ' 7,666' Tubing 2000 2260 ' 2240 2220 Interval O P.T.D. 1900300 Type test M Test psi 1917 Casing 2300 4060 , 3960 3940 ' P/F P Notes: 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 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) , Form 10 -426 (Revised 06/2010) MIT PBU WGI 04 22 11.xls • Page 1 of 1 Regg, James B (DOA) PT)S ]coo3oo From: Daniel, Ryan [Ryan.Daniel @bp.com] Sent: Wednesday, April 27, 2011 11:23 AM l I 1 t To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA) Cc: Schwartz, Guy L (DOA); AK, D &C Well Integrity Coordinator; Bill, Michael L (Natchiq) Subject: WGI -06 (PTD1900300) revised plan forward Attachments: MIT PBU WGI -06 04- 23- 11.xIs; MIT PBU WGI -06 04- 22- 11.xIs Guy et al, RE: Revised plan forward for WGI -06, Thank you for concurring with our revised plan forward with WGI -06. Here are the two MIT records for WGI -06 (PTD1900300) conducted on the 22nd and 23 of April 2011. • 22nd April 2011 MIT -IA passed • 23 April 2011 MIT -T passed The slope well integrity team will arrange to bring the well back online and conduct a state witnessed test in the near future. Let me know if you have any other questions relating to this well. Thanks Ryan Daniel Alaska Wells Integrity Team Leader r P,PR 2 8 ,all _well stock Integrity l ent and Compliance I ells Risk and °mations Management System (01 --Alaska L OP and Wells Site Technical 'r cctiis (STP) 545 M anat.;r c V of Change cc >1(5.) tir fin r[ -,.r,c at'gory Management and operations Advisor PP Alaska Well 907 564 5430 work 907 748 1140 mobile 907 346 3333 home r; aC .d!Vi V i .cirri 4/27/2011 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.rega @alaska.aov; doa.aogcc.prudhoe.bay alaska.gov; phoebe.brooks(a)alaska.00v; tom.maundert alaska.gov OPERATOR: BP Exploration (Alaska), Inc. T�, 4"(0-7() FIELD / UNIT / PAD: Prudhoe Bay / PBU/ WGI DATE: 04/23/11 OPERATOR REP: Mr lveson AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well WGI -06 l Type Inj. N TVD - 7,666' Tubing 3500 4000 3980 3980 ' Interval 0 P.T.D. 1900300 ..- Type test P Test psi 1917 Casing 80 120 120 120 P/F P ' Notes: Pre Rig Screening: OA 0 0 0 0 MIT -T to validate tubing and 9 5/8" Integrity between packers / Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 - 426 (Revised 06/2010) 2011- 0423_MIT_PBU_WGI- 06_MITT.xls • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.rega ialaska.gov; doa.aogcc.prudhoe.bay ialaska.gov; phoebe.brookst alaska.gov; tom.maundert alaska.gov OPERATOR: BP Exploration (Alaska), Inc. eQ 4(z1 q FIELD / UNIT / PAD: Prudhoe Bay / PBU/ WGI DATE: 04/22/11 OPERATOR REP: Mr Iveson AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well WGI -06 Type Inj. N ' TVD • 7,666' Tubing 2000 2260 ` 2240 2220 ' Interval 0 P.T.D. 1900300 ' Type test P Test psi ' 1917 Casing 2300 4060 • 3960 3940 ' P/F P Notes: Pre -RWO screening OA 0 0 0 0 MIT -IA to validate production casing by tubing annulus and packer integrity' Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi_ Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval I P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P /F_ Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) 2011 0422_MIT_PBU_WGI - 06.xls • • From: Schwartz, Guy L (DOA) Sent: Wednesday, April 27, 2011 10:03 AM To: Maunder, Thomas E (DOA) Subject: FW: WGI -06 (PTD1900300) revised plan forward Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Daniel, Ryan [mailto:Ryan.Daniel @bp.com] Sent: Wednesday, April 27, 2011 9:58 AM To: Schwartz, Guy L (DOA) Subject: FW: WGI -06 (PTD1900300) revised plan forward Good Morning Guy, Here is a copy of the two AWGRS well service reports from Little Red that detail the MIT -IA and MIT -T tests performed on WGI -06 on the 22 and 23 of April 2011. • The first report dated 4/22/2011 captures the MIT -IA test data JUL 1 2 2011 • • WSR WGI-06 22,x'2011 Microsoft Internet Explorer , 1 F_lle VII tew Fivartes D p I i k , ,. u . v 4 L j A dress iti http: f f apps2- alaska.bpweb.bp.com f awgrs- wellservicereportf default. aspx? id= CC219F390EAD4D9DADD2F1B9E8AFI WELL SERVICE REPORT WELL DATE JOB SCOPE DAY SUPV WGI-06 4/22/2011 RWO EXPENSE SALA COST CODE PLUS DAILY WORK NIGHT SUPV X4 00R7H E:PREPOST - D MIT MIT - T; LIQUID PACK IAIOA IVESON MIN ID DEPTH TTL SIZE KEY PERSON UNIT 0 " 0 FT 0 " LRS HALLIFAX LRS 70 DAILY SUMMARY TIIIO= vacl0l0 Temp =SI MIT IAto 4000 psi ***Passed*** Pumped 8.9 bbls diesel into IAw /jumper to TBG to pressure TxIA to 2000 psi. Pumped addition 1.6 bbls diesel down IA to reach test pressure. 1st 15 mins Iost 100 psi, 2nd 15 min Iost 20 psi, for a total loss of 120 psi in 30 min. Pumped addional 1.9 bbls diesel to pressure TIIA to 4200/4260. Started bleeding IAP to 0, TP fell to 3500 psi. ***Continued on 4 -23 -11 WSR*** LOG ENTRIES Init -> 0 0 0 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 21:00 Start ticket, Spot equipment 21:13 PJSM, RU, PT 22:12 .5 OIst diesel 10* vac 0 0 Start down IA 22:17 .5 2.4 " 0 2400 0 SD, Bleed press. to TBG 22:22 .5 2.4Ist 0 500 0 Start down IA 22:25 .5 4.4 0 2500 0 SD, Bleed to TBG 22:34 .5 4.4 /st 20 2200 0 Start down IA wl open EQ jumper 22:52 .2 8.9 " 2000 2300 0 SI jumper to TBG, keep pumping down IA 22:56 .4 10.5 2260 4060 0 SD, StartTest 23:11 2240 3960 0 15 mins (100) 23:26 2220 3940 0 30 mins (-20) 23 :28 EQ TBO and IA 23:35 .4 10.5 /st " 2760 2860 0 Start down 'Awl open EQ jumper 23:49 .4 12.4 4200 4260 0 SD, Line up and bleed back IA 23:57 3500 0 0 Shut bleed. 23:59 End ticket, ***Continued on next WSR*** Final - > I *3 Done intro* • The second report dated 4/23/2011 captures the MIT - test data • WSR - WGI -06 - 4/23/2011 - Microsoft Internet Explorer Fie Edit tew Favorites Bad` b - , g ,.„.J Search �,° f - Eavar i ieb - I - �; i► -- - +r - .{ - - 1�' s!�' ff's1 j A ress- 6Pubtp:jjapps2- alaska. bpweb. bp.comjawgrs- weliservicereportj default .aspx ?id= C828118ADD9646 Discuss F799- 584C2DIZI WELL SERVICE REPORT WELL DATE JOB SCOPE DAY SUPV WGI -06 4/23/2011 RWO EXPENSE SALA COST CODE PLUS DAILY WORK NIGHT SUPV X4- 00R7H- E:PREPOST -D MIT -T; MIT-IA; LIQUID PACK IAIOA IVESON MIN ID DEPTH TTL SIZE KEY PERSON UNIT 0" 0 FT , 0" LRS HALLIFAX LRS 70 DAILY SUMMARY "*"Continued from 4122111**" MIT T to 4000 psi ***Passed"* Pumped .7bbls diesel to pressure up TBG from 3500 psi to 4000 psi. 1st 15 mins lost 20 psi, 2nd 15 lost 0 psi. Bled backTP to 0 psi. Valve positions upon departure:MVx2,SSV= closed; IA,OA=open, operator notified. FWHP's =01010 LOG ENTRIES Init -> TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 00:00 01st diesel amb 3500 80 0 Start down TBG 00:50 min .7 " amb 4000 120 0 SD, Starttest 01:05 3980 120 0 15 mins (-20) 01:20 3980 120 0 30 mins (-0) 01 :22 Pass per Iveson, Bleed backTP and IAP to 0 02:00 Start RD, reinstall flange, PT IA flange to 3000 psi 02 :59 End ticket Final - ? im Dane 7 1 I i Loca Intranet • Alaska Wells Integrity Team Leader -- -Well stock Integrity Management and Compliance --Wells Risk and Operations Management System (OMS) - -- Alaska DWOP and Wells Site Technical Practice (STP) t t ells Management of Change (BMOC; --- Wireline /F -line Category Management and Operations Advisor BP Alaska Wells 907 564 5430 work 907 748 1140 mobile 907 346 3333 home ryan.deniel ^bp.com From: Daniel, Ryan Sent: Tuesday, April 26, 2011 5:50 PM To: Schwartz, Guy L (DOA) Cc: Reem, David C; Bjork, David; Kara, Danny T; AK, D &C Well Integrity Coordinator; Cismoski, Doug A Subject: Re: WGI -06 (PTD1900300) revised plan forward Guy, I have confirmed with Dave Bjork, the MIT -T was performed with a plug in the lower tail and was a PASS test. Let me know if you need any more information. Thanks Ryan Sent from my mobile... On Apr 26, 2011, at 15:54, "Schwartz, Guy L (DOA)" <guy.schwartzgalaska.gov> wrote: Daniel, One more thought popped into my head. Was there a charted MIT -T done against the plug PXN in the lower tubing tail at 8350' and ?? It would be good to have that section of the 9 5/8" casing tested (8067- 8298' md) and documented since the last RWO. I don't recall if any milling activites were part of the last RWO scope that could have caused any casing damage. Also, with the less than ideal • • cement bond it would be prudent to check 9 5/8" and verify it is jug tight where it will see injection gas pressure. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Daniel, Ryan [mailto:Ryan.Daniel @bp.com] Sent: Tuesday, April 26, 2011 3:18 PM To: Schwartz, Guy L (DOA) Cc: Reem, David C; Bjork, David; Kara, Danny T; AK, D &C Well Integrity Coordinator; Cismoski, Doug A Subject: WGI -06 (PTD1900300) revised plan forward Good Afternoon Guy, BP Exploration Alaska Inc seek the commissions concurrence on a revised plan forward for WGI -06 (PTD1900300). As discussed earlier today the well passed a pre rig MIT -IA on 4/22/2011. Please find the MIT -IA record completed by our well integrity coordinator (WIC) attached. Based on this passing test we propose bringing the well back online, and conducting a state witnessed MIT within 5 days when the well is stable. Please advise, Thank you Ryan Daniel Alaska Wells Integrity Team Leader --Well stock Integrity Management and Compliance -- -Wells Risk and Operations Management System (OMS) -- Alaska DWOP and Wells Site Technical Practice (STP) -- -Wells Management of Change (BMOC) - -- Wireline /E -line Catcgoiy Management and Operations Advisor BP Alaska Wells 907 564 5430 work 907 748 1140 mobile 907 346 3333 home an.daniel@bp.com • • sirof[E LELAsEn SEAN PARNELL, GOVERNOR �+ 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 a Engineering Team Leader D 0� BP Exploration (Alaska), Inc. V V P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU WGI -06 Sundry Number: 311 -095 Dear Mr. Reem: t liD MAC Lu'd Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 3 a day of March, 2011. Encl. STATE OF ALASKA =' I t� t, ,f CJ \C) . ALASKAL AND GAS CONSERVATION COMMIS 4 y`'R 14 2 , ii; - G APPLICATION FOR SUNDRY APPROVAL 2M' `r-,..?9- // 20 AAC 25.280 VIA 2 TO & Gm* Cana_ Commission 1. Type of Request: ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool - ® Repair Well ❑ Change Approved Program ❑ 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 190 - 030 3. Address: - .1 Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 029 - 22021 - 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 -06 - Spacing Exception Required? ❑ Yes 0 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): 9240' - 8685' - 9212' 8661' 8350' None Casing Length Size MD TVD Burst Collapse Structural Conductor 119' 20" 119' 119' 1490 470 Surface 3491' 13 -3/8" 3491' 3491' 3450 1950 Intermediate 8635' 9 -5/8" 8635' 8163' 6870 4760 Production Liner 905' 7" 8335' - 9240' 7902' - 8685' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8685' - 9156' 8206' - 8613' 7 - 5/8 ", 29.7# x 7", 26# L -80 8190' MD Packers and SSSV Type: 9-5/8" x 7" BKR S -3 packer Packers and SSSV 8067' MD / 7666' TVD 9-5/8" x 5-1/2" Baker FB -1 PERM packer MD (ft) and TVD (ft): 8298' MD / 7869' 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: April 15, 2011 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas . ® GINJ ❑ GSTOR ❑ Abandoned ❑ WAG ❑ SPLUG ❑ Suspended Commission Representative: 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Bjork, 564 -5683 Printed Name David Reem Title Engineering Team Leader Prepared By Nam&Number. Signature J; C, /2 % �h/1 Phone 564 Date 4 1 i1 Elizabeth Barker, 564 -5674 Commission Use Only Conditions of approval: Notify Commission o that a representative may witness �1 t i X G, Sundry Number ;,/ ❑ Plug Integrity ❑ BOP Test 11Mechanical Integrity Test ❑ Location Clearance - 4pao Ps' (SOP 1;:s Other. A /; S t ( n -r ) z5OO Ps: Subsequent Form Required: / 6- l o L1 APPROVED BY /3o 1 1 Approved By: ' COMMISSIONER THE COMMISSION Date 3 Form 10-4 -a ` , . I. riis 3 1 o 7 e 3 -Z$ / Submit In Duplicate ORIGINAL f • • • - bp GP g WGI -06 Rig Workover Scope of Work: Repair TxIA communication. Pull 7 - Tubing. Mill and retrieve the packers. Test the casing and install new 7- x 4 - injection completion. MASP: 2,460 psi Well Type: Gas Injector Estimated Start Date: April 15 2011 Production Engineer: Bob Chivvis Intervention Engineer: David Bjork Pre -rig prep work: S 1 Clean up the original packer tailpipe and pull the PXN plug if possible C 2 Lay in sized salt pill and 100ft cement plug in the 7" liner, circulate the tubing to 9.8 -ppg brine. test the salt/cement plug to to 1,000 -psi Proposed Procedure: 1. MIRU Nabors 7ES. ND tree. NU 4 Preventer BOPE with annular, 7- fixed rams, blind / shears," mud cross and 3 - /2" 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. Mill and retrieve the lower packer. 5. RIH with a 7" RTTS and test the casing and liner lap to 4,000 -psi for 30 charted minutes. - 6. Install a test plug and change the lower VBR's to 7" fixed rams. Test the fixed rams to 4,000 -psi. 7. Run 7 29.7# L -80 VamTopHC IPC x 7" 26# L -80 VamTopHC injection completion with BAL -O • SVLN. 8. Displace the IA to completion fluid, freeze protect and set the packer. • 9. Test tubing and IA to 4,000 psi. 10. Set TWC. ND BOPE. NU and test tree. RDMO. • Post-rig work: S 1 Pull isolation sleeve, Pull Ball -n -Rod, pull RHC seat. C 2 Clean out cement plug and salt pill S 3 Set SCSSSV. F 4 Post RWO AOGCC MIT -IA TREE = 6 CAMERON • VV G 1-0 6 0 WELLHEAD = MCEVOY ACTUATOR = BAKER Final As -Built RWO KB. ELEV = 60' BF. ELEV = KOP = 4000' 13 -3/8" CSG, 68 #, -I 71' f - Max Angle = 31 @ 9200' K -55, ID = 12.415" Datum MD = N/A ' 1 I 2199' 1- 7" CAMCO DB -6 ID = 6.00" Datum TVD= 8800' SS 13 -3/8" CSG, 68 #, L -80, ID = 12.415" H 3491' I-- 17-5/8" TBG -IPC, 29.7 #, L -80 VamTopHC 1-1 7,978' I ' I 8,036' IH 7" OTIS R NIP, ID = 5.963" I j, 1 8,067' H 9 -5/8" X 7" BKR S -3 PKR, ID = 6.059" I 17" TBG, 26 #, L -80, TC-II I-J 8,117' I 1 8,101' H 7" OTIS R NIP, ID = 5.963" 1 8,171' I- 7" OTIS RN NIP, ID = 5.770" I ;j / 1 8,189' H 7" WLEG I i �• g e 8298' H 9 -5/8" X 5 -1/2" BKR FB -1 PERM PKR ( 8301' I-I BAKER SEALBORE EXTENSION I 8311' I-J BAKER MILLOUT EXTENSION I 831T H 7-5/8" X 4-1/2" X01 TOP OF 4 -1/2" TBG -IPC H 8318' I 'TOP OF 7" LNR H 8335' 1 - 8350' I- 14 -1/2" PXN PLUG (03/15/10) 1 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 8635' 1 8350' �4 -1/2" OTIS XN NIP, ID = 3.725" 836T H 4 -1/2" BKR SHEAROUT SUB W/WLEG I I4 -1/2" TBG -IPC, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 8363' I---- I 1 8363' H 4 -1/2" TUBING TAIL PERFORATION SUMMARY 1 REF LOG: FINAL CNP ON 03/13/90 ANGLE AT TOP PERF: 30 @ 8685' 1 Note: Refer to Production DB for historicalperf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 4 8685 -8738 0 05/30/90 3 -3/8" 4 8782-8844 0 05/30/90 1 3.3/8" 4 8849 -8884 0 05/30/90 3 -3/8" 4 8889 -9049 0 05/30/90 3 -3/8" 4 9062 -9085 0 05/30/90 3 -3/8" 4 9091 -9097 0 05/30/90 1 3 -3/8" 4 9101-9126 0 05/30/90 3 -3/8" 4 9130 -9136 0 05/30/90 3 -3/8" 4 9140 -9156 _ 0 05/30/90 PBTD I 9212' "WAY 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" 1-1 9240' Wh't.'0.■ DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/18/90 ORIGINAL COMPLETION WELL: WGI-06 05/08/90 LAST WORKOVER PERMIT No: 1900300 12/16/10 DPF Doyon 141 RWO API No: 50- 029 - 22021 -00 SEC 11, T11 N, R14E, 3169.9' FEL & 4988.09' FNL BP Exploration (Alaska) WELLHEAD 6 -3/8° CAMERON • W G I -0 6 • ACTUATOR = BAKER P ro osed RWO KB. ELEV = 60' P BF. ELEV = KOP = 4000' 13 -3/8" CSG, 68 #, H 71' I- I 2,200' H 7" TBG, 26# L -80, TC-II I Max Angle = 31 @ 9200' K -55, ID = 12.415" Datum MD = N/A Datum TVD = 8800' SS ! 2,200' I- 7" CA MCO BAL -O ID = 5.937" 113 -3/8" CSG, 68 #, L -80, ID = 12.415" I-J 3491' I--- 7" TBG, 26 #, L -80, TC-II IH 8,28$' I I 17-5/8" TBG -IPC, 29.7 #, L -80 VamTopHC Ii 8,285' I 8,285' I- 17 -5/8" x 4 -1/2" crossover I I4 -1/2" TBG -IPC, 12.6 #, L -80 TC-11 H I TOP OF7" LNR h 8335' I — ] I 8,382' H4- 1/2 "'X' 3.812" I * 8,413' I-17" x 4 -1/2" HES TNT packer I 47 L- ID = 1" ■ 9-5/8" CSG, #, 80, 8.68 I 8 635' $ 447' 4- 1/2 "'X' 3.812" - I I u I I� I P I 8,520' I- I4- 112 " 'XN' 3.725" I I 8,538' 1-14-1/2" WLEG I PERFORATION SUMMARY I REF LOG: FINAL CNP ON 03/13/90 ANGLE AT TOP PERF: 30 @ 8685' I Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 4 8685 -8738 0 05/30/90 3 -3/8" 4 8782 -8844 0 05/30/90 I 3 -3/8" 4 8849 -8884 0 05/30/90 3 -3/8" 4 8889 -9049 0 05/30/90 3 -3/8" 4 9062 -9085 0 05/30/90 3 -3/8" 4 9091 -9097 0 05/30/90 I 3 -3/8" 4 9101 -9126 0 05/30/90 3 -3/8" 4 9130 -9136 0 05/30/90 3 -3/8" 4 9140 -9156 0 05/30/90 PBTD I 9212' . 1...........1..1.....1..1 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" H I 9240' 1 •�• � •�' � •�• � •�' � DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/18/90 ORIGINAL COMPLETION WELL: WGI -06 12/20/10 LAST WORKOVER PERMIT No: '1900300 API No: 50- 029 - 22021 -00 SEC 11, T11 N, R14E, 3169.9' FEL & 4988.09' FNL BP Exploration (Alaska) WGI -06 PTD 190 -030 sundry 310 -206 Page 1 of 5 • Schwartz, Guy L (DOA) From: Bjork, David [David.Bjork @bp.com] Sent: Thursday, March 24, 2011 2:34 PM To: Schwartz, Guy L (DOA) Subject: RE: WGI -06 (PTD 190 -030 ) sundry 310 -206 Guy, We would like to replace the BAL -O and WRDP -2 with a DB-6 and A -1 injection valve. Do you need any supporting documentation? Regards, Dave From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Tuesday, March 22, 2011 1:16 PM To: Bjork, David Subject: RE: WGI -06 (PTD 190 -030 ) sundry 310 -206 Dave, It would be better to resubmit a sundry with the new procedure. The old sundry (310 -206) is closed out anyway. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Bjork, David [mailto:David.Bjork @bp.com] Sent: Tuesday, March 22, 2011 1:06 PM To: Schwartz, Guy L (DOA) Subject: RE: WGI -06 (PTD 190 -030 ) sundry 310 -206 Guy, Is this work approved under the original sundry? thanks, Dave From: Schwartz, Guy L (DOA) [ maitto:guy.schwartz @alaska.gov] Sent: Thursday, March 17, 2011 1:43 PM To: Bjork, David Subject: RE: WGI -06 (PTD 190 -030 ) sundry 310 -206 Dave, Looks fine as written. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 3/29/2011 • WGI -06 PTD 190 -030 sundry 310 -206 Page 2 of 5 • 444 -3433 (cell) From: Bjork, David [mailto:David.Bjork @ bp.com] Sent: Thursday, March 17, 2011 11:01 AM To: Schwartz, Guy L (DOA) Cc: Reem, David C; Hubble, Terrie L; Barker, Elizabeth R (SAIC) Subject: RE: WGI -06 (PTD 190 -030) sundry 310 -206 Guy, Attached is a revised scope of work for the WGI -06 recomplete scheduled in mid April. Please call me if you have any questions. Regards, Dave From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Friday, February 11, 2011 10:51 AM To: Bjork, i . , . u . : RE: WGI -06 (PTD 190 -' 1) sundry 310 -206 i . Dave, I looked at the bond log again and have to come to the conclusion we need to do something else here. We are compromising the 9 5/8" casing every time we mill up a packer and with such poor cement behind it the commission is not ready to approve anything that leaves the 9 5/8" exposed to the injection pressure at this time. \ Call me to discuss other options. . Regards, \ y Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Bjork, David [mailto:David.Bjork @bp.com] Sent: Tuesday, February 01, 2011 10:02 AM To: Schwartz, Guy L (DOA) Subject: RE: WGI -06 (PTD 190 -030 ) sundry 310 -206 Guy, Looking at the recomplete on this well, after the last failed RWO.... Obviously we will have to mill up the upper packer. We are hoping to avoid milling up the lower packer. Would we be allowed to recomplete with a new packer depth -40ft above the milled packer setting depth? It would stack out as. 8,298' original packer (left in the well). '10 RWO packer set at 8,067' to be milled and retrieved. Proposed '11 RWO new packer setting depth of 8,027', placing the packer in "virgin, tested" casing. Is this too close to the cement top? Thanks for the help, 3/29/2011 WGI -06 PTD 190 -030 sundry 310 -206 Page 3 of 5 • Dave Bjork 564 -5683 440 -0331 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Monday, December 20, 2010 10:34 AM To: Bjork, David Subject: RE: WGI -06 (PTD 190 -030 ) sundry 310 -206 Dave, Don't need a 403 sundry .. Just document everything in the 404 report. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Bjork, David [mailto:David.Bjork @bp.com] Sent: Monday, December 20, 2010 10:15 AM To: Schwartz, Guy L (DOA) Cc: Stewman, Sondra D; Barker, Elizabeth R (SAIC); Reem, David C Subject: RE: WGI -06 (PTD 190 -030 ) sundry 310 -206 Guy, The well will remain secured with a PXN plug in the original packer tail at 8,350'. The well was loaded with 9.8- ppg brine and freeze protected. A BPV was installed. The tubing hanger seals were tested and dry hole tree was installed and tested. Do you need a (10 -403)? Regards, Dave From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: '• ay, December 17, 2010 11:25 AM To: Bjork, 'd Cc: Stewman, So D; Barker, Elizabeth R (SAIC); Reem, David C Subject: RE: WGI -06 • 190 -030 ) sundry 310 -206 Dave, Ok.. sounds like regrouping is the right a er for this well. Please send me a outline of what you plan to do to secure the well. Thanks, Regards, Guy Schwartz 3/29/2011 - WGI -06 PTD 190 -030 sundry 310 -206 Page 4 of 5 • Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Bjork, David [mailto:David.Bjork @bp.coml Sent: Friday, December 17, 2010 10:56 AM To: Schwartz, Guy L (DOA) Cc: Stewman, Sondra D; Barker, Elizabeth R (SAIC); Reem, David C Subject: RE: WGI -06 (PTD 190 -030 ) sundry 310 -206 Guy, We will stop the current operations, and come back with a plan to repair the well. thanks, Dave From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Friday, December 17, 2010 10:28 AM To: Bjork, David Cc: Stewman, Sondra D; Barker, Elizabeth R (SAIC); Reem, David C Subject: RE: WGI -06 PTD 190 -030 ) sundry 310 -206 Dave, I reviewed the 9 5/8" Cern: nt bond log and I don't think it would be prudent to move the packer uphole. Cement coverage is poor at best an, essentially stops at about 7700' md. I cannot approve your proposed changes below.... Please call to discu other options. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Bjork, David [mailto:David.Bjork @bp.com] Sent: Friday, December 17, 2010 9:41 AM To: Schwartz, Guy L (DOA) Cc: Stewman, Sondra D; Barker, Elizabeth R (SAIC); Reem, David C Subject: RE: WGI -06 PTD 190 -030 sundry 310 -206 Guy, Afte r running the new completion, we were unable to get a passing IA test, appears the S -3 Packer is leaking. 9 p We would like to perform the following steps to re- complete the well. Also a ached is a revised schematic. Please call with any questions or comments. Regards, Dave Bjork 564 -5683, 440 -0331 1. RU SLB slickiline on Doyon 141 with full pressure control. RIH and pull ball -n -rod and RHC seat from the RN nipple at 8,171'. Set a 4 -1/2" junk catcher in the 4 -1/2" tailpipe below the original completion at 8,298'. 3/29/2011 WGI -06 PTD 190 -030 sundry 310 -206 Page 5 of 5 110 flp Concurrently Toad the pits with 9.8 -ppg brine and have 2 (290 -bbl) vac trucks of seawater on location at all times. 2. RIH with Baker multistring cutter on 4" drill pipe. Max knife throw set to no more than 8 ". RIH and cut the 7- 5/8" tubing 15' above the 7 -5/8" x 7" crossover at 7,965'. POOH SDDP. 3. Pull and lay down the 7 -5/8" VamTop HC. Install thread protectors and send the tubing string in for inspection. 4. RIH with a dress off / casing scraper assembly on DP. Dress and bevel the 7 -5/8" cut, swap over to clean brine. POOH LDDP. 5. Run new completion and space out Wireline Re -Entry Guide -100' above the cut joint at -7.965', the upper packer depth will be - 7,791'. 6. Freeze protect, set packer, test the tubing to 4,000 -psi, test the casing to 4,000 -psi. Install TWC 7. ND BOPE/ NU Tree and test 8. RDMO From: Schwartz, Guy L (DOA) [ mailto :guy.schwartz @alaskagov] Sent: Friday, November 12, 2010 10:00 AM To Bjork, David Subject: RE: WGI -06 PTD 190 -030 sundry 310 -206 Dave, Thanks for the updated program... I will supercede the previous version in our well file... Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Bjork, David [mailto:David.Bjork @bp.com] Sent: Thursday, November 11, 2010 8:36 AM To: Schwartz, Guy L (DOA) Cc: Reem, David C; Barker, Elizabeth R (SAIC) Subject: WGI -06 PTD 190 -030 sundry 310 -206 Guy, Attached is a revised scope of work for WGI -06 RWO. The current plan is to utilize Doyon 141 instead of Doyon 16 for the workover. Doyon 141 can accommodate a 4 preventer stack while performing the workover. Regards, Dave « AOGCC Scope of Work WGI -06 revision 2.ZIP» 3/29/2011 STATE OF ALASKA ALASKIDL AND GAS CONSERVATION COMMIS °' " RECEJVE REPORT OF SUNDRY WELL OPERANS FEB 25 2011 1. Operations Performed: f � ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Ente us . . VPe as Cons. s ❑ Alter Casing IS Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Other Anchorage ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑ Development ❑ Exploratory 190 - 030 3. Address: ® Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 - 029 - 22021 - 00 - 00 7. Property Designation: 8. Well Name and Number: ADL 028302 PBU WGI -06 9. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Oil Pool 10. Present well condition summary Total depth: measured 9240' feet Plugs (measured) 8350' feet true vertical 8685' feet Junk (measured) None Effective depth: measured 9212' feet Packer: (measured) 8067' / 8298' feet true vertical 8661' feet Packer: (true vertical) 7666' / 7869' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 119' 20" 119' 119' 1490 470 Surface 3491' 13 -3/8" 3491' 3491' 3450 1950 Intermediate 8635' 9-5/8" 8635' 8163' 6870 4760 Production Liner 905' 7" 8335' - 9240' 7902' - 8685' 8160 7020 Perforation Depth: Measured Depth: 8685' - 9156' N ED MAR 8 2011 True Vertical Depth: 8206' - 8613' Tubing (size, grade, measured and true vertical depth): 7 -5/8 ", 29.7# x 7 ", 26# L - 8190' MD 7774' TVD 4 12.6# 8298' - 8363' MD 7869' - 7926' TVD Packers and SSSV (type, measured and true vertical depth): 9-5/8" x 7" BKR S - packer 7666' TVD 8067' MD 7869' TVD 9-5/8" x 5 -1/2" Baker FB -1 PERM packer 8298' MD 11. Stimulation or cement squeeze summary: a -.p.,J� r2 w 0 Intervals treated (measured): ,✓ - a " .e e M f 'I 1 S s ` H 5 Treatment description including volumes used and final pressure: Cut and pulled 7" tubing from approximately 8298'. Run new completion. New Completion Packer failed IA test Rigged down to evaluate future repair plans. PXN Plug remains in place at 8350'. 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: I 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: ❑ Exploratory ❑ Development ® Service ❑ Stratigraphic ® Daily Report of Well Operations ® Well Schematic Diagram 15. Well Status after work: ® GINJ ❑ Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Bjork, 564 -5683 310 - 206 Printed Name Elizabeth Barker Title Drilling Technologist Signature (T' ,4 4 tG Qom/ Phone 564 -5674 Date Prepared By Barker, 564- Elizabeth Barker, 564 -566 74 Form 10-404 Revised 16 610 1/6_, " 3 .g 11 Submit Original Only • • WGI -06 Well History (Pre -Rig Workover) Date Summary 8/2/2010 T/I/0= 100/120/100. Temp= SI. WHPs, T & IA FL (for fullbore). TBG FL near surface. IA FL CO surface. OA FL near surface. SV, WV= Closed. SSV, MV =Open. IA, OA= OTG. 8/2/2010 T /I /O= 60/120/ Temp= S/I CMIT TxIA PASSED to 4000 •si, MIT -OA PASSED to 2000 psi (Pre RWO) CMIT -TxIA: Pressured up TxIA with 7.5 bbls diesel. Rigged up U -tube hose to equalize pressures. TxIA lost 20/0 psi in 30 min test. MIT -OA: Pressured up OA with 7.5 bbls diesel. OA lost 120 psi in 1st 15 mins and 40 psi in 2nd 15 mins for a total loss of 160 psi in 30 min test. Bled all pressures back. Final WHPs 0/100/00 SV,WV= Shut SSV,MV,IA,OA= Open 8/3/2010 ** *WELL SI ON ARRIVAL (ELINE TUBING CUT) * ** INITIAL T/I/0 = 0/50/50 CUT TUBING AT 8290 FT IN 5.5" PUP JOINT ABOVE XO. CORRELATED TO TUBING TALLY. GOOD INDICATION AT SURFACE. FINAL T /I /O = 0/50/50, SWAB- CLOSED, MASTER AND SSV -OPEN. DSO NOTIFIED. ** *JOB COMPLETE * ** 9/15/2010 T /I /0= 20/20/100 Temp = SI Circ -out/ CMIT TxIA Passed to 500 psi. (Pre- RWO) Pumped 5 bbls of neat followed by 652 bbls of 2% KCL down the IA taking returns up the tubing to surface tanks. Pumped a 3 bbl neat flush followed by 157 bbls of diesel down the IA. Let U -Tube for - 1 hr. CMIT T/I pressured up to 500/490 psi with 1.1 bbls diesel. T/I lost 0/10 psi in first 15 minutes and 0/0 psi in second 15 minutes. For a total of 0 /10 psi in 30 minutes. Bled pressure down freeze protected choke skid and surface hardline with 2 bbls diesel. FWHP's= 0/0/200 VALVES in following positions - and operator notified of positions and result of job: Wing closed, Swab closed, SSV closed, Master open, IA open, OA open - Well SI 9/18/2010 T /I /O= Vac /20/100. Temp =Sl. Bleed OA to 0 psi (RWO prep). OA FL near surface. Bled OAP from 100 psi to 2 psi in 1 hr, 30 mins (FTS in 30 secs). Bled IAP from 20 psi to 0 psi in 2 mins (all gas). Monitor 30 mins. OAP increased 14 psi. Final T /1 /O= Vac /0/16. ** Job is Incomplete ** SV, WV =C. SSV, MV =O. IA, OA =OTG. NOVP. 10/10/2010 T /I /O= Vac /10/40 Temp =S1 Bleed IA & OA to 0 psi (pre PPPOT work) Re- energize seals pre -rig. Bled IAP and OAP to 0 psi in 15 min. (gas) Cameron performed passing PPPOT -IC after re- energizing secondary Y- seals. FW HP's= Vac /0 /0 WV, SV =C. SSV, MV =C. IA, OA =OTG. NOVP. * *Job Complete ** 10/10/2010 T /I /O= VAC /0/0, Temp =Sl. PPPOT-IC (PASS), re- energize secondary seals. Pre RWO. DHD bled IAP & OAP to 0 psi, maintained open bleed. Stung into IC test port (0 psi). Opened PKG port SBS (0 psi). Removed PKG port plug, RU PKG gun and re- energized secondary Y seal. Pumped through IC test void, good returns. Pressured test void to 3500 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in second 15 (PASS). Bled void to 0 psi. 10/14/2010 T /I /O= vac /0/0 Set BPV Pre Rig: Pressure tested master valve at 500 PSI for 5 min (pass) Pressure tested SSV at 500 PSI for 5 min (pass). RU CIW lubricator set 6" CIW J BPV #422 at 128" pre rig . * ** Job completed * ** Page 1 of 2 • WGI -06 Well History (Pre -Rig Workover) Date Summary 10/20/2010 T /I /O= S1 /0/0 ( PRE RIG WORK) Tested primary barrier to 500 psi.(pass) Verified leak tight isolation on second barrier. Removed 3 1/8 companion valve. Installed 3 1/8 blind and pressure tested blind to 500 psi low for 5 min. (pass) Then 5000 psi for 5 min. (pass) Removed 2 1/16 I/A VR blind. Unable to break free VR plug. Put blind back on and filled with kroil and heat on it. Removed 2 1/16 O/A VR blind. Installed 2 1/16 FMC model 120 HWO valve. Rigged up VR lubricator. Pressure tested Valve and lubricator to 500 psi against VR plug for 5 min. (pass) Then to 3500 psi for 5 min. (pass). Removed VR plug and rigged down lubricator. Installed jewelry on blind and pressure tested to 500 psi for 5 min. (pass) Then 3500 psi for 5 min. (pass). ** *JOB IN PROGRESS* ** 10/21/2010 T /I /O= SI /0/0 Removed IA blind flange, attempted to remove IA VR plug (unsuccessful). Reinstalled Blind flange. Rigged up lubricator to OA valve and pressure tested to 500 psi for 5 min (PASS) then 3500 psi VR and pressure tested to 500 psi for 5 min (PASS) then to 3500 for 5 min (PASS) Installed 2 V plug p p ( ) psi p for 5 min (PASS) Removed 2 1/16 McEvoy OA valve. Installed blind flange and pressure tested to 500 psi (PASS) then to 3500 psi (PASS) removed scaffolding platform from tree ** *JOB COMPLETE * ** 10/26/2010 T /I /O= S1 /0/0 Fill VR blind void up with kroil and pressured up to 2150 psi. to see if it will help free VR plug. 11/14/2010 (WH- Repair) T /I /O= SI /0/0 Bled off the void, in between the blind side of the IA and the VR plug. 12/2/2010 T /I /O =0/0/0 Pre Rig Dry hole tree installation. Verified barriers. Removed 6 3/8" x 7 1/16" CIW tree from SSV up. Installed 6 3/8" x 7 1/16" CIW FLS swab valve on master valve. Torqued to spec. Pressure tested swab to 500 psi for 5 min ( pass) and 5000 psi for 5 min (pass). Bled off tree. ** *Job Complete * ** 12/7/2010 T /I /O= 100/100/0. (RWO Prep.) Bled treecap to 0 psi. (gas) Perform 10 min. barrier test on BPV - PASSED to 1000 psi. Pumped 2.3 bbls of diesel down the IA to reach test pressure. Bled to Final WHP= 0/0/0. SV, MV = closed, IA/OA = OTG. Page 2 of 2 TREE = 6 -3/8" CAMERON WELLHEAD = MCEVOY VVG I 0 6 PRESSOR ABOVE3 00 PS FOR NOT ACTUATOR = BAKER C KB. ELEV = 60' EMERGENCY FIELD FUEL GAS BF. ELEV = 1 = KOP 4000' 13 -3/8" CSG, 68 #, -I 71' I Max Angle = 31° @ 9200' K -55, ID = 12.415" Datum MD = N/A 1 1 2199' I-1 7" CAMCO DB -6 NIP, ID = 6.00" I ' k Datum TVD = 8800' SS 7 G°` 511r 113 -3/8" CSG, 68 #, L -80, ID = 12.415" H 3491' 1 • 11 p `C � $ q Poi C ` . t\ 7 -5/8" TBG -IPC, 29.7 #, L -80 VAM TOP HC, 7979' l \ OTIS R S $ .0459 bpf, ID = 6.875" / 8036' -17" OTIS R NIP, ID = 5.963" I Z 1 8067' H 9 -5/8" X 7" BKR S -3 PKR, ID = 6.059 " ?? Minimum ID = 3.725" @ 8350' 4-1/2" OTIS XN NIPPLE I i 1 8101' I-I 7" OTIS R NIP, ID = 5.963" I ' , I 8172' H 7" OTIS RN NIP, ID = 5.770" I 7" TBG, 26 #, L -80 TCII, .0383 bpf, ID = 6.276" H 8190' 1- -/ -1 8190' H 7" WLEG, ID = 6.276" I 8298' I- -I 9 -5/8" X 5 -1/2" BKR FB -1 PERM PKR I 830 H BAKER SEALBORE EXTENSION I 8312' I-I BAKER MILLOUT EXTENSION 1 8318' H 7 -5/8" X 4-1/2" XO, ID = 3.995" I TOP OF 7" LNR H 8335' 1 „, 8350' H4 -1/2" PXN PLUG (03/15/10) I " 8350' H 4-1/2" OTIS XN NIP, ID = 3.725" I 8362' H 4 -1/2" BKR SHEAROUT SUB 1 14-1/2" TBG,12.6 #, L -80, .0152 bpf, ID = 3.958" I—I 8363' I- 8363' H 4 -1/2" WLEG, ID = 3.958" I . ■ 1 8348' I---I EL MD TT LOGGED 05/31/90 I 19 -5/8" CSG, 47 #, L -80, ID = 8.681" H 8635' PERFORATION SUMMARY REF LOG: FINAL CNP ON 03/13/90 1 ANGLE AT TOP PERF: 30 @ 8685' Note: Refer to Production DB for historical perf data 1 SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 4 8685 -8738 0 05/30/90 3 -3/8" 4 8782 -8844 0 05/30/90 1 3 -3/8" 4 8849 -8884 0 05/30/90 3 -3/8" 4 8889 -9049 0 05/30/90 3 -3/8" 4 9062 -9085 0 05/30/90 1 3 -3/8" 4 9091 -9097 0 05/30/90 3 -3/8" 4 9101 -9126 0 05/30/90 3 -3/8" 4 9130 -9136 0 05/30/90 1 3 -3/8" 4 9140 -9156 0 05/30/90 1 PBTD H 9212' 101■0■1 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" 1-1 9240' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/18/90 ORIGINAL COMPLETION WELL: WGI-06 05/08/90 LAST WORKOVER PERMIT No: 1900300 12/16/10 DOYON141 RWO API No: 50- 029 - 22021 -00 12/27/10 ? /JMD DRLG DRAFT CORRECTIONS SEC 11, T11 N, R14E, 728' FNL & 1109' FEL 01/04/11 MBMIPJC FINAL DRLG CORRECTIONS 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) • • h L, � I A I � ` =��. Pag 1, '' ®perms - a ty Rp . _ m �� ' . . �� = a.. ;, Common Well Name: WGI -06 AFE No Event Type: WORKOVER (WO) Start Date: 12/2/2010 End Date: 12/18/2010 X4- 00R7H -E (2,461,000.00 ) Project: Prudhoe Bay (various) Site: WGI Rig Name /No.: DOYON 141 Spud Date/Time: Rig Release: 12/18/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: DFE @0.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/3/2010 06:00 - 12:00 6.00 MOB N WAIT PRE FABRICATE HANDRAILS FOR THE MUD ELEVATOR, WORK ON MAINTANENCE PROGRAM WORK ORDERS, INSPECT THE DRAW WORKS CHAINS AND BRAKE BANDS /PADS. INSPECT THE DRAG CHAINS AND GEAR ENDS IN THE MUD PITS AND ROCKWASHER. ASSEMBLE THE MUD PUMPS.. 12:00 - 14:30 2.50 MOB N WAIT PRE DOYON SAFETY STAND DOWN MEETING WITH DOYON HSE REP BEN BEARDEN, DOYON SUPERINTENDENT MARK EGHOLM, D OYON TOOL PUSHER CHARLIE HU RE NTINGTON, AND.BP WSL RICHARD BORDES. VIEW PAST INCIDENTS AND THE NEED TO CREATE SOPs ON OFF- LOADING/LOADING THIRD PARTY EQUIPMENT AND "MUD ELEVATOR OPERATIONS. ELEVATED AWARENESS BROUGHT TO DOING HAZARD RECOGNITION CAR BEMA AND DS HAVING FORE AR SPOTTER PERFOR FOR ING LOADER T SK OPERATIONS. ALSO, STRESS THE IMPORTANCE OF RESPONSIBILITY AND ACCOUNTABILITY OF ALL CREW MEMBERS. 14:30 - 20:30 6.00 MOB N WAIT PRE INSPECT THE DRAG CHAIN IN THE ROCKWASHER, TAKE A LINK OUT OF THE PIT DRAG CHAIN. CLEAN AND REINSTALL DRAWWORKS COVER, CLEAN AND INSPECT THE IRON ROUGHNECK FOR LEAKS AND REPLACE 2 HOSES ON THE VERTICAL LIFTING RAMS. PALLET AND BAND ALL WELLHEAD TOOLS FOR RETURN TO TOOLSERVICE. 20:30 - 00:00 3.50 MOB N WAIT PRE WORK ON GATHERING IDEAS AND REWRITING SOPs WITH ALL CREW MEMBERS. 12/4/2010 00:00 - 03:30 3.50 MOB N WAIT PRE WORK ON GATHERING IDEAS AND REWRITING SOPs WITH ALL CREW MEMBERS. 03:30 - 12:00 8.50 MOB N WAIT PRE PERFORM MAINTANENCE IN THE ROCKWASHER PITS CHANGE OUT 2 DEMCO VALVES. REMOVE THE TOP SPINNERS ON THE IRON ROUGHNECKAND REPAIRA LEAKING RAM AND REINSTALL. WRITE SOP REGARDING OFF - LOADING THIRD PARTY EQUIPMENT WITH THE FORKLIFT. PERFORM MAINTENANCE ON RIG FLOOR TUGGERS, SEMI - ANNUAL INSPECTION ON CELLAR TUGGER AND RIG FLOOR TUGGERS. 12:00 - 14:00 2.00 MOB N WAIT PRE HELD SAFETY STAND DOWN MEETING TO REVIEW INCIDENTS AND HAVE CREW FEED BACK. Printed 2/24/2011 2:12:40PM LASl4A BP 141" Pir 3 ©per• unimary Rppm Common Well Name: WGI-06 06 AFE No Event Type: WORKOVER (WO) Start Date: 12/2/2010 End Date: 12/18/2010 X4- 00R7H -E (2,461,000.00 ) Project: Prudhoe Bay (various) Site: WGI Rig Name /No.: DOYON 141 Spud Date/Time: Rig Release: 12/18/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: DFE @0.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1 14:00 - 20:00 6.00 MOB N WAIT PRE WORK WITH DENALI CRANE INSPECTION REP. DARREN FOLKERS ON THE FOLLOWING: - KOOMY ROOM TROLLY BEAM - 2 TROLLY BEAMS IN THE PUMP ROOM CHAIN HOIST ON FLOWLINE -2 CHAIN HOISTS IN PUMP ROOM - CHAIN HOIST ON THE RIG FLOOR - CHAIN HOIST FOR CHARGE PUMPS - BRIDGE CRANE IN THE PIPE SHED - 2 BRIDGE CRANES IN THE CELLAR - 3 TUGGERS ON THE RIG FLOOR - MAN RIDER ON THE RIG FLOOR WELDER WORKED ON REPAIRING THE PIPE SKATE TROLLY, IRON ROUGHNECK SPINNER CAGE AND HYDRAULIC LINE FITTING IN THE CELLAR. 20:00 - 00:00 4.00 MOB N WAIT PRE TAKE APART THE FLOW LINE FROM THE MUD PITS TO THE SUB STRUCTURE ALONG WITH THE HIGH PRESSURE LINE FROM THE CELLAR TO THE MUD PITS. WORK ON THE DRAG CHAIN IN THE MUD PITS. COMPLETED MAINTANANCE ON PULL BACK TUGGER ON THE RIG FLOOR AND BOTH EZ TORQUES ON THE RIG FLOOR. 12/5/2010 00:00 - 02:00 2.00 MOB N WAIT PRE WORK ON GATHERING IDEAS AND REWRITING SOPs WITH ALL CREW MEMBERS. 02:00 - 06:00 4.00 MOB N WAIT PRE PERFORM MAINTENANCE ON THE DRAG CHAIN IN THE ROCKWASHER, SHAKERS IN THE MUD PITS, AND GENERAL HOUSE KEEPING ON THE RIG FLOOR, PIPE SKATE, AND MUD PUMPS. 06:00 - 12:00 6.00 MOB N WAIT PRE PREPARE THE RIG FOR THE UPCOMING BP AUDIT. CLEAN AND STRAIGHTEN UP THE MEZZANINE, DOG HOUSE, CHOKE HOUSE AND PUMP ROOM WIRING. SHUT DOWN BOILER #1 TO CHANGE OUT THE SHUT DOWN PROBE. THE WELDER IS FABRICATING 4" OPEN -ENDED SYPHON PIPE ON THE MUD GAS SEPARATOR AND MUD ELEVATOR CAGE IN THE SHOP. 12:00 - 14:00 2.00 MOB N WAIT PRE SAFETY STAND DOWN MEETING IN CAMP WITH BOTH CREWS FINALIZING PROCEDURES ON LOADING/UNLOADING MUD ELEVATOR WITH MUD PRODUCTS AND A PROCEDURE ON UNLOADING MUD PRODUCTS FROM THE TRUCK. Printed 2/24/2011 2:12:40PM ''1" . �i - `` �Opera'fiq �rnma R p-O 1 � 1 "' Common Well Name: WGI -06 AFE No Event Type: WORKOVER (WO) Start Date: 12/2/2010 End Date: 12/18/2010 X4- 00R7H -E (2,461,000.00 ) Project: Prudhoe Bay (various) Site: WGI Rig Name /No.: DOYON 141 Spud Date/Time: Rig Release: 12/18/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: DFE @0.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:00 - 00:00 10.00 MOB N WAIT PRE WELD THE HANDRAILS AND CAGE ONTO THE MUD ELEVATOR AND TEST RUN WITH AN EMPTY TOTE. CHANGE OUT SHAKER BED RUNNERS ON THE #3 SHAKER. REMOVE THE CROWN -O -MATIC FROM THE DRAW WORKS TO HAVE TUBOSCOPE INSPECT. FIXED LOW PURGE ALARM LIGHTS ON DRILLERS CONSOLE ALONG WITH LOW PURGE WARNING LIGHTS THROUGHOUT THE RIG. COMPLETE PREVENTATIVE MAINTENANCE ON RIG FLOOR AIR HEATERS AND OFF DRILLERS SIDE HYDRAULIC PUMP IN THE PIPE SHED. WORK ON THE FOLLOWING PROCEDURES: LOADING THE MUD ELEVATOR - UNLOADING THE MUD ELEVATOR - LOADING AND OFFLOADING TRUCKS WITH TOOLS AND EQUIPMENT - LOADING. AND OFFLOADING TRUCKS OF TUBULARS 12/6/2010 00:00 - 12:00 12.00 MOB N WAIT PRE REWRITE AND REVIEW PROCEDURES. CLEAN AND STRAIGHTEN THE MEZZANINE, CLEAN OUT THE SUMPS IN THE PUMP ROOM, PAINTING THE ELEVATOR TROLLEY, INSPECTING PVC PIPING IN THE ROCK WASHER, AND GENERAL RIG MAINTENANCE. CLEAN OUT THE CENTRIFICAL ROOM AND UNDER THE MUD PUMPS. CHANGE OUT THE SHACKLES ON THE BOP STACK AND REMOVE 2 PART SHACKLES FROM THE BOP ADJUSTMENT LINES. REPLACE 3" DEMCO VALVE ON THE DISCHARGE TO PIT # 2. MOUNT PRESSURE GAUGE FOR MUD / GAS SEPERATOR ON THE REMOTE CHOKE PANEL 1/4" STAINLESS STEEL LINE TO THE MUD / GAS SEPERATOR. CLEAN UP THE RAA / SAA CONTAINMENT TRAYS. FIXED DIESEL DRIP ON THE #2 BOILER FEED PUMP AND CHANGE OUT THE RELIEF VALVE ON THE RIG AIR TANK IN THE MEZZANINE. WELDER CUT EQUALIZER RISERS FREE BETWEEN PITS 3 & 6 ALONG WITH PITS 1 & 2. ALSO REMOVED OLD PVT PROBES IN PITS 1,4 AND TRIP TANK. INSTALLED THE GUARDS ON THE MUD ELEVATOR. 12:00 - 14:00 2.00 MOB N WAIT PRE SAFETY MEETING WITH BOTH CREWS ON HAZARD RECOGNITION. 14:00 - 00:00 10.00 MOB N WAIT PRE WORK ON INSULATING STEAM LINES THROUGHOUT THE RIG. CHANGE OUT 6" DEMCO VALVE ON #2 MUD PUMP. REPLACE SEALS IN RISER BETWEEN PITS 1 & 2. HAD QUADCO REP. CALIBRATE THE WT. INDICATOR, STAND PIPE PRESSURE GAUGE ON DRILLERS CONSOLE, PUMP #1 AND #2 PRESSURE GAUGES ON THE DRILLERS CONSOLE, EZ- TORQUE GAUGE, BOTH IRON ROUGHNECK GAUGES, AND CASING GAUGE. RE- INSTALLED THE CROWN -O- MATIC. Printed 2/24/2011 2:12:40PM , , c h Amer - A AS CA BP of .O ati Summary Report . , _ , € ;: Common Well Name: WGI -06 AFE No Event Type: WORKOVER (WO) Start Date: 12/2/2010 End Date: 12/18/2010 X4- 00R7H -E (2,461,000.00 ) Project: Prudhoe Bay (various) Site: WGI Rig Name /No.: DOYON 141 Spud Date/Time: Rig Release: 12/18/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: DFE @0.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/7/2010 00:00 - 12:00 12.00 MOB N WAIT PRE WORK IN THE PITS INSTALLING GREASE LINES IN THE CONVEYOR TROUGHS. CONTINUE INSULATING STEAM LINES THROUGHOUT THE RIG, CHANGE OUT THE BEDDING ON THE SHAKER IN THE ROCKWASHER. CHANGE OUT THE AIR BOOTS ON THE FLOW LINE, REMOVE THE OLD FLOW PADDLE FROM THE FLOW LINE. RE- INSTALL FLOW LINE SECTION FROM DRIP PAN TO MEZZANINE. CLEAN AND INSPECT THE AIR BOOT CAVITY ON THE DUTCH RISER SYSTEM. MEASURE THE HYDRAULIC LINES ON THE SKATE FOR REPLACEMENT AND ADD GLYCOL TO MOTORS # 1 AND #2. SERVICE THE TOP DRIVE AND INSPECT THE ELEVATOR BAILS. WELDER INSTALLED THE SIPHON BRAKE ON THE MUD /GAS SEPARATOR. 12:00 - 20:00 8.00 MOB N WAIT PRE INSTALL NEW BEDDING ON THE SHAKER IN THE ROCK WASHER. PERFORM A TEST RUN ON THE MUD ELEVATOR WITH THE RECENT MODIFICATIONS FOR BP SUPERINTENDENT, WSL, DOYON SAFETY REP, TOOL PUSHER AND TOUR PUSHER. AUTHORIZATION TO PROCEED WITH RIG MOVE GIVEN BY ALAN MADSEN AS PER LOWELL CRANE. 20:00 - 00:00 4.00 MOB N WAIT PRE PREPARE THE RIG FOR MOVING TO WGI-06. SHOVEL SNOW OUT FROM THE WHEEL AREA IN THE REAR OF THE SUB. FREEZE PROTECT THE WASH DOWN PUMPS IN THE PITS, ROCKWASHER, TRASH PUMP, AND CENTRIFUGAL PUMP. DISCONNECT THE CHOKE HOSE FROM THE PITS, SECURE THE WELL SIGN. THAW OUT THE CUTTING TANK AND REMOVE ANY RESIDUAL FLUID IN IT. 12/8/2010 00:00 - 09:30 9.50 MOB P PRE WORK AROUND THE RIG PREPARING TO MOVE THE RIG. FREEZE PROTECT THE ENVIROVAC, DISCONNECT THE TIOGA FROM THE PIPESHED, AND BEGIN SHIPPING MISC. MATERIAL TO WGI -06. 09:30 - 22:00 12.50 MOB P PRE MOVE 3 POWER PACK MODULES AND ROCKWASHER FROM J-20C TO WGI -06, FOLLOWED BY 3 MORE MODULES FOLLOWED BY THE SUB. 22:00 - 00:00 2.00 MOB P PRE PULL THE SUB OVER WGI -06 AND BE I RIGGING UP. 12/9/2010 00:00 - 09:00 9.00 MOB P PRE RIG UP AND CONNECT ALL OF THE MODULES OVER THE WELL. WORK ON THE RIG ACCEPTANCE CHECK LIST. HOOK UP ALL ELECTRICAL AND SERVICE LINES BETWEEN THE MODULES. TURN ON THE STEAM, WATER, AND AIR HEATERS. LOWER THE PIPE SKATE RAILS, BERM THE ROCK WASHER, AND ASSEMBLE THE MUD PUMPS AND LINES. 09:00 - 10:00 1.00 MOB P PRE SPOT AND RIG UP UP THE 500 BBL BLEED BACK TANK AND PRESSURE TEST THE HARDLINE. 10:00 - 11:00 1.00 MOB P PRE HOLD PRE -SPUD MEETING WITH RIG CREW, TOOLPUSHER, WSL'S, AND RWO SUPERINTENDENT JIM WILLINGHAM. Printed 2/24/2011 2:12:40PM Allinrth Operation Sul � ,a� �@ ' �[[ €€ Common Well Name: WGI -06 AFE No Event Type: WORKOVER (WO) Start Date: 12/2/2010 End Date: 12/18/2010 X4- 00R7H -E (2,461,000.00 ) Project: Prudhoe Bay (various) Site: WGI Rig Name /No.: DOYON 141 Spud Date/Time: Rig Release: 12/18/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: DFE @0.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:00 - 12:00 1.00 MOB P PRE RWO SUPERINTENDENT JIM WILLINGHAM PERFORMED WALK THROUGH ON THE RIG TO VERIFY ALL OF THE SAFETY CRITICAL EQUIPMENT WAS IN PROPER WORKING CONDITION. 12:00 - 14:30 2.50 MOB P PRE TAKE ON 9.8 PPG BRINE INTO THE MUD PITS. 14:30 - 15:30 1.00 MOB P PRE HOLD PRE -SPUD MEETING WITH RIG CREW, TOOLPUSHER, WSL'S, AND RWO SUPERINTENDENT JIM WILLINGHAM. 15:30 - 16:00 0.50 WHSUR P WHDTRE RIG UP TO CIRCULATE DOWN THE IA WITH RETURN FROM THE TUBING TO THE OPEN TOP BLEED TANK. 16:00 - 19:30 3.50 WHSUR P WHDTRE RIG UP DSM LUBRICATOR. HAD ISSUES TESTING THE TREE CAP AND MASTER VALVE, CALLED OUT THE GREASE CREW TO GREASE THE VALVES. RE- TESTED. GOOD TEST. 19:30 - 21:00 1.50 WHSUR P WHDTRE TEST THE LUBRICATOR TO 350 PSI LOW / AND 4000 PSI HIGH. PULL THE BPV. 21:00 - 22:00 1.00 WHSUR P DECOMP HOLD THOROUGH PJSM ABOUT DISPLACING THE WELL WITH RIG CREW, MUD ENGINEER, TOURPUSHER, TRUCK PUSHER, AND WSL. 22:00 - 00:00 2.00. WHSUR P DECOMP CIRCULATE THE DIESEL OUT OF THE TUBING AT 3 BPM WITH 300 PSI. PUMPED 105 BBLS AND RECOVERED 105 BBLS. 12/10/2010 00:00 - 03:30 3.50 WHSUR P DECOMP DISPLACE OUT THE ANNULUS WITH 585 BBLS OF 9.8 PPG BRINE AT 4 BPM WITH 500 PSI. 03:30 - 04:00 0.50 WHSUR P DECOMP MONITOR THE WELL, STATIC. 04:00 - 06:00 2.00 WHSUR N WAIT DECOMP WAIT ON DSM TO INSTALL THE TWC. DELAYED AT NORDIC 2 INSTALLING AND TESTING A BPV. 06:00 - 09:30 3.50 WHSUR P DECOMP ATTEMPT TO TEST THE LUBRICATOR TO 250 PSI LOW / 4000 PSI HIGH. COULD NOT GET A TEST ON LUBRICATOR TO 4000 PSI. CALLED OUT THE GREASE CREW AND HAD THE MASTER VALVE GREASED. TOOK SEVERAL MORE ATTEMPTS TO GET THE TEST TO 4000 PSI, BUT DID ACHIEVE A PASSING TEST. 09:30 - 11:30 2.00 WHSUR P DECOMP INSTALL THE TWO WAY CHECK AND TEST TO 1000 PSI FROM BELOW AND 4000 PSI FROM ABOVE. 11:30 - 12:00 0.50 WHSUR P DECOMP RIG DOWN AND REMOVE THE LUBRICATOR FROM THE FLOOR. 12:00 - 14:00 2.00 WHSUR P DECOMP NIPPLE DOWN THE TREE AND REMOVE FROM THE CELLAR. VERIFY THE TUBING HANGER THREADS AND MAKE UP THE CROSSOVER INTO THE TUBING HEAD 11.5 TURNS. BACK OUT AND LAY DOWN THE CROSSOVER. 14:00 - 15:30 1.50 BOPSUR P DECOMP SET THE STACK ON THE TUBING SPOOL AND REMOVE THE DUTCH RISER SYSTEM. 15:30 - 17:00 1.50 BOPSUR P DECOMP INSTALL THE ANNULAR PREVENTER CAP REMOVAL TOOL AND REMOVE THE CAP. 17:00 - 18:00 1.00 BOPSUR P DECOMP REMOVE THE OLD ANNULAR PREVENTER ELEMENT AND CLEAN OUT THE BODY. Printed 2/24/2011 2:12:40PM i7 �, - «rte � LA KA - B ' � 0 ®a:13 ., 0 ' I list - �k�[ [€ � .. [ Common Well Name: WGI -06 AFE No Event Type: WORKOVER (WO) Start Date: 12/2/2010 End Date: 12/18/2010 X4- 00R7H -E (2,461,000.00 ) Project: Prudhoe Bay (various) Site: WGI Rig Name /No.: DOYON 141 Spud Date/Time: Rig Release: 12/18/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: DFE @0.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:00 - 19:15 1.25 BOPSUR P DECOMP INSTALL THE NEW ELEMENT. ATTEMPT TO MAKE UP THE CAP, BUT TORQUED UP AFTER ONLY 3 THREADS ENGAGED. STOP AND CONSULT WITH THE RIG MECHANIC. 19:15 - 20:30 1.25 BOPSUR P DECOMP °' CHANGE OUT THE BOTTOM SET OF RAMS TO 2 -7/8" X 5" WITH NEW ELEMENTS. 20:30 - 00:00 3.50 BOPSUR P DECOMP BACKED OUT THE CAP AND FOUND THAT THE SECOND THREAD WAS GAULD. MECHANIC DRESSED THE THREADS AND MADE UP CAP WITH NO ISSUES. 12/11/2010 00:00 - 02:00 2.00 BOPSUR P DECOMP CHANGE OUT THE TOP RAMS TO 7" CASING RAMS WITH NEW ELEMENTS. 02:00 - 03:30 1.50 BOPSUR P DECOMP NIPPLE DOWN THE 13-3/8" X 11 -5/8" ADAPTOR FLANGE FROM THE BOTTOM OF THE BOP STACK AND NIPPLE UP THE NEW 13 -3/8" X 13 -3/8" ADAPTOR FLANGE. 03:30 - 08:00 4.50 BOPSUR P DECOMP NIPPLE UP THE BOP STACK ON THE WELLHEAD AND RE- VERIFY THE MEASUREMENT FROM THE TUBING HANGER NECK TO THE LOWER RAMS. 08:00 - 09:00 1.00 BOPSUR P DECOMP RIG UP BOP TESTING EQUIPMENT. 09:00 - 11:30 2.50 BOPSUR N WAIT DECOMP HOLD SAFETY STAND DOWN WITH NEUHARTH'S CREW TO EXPLAIN THE RECENT STAND DOWN THAT WAS HELD ON THE RIG DURING THE CREWS DAYS OFF. ALSO, HELD PRE -SPUD AND DISCUSSED CRITICAL WELL OPERATIONS. RWO SUPERINTENDENT JIM WILLINGHAM, TOOL PUSHER CHARLIE HUNTINGTON, AND BP WSL'S DUNCAN FERGUSON AND BILL DECKER. 11:30 - 12:00 0.50 BOPSUR P DECOMP PRESSURE TEST THE BOP BODY TO 250 PSI LOW FOR 5 MINUTES. GOOD TEST. 12:00 - 18:00 6.00 BOPSUR P DECOMP TEST BOPE WITH 4" AND 7" TEST JOINTS TO p A LOW 250 PSI / HIGH 4000 PSI, EXCEPT FOR �01 ANNULAR WHICH WAS TESTED TO 3500 PSI. - EACH TEST CHARTED AND HELD FOR 5 MINUTES. TEST WITNESSED BY BP WSLs DUNCAN FERGUSON AND BILL DECKER. STATES RIGHT TO WITNESS WAIVED BY AOGCC REP BOB NOBLE ON 12/09/2010 @ 19:00 HRS. 18:00 - 18:30 0.50 BOPSUR P DECOMP BLOW DOWN CHOKE MANIFOLD AND KILL LINE. 18:30 - 19:15 0.75 DHB P DECOMP PICK UP AND INSTALL THE DUTCH RISER EXTENSION AND INSTALL THE LUBRICATOR. 19:15 - 20:15 1.00 DHB P DECOMP TEST THE LUBRICATOR TO 250 PSI LOW AND 4000 PSI HIGH. GOOD TEST. PULL THE TWC. -HOLD RIG EVACUATION DRILL WITH WILLIAMS' CREW, CRT 3 MIN 15 SEC. HOLD AAR AFTER. 20:15 - 22:15 2.00 CASING P DECOMP MAKE UP TIW TO 7" LTC CROSSOVER AND POSITION ON THE RIG FLOOR FOR WELL CONTROL. POSITION A JOINT OF DRILL PIPE IN THE OFF DRILLERS SIDE FOR WELL CONTROL. Printed 2/24/2011 2:12:40PM rth America �` „ €ll € € i a* 7 0 Common Well Name: WGI -06 AFE No Event Type: WORKOVER (WO) Start Date: 12/2/2010 End Date: 12/18/2010 X4- 00R7H -E (2,461,000.00 ) Project: Prudhoe Bay (various) Site: WGI Rig Name /No.: DOYON 141 Spud Date/Time: Rig Release: 12/18/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: DFE @0.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:15 - 23:00 0.75 CASING P DECOMP MAKE UP 7” LH ACME CROSSOVER TO A JOINT OF DRILL PIPE AND SCREW INTO THE 7" CASING HANGER. BOLDS AND PULL HANGER TO THE RIG FLOOR WITH 225K UP WT. 23:00 - 00:00 1.00 CASING P DECOMP WELL STATIC. SHUT IN THE ANNULAR AND CIRCULATE AT 2 BPM WITH 50 PSI THROUGH THE CHOKE AND GAS BUSTER AS A SAFETY PRECAUTION. 12/12/2010 00:00 - 02:00 2.00 CASING P DECOMP SHUT IN THE ANNULAR AND CIRCULATE AT 2 BPM WITH 50 PSI THROUGH THE CHOKE AND GAS BUSTER AS A SAFETY PRECAUTION. 02:00 - 03:00 1.00 CASING P DECOMP RIG UP CASING EQUIPMENT AND CONTROL LINE SPOOLER. PREPARE TO PULL 7" CASING. 03:00 - 03:30 0.50 CASING P DECOMP BREAK OUT THE LANDING JT AND CROSSOVER, LAY DOWN THE TUBING HANGER. ALL. PIECES WERE INTACT. 03:30 - 13:00 9.50 CASING P DECOMP PULL 7" 26# L -80, LTC COMPLETION. AS FOLLOWS: - 198 JTS. OF 7" 26# L -80, LTC TUBING - 4 PUP JTS. - SSSV - DUAL CONTROL LINE AND 52 STAINLESS STEEL BANDS. - 5.5" CUT JOINT 2.31' LONG. 6.4" FLARE ON THE CUT. - HELD SPILL DRILL WITH NEUHARTH'S CREW, CRT 1 MIN 54 SEC. 13:00 - 13:30 0.50 CASING P DECOMP KICK WHILE TRIPPING DRILL WITH WILLIAMS' CREW. AAR HELD AFTER 13:30 - 15:15 1.75 CASING P DECOMP RIG DOWN AND LAY DOWN CASING EQUIPMENT. 15:15 - 16:30 1.25 CLEAN P DECOMP CLEAN AND CLEAR THE RIG FLOOR. LOAD THE SHED WITH 6.25" DRILL COLLARS AND PICK UP BACKER FISHING TOOLS. 16:30 - 17:30 1.00 CLEAN P DECOMP INSTALL THE WEAR RING. 17:30 - 19:30 2.00 CLEAN P DECOMP PICK UP BAKER FISHING BHA. - 5.5" TUBING SPEAR WITH 4.805" NOMINAL GRAPPLE - BUMPER SUB - OIL JAR - PUMPOUT OUT SUB - (9) 6.25" DRILL COLLARS - INTENSIFIER - X -OVER 19:30 - 00:00 4.50 CLEAN P DECOMP SINGLE IN THE HOLE WITH 4" DRILL PIPE FROM THE SHED TO 5257'. -UPWT. 124K /DOWN WT. 118K 12/13/2010 00:00 - 02:00 2.00 CLEAN P DECOMP CONTINUE RUNNING IN THE HOLE ON 4" DRILL PIPE. ESTABLISH CIRCULATION AT 6 BPM WITH 820 PSI AND 3 BPM WITH 210 PSI. - UP WT. 170K / DOWN 140K - FIRE DRILL WITH NEUHARTH'S CREW, CRT 1 MIN 38 SEC. Printed 2/24/2011 2:12:40PM 1 3 Meith America kA �f. Operation Sum L Rep rt ' , Common Well Name: WGI -06 AFE No Event Type: WORKOVER (WO) Start Date: 12/2/2010 End Date: 12/18/2010 X4- 00R7H -E (2,461,000.00 ) Project: Prudhoe Bay (various) Site: WGI Rig Name /No.: DOYON 141 Spud Date/Time: Rig Release: 12/18/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: DFE @0.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:00 - 03:15 1.25 CLEAN P DECOMP PUMP AT 3 BPM WITH 210 PSI WHILE ENGAGING FISH. PRESSURE INCREASE TO 300 PSI AS SPEAR ENTERED THE LOCATOR SEAL. PICKED UP TO VERIFY SPEAR WAS ENGAGED IN THE FISH. JAR UP STARTING AT 200K AND AT 250K PULLED LOCATOR SEAL ASSEMBLY FREE. 03:15 - 11:30 8.25 CLEAN P DECOMP PULL AND RACK BACK ONE STAND. CLOSE ANNULAR. CIRCULATE AT 3 BPM WITH 200 PSI. FOR ONE BOTTOMS UP. OPEN WELL AND MONITOR FOR 10 MINUTES. NOT STATIC, SOME BUBBLES AND SLOW BOILING IN THE RISER. CLOSE ANNULAR. CIRCULATE ONE AND A HALF BOTTOMS UP . BRINE WEIGHT IN AND OUT 9.8 PPG. OPEN WELL. 11:30 - 12:00 0.50 CLEAN P DECOMP MONITOR WELL. STATIC. BLOW DOWN CHOKE LINES AND -TOP DRIVE. 12:00 - 16:00 4.00 CLEAN P DECOMP POH WITH `FISHING BHA. STAND BACK 4" DRILL PIPE. HOLE TAKING CORRECT FILL. BRINE WEIGHT IN AND OUT 9.8 PPG 16:00 - 17:30 1.50 CLEAN P DECOMP LAY DOWN THE FISHING BHA AND FISH. THE LENGTH OF THE LOCATOR SEAL ASSEMBLY FISH IS 18.67'. ALL SEALS WERE INTACT. 17:30 - 18:00 0.50 CLEAN P DECOMP MONITOR THE WELL. STATIC. 18:00 - 19:00 1.00 CLEAN P DECOMP PICK UP 9 -5/8" CASING SCRAPER AND MAKE UP AS FOLLOWS: - 5" BULL NOSE - PUP JOINT - DOUBLE PIN X OVER - CASING SCRAPER - BIT SUB - OIL JARS - PUMPOUT SUB - (9) DRILL COLLARS - X OVER 19:00 - 00:00 5.00 CLEAN P DECOMP RUN IN THE HOLE ON4" DRILL PIPE FROM THE DERRICK. RECIPROCATE 4 TIMES FROM 8018' TO 8107'. RUN IN THE HOLE FROM 8107' TO 8205'. 12/14/2010 00:00 - 01:30 1.50 CLEAN P DECOMP WASH DOWN FROM 8205' TO 8296' AT 2 BPM WITH 100 PSI. TAG PACKER AT 8285' WITH BOTTOM OF THE BULLNOSE AT 8296'. 01:30 - 03:30 2.00 CLEAN P DECOMP DISPLACE WELL FROM 9.8 PPG BRINE TO CLEAN 110 DEGREE 9.8 PPG BRINE AT 8 BPM WITH 225 PSI. 555 BBLS IN AND 555 BBLS OUT. 03:30 - 03:45 0.25 CLEAN P DECOMP CLEAN AND CLEAR THE FLOOR, BLOW DOWN THE TOP DRIVE. 03:45 - 04:30 0.75 CLEAN P DECOMP LAY DOWN 12 JOINTS OF DRILL PIPE AND RACK BACK 1 STAND TO USE FOR PICKING UP AND SETTING THE RTTS. - HOLD KICK WHILE TRIPPING DRILL WITH NEUHARTH'S CREW, CRT 1 MIN 54 SEC. 04:30 - 06:00 1.50 DHB P DECOMP PICK UP THE 9 -5/8" RTTS, RUN IN THE HOLE 1 STAND AND SET AT 99.65'. TEST TO 1000 PSI FOR 10 MINUTES FROM ABOVE. GOOD TEST. OPEN UP THE OA TO THE CELLAR TANK FOR CONSTANT MONITORING. CLEAR RIG FLOOR Printed 2/24/2011 2:12:40PM .=t ' illiv tthe .0 11 410Orth America ket- . i� t Operation. S mi .R@ ®q1° � ttkr, _ Common Well Name: WGI -06 AFE No Event Type: WORKOVER (WO) Start Date: 12/2/2010 End Date: 12/18/2010 X4- 00R7H -E (2,461,000.00 ) Project: Prudhoe Bay (various) Site: WGI Rig Name /No.: DOYON 141 Spud Date/Time: Rig Release: 12/18/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: DFE @0.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 09:30 3.50 BOPSUR P DECOMP PULL WEAR BUSHING. NIPPLE DOWN THE BOP AND TUBING SPOOL. LIFT BOP AND TUBING SPOOL TOGETHER TO UNSEAT FROM 9 5/8" CASING STUB WITH BRIDGE CRANE. SET BOP AND TUBING SPOOL DOWN ON WELL HEAD. DISCONNECT TUBING SPOOL AND STAND BACK BOP. 09:30 - 11:00 1.50 BOPSUR P DECOMP CHANGE TOP RAMS FROM 7" TO NEW 7 5/8" FIXED RAMS.' - 11:00 - 12:00 1.00 WHSUR P DECOMP NIPPLE DOWN 13 -5/8" TUBING SPOOL. REMOVE "INNER ANNULUS VALVES FROM TUBING SPOOL. 12:00 - 14:00 2.00 WHSUR P DECOMP PJSM - NIPPLE DOWN OLD TUBING SPOOL. M/U PACKOFF RUNNING TOOL TO 4" DP JT. PULLED CASING PACKOFF WITH 12K UPWEIGHT. INSTALLED NEW CASING PACKOFF. 14:00 - 17:30 3.50 WHSUR P DECOMP NIPPI FD UP NEW TUBING SPOOL CAMERON WELLHEAD REP. PRESSURE TESTED CASING PACKOFF TO 250 -PSI LO /5000 -PSI HI FOR 30- MINUTES. RIG UP TEST EQUIPMENT FOR TESTING 7 -5/8" CASING RAMS. 17:30 - 19:00 1.50 BOPSUR P DECOMP NIPPLED UP BOP STACK. 19:00 - 22:00 3.00 BOPSUR P DECOMP PRESSURE TESTED 7 -5/8" CASING RAMS PER BP /AOGCC REQUIREMENTS TO 250 -PSI (pp LO /4000 -PSI HI FOR 5 MINUTES EACH TEST PRESSURE. EXPERIENCED DIFFICULTIES IN GETTING BOP TEST PLUG TO SEAL. 22:00 - 22:30 0.50 BOPSUR P DECOMP LAY DOWN 7 -5/8" TEST JT. AND TEST PLUG. 22:30 - 22:45 0.25 CLEAN P DECOMP PICK UP AND SET 9 -1/8" WEAR BUSHING. 22:45 - 00:00 1.25 CLEAN P DECOMP PJSM - SLIP AND CUT DRILLING LINE. SLIPPED AND CUT DRILLING LINE. 12/15/2010 00:00 - 00:30 0.50 CLEAN P DECOMP SERVICE TOP DRIVE AND DRAWWORKS AND FINISH UP WITH SLIPPING AND CUTTING DRILLING LINE. 00:30 - 01:30 1.00 CLEAN P DECOMP MAKE UP 9 -5/8" NALCO RTTS PACKER RETRIEVING TOOL ON STAND OF DP. SCREW CLOSED FLOOR SAFETY VALVE IN TOP OF STAND WITH 5 FT. DP PUP INTO TOP OF FLOOR SAFETY VALVE. SCREW INTO PACKER WITH RETRIEVING TOOL AND OPEN EQUALIZING VALVE. OPENED FLOOR SAFETY VALVE AND OBSERVED 0 -PSI ON DRILLPIPE. SCREWED INTO 5 FT. 4" XT -39 DRILLPIPE PUP WITH TOP DRIVE. CLOSE ANNULAR PREVENTER AND UNSET PACKER. OBSERVED 0 -PSI ON ANNULUS AND 0 -PSI ON DRILLPIPE. OPENED ANNULAR PREVENTER. LAYED DOWN 5 FT. DP PUP AND FLOOR SAFETY VALVE. LAYED DOWN 3 JTS. OF 4" XT -39 DRILLPIPE AND 9 -5/8" HALCO RTTS PACKER. Printed 2/24/2011 2:12:40PM 0 ®rrtrrea LIAP �R ' _ er f1' ary Reps ' .� - , Common Well Name: WGI -06 AFE No Event Type: WORKOVER (WO) Start Date: 12/2/2010 End Date: 12/18/2010 X4- 00R7H -E (2,461,000.00 ) Project: Prudhoe Bay (various) Site: WGI Rig Name /No.: DOYON 141 Spud Date/Time: Rig Release: 12/18/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: DFE @0.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:30 - 02:00 0.50 CLEAN P DECOMP POH LAYING DOWN 4" XT -39 DRILLPIPE 1 X 1 THROUGH PIPE SHED. LAYED DOWN 3 JTS. 4" XT -39 DP AND FLOW COMMENCED FROM DRILLPIPE. PULLED ADDITIONAL 2 JTS. AND DRILLPIPE CONTINUED TO FLOW. DRILLPIPE AND ANNULUS ARE OUT OF BALANCE. 02:00 - 03:30 1.50 CLEAN P DECOMP SCREW INTO DRILLPIPE WITH TOP DRIVE. CIRCULATED WELL TO CONDITION BRINE. CBU. SHUT DOWN PUMP AND OBSERVED WELL FOR 15 MINUTES. NO FLOW. 03:30 - 06:00 2.50 CLEAN P DECOMP POH LAYING DOWN 4" DRILLPIPE 1 X 1 THROUGH`' PIPE SHED. 06:00 - 09:00 3.00 CLEAN P DECOMP CONTINUE POH LAYING DOWN 4" DRILLPIPE 1 X 1 THROUGH PIPE SHED TO 311'. 09:00 - 10:00 1.00 CLEAN P DECOMP MONITOR WELL FOR FLOW AT BHA. NO FLOW NOTED. 10:00 - 10:30 0.50 CLEAN P DECOMP BREAK OUT AND LAY DOWN BHA #2: 9 -5/8" CASING SCRAPER. 10:30 - 11:00 0.50 CLEAN P DECOMP CLEAR AND CLEAN RIG FLOOR. 11:00 - 12:00 1.00 RUNCOM P RUNCMP RIG UP 7 -5/8" TUBING HANDLING/RUNNING TOOLS TO RIG FLOOR. 12:00 - 13:30 1.50 RUNCOM P RUNCMP PJSM - RUNNING PREMIUM COMPLETION TUBING. MADE DUMMY RUN WITH 4" XT -39 DRILLPIPE LANDING JOINT AND MCEVOY SSH 13" X 7" TUBING HANGER. VERIFIED LANDING TO CORRECT DEPTH INTO TUBING SPOOL AND MARKED LANDING JOINT AT ROTARY TABLE. MADE UP FLOOR SAFETY VALVE TO 4" XT -39 X 4 -1/2" IF B X P XO AND 4 -1/2" IF X 7" TCII B X P XO FOR WELL CONTROL. MADE UP DART VALVE TO SINGLE JOINT OF 4" XT -39 DP AND STAGED IN PIPE SHED FOR WELL CONTROL. 13:30 - 14:30 1.00 RUNCOM P RUNCMP RIH WITH COMPLETION ,IEWFI RY PFR PLANNED RUNNING ORDER AND VERIFIED PLACEMENT OF RN NIPPLE WITH RHC PLUG BODY BELOW PACKER. BAKER -LOK'D AND TORQUE TURNED ALL 7 ", 26# L -80 TCII CONNECTIONS BELOW PACKER TO 10,100 FT -LBS. VERIFIED MAKEUP OF ALL CONNECTIONS ON TORQUE TURN COMPUTER. BAKER COMPLETIONS REPRESENTATIVE, DRILLER AND WSL VERIFIED PROPER PLACEMENT OF COMPLETION HARDWARE BELOW PACKER IS IN CORRECT ORDER PER PLANNED RUNNING ORDER. 14:30 - 21:00 6.50 RUNCOM P RUNCMP MADE UP FLOOR SAFETY VALVE WITH XO FOR 7 -5/8" 29.7# L -80 VAM TOP HC TUBING. CHANGED OUT ELEVATORS TO RUN 7 -5/8" TUBING AND RESUMED RIH WITH COMPLETION. TORQUE TURNED ALL CONNECTIONS TO 14,450 FT -LBS. AND VERIFIED MAKEUP OF ALL CONNECTIONS ON TORQUE TURN COMPUTER. APPLIED JET LUBE SEALGUARD THREAD COMPOUND ON ALL VAM TOP CONNECTIONS WITH PRESCRIBED MUSTACHE BRUSH. UTILIZED STABBING GUIDE WHEN STABBING EACH CONNECTION. Printed 2/24/2011 2:12:40PM �Orth A Tgo 11 e i € ., : '°� "rw,.. — R , 41 r t ip �h.. 3 � — .elf ' '' 4 Common Well Name: WGI -06 AFE No Event Type: WORKOVER (WO) Start Date: 12/2/2010 End Date: 12/18/2010 X4- 00R7H -E (2,461,000.00 ) Project: Prudhoe Bay (various) Site: WGI Rig Name /No.: DOYON 141 Spud Date/Time: Rig Release: 12/18/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: DFE @0.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:00 - 23:00 2.00 RUNCOM N RREP 4,118.00 RUNCMP PIPE SKATE MALFUNCTION BEING INVESTIGATED AND REPAIRED. REPLACED CONTROL CABLE AND TESTED FUNCTION OF PIPE SKATE. 23:00 - 00:00 1.00 RUNCOM P RUNCMP ' RESUME RIH WITH 7 -5/8" COMPLETION TUBING. 97 JTS. RIH AT 00:00 -HRS. 99 JTS. REMAINING TO RIH. 12/16/2010 00:00 - 05:30 5.50 RUNCOM P RUNCMP CONTINUE RIH WITH 7 -5/8" COMPLETION TUBING. 147 JTS. RIH AT 02:30 -HRS. 05:30 - 06:30 1.00 RUNCOM P RUNCMP PU /MU 4" XT-39 DRILLPIPE LANDING JT. WITH XO TO 7" TCII AND MAKEUP TO MCEVOY SSH 13" X'7" TUBING HANGER WITH XO PUP TO 7 -5/8" VAM TOP HC. MADE UP SAME TO 7 -5/8" STUMP. CAMERON WELLHEAD REPRESENTATIVE INSPECTED AND VERIFIED SEAL ELEMENT IS CORRECT AND IN GOOD CONDITION AND THAT CONTROL LINE PORT PLUGS ARE TEFLON TAPED AND TIGHT. COATED HANGER AND SEALING ELEMENT WITH JET LUBE SEALGUARD THREAD COMPOUND. P/U WT. = 235K, S/O WT. = 215K. LANDED TUBING HANGER. 7" WLEG AT 8,190' MD. TOP OF OLD PACKER AT 8,285'. 06:30 - 07:30 1.00 RUNCOM P RUNCMP RIG DOWN TUBING RUNNING/HANDLING TOOLS. CLEAR AND CLEAN RIG FLOOR. 07:30 - 11:30 4.00 RUNCOM P RUNCMP PJSM. REVERSE CIRCULATE 375 -BBLS. II 9.8 -PPG 120F BRINE AT 3.0 -BPM AND 300 -PSI. REVERSE CIRCULATE 100 -BBLS CORROSION INHIBITED 9.8 -PPG BRINE AT 3.0 -BPM AT 300 -PSI. 11:30 - 12:00 0.50 RUNCOM P RUNCMP PJSM - MIRU LRS FOR FREEZE PROTECT WELL. 12:00 - 13:30 1.50 RUNCOM P RUNCMP LRS P/T LINES TO 3500 -PSI. LRS REVERSE CIRCULATED 40 -BBLS. DIESEL INTO VA AT 3.0 -BPM AT 300 -PSI. WITH RETURNS TO ROCK WASHER. RIG DOWN LRS. CLOSED HCR CHOKE . BLEW DOWN MUD MANIFOLD. ALLOW U -TUBE VA TO TUBING THROUGH CEMENT LINE TO HCR KILL LINE. SIMOPS PJSM, REMOVE OLD TUBING SPOOL FROM CELLAR AND STAGE NEW WELLHEAD/ DRY HOLE TREE EQUIPMENT IN CELLAR. Printed 2/24/2011 2:12:40PM cr i' 404-ALASKA 1 BP pc ® 1 , ;, � E _ � p e IinaS ffi Ew mary Report � � �� a':+ � �� _ �` ft= Common Well Name: WGI -06 AFE No Event Type: WORKOVER (WO) Start Date: 12/2/2010 End Date: 12/18/2010 X4- 00R7H -E (2,461,000.00 ) Project: Prudhoe Bay (various) Site: WGI Rig Name /No.: DOYON 141 Spud Date/Time: Rig Release: 12/18/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: DFE @0.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:30 - 20:30 7.00 RUNCOM P RUNCMP MONITORED WELL - NO FLOW. OPENED BLIND /SHEAR RAMS, INSTALLED LANDING JOINT AND DROPPED BALL & ROD. LAYED DOWN LANDING JOINT. ESTABLISHED CIRCULATION THROUGH HCR KILL. CLOSED BLIND /SHEAR RAMS WITH VA OPEN TO RIG PITS. PRESSURED UP TUBING TO 4000 -PSI TO SET PACKER AND TEST TUBING. HELD 4000 -PSI FOR 30- CHARTED MINUTES ON TUBING (GOOD TEST). BLED TUBING PRESSURE OFF TO 1500 -PSI. PRESSURED UP VA TO 4000 -PSI. I/A PRESSURE BLED OFF TO 3500 -PSI AND TUBING PRESSURE INCREASED TO 3400 -PSI. BLED VA TO 0 -PSI AND TUBING DECREASD TO 2600 -PSI AND STABILIZED. BLED TUBING TO 1500 -PSI. ATTEMPT TEST VA AGAIN TO 4000 -PSI. I/A DECREASED TO 3650 -PSI AND TUBING INCREASED TO 2700 -PSI. BLED VA AND TUBING TO 0 -PSI. PRESSURED UP TUBING TO 4500 -PSI AND HELD FOR 20- MINUTES PER BAKER REP WITH VA OPEN TO PITS. TUBING PRESSURE DECREASED TO 4400 -PSI. BLED TUBING TO 1500 -PSI. PRESSURED VA TO 4000 -PSI. TUBING INCREASED TO 2400 -PSI WHILE INCREASING TUBING PRESSURE AND THEN BEGAN EQUALIZING WITH TUBING. BLED OFF VA AND TUBING AND OPENED BLIND /SHEAR RAMS. INSTALLED 4" XT -39 DRILLPIPE LANDING JT. WITH FLOOR SAFETY VALVE AND BLEEDER LINE TO RIG FLOOR. PRESSURED UP VA TO 2000 -PSI. TUBING FLOWING COTINUOUS 1/2" STREAM AND PRESSURE DROPPED TO 1700 -PSI OVER 10- MINUTES. BLED OFF VA. PRESSURE UP VA TO 2000 -PSI AND VERIFIED COMMUNICATION TUBING TO VA. TUBING PRESSURE DROPPED TO 1500 -PSI IN 25- MINUTES. BLED OFF VA. 20:30 - 00:00 3.50 RUNCOM P RUNCMP MADE UP TOP DRIVE TO LANDING JOINT AND TUBING HANGER. CAMERON BACKED OUT LOCKDOWN SCREWS. PRESSURED UP TUBING TO 2500 -PSI AND PULLED UP TO 50K OVER STRING PICKUP WEIGHT OF 235K TO ASSIST PACKER SETTING. RELANDED TUBING HANGER, BLED OFF TUBING PRESSURE TO 0 -PSI AND CAMERON RAN IN LOCKDOWN SCREWS. LAYED DOWN LANDING JOINT. BLEW DOWN TOP DRIVE. PRESSURED UP TUBING TO 4000 -PSI FOR 30- CHARTED MINUTES (GOOD TEST). BLED TUBING TO 1500 -PSI. PRESSURED UP VA TO 4000 -PSI. I/A DECREASED TO 3400 -PSI IN 10- MINUTES AND TUBING INCREASED TO 2400 -PSI. I/A STABILIZED AT 3400 -PSI AND TUBING STABILIZED AT 2500 -PSI. 12/17/2010 00:00 - 02:00 2.00 DHB P DECOMP RIG UP AND SET DUTCH LUBRICATOR LOCKDOWN MANDREL, RUN IN LOCKDOWN SCREWS AND CLOSE ANNULAR PREVENTER. LOAD SLICKLINE BOPS TO RIG FLOOR AND SLICKLINE LUBRICATOR TO PIPESHED. 02:00 - 02:15 0.25 DHB P DECOMP PJSM - RIGGING UP SLICKLINE. Printed 2/24/2011 2:12:40PM � ortk A`rri I •� BP : Page 1 M:t b erOtCrnt * 0 ° ; .� - ` , Common Well Name: WGI -06 AFE No Event Type: WORKOVER (WO) Start Date: 12/2/2010 End Date: 12/18/2010 X4- 00R7H -E (2,461,000.00 ) Project: Prudhoe Bay (various) Site: WGI Rig Name /No.: DOYON 141 Spud Date/Time: Rig Release: 12/18/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: DFE @0.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:15 - 04:30 2.25 DHB P DECOMP RIG UP SWS SLICKLINE UNIT WITH FULL PRESSURE CONTROL. PRESSURE TEST LUBRICATOR TO 250 -PSI LO /3500 -PSI HI FOR 5- CHARTED MINUTES. 04:30 - 12:00 7.50 DHB P DECOMP RIH WITH SLICKLINE. RECOVER BALL AND ROD FROM RN NIPPLE AT 8171'. RIH WITH SLICK LINE, RECOVER RHC -M SLEVE FROM RN NIPPLE AT 8171' RIH WITH SLICK LINE WITH JUNK CATCHER. HELD UP AT 7 5/8" X 4 1/2" XO AT 8317'. POH AND LAY DOWN JUNK CATCHER. RIH WITH LIB TO IDENTIFY OBSTRUCTION. INSTRUCTIONS RECEIVED FROM ANCHORAGE AT 11:00 HRS TO STOP - DECOMPLETE OPERATIONS. 12:00 - 12:30 0.50 DHB P DECOMP PJSM: RD SLICKLINE. POH WITH SLICK LINE L.I.B. AND LAY.DOWN SAME. RIG DOWN SWS SLICK LINE UNIT. CLEAR RIG FLOOR. 12:30 - 14:00 1.50 RUNCOM P RUNCMP SAFETY STAND DOWN WITH NEW CREW. REVIEWED BP'S CRITICAL WELL POLICY AND SAFETY CRITICAL EQUIPMENT CHECKLIST REQUIREMENTS. CREWS, TOOLPUSHER, WSL AND RWO SUPERINTENDENT IN ATTENDANCE 14:00 - 15:00 1.00 RUNCOM P RUNCMP RIG DOWN LINES IN CELLAR. 15:00 - 17:30 2.50 RUNCOM P RUNCMP RIH WITH 7 JTS. OF 4" XT -39 DRILLPIPE, MAKEUP FLOOR SAFETY VALVE AND HEADPIN. MIRU LRS. FREEZE PROTECT TUBING WITH 12 -BBLS. DIESEL. RDMO LRS. POH UD 7 JTS. DRILLPIPE. 17:30 - 21:00 3.50 WHSUR P WHDTRE RIG UP DUTCH LOCKDOWN LUBRICATOR MANDREL. PICK UP AND MAKE UP LUBRICATOR AND TEST SAME TO 500 -PSI. TEST VERIFIED BY DSM PERSONNEL. SET TWC. 21:00 - 21:30 0.50 WHSUR P WHDTRE PRESSURE TEST TWC FROM ABOVE TO 400 -PSI LO AND 4000 -PSI FROM ABOVE FOR ✓ 10- CHARTED MINUTES EACH TEST. UNABLE TO TEST TWC FROM BELOW DUE TO ABSENCE OF FLOW PATH FROM VA TO TUBING. 21:30 - 22:30 1.00 BOPSUR P WHDTRE PJSM - NDBOPE. REVIEWEDSWEENEY WRENCH OPERATION AND PINCH POINTS. ND BOPE. INSPECT AND CLEAN OFF TOP OF TYPE "J" TWC. 22:30 - 00:00 1.50 WHSUR P WHDTRE NU TUBING HEAD ADAPTER FLANGE AND TWO VALVE DRY HOLE TREE. 12/18/2010 00:00 - 09:30 9.50 WHSUR P WHDTRE PRESSURE TEST ADAPTER FLANGE API RING SEAL, HANGER SEALS AND HANGER VOID TO 5000 -PSI FOR 30 MINUTES. DSM PULLED TWC AND SET BPV. DID NOT PRESSURE TEST BPV FROM BELOW SINCE THERE IS NO FLOW PATH FROM VA TO TUBING. 09:30 - 12:00 2.50 WHSUR P WHDTRE CAMERON DRESS WELLHEAD WITH VALVES AND GAUGES. CLEAN AND EMPTY RIG PITS AND ROCKWASHER. SECURE TREE AND CELLAR. PREP RIG FOR MOVE TO NGI -14. RELEASE RIG AT 12:00 -HRS. Printed 2/24/2011 2:12:40PM 4Q2010 Not Operable Injector Report • Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWefllntegrityCoordinator @bp.com] Sent: Saturday, February 19, 2011 2:43 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy 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; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 4Q2010 Not Operable Injector Report Attachments: Not Operable Injector Report 4Q2010.zip Hello Tom, Jim, Phoebe and Guy, Attached is the 4Q 2010 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 4Q2010.zip» Notes on wells: r U' k Clef Removed from Quarterly Injection Report: (� B1 -14: Passed AOGCC MITIA with Badami field restart R -13: Furmanite wrap repaired startinghead leak. Added to Quarterly Injection Report: MPF -92: Added until injection is requested. MPF -95: Added until injection is requested. MPL -09: Added until Furmanite clamp is fabricated and installed to mitigate startinghead leak. Z -12: Added until TxIA communication is repaired. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 2/22/2011 Well WGI -06 Injection Plot Well: WGI -06 PrpssttrP vs Rare TIO Plot O PTD #: 1900300 AA: 4E.008 -- _ Tbg -- IA Approval: 5/31/06 OA Reason: Slow TxIA • m ° o Monthly report a Q 4 -year MITIA 9/25/06 a — a IAP monitoring equipment I" 1 Y Monthly Report w /flagged o IA bleeds Secured w/ TTP 03/15/10 due to • •Last 90 days •Last Month I TxIA o • Plan forward is to set a patch 0 0 0 1 1 1 0 pending LDL results. 6/18/10 9/8/10 11/29/10 2/19/11 Injection Rate, MCFPD Volume Injected Tubing Pressure Tbg Press IA Press OA Press S 1 11/4..\ 1 S ` -Q k Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 01/01/11 0 0 01/01/11 0 10 10 12/31/10 0 0 12/31/10 0 10 10 12/30/10 0 0 12/30/10 0 10 10 12/29/10 0 0 12/29/10 0 10 10 12/28/10 0 0 12/27/10 0 10 10 12/27/10 0 0 12/26/10 0 10 10 12/26/10 0 0 12/24/10 0 10 10 12/25/10 0 0 12/23/10 0 10 10 12/24/10 0 -100 12/22/10 0 10 10 12/23/10 0 -100 12/21/10 0 10 10 12/22/10 0 -100 12/20/10 0 10 10 12/21/10 0 -100 12/19/10 0 10 10 • 12/20/10 0 -100 12/18/10 0 10 10 12/19/10 0 -100 12/17/10 0 10 10 12/18/10 0 -100 12/16/10 0 10 10 12/17/10 0 -100 12/15/10 0 100 10 12/16/10 0 -100 12/14/10 0 100 10 12/15/10 0 -100 12/13/10 0 100 10 12/14/10 0 -100 12/12/10 0 100 10 12/13/10 0 -100 12/11/10 0 100 10 12/12/10 0 -100 12/10/10 0 100 10 12/11/10 0 -100 12/09/10 0 100 10 12/10/10 0 -100 12/08/10 0 100 10 12/09/10 0 -100 12/07/10 0 100 10 12/08/10 0 -100 12/06/10 0 100 10 12/07/10 0 -100 12/05/10 0 100 10 12/06/10 0 -100 12/04/10 0 100 10 12/05/10 0 -100 12/03/10 0 0 0 12/04/10 0 -100 12/02/10 0 0 0 12/03/10 0 -100 12/01/10 0 0 0 12/02/10 0 -100 11/30/10 0 0 0 WGI -06 PTD 190 -030 sundry 310 -206 Page 1 of 3 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, December 17, 2010 11:25 AM To: 'Bjork, David' Cc: Stewman, Sondra D; Barker, Elizabeth R (SAIC); Reem, David C Subject: RE: WGI -06 (PTD 190 -030) sundry 310 -206 Dave, Ok.. sounds like regrouping is the right answer for this well. Please send me a outline of what you plan to do to secure the well. Thanks, Regards, Guy Schwartz EV 0E!, i! 7 ZU10 Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Bjork, David [mailto: David. Bjork@bp.com] Sent: Friday, December 17, 2010 10:56 AM To: Schwartz, Guy L (DOA) Cc: Stewman, Sondra D; Barker, Elizabeth R (SAIC); Reem, David C Subject: RE: WGI -06 (PTD 190 -030 ) sundry 310 -206 Guy, We will stop the current operations, and come back with a plan to repair the well. thanks, Dave From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Friday, December 17, 2010 10:28 AM To: Bjork, David Cc: Stewman, Sondra D; Barker, Elizabeth R (SAIC); Reem, David C Subject: RE: WGI -06 (PTD 190 -030 ) sundry 310 -206 Dave, I reviewed the 9 5/8" Cement bond log and I don't think it would be prudent to move the packer uphole. Cement coverage is poor at best and essentially stops at about 7700' md. I cannot approve your proposed changes below.... Please call to discuss other options. Guy Schwartz Senior Petroleum Engineer AOGCC 12/17/2010 WGI -06 PTD 190 -030 sundry 310 -206 Page 2 of 3 793 -1226 (office) 444 -3433 (cell) From: Bjork, David [mailto: David. Bjork @bp.com] Sent: Friday, December 17, 2010 9:41 AM To: Schwartz, Guy L (DOA) Cc: Stewman, Sondra D; Barker, Elizabeth R (SAIC); Reem, David C Subject: RE: WGI -06 PTD 190 -030 sundry 310 -206 Guy, After running the new completion, we were unable to get a passing IA test, it appears the S -3 Packer is leaking. We would like to perform the following steps to re- complete the well. Also attached is a revised schematic. Please call with any questions or comments. Regards, Dave Bjork 564 -5683, 440 -0331 1. RU SLB slickiline on Doyon 141 with full pressure control. RIH and pull ball -n -rod and RHC seat from the RN nipple at 8,171'. Set a 4 -1/2" junk catcher in the 4 -1/2" tailpipe below the original completion at 8,298'. Concurrently load the pits with 9.8 -ppg brine and have 2 (290 -bbl) vac trucks of seawater on location at all times. 2. RIH with Baker multistring cutter on 4" drill pipe. Max knife throw set to no more than 8 ". RIH and cut the 7- 5/8" tubing 15' above the 7 -5/8" x 7" crossover at 7,965'. POOH SDDP. 3. Pull and lay down the 7 -5/8" VamTop HC. Install thread protectors and send the tubing string in for inspection. 4. RIH with a dress off / casing scraper assembly on DP. Dress and bevel the 7 -5/8" cut, swap over to clean brine. POOH LDDP. 5. Run new completion and space out Wireline Re -Entry Guide -100' above the cut joint at 7.965', the upper packer depth will be - 7,791'. 6. Freeze protect, set packer, test the tubing to 4,000 -psi, test the casing P to 4,000-psi. Install TWC 7. ND BOPE/ NU Tree and test 8. RDMO From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Friday, November 12, 2010 10:00 AM To: Bjork, David Subject: RE: WGI -06 PTD 190 -030 sundry 310 -206 Dave, Thanks for the updated program... I will supercede the previous version in our well file... Guy Schwartz Senior Petroleum Engineer 12/17/2010 WGI -06 PTD 190 -030 sundry 310 -206 Page 3 of 3 AOGCC 793 -1226 (office) 444 -3433 (cell) From: Bjork, David [mailto: David. Bjork@bp.com] Sent: Thursday, November 11, 2010 8:36 AM To: Schwartz, Guy L (DOA) Cc: Reem, David Q Barker, Elizabeth R (SAIL) Subject: WGI -06 PTD 190 -030 sundry 310 -206 Guy, Attached is a revised scope of work for WGI -06 RWO. The current plan is to utilize Doyon 141 instead of Doyon 16 for the workover. Doyon 141 can accommodate a 4 preventer stack while performing the workover. Regards, Dave <<AOGCC Scope of Work WGI -06 revision 2.ZIP>> 12/17/2010 TREE = 6 -3/8" CAMERON \ /� J G I 0 G V WELLHEAD = MCEVOY v V ACTUATOR= BAKER Proposed RWO KB. B-E\/ = 60' BF. ELEV = KOP= 4000' 13 -3/8" CSG, 68 #, 71' Max Angle = 31 @ 9200' K -55, ID = 12.415" Datum MD = WA i 2,200' 7" GAMCO DB -6 ID = 6.00" Datum TV D = 8800' SS I 13 -3/8" CSG, 68 #, L -80, ID = 12.415" 3491' 7,761' 7" OTIS R N IP, TI D= 5.963" 7 -5/8" TBG -IPC ? #, L -80 VamTopHC 7,706 � _ 77g1' 9 -518" X 7" BKR S -3 PKR, ID = 6.059" 7, 825' 7 " OTIS R N IP, ID = 5.963" 7,965 1 Cut and beveled 7 - 5/8" Tubing 8, 037 7" OTIS R NIP, ID = 5.963" 4 9-518" X 7" BKR — S3 PKR, ID = 6.059" 8,103 7" OTIS R NIP, ID = 5.963" 8,173' 7" OT RN NIP, I = 5.770 8,189 7" WL EG 8298 9 -5/8" X 5 -1/2" BKR FB -1 PERM PKR EX 8301 BAKER SEA LBORE TENSION 8311 ° BAKER MILLOUT EXTENSION 8317 7 -5/8" X 4 -1l2" XO TOP OF 4 -112" TBG -IPC 8318 TOP OF 7" LNR 8335' 8350 4 -1/2" PXN PLUG (03(15/10) 9 -5/8" CSG, 47 #, L -80, ID = 8.681" 8635' 8350 4 -112" OTiS XN NIP, ID = 3.725" 8362' 4 -1(2" BKR SHEAROUT SUB W/WLEG 4 -112" TBG -IPC, 12.6 #, L -80, .0152 bpf, ID = 3.958" 8363' 8363 4 -112" TUBING TAIL PERFORATION SUMMARY REF LOG: FINAL CNP ON 03/13/90 ANGLE AT TOP PERF: 30 @ 8685' Note: Refer to Production DB for historical erf data SIZE SPF INTERVAL O n/S z DATE 3 -3/8" 4 8685 -8738 O 05/30/90 3 -3/8" 4 8782 -8844 O 05/30/90 3 -3/8" 4 8849 -8884 O 05/30/90 3 -318" 4 8889 -9049 O 05/30190 3 -3/8" 4 9062 -9085 O 05/30/90 3 -3/8" 4 9091 -9097 O 05/30/90 3 -318" 4 9101 -9126 O 05/30/90 3 -3 18" 4 9130 -9136 O 05130190 3-3/8 4 1 9140 -9156 1 O 1 05/30190 PBTD 9212' 7" LNR, 29 #, L -80, .0371 bpf, ID = -6 9240° DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03118/90 ORIGINAL COMPLETION WELL: WGV06 05108/90 LAST WORKOVER PERMIT No: 1900300 API No: 50- 029 - 22021 -00 SEC 11, T11 N, R14E, 3169.9' FEL & 4988.09' FNL BP Exploration (Alaska) WGI -06 PTD 190 -030 sundry 3106 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, November 12, 2010 10:00 AM To: 'Bjork, David' Subject: RE: WGI -06 PTE} 190 -030 sundry 310 -206 Dave, Thanks for the updated program... I will supercede the previous version in our well file.... Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Bjork, David [mailto: David. Bjork@bp.com] Sent: Thursday, November 11, 2010 8:36 AM To: Schwartz, Guy L (DOA) Cc: Reem, David C; Barker, Elizabeth R (SAIL) Subject: WGI -06 PTD 190 -030 sundry 310 -206 N 0 Guy, Attached is a revised scope of work for WGI -06 RWO. The current plan is to utilize Doyon 141 instead of Doyon 16 for the workover. Doyon 141 can accommodate a 4 preventer stack while performing the workover. Regards, Dave <<AOGCC Scope of Work WGI -06 revision 2.ZIP>> i I 11/12/2010 O bp G --D `1 U —030 WGI -06 Rig Workover Scope of Work: Repair TAA communication. Pull 7 Tubing. Replace tubing spool and change casing p P 9 P 9 P 9 9 pack -offs. Install new 7 - injection tubing. MASP: 2,460 psi , P Well Type: Gas Injector Estimated Start Date: December 1, 2010 Production Engineer: Bob Chiwis Intervention Engineer: David Bjork Pre -riq prep work: S 1 Set a 4-'/ PXN plug at 8,350' MD. F 2 CMIT -T x IA to 4,000 psi. MIT -OA to 2,000 psi. Record LLR as necessary. E 3 Power Jet cut the in the middle of the V/2" 17# tubing pup at 8,290 ft. (Reference tubing tally of 5-08-90). F 4 Circulate well with seawater. FP with diesel through the cut. Post cut CMIT -T x IA to 500 psi W 5 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. V 6 Set a BPV in the tubing hanger. Secure well. O 7 Remove the wellhouse & flow line. Level the pad as needed for the rig. Proposed Procedure: I 1. MIRU Rig. ND tree. NU 4 Preventer BOPE with annular, blinds, 3 - x 6" VBR's, mudcross and 7" fixed rams. Pressure test the V/ x 6" VBR's, 7° fixed and blind rams to 4,000 psi, annular to 3,500 psi. Circulate out freeze protection fluid and circulate well to clean seawater. 2. Pull and LD 7" tubing string from cut. Install test plug. 3. Retrieve locator seal assembly. Set storm packer. 4. ND BOPE and tubing spool, replace the tubing spool and casing packoff (Two barriers are the storm packer and packer / PXN plug). Change the 7" fixed rams to 7- / fixed and test to 4,000 -psi. 5. Scrape the casing and circulate the wellbore to clean seawater. 6. Run 7- 5 /g" 29.7# L -80 VamTopHC IPC injection completion. 7. Displace the IA to completion fluid, freeze protect and set the packer. 8. Test tubing and IA to 4,000 psi. 9. Set TWC. ND BOPE. NU and test tree. RDMO. Post -rig work: S 1 1 Pull Ball -n -Rod, pull RHC seat, pull PXN plug from 8,350'. WGI-06 RWO revision (sundry n: er 310-206) PTD 190-030 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, September 08, 2010 3:29 PM To: 'Bjork, David' Subject: RE: WGI-06 RWO revision (sundry number 310-206) PTD 190-030 Page 1 of 1 Dave, Your proposed change to the approved sundry (310-206) as written in the attached document is acceptable. Leaving the existing packer with PXN plug installed during the RWO is safer operationally than milling up the packer and dealing with any trapped gas or pressure underneath. Regards, Guy Schwartz , t ~ <<, i r 4 ~,? Senior Petroleum Engineer ;,;~ AOGCC 793-1226 .(office) 444-3433 (cell) From: Bjork, David [mailto:David.Bjork@bp.com] Sent: Wednesday, September 08, 2010 12:59 PM To: Schwartz, Guy L (DOA) Cc: Reem, David C; Hubble, Terrie L; Stewman, Sondra D Subject: WGI-06 RWO revision (sundry number 310-206) PTD 190-030 Guy, The proposed WGI-06 RWO was previously approved under sundry 310-206. We would like to ammend the proposed procedure to not include milling up the original packer. Please review the revised scope of work and revised proposed schematic. Feel free to call if you have any questions, Regards, Dave Bjork 564-5683(w) 440-0331(c) «WGI-06 proposed rev1.pdf» «AOGCC Scope of Work WGI-06 revision 1.ZIP» 9/8/2010 • WGI-06 Rig Workover • /~~ l70-036 SuNae~ ~ 3ld -zap Scope of Work: Repair TxIA communication. Pull 7" Tubing. Replace tubing spool and change casing pack-offs. Install new 7 s/$" injection tubing. MASP: 2,460 psi ~ (,,C1o~~~-' ,o~'o ~~, Well Type: Gas Injector J Estimated Start Date: October 15, 2010 ~~ ~ ~ `~v Production Engineer: Bob Chiwis Intervention Engineer: David Bjork Pre-riq prep work: S 1 Seta 4- /2" PXN lu at 8,350' MD. F 2 CMIT-T x IA to 4,000 si. MIT-OA to 2,000 si. Record LLR as necessa E 3 Power Jet cut the in the middle of the 5- /2" 17# tubing pup at 8,290 ft. (Reference tubing tally of 5-08-90 . F 4 Circulate well with seawater. FP with diesel throu h the cut. Post cut CMIT-T x IA to 500 si W 5 Check the tubing and casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaks a check one at a time . PPPOT-T & IC. V 6 Set a BPV in the tubin han er. Secure well. Cr -t- ~,.,,,,, {~.e /as - O 7 Remove the wellhouse 8~ flow line. Level the ad as needed for the ri . Proposed Procedure: 1. MIRU Rig. ND tree. NU 3 Preventer BOPE with annular, blinds, mudcross and 7" fixed rams. / Pressure test the 7" fixed and blind rams to 4,000 psi, annular to 3,500 psi. Circulate out freeze protection fluid and circulate well to clean seawater. 2. Pull and LD 7" tubing string from cut. Install test plug. 3. Change out the 7" fixed rams to 3-'/2" x 6" VBR's and test to 4,000psi with a 4" test joint (two barriers are the packer /PXN plug and test plug) 4. RetriPV I CafA1' CPaI 8SS mbl Set storm packer. ~~~esf~ 5. ND BOPE and tubing spool, replace the tubing spool and casing packoff. (two barriers are the storm packer and packer /PXN plug) 6. Scrape the casing and circulate the wellbore to clean seawater. 7. Install test plug. Change out the 3 '/2" x 6" VBR's to 7-5/$" fixed rams and test to 4,000 psi with a 7-5/$" test joint (two barriers are the packer /PXN plug and test plug) 8. Run 7 5/$" 29.7# L-80 VamTopHC IPC injection completion. - 9. Displace the IA to completion fluid, freeze protect and set the packer.'" 10. Test tubing and IA to 4,000 psi. ' 11. Set TWC. ND BOPE. NU and test tree. RDMO. ~'°~ Post-rig work: S 1 Pull Ball-n-Rod, ull RHC seat, ull PXN lu from 8,350'. TREE= 6-3/8" CAMERON W G 1 0 6 WELLHEAD= MCEVOY ACTUATOR= BAKER KB. E1EV = 60' BF. ELEV = KOP = 4000' Max Angle = 31 @ 9200' Datum MD = WA Datum TVD = 8800' SS • - • Proposed RWO 13-3/8" CSG, 68#, 71' K-55, ID = 12.415" ~ ~ - - 2 200' 7" CA MCO DB-6 ID = 6.00" 13-3/8" CSG, 68#, L-80, ID = 12.415" 7-5/8" TBG-IPC, 29.7#, L-80 VamTopHC 7,980' 7" TBG, 26#, L-80, TGII 8,207 8,052' 7" OTIS R NIP, ID = 5.963" 8,084' 9-5/8" X 7" BKR S-3 PKR, ID = 6.059" 8,118' 7" OTIS R NIP, ID = 5.963" 8,189' 7" OTIS RN NIP. ID = 5 ? 10" 8,207' 7" WLEG 8298' 9-5/8" X 5-1/2" BKR FB-1 PERM PKR 8301' BAKER SEALBORE EXTENSION 8311' BAKER MILLOUT EXTENSION TOP OF 4-1/2" TBG-IPC 8318' 8317 7-5/8" X 4-1 /2" XO TOP OF 7" LNR 8335' 8350' 4-1/2" PXN PLUG (03/15110) 8350' 4-1/2" OTIS XN NIP, ID = 3.725" 9-5/8" CSG, 47#, L-80, ID = 8.681" 8635' 8362' 4-1/2" BKR SHEAROUT SUB W/WLEG 4-1/2" TBG-IPC, 12.6#, L-80, .0152 bpf, ID = 3.958" 8363' 8363' 4-112" TUBING TAIL PERFORATION SUMMARY REF LOG: FINAL CNP ON 03/13/90 ANGLE AT TOP PERF: 30 @ 8685' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8685-8738 O 05/30/90 3-3/8" 4 8782-8844 O 05/30/90 3-3/8" 4 8849-8884 O 05/30/90 3-3/8" 4 8889-9049 O 05/30/90 3-3/8" 4 9062-9085 O 05/30/90 3-3/8" 4 9091-9097 O 05/30/90 3-3/8" 4 9101-9126 O 05/30/90 3-3/8" 4 9130-9136 O 05/30/90 3-3/8" 4 9940-U95 ~ ~ O;i3O!90 ~~ I~ 9212' 17" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I DATE REV BY COMMENTS DATE REV BY COMMENTS 03/18/90 ORIGINAL COMPLETION 05/08/90 LAST WORKOVER PRUDHOE BAY UNff WELL: WGL06 PERMff No: ®1900300 API No: 50-029-22021-00 SEC 11, T11 N, R14E, 3169.9' FEL & 4988.09' FNL BP Exploration (Alaska) u • ~~Q~C~ OCR Q~Q~~{Q /,E,...~.~o~..~. David Reem Engineering Team Leader ., .,- 7 ~'E~s BP Exploration (Alaska), Inc. ~~~~'~~~~~ ~`~`~ `' ~ ~jd P.Q. Box 196612 q Anchorage, AK 99519-6612 1 Re: Prudhoe, Bay Field, Prudhoe Bay Oil Pool, PBU WGI-06 Sundry Number: 310-206 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. As provided in AS_ 31_.05.080,_ within 20_day_s after written__notic_e ofthis -- - - - 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. incerely, DATED this ~~day of July, 2010. Encl. Daniel T. Seamount, Jr. Chair ~~~ ~~ ,k.l ,~'~' ` STATE OF ALASKA • ~ ALASKA•AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ~(1 AAC ~.ri ~R~ .~11L A h 2010 .__ n:~ Q. r~na t'nt~~_ L't~rlOrti$$~Otl 1. Type of Request: {~110t1~lC't~e ^ Abandon ^ Plug for Redrill ^ Perforate New Pool -® Repair Well ^ Change Approved Program ^ 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: .Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 190-030 - 3. Address: ®Service _ ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22021-00-00 - 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: ~ pgU WGI-06 - Spacing Exception Required? ^ Yes ®No 9. Property Designation: ~ 10. Field /Pool(s): Oil P l dh B Fi l TP ADL 028302 - oe ay oo Prudhoe Bay e d ru 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9240' - 8685' 9212' 8661' 8350' None Casin Len th Size MD ND Burst Colla e Structural Conductor 1 2 1 11 1 Surface 34 1' 13-3/8" 491' 91' 34 19 Intermediate 8635' - ! " 6 8163' 687 476 Production Liner 905' 7" 8 ' - 924 ' 7 2' - 8685' 81 70 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8685' - 9156' 8206' - 8613' ~", 26# x s-v2~~, ~ ~# x 4-1 /2", ~ 2.s# L-80 8363' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker'FB-1' packer Packers and SSSV 8298' / 7869' MD (ft) and ND (ft): 12. Attachments: .Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ~ ®Service ^ Detailed Operations Program 14. Estimated Date for 5. Well Status after proposed work: Commencing Operations: August 20, 2010 ^ Oil ^ WINJ ^ WDSPL ^ Plugged 16. Verbal Approval: Date: ^ Gas ®GINJ - ^ GSTOR ^ Abandoned ^ WAG ^ SPLUG ^ Suspended Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Bork, 564-5683 Printed Name avid Reem Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-5743 Date ~ 6 ZOtO Terrie Hubble, 564-4628 Commission Use Onl Conditions of approval: otify Commission o that a representative may witness d „_, Sundry Number: ~ tegrity Test ^ Location Clearance echanica l I ^ Plug Integrity BOP Test n - p b~. `~~~ (~J ~ .~ ~7'~3 ~ . Other. ~ oZJr-~' ~ .S ~- ~ h n .~,~,.~ ~ ~ ~ r~rtic'"^~ Subsequent Form Required: ~ p 4 G~ ~ ~..~ APPROVED BY "') J l ~ I/~ Approved By: COMMISSIONER THE COMMISSION Date Form 10-403 Wised 01/2010 r1GD~S ~~~ i S qo~o ~ ~ ~ ~ ~ ~ ~ ,~_ j~,(UIn Duplicate ~7 1 L ~~~~d • ~~ >~'.~°_ WGI-06 Rig Workover • Scope of Work: Repair TxIA communication. Pull 7" Tubing. Mill and retrieve Baker FB-1 packer. Replace tubing spool and change casing pack-offs. Install new 7 s/a" injection tubing. MASP: 2,460 psi Well Type: Gas Injector Estimated Start Date: August 20, 2010 Production Engineer: Bob Chivvis Intervention Engineer: David Bjork Pre-riq prep work: S 1 Seta 4- /Z" PX lu at 8,350' MD. F 2 CMIT-T x IA to 4,000 si. MIT-OA to 2,000 si. Record LLR as necessa E 3 Power Jet cut the in the middle of the 5- /2" 17# tubing pup at 8,290 ft. (Reference tubing tally of 5-08-90 . F 4 Circulate well with seawater. FP with diesel throu h the cut. Post cut CMIT-T x IA to 500 si W 5 Check the tubing and casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaks a check one at a time . PPPOT-T & IC. V 6 Set a BPV in the tubin han er. Secure well. O 7 Remove the wellhouse & flow line. Level the pad as needed for the ri . Proposed Procedure: 1. +, MIRU Rig. ND tree. NU 3 Preventer BOPE with annular, blinds, mudcross and 7" fixed rams. , Pressure test the 7" fixed and blind rams to 4,000 psi, annular to 3,500 psi. Circulate out freeze protection fluid and circulate well to clean seawater. 2. Pull and LD 7" tubing string from cut. Install test plug. 3. Change out the 7" fixed rams to 3-'/2' x 6" VBR's and test to 4,000psi with a 4" test joint (two barriers are the PX plug and test plug) 4. Retrieve locator seal assembly. Set storm packer. 5. ND BOPE and tubing spool, replace the tubing spool and casing packoff. (two barriers are the storm packer and PX plu ) 6. Mill and retrieve 9 ~/$° x 5-'/2' FB-1 Packer and tailpipe. Bullhead packer gas with kill weight fluid. 7. Run a bit and scraper to 9,200'. ' 8. Run and seta 7" composite bridge plug 8,500'. Pressure test the plug to 1,000 psi. Install test plug. 9. Change out the 3-'/z" x 6" VBR's to 7 5/$" fixed rams and test to 4,000 psi with a 7-5/8" test joint (two barriers are the composite plug and test plug) 10. Run 7 s/8" 29.7# L-80 VamTopHC IPC injection completion. 11. Displace the IA to completion fluid, freeze protect and set the packer. 12. Test tubing and IA to 4,000 psi. 13. Change out the 7 s/8" fixed rams to 3-'/" x 6" VBR's and test to 4,000 psi with a 4" test joint (barriers are the composite plug and TWC). 14. RIH with a 5 3/4° junk mill and drill up the composite bridge plug and push to PBTD 15. POOH laying down all but 3,200' of drill pipe. 16. RU Slickline and set a RN plug at 8,287'. 17. RIH with drillpipe and freeze protect. POOH LDDR. 18. Set TWC. ND BOPE. NU and test tree. RDMO. • TREE _ ' 6-3/8" CAMERON WELLF~FA = MCEVOY ACTUATOR= BAKER KB. ELEV - Ii0 BF. ELEV KOP = 4000' Max Angle = 31 @ 9200' Datum MD = N/A Datum TVD = 8800' SS 13-3/8" CSG, 68#, K-55, ID = 12.415" G I -O ~ PSI. ~N FOREM ERGENCY FIELD FUEL AS***00 I 71' I 13-3/8" CSG, 68#, L-80, ID = 12.415" 3491' Minimum ID = 3.725" @ 8350' 4-1/2" OTIS XN NIPPLE 7" TBG-IPC, 26#, L-80, .0383 bpf, ID = 6.276" 8285' TOP OF 5-1/2" TBG-IPC 285' 5-112" TBG-IPC, 17#, L-80, .0232 bpf, ID = 4.892" ~~ 8318' I. TOP OF 4-1 /2" TBG-IPC 8318' _ _._ _ TOPaF 7"-LNR- - ----8335 ~~4-1/2" TBG-IPC, 12.6#, L-80, .0152 bpf, ID= 3.958" I~ 8363' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 8635' PERFORATION SUMMARY REF LOG: FINAL CNP ON 03/13/90 ANGLE AT TOP PERF: 30 @ 8685' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8685-8738 O 05/30/90 3-3/8" 4 8782-8844 O 05/30/90 3-3/8" 4 8849-8884 O 05/30/90 3-3/8" 4 8889-9049 O 05/30/90 3-3/8" 4 9062-9085 O 05/30/90 3-3/8" 4 9091-9097 O 05/30/90 3-318" 4 9101-9126 O 05/30/90 3-3/8" 4 9130-9136 O 05/30/90 3-3/8" 4 9140-9156 O 05/30/90 PBTD I-I 9212' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I~ 924Q' ~- 2156' 7" CAM BAL-O SSSV NIP, ID = 5.937" ~~ ~~ 8285' 7" X 5-1/2" XO 8295' 5-1/2" BKR LOC SEAL ASSY 8298' 9-5/8" X 5-1/2" BKR FB-1 PERM PKR 8301' BAKER SEALBORE EXTENSION 8311' BAKER MILLOUT IXTENSION 831T 7-5/8" X 4-1/2" XO 8350' 4-1/2" PXN PLUG (03/15/10) _. _ _ 8350' 4-1/2" OTIS XN NIP, ID = 3.725" 8362' 4-1/2" BKR SHEAROUT SUB W/WLEG 8363' 4-1/2" TUBgVG TAIL 8348' ELMD TT LOGGED 05/31/90 ~„ .l1_ Ga.u.p. `'z ='' 4 DATE REV BY COMMENTS DATE REV BY COMMENTS 03/18/90 ORIGINAL COMPLETION 08/07/07 DSM/SV TREE C/O 05/08/90 LAST WORKOVER 03!21/10 JCM/SV SET PXN PLUG (03!15/10) 11/03/01 RN/TP CORRECTIONS 04/02/10 DGJMD SAFETY NOTE UPDATE 03/25/03 JLA/KK CSG & SAFETY NOTE REV. 04/11/03 JRC/KK CASING CORRECTION 12/04/06 RAC/TLH TREE CORRECTION PRUDHOE BAY UNff WELL: WGI-06 PERMIT No: 1900300 API No: 50-029-22021-00 SEC 11, T11N, R14E, 3169.9' FEL 8~ 4988.09' FNL BP Exploration (Alaska) J TREE= 6-3l8" CAMERON WELLHEAD= MCEVOY ACTUATOR= BAKER KB. ELEV = 60' BF. ELEV = KOP = 4000' Max Angle = 31 @ 9200' Datum MD = NIA Datum TVD = 8800' SS ~ WGI-06 Proposed RWO 13-3/8" CSG, 68#, I-~ 71, K-55, ID = 12.415" 7" CAMCO DB-6 ID = 6.00" 13-3/8" CSG, 68#, L-80, ID = 12.415" %-~ ` X9.7#, L-8o va 8,080' 8,150' 7" OTIS R NIP, ID = 5.963" 8,181' 9-5l8" X 7" BKR S-3 PKR. ID = 6.059" 7" TBG. 26#, L-80, TGII 8,305' 8,215' 7" G- = 5.963" $, 28T 7" OTIS RN NIP.. ID = 5.770" 8,305' 7" N~LEG TOP OF 7" LNR 8335' 9-5/8" CSG, 47#, L-80, ID = 8.681" I~ 8635' PERFORATION SUMMARY REF LOG: FINAL CNP ON 03/13/90 ANGLE AT TOP PERF: 30 @ 8685' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8685-8738 O 05/30/90 3-3/8" 4 8782-8844 O 05/30/90 3-3/8" 4 8849-8884 O 05/30/90 3-3/8" 4 8889-9049 O 05/30/90 3-3/8" 4 9062-9085 O 05/30/90 3-3/8" 4 9091-9097 O 05/30/90 3-3/8" 4 9101-9126 O 05/30/90 3-3/8" 4 9130-9136 O 05/30/90 3-3/8" 4 9140-9156 O 05/30/90 I PBTD 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I 9212' I DATE REV BY COMMENTS DATE REV BY COMMENTS 03/18/90 ORIGINAL COMPLETION 05/08/90 LAST WORKOVER PRUDHOE BAY UNIT WELL: WGF06 PERMff No:'1900300 API No: 50-029-22021-00 SEC 11, T11 N, R14E, 3169.9' FEL & 4988.09' FNL BP Exploration (Alaska) ~ ~ S WELL LQG TRANSM/TTAL ,a. PROACTIVE DIAfINOSTIC 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 LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road v,~ C (~ b ~~3 d Suite C Anchorage, AK 99518 l 9 ~~ 5 Fax: (907) 245-8952 1) Leak Detection - WLD 03-Apr-10 WGI-06 1 BL/ EDE 50-029-22021-00 2J Signed Print Name: ,, Date : ~ ~ I~ ~„i 3 ~~~~. Ccsr~i~ ~~~~ ~-"~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : ,,pdsanchoraget~memorvaog.com WEBSITE : www.memorV9og.com C:\Documents and Settmgs\Diane Williams\Desktop\Tmnsmit_BP.docx NOT OPERABLE: Injector WGI -,PTD #1900300) Secured to evaluate bonce /contro... Page 1 of 2 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [ NSUADWWellIntegrityEngineer @BP.com] Sent: Friday, March 19, 2010 11:21 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Cc: Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Area Mgr East (FS1 /2 /COTU /Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; GPB, Wells Opt Eng; NSU, ADW Well Integrity Engineer; Quy, Tiffany; GPB, Optimization Engr; GPB, EOC Specialists Subject: NOT OPERABLE: Injector WGI -06 (PTD #1900300) Secured to evaluate balance /control line seals in wellhead All, Injection well WGI -06 (PTD #1900300) has been secured with a downhole plug. Attempts to change out the SSSV did not affect the rate of IA repressurization. Therefore a downhole plug was set to secure the well. The next step will be to evaluate the control and balance line seals in the wellhead. The well has been classified as Not Operable. Once the well is ready for injection again, another reclassification notification will be sent. Please let us know if there are any questions. Thank you, Anna Du6e, �.�. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group 2.Vt Phone: (907) 659 -5102 APR Pager: (907) 659 -5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Wednesday, January 27, 2010 1:50 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; Schwartz, Guy (DOA) <guy.schwariz @alaska.gov >'; 'Brooks, Phoebe L (DOA)' Cc: Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Integrity Engineer; NSU, ADW Well Operations Supervisor; GPB, Area Mgr East (FS1 /2 /COTU /Seawater); GPB, FS1 DS Ops Lead; GPB, FS1 DS Ops Lead Subject: UNDER EVALUATION: WGI -06 (PTD #1900300) Increased rate of IA repressurization All, WGI -06 (PTD #1900300) has known IA repressurization and is approved for continued operation under AOGCC Administrative Approval 4E.008. The rate of IA repressurization has increased as evidenced on the TIO plot. The well has been reclassified as Under Evaluation for slickline to reset the SSSV and to monitor the wellhead pressures. The plan forward for the well is as follows: 1. Slickline: Pull and reset SSSV 2. DHD: Monitor wellhead pressures A TIO plot, wellbore schematic and Administrative Approval 4E.008 have been included for reference. Please call with any questions. 2/22/2011 NOT OPERABLE: Injector WGI -CePTD #1900300) Secured to evaluate bonce /contro... Page 2 of 2 Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659 -5102 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 I I 2/22/2011 RE: UNDER EVALUATION: W136 (PTD #1900300) Increased rate of I epressuriz... Page 1 of 2 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [ NSUADWWellIntegrityEngineer @BP.com] Sent: Wednesday, February 24, 2010 9:10 AM To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Subject: RE: UNDER EVALUATION: WGI -06 (PTD #1900300) Increased rate of IA repressurization Attachments: WGI -06 TIO Plot 02 -24 -10 .doc All, WGI -06 had its SSSV changed out on 02/23/10 after the IAP began tracking the tubing pressure. A successful drawdown test was performed after the valve was set indicating the packing is holding. The plan forward is to monitor the TIO plot for two weeks and notify the AOGCC of the IA pressure build up rate results. The most recent TIO plot has been attached for your reference. «WGI-06 TIO Plot 02-24-10 .doc Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659 -5102 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer Sent: Friday, February 05, 2010 12:11 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Brooks, Phoebe L (DOA)'; 'Schwartz, Guy L (DOA)' Cc: NSU, ADW Well Integrity Engineer Subject: FW: UNDER EVALUATION: WGI -06 (PTD #1900300) Increased rate of IA repressurization Jim, WGI -06 (PTD# 1900300) has been confirmed to have sustained casing pressure on the IA. The wellhead pressures were 3680/2120/460 on 02/05/10. A SSSV was changed out to mitigate TxIA communication on 02/01/10, however, after the well was placed on injection the communication became worse. Slickline is currently rigging up over the well to pull the SSSV, inspect the packing, and re -set a redressed SSSV. We will continue to let you know how this progresses. I have attached the most recent TIO plot for your reference. « File: WGI -06 TIO Plot 02- 05- 10.doc » Thank you, 2/22/2011 RE: UNDER EVALUATION: W06 (PTD #1900300) Increased rate of IIepressuriz... Page 2 of 2 Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659 -5102 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer Sent: Wednesday, January 27, 2010 1:50 PM To: 'Regg, James B (DOA)'; Maunder, Thomas E (DOA); 'Schwartz, Guy (DOA) <guy.schwartz @alaska.gov >'; 'Brooks, Phoebe L (DOA)' Cc: Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Integrity Engineer; NSU, ADW Well Operations Supervisor; GPB, Area Mgr East (FS1 /2 /COTU /Seawater); GPB, FS1 DS Ops Lead; GPB, FS1 DS Ops Lead Subject: UNDER EVALUATION: WGI -06 (PTD #1900300) Increased rate of IA repressurization All, WGI -06 (PTD #1900300) has known IA repressurization and is approved for continued operation under AOGCC Administrative Approval 4E.008. The rate of IA repressurization has increased as evidenced on the TIO plot. The well has been reclassified as tinder Evaluation for slickline to reset the SSSV and to monitor the wellhead pressures. The plan forward for the well is as follows: 1. Slickline: Pull and reset SSSV 2. DHD: Monitor wellhead pressures A TIO plot, wellbore schematic and Administrative Approval 4E.008 have been included for reference. « File: WGI -06 TIO Plot 01- 27- 10.doc » « File: WGI- 06.pdf » « File: WGI -06 AA Approval 4E.008 05-31 - 06.pdf » Please call with any questions. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659 -5102 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 2/22/2011 • • WGI-06 (PTD# 1900300) ?Lk. 4 ,1 0 —0— Tbg 2 OW —a— OA 1 0 0 ° 0 °A , OA 1 TO 11/2R 12/65/01 12/1 12/1 12/26/03 01A:11/10 01/69/10 01/1 oimno 01);0f10 02/64710 0211'3;10 02/..:0/10 WGI-06 (PTD #1900300) TIO Plot 4,040 3.000 - —-IA 2,000 - 00A —4— 000A On 1,000 - 11/07/09 11/21/09 12/05/09 12/19/03 01/02/10 01/16/10 _ _ _ OPERABLE:WGI-06 (PTD #1900300) IA repressurization manageable Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~~~~~~ ~ Sent: Sunday, August 23, 2009 10:40 AM ~e To: NSU, ADW Well Integrity Engineer; Regg, James B(DOA); Maunder, Thomas E(DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Sinyangwe, Nathan; Schwartz, Guy L(DOA); NSU, ADW WL & Completion Supervisor; NSU, ADW Weils Slickline Scheduler Cc: GPB, Wells Opt Eng; GPB, EOC Specialists; Quy, Tiffany Subject: OPERABLE:WGI-06 (PTD #1900300) IA repressurization manageable Attachments: WGI-06 TIO Plot.doc / All, WGI-06 (PTD #1900300) has been reclassified as Operable with a current AOGCC Administrative Approvai for slow IA repressurization. On 7/26 the SSSV was reset, effectively slowing the rate of IA repre` ssurization as evidenced on the attached TIO plot. ~' «WGI-06 TIO Plot.doc» Please let us know if there are any questions. Thank you, Torin Roschinger (ait. Anna Dube) Weli Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer Sent: Friday, August 07, 2009 6:53 PM x;,'~sb: i~'~~$~.~ -~ ;; (, ~' t~ U~~; To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; GPB, Area Mgr East (FSi/2/COTU/Seawater); GPB, FSl OTL; GPB, F51 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Sinyangwe, Nathan; 'Schwartz, Guy (DOA) <guy,schwar~@alaska.gov>'; NSU, ADW WL & Completion Supervisor; NSU, ADW Wells Slickline Scheduler Cc: GPB, Wells Opt Eng; GPB, EOC Specialists; Sala, Jaycen (CH2MHill); NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION:WGI-06 (PTD #1900300) Increased rate of IA repressurization All, WGI-06 (PTD #1900300) has known IA repressurization and is approved for continued operation under AOGCC Administrative Approval 4E.008. Again, the rate of IA repressurization has increased after resetting the SSSV on 7/26/09. The well has been reclassified as Under Evaluation for slickline to pull and reset the SSSV. A TIO plot and wellbore schematic have been included for reference. 8/24/2009 OPERABLE:WGI-06 (PTD #1900300) IA repressurization manageable Page 2 of 2 Please let us know if you have any questions. Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) Well {ntegrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 8/24/2009 PBU WGI-06 PTD# 1900300 8/23/2009 Ti0 Pressures a,ooo ~ 3,000 ~,n00 1,000 f Tbg ^ IA --~- OA OOA OOOA ~ On ~ 07/24IU~d U7/26l09 07128i09 07';0/09 08/OVC19 03.~03I09 ng/05.%09 08.%07/ii9 081~9/09 08/71109 08l13/l79 08/15/09 09.f17/09 D2119/09 06/21/09 OPERABLE:WGI-06 (PTD #19~00) Ra.te of IA repressurization reduced by resetting 5... Page 1 of 2 ~ Schwartz, Guy L (DOA) ~~3~~ From: NSU, ADW Well Integrity Engineer [NSUADWWeillntegrityEngineer@BP.com] Sent: Sunday, August 02, 2009 12:29 PM To: Regg, James S(DOA); Maunder, Thomas E(DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engei, Harry R; NSU, ADW Weil Operations Supervisor; Sinyangwe, Nathan; Schwartz, Guy L (DOA) Cc: GPB, Wells Opt Eng; GPB, EOC Specialists; Quy, Tiffany; NSU, ADW Well lntegrity Engineer Subject: OPERABLE:WGI-06 (PTD #1900300) Rate of IA repressurization reduced by resetting SSSV Attachments: WGI-06 TIO plot.doc All, WGI-06 (PTD #1900300) has been reclassified as Operable with a current AOGCC Administrative Approval for slow IA repressurization. The SSSV has been reset, effecitvely slowing the rate if IA repressurization as evidenced on a recent TIO plot. «WGI-06 TIQ plot.doc» Please let us know if there are any questions. Thank you, Anna ~u6e, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 ~.~~ `~'(„''~'~`~~~~~ ~f~ te>> ... ._ ~~~' From: NSU, ADW Well Integrity Engineer Sent: Monday, ]uly 13, 2009 1:54 PM To: 'Regg, Ja B(DOA)'; 'Maunder, Thomas E(DdA)'; GPB, Area Mgr East (FSSJ2/CO7U/Seawater); GPB, FSl OTL; GPB, F51 DS Ops lead; Rossberg, R Steven; gel, Harry R; NSU, ADW Well Operations Supervisor; Sinyangwe, Nathan; SchwaKz, Guy (DOA) <guy.schwartzC~ilalaska.gov> Cc: GPB, Wells Opt Eng; G EQC Specialists; Sala, Jaycen (CH2MHilp; NSU, ADW Well Integriry Engineer; Winslow, Jack L.; CUngingsmith, Mike J (CH2M Hill) Subject: UNDER EVALUATION:WGI- P'TD #1900300) Increased rate of L4 repressurization All, WGI-06 (PTD #1900300) has known IA repressu ~ tion and is approved for continued operation under AOGCC Administrative Approval 4E.008. The rate of IA repre rization has increased as evidenced on the TIO plot. The well has been reclassified as Under Evaluation for slickli to pull and reset the SSSV. A TIO plot and wellbore schematic have been included for Please let us know if you have any questions. Thank you, 8/3/2009 OPERABLE:WGI-06 (PTD #1~00) Rate of IA repressurization reduced by resetting 5... Page 2 of 2 ~ Anna ~u6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (9~7) 659-5100 x1154 8/3/2009 ITNDER EVALUATION:WGI-~TD #1900300) Increased rate of IA repressurization Page 1 of 2 ~ Schwar#z, Guy L (DOA) From: NSU, ADW Weil Integrity Engineer [NSUADWWeIilntegrityEngineer@BP.com~ Sent: Tuesday, July 21, 2009 8:20 PM To: Schwartz, Guy L(DOA); NSU, ADW Weli Integrity Engineer Cc: Regg, James B(DOA); Maunder, Thomas E(DOA) Subject: RE: UNDER EVALUATIQN: WGI-Q6 (PTD #1900300) increased rate of IA repressurization Guy, A wireline retrievable SSSV is used in WGI-06 because it allows the capability to backflow the well. This is done during the annual turn-arounds to run the facilities. You are correct, the AOGCC should have been notified in May. The closest attention to IA pressure changes will be taken and brought to your attention in a timely manner. Please call or email with any further questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907} 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: Schwariz, Guy L {DOA) [mailto:guy.schwartzCa~alaska.govJ Sent: Friday, July 17, 2409 2:31 PM To: NSU, ADW Well Integrity ~ngineer Cc: Regg, James B(DOA); Maunder, Thomas E(DQA) Subject: RE: UNDER EVAI.UATION:WGI-06 (PTD #1900300) Increased rate of IA repressurization Anna, Keep us notified of the outcome of the SSSV reset. I looked up the last MIT-IA and it was done on 9/25/06. Also, I was wondering why not just run an injection valve if the Wireline retrievable SSSV's are troublesome when used in gas service??? It seems they would be better suited if the hydraulic ports could be isolated reliably. I don't think there is a regulatory issue with their use as far as I know. One more point... I looked at the TIO chart. AOGCC should have received notification much earlier than July 13th. By 5-22-09 two bleeds had already been completed on the IA and the new buildup rate on the IA was clearly established. Condition No. 6 in AA 4E.008 states the AOGCC must be notified if there is any change in the wells mechanical condition and it would appear to me that this change in the IA behaviar would justify prompt notification. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 7/2'7/2009 IJNDER EVALUATION:WGI-~TD #1900300) Increased rate of IA re ressurization Page 2 of 2 ~rom: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Monday, July 13, 2009 1:54 PM To: Regg, James B(DOA); Maunder, Thomas E(DOA); GPB, Area Mgr East (FSi/2/COTU/Seawater); GPB, FS1 OTL; GPB, FSi DS Ops Lead; Rossberg, R 5teven; Enget, Harry R; NSU, ADW Well Operations Supervisor; 5inyangwe, Nathan; Schwartz, Guy L(DOA) Cc: GPB~ Wells Opt Eng; GPB, EOC Specialists; Sala, )aycen (CH2MHill); NSU, ADW We11 Integrity Englneer; Winslow, Jack L.; Clingingsmith, Mike J(CH2M Hill) Subject: UNDER EVALUATIDN:WGI-06 (PTD #1900300) Increased rate of IA repressurization All, WGI-06 (PTD #1900300) has known IA repressurization and is approved for continued operation under AOGCC Administrative Approval 4E.008. The rate of IA repressurization has increased as evidenced on the TIO plot. The well has been reclassified as Under Evaluation for slickline to pull and reset the SSSV. A TIO plot and welibore schematic have been inciuded for reference. «WGI-06 TIO PIot.ZIP» «WGI-06.pdfi> Please let us know if you have any questions. Thank yau, Anna ~Du6e, ~'. E. Well Integrity Coordinator GPB Welis Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 7/27/2009 /'" ~~ = 6-3/8" CAMERON , WElLHEAD = MCEVOY ACTUATOR= BAKER KB. E1EV = 6~~ BF. ElEV - KOP = 4000' Max Angle = 31 @ 9200' Datum MD = N/A Datum ND = 8800' SS W G I~O ~ SAFEfY ES: DO NOT PRESSURE OA ABOV E 3000 PSI. 13-3/8" CSG, 68#, 71 ~ K-55, ID = 12.415" 2156~ 7" CAM BAL-O SSSV NIP, ID = 5.937" 13-3/8" CSG, 68#, L-80, ID = 12.415" 3491' Minimum ID = 3.725" @ 8350' 4-1/2" OT1S XN NIPPLE 7" TBG-IF'C, 26#, L-80, .0383 bpf, ID = 6.276" $285~ TOP OF 5-1 /2" TBG-~C 8285' ( 5-1/2" TBG-~C, 17#, L-80, A232 bpf, ID = 4.892" ~ 8318~ TOP OF 4-1 /2" TBG-IPC 8318~ TOP OF 7" LNR 8335~ 4-112" TBG-IPC, 12.6#, L-80, .0152 bpf, ID = 3.958" 8363~ 9-5/8" CSG, 47#, L-80, ~= 8.681" 11 8635, PERFORATION SUMMARY REF LOG: FINAL CNP ON 03/13/90 ANGLE AT TOP PERF: 30 @ 8685' Note: Refer to Production DB for historical perf data SiZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8685-8738 O 05l30/90 3-3/8" 4 8782-8844 O 05/30/90 3-3/8" 4 8849-8884 O 05/30/90 3-3/8" 4 8889-9049 O 05/30/90 3-3/8" 4 9062-9085 O 05/30/90 3-3/8" 4 9091-9097 O 05l30l90 3-3/8" 4 9101-9126 O 05/30/90 3-3/8" 4 9130-9136 O 05/30/90 3-3/8" 4 9140-9156 O 05/30/90 ~~ I-I 9212' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~-~ 92~~ $2$~j• -17'• X 5-1l2" XO ~ 8295' 5-1/2" BKR LOC SEAL ASSY $29$' 9-5(8" X 5-1/2" BKR FB-1 PERM PKR 8301' BAKEf2 SEALBORE IXTENSION 8311' BAKER MILLOUT DCTB~1SbN 8317~ 7-5/8" X 4-1 /2" XO~ 83~30' -j4-1/2" OTtS XN NIP, ID = 3.725" ~ 8362~ 4-1l2" BKR SHEAROUT SUB W/WLEG 8363~ 4-1/2" TUBING TAIL $34$' F1MD TT LOGGED 05/31/90 DATE REV BY COMMENTS DATE REV BY CAMMENTS 03N 8/90 ORIGINAL COM PLETION 08l07/07 DSM/SV TREE C/O 05/08/90 LAST WORKOVER 11/03/01 RN/TP CORRECTIONS 03/25/03 JLA/KK CSG & SAFEfY NOTE REV. 04111/03 JRGKK CASING CORRECTION 12i04/O6 RAC/TLH IREE CORRECTION PF2UDHOE BAY UN(f WELL: WGI-06 PERMR' No: ~1900300 API No: 50-029-22021-00 SEC 11, T11 N, R14E, 3169.9' FEL & 4988.09' FNL BP 6cploration (Alaska) ~ ~ WGI-06 (PTD #1900300) TIO Plot a.ooo .......-••••• ..................•••-•••-•-•••--.............•••-•••-••-••-•...••••--•••-.... ~ ~ ^ ~• ~ r ~ ~ = • r ' ~ r r ~ ~- Tbg ^ IA ~ -~ Q4 OOA ~ ~ OOOA ~ ~ ^ ~ On ~ : ~ •~' . • ^. . .~ ~9 05I09/09 05/16/09 OS/23/09 05/30l09 06/06/09 06/13/09 D6/20/09 06i27/09 07104I03 07/71/D9 W/1B/09 07/25;09 OPERABLE: WGI -06 (PTD #193.00) IA repressurization Minimized • Page 1 of 2/,t Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [ NSUADWWelllntegrityEngineer @BP.com] Sent: Friday, September 19, 2008 7:00 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1 /2 /COTU /Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Daniel, Ryan; Randall, Jaclyn S; GPB, Wells Opt Eng Cc: Winslow, Jack L.; NSU, ADW Well Integrity Engineer Subject: OPERABLE: WGI -06 (PTD #193 00) IA repressurization Minimized Attachments: WGI -06 TIO Plot.doc I CA° All, The SSSV was changed out on well WGI -06 (PTD #1900300) on 09/14/08. The well was returned to gas injection and the IA pressure was bled. The well has been monitored for several days to determine the success of the SSSV change out. As seen in the attached TIO plot, the IA has not built pressure since it was bled on 09/16/08. The well has been reclassified as Operable. «WGI -06 TIO Plot.doc» _ Please call with any questions or concerns. Thank you, Andrea Hughes MAR 1 0 2U1 Well Integrity Coordinator Office: (907) 659 -5102 Pager: (907) 659 -5100 x1154 From: , ADW Well Integrity Engineer Sent: Monday, . ust 25, 2008 3:13 PM To: 'Regg, James B • '; 'Maunder, Thomas E (DC)Ay; GPB, Area Mgr East (FS1 /2 /COTU /Seawater); GPB, FS1 OTL . FS1 DS Ops Lead; Rossberg, R Steven; Engel, Ha •; NSU, ADW Well Operations Supervisor Cc: NSU, ADW Well Integrity Engineer; Ros ''•er, Torin T.; Dube, Anna T Subject: UNDER EVALUATION: WGI -06 (PTD #1• 4 1300) Increase in IA repressurizati. Jim, Well WGI -06 (PTD #1900300) is operating und- • dministrative • . • oval 4.008 dated 05/31/06 for slow IA repressurization. Over the last few days t - • eed frequency has incre- -d. The well was shut -in just before the rate of IA repressurization increased, - -ding us to believe the SSSV packin. • .s failed. A TIO plot, injection plot and wellbore schematic have be- - ncluded for reference. Bleed events summa . > 08/22/08: Ble• • P from 1890 psi to 725 psi, 31 minutes, all gas > 08/24/0:: =led IA from 2020 psi to 1450 psi, 30 minutes, all gas e plan forward for the well is as follows: 1. S: Reset SSSV 2/22/2011 i I • • WGI -06 TIO Plot 4,000 -441146.11". 3,000 - • ■ 2.000 - • • • 1.000 11-x 0 • • 06/21/08 07/05/08 07/19/08 08/02/08 08/16/08 08/30/08 09/13/08 WGI -06 Injection Plot 4,000 - 150,E 3.800 - 140,000 1600 -100,000 3,400 3200 120,003 3000 - 110,000 2,800 - 100,000 2.600 2,400 - - 00,E Q. 2.200 - 80,000 0 2.000 -70,000 q 1,800 - v 1.600 - - 00,000 ° 1,400 - - 50,100 1200 - 40.000 1,000 - 600 - - 30.000 600 - - 20,000 400 -10,000 200 - 06/21 00/28/08 07/05/08 07/12/08 07/19/08 07/26 1/02/08 08/89 /08 08/16/08 08/23/08 08/90/08 09/ 09113/00 UNDER EVALUATION: WGI-06 (PTD #1~3893~Q) Increase in IA repressurization Page 1 of 1 IQO~ 03® • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] p Sent: Monday, August 25, 2008 3:13 PM ~ ~~i I J~~~° To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East t (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor Cc: NSU, ADW Well Integrity Engineer; Roschinger, Torin T.; Dube, Anna T Subject: UNDER EVALUATION: WGI-06 (PTD #19,~A~A-38'C~ Increase in IA repressurization Attachments: WGI-06 TIO and Injection Plot.doc; WGi-06.pdf Jim, 4t .~ Well WGI-06 (PTD #1900300) is operating under Administrative Approval A-O'~dated 05/31/06 for slow IA repressurization. Over the last few days the bleed frequency has increased. The well was shut-in just before the rate of IA repressurization increased, leading us to believe the SSSV packing has failed. A TIO plot, injection plot and wellbore schematic have been included for reference. Bleed events summary: > 08/22/08: Bled IAP from 1890 psi to 725 psi, 31 minutes, all gas > 08/24/08: Bled IA from 2020 psi to 1450 psi, 30 minutes, all gas The plan forward for the well is as follows: 1. S: Reset SSSV 2. WIC: POI and monitor TIO plot ~r~~f ~FP ~ ~ 2~~~ The well has been classified as Under Evaluation and placed on a 28-day clock. «WGI-06 TIO and Injection Plot.doc» «WGI-06.pdf» ,/" Please calf with any questions. Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 9/5/2008 • • t'(31.1 l~~r -off ~ P~ ~~~-o.~u {,OLaJ , 3.~1 ,T~, zoo ~ ~ ~ ~~ ~ ~~~~ ,.~ -.~~ ~~~a p5l31.+Ufi 06:'07t~d OF;~drt~ ~- ''; ~~: _ ~" :L - _ ~ -- - -~ _.._ _ l~."~ _.._ _'3~E 4 Cb0 3,511 3,10 S~~ ~ 2,~0 1.500 1.[~~=' 5C ~10:C~7d 15Q,~Ct1 ~ 0 1N,iL~I ~ c~ a v n ~.~ o_ZS~,o tA: UltW Y#3f:IfW Q7~IN ~ir ~#tW ~+e~G1W SA'd EnlCe~C'+ TREE = 6-318" CAMERON WELLHEAD= MCEVOY _ACTUAT_OR= BAKER KB. ELEVp~-} ~ ~~ 60~ BF. ELEV • ® SAF RTES: DO NOT PRESSURE OA ABOVE 3000 PSI. KOP = 8000' 13-3(8" CSG, 68#, 71' II-•I- Max Angle = _ :s i @ 9200' K_55, ID = 12.415" Datum MD = N/A Datum TV D = 8800' SS 13-318" CSG, 68#, L-80, ID = 12.415" Minimum ID = 3.725" 8350' 4-1 /2" OTIS XN NIPPLE 7" TBG-IPC, 26#, L-80, .0383 bpf, ID = 6.276" --~ TOP OF 5-112" TBG-IPC -~ ~-~-f --~ 2156' -~ 7" CAM 8AL-O SSSV NIP, ID =5.937" 8285' 8285' 5-112" TBG-IPC, 17#; L-80, .0232 bpf, ID = 4.892" ~ 8318' rTOP OF 4-112" TBG-IPC 8318' TOP OF 7" LNR 8335' 4-112" TBG-IPC, 12.6#, L-80, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#; L-80; ID = 8.681" (-~ 8635 PERFORATION SUMMARY REF LOG: FINAL CNP ON 03/13190 ANGLE AT TOP PERF: 30 @ 8685' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpniSgz DATE 3-3/8" 4 8685-8738 O 05130/90 3-318" 4 8782-8844 O 05/30190 3-318" 4 8849-8884 O 05130190 3-318" 4 8889-9049 O 05/30/90 3-318" 4 9062-9085 O 05/30/90 3-318" 4 9091-9097 O 05/30J90 3-318" 4 9101-9126 O 05130/90 3-318" 4 9130-9136 O 05130190 3-318" 4 9140-9156 O 05/30/90 PBTD I---I 9212' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" [ 9240' 8285' -j 7° x 5-11z" xo ~ 8295' S-112" BKR LOC SEAL RSSY 8298' 9-518" X 5-1/2" BKR FB-1 PERM PKR 8301' BAKER SEALBORE EXTENSION 8311' j BAKER MILLOUT DCTENSION $317' - 7-518" X 4-112" XO $350' ~-14-112" OTiS XN NIP, ID = 3.725°' $362° 4-1I2" BKR BREAKOUT SUB WIWLEG 8363' 4-112" TUBING TAIL $348' ELMD TT LOGGED 05131/90 DATE REV BY COMMENTS 03/18190 ORIGINAL COMPLETION 05108!90 LAST WORKOVER 11/03/01 RNlTP CORRECTIONS ~~....~.~~~~~..~~~~~~.- 03i25/03 JLAiKK CSG & SAFETY NOTE REi 04111103 JRC/KK CASING CORRECTION 12/04106 RAC/TLH TREE CORRECTION DATE ~ REV BY ~ COMMENTS 08!07107 DSNUSV TREE C/fl PRUDHOE SAY UNI>" WELL: WGI-06 PERMIT No: 1900300 APi No: 50-029-22021-00 SEC 11, T11 N, R14E, 3169.9' FEL & 4988.09' FNL BP Exploration (Alaska) OPERABLE -WGI-06 (PTD #1900300) Increase in IA repressurization Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Sunday, June 08, 2008 7:31 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor Cc: Roschinger, Torin T.; NSU, ADW Well Integrity Engineer Subject: OPERABLE -WGI-06 (PTD #1900300) Increase in IA repressurization Attachments: WGI-06 TIO plot.BMP ~ Jim, The SSSV was pulled and reset on WGI-06 (PTD #1900300} on 05/23/08. The attached TIO plot shows pressure reading since resetting the SS V confirming the IA repressurization rate has decreased considerably. The well has been reclassified as Operable under AA 4E.008 for slaw TxIA communication. «WGI-06 TIO plot.BMP» Please let us knew if you have any questions. k~~~olN~~ SFP i ~ 2008 From: NSU, ADW Well Integrity Engineer Sent: Wednesday, May 21, 2008 8:20 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FSl OTL; GPB, FSl DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor Cc: NSU, ADW Well Integrity Engineer; Townsend, S. Eliot; Wellman, Taylor T Subject: UNDER EVALUATION -WGI-06 (PTD #1900300) Increase in IA repressurization Jim, 4t• ~ Wefl WGI-06 (PTD #1900300) is operating under Administrative Approval 4.008 dated 05/31/06 for slow IA repressurization. Over the last 2 weeks the bleed frequency has increased indicating an increase in the rate of repressurization. We believe the source of the increased repressurization is the SSSV. A 30-day TIO plot and wellbore schematic have been included for reference. The well has been reclassified as Under Evaluation. The plan forward for the well is as follows: 1. S: Pull and reset the SSSV 2. WIC: Monitor the TIO plot for two weeks to determine if changing out the SSSV reduced the rate of repressurization. We will communicate the results of the above actions after the monitoring period. 9/5/2008 OPERABLE - WGI-06 (PTD #1900300) Increase in IA repressurizati~ Page Z of 2 Please let me know if you have any questions. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 9/5/2008 ~~ ~, d. e[ ,~ I I ~ `~ O ~ ~ + ~ ~ a 0 00 a a L`' 0 0 -, 00 0 v ~, + .~. O ~ 0 ~ ~ 0 ~ _ ~ ~ ~ ~ ~ ~ 0 _ ~ ~ o c o 0 0 0 0 ~_~ ~ ~ - 0 0. n. L'1 ~ ~ ~ ~ ~ ~ 1 O O o O ~ ~ o a o a ~t r ~ cv UNDER EVALUATION -WGI-06 (PTD #1900300) Increase in IA repressurization Page 1 of 1 • • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~ ~ /~'~ Sent: Wednesday, May 21, 2008 8:20 PM / l To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor Cc: NSU, ADW Well Integrity Engineer; Townsend, S. Eliot; Wellman, Taylor T Subject: UNDER EVALUATION -WGI-06 (PTD #1900300) Increase in IA repressurization Attachments: WGI-06 TIO PIot.BMP; WGI-Oii.pdf i Jim, Well WGI-06 (PTD #1900300) is operating under Administrative Approval 4.008 dated 05/31/06 for slow IA repressurization. Over the last 2 weeks the bleed freauency has increased indicating an increase in the rate of repressurization. We believe the source of the increased repressurization is the SSSV. A 30-day TIO plot and wellbore schematic have been included for reference. The well has been reclassified as Under Evaluation. «WGI-06 TIO PIot.BMP» «WGI-06.pdf» The plan forward for the well is as follows: 1. S: Pull and reset the SSSV ~ 2. WIC: Monitor the TIO plot for two weeks to determine if changing out the SSSV reduced the rate of :/" repressurization. We will communicate the results of the above actions after the monitoring period. Please let me know if you have any questions. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~~ JUN ~ ~ 2008 6/4/200& c~ M ~J i • s l~ T yd T ~C ;;~ g,. ~~~ 0 +L ~y; a3 G lj y rte ,,~ 0 w 0 ~x, 0 acs a C C u~ ao 0 t S~ ~r~ +~.: X17 Q t0 ~~ ~ {{3 NN~ '-a r acs G Sy U'i 06 Q U7 0 a a 0 0 0 ri QI a 0 a ~~•i a 0 a0 O O i17 5~ ct a0 C3 Q ~' ~~ TREE= 6-318"CAMEf WELLHEAD= MCEVOY ACTUATOR = BAKER KB. ELEV .`,.: .,., ..u.,w, ... 60 BF. ELEV =_ _ KOP = 4000' Max Angle = 31 @ 9200' _ .. Datum MD = ... ... . N(A Datum TV D = 8$00' SS ~® 13-318" CSG, 68#, 71' K-55, ID = 12.415" (13-3i8" CSG, 68#, L-80, ID = 12,415" ~-~ 3491' Minimum ID = 3.725" @ 835Q' 4=1/2" OTlS XN NIPPLE 7" TBG-IPC, 28#, L-80, A383 bpf, ID = 6.276" $2$5` TOP OF 5-112" TBG-IPC 5-112" TBG-IPC, 17#; L-80; .0232 bpf; ID = 4.892" ' $318' TOP OF 4-112" TBG-EPC 8318° TOP OF 7" LNR 8335' 82$5' -i7" X 5-1l2" XO 8295` 5-112" BKR LOC SEAL ASSY $298' 9-5f8" X 5-if2" BKR FB-1 PERM PKR $3O1' BAKER SEALBORE EXTENSKN 8311' BAKER MILLOUT EXTENSION 8317' 7-5r8° x 4-112° xo 8350' -14-112" OT(S XN NIP. 9D = 3.725" ~4-112" TBG-IPC, 12.6#, L-80, A152 bpf, ID = 3.958" ~-~ 8363° 9-5!8" CSG: 47#, L-80; ED = 8.681" ~-j 8635' PERFORATtON SUMMARY REF LOG: FINAL CNP ON 03113190 ANGLE AT TOPPERF: 30 @ 8685` Nots: Refer to Production DB #or historical perf data SIZE SPF ENTERVAL OpnlSgz DATE 3-3J8" 4 8685-8738 O 05!30/90 3-318" 4 $782-8844 O 05!30190 3-3/8" 4 8849-8884 O 05(30,90 3-318" 4 8889-9049 O 05(30190 3-318" 4 9062-9085 O 05130190 3-3/8" 4 9091-9097 O 05/30/90 3-3l8" 4 9101-9126 O 05(30(90 3-318" 4 9130-9136 O 05(30190 3-3/8" 4 9140-9156 O 05/30f90 PBTD 6212' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9240' SAF TES: DO NOT PRESSURE OA ABOVE3flflfl PSI. 2156' 7" CAM BAL-O SSSV NIP; ID = 5.937" $362° 4-112" BKR SHEAROUT SUB WIINLEG 8363' 4-1,'2" TUBING TAIL $34$` ELMD TT LOGGED 05/31(90 DATE REV BY COMMENTS DATE REV BY COMMENTS 03118/90 ORIGINAL COMPLETION 0$,•'07107 DStv~'SV TREE C/O OSd08t90 LAST WORKOVER 11/03!01 RN/TP CORRECTIONS 03125/03 JLAlKK CSG & SAFETY NOTE REV. 04111/03 JRGiKK GASING CORRECTION 12104!06 RACITLH TREE CORRECTION PRUDHOE BAY UNCT WELL WGI-06 PERMIT No: 1900300 APi No: 50-029-22021-00 SEG 11, T11 N; R14E, 3169.9' FEL & 4988.09` FNL BP Exploration {Alaska} WGI-06 (PTD #1900300) TxIAmunication repaired • Page l ,~af~ ~~F~ Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~ "'1j2(p~ Sent: Thursday, March 06, 2008 8:43 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; GPB, EOC Specialists; GPB, Wells Opt Eng Cc: NSU, ADW WI Tech; Winslow, Jack L.; Senden, Leslie B; NSU, ADW Well Integrity Engineer Subject: WGI-06 (PTD #1900300) TxfA communication repaired Jim, The SSSV change out was completed an 02121108. Since that time, the lAP has remained stable at 600 psi. A 60-day TIO plot has been included far your reference. The well has been remaved far the monthly injection report. Please call with any questions or concerns. Thank you, Andrea Hughes From: NSU, ADW Well Integrity Engineer _ , ,~ Sent: Monday, February 18, 2008 1:56 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Many R; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FSl OTL; GPB, FSl DS Ops Lead; GPB, EOC Specialists; GPB, Wells Opt Eng Ce: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Winslow, Jack L.; Senden, Leslie B Subject: WGI-06 (PTD #1900300) Increase in IA repressurization rate Hello Jim and Tom, Well WGI-06 (PTD #1900300) is operating under Administrative Approval 4.008 dated 05/31/06 for slow IA repressurization. Over the last month, the bleed frequency has increased indicating an increase in the rate of repressurization. We believe the source of the increased repressurization is the. SSSV. A 30-day TIO plot and wellbore schematic have been included for reference. The plan forward is to: 1. Slickline: Pull and reset the SSSV 2. Well Integrity Coordinator: Monitor the TIO plot for two weeks to determine if changing out the SSSV reduced the rate of repressurization. We will communicate the results of the above actions after the monitoring period. Please let me know if you have any questions. Thank you, ,A9ZSZQ ~116e, ~P. E. tt11e11 Integrity Coordinator GPB We11s Group Phone: (9117) 659-5102 Pager: (907) 659-51(1(1 x1154 3/12/2008 WGI-06 (PTD #1900300) Increa~ IA repressurization rate ~ Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~~ ~'~~~ Sent: Monday, February 18, 2008 1:56 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr East (FS1l2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; GPB, EOC Specialists; GPB, Wells Opt Eng Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Winslow, Jack L.; Senden, Leslie B Subject: WGI-06 (PTD #1900300) Increase in IA repressurization rate Attachments: WGI-06 30-day TIO PIot.BMP; WGI-06.pdf Hello Jim and Tom, Well WGI-06 (PTD #1900300) is operating under Administrative Approval 4.008 dated 05/31/06 for slow IA repressurization. Over the last month, the bleed frequency has increased indicating an increase in the rate of repressurization. We believe the source of the increased repressurization is the SSSV. A 30-day TIO plot and wellbore schematic have been included for reference. «WGI-06 30-day TIO PIot.BMP» «WGI-06.pdf» The plan forward is to: 1. Slickline: Pull and reset the SSSV 2. Well Integrity Coordinator: Monitor the TIO plot for two weeks to determine if changing out the SSSV reduced the rate of repressurization. We will communicate the results of the above actions after the monitoring period. ,f Please iet me know if you have any questions. Thank you, ell Integrity Coordinator GPB ells Group Phone: {907) 659-5102 Fager: (907) 659-51€90 x1154 2/19/2008 ~,ooo s,a0o M• ~A .eH, /~ny_, c ~ ~~ ~~ ~~, ~~~~ 2,004 1,000 0 1 1 11 712007 12f2I~007 121171200 1 ~~008 1 J17~2008 2J1 X008 2M 7008 313008 # Tby • ~- i~ -yk- OA 04A ~O~ ~IMlC~I~B TIC Plot TREE= 6-3,`8" CAi~ERON WELLHEAD= MCEVOY ACTUATOR= BAKER KB. ELEV = ~ 60' BF. ELEV KOP = !Max Arryle - 400t`' 31 i~ 92tiii I Datum MD = NtA Datum TV D = 8800' SS 13-318" CSG, 68#, p °(" K-55, !D = 12.415" 13-318" CSG, 68#, L-80, ID = 12.415" 3491' t'~ ;` 2156' --{ ?" CAIN BA L-O SSSV NIP, ID = 5.937" 82$5' -~ 7" X 5-1l2" XO $295' - 5-1t2" BKR LOC SEAL ASSY $298' 9-5J8" X 5-1?2" BKR FB-1 PERM PKR 8301' BAKER SEALBORE EXTENSION 83'1-~-~--1 ° ~~~ BAKER €~ILLOUT EXTENSION 5-1t2" TBG-iPC, 17#, L-80, .0232 bpf, ID=4.892" ~ 831$' TOP OF 4-112" TBG-IPG $318' TOP OF 7" LNR -I $335' ]4-if2" TBG-IPC, 12.6#: L-80, .0152 bpf, iD = 3.958" I-{ $363' 9-5/8" CSG, 47#: L-80, ID = 8.681" f 8635' PERFORATION SUMh„1ARY REF LOG: FINAL CNP ON 03113/90 ANGLE AT TOP PERF: 30 @ 8883 Note: Refer to Praductian D8 for historical perf data SIZE SPF INTERVAL OpniSgz DATE 3-318" 4 8686-8738 O 05130.?90 3-31$" 4 8782-8844 O 05130'90 3-318" 4 8849-8884 O 05130?90 3-318" 4 8889-9049 O 05130?90 3-3l8" 4 9062-9085 O 05130?90 3-318" 4 9091-9097 O 05130190 3-318" 4 9101-912f O 05130.•'90 3-3t8" 4 9130-9136 d 05)30190 3-318" 4 9140-9156 O ;)5130!90 PBTD I-i 9212' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I--{ 9248' 835D' -{4-112" OTIS XN NIP, ID = 3.725" 8362' 4-1 i2" BKR SHEISROUT SUB ~NtWLEG 83$3' 4-1I2" TUBING TAIL 8348' ELMD -TT LOGGED 05?31!9© DATE REIN BY I COPI~MENTS 43f18/94 !, t3RtGtNAL CgPLETIC3N 45}4$194 LAST WORKOVE'f2 11,'""03,''01 RN,'TP CORRECTIONS 03x''25?03 JLAiKK CSG & Sr11=EiY NOTE RED 04,'11!03 JRC,'KK CASING CORRECTION 12%04!06 RAC:'TLH TREE CORRECTION SAFEI TES: DO NAT PRESSURE DA ASt~V E 3440 PSt. DATE ~ REV BY 08,-07107 DSr.I[;'SV TREE C!O PRUDHOE BAY UNIT tJVELL: b~:`G1~06 PERMf7 No °'1900300 API No: 50-029-22021-00 SEC 11, T11 N, 814E 3169.9' FEL & 4988.09' FNL 13P Exploration (Alaska} WGI-06 (PTD #1900300) TxIA unication Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Saturday, December 15, 2007 9:33 PM ~ To: Regg, James B (DOA) ~~r ~ (?i~ ~t~ l~ t.~~ Cc: NSU, ADW Well Integrity Engineer Subject: FW: WGI-06 (PTD #1900300) TxIA Communication Attachments: WGI-06 TIO PIot.BMP ~, Jim, The SSSV was reset in WGI-06 on 12105/07 maintain the IA pressure below MAASP. I have attached a TIO plot for your reference. ~µ, Since then, the iAP has again become stable with no bleeding required to Please call with any questions. Thank you, '~~' ~~G~ JAN ~ ~ ?-(lG Andrea Hughes `t x,41 Vic? l,t, ~,~;.~~ r-~f-z, ,~c~_ c' ~ Icy ~ ; j i J / F~.1~Cdrr~~ '~7~= ~~tQlr~;~il~`1 ¢GtiS1'~iif' ~+'~'SSi,v"e. - c~,,~ ~ ~ ~+`^~ ~ ~~ ~ ms's . •~~~`c~ IZ~Zu~c~~ From: Lau, John, Jack On Behalf Of NSU, ADW Well Integrity Engineer Sent: Monday, December 03, 2007 8:15 PM To: Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: RE: WGI-06 (PTD #1900300) TxIA Communication Jim, I apologize for the delay, WGI-06 is scheduled as the next well for Slickline. Weather permitting the unit should move to WGi-06 within the next few days. Please let me know ifi you have additional questions or concerns; Jack From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, December 03, 2007 10:08 AM To: NSU, ADW Well Integrity Engineer Subject: RE: WGI-06 (PTD #1900300) TxIA Communication Timeline for diagnostics? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 12/19/2007 WGI-06 (PTD #1900300) TxIA Page 2 of 2 From: Lau, John, Jack [mailto:laujj0@BP.com} On Behalf Of NSU, ADW Well Integrity Engineer Sent: Saturday, December 01, 2007 10:25 PM To: NSU, ADW Well Integrity Engineer; GPB, Area Mgr North (Gas Plants/GPMA); GPB, Area Mgr East (FSi/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Wel{ Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); Senden, Leslie B; NSU, ADW WL & Completion Supervisor; Cismoski, Doug A Cc: Lau, John, Jack; Holt, Ryan P (ASRC); Varble, Doug A Subject; WGI-06 (PTD #1900300) TxIA Communication Hello all, Well WGI-06 (PTD #1900300) has TxIA communication represented by increasing IA pressure. This well has an active Administrative Approval to continue gas injection while experiencing slow TxIA communication. The wellhead pressures were 3628/2000/100 on 11/26/07 before the IA pressure was bled to 1500 psi. After a subsequent bleed was required by operations on 11/28!07, diagnostics were performed to evaluate the IA repressurization rate. The well was shut in on 12/01/07 when the IA repressurization rate was established at 560 psi/day. The plan forward is to troubleshoot the SSSV. The plan forward is: 1. SL: Troubleshoot SSSV A weilbore schematic and plot of wellhead pressure have been included for reference. «WGI-06.pdf» «WGI-06 TIO PIot.BMP» Please call with any questions. Thank you, Jack Lau (for Anna Dube) Well Integrity Coordinator Office: (907} 659-5102 Pager: (907) 659-5100 x1154 12/ 19/2007 I 4,000 x,000 WG1~6 TICS Plot I' ~ ~ I ~0 -03c, -~-- Tbg ~ i~ 2,000 ~~ rn~,A~ 1,000 -' y'J ~,~'.~, 9~15~007 930x2007 10x1512007 10x30x2007 11 x14x2007 11 x29x2007 12M 5x2007 12x30x2007 -~- o~ oar ooo~ WGI-06 (PTD #1900300) TxIA unication Page 1 of 1 • Regg, James B (DOA) From: Lau, John, Jack [IaujjO@BP.com] on behalf of NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Saturday, December 01, 2007 10:25 PM To: NSU, ADW Well Integrity Engineer; GPB, Area Mgr North (Gas Plants/GPMA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); Senden, Leslie B; NSU, ADW WL & Completion Supervisor; Cismoski, Doug A ~~ Cc: Lau, John, Jack; Holt, Ryan P (ASRC); Varble, Doug A 1~~~~~ (Z )c°~I Subject: WGI-06 (PTD #1900300) TxIA Communication Attachments: WGI-06.pdf; WGI-06 TIO PIot.BMP Hello all, Well WGI-06 (PTD #1900300) has TxIA communication represented by increasing IA pressure. This well has an active Administrative Approval to continue gas injection while experiencing slow TxIA communication. The wellhead pressures were 3628/2000/100 on 11/26/07 before the IA pressure was bled to 1500 psi. After a subsequent bleed was required by ~~ operations on 11/28/07, diagnostics were performed to evaluate the IA repressurization rate- The well was shut in on 12/01/07 when the IA repressurization rate was established at 560 psi/day. The plan forward is to troubleshoot the SSSV. The plan forward is: 1. SL: Troubleshoot SSSV A wellbore schematic and plot of wellhead pressure have been included for reference. «WGI-06.pdf» «WGI-06 TIO PIot.BMP» Please call with any questions. Thank you, Jack Lau (for Anna Dube) Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~t~~ , y~ ~~~ ~ ~~~~ 12/3/2007 ~OOO ==: ~~~ ~o -~ ~i -s- • Oql # LaaZ! 41Z 4 ~ o -p6 - ~-~! d LOa~! 410 4 La0Z1418 L00~1419 taaz~ 41tr LaaZl0014 9aaZ141~ 4 0 aao' 4 aoa'z aoo'~ oaa'tr TREE= 8-3,'8°` CAMERON WELLHEAD= MCEVOYI ACTUATOR = BAKEF2~ KB. ELEV = 8a'' BF. ELEV = KOP=_ ~ aaao' _ Max Angle = _ 31 cz 92aQ' Datum MD = } ~ NIA Datum TV D = 8800' SS 13-318" CSG, 68#; ~-~ 71' K-55, iD = 12.415" 13-3t8" CSG, 68#, L-80, ID = 12.415" 34$1' I~Ittllt'17Ut71 I©= 3.725" ~$~50' 4-1 /2" QTIS XN NIPPLE 7" TBG-IPC, 26#, L-80, .0383 bpf, iD = 8.276" $2$5" TOP OF 5-1 F2" TBG-IPC $2$5' 5-1/2" TBG-IPC, 17#, L-80, .0232 bpf, ID = 4.882" ~ $31 $` TOP OF 4-112" TBG-I~ $31 $' TOP OF 7" LNR $335' 4-112" TBG-IPC, 12.6#, L-80, .©152 bpf, lD = 3.958" ]-~ $363' 9-5i8" CSG, 47#: t_ 80, IL) = 8.681" ~ $635` PERFORATION SUMMARY REF LOG: FINAL CNP ON 03i13r9a ANGLE AT TOP PERT: 30 ~ 8685' Note: Refer to il-oductian DB for historical perf data SIZE SPF INTERVAL Opnr'Sgz BATE 3-318" 4 8685-8738 O 0513ar9a 3-318" 4 8782-8844 O 05i3a190 3-318" 4 8849-8884 O 0513a190 3-3?8" 4 8889-9a49 O 05130.!90 3-318° 4 9062-9a85 O 05130190 3-318" 4 3091-9097 O 05130190 3-318" 4 9101-9125 O 0513a19a 3-318" 4 9130-9136 O 05130/90 3-318" 4 9140-9158 O 05130/90 PBTD f-p 9212` 7" LNR, 29#, L-8a, .0371 bpf, ID = 6.184" $295' ~ 5-1f2" BKR LUC SEAL ASSY $29$' 9-5l8" X 5-112" BKR FB-1 PERM PKR $301' BAKER SEALBORE EXTENSION $311' BAKER MILLOL}T EXTENSiO~ 8317' 7-518" X 4-112" XO $350° -~4-1/2" OTES XN NIP, ID = 3.725 $362' 4-112" BKR SHEAROUT SUB WlWLEG $363' 4-11'1° TUBING TAIL $34$°~ ELMD T7 LOGGED 05?31'9a DATE REV BY COMMENTS 0311$!90 ORiG4NAL CO~e1PLETiC3N 05008190 LAST WflRKflV ER 11,'03;01 RNiTP CORRECTIONS 03;'25!03 JLA;KK CSG ~ SAFETY NOTE REV. 04111!a3 JRCiKK CASING CORRECTION 12iG41G6 RAC/TLH TREE CORRECTkON ~ I SAFET TES: DO NOT PRESSEIREOA ABOVE3000 PSI, DATE ~ REV B~ COMMENTS 081471Q7 DS~rb'SV TREE CiO ~--~--~---- 2156° _ L CANT BAL-O SSSV NIP, lD = 5.937° MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commi TO: Jim Regg P.I. Supervisor ..-) 1',/ /;1// , ·...t.?!'.¡' , , i ' DATE: Monday, October 02, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI-06 PRUDHOE BA Y UNIT WGI-06 Src: Inspector O-D~O \C{ FROM: John Crisp Petroleum Inspector NON-CONFIDENTIAL Reviewed By: ....-.;;--<--., P.I. Suprv .Jþjè:- Comm Well Name: PRUDHOE BAY UNIT WGI-06 API Well Number 50-029-22021-00-00 Inspector Name: John Crisp Insp Num: mitJCr0609281 05317 Permit Number: 190-030-0 Inspection Date: 9/25/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. f-- , ---, I I -- Well WGI-06 jType Inj. ~ N I TVD I 7869 I IA 4]40 4320 4300 4300 , , -----.-.1__. I -- I - : I I P.T. 1900300 !TypeTest i SPT j Test psi ] 967.25 OA 730 , 730 I 730 730 I I , I I - .- Interval REQVAR P/F P Tubing I 2400 ! 2420 2420 2420 I - Notes 2nd MIT for AOGCC variance compliance. Re-pressured IA from 4140 psi to 4320 psi with ,2 bbl's. -' Monday, October 02, 2006 Page 1 of I MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commi TO: Jim Regg P.I. Supervisor v·'~ DATE: Monday, October 02, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI-06 PRUDHOE BA Y UNIT WGI-06 ~ Src: Inspector O ; 0 "30 \C{ FROM: John Crisp Petroleum Inspector NON-CONFIDENTIAL Reviewed By: 'Tìš~2- P.I. Suprv "._ . , Comm Well Name: PRUDHOE BAY UNIT WGI-06 Insp Num: mitJCr060928J04837 ReI Insp Num Permit Number: 190-030-0 Inspector Name: John Crisp Inspection Date: 9/25/2006 API Well Number 50-029-22021-00-00 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -~ Well: WGI-06 !Type Inj.: N : TVD 7869 IA I 1460 : 4260 I 4190 : 41~ I P.T. I 1900300 :TypeTest I SPT I Test psi . 1967.25 i OA: 680 I' 730 i 730 I 730:' ,- -. ' , ._~-.__.~_.----L-.~.-t----------T--'-- __...1.....-..__ Interval REQ~AR P/F I__!ubing: , 228~. I 2400 , 2400 I 2400: ; Notes 1st test for AOGCC MITIA for variance complíance. 4.8 bbl's pumped for test. Agreed with Operator to re-pressure for second test. ;'~·i.'''''''' ¡:. <~ (~.. ç,')",--¡.,,,",,, ;)¡"'iÍ"C"\~' \;~t~' kt Monday, October 02, 2006 Page I of 1 • FRANK H. iV7URKONISK/, GCS` /ER~ifOR 333 W. 7"' AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADYIINISTRA~'IVE APPR®~'AL 4E.008 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612 :anchorage, AK 99~ 19-6612 • ~~~~~ JAN ~ ~ 2008 RE: PBU ~L'GI-06 (PTD 190-030) Request for Administrative Approval Dear Mr. Rossberg: Pursuant to Rule 9 of Area Injection Order ("AIO") 04E.000, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to continue gas injection in the subject well. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU WGI-06. The Commission further finds that the well demonstrates IA repressurization of about 2~ psi per day, that can be safely managed with periodic pressure bleeds. How- ever, the Commission acknowledges that events such as SSSV control line failures may allow- the well's tubing pressure to communicate with the IA. Accordingly, the Cornrnis- sion believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety, if the well's operation is subject to the con- straints enumerated below. AOGCC's administrative approval to continue gas injection in PBU WGI-06 is condi- tioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily-; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates, and shall flag the well's periodic pressure bleeds on the report; 3. BPXA shall perform an MIT - IA every four years to the maximum anticipated injection pressure, the anniversary date of which shalt be this approval's effective date; • ~ Utr. Steve Rossberg May 3 I , 2006 Pale 2 oT 2 ~ 4. BPXA shall limit the wen's IA operating pressure to 2000 psi; ~. BPXA shall install and operate remote pressure monitoring equipment on the w-el1's IA; b_ BPS.=~ shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; and 7. after well shut in due to a change in the well's mechanical condition, AOGCC ap- proval shall be required to restart injection. As provided in AS 31.0.080, 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 consid- ered timely if it is received 6y 4:30 PtiI 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 Commi~n decision to Superior Court unless rehearing has been requested. Done ~A or e~ Alaska and dated 1~1ay 31, 2006. ~' ~j ~, o rman Dan T. 5eamount Chairman Commissioner c~ ~ ~~ ~ 'i JJgy~~ ~t t~ ~ :~z ~~ , V Y s.a~ 9~4-~~ ~ k1~i~ ~ vt:/ ~ ~ ~ ~ ,r ~ ~ ~ r~ ~~~ ~~? ~ ~ r~ R ~ t'-~~ C ' ` ii ~ `y~ a ~'.r t = r < ~.~ a~~ . C thy. Foerster Commissioner Re: WGI-06 (PTD # 1900300) Slow IA Repressurization e 'tLl1'D -0;30 BP notified the Commission about varying degrees of pressure communication affecting 6 PBU gas injectors. Wells are: AGI-06¡ TxIA NGI-01; TxIA NGI-06¡ IAxOA NGI-10¡ IAxOA NGI-13; TxIA WGI-06¡ TxIA BP intends no repairs to correct the pressure communication, instead relying on human intervention to manage the pressures. The correct mechanism for reviewing continued operation of these wells is the administrative approval process under AIO 4D Rule 9. Please submit admin approval requests to the Commissioner's attention. Jim Regg AOGCC NSU, ADW Well Integrity Engineer wrote: Hello Jim and Winton. Well WGI-06 (PTD # 1900300) is exhibiting indications of pressure communication between the tubing and IA, as noted on the attached TIO plot. An MITIA on 6/15/03 passed to 2500 psi. The field Operators safely manage this repressurization by bleeding the IA pressure approximately once every 30 days. This pressure management maintains the IA pressure below BP's maximum allowable annular surface pressure limit of 2000 psi. Current plans are to continue gas injection operations. No repairs are planned at this time. Attached is a TIO plot and wellbore schematic. Please call with any questions. «WGI-06.pdf» «WGI-06 TIO Plot.jpg» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, xl154 Email: NSUADWWeIIIntegrityEngineer@bp.com ::.r!l~~~~(?~~?_1!.!\P!'JÍ'Ì~~;b~.£1~~3E~~YJ?_~!9~_J]~_~E~ÞE~_~(?~f!? 1 of 1 3/24/2006 9:36 AM WGI-06 (PTD # 1900300) Slow IA Repressurization . e Hello Jim and Winton. Well WGI-06 (PTD # 1900300) is exhibiting indications of pressure communication between the tubing and IA, as noted on the attached TIO plot. An MITIA on 6/15/03 passed to 2500 psi. The field Operators safely manage this repressurization by bleeding the IA pressure approximately once every 30 days. This pressure management maintains the IA pressure below BP's maximum allowable annular surface pressure limit of 2000 psi. Current plans are to continue gas injection operations. No repairs are planned at this time. Attached is a TIO plot and well bore schematic. Please call with any questions. «WGI-06.pdf» «WGI-06 TIO Plot.jpg» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100,x1154 Email: NSUADWWelllnteQrityEnQineer@bp.com n u Content-Description: WGI-06.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: WGI-06 no Plot.jpg TIO Plot.jpg Content-Type: image/jpeg Content-Encoding: base64 1 of 1 3/20/2006 10:29 AM TREE = CIW GEN 4 WELLHEAD = MCE:VOY WGI-06 SAFETY NOTES: DO NOT PRESSURE OA ABOVE 3000 PSI. A CTl.IA. TOR- AXELSON KB. B..EV = 60' BF. ELEV = KOP= 4000' 1113-3/8" CSG, 68#, 71' t- Max Anale = 31 (éI) 9200' K-55, D = 12.415" . 2156' -17" CAM BAL-O SSSV NIP, ID-5.937" I DatumMD= N/A Datu m TVD = 8800' SS 113-318" CSG, 68#, L-80, ID = 12.415" I 3491' ~ ~ --::> ~P:: ~'5'Ops~ (-O~l~f5£.. -:. nSë)f~J ~ Minimum ID = 3.725" @ 8350' 4-1/2" OTIS XN NIP PLE IT' TBG-IPG, 26#, L-80, .0383 bpf, ID = 6.276" 8285' L 8285' -i7" x 5-1/2" XO I 1 TOP OF 5-112" TBG-PC I 8285' yi S 8295' -15-112" BKRLOCSEALASSY I ~ 25 8298' 1-19-518" x 5-1/2" BKR FB-1 PERM PKR I 8301' HBAKERSEALBORE EXTENSON I J 8311' -1 BAKER MLLOUT EXTENSION I 15-112" TBG-IPC, 17#, L-80, .0232 bpf, ID= 4.892" I 8318' I 8317' -i 7-518" X 4-1/2" XO I I TOP OF 4-1IZ' TBG-PC 8318' r---' TOP OF 7" LNR 8335' -- I I I 8350' 4-112" OTIS XN NIp, ID= 3.725"j l--l 8362' 4-112" BKR SHEA ROUT SUB W/\M.EG I 4-1/2" TBG-IFC, 12.6#, L-80, .0152 bpf, ID = 3.958" 8363' I 8363' 4-112" WBING TAIL I 8348' HB..MD TT LOGGED 05/31190 I I 9-518" CSG, 47#, L-80, ID = 8.681" 8635' ----J ~ -':;::> }v\ß.{ p=- ~ <3 7Df~; ÆRFORA llON SLMMARY I Cö«4f~ -:::. 41SDr~; REF LOG: ANAL GNP ON 03/13/90 ANGLEA TTOP PERF: 30 @ 8685' I Note: Refer to Production DB for historical perf data SIZE S~ INTERVAL Opn/Sqz DATE 3-318" 4 8685-8738 0 05/30/90 I 3-318" 4 8782-8844 0 05/30/90 3-318" 4 8849-8884 0 05/30/90 3-318" 4 8889-9049 0 05/30/90 [ 3-318" 4 9062-9085 0 05/30/90 3-318" 4 9091-9097 0 05/30/90 3-318" 4 9101-9126 0 05/30/90 [ 3-318" 4 9130-9136 0 05/30/90 3-318" 4 9140-9156 0 05/30/90 I PBTD I 9212' I 7" LNR, 29#, L-80, .0371 bpf, ID =6.184" 9240' DATE REV BY COMMENTS [)II. TE RE:V BY COMMENTS ffiUDHOE BA Y UNT 03/18/90 ORIGINAL COMPLETION 04/11103 JRC/KK CASING CORRECTION WB.. L: V\IG 1-06 05/08/90 LAST WORKOVER PERMIT No: 1900300 01/17/01 SIS-SL T COt-NERTBJ TO CANVAS API No: 50-029-22021-00 02/07/01 SIS-MD REVISION SEC 11, T11N, R14E, 3169.9' FEL & 4988.09' FNL 11/03/01 RNlTP CORRECTIONS 03/25/03 JLA/KK CSG & SAFETY NOTE REV. BPExploration (Alaska) MEMORANDUM TO: THRU: FROM: Randy Ruedrich Commissioner P.I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 15, 2003 SUBJECT: Mechanical Integrity Tests BPX Prudhoe Bay Field WGI Pad Prudhoe Bay Field John Crisp Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. ] vv~,I ,v.o~ I~,~,ni.I ~ I~'~'D' I ~° I~u~ I~° I~° I ~° I ~° I'~'~w'l ~ I P.T.D.I 1900300 ITypetestl P ITestpsil 2000 I Casingl 1270I 2500 I 246°l 249°l P/F I -P I Notes: OA 880 psi. during test. 2.2 BBL. Pumped I w~,,I w~,.o, I~,,e,.i.I ~ I~'¥'~' I ~ I~u~'"~ I~° I~° I ~o I ~o I,n,~v~,l , I P.T.D.I 1900400 ITypetestI P ITestpsil 2000 I Casingl 540 I 2040 I 2020 I 2000 I P/FI PI Notes: OA 200 psi. during test. 7 BBL. Pumped. I WellI P.T.D. I Type test Notes: WellI P.T.D.I Notes: Well[ P.T.D. I Type test Notes: ./,' Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. 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 Workover O= Other (describe in notes) Test's Details I traveled to PBU to witness 4 year MIT's on WGI. WGI 07 's pressure test started ~ 2500 psi. Atter 15 minutes the pressure had dropped to 2280 psi. The pressure on W-07 after 30 minutes was 2040 psi. The pressure on W-07 stabilized ~ 2040 psi. & had no change for 30 minutes. M.I.T.'s performed: 2 Number of Failures: 0 Attachments: Total Time during tests: 3 hrs. cc: MIT report form 5/12/00 L.G. ~CANNE[~' AUG 0 ~i 2003 2003-0615_MIT_PBU_WGI-07jc.xIs 6/24/2003 MEMORANDUM State of Alaska THRU: Alaska Oil and Gas Conservation Commission TO' Julie Heusser, ~-~' DATE: Commissioner Tom Maunder, P. I. Supervisor~ \ I\~'-~\- FROM: John Crisp~ SUBJECT: Petroleum Inspector January 15, 2000 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 1-15-01jc.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 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& Number Number PSI PSI T~p Code Code Code Passed GAS or CYCLE WGI-01 1~90310 3400 2900 2440 P P P GINJ WGI-02 1790430 3400 2900 2650', P P P GINi WGI-03 1790490 3400 2900 2350 P P P GINJ wGI-04 1790500 3400 2900 2350 P P P GINJi WGI-05 1~00250 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 1900490 3400 2900 2620 P P P GINJ Wells: 8 Components: 24 Failures: 2 Failure Rate: 8.3% [:390 Day Remarks: WGI-07 Shut in untill repaired & re-tested. 1/18/01 Page 1 of 1 SVS PBU WGI Pad 1-15-01jc.xls ~"-'" STATE OF ALASKA 0 !{ I G IN · ,,__~SKA OIL AND GAS CONSERVATION COMMISSION · : i~2', WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well GAS INJECTOR OIL [---] GAS r~ SUSPENDED ~ ABANDONED E~ SERVICE r-~ 2 Name of Operator '7 Permit Number ARCO Alaska, Inc 90-30 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22021 4 Location of well at surface ~~L~'~ 9 Unit or LeaSe Name ~u~ ! T'7': ....... ~-"~r PRUDHOE BAY UNIT AtTop Producing Interval ~ -~"~.~ J J V~JFi~ J 10 Well Number 172' FSL, 1959' FEL, SEC 2, T11N, R14E UM At Total Depth .ti... 11 Field and Pool 291'ESL, 2108'FWL, SEC 2, T11N, R14E UM '. ......... v ~_: PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial Nol PRUDHOE BAY OIL POOL RKB 60'I ADL 28302 12 Date Spudded 13 Date T.D. Rea'ch~cl 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 116 No. of Completions 03/02/90. 03/14/90. 05/30/90*I N/A fee! MSLI 1 , , 17 Total Depth (MD+'I-VD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set 21 Thickness of permafrost 9240' MD/8685' TVD 9212' MD/8661' TVD YES [~ NO r'~[ 2156, feet MD 1900' (approx) 22 Type Electric or Other Logs Run CBL/VDL/CBT/GR, GCT 23 CASING, LINER'AND cEMENTING RECORD ' ' ' SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ....... 20" 91.5# H-40 SURF 119' 30" 2150# POLESET 13-3/8" 68.0# L-80/K-55 SURF 3491' 17-1/2" 2200 SX AS III & 650 SX CLASS G , , , TOP JOB W/170 SX AS I 9-5/8" 47.0# L-80 SURF 8635' 12-1/4" 485 SX CLASS G & 325 SX CS I , 7" 29.0# L-80 8335' 9240' 8-1/2" 325 SX CLASS G , 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) 8685'-8738'MD/8206'-8252'TVD SIZE DEP.TH SET (MD). . .:PACKER SET (MD) 8782'-8844'MD/8290'-8344'TVD 7" / 4-1/2" 8363' 8298' PERFORATED W/4 SPF 8849'~8884'MD/8348'-8378'TVD 60°/1200 PHASING 8889'-9049'MD/8383'-8521'TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, FTC 9062'-9085'MD/8532'-8552'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9091'-9097'MD/8557'-8562'TVD N/A 9101'-9126'MD/8566'-8587'TVD 9130'-9136'MD/8591'-8596'TVD .... 9140'-9156'MD/8599'-8613'TVD 27 N/A PRODUCTION TEST , Date First Production IMethod of Operation (Flowing, gas lift, etc.) , , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE sIzE' I GAS-OIL RATIO . .. TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATF ~ 28 CORE DATA Brief description of lithology, porositY, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ' ' ' ' *NOTE: DRILLED RR 3/18/90. TUBING RUN 5/9/90. PERFORATED WELL 5/30/90. :~i,~S~,:~. Cji & Gas Cons. gnch0ra0ja , , Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS ,,, ~ Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP SADLEROCHIT 8785' 8293' GOC 9175' 8629' BASE SADLEROCHIT 9187' 8640' NONE , , , , ,, 31. LIST OF ATTACHMENTS ADDE,NDUMS (SIGNED 4/6/90 & 6/20/90) 32, I hereby certify that the foregoing is true and correct to the best of my knowledge Signed //(/~ ~ ~.~.~ ~.,~, ~,.,'/, .... Title , ....... DRILLING ANALYST Date ~' ~ - ~'~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repeal and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate '"none". Form 10-407 ADDENDUM DAILY DRILLING REPORT Well # W G I- 6 Work performed: Cost: $36.858 AFE: AS20;~5 Date: 3/27/90 Summary Ran CBL/VDL/CBT/GR w/0 psi, & 1000 psi 1. Good cement behind 7" and liner lap 2. Poor bonding behind 9-5/8" 3. Ran GR/CCL to 13-3/8" csg shoe Ran GCT (agrees w/MWD surveys) ~'NG ~PER'~DENT WELL HISTORY ADDENDUM WELL WORK LOG Well # W G I- 6 Work performed: INITIAL PERFORATIONS Cost: $79.859.00 Date: 5/30/90 AFE: AS2025 Time 0730 1050 1325 RIH 1 51 0 RIH 1 705 RIH 1 845 RIH 202O RIH 2205 RIH 2345 RIH 0145 RIH 0345 RIH O545 RIH 1055 RIH 1305 RIH 1 5O5 RIH 1645 RIH DRILLING SUPERINTENDENT RU SWS. All guns are 4 spf, 60°/120° phasing. RIH w/ gun #1, shoot f/ 9140-9156. POH, all shots fired. w/ gun #2, shoot f/ 9116-9126, 9130-9136, 9091-9097. w/ gun #3, shoot f/ 9101-9116, 9082-9085. w/ gun #4, shoot f/ 9062-9082, 903tj-9049. w/ gun #5, shoot f/ 9029-9039, 9009-9029. w/ gun #6, shoot f/ 8999-9009, 8979-8999. w/ gun #7, shoot f/ 8969-8979, 8949-8969. w/ gun #8, shoot f/ 8939-8949, 8919-8939. w/ gun #9, shoot f/ 8909-8919, 8889-8909. w/ gun #10, shoot f/ 8864-8884, 8834-8844. w/ gun #11, shoot f/ 8849-8864, 8824-8834. w/ gun #12, shoot f/ 8814-8824, 8794-8814. w/ w/ w/ gun #15, shoot f/ 8685-8705. POH, all shots fired. POH, asf. POH,'.all shots fired. POH; all shots fired. POH, all shots fired. POH, all shots fired. POH, all shots fired. POH, all shots fired. POH, all shots fired. POH, all shots fired. POH, all shots fired. POH, all shots fired. gun #13, shoot f/ 8784-8794, 8782-8784, 8735-8738. POH, asf. gun #14, shoot f/ 8725-8735, 8705-8725. POH, all shots fired. Pump 400 bbls 60/40 meth/wtr. Summary: 9140-9156 9130-9136 91_01-9126 9091 -9097 9062-9085 8889-9049 8849-8884 8782-8844 8685-8738 Freeze protect WHP=1000. Perforated all w/ 4 spf Well secured. ORIGINAL SUB-$URFACE DIRECTIONAL $URVEY I~]UIDANCE I~ONTINUOUS ~____]OOL Company ARCO ALASKA) INC. Well Nmme WGI-6 [728' FNL,1109' F)o)dJLocat)on PRUDHOE BAY~ NORTH i FEL~SEC ll,TllN,R14E,UM) SLOPEm ALASKA Jo13 Reference. No. ICi OFILMED FRITZKE Date,, 27-MAR-90 Computed B~ KRUWELL GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKAt INC. WGI - 6 PRUDHOE BAY NORTH SLOPEr ALASKA SURVEY DATE: 2T-MAR-1990 ENGINEER: A. FRITZKE METHODS OF COPqPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 61 DEG 58 MIN gEST COHPUTATION DATE: 15-HAY-90 PAGE ARCO ALASKAt INC. IdGI - 6 PRUDHOE BAY NORTH SLOPEr ALASKA TRUE SUB-SEA COURSE NEASURED VERTICAL VERTICAL DEVIATION AZIRUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN DATE OF SURVEY: IT-MAR-1990 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: A. FRITZKE INTERPOLATED VALUES FOR EVEN 100 FEET OF HEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. OEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/MEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG NIN 0.00 0.00 -60.00 0 0 N 0 0 E 100.00 100.00 40.00 0 3 S 59 41 E ZO0.O0 200.00 140.00 0 4 N 45 30 W 300.00 300.00 240.00 0 3 S 47 22 M 400.00 400.00 340000 0 7 N 78 22 ~1 500.00 500.00 440.00 0 3 S 89 52 Id 600.00 600.00 540.00 0 3 S 66 53 Id 700.00 700.00 640.00 0 6 N 83 28 ~1 800.00 800.00 740.00 0 I N 36 38 id 900.00 900.00 840.00 0 I N 88 32 Id 0 2 N 47 11 E 0 0 S 5 52 Id 0 5 S 6434 E 0 33 S 67 53 E 0 46 S 72 19 E 0 54 S 67 25 E 0 51 S 58 58 E 0 48 S 58 33 E 0 43 S 53 I E 0 37 S 86 50 E 1000.00 lO00.O0 940.00 1100.00 1100.00 1040.00 1200.00 1200.00 1140.00 1300.00 1300.00 1240.00 1400.00 1399.99 1339.99 1500.00 1499.98 1439.98 1600.00 1599.97 1539.97 1700.00 1699.96 1639.96 1800.00 1799.95 1739.95 1900.00 1899.94 1839094 0 37 N 85 6 E 0 44 N 64 7 E 0 52 N 47 39 F I 0 N 51 26 E I 5 N 5155 E I 2 N 57 45 E 0 54 N 66 36 E 1 4 N 81 16 E 1 12 N 88 13 E I 11 S 83 50 E 2000.00 1999.94 1939.94 2100.00 2099.93 2039.93 2200.00 2199.92 2139.92 2300.00 2299.91 2239.91 2400.00 2399.89 2339.89 2500.00 2499.87 2439087 2600.00 2599.86 2539.86 2700.00 2699.84 2639.84 2800.00 2799.82 2739.82 2900.00 2899.80 2839.80 I 8 S 77 13 E 0 58 S 72 39 E 045 S 66 7 E 041 S 64 9 E 0 31 S 60 23 E 0 23 S 72 16 E 0 28 S 79 10 E 0 11 S 81 35 E 3 20 N 78 37 Id 6 40 N 86 30 id 3000.00 2999.78 2939.78 3100.00 3099.76 3039.76 3200000 3199.75 3139.75 3300.00 3299.74 3239.74 3400.00 3399.74 3339.74 3500.00 3499.74 3439.74 3600.00 3599.73 3539.73 3700.00 3699.73 3639.73 3800.00 3799.69 3739.69 3900.00 3899.29 3839.29 0.00 0.00 0.00 N 0.00 E 0.00 1.01 0.15 S 0.08 0.04 0.00 0.11 S 0.10 0.15 0.04 0.10 S 0.23 id 0.24 0.00 0.07 S 0.31 id 0.33 0.24 0.10 S 0.43 id 0.46 0.00 0.08 S 0.57 id 0.59 0.15 0.05 S 0.70 Id 0.63 0.00 0.06 S 0.75 0.70 0.00 0.01 S 0.80 id 0.67 0.00 0.00 S 0.76 id 0.67 0.00 0.01 N 0.75 id 0.63 0.15 0.01 N 0.71, id 0.15 0.59 0.23 S 0.29 id -1.04 0.07 0.60 S 0.86 E -2.51 0.00 1.11 S 2.25 E -4.02 0.13 1.75 S 3.62 E -5.46 0.00 2.51 S 4.85 E -6.75 0.00 3.24 S 5.92 E -7.84 0.38 3.63 S 6.95 E -8.71 0.00 3.55 S 7.98 E -9.57 0.36 3.26 S 9.11 E -10.16 0.00 2.43 S 10.21 E -10.73 0.29 1.36 S 11.43 E -11.50 0.00 0.22 S 12.91 E -12.35 0.10 0.85 N 14.45 E -13.28 0.43 1.67 N 15.93 E -14.50 0.30 2.11 N 17.54 E -16.21 0.00 2.26 N 19.57 E -18.09 0.10 2.18 N 21.66 E -19.99 0.00 1.86 N 23.64 E -21.86 0.39 1.39 N 25.50 E -23.34 0.12 0.84 N 26.90 E -24.60 0.00 0.31 N 28.03 E -25.64 0.16 0.18 S 28.95 E -26.40 0.00 0.53 S 29.63 E -27.17 0.00 0.73 S 30.39 E -27.75 0.14 0.82 S 31.00 E -26.07 3.10 0.55 S 29.25 E -17.83 3.77 0.65 N 20.55 E 0.00 N 0 0 E 0.17 S 28 12 id 0.15 S 42 4 W 0.25 S 66 13 id 0.32 S 77 14 Id 0.44 S 76 52 id 0.58 S 81 55 ~-' ~ 0.70 S 86 10 ~ 0.75 S 85 24 # 0.80 S 89 32 M 0.76 S 89 55 id 0.75 N 88 53 Id 0.71 N 89 29 Id 0.37 S 51 5 Id 1.05 S 55 24 E 2.51 S 63 40 E 4.02 S 64 10 E 5.4,6 S 62 36 E 6.75 S 61 20 E 7.84 S 62 26 E 8.74 S 66 0 E 9.67 S 70 18 E 10.50 S 76 36 E 11.51 S 83 14 E 12.91 S 89 0 E 14.47 N 86 37 E 16.02 N 84 I E 17.67 N 83 9 t .ii 19.70 N 83 24 E 21.77 N 84 15 E 23.71 N 85 30 E 25.54 N 86 53 E 26.91 N 88 12 E 28.03 N 89 22 E 28.95 S 89 39 E 29.63 S 88 58 E 30.40 S 88 37 E 31.02 S 88 30 E 29.25 S 88 55 E 20.56 N 88 11 E CONPUTATION DATE: 15-#AY-90 PAGE 2 ARCO ALASKAt INC. #O! - 6 PRUDHOE BAY NORTH SLOPEr ALASKA DATE OF SURVEY: IT-NAR-t990 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: A. FRITZKE INTERPOLATED VALUES FOR EVEN 100 FEET OF NEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZo DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/MEST DZST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 4000.00 3998.24 3938.24 10 6 4100000 4096.34 4036034 11 39 4200.00 4193.83 4133.83 14 36 4300000 4289.48 4229048 18 51 4400.00 4383.78 4323078 19 37 4500.00 4478.16 4418.16 19 3 4600.00 4572.48 4512048 19 48 4700.00 4666.62 4606062 19 30 4800.00 4760.65 4700.65 ZO 42 4900.00 4853.25 4793.25 23 36 N 88 3 Id -4.98 4.12 N 77 41 Id 12.95 3.96 N 66 34 id 34.83 5.09 N 63 41 id 63.89 2.38 N 63 28 Id 97.14 0.57 N 65 58 Id 130.16 0.95 N 66 7 id 163.28 0.83 N 64 37 Id 196.95 0.78 N 62 22 Id 230.96 2.76 N 61 3 id 268.65 2.79 1.06 N 6.21 E 6.30 N 80 18 E 2.95 N 13.10 id 13.43 N 77 19 bi 10.45 N 33.89 bi 35047 N 72 52 bi 22.80 N 60.24 bi 64.41 N 69 16 id 37-65 N 90.00 id 97.56 N 67 18 bi 51.89 N 119.83 bi 130.58 N 66 35 bi 65.25 N 150.24 bi 163.80 N 66 31 ' ~ 79.29 N 180.91 bi 197.52 N 66 ZO ~ · / 94.47 N 211.36 bi 231.51 N 65 55 id 112.56 N 244.43 bi 269.10 N 65 16 id 5000.00 4943.99 4883.99 25 59 5100.00 5033.55 4973.55 26 51 5200.00 5122.38 5062.38 27 37 5300.00 5210097 5150097 27 42 5400000 5299.55 5239.55 27 40 5500.00 5387.88 5327088 28 7 5600.00 5476.39 5416.39 27 12 5700000 5565.62 5505062 26 48 5800000 5654.58 5594058 27 26 5900.00 5743.47 5683047 27 5 N 64 33 id N 67 29 Id N 68 46 id N 67 44 Id N 67 43 id N 68 16 id N 66 55 id N 65 15 Id N 64 S5 Id 310.66 2.50 355.02 1097 400.65 1.13 446.76 0.48 492.94 0.62 539.55 0.55 585.86 1.78 630089 lo00 676.51 0035 722.24 0040 131.90 N 281.72 bi 311.07 N 64 55 Id 149.89 N 322.40 Id 355.54 N 65 4 M 166.73 N 365.12 bi 401.39 N 65 27 Id 184.07 N 408.13 Id 447.72 N 65 43 id 201070 N 451.06 Id 494.10 N 65 54 id 219.23 N 494.54 Id 540.95 N 66 6 id 236.84 N 537.63 Id 587.48 N 66 14 bi 255.42 N 578.75 Id 632061 N 66 11 id 274.70 N 620017 Id 678028 N 66 7 Id 293095 N 661.73 Id 724.08 N 66 3 id 6000.00 5832.66 5772o66 26 42 6100.00 5921.99 5861099 26 48 6200000 6011.30 5951.30 26 36 6300.00 6100.87 6040087 26 15 6400.00 6190.48 6130.48 26 33 6500.00 6279.40 6219.40 28 2 6600.00 6367.28 6307.28 28 45 6700.00 6454096 6394.96 28 47 6800.00 6542.57 6482.57 28 55 6900.00 6630.11 6570.11 28 49 N 64 31 id 767.42 N 64 31 Id 812.33 N 64 46 id 857.27 N 67 41 id 901.60 N 67 51 id 945074 N 67 19 id 991.28 N 66 58 id 1038.81 N 67 12 id 1086.69 N 67 13 bi 1134.71 N 67 4 id 1182.85 0.28 0.23 0.85 0.62 0.94 1.43 0.30 0o31 0030 0.32 313029 N 702.62 id 769.30 N 65 58 bi 332.67 N 7&3.17 Id 814.23 N 65 53 id 352.00 N 783.79 bi 859.20 N 65 49 Id 69 90 N 824.48 bird903.66 N 65 50 id 86:60 N 865.60 Id 948.01 N 65 56 id 404.09 N 907.88 id 993.75 N 66 0 Id 422.64 N 951.85 bi 1041.46 N 66 3 ~' 441.37 N 996.12 bi 1089.53 N 66 6 ~ ,1~ 460006 N 1040.58 bi 1137.74 N 66 9 Id 478.81 N 1085.13 id 1186.07 N 66 11 bi 7000.00 6717.88 6657088 28 29 7100000 6805.95 6745.95 28 4 7200.00 6894.28 6834.28 27 52 7300.00 6983.01 6923.01 26 55 7400.00 7072.67 7012.67 25 45 7500.00 7162.71 7102.71 25 59 7600.00 7252.33 7192.33 26 41 7700.00 7341.49 7281.49 27 10 7800000 7430.26 7370026 27 40 7900000 7518.63 7458.63 28 6 N 65 3 Id 1230063 N 63 46 id 1277.94 N 61 50 id 1324.83 N 61 20 id 1370.94 N 60 38 id 1415.21 N 58 51 id 1458.68 N 58 49 id 1502.98 N 58 45 Id 1548.18 N 58 54 id 1594.15 N 58 50 Id 1640o90 I °08 O. 96 00O4 1.42 0.86 0.70 0.62 0.52 0.69 0.32 498.16 N 1128.96 id 1233.98 N 66 11 518.63 N 1171.66 Id 1281.32 N 66 7 id 540015 N 1213.32 Id 1328.12 N 66 0 id 562.07 N 1253.88 id 1374.10 N 65 51 id 583.52 N 1292.62 bi 1418.23 N 65 42 id 605.49 N 1330.17 628.49 N 1368.11 t/ 1505.,56 N 65 Z0 Id 651.93 N 1406.84 Id 1550.56 N 65 8 675.77 N 1446.23 id 1596.32 N 64 57 Id 699.97 N 1486.31 bi 1642.89 N 64 47 bi CONPUTATION DATE: 15-MAY-90 PAGE 3 ARCO ALASKAt INC. MGI - 6 PRUDHOE BAY NORTH SCOPEt ALASKA DATE OF SURVEY: ZT-MAR-1990 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: A. FRITZKE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZI#UTH DEPTH DEPTH DEPTH DEG #IN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/MEST DIST. AZZ#UTH FEET DEG/100 FEET FEET FEET DEG MZN 8000.00 7606.83 7546.83 28 6 8100.00 7694.98 7634.98 28 17 8200.00 7782.96 7722.96 28 30 8300.00 7870.72 7810072 28 47 8400.00 7958.29 7898o29 28 59 8500000 8045.61 7985.61 29 21 8600.00 8132.59 8072.59 29 45 8700000 8219.29 8159.29 30 4 8800.00 8305.78 8245078 30 14 8900.00 8392.11 8332.11 30 15 N 59 50 id 1687.96 N 60 19 M 1735.15 N 60 24 ii 1782.69 N 60 39 id 1830.60 N 60 48 ii 1878.88 N 61 19 M 1927.61 N 61 33 id 1976.94 N 60 56 ii 2026077 N 61 20 id 2076.95 N 61 18 id 2127.42 0 0.35 0.34 0.55 0.43 0.52 0.30 0.78 0.26 0.99 724.07 N 1526.79 bi 1689.78 N 64 38 Id 747.61 N 1567.72 bi 1736.86 N 64 30 bi 771.10 N 1609.07 id 1784.29 N 64 24 Id 794.72 N ~1650.77 bi 1832.11 N 64 18 ii 818.35 N 1692.88 bi 1880.30 N 64 12 ii 841.97 N 1735.52 ii 1928.97 N 64 7 ii 865.52 N 1778.87 bi 1978.26 N 64 3 889.60 N 1822.50 bi 2028.03 N 63 59 k 913.78 N 1866.48 id 2078.16 N 63 55 Id 938.01 N 1910.75 Id 2128.57 N 63 51 bi 9000.00 8478.59 8418.59 30 16 9100.00 8564.80 8504080 30 33 9200.00 8650.88 8590.88 30 41 9240000 8685027 8625.27 30 41 N 61 44 ii 2177.64 N 62 14 ii 2228.30 N 62 21 ii 2279.20 N 62 21 Id 2299.61 0.71 0.22 0.00 0.00 962.05 N 1954.85 bi 2178076 N 63 48 Id 985.80 N 1999.59 Id 2229.39 N 63 45 Id 1009.48 N 2044.65 bi 2280.27 N 63 43 ii 1018.96 N 2062.73 bi 2300.68 N 63 43 Id COMPUTATION DATE: 15-HAY-90 PAGE ARCO ALASKAt INC. WGI - 6 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 2T-#AR-I990 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: A. FRTTZ. KE XNTERPOLATED VALUES FOR EVEN 1000 FEET'OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG HIN DEG HIN VERTICAL DOGLEG RECTAlqGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET OEG NIN 0.00 0.00 -60.00 0 0 1000.00 1000.00 940°00 0 2 2000.00 1999.94 1939.94 0 37 3000.00 2999.78 2939°78 I 8 4000.00 3998.Z4 3938.24 10 6 5000.00 4943.99 4883.99 Z5 59 6000.00 5832.66 5772.66 26 42 7000.00 6717.88 6657.88 28 29 8000.00 7606.83 7546.83 28 6 9000.00 8478.59 8418.59 30 16 N 0 0 E 0.00 N 47 11 E 0.67 N 85 6 E -8.71 S 77 13 E -19.99 N 88 3 W -4.98 N 64 33 W 310.66 N 64 31 W 767.42 N 65 3 ia 1230.63 N 59 50 W 1687.96 N 61 44 M 2177.64 0.00 0.00 0.00 0.00 4.1Z 2.50 0.28 1.08 0 0.71 0.00 N 0.00 E 0.00 N 0 0 E 0.00 S 0.76 W OoT6 S 89 55 ~1 3.55 S 'i'.98 E 8.74 S 66 0 E 1.86 N 23.64 E Z3.71 N 85 30 E 1.06 N 6.21 E 6.30 N 80 18 E 131.90 N 281.7Z ia 311.07 N 64 55 ia 313.29 N 702.62 1,,I 769.30 N 65 58 ' 498.16 N 1128.96 ia 1Z33.98 N 66 11 T24.07 Iq 1526.79 1,,I1.689.78 N 64 38 ia 962.05 N 1954.85 W 2178.76 N 63 48 ia 9Z40.00 8685.27 8625.27 30 41 N 62 21 ia 2299.61 0.00 1018.96 N 2062.73 M 2300.68 N 63 43 W CONPUTATION DATE: 15-NAY-90 PAGE ARCO ALASKA, INC. MG! - 6 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 27-#AR-1990 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: A. FRITZKE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE mEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEPTH DEG giN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/IdEST DIST. AZIMUTH FEET DEG/tO0 FEET FEET FEET, DEG mIN 0.00 0.00 -60.00 0 0 N 0 0 E 60.00 60.00 0.00 0 3 S 47 40 Id 160.00 160.00 100.00 0 Z N 11 4¢ Id 260.00 260.00 200o00 0 6 S 84 0 Id 360.00 360.00 300.00 0 4 N 51 58 Id 460.00 460.00 400.00 0 4 S 48 9 Id 560.00 560.00 500.00 0 S N 86 23 Id 660.00 660.00 600000 0 6 N 65 38 Id 760.00 760.00 700.00 0 I S 9 2 Id 860000 860.00 800000 0 3 N 37 55 Id 0.00 0.00 0.00 N 0.00 E 0.01 1.23 0.12 S 0.08 Id 0.00 0.00 0.14 S 0.08 ~1 0.12 0.00 0.08 S 0.18 ii O.1T 0.21 0.10 S 0.25 kl 0.32 0.17 0.09 S 0.41 Id 0.43 0.23 0.07 S 0.53 Id 0.52 0.00 0.07 S 0.63 ii 0.63 0.00 0.06 S 0.75 Id 0.67 0.00 0.03 S O.T7 ii 0.00 N 0 0 E 0.15 S 31 14 U 0.16 S 29 6 M 0.20 S 65 59 Id 0.27 S 68 27 Id 0.42 S 77 29 Id 0.53 S 82 8 I,' ~ 0.63 S 83 43 L 0.75 S 85 33 id 0.77 S 87 58 id 960.00 960.00 900.00 1060000 1060.00 1000.00 1160.00 1160.00 1100.00 1260.00 1260.00 1200.00 1360o01 1360.00 1300000 1460.02 1460.00 1400000 1560.03 1560.00 1500000 1660.04 1660.00 1600000 1760.05 1760.00 1700.00 1860.05 1860.00 1800.00 0 3 S 83 19 E 0 0 N 46 36 bi 0 I N 80 37 E 0 19 S 56 51 E 0 44 S 74 S E 0 53 S 69 19 E 0 53 S 65 44 E 0 49 S 58 30 E 0 42 S 53 53 E 037 S 75 3 E 0.69 0.00 0.01 S 0.79 0.67 0.00 0.01 N O.T5 0.67 0.00 0.02 N 0.75 id 0.44 0.54 0.10 S 0.56 Id -0.54 0.00 0.45 S 0.37 E -1.89 0.11 0.89 S 1.67 E -3.43 0.28 1.48 S 3.10 E -4.91 0.12 2.22 S 4.38 E -6.26 0.20 2.94 S 5052 E -7.43 0.43 3.56 S 6.52 E 0.79 S 89 12 bi 0.75 N 88 56 Id 0.75 N 88 46 Id 0.56 S 80 0 Id 0.58 S 39 31 E 1.89 S 62 8 E 3.44 S 64 27 E 4.91 S 63 6 E 6.26 S 62 0 E 7.43 S 61 22 E 1960006 1960.00 1900.00 Z060.OT 2060.00 2000.00 2160007 2160.00 2100.00 2260.09 2260.00 2200.00 2360.10 2360.00 2300.00 2460012 2460.00 2400.00 2560.14 2560.00 2500.00 2660015 2660.00 2600000 2760.17 2760.00 2700.00 2860.19 2860.00 2800°00 0 35 N 83 14 E 0 41 N 73 49 E 0 47 N 49 27 E 0 57 N 48 24 E I 6 N 52 45 E I 5 N 55 42 E 0 58 N 61 35 E 0 58 N 76 3 E I 12 N 86 14 E I 12 S 86 19 E -8.37 0.00 3.59 S 7.57 E -9.25 0.28 3.44 S 8.65 E -9.96 0.33 2.82 S 9.78 E -10.48 0.03 1.80 S 10.91 E -11.19 0.00 0.69 S 12.31 E -12.00 0.00 0.45 N 13.83 E -12.90 0.19 1.38 N 15.35 E -13.95 0.24 1.97 N 16.85 E -15.50 0.00 2.22 N 18.74 E -17.33 0.06 2.25 N Z0.83 E 8.38 S 64 36 E 9.31 S 68 19 E 10.18 S 73 54 E 11.06 S 80 38 E 12.33 S 86 47 E 13.84 N 88 9 E 15.41 N 84 52 E 16.97 N 83 20 [ 18.87 N 83 14 E 20.95 N' 83 50 E 2960.21 2960.00 2900.00 3060.23 3060.00 3000.00 3160.24 3160.00 3100.00 3260.25 3260.00 3200.00 3360.26 3360.00 3300.00 3460.26 3460.00 3400.00 3560.27 3560.00 3500.00 3660027 3660.00 3600.00 3760.2T 3760.00 3TO0.O0 3860.49 3860.00 3800.00 I 8 S 80 31 E I 7 S 75 26 E 0 51 S 67 43 E 0 43 S 64 28 E 034 S 6126 E 0 24 S 61 15 E 0 29 S 75 46 E 0 21 S 84 8 E I 11 N 82 23 Id 5 24 N 81 52 Id -19.24 0.21 2.01 N 22.87 E -21.15 0.00 1.58 N 24.80 E -22.80 0.33 1.06 N 26.39 E -24.11 0.00 0.52 N 27.59 E -25.27 0.10 0o01 N 28.63 E -26.14 0.21 0.42 S 29.38 E -26.85 0.01 0.66 S 30.07 E -27.58 0.27 0.80 S 30.82 E -27.59 6.09 0.84 S 30.81 E -21.65 2.89 0.24 N 24.65 E 22.96 N 84 58 E 24.85 N 86 21 E 26.42 N 87 42 E 27.60 N 88 55 E 28.63 N 89 59 E 29.39 S 89 10 E 30.07 S 88 44 E 30.83 S 88 31 E 30.82 S 88 26 E 24.66 N 89 26 E COMPUTATION DATE: 15-MAY-90 PAGE 6 ARCO ALASKAt INC. WGI - 6 PRUDHOE BAY NORTH SLOPEr ALASKA DATE OF SURVEY: IT-MAR-1990 KELLY .BUSHING ELEVATION: 60.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG #IN DEG WIN 3961.25 3960.00 3900.00 8 28 4062.91 6060.00 4000.00 1! 32 4165.14 6160.00 4100.00 13 4 4268092 4260.00 4200000 17 57 4374.76 6360.00 6300.00 19 40 4680079 4460.00 4400000 19 6 4586.74 4560.00 4500.00. 19 46 6692098 6660.00 4600.00 19 32 4799.31 6760.00 4700.00 20 40 6907.35 4860.00 6800.00 23 48 ENGINEER: A. FRITZ,KE 5017.83 6960.00 4900.00 26 10 5129.70 5060.00 5000.00 27 13 5242045 5160.00 5100000 27 35 5355.36 5260.00 5200.00 27 36 5468.39 5360.00 5300.00 28 6 5581055 5460.00 5400.00 27 25 5693070 5560.00 5500.00 26 46 5806.11 5660.00 5600.00 27 25 5918.56 5760.00 5700000 27 2 6030060 5860.00 5800.00 26 39 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET OEG 6142.58 5960.00 5900.00 26 47 6254.41 6060.00 6000.00 26 22 6365.95 6160.00 6100000 26 21 6478.08 6260.00 6200.00 27 41 6591.70 6360.00 6300.00 28 45 6705.75 6460.00 6400.00 28 47 6819.92 6560.00 6500.00 28 58 6934.10 6.660.00 6600.00 28 41 7047088 6760.00 6700.00 28 16 7161022 6860.00 6800.00 27 56 N 88 52 W -10.59 3.33 N 84 10 W 5.93 2.30 N 68 9 W 26.50 4.06 N 64 13 W 56.03 3.88 N 63 23 W 88067 0.54 N 65 21 W 123.89 1.43 N 66 16 W 158.81 0.91 N 64 44 id 194.60 0.80 N 62 23 W 230.71 2.75 N 61 7 W 271.57 2.68 TZT¢.IT 6960.00 6900.00 27 15 7385.92 7060.00 7000.00 25 51 7496.99 7160.00 7100.00 25 58 7608.59 7260.00 7200.00 26 44 7720.82 7360.00 7300.00 27 16 7833060 7460.00 7400.00 ZT 52 7946090 7560.00 7500.00 28 T 8060029 7660.00 7600.00 28 11 8173.89 7760.00 7700.00 28 27 8287077 7860.00 7800.00 28 44 N 65 13 id 318.50 N 68 19 W 368.44 N 67 59 g 420.19 N 67 37 W 672.34 N 68 11 id 524.75 N 67 20 W 577.41 N 64 57 id 628.06 N 65 16 W 679.31 N 64 48 g 730.68 N 64 25 W 781.15 N 64 29 W 831.50 N 66 28 W 881.47 N 68 0 W 930.65 N 67 23 W 981.11 N 66 58 W 1034.83 N 67 12 W 1089.65 N 67 13 W 1144.30 N 66 42 W 1199.19 N 64 23 W 1253.37 N 62 16 id 1306.69 N 61 31 W 1359.20 N 60 50 id 1409.07 N 58 53 id 1457.36 N 58 50 W 1506.83 N 58 47 W 1557.70 N 58 54 id 1609.79 N 59 10 id 1662.97 N 60 10 id 1716.38 N 60 26 id 1770.24 N 60 36 W 1824.72 0.89 N 12.47 E 12.50 N 85 55 E 1.80 N 5.76 W 6.03 N 72 36 W 7.21 N 26.18 W 27.15 N 74 36 W 18.46 N 51.38 W 54.60 N 70 15 W 33.87 N 82.42 W 89.11 N 67 40 W 49.29 N 114.11 W 124.30 N 66 38 W 63.43 N 166.14 W 159.32 N 66 32 I,' '~ 78.29 N 178.78 W 195.17 N 66 21 k / 94.36 N 211.14 Id 231.26 N 65 55 id 113.97 N 246.98 W 272.01 N 65 14 W 1.86 2.00 0.70 0.31 0.54 1.63 0.87 0.42 0.44 0.07 135.21 N 288.86 Id 318.92 N 64 55'W 154.97 N 334.90 W 369.02 N 65 10 W 173.98 N 383.40 W 421.03 N 65 36 W 193.83 N 431.91 Id 473.41 N 65 50 W 213.70 N 480.71 g 526.08 N 66 2 W 233.55 N 529.81 W 579.00 N 66 13 W 254.21 N 576.19 W 629.77 N 66 12 id 275.87 N 622.72 W 681.09 N 66 6 W 297.53 N 669.37 W 732.52 N 66 2 W 319.21 N 715.02 W 783.04 N 65 57 W 0.43 1.68 0.39 1.64 0.31 0.29 0.25 1.05 0.78 0.99 340.93 N 760.49 W 833.42 N 65 51 362.03 N 805.88 380.89 N 851.54 W 932.85 N 65 54 W 400.16 N 898.46 M 983.54 N 66 0 W 421.07 N 948.18 W 1037.47 N 66 3 W 442.44 N 998.68 id 1092.29 N 66 6 W 463.79 N 1049.45 W 1147.37 N 66 9 V 485.25 N 1100.21 507.88 N 1149.56 Id 1256.74 N 66 10 531.65 N 1197.29 1.27 0.91 0.73 0.51 0.48 0.60 0.62 0.25 0.20 0.44 556.45 N 1243.58 W 1362.40 N 65 54 W 580.51 N 1287.27 id 1412.11 N 65 44 W 604.82 N 1329.04 W 1460.19 N 65 32 W 630.49 N 1371.41 W 1509.40 N 65 19 W 656.88 N 1415.00 W 1560.03 N 65 6 Id 683.86 N 1459.64 W 1611.89 N 64 54 id 711.36 N 1505.24 id 1664.87 N 64 42 id 738.29 N 1551.42 W 1718.13 N 64 33 W 764095 N 1598.26 M 1771.87 N 64 25 W 791.84 N 1645.65 W 1826.24 N 64 18 W COMPUTAT'I:ON DATE: 15-#AY-90 PAGE ARCO ALASKA, INC. #GI - 6 PRUDHOE BAY NORTH SLOPEr ALASKA DATE OF SURVEY: 27-NAR-I'990 KELLY BUSHING ELEVATION: 60000 FT ENGINEER: A. FRITZKE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG giN DEG NIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/MEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET OEG NIN 8401095 7960000 T900.O0 28 59 8516.52 8060.00 8000.00 19 25 8631.58 8160.00 8100.00 29 ,8 8747.05 8260.00 8100.00 30 5 8862.80 8360.00 8300.00 30 2 3 8978.49 8,60.00 8,00.00 30 10 9094.42 8560.00 8500.00 30 32 9210061 8660.00 8600000 30 ,1 ,o.oo N 60 49 W 1879082 N 61 24 g 1935.72 N 61 14 g 1992063 N 61 15 W 2050.35 N 61 20 ~ 2108.64 N 61 31 ~ 2166o82 N 62 13 ~ 2225.46 N 62 21 # 2284.61 N'62 21 g 2299.61 0.51 0 .T2 0.47 0.24 O.T5 0.22 0.00 0.00 818.82 N 1693.71 g 1881.25 N 64 12 845.85 N 1742.63 ~ 1937.07 N 64 7 873.04 N 1792.63 g 1993.92 N 64 2 901001N 1843.14 g 2051.58 N 63 57 928.99 N 1894o28 g 2109081 N 63 53 956.90 N 1945.32 ~ 2167.94 N 63 48 984°48 N 1997.08 W 2226055 N 63 46 1011.99 N 2049°44 ~ 1285o68 N 63 43 1018.96 N 2062.73 ~ 1300.68 N 63 ,3 COMPUTATION DATE: 15-MAY-90 PAGE~ 8 ARCO ALASKA· INC. #GI - 6 PRUDHOE BAY NORTH SLOPE· ALASKA MARKER 13 3/8N CASING SHOE 7w CASING TOP 9 5/8m CASING SHOE SAG SHUBLIK TOP SAD ZONE 4 ZONE 3 ZONE 2 ZONE la LAST GCT READING GOC BASE SAD PBTD* TO DATE OF SURVEY: Z?-MAR-1990 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: A. FRIT!KE INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 716· FNL & 1109· FELt SEC11T11N R14E·UM MEASURED DEPTH TVO BELON KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/MEST 9163.80 8619.75 8559.75 1000.90 N 2028.28 9175.00 8629.38 8569.38 1003.55 N 2033.34 9187.00 8639.70 8579.70 1006.~0 N 2038.77 9212.00 8661.20 8601.20 1012.32 N 2050.07 9240.00 8685.27 8625.27 1018.96 N 2062.73 3491.00 3A90.74 3~30.74 0.51 S 29.57 8335.00 7901.39 7841.39 801.99 N 1665.47 8635.00 8162.97 8102.97 873.85 N 1794.12 8682.00 8203.71 8143.71 885.21 N 1814.62 8741.00 8254.77 8194.77 899.5~ N 1840.48 8785.00 8292.82 8232.82 910.16 N 1859.85 ,8785.00 8292.82 8232.82 910.16 N 1859.85 8865.00 8361.90 8301.90 929°52 N 1895.25 8942.00 8428.43 8368.43 948.14 N 1929.25 9126.00 8587.20 8527.20 991.95 N 2011.28 ARCO ALASKA, INC. WG! - 6 PRUDHOE BAY NORTH SLOPE, ALASKA MARKER 13 3/8" CASING SHOE 7# CASING TOP 9 5/8" CASZNG SHOE SAG SHUBLZK TOP SAD ZONE & ZONE 3 ZONE Z ZONE lA LAST GCT READING GOC BASE SAD PBTO TD COMPUTATION DATE: 1S-MAY-90 PAGE 9 DATE OF SURVEY: 27-MAR-I'M90 KELLT BUSHZNG ELEVATION: 60.00 FT ENGZNEER: A. FRITZ,EE · f~::~f~f STRAT ]:GRAPHIC SUMMARY SURFACE LOCATION : ?28' FNC E, 1109' FEL, SEC11 T11N R14E,UN NEASUREO DEPTH TVO BELON KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/MEST 3491.00 3490.74 3430.74 0.51 S 29.57 8335.00 7901.39 7841.39 802.99 N 1665.47 8635.00 8162.97 8102.91 873.85 N 1794.12 8682.00 8203.71 8143.71 885.21 N 1814.62 8741.00 8254.77 8194.77 899.54 N 1840.48 8785.00 8292.82 8232.82 910.16 N 1859.85 8785.00 8292.82 8232.82 910.16 N 1859.85 8865.00 8361.90 8301.90 929.52 N 1895.25 8942.00 8428.43 8368.43 948.14 N 1929.25 9126.00 8587.Z0 8527.20 991.95 N 2011.28 9163.80 8619.75 8559.75 1000.90 N 2028.28 9175.00 8629°38 8569.38 1003.55 N 2033.34 9187.00 8639.70 8579.70 1006.40 N 2038.77 9212o00 8661.20 8601.20 1012.32 N 2050.07 9240.00 8685.27 8625.27 1018.96 N 2062.73 FINAL WELL LOCATTON AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 9240.00 8685.27 8625.27 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 2300.68 N 63 43 1~ SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA, INC. WELL WOI - 8 FIELO PRUOHOE BAY COUNTRY USA RUN ONE DATE LOOOEO 27 - MAR - 90 REFERENCE 738S2 RE EIV£D JUN - 6 1990 7jlas~ Oil & (;as Cons. commissiorl ;Anchorage WELL' WGI-6 ~ ,HORIZONTAL PROJECTION (728' FNL, 1109' FE"~-~' SEC 11, TllN, R14E, UM) J s ~ ~~ _~ I.~ i : : , ~ , ' ' - -'r-'t--~' .-?--'l--.i- ....... ~-.4-'. ..' .... ~-...,l- .... ' ' ' '-- . , ' "'?'" "?' ~ ~ ~ ? ! i-.;--~: .~ ~ ?477-v+4q-4-~M~. -~..'~'~, , ~ ~ ;-~_~I ~ r ? r ~ ~ '-I-!-,."i-.b+-H-4 ..... ;.+.b;... 4-4-4+ .... H.;- _k ]_i J ' ' ~ ~ ! i ~ ! I ~ ; | I' ,~, 'T ..... T' "w'-'~` T ' r-'l'-~" ."'~ ~ h-4.--,~,,.,i-. I ...~. , ' ; ,. , --*~/ '"~'"'-'?-,'T'-'"'?'"-'~'"'~- - ~ --',tM4--~, ....................... ,.~ _.,~ ~ · . , -I . , ~ ~ '-'t~-- 4--.4 .... '- -1-4- ~ , , ' ..... -?' ""r" ~-~"" .: . . - ~ ~_....~....~ , . . 't- -4' ~ - 4.,-,1--? ..... + - ~,, ~ .... ,..+..~...._~ .............. . ;_,...,_,.: . r .... 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I: ~~I -:i[~l' i. , :~ ~'~?'~-'1 ......... ~..~-~ ..... ~---~..~ ..... ; r..~--~-?--~.~~ ~ ~ ~ ~,T~ T , i ~ ~ ~ [ ~ ~ ~:~ :~--~-~"~-~~'~ ~ ~i~~ ,,, ; ~;: i;'~--+.-!-.~ ...... t~-+.ff---f-'~-+'.'~ ....... ~-~.'t'"~-~'~i--~-~- . : ~ / ! ~ ; : , : : ; : ~:~ -' ~,:: :; , - . ~ ' - : ~ ' - - ~ : : : : : - , , i ~ ~ ~''~-~ '*~ .... ?~'"T'"'~?~ tF i i {i~ ~~ "~"~ ....... ?~'~'"? ...... ?"*~'~'"?'*T"T'~T"? .... :-~"'~- ~ , , , ~ ~ ....... ~ ....... , .............. ~ , ~ ,~ ~ . , ~ . , , :T: f i~ i ~-~-'~'?-~'-t-~-", ....... ~.--~..4.~-~-~. f , , ' , ~ '~'~"~"~-~"'"~""'~ ........ ?~'~"'"f-~'~ .......... *"~ ~- :'~'"~'T- ~,.~... ~_~.~. ~.~.., ....... {...,..~ ........................ ~ ................... ~.~.~ - ~. ~ .: : ~ ....... , .................................................... { ........................ ~...d.4_.r.~- ~ ~ ~ ~ ~ ~: L ~-.~~;...L~..~4...t..~..~..~ ~ ~ ~ ~ ~ T ~ L ~ ~ ~ ~.-.~.~-~..~....~.~-~...~ ...... *...~..;.-~ 41~"l*'"~'"~'" ~..~.4..d--~...~... : · _ · ~. ~.. ~.. -~..-~.~ ........ ~- -~ ~ ..... ~...~..~...~ ...... ~ ........ ~ ...... , .................. ~ ....... , ...... ~ ..... , ....... ~..~ F~3,.ECTION ON VERTICI:IL PLI:II~ 298. - 118. ~ IN VERTIC¢II. OI~PTH6 HORIZ $Ct~,£ = 1/500 IN/FT ORIGINAL C(XgP~,~Y ;J~N~,'O0 AIJ$~ INC, WELL ~ ~I-6 LOCATI~ 1 PRUDHO£ ~Y I~)CATI~ 1! ~ ~h~-'hL~'~IC D~I,I~TI~ ~,75 WELL HEAD LIr, ATI~: LAT(~'-S) 0.00 P. ZI~LYTH ~ RI~T~¥ T~I.l~ 1'0 T~W~1~ IS D~(F./-W) RECEIVED n PR ! 8 19.o0 Alaska 011 & Gas Cons. Commi~lon Anchorage , lCi O :i L ,, ED I'~~ INTl.'UAL UF. RTI~ !)DTH I)~TH ft fi: ft 488.0O 0.0 9'.76. ~0 508.0 1482.00 466,0 1461.98 1977,00 495.0 1976,75 24~,00 500.0 2476.88 SU~UEY CALCULATIONS ~c~c RADIU~ OF CUF~TL~ I'E'I'HOD~ TARG~ STATIDII AZtI~ITH LATIT1JI)£ S~'TIL1N INCH, K/-S ft d~ deg ft 0,00 0,00 0.00 0.00 -0.04 0.20 63,50 0,72 -3,35 0,70 125,50 0.44 -7,96 0.60 54,10 0.45 -11.20 1,30 49,80 5.~ 2980.00 503,0 2979.75 343~,00 458,0 3437.67 3&~.O0 197.0 3634,~ 3824,00 187,0 3823.48 4200.00 376.0 4194,22 -21,94 1,30 99.80 2,66. -29,97 0.80 152,70 -2.12 -31,94 0,40 95,70 -3,23 -29.06 4.10 2.79.60 !,55 29,2~ 14.20 294.50 19,11 4389,00 189,0 4374,~ 4606,~ 217,0 4~9,09 47'-70. O0 184,0 4751,94 5010,00 220.0 4954.21 5197,00 187,0 5120,97 84,12 19.60 299,20 43,91 1~7.78 20.10 296,20 78.16 220.83 20.00 297,90 I06,85 307.08 26.20 297,~0 147,15 391.52 27,60 293.40 183,69 b'D08.00 311.0 5395 5824,00 316,0 6138,00 3!4.0 5955,12 6507.00 369.0 6282,13 6818.1:X) 311.0 655'5.05 536.14 28,~ 291,~ Z39.38 ./G2,38 27.20 295,70 298.29 82~,33 27,00 ~8,50 363.45 f~,98 28,20 293,20 437,96 1144,56 29.10 295,00 498.84 7134.00 316,0 6832,75 7391.00 257,0 7061.83 76~,00 302,0 7331 8006.00 313,0 7609.24 8318,00 312,0 7883,82 12~,21 27,?0 298,50 566,70 141i ,66 26,00 300,80 624,31 1546,61 27,20 304,00 696,76 1691,37 28,00 900.20 773.80 183~,49 28.70 300.00 848.10 8904,00 ':331,0; "83?2,55 9122,00 218,0 8580,68 9'240,00 !18,0 8682,45 1964,26 29, .c,'O 3(X),~' 910,47 2130,21 30,30 300,~ 794,12 2240,34 30,40 296,80 1046,~ 2300,02 30.40 296.80 1073.84 9240' I0 A PRO,.T~ SLIW~ AT TI) D~A~TU~ DISF'LACE~ at AZI.~tFTH £/-W 0,00 0.~ 0,00 0.4~ 0,85 31.~ 4.07 4,09 9.34 9,~ 87,21 15.87 16,8! 70.~ U. eg/ 0.04 0,13 0,15 0.14 26.53 26,67 84,27 0,22 33.06 33,13 '~,$7 0.23 ~.70 34,85 95,33 0.~ 34,05 34,08 87.~ 2,36 -22,8,6 29.79 D??,~ 2.74 -71.84 84.20 3Gi,43 2,94 -137.08 i57,79 299.69 0,52 -193.26 ~:~0.63 ~8,94 0,32 -269.53 307.08 2?8,63 2.82 -345,81 391.~ 297.96 1.30 -480,26 536,61 296,49 0.33 -614.78 683.32 29~J.88 0.68 -742,10 826,32 ~6.09 0.41 -895,8~ ~7.21 296,05 0.74 -1032.00 1146,24 2?5,60 0.40 -1166.62 1296.98 295.91 -1267,83 1413.21 29'6.22 -1381.99 1547.70 296,7~ -1504,81 1692.11 297,21 -1632,~ 1~0.09 297,45 -1741.06 1964,76 297,6i -1884.45 2130,59 -198i,10 2240,72 297,85 -2034,40 2~00,42 297,8,3 0,65 0.84 0,62 0,62 O. 23 0,47 0,I4 P~ ~o [~I'Q>i~I,~Y ~ ~ I~, LOCATI~ 1 PRI.O)HO£ I,O~.J~TI~ 2 05-~W~R-~ I'W~"I,[~'TIC D~T,I,I~T!~ ~,,"5 F'~E NO, 2 MI1 ~ I~_CI~ C~MINC_C~ I_RATE A~_C~ C'~,..~_CHG I~J~N_FJATE ft ft ~eg ~eg de~,'lOOft deg ~eg ~eg/lOO~t ft de~ U~.o./!O~ft 468,0 48~,00 0.00 0.00 0.00 O.DO 0.00 0.00 O.~J 0,00 0,00 0,00 ~6.0 996°00 0.20 0,20 0,04 63,50 63,~ 12,50 -0,85 0,00 0,04 O,Oi 1482,0 1481,98 0.50 0,70 0,I0 62,00 I~.50 12.76 -2.35 78.00 0,13 0,02 1977.0 1976.95 -0,I0 0,60 -0,02 -71.40 54.10 -14,42 -4,91 13!.77 0.15 0.00 2477,0 2476,86 0,70 1,30 0.14 -4,3.0 49.60 -0,86 2'760.0 2979.75 0.00 1.30 0,00 50.00 99.80 9.94 -15.16 114.96 0.22 0.02 3438.0 3437.67 -0.50 0,00 -0.11 52.30 152.70 11,55 -14.12 141.99 0.23 0.~ ~JS,0 ~.34.66 -0.40 0.40 -0.20 -57.00 ?5.70 -28.93 -13,94 150,03 0.34 0.06 ~24,0 3823.48 3.70 4.10 1.96 184.10 279.80 97,41 -17.81 175.91 2.~ !.08 4200.0 4194.22 10,I0 14,20 2.69 14,70 294,50 3.71 -12.54 6.38 2.74 O.W 4389.0 4374.95' 5,40 19,60 2.86 4,70 299,20 2,49 -3.72 16.46 2.94 0.I1 4606,0 457~.09 0.50 20,10 0,23 -3,00 296.20 -1,38 -2.18 65,26 0,52 1.12 4790,0 4~1,94 -0,10 20,00 -0.05 1,70 297,90 0.92 -0,14 100,55 0,32 0.11 5010.0 4954.21 6,20 26.20 2.82 -0,10 297.~ -0,05 1,44 0.31 2.~2 1.!4 5197.0 5120,97 1,40 27,60 0,75 -4,40 293.40 -2.~ -5.69 20.40 t.30 0.61 5508,0 53:/5,82 0,60 28.20 0,19 -1,00 291.60 -0,58 22.53 55,31 0.33 0,3i 5824,0 5675.60 -I.00 27,20 -0.32 4.10 2$5.70 1.30 ~,97 119.49 0,68 0.11 6138.0 5955.i2 -0.20 27.00 -0,06 2.60 29B,.50 0,89 40,46. 100,16 0.41 0.~ 6507.0 6282,13 1,20 28,20 0,3'.3 -5.30 293,20 -1,44 49,55 ~.,32 0.74 0.09 6818,0 6555,05 0.90 29,10 0,29 1.80 295.00 0,58 6,31 56.85 0.40 0.11 7134.0 6832,75 -1,20 27,90 -0,38 3.50 298,50 1.I1 67,68 127,23 0,65 7.35'1.07061,83 -1,90 26,00 -0,74 2,~ 300,80 0,8~ 66,16 152.28 0.64 0.07 7693,0 7331.86 1,20 27,20 0,40 3.20 304.00 1,06 57,91 51.49 0.62 0.07 8006.0 7609,24 O.(K.. 28.00 0,26 -3.80 '300,20 -1,21 49.81 67,25 0.62 0.00 8316.0 7883.82 0,70 28.70 0,22 -0,20 300.00 -0,06 62.03 44.57 0.23 0.13 8573.0 8106.19 1.20 29,~0 0,47 0,00 300,00 O,OO 44,32 0.00 0.47 0,10 8904.0 6392.55 0,40 30,30 0,12 0,50 30~,50 0,15 40.41 32.18 0.14 0.t0 91~.0 8580,68 0,10 30,40 0.05 -3,70 296.80 -1,70 40,89 8.8.53 O.&6 0.33 92~,0 8662.45 0,00 30,40 0,00 0,00 296.~0 0,00 43,08 90.~j 0,~ 0.73 PERMIT # ~ _ .~o WELL NAME ........ . .. COMPLETION DATE J- I $ ~ i.~ e~u."" ~.O,~q'AC" ' · ~', I '" ~OGCC GEOLOGiCAL'MAtERIALS INVENTORY LIS:I' ....... [ check off or list data as it is received "4'07' '! d'/~'~/~'e dril,lin~! histo'ry../' Survey ,, cored ir~terv~ls cor,,c,,,an ,a, lysis ,,,dry ditch intervals digital data _ ................................. ~,'~,~' , , , ..... LOG TYPE "' RUN INTERVALS SCALE NO. .... i) .................... " ' , ' ' ..... , ., / , ,, '.'... ....cE~ ,,, - ~.~. i'~} ....... ... 12] .......... , ,, ..... ..... ..... ..... , , ,, , ,, ARCO ALA~KA, INC. F'.O. BOX ic':)0S60 ANCHORAGE, ALA~'KA 995i0 DATE ' 6/i 2/90 REFERENCE' ARCO CASED HOLE FINALS t -9 6-6-90 COLLAR 2-:3 6-6-90 COMP. NEUTRON G/R 2-t0 6-6-90 CONF'. NEUI'RON G/R 2- ~ :3 6-9-90 COLLAR °-"~S 6-8-90 COLLAR 3-20 6-7-90 COMP. NEUI'RON G/R 3-22 6-7-98 COMF'. NEUTRON G/R 4-t6 6-7-98 COMP. NEU'FRON G/R 4-23 6-8-90 CC)MF'~ NEUTRON G/R 4-24 6-8-90 COMP. NEUTRON G/R ~-6 6-i0-90 COMP. NEUI'RON G/R 7-9 6-9-90 COMP, NEUTRON G/R 7-9 6-9-90 DIFF. TEMPFRATURE 7-34 6-9-90 COMP. NEUTRON G/R ~ 2-~ 8 6-4-90 CET ~ 2-t 8 6-4-90 CBT t6-22 5-29-9~ CBT t 6-.~. 5-29-90 G/R ~ 6-22 5-29-9~ CET WGI-5 6-3-90 PERF RECORD WGI-6 5-:30-9~ PERF RECORD WGI-? 6-~ -90 PERF RECORD WGI-8 6-2-90 F'ERF RECORD RUN I , 5' RUN t , 5' RUN t, 5' RUN t, 5' RUN t, 5 ' RUN t, 5" RUN t , 5' RUN t, 5' RUN i , 5' RUN t , 5' RUN ~ , 5' RUN I , 5' RUN ~ , 5' RUN ~, 5' RUN ~ , 5' RUN ~ , 5' RUN ~ , 5' RUN ~ , 2' RUN ~ 5 ' RUN t , 5' RUN ~, 5' RUN ~ ~ 5' RUN ~, 5' A'FLA~ ATLAS ATLAS' Ai'LA~,~ A'FLA~~ AI'I_A~ A'fLA~,~ ATLA~ ATLA&~ ATI_A$ ATL, A&~ AI'I_A&~ ATLA$ ATLA~ $CH &'CH ~CH ~CH ~CH ,~CH ~CH SCH PLEASE SIGN AND RETURN THE RECEIVED BY __ -lnT~--1-~-~ ~ ~U~ ---- '- - HAVE A NICE DAY~ ~ALLY HOFFECKER ATO-t 529 COPY AS RECEIPT OF DATA. TRAN$~ 90218 DISTRIBUTION CENTRAL FILE~ CHEVRON EXTENSION EXPLORATION EXXON MARATHON MOBIL " F'HILL. IF'£ '1I' PB WELL FILES R & D ,.II. ~ BF'X STATE OF ALASKA TEXACO · ~,.ASKA OIL AND GAS CONSERVATION COrv~MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown,~ Stimulate Alter casing __ Repair well Pull tubing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 728' FNL, 1109' FEL, Sec. 11, T11N, R14E, UM At top of productive interval 172' FSL, 1959' FEL, Sec. 2, T11N, R14E, UM At effective depth 278' FSL, 2132' FWL, Sec. 2, T11N, R14E, UM At total depth 291' FSL, 2108' FWL, Sec. 2, T11N, R14E, UM Plugging m Perforate Other~--~ 6. Datum elevation (DF or KB) 60' RKB 7. Unit or Property name Prudhoe Bay Unit f~t 8. Well number WG~-6 9. Permit number/approval number 90-30/90-200 10. APl number 50-029-22021 11. Field/Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured true vertical 9240' 8685' feet Plugs (measured) feet EZSV set @ 9212' Effective depth: measured 921 2' true vertical 8661 ' feet Junk (measured) None feet Casing Length Size Conductor 8 0' 2 0" Surface 3453' 1 3 - 3/8" Intermediate Production 8 6 0 0' 9 - 5 / 8" Liner 905' 7" Perforation depth: measured None true vertical N o n e Cemented Measured depth True vertical depth 2150# Poleset 1 19' 1 19' 2200 sx AS III & 3491' 3491' 650 sx Class G - Top job w/170 sx AS I 485 sx Class G 8635' 81 63' 325 sx Class G 8335'-9240' 7901 '-8685' RECEIVED Tubing (size, grade, and measured depth) 7" / 4-1/2", L-80 tbg W/ tail @ 8363' Packers and SSSV (type and measured depth) Camco 'BaI-O' sssv @ 2156', & Baker 'FB-I' pkr @ 8298' 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) JUN - 6 1990 Alaska 0il & Gas Cons. Commission ~choraoa Treatment description including volumes used and final pressure 14. N/A Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation 15. Attachments *Completion Well History Copies of Logs and Surveys run X Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Gas In!e(;;tor 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-4040~{ev 05/17/89 Title Drilling] Analyst Date ~'-.~/- SUBMIT IN DUPLICATE Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Reporl" on the first Wednesday after a well is spudded or workover operatlonl are starled. Dally work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. [ oounty. p. ri.~ or ~9, s~oPE Lea,e or un. ADL: 28302 Title COMP LETE IStete AK PRUDHOE BAY IWell no. WGI-6 AUth. or W.O. noAS2025 API: 50-029-22021 Operator ARCO Spudded or W.O. be~n ACCEPT Dste and depth as of 8:00 a.m. 05/07/90 ( TD: 0' PB: 0 SUPV:LP 05/08/90 ( TD: 0 PB: 0 SUPV:LP 05/09/90 ( TD: 0 PB: 0 SUPV:LP IDate 05/06/90 IH°ur 2000 HRS IARCO W,I. 21. 0000 Prior status if a W.O. Complete record for each day reported NABORS 2ES .9) RU TO TEST BOPE 7"@ 9240' MW: 9.3 NeC1 0800 TO 2000 MOVE RIG F/DS 14-17 TO WGI-6. ACCEPT RIG 2000 HRS 5/6/90. CUT AND SPREAD HERCULITE IN CELLAR AREA, TAKE ON SEAWATER. CHECK WELL FOR PRESSURE. ND DRY HOLE TREE AND REMOVE FROM CELLAR. NU STACK. CHANGE RAMS TO 7". INSPECT BLIND RAMS. PULL BPV, BOLDS, PULL DUMMY HANGER TO FLOOR. INSTALL TEST PLUG. RU TO TEST BOPE. DAILY:S63,790 CUM:$1,939,971 ETD:S1,939,971 EFC:$2,775,000 RUNNING 7" COMPLETION STRING 7"@ 9240' MW: 9.3 NeC1 TEST PLUG LEAKING. PULLED AND REPLACED SEAL. STILL LEAKING. C/O TEST PLUG. STILL LEAKING. PU 700' OF 3-1/2" DP AND RIH. HANG DP BELOW TEST PLUG. TEST BLIND RAMS AND CHOKE. INSTALL JOINT OF 7" CASING. TEST ANNULAR AND PIPE RAMS. RD TEST TOOLS. CLEARED FLOOR. CIRC OUT DIESEL CAP W/9.3PPG BRINE. POOH AND STAND BACK DP IN DERRICK. INSTALL WEAR BUSHING. RU ATLAS WL AND TEST LUBRICATOR TO 1000 PSI. OK. RUN 8.5" GR/JB/CCL TO TOL @ 8325 WLM. CORRELATE TO CBT LOG DATED 27MAR90. LD LOGGING TOOLS. RU CSG EQUIP. MU AND RIH W/4-1/2",L-80 TAIL ASS'Y. MU BAKER WL SETTING TOOL AND 9-5/8" BAKER FB-1 PACKER. RIH AND SET PACKER AT 8286. POOH AND LD SETTING TOOL. RD ATLAS. PULL WEAR BUSHING. PU AND MU BAKER LOCATOR SEAL ASS'Y. RIH W/7" COMPLETION ASSEMBLY. 7", 26#, L-80, IPC, LTC-MOD TUBING. DAILY:S37,506 CUM:$1,977,477 ETD:S1,977,477 EFC:$2,775,000 RIG DOWN RIG 7"@ 9240' MW: 8.5 FSW CONTINUE RUNNING 7" COMPLETION ASS'Y. STING INTO PACKER TO VERIFY SEALS. OK. MU HANGER AND SPACE OUT. DISPLACE WELLBORE W/INHIBITED BRINE. FREEZE PROTECT TOP 2200' W/DIESEL. LAND TBG. ATTEMPT TEST TBG. XO'S ABOVE LANDING JOINT LEAKING AT 2200 PSI. TEST ANNULUS. OK. ND STACK. NU TREE AND TEST TREE AND PACKOFF TO 5000 PSI. OK. TEST TBG TO 4000 PSI F/15 MIN. OK. SHEARED OUT SOS. BLEED PRESSURE OFF ANNULUS AND TBG. SECURE WELL. BEGIN RIG DOWN. NOTE: WILL MOVE TO WGI-7 AND RETEST WGI-6 WITH TRIPLEX PUMP SO STATE CAN WITNESS. DAILY:S310,260 CUM:$2,287,737 ETD:S2,287,737 EFC:$2,775,000 The above is correct ~ For form'~preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Title Dr!!!!.r!..n Supt AR3B-459-1-D INumberall prepared for each well. I as they are dally well history forms consecutively Page no. /- ~O Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well ia Plugged, Abandoned or Sold. "Final Report" should be submitted also when oPerations are suspended for an indefinite or appreciable length of t me. On workovera when an official test is not required upon completion, report completion and representative test date in blocks provided· The "Final Report" form may be used for reporting the entire operation if apace is available. Accounting cost center code District ICounty or Parish State ARCO ALASKA INC. I NORTH SLOPE AK Field ~Leese or Unit PRUDHOE BAY I ADL: 28302 I Title CO~ LETE no. WGI-6 Auth. or W.O. no. AS2025 Operator J A.R.Co. W.I. ARCO J 21. 0000 Spudded or W.O. begun Date ACCEPT 05/06/90 Date and depth as of 8:00 a.m. 05/10/90 ( TD: 0 PB: 0 SUPV: RWO API: 50-029-22021 Complete record for each day repoded NABORS 2ES ~2) Iotal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our I Prior status if a W.O. I 2000 HRS 7"@ 9240' MW: 8.5 FSW RELEASED RIG AT 0600 HRS ON 5/9/90. STATE WITNESSED MIT TEST W/2350 PSI 5/9/90 AT 2030 HRS. NOTE: CAMCO 'BAL-O' SSSV @ 2156', BAKER 'FB-i' @ 8298', & TT @ 8363'. DAILY:S70,934 CUM:$2,358,671 ETD:S2,358,671 EFC:$2,775,000 RECEIVED JUN - 6 1990 Alaska 0il & Gas Cons. Commission Anchorage Old TD Released rig Classifications (oil, gas, etc.) Producing method Potential test data New TD I PB Depth Date IKind of rig Type completion (single, dual, etc.) Official reservoir name{s) Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on teat Gee per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct , rTitle For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Number all dally well history forms consecutively Page no. I aa they' are prepared for each well. J I AR3B-459-3-C DIvII~o(1 of AtlantlcRlchfleldCompany April 18, 1990 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: WGI-5,6,7, & 8 As-buiits Dear Mr, Chatterton: Enclosed are copies of the subject As-buiits for your information. If you have any questions, please call me at 263-4618. Sincerely, Engineering Aide DW cc: File W1-1 REC£1VED APR 2 z ]9~n ~i~ & C~a~ Cons. Commission Anchorag~ ARCO Naska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6OO1-A ! · 2e 3e 4e 6(3 7e THIS SURVEY ' f RECEIVED APR 2 VICINITY MAP NOT TO SCALE PRUDHOE BAY liN. LEGEND L OCA TED WITHIN PRO TRA~~ & Gas Cons. SECT/ON il, T. II N., R. 14 UMIA T MERIDIAN, ALASKA Anch°rag~e CONDUCTORS AS-BUILT THIS SURVEY WELL A.S.P. COORDINATES NORTHING EASTING 5,971,185, 66 6 5,971 ~ 535..79 5,971,ql8.97 5,971,302. ,Fl 685,12.5.51 685,153.47 PLANT COORDS. L~19 . 9 7 370.43 N 489.7'I W ~..9~ 369.90 '369.81 · EXISTING CONDUCTOR GEODETIC POSITION LAT. 70'19'34.551 70'!9'38.014' 70'19'36.858' LONG. 148'29 '53.494 NO TES h) BASIS OF'[.OCA TION PER NGI MON~T$ NI..C & NI-D. 2.) ALASKA STATE PLANE COORDINA T'CS ,ARE ZONE 4, k' 0.9999390. t 4~ ' 29 ' 54 . 20~ ! ELEV. CELLAR BOX '2!.5 L OCA T/ON IN SEC T/ON /OEO' F'I( I035' FEZ. 728' ~ I l Og ' FEZ. 845' ~ I085' FEL 963' FNL I0~' FEL SI,f~'~'Yi:~ ' S CERTIFICATE I HERE~Y C~rI'IFY I'N,T I ,~1 ~Y RE61~ AND LI~ ~ ~- TI~ ~ ~1~ IN ~ ~A~ ~ ~ ~ ~T ~lS ~T ~ ~ ~-~ILT ~ ~ ~ ~ ~ ~ ~ DI~ ~1S1~ ~ ~T ~ DI~I~ BASIS OF ELF. VA TION IS ARCO DA TUM (M.L.L.tflJ. REF. FIELD BOOK, 90-06 0 ISSUED FOR' ,~F'ORMA T/ON fDmmaeARCO Alaska, Inc. F.R. BELL & ASSOCIA T-CS CONDUCTOR A S-BUlL T VVGi PAD~ WELLS ~6~ 7 klAR RIrA l ~'°' "°' DS 17 NTS J eH'r. I t'$5. ~,~_ _ - -- I I1.1 I I II I I I Il Il Il . F:'., ()., B (3 X i 'S' (~ 3 6".'} A N F: I-.I F1R A q F A L. A c K A ,::;, o ,:< ................ ..-, _. i (:.:. RECEIVED ,. . t,4 y I 1.9,90 t.. r~ TE 5- i i -9(:} ~ Oil & aas Cons. Commission IREFERENC. E- ARCO CASED HOLE FIi'~.Al...,? Ar~chorage "; - i ;':; m' ... 7 - 9 ,q F' tit I A f;.: F;.'. [ I f.J i .=.::" ~ -..'~ I:.' ., .'% IL- .... ~ -' ..:.: ..... '"- 9 r:"' 1::' 1-- t;: I:' ~,I::' f" f'l I';' 'f) F.'.I N t , ,:c. ").,: .... .... i =~'.. .4-27 ....9,3 -r 'r:~ r:.., ..... , r'l.... ....... i'rl"r.:'c;": .. REE:Or.;.'.D I:;.:~ ...... ~i'~ i., ~'.." "'~- ~ "- "'/~'-~': I~;'] ~'~f]l... '~" ': ...." .." ................ R U N i .... · ") ~ ") C', ..", ") L ._ C;, ..: ..... :, ,-, 4 -- F:' Iii] F~: F' F.' F:' Fi Fi E' 'F', ,.~., ...................... R U N i ..... " · '" '" '-' A '.':; -- 6 o ;:-, C: C 1_ R LIN i , :~" ::L "- ..:' '..'-' ~ .....: .... :' ¥--i .'.5 4-28 .... 9,::} F'FC RUN i , '5" S-'-4 4-26-9,:~, K.T. NLEY BUTTON S'Ft.~ F.'.EC;ORD RUN i., ].'.'" 6 - 4 4 - :)-? - c;,,,:, F:' fi:: R F P ['i: r': ri R Ii, RLI N i =~" ..... · "" ......... .. I .-" 6 .... 9 4.-S0-9,:.} PERF RI~'.C:ORD RUN i., .~$" i i ..-->--~.,~. <. ..~q--,-t-~'r:;, . ... q'F.~.r.;i'iE'N. TED P, Fii'4i')/f];R'/FiFll F;.'.t li'J i , ~':" ,.: ................................. ;. i,1'-i7 S-i-9G VER'F.[!_O[; RUN t , 5" i l~-'-i ? 4-29--9;:') C.'OL. LAR/F:'ERF RUN' i , 5" WGI'-6 5-'?-9':) CCI. RUN i , S" ':' -" ¢' D ....... f I._E:~,.:.E SIGN AN RE:.TLJRN THE ATTAC'.HED COPY AS REF'.EIF'T OF DATA. RE-'. C EI'v'ED BY ..... ._~._~ HAVE: A NICE DAY! ,':,.." A I... I_ "r' HOFFECKER ATO- t '--~9 DISTRIBtJTION CENTRAl.. FILl-iS CHEVRON D & H EXTENSION EXF'LORATION EXXON MARATHON MOBIL F'FIZLLIF'S ? B W E L.. L F I L.. E,S' R & D BPX ,S'TATE or- ALASKA TEXACO ~RCO ALA~'KA, P, O. BOX ANCHORA£;E, ALA,?K A 995~ (~ DATE · 4- F~EFERENCE' ARCO C;A.S'ED HOLE FINAL.,S' ~-'5 3-"3 ~ -'9~ PERF' F~EC;ORD 2-9 ~-22"89 F'ERF RECORD 3-3 3-'3~-'9.0 PFRF DEPTH REC;ORD S-23 4-~ ""9~3 PERF RECORD 3-24 4'"4-9() PERF RE:CORD 4-5 tt'-J2-89 PERF RECORD 7'"'2 ~ ~ ()-3~""89 TEHP 9-29 4-7-'9~ COLI...AR/PEI~F ~2-~ ~'1-'~7-89 F'ERF RECORD F'WDWt -2 4-7'-9~) CBT PWDW'! _o ,,. 4-"'?-' 9~ CEI' W(; I -'6 3- 2'7'- 9 e CBT W C; I - 6 3 - 2 '7 - 9 e C E T PI_EASE .S"IGN AND RETLJRN THE ATTACHED COPY A.~ ,S'AL.L.Y FIC)F=FECK E£R ATO.-t 529 APR ! 8 1990 Alaska 011 & Gas Cons. Commission Anchorage DISTRIBUI'ION CENTRAL FILES .CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL RECEIPT OF RUN ~ , 5" RI. JN'i, 5" RIJN 'i, .5" RUN 2, RUN ~ , 5" RUN 'l ,5," RLJN t , 5" RtJN t , 5" RLJN t, 5" RUN ~ , ~' RUN RUN ~, 2'&5' RLJN ~ , 5' DATA F'HILL IF',S PB WELL. F']:L.E$ R & D BPX STATE OF' ALASKA TEXACO ,t.'.' C I..I I..IL,?¢ 3' C I..I ~(:;I..I ,S' C FI I..I I... ,'~,' I.-IL,S' A TI.. A,~'¢ I..IL,? $ C I..I $CI.-I $CI.-! SC'FI A R C'; CI AI...A~?K A , F',~ O, BOX ANCHC)F;:AC;E, AL..A~TKA 995~ 0 DATE · 4-~ ~ -90 RI!!iFEREiNC;E: ARC,(.. MAGNETIC 'T'AF'E($) WITH L.I~¢I'ING(,.?) · ,'. '°' ; '..' · °'" "~ ! 2'"'28 3-.-1'~ or.':', DT..L/E¢C,.,/D~"N F,'IlN t JOB:~37688.4 F-I..E.A,~E. EI(;N AND RETURN TI-lIE AI'TACHI:_'D COPY AS RECEIF"r OF' DATA. RECEIVED R I::. C'. E:. I V [il I) B Y .............................................................. I~IAVE A NICE DAY! APR 1 8 1990 ,S'; A L.. L. Y H C) F F E C K E R Alaska Oil & Gas C~s. Cemmisslon A T O .... t "';., ,; '~ -q~ Anchorage APPROVED 'T'RAN$'~ 9('7t HL. ,.? NI... ,S' F:'E I) I ~' 3"R I BUI' I ON CENTRAL FILES (CH) C. HEVRC)N TAHHA,.? BF,'OWN (OH) EXXON HARATHON HOBIL F'H I kl.. I F',S" F'B WELL F'IL.E;$ R & D BPX STATE OF ALASKA TEXACO ARCO AI...A,?KA, ]:NC F'~O, BOX i80360 ANCFIORAGIE, AL.A,?K A 99~ (') DATE· 4-~-98 RE. FE:.F,~E. NCE' ARCO (.)F'E'..N HOL..Eil FINALS' 2'-'28 3'"~ S .... 90 ]'VI) 2-28 3-~ 2"'9r3 comp, .~oni c ".~-."~ 3-"~ ~-..9(.) dj I. ~.. ~% ~.. ~.. 2-28 3- 2-.28 3-.~-9(.) x .... y cal. Jper 2 .... 28 3-~ S.--9~) gr 2....28 S-~4-.9() forma¢ion Ces't' wgJ-6 S/~S'-~5/9~) dgr/ewr wgJ-6 Zf/~3 .... ~/9(.) dgr/cnp/~fd wgi-6 3/~-~5/9~ ewr/dgr/cnp/.sfd RUN t , t'&2' F.IL.,S' RUN t, 2 "&5' HI_,.? RUN t , 2 "&5' I.'II...S' RtJN ~ , 2 "&5' HI...~Z RUN ~ , 2' HLS RUN ~ , 5' Hl....f; RLJN ~ , ~' HI_,S' RUN 1, 2'&5" nL ~pe RUN ~, 2'&5' nL .spe RUN ~, 2'&S'~vd n[ ~pe F'I...EA,.~E SIGN AND RE:TURN 'T'F.IE AI'I'ACHED COPY IV. ED .................................... HAVE A N ICE DAY ~ .qPR 1 8 1990 S A I... I.. Y H 0 F:' F:' EEC K E R ~laska Oil & A T 0- ~ 5 2 9 · ~cho~ge RECEIP'T OF' DATA, APF'ROVE:D ~ 'FRAN,?:[ 9et 40 D 15'TR I BUI' I ON " CENTRAL FILES '"' F'FIIL. I_ I F'$ · ..'"' CHEVRON F:'B WEL. L. FIL. E$ ~ D & H '~ F: & D " " r" ' '~ BF:'X · "'... EXI'FN ~' I ON,, E. XF LJRAI ION ~ '.~ EXXON .~ 3~'I'AI'E OF ALASKA ...'"' MARATHON ~ TEXACO ~~ MOBIL ARCO ALA~'KA, INC,. P, 0 ,. BOX 'i (.)..r',.S60 ANCI-IORA(;E, AI...A$:KA 99.5t 0 DATIF. · 4- t t -9(.) RFF:'ERIENCE ARC(.. DIF;,'EC'TIONAL DATA MWD DI "' .......... RI'_' L. t IONAI.. MWD DiREC"I"]:ONAL. S'URVEY ANA ANA PLEASE :~;iGN AND I;:ETURN THE A'I"TACHIF.:D ..,OF f A:g' RECEIF'T OF DATA DI~TRIBUTION CFNTRAL I""'I!_1:.,., C I"t E V R O N D & M ~' EXTENSION EXPL. ORATION '11' '"",-EXXON MARATHON MOBIL. F'HILLIF'3~ · ..'"' F:'B W E L L. F I L E ,S' ( 2.. C 0 F:' ]: E .? ) R & D "" BPX ,11· 3'TA'i"E (IF ALA,g'KA TEXACO ARCO ALA.?KA, P.O. BOX ANCHORAG[:, ALoA~'K A DATE · 4-4-9¢, REFERENCE · ARCO OPEN HOLE FINAL~ 5-27 t~./2S-St;'89 EWR/DGR RUN~' t-tt, '.2 "&5 ·l'¥D 5-27 t~/23-'3t/89 DGR/CNP/,~r.."D RUN,~ t-tt, 2"&5'TVD WGI-6 ~/i~--t4/9¢ GR RESISTIVITY RUN ?, 2'TVD WGI-6 ~/t¢-t4/98 GR RE~'IS'FIVITY RUN ?, 2' F'WDWi'-°~. 3_o6_o¢~ ,, CALIPER-GR RUN t, -o" PWDW~-~ S'-~ CALIF'ER-GR RUN ~, 5' PLEe~¢E SIGN AND RETURN THE ATTACHED COPY AS' RECEIPT OF DATA RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER ATO- t 529 RECEIVED APR - 6 1990 $~0_¢PPROVED .Alaska 0il & Gas Cons. Corem'ts R AN S:; 9e ~ 2 9 AnchOrage NI._ 5;F'E NL. ZF'E ANA AMA f,..' C H ZCI.-t DISTRIBUTION CENTRAL FILES ~ PHILLIPS CHEVRON F'B WELL FILES D & M ..- ~ R & D EXTENSION EXPLORATION ~ BF'X EXXON "~, STATE OF ALASKA MARATHON ~" TEXACO MOBIL A' O~, OIL AND GAS CONSERVATION COMI, SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon 2. Name of Operator _ Suspend _ Operation Shutdown ~ Re-enter suspended well _ Alter casing _ Time extension _ Stimulate _ Change approved program _ Variance _ Perforate _ Other_ 6. Datum elevation (DF or KB) Repair well _ Plugging _ Pull tubing_ 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service .~X ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 728' FNL, 1109' FEL, Sec. 11, T11N, R14E, UM At top of productive interval 300' FSL, 2240' FWL, Sec. 2, T11N, R14E, UM (approx) At effective depth 349' FSL, 2156' FWL, Sec. 2, T11N, R14E, UM (approx) At total depth 356' FSL, 2144' FWL, Sec. 2, T11N, R14E, UM (approx) 9240' feet 8682' feet 12. Present well condition summary Total Depth: measured true vertical Plugs (measured) RKB 6O' 7. Unit or Property name Prudhoe Bay Unit 8. Well number WGI-6 9. Permit number 90-90 10. APl number 50-029-22021 11. Field/Pool Prudhoe Bay Field Prudhoe Bay Oil Pool EZSV set @ 9212' Effective depth: measured true vertical 9212' 8658' feet Junk (measured) None feet Casing Length Conductor 8 O' Surface 3453' Intermediate Production 86 0 O' Liner 905' Perforation depth: measured Size 20" 13-3/8" 9-5/8" 7" None true vertical N o n e Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Cemented Measured depth True vertical depth 2150# Poleset 119' 119' 2200 sx AS III & 3491' 3491' 650 sx Class G - Top job w/170 sx AS I 485 sx Class G 8 6 3 5' 81 6 0' 325 sx Class G 8335'-9240'RECEi ~~682' APP, - ,C, !990 Oil & Gas Cons. Comm'~ssto~. Anchorage 13. Attachments Well Histo~ Description summary of proposal Detailed operation program_ BOP sketch 14. Estimated date for commencing operation April 20, 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Service Gas Injection Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~, ~~~/~/~/~ ? Title Drillincj Analyst FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ ,__;,BOP Test_ Location clearance ~ Mechanical Integrity Test'~' Subsequent form require blRIGINAL SIGNED 8Y L0[~NtE C. SI~11TH Approved by the order of the Commission Commissioner Form 10-~03 Rev 06/1 IApproval No. SUBMIT IN TRIPUCATE ARCO O. and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Rel~ert" on the first Wednesday after a well is spudded or wor~(over operations are started. Daily work prior to Sl:)udding should be summarized on the form giving inclusive dates only. API: 50-029-22021 Operator ARCO IARCO W.~. 21. 0 0 0 0 Spudded or W.O.,J~[~ IDate 03/02/90 IHour 20: 4 5 IPrior status if a W.O. Date and depth as of 8:00 a.m. 03/03/90 i TD: 568'( SUPV:MWW 03/04/90 ( TD: 2588'( SUPV:MWW 03/05/90 ( TD: 3510'( SUPV:MWW 03/06/90 ( TD: 3510'( SUPV:MWW 03/07/90 ( TD: 4080'( SUPV:MWW 03/08/90 ( TD: 5581'( SUPV:RJB 03/09/90 ( TD: 6326'( SUPV:RJB 03/~n.'90 ( TD: 7366'.( SUPV:RJB Complete record foD~l'r~(~jy ~,ported 2) 449) 3) 2020) 4) 922) 5) 0) 7) .501) 8) 745) 9) L040) POOH W/ BIT #1. 20"@ 119' MW: 8.9 VIS:300 MVOE RIG F/ WGI-5 TO WGI-6. ACCEPTED RIG AT 10:30 HRS, 3/2/90. NU AND TEST DIVERTER. PU BHA # 1. MIX SPUD MUD. SPUD WELL AT 20:45 HRS, 3/2/90. DRLD 17-1/2" HOLE F/ 119' TO 568'. DAILY:S76,038 CUM:$137,804 ETD:S150,000 EFC:$2,762,804 DRLG AT 2588' MW: 9.6 VIS:240 MU BHA#2 AND BIT %2, RIH DRILL FROM 568' TO 2588' DAILY:S58,894 CUM:$196,698 ETD:S150,000 EFC:$2,821,698 PREP TO CMT 13-3/8" CSG. MW: 9.6 VIS:240 DRILLED 17-1/2 "HOLE TO 3510', CBU, SHORT TRIP, CIRC, DROP SURVEY, POOH, RUN 13-3/8" CSG TO 3491'. PREP TO CMT AT REPORT TIME. DAILY:S229,826 CUM:$426,524 ETD:S500,000 EFC:$2,701,524 NU, PREP TO TEST BOPE. 13-3/8"@ 3491' MW: 9.7 VIS: 53 CEMENT 9-5/8" COG W/ 2200 SX AS III & 650 SX CLASS G. ND DIVERTER, DO TOP JOB, CMT W/ 170 SX AS I, LAND CSG, SET 13-3/8" HEAD, CLEAN MUD PITS, NU BOPE, PREP TO TEST. DAILY:S189,955 CUM:$616,479 ETD:S700,000 EFC:$2,691,479 RIH W/ NEW MWD. 13-3/8"@ 3491' MW: 9.1 VIS: 38 NU AND TEST BOPE, RIH W/ BHA #3, TEST CSG TO 2500 PSI, DRILL 10' OF NEW HOLE, CIRC AND COND MUD, PERFORM 13.7 PPG EMW LOT, DRLG F~ 3520' TO 4080', MWD FAILED, POOH, SWAP OUT MWD, RIH. DAILY:S63,335 CUM:$679,814 ETD:S750,000 EFC:$2,704,814 DRILLING AHEAD AT 5581'. 13-3/8"@ 3491' MW: 9.4 VIS: 41 RIH W/ BHA #4 TO 4040', REAM TO BTM 4080', NO FILL, DRLG AND SLIDE WHILE BULIDING ANGLE, DRLG TO 5581'. DAILY:S55,474 CUM:$735,288 ETD:S850,000 EFC:$2,660,288 RIH W/ BHA # 6 13-3/8"@ 3491' MW: 9.4 VIS: 47 DRLD TO 5767'. CBU. SURV. POOH. CHNG BHA. RIH TO 5767' DRLD W/ STEERABLE MOTOR TO 6326'. LOST 400 PSI. POOH WET. CHNG BHA. DAILY:S63,814 CUM:$799,102 ETD:S799,102 EFC:$2,775,000 DRLG AT 7366'. 13-3/8"@ 3491' MW: 9.6 VIS: 39 RIH TO 13-3/8" SHOE, CUT DRILL LINE, RIH TO BTM, NO FILL, DRILL FROM 6326' TO 7366'. DAILY:S60,417 CUM:$859,519 ETD:S1,000,000 EFC:$2,634,519 The above i ....... t ~ --'~ Signat#,re , ~%. \ %, ~,~~Da Fo orm ~ eparation a~d distribution, ~ ~ see Procedures Manual, Section 10 Dr rig. Pages 86 and 87. ~ ~ u,, & va~ Cons. C0mmissl0F: AR3B-459-1-D ~:~r~ch0rag~ J?,t,. Drilling SUlJL Number all daily well history forms consecutively as they ara prepared for each well. Page no. ARCO gl, ..,d Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show tormation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not tess frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District Field Date and depth as of 8:00 a,m. ARCO ALASKA INC. ICounty or Parish NORTH SLOPE I PRUDHOE BAY ILease or Unit WGI-6 I Complet ...... d f ..... h]~/(~;~ d~lling ..... k .... in prog .... 03/11/90 TD: 8147' SUPV:RJB 03/12/90 TD: 8650' SUPV:RJB 03/13/90 TD: 8650' SUPV:RJB 03/14/90 TD: 9189' SUPV:RJB 03/15/90 TD: 9240' SUPV:DBJ 03/16/90 TD: 9240' SUPV:DBJ 03/17/90 TD: 9240' SUPV:DBJ lo) 781) 11) 503) 12) 0) 13) 539) 14) 51) 15) 0) 16) 0) State AK IWoH no, DRLG 12.25" HOLE AT 8147' 13-3/8"@ 3491' MW: 9.9 VIS: 44 DRLG FROM 7366 TO 7462, CBU, DROP SURVEY, POH, CHANGE BIT, RIH, CUT DRLG LINE, DRLG FROM 7462' TO 8147' DAILY:S77,605 CUM:$937,124 ETD:S1,050,000 EFC:$2,662,124 RUNNING 9-5/8" CSG. 9-5/8"@ 8635' MW:10.0 VIS: 40 DRLG 12-1/4" HOLE FROM 8147 TO 8650', SHORT TRIP, CBU, DROP SURVEY, POOH, RET SURVEY, INSTALL 9-5/8" RAMS, BEGIN RUNNING 9-5/8" CSG. DAILY:S53,610 CUM:$990,734 ETD:S1,100,000 EFC:$2,665,734 P/U BHA #8 9-5/8"@ 8635' MW: 0.0 VIS: 0 RAN 9-5/8" 47 L-80 BTC-MOD CSG TO 8635'. CIRC. CMT'D W/ 485 SX CL G AT 15.8PPG DID NOT BUMP PLUG. FLOATS HELD. RAN PO. N/D DRLG SPOOL. N/U BOPE. TESTED BOPE. P/U BHA #8. DAILY:S427,365 CUM:$1,418,099 ETD:S1,418,099 EFC:$2,775,000 DRLG CLOSE TO TD. 9-5/8"@ 8635' MW: 9.2 VIS: 36 PU 8.5" BHA AND MWD, TEST CSG, DRLG FLOAT EQUIPMENT, TEST CSG, PERFORM PIT TO 12.5 PPG EMW, DRLG 10' OF NEW HOLE, PERFORM FIT TO 12.5 PPG EMW, DRILL 8.5" HOLE FROM 8660' TO 9189'. DAILY:S52,951 CUM:$1,471,050 ETD:S1,600,000 EFC:$2,646,050 RIH W/ 7" LINER. 7"@ 9240' MW: 9.3 VIS: 38 TD 8.5" HOLE AT 9240' MD, NO OH LOGS WILL BE RUN, MWD ONLY, SHORT TRIP, HIT BRIDGE, REAM TO BTM, CBU, COND MUD, SHORT TRIP, SPOT NUT PLUG, POOH, LD BHA , RUN 7" LINER ON DP, RIH W/ LINER AT REPORT TIME. DAILY:S121,269 CUM:$1,592,319 ETD:S1,800,000 EFC:$2,567,319 POOH W/ 8.5" BIT AND SCRAPER. 7"@ 9240' MW: 9.3 VIS: 44 RIH W/ 7" LNR F/8335'-9240', CMT W/325 SX CLASS G, FULL RETURNS, RELEASE F/ LINER, POOH, MU 8.5" BIT AND SCRAPER, CUT DRILL LINE, RIH, CBU, WASH AND REAM TO LINER TOP AT 8335', CBU, POOH. DAILY:S99,900 CUM:$1,692,219 ETD:S2,000,000 EFC:$2,467,219 POOH TO SET EZSV IN RAT HOLE. 7"@ 9240' MW: 9.3 VIS: 66 POOH, LD 8.5" BIT AND BHA, RIH W/ 6" BIT AND BHA, WASH/REAM F/ 8335' TO 9055', DRLG CMT F/ 9055' TO 9115', SLOW ROP, POOH, JUNK IN HOLE LOCKED UP BIT, RIH W/ 6" MILL AND BOOT BASKETS, MILL TO 9153' LC, TEST LINER/CSG TO 4000 PSI, OK, DRILL LC/FC AND 10', LINER WOULD NOT RETEST, CBU, POOH TO SET EZSV ON BOTTOM. DAILY:S89,944 CUM:$1,78~,163 ETD:S2,000,000 EFC:$2,557,163 The above is correct Signature % ~%'~ ~ %, For formpreparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 grilling Supt. AR3B-459-2-B Number all daily well hislory forms consecutively Page no as they are prepared for each well. ARCO 06 .... d Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlartm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ unfil completion, District Ai~.C O A ~.~S [,~..r NC. Icounty or Parish NO~.TH $.l.,OpE Jsta~e AK Field PR[.TD"OE BAY IL ...... Unit .G.T_6 IWell no. Complete record for eac~ q~illJng or workover in progress Date and depth as of 8:00 a.m. 03/18/90 TD: 9240' SUPV:DBJ 17) o) ND BOPE. 7"@ 9240' MW: 9.3 VIS: 0 POOH, LD BHA, RIH W/ EZSV ON DP, SET AT 9212', TEST LINER/CSG TO 4000 PSI, OK, CBU, DISPLACE HOLE TO BRINE, LDD? FROM DERRICK, PULL WEAR RING, INSTALL DUMMY HGR AND BPV, ND FLOWLINES, ND BOPE. DAILY:S73,393 CUM:$1,855,556 ETD:S2,100,000 EFC:$2,530,556 RECEIVED i\ i"): ') · - Ar~chorafe The above is correct For form~preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 J,,,,e Drilling Supt. AR3B-459-2-B Number all daily well history forms consecutively as they are prepared for each well. JPage no. ARCO O,, and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Rellett" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also whirl, operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, reporl completion end representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Auth. or W.O. no. AS2025 Operator ARCO Spudded or W.O. ~ I Accountlng cost center code District ARCO ALASKA ,NC IC°unty °r Parish NORTH SLOPE [state · AK Field PRUDHOE BAY IL ...... Unit ADL: 28302 I ~4e~ i~o_.6 Title DRILL A.R.Co. W.I. Date API: 50-029-22021 21.0000 03/02/90 Iotal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well I our 20: 45 IPrlor status if a W.O. 1 Date and depth as of 8:00 a.m. 03/19/90 TD: 9240' SUPV:DBJ Complete record fOb~t~y ~ported (18) ( 0) FINAL REPORT, RELEASE RIG. 7"@ 9240' MW: 9.3 VIS: 0 FINISH ND BOPE, N'U TBG SPOOL AND DH TREE, CLEAN AND INJECT PITS, FREEZE PROTECT WGI-6, RELEASE RIG AT 12:00 HRS ON 03/18/90. DAILY:S20,625 CUM:$1,876,181 ETD:S2,100,000 EFC:$2,551,181 RECE[VED Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3~C Number all daily well hislory forms consecutively as they are prepared for each well. iPage no. Division of AtlantlcRichfleldCompany February 28, 1990 Telecopy~ (907)276-7542 Mr. John Gillespte Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Prudhoe Bay Unit WGI-6 ARCO Alaska, Inc. Permit No. 90-30 Sur. Loc. 728'FNL, il09'FEL, Sec. 11, TllN, R14E, UM. Btmhole Loc. 364'FSL, 2120'F~L, Sec. 2, TllN, R14E, UM. Dear Mr. Giliespie: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional pe~its required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. %~ere a di.verter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ve~¥_?trul¥ you=s, C.'~. Chatterton Cha!~an o f Alaska Oil an4 Gas Conservation BY ORDER OF ~E COb~MISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASK; '"IL AND GAS CONSERVATION ( ~MISSlON PERMIT TO DRILL 20 AAC 25.005 ~t Gas Injection Well la. Type of work Drill ~' Redrill --I lb. Type of well. Exploratory ~ Stratigraphic Test ~ Development Oil '~ Re-Entry - DeepenGI Service ~ Developement Gas - Single Zone ~ Multiple Zone L-., 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 728'FNL, ll09'FEL, Sec.ll, TllN, R14E, UM At top of productive interval 300'FSL, 2240'FWL, Sec. 2, TllN, R14E, UM At total depth 364'FSL, 2120'FWL, Sec. 2, TllN, R14E, UM 12. Distance to nearest property line 2119' feet 13. Distance to nearest well WGI-4 @ 3000'MD/TVD min = 104 ' feet 16. To be completed for deviated wells 29 o 1 Kickoff depth 3800 feet Maximum hole angle 0 5. Datum Elevation (DF or KB) Pad 19' RKB 58 feet 6. Property Designation 7. Unit or property Name Prudhoe Bay Unit 8. Well number WGI-6 9. Approximate spud date 03/02/90 14. Number of acres in property 2560 10. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool 11. ~pe Bond(see20A^c25.025) Statewide Number No. U-630610 Amount $200,000 15. Proposed depth,MSandTV~, 9228'MD 8663'TVD feet 17. Anticipated pressure (see 20 AAC 25.035 fe)t2)l Maximum surface 2 817 psig At total depth ¢YVD) 8 4 5 2 ' Ps~G Quantity of cement (include stage data) 18. Casing program size Hole 30" 17-1/2' 12-1/~t Casing 20" 13 -3/8' 8-1/2" 7" Weight 91.5# 68~ L ,~7~ 29# Specifications GradelCoupling H-401 Weld -8o/K155 BTC L-80~BTC/MOd L-80[ BTC l~ngth 80' 3462' 8625' 866' Setting Depth Top Bottom ! TW ! I TVD 119' 3500' 8168' 8663' 2000# Poleset 000 sx CS III&600 sx CL ( 1000 sx G 300 sx ~a~ex ~ ..... 19. To be completed for Redri I, Re-entry, and Deepen O2erations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented measured true vertical Measured depth True Vertical depth 20. Attachments Filing fee [] Property plat [] BOP Sketch ~. Diverter Sketch ~-' Drilling program ,~ Drilling fluid program G Time vs depth plot ~ Refraction analysis [] Seabed report ,% 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,.2,.,. Title Regional Drilling Engineer Date Commission Use Only (JPS) PD3/106/~ / / Permit Num r I APl number I Approval date I See cover letter '' ~,¢>--D-~K2) J 50--oZ~-. ~--F_-o2_/J 02/28/90 J for other requirements ConSitions of approval Samples require, d ~ Yes ~ No Mud Icg required Q Yes ~No Hydrogen sulfide.measures Fi,,y.~e-h~i~'No Directi6nal survey required ~ Yes ~ No Required Working~sure~for/SrOPE/ .~M; ~,~ 31Vi; ,~ 5M; [] 10M; [] 15M Other: / 1/3//1 .I il // -//'~ /~ ~ i/'~ /~,~,,, Approved by Commissioner the commission Date Sub~it in 't'riplicaie? Form 10-401 Re~--1-85 / / PRUDHOE BAY DS WGI-6 (GAS INJECTION WELL) PRELIMINARY DRILLING PROCEDURE 1. MIRU drilling rig. NU diverter and function test same. 2. Drill 17-.1/2" vertical hole to 3500' TVD/MD. . Set 13-3/8" casing and cement same. Nipple up BOPE and test to 5000 psi. TeSt casing to 2500 psi for 30 minutes. 4. Pick up 12-1/4" BHA and RIH. Drill 10 ft of new hole and perform leakoff test. . Drill 12-1/4" vertical hole to 3800' TVD / MD and begin kick-off. Build .angle at 2 o per 100' until angle is 29 o 10' in a N 61 o 58' W direction at 5196' TVD/5259' MD end of curvature. o Drill to the 9-5/8" casing point at 8168' TVD / 8662' MD while maintaining angle at 29 o 10' in a N 61 o 58'W direction. 7. Set 9-5/8" casing and cement same. 8. Pick up 8-1/2" BHA and RIH. Test casing to 4000 psi. 9. Drill 10 ft of new hole and perform EMW test. 10, · 11. 12. 13. 14. Drill 8-1/2" hole while maintaining angle at 29 o 10' in a N 61 o 58' W direction to the well TD of 8663' TVD / 9228' MD with 2297' departure ( 100' target radius is needed to avoid faults in the area). Set 7" liner and cement same. Clean out the 7" liner and 9 5/8" casing and test liner / casing to 4000 psi for 30 minutes. Circulate well to brine and freeze protect with diesel. Release drilling rig. Run cased hole logs 7 days after rig release. MI and RU completion rig. Run 7" tubing and packer assembly. NU 7" tree and test to 5000 psi. Notify AOGCC at least 24 hrs in advance to witness Mechanical Integrity Test on casing as per requirements for Class II gas injection well. Test tubing and casing to 4000 psi. Release completion rig. 15. Rig up wireline unit and perforate. RECEIVED FEB 2 6 19~)0 Anchorag~ NOTE; PRUDHr'''' BAY DS WGI-6 ( GAS INJE6=~ON WELL ) PREL,~IINARY DRILLING PROCEDUt... CONT. ao Excess non-hazardous fluids developed from the well operations and as necessary to control the reserve pit fluid level will be pumped down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended period. The annulus will be sealed with 300 sx of cement followed by Arctic Pack. b. There is one well within 200 ft. of the proposed well. WGI-4 crosses within 103' at a depth from surface to 3000' TVD/MD. c. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.033. d. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/fi). e. Based on previous logs, no potential productive zones are anticipated above 3500' TVD. f. No potential hazardous levels of H2S are anticipated in this well. SOLIDS CONTROL EQUIPMENT Shale shaker Mud cleaner Centrifuge Trip tank Degasser Pit level indicators (visual and audio) Fluid flow sensor Fluid Agitators ProDS WGI-6 ( GAS INJECTION,~LL ) MUD PROGRAM DEPTH DENSITY VIS YP INT 10MIN FL OIL SOLIDS MUD (TVD) (PPG) GELS GELS CC/30MIN (%) (%) TYPE SPUD 8.8 300 70 30+ 50+ 25 0 2 GEL-BENEX to to to to to SPUD MUD 13-3/8 9.2 100 40 6 csg pt. SET 13-3/8" CASING DEPTH DENSITY PV YP INT t0 min FL OIL SOLIDS MUD (TVD) (PPG) (CP) (#/ft GEL GEL cc/30min (%) (%) TYPE 13-3/8" 9 10 6 2 4 25 0 2 LIGHTLY to to to to to to to to to TREATED K-10 9.7 15 10 4 10 10 6 POLYMER K-10 9.8 10 6 2 4 10 2 4 LIGHTLY to to to to to to to to to TREATED 9-5/8" 10 15 10 4 10 6 5 9 POLYMER SET 9-5/8" CASING DEPTH DENSITY PV YP INT 10min FL OIL SOLIDS MUD (TVD) (PG) (CP) (#/ft) GEL GEL cc/30min (%) (%) TYPE 9-5/8" 8.7 10 6 2 8 8 2 4 LIGHTLY to to to to to to to to to TREATED 7" Liner 9.1 15 10 4 10 6 5 6 POLYMER SET 7" LINER . THIS MUD PROGRAM IS ONLY A GUIDELINE. ACTUAL HOLE CONDITIONS WILL DICTATE THE ACTUAL MUD PROPERTIES. ANY MAJOR CHANGES SHOULD BE DISCUSSED WITH THE ARCO ANCHORAGE OFFICE. ) RKB ELEVATION 58' 20" Casing TVD=] 19 TMD=ll9 =0 : AR{ 20 ALASKA, II'lC. wgi-{3 ~'/'~ I T 1'~. ~ooo o,..,--,-,~.,. I - I000' SHL: U 1 tN 14E 11 728' FNL 1109' FEL THL: U 1 IN 14E 2 300' FSL 2240' FWL BHL: U 11N 14E 2 364' FSL 2120' FWL N 61 58' 2000 3000 13-3/8" Casing TV )=3500 TMD=3500 D]:.P=0 KOP TVD=3800 2.0 4000 4,0 6.0 10.0 ~tzo }1 v~.o TVD=4500 TMD=4506 DEP=86 I~ ~s.o ~2o. oK-15 TVD=-4793 TMD--4803 DEP=I'~3 ~ 24.o 5000 · ,=5196 TMD=5259 DE ~=363 6000' AVER~ ~GE ANGLE = 29 10' '7000 K-i0 TV~=?058 ¥MD=7390 D ~=i402 ~ TVD=?558 TMD=?9~3 DEP=1681 8000 PUT R. TVD=8102 TMD=8587 DEP=198~ A LCU TVD=gl0g '1'MD=§593 DEP=19§g 9-5/8" CASING T~D=8168 TMD=8662 I~EP=2022 G R. TVD=81~8 TMD=8673 DEP=20 UBLIK TVD=8225 TMD=8?30 DEP: :2055 P SADLERO(tHIT TVD=8263 TMI~8??0 DEP=20?5 RGET TVI)=~63 TMD=9000 COC TVD~§633 TMD---9t94 DEP:~2280 9000 BASE SAD~EROCHIT TVD=8663JTMD=9228 DEP=229~ TD TVD=8~563 TMD=9225 DEP=~297 10000 0 1000 2000 3000 4000 5000 6000 '7000 VERTICAL SECTION ARCO ALASKA, INC. wgi-6 N 61 58' W -5000 4000 ~1000 < © rO 0- -1000- -2000- -3000- -5000 -1000 -2000 -4000 3OO0 -4000 -3000 -2000 -1000 0 1000 2000 ~ , i i i i i ii i i i i i i r · i I i i i i i i i i r i I r r I i I I i r r i i i i I r i i I i r i I I i i i i Ii i i i i i i i ti WGI-0 l 8333 / 7557 8016 / 7231 . 7587 / 6812 WGI-()4 8,~7 7151 80 N767 V279 ~~915 ~ 5854 (~5 5830 ~5316 ~ 4978~ 9000 wgi-5 9855 10168 1~57 ........ ] ...................... ~ ............ i .... -3000 E - W COORDINATES -2000 - 1000 1000 2OO0 '-3000 3000 DOYON 9 MUD SYSTEM 32 BBLS 32 BBLS TRIP TANKS I [ D~..GASSF-,R J (30 BBLS) (83BBLS) I I (97 BBLS) (97 BBLS) PIT.T. PIT (36 BBLS) (36 BBLS) SHAKER DESANDER SHA~.R MIX PIT SUCTION PIT (448 BBLS) (122 BBLS) OTHER EQUIPTb~D~f - DRI?.TJING FLUID SYSTEM (3) DERRICK FLO-LINE CT.~.~NER (1) PVT SENSOR PER PIT w/ visual and audio warning devices (1) AGITATOR PER PIT (1) DRIT.T. ING FLOW SHOW SENSOR w/ readout convenient to the driller's console 13-5/8" o000 psi BOP STA K DIAGRAM I PIPE RA BUND SPOOL C ASING SPOOL PIPE RA 7-] BRADEN HEAD ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVIOR TO THE PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT THE ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH THE CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRES- SURE. 195/8" STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING FLUID. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACTED. MARK THE RUNNING JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN THE TEST PLUG ON DRILL PIPE AND SEAT IN WELL- HEAD. 3. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. 4. FUNCTION TEST CHOKES. 5. IN EACH TEST, FIRST HOLD 250 PSI FOR 3 MINUTES PRIOR TO THE HIGH PPRERSSURE TEST. 6. INCREASE PRESSURE ON ANNULAR TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 7. OPEN ANNULAR PREVENTER AND CLOSE TOP PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 8. CLOSE VALVES DIRECTLY UPSTREAM OF THE CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 9. OPEN TOP SET OF PIPE RAMS. CLOSE BO'II-OM PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 10. TEST REMAINING MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF THE VALVE AND ZERO PRESSURE DOWNSTREAM. 11. BLEED PRESSURE TO ZERO. OPEN BOTTOM PIPE RAMS. 12. BACK OFF RUNNING JOINT AND POH. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 3 MINUTES. 13. BLEED OFF ALL PRESSURE. OPEN BLIND RAMS. FILL MANIFOLD AND LINES WITH NON-FREEZING FLUID. SET ALL VALVES IN THE DRILLING POSITION. 14. TEST STANDPIPE VALVES TO 5000 PSI. 15. CHECK DEGASSER OPERATION. 16. RECORD BOP TEST INFORMATION ON THE BOP TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 17. PERFORM COMPLETE BOP TEST WEEKLY AND FUNCTION TEST DAILY. SURFACE HOLE DIVERTER SYSTEM SCHEMATIC ARCO ALASKA, INC. FILL-UP LINE ! RISER IFLOWLINE I I 2000 PSI DIVERTER 10" LVE I I i ICONDUCTOR NOTE' ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL .REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS A VARIANCE FROM 20AAC25.035 10" VENT LINES I WELL O : O ~m NOTE: 100' FROM ANY IGNITION SOURCE ALL TURNS 90 DEGREE TARGET TEES RESERVE PIT JG 7/27/87 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE ~ (1) Fee 1. (2) Loc /~_;~ 8C/__Z_Z~~). '' ' (~ thru C8) (3) Admin ~ Z/~_?~f~ 9. ' ('9 thru~ 10. ~~ ~-~2-~ 11. (10 and 13) 12. 13. (4) .Casg ~~. (14 thru 22) (23 thru 28) Company Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. 3. Is we]] located proper distance from property line .................. 4. Is we~ located proper distance from other wells .................... 5. Is suz~icient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Lease&YES Well No.NO ~'~ ~ ~ ~;~ ~cZ:) f~ARK~ ~ ~2~-'~ 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ ~ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ...................... ~ 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 ......... , ........... ,~ Will all casing give adequate safety in collapse, tension and burst.. ,~ Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... ~ Is the drilling fluid program schematic and list of equipment adequate ~ Are necessary diagrams and descriptions of diverter and BOPE attached. ~ Does BOPE have sufficient pressure rating - Test to ~~ psig .. ,,~ Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. ~ (6) OTHER/.(/~2_~9 thru 3'1)' (6) Add: '~-'~'m ~-~7-~p Geology: Engi. neering: rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks O Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX.. No special'effort has been made to chronologically organize this category of information. .. (NOTE: ** REEL HEADER ** SERVICE NAME: SSDS DATE: 90/04/06 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: **** LIS READ **** PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: RLL DATE: 90/04/06 ORIGIN OF DATA: WGI6 TAPE NAME: PBU/EOA CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** ICROFILMED ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: WGI-6.MWD SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/04/06 MAX. RECORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** COMMENTS ** COMPANY: ARCO ALASKA INC. WELL: WGI-6 FIELD: PRUDHOE BAY - EAST LOCATION: ARCTIC NORTH SLOPE, ALASKA, USA. COMPLETED: MARCH 14, 1990 RIG: DOYON 9 RLL ENGINEERS: KRELL & WESTLEY COMPANYMAN: R. BORDES COMMENTS: NUCLEAR LOGS ARE CALIPER COMPENSATED AND CORRECTED FOR TOOL WEAR. LOGS ARE DEPTH SHIFTED TO SCHLUMBERGER CASED HOLE GAMMA. TVD LOGS HAVE BEEN CALULATED FROM DATADRIL SURVEY DATA USING THE RADIUS OF CURVATURE METHOD. ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT TVD DATDRL NDIS DATDRL EDIS DATDRL DEVI DATDRL GRCH SCHLUM GR MWD ROP MWD EWR MWD FXE MWD NF0 MWD NFl MWD NN0 MWD NN1 MWD RHOB MWD CAL MWD DRHO MWD NPSC MWD ORDER# LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 DEG 0 0 0 0 1 4 0 1 68 GAPI 0 0 0 0 1 4 0 1 68 AAPI 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 INCH 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 TYPE SIZE REP CODE 4 1 66 0 1 66 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS ENTRY DESCRIPTION 255 LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API ID DEPT TVD DATDRL NDIS DATDRL EDIS DATDRL DEVI DATDRL GRCH SCHLUM GR MWD ROP MWD EWR MWD FXE MWD NF0 MWD NFl MWD NN0 MWD NN1 MWD RHOB MWD CAL MWD DRHO MWD NPSC MWD ORDER# LOG TYP CLS MOD FT 0 0 0 0 FT 0 0 0 0 FT 0 0 0 0 FT 0 0 0 0 DEG 0 0 0 0 GAPI 0 0 0 0 AAPI 0 0 0 0 FT/H 0 0 0 0 OHMM 0 0 0 0 HOUR 0 0 0 0 CTS 0 0 0 0 CTS 0 0 0 0 CTS 0 0 0 0 CTS 0 0 0 0 G/C3 0 0 0 0 INCH 0 0 0 0 G/C3 0 0 0 0 P.U. 0 0 0 0 FILE SZE PROC SPL REPR NO. LVL CODE 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 ** DATA VERIFICATION (every 100 FT) ** DEPT TVD NDIS EDIS ROP EWR FXE NF0 RHOB CAL DRHO NPSC 8400. -999. -999. 000 7955.625 -42.581 73.753 250 -999.250 -999.250 -999.250 250 -999.250 -999.250 -999.250 8500. 89. 3. 000 8042.817 -18.099 31.349 943 8.985 .367 481.000 560 8.400 .000 -999.250 8600. 242. 3. 000 8129.612 6.737 -11.659 813 5.229 .995 404.000 480 8.400 .000 -999.250 8700. 126. 2. 000 8216.221 31.819 -54.901 688 119.594 .186 999.000 115 8.980 .002 25.734 8800. 185. 2. 000 8302.723 57.107 -98.234 977 323.248 .131 1265.778 050 8.680 -.007 17.964 8900. 109. 2. 000 8389.121 82.602 -141.657 624 266.785 .263 1361.998 290 9.120 .012 15.338 9000. 159. 2. 000 8475.441 107.628 -185.500 426 293.736 .215 1227.910 060 8.590 .000 18.708 9100. 226. 2. 000 8561.721 131.379 -230.125 978 9.169 .256 850.595 400 8.680 .005 29.505 9200. 28. -999. 000 8647.975 154.226 -275.275 470 2.162 .978 744.087 250 8.350 .000 -999.250 9300. -999. -999. 000 8734.225 177.042 -320.443 250 -999.250 -999.250 -999.250 250 -999.250 -999.250 -999.250 ** 129 DATA RECORDS ** FROM ** FILE TRAILER** FILE NAME: WGI-6.MWD SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/04/06 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: 1024 DEVI GRCH GR NFl NN0 NN1 29.080 -999.250 -999.250 -999.250 -999.250 -999.250 29.553 57.188 70.427 503.000 2360.000 2520.000 29.932 35.438 47.062 440.040 2293.302 2327.164 30.054 35.281 55.651 967.000 3272.000 3192.000 30.174 15.938 26.844 1226.389 3747.374 3618.152 30.292 18.359 27.812 1316.659 3768.657 3804.320 30.342 11.125 25.033 1171.000 3752.000 3771.642 30.389 39.000 69.099 906.883 3190.154 3199.394 30.399 43.656 96.108 743.139 2880.117 2866.356 30.400 -999.250 -999.250 -999.250 -999.250 -999.250 8400.00 TO 9300.00 FT ********** END OF FILE (EOF # 2) ********** ** FILE HEADER ** FILE SEQUENCE # 2 FILE NAME: WGI-6.RPT SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/04/06 MAX. RECORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** COMMENTS ** REPEAT (MAD) DATA. LOGGED FROM 8938.50 TO 9194.00 FEET MEASURED DEPTH. ~0 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT FXE REPEAT GR REPEAT RATE REPEAT EWR REPEAT NFO REPEAT NFl REPEAT NN0 REPEAT NN1 REPEAT RHOB REPEAT CAL REPEAT DRHO REPEAT NPSC REPEAT ORDER# LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 2 4 0 1 68 HOUR 0 0 0 0 2 4 0 1 68 AAPI 0 0 0 0 2 4 0 1 68 FT/H 0 0 0 0 2 4 0 1 68 OHMM 0 0 0 0 2 4 0 1 68 CTS 0 0 0 0 2 4 0 1 68 CTS 0 0 0 0 2 4 0 1 68 CTS 0 0 0 0 2 4 0 1 68 CTS 0 0 0 0 2 4 0 1 68 G/C3 0 0 0 0 2 4 0 1 68 INCH 0 0 0 0 2 4 0 1 68 G/C3 0 0 0 0 2 4 0 1 68 P.U. 0 0 0 0 2 4 0 1 68 ** DATA FORMAT SPECIFICATION ** TYPE SIZE REP CODE 4 1 66 0 1 66 ENTRY BLOCKS ENTRY DESCRIPTION 255 LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 2 4 0 1 68 FXE GR RATE EWR NFO NFl NN0 NN1 RHOB CAL DRHO NPSC ,REPEAT REPEAT REPEAT REPEAT REPEAT REPEAT REPEAT REPEAT REPEAT REPEAT REPEAT REPEAT HOUR AAPI FT/H OHMM CTS CTS CTS CTS G/C3 INCH G/C3 P.U. 0 0 0 0 0 0 0 0 0 0 0 0 68 68 68 68 68 68 68 68 68 68 68 68 ** DATA VERIFICATION (every 100 FT) DEPT FXE GR RATE NN0 NN1 RHOB CAL EWR NF0 DRHO NPSC NFl 8900.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 9000.000 14.570 23.835 106.089 3615.389 3518.749 2.094 8.580 123.489 958.229 -.003 23.331 940.076 9100.000 14.529 34.343 103.906 2991.221 3094.121 2.391 8.840 27.871 803.080 .003 30.528 757.825 9200.000 13.508 81.714 109.730 2426.110 2460.220 .500 8.350 2.017 578.575 ,000 -999.250 650.370 ** 32 DATA RECORDS ** FROM 8900.00 TO 9200.00 FT ** FILE TRAILER** FILE NAME: WGI-6.RPT SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/04/06 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: 1024 ********** END OF FILE (EOF # 3) ********** ** TAPE TRAILER** SERVICE NAME: RLL DATE: 90/04/06 ORIGIN OF DATA: WGI6 TAPE NAME: PBU/EOA CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 90/04/06 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT