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190-040
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, September 23, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC WGI-07 PRUDHOE BAY UNIT WGI-07 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/23/2025 WGI-07 50-029-22031-00-00 190-040-0 G SPT 7832 1900400 1958 3646 3645 3641 3639 9 10 10 12 4YRTST P Guy Cook 8/15/2025 Testing was completed with a Little Red Services pump truck and calibrated gauges. 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-07 Inspection Date: Tubing OA Packer Depth 192 2401 2370 2361IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250815171232 BBL Pumped:5 BBL Returned:2.4 Tuesday, September 23, 2025 Page 1 of 1 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU WGI-07 Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 190-040 50-029-22031-00-00 9005 Conductor Surface Intermediate Production Liner 8690 80 3443 8354 915 8958 20" 13-3/8" 9-5/8" 7" 8649 43 - 123 42 - 3485 40 - 8394 8085 - 9000 43 - 123 42 - 3485 40 - 8163 7891 - 8686 8937 470 2260 4760 7020 None 1490 5020 6870 8160 8403 - 8927 7-5/8" 29.7# x 7" 26# L80 38 - 8098 8170 - 8622 Structural 7" Baker S-3 2208 / 2208 8038 7849 Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com (907) 564-4672 PRUDHOE BAY / PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028302 38 - 7903 234483 267010 180 150 3648 3643 324-072 13b. Pools active after work:PRUDHOE OIL 7" Camco A1 8038 / 7849 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 3:20 pm, Mar 29, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.03.28 10:30:19 - 08'00' Bo York (1248) WCB 7-1-2024 DSR-4/12/24 RBDMS JSB 040424 ACTIVITYDATE SUMMARY 3/4/2024 T/I/O= 2726/145/0 (TBGING WASH/PICKLE) GI Water Wash. Pumped 10 BBLS 60/40 followed by 100 BBLS 180* Diesel down the TBG. Pumped 330 BBLS Fresh Water with .02% F-103 Surfactant, 2 hour soak, Pump 270 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. **Waited on DSL from 0850-1213 hrs** Daily Report of Well Operations PBU WGI-07 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-07 Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 190-040 50-029-22031-00-00 ADL 0028302 9005 Conductor Surface Intermediate Production Liner 8690 80 3443 8354 915 8958 20" 13-3/8" 9-5/8" 7" 8649 43 - 123 42 - 3485 40 - 8394 8085 - 9000 43 - 123 42 - 3485 40 - 8163 7891 - 8686 8937 470 2260 4760 7020 None 1490 5020 6870 8160 8403 - 8927 7-5/8" x 7" L80 38 - 80988170 - 8622 Structural 7" Baker S-3 7" Camco A1 8038 / 7849 2208 / 2208 Date: Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com 907.564.4672 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 2:03 pm, Feb 08, 2024 Digitally signed by Eric Dickerman (4002) DN: cn=Eric Dickerman (4002) Date: 2024.02.07 14:22:36 - 09'00' Eric Dickerman (4002) DSR-2/13/24SFD 2/9/2024MGR13FEB23 10-404 *&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.28 13:53:55 -09'00' 324-072 RBDMS JSB 022924 Well Work Prognosis Well Name:WGI-07 API Number:50-029-22031-00 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:1900400 First Call Engineer:Dave Bjork Office: 907-564-4672 Cell: 907-440-0331 Second Call Engineer: Gas Injection Rate: ~250,000 Mscf/Day Injection Pressure: 3,660 psi Reservoir Pressure (Estimate): 3300 psi Program Objective(s): WGI-07 is a gas cap injection well that has demonstrated a decrease in injectivity. The well has not been water washed since 2019. 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 Well WGI-07 GI Water Wash 01/28/24 David Bjork (907) 564-4672 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 330 bbls of fresh water with 0.02% F-103 surfactant at ~5 bpm. Max pressure during this pumping can reach 1800 psi. Once 360 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 50 bbls to soak outside the perfs. b.) After 2 hour soak time, resume pumping at max rate/pressure (whichever is hit first) for next 270 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 330 5 66 1.10 Soak 2.00 FW flush 270 5 54 0.90 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 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 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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y Samantha Carlisle at 8:50 am, Dec 06, 2021 'LJLWDOO\VLJQHGE\%R<RUN '1 FQ %R<RUNF 86R +,OFRUS $ODVND//&RX $ODVND1RUWK 6ORSHHPDLO E\RUN#KLOFRUSFRP 'DWH %R<RUN DSR-12/7/21MGR03JAN2022 RBDMS HEW 12/8/2021 SFD 12/6/2021 $&7,9,7<'$7(6800$5< 7,2 :DWHU:DVK3XPSEEOVEEOV GLHVHO EEOV NFOZLWK)GRZQWEJWRVSRWGLHVHOLQWRWKSHUIV6RDNIRUKUV3XPSDQ DGGLWLRQDOEEOV.&/ZLWK)DQGDEEOWDLO)LQDO:+3 V 7XUQHGZHOORYHUWR'62WR32, 'DLO\5HSRUWRI:HOO2SHUDWLRQV 3%8:*, MEMORANDUM TO: Jim Regg��� P.I. Supervisor I I FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 23, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC WGI-07 PRUDHOE BAY UNIT WGI-07 Src: Inspector Reviewed By: P.I. Supry �1Z Comm Well Name PRUDHOE BAY UNIT WGI-07 API Well Number 50-029-22031-00-00 Inspector Name: Lou Laubenstein Permit Number: 190-040-0 Inspection Date: 8/15/2021 Insp Num: mitLOL210815145936 Rel Insp Num: —T Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well WGI-07 - -Type T Inj G " I VD 7832 Tubing 34 70 3470 ' 3464 3456 3456 PTD 19ooaoo Type Test I SPT Test psi 1958 IA 198 2512 2509 2503 2500 BBL Pumped: 4.8 BBL Returned: 4.8 OA 12 IO 13 ' 14 ' 14 ` Interval 4YRTST - - P/F P - Notes: 4 Year MIT -IA Monday, August 23, 2021 Page 1 of I Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:190-040 6.API Number:50-029-22031-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028302 Property Designation (Lease Number):10. 8. PBU WGI-07 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Water Wash Op Shutdown GAS GSTOR WAG 5 SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 9005 Effective Depth MD: L-80 11. 08/01/2021 Commission Representative: 15. Suspended Contact Name: Dave Bjork Contact Email: david.bjork@hilcorp.com Authorized Name: Bo York Authorized Title:Sr Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 7" A-1 Injection SSSV Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8690 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 8038, 7849 2208, 2208 Date: Liner 915 7"8085 - 9000 7891 - 8686 8160 7020 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 42 - 3485 42 - 3485 14. Estimated Date for Commencing Operations: BOP Sketch 43 - 123 Conductor 6870 Proposal Summary 13. Well Class after proposed work: 7" Baker S-3 Packer 8403 - 8927 8170 - 8622 7-5/8" 29# x 7" 26#38 - 8098 Liner 8958 8649 None 8937 43 - 123 470 13-3/8" 9-5/8" Contact Phone:(907)564-4672 Date: 4760 80 149020"Surface 2260 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Production 3443 5020 Liner 8355 40 - 8394 40 - 8163 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2528 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. 321-314 By Meredith Guhl at 12:23 pm, Jun 25, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.06.25 07:39:39 -08'00' Bo York SFD 6/25/2021 10-404 MGR01JULY21 DSR-6/25/21 dts 7/1/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.06 11:27:42 -08'00' RBDMS HEW 7/7/2021 Well Work Prognosis Well Name:WGI-07 API Number:50-029-22031-00 Current Status:Gas Injector Leg: Estimated Start Date:July 10th, 2021 Rig:N/A Reg. Approval Req’d?10-403 Date Reg. Approval Received: Regulatory Contact:Carrie Janowski Permit to Drill Number:1900400 First Call Engineer:Dave Bjork Office: 907-564-4672 Cell: 907-440-0331 Second Call Engineer:Ryan Thompson Office: 907-564-5280 Cell: 907-301-1240 Gas Injection Rate: ~195,000 Mscf/Day Injection Pressure: 3,537 psi Reservoir Pressure (Estimate): 3250 psi Program Objective(s): WGI-07 is a gas cap injection well that has demonstrated a decrease in injectivity. The well has not been water washed since 2019. 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ q�ps-��s FF((yy �_,qqgg �__,, ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ C Ap1'+rbvEd�A/ogram ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Water Wash p 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5. Permit to Drill Number: 190-040 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service R1 6. API Number: 50-029-22031-00-00 1 7 Property Designation (Lease Number): ADL 028302 B. Well Name and Number: PBU WGI-07 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 9005 feet Plugs measured None feet true vertical 8690 feet Junk measured 8937 feet Effective Depth: measured 8958 feet Packer measured 8038 feet true vertical 8649 feet Packer true vertical 7849 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 43-123 43-123 1490 470 Surface 3443 13-3/8" 42-3485 42-3485 5020 2260 Intermediate 8355 9-5/8" 40-8394 40-8163 6870 4760 Production Liner 915 7' 8085-9000 7891-8686 8160 7020 Perforation Depth: Measured depth: 8403-8927 feet True vertical depth: 8170-8622 feet Tubing (size, grade, measured and true vertical depth) 7-5/8" 29# x T' 26#, L-80 38-8098 38-7903 Packers and SSSV (type, measured and T' Baker S-3 Packer 8038 7849 true vertical depth) 7" A-1 Injection SSSV 2208 2208 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 11 Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 232924 200 3777 Subsequent to operation: 245183 265 3667 14.Attachments :(required per 20 MC 25.07026.071. a 25.283) 15. Well Class after work: Daily Report of Well Operations m Exploratory ❑ Development ❑ Service [a Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ 0 SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319479 Authorized Name: Brown, Don L. Contact Name: Brown, Don L. Authorized Title: Petroleum Engineer Contact Email: bmwd2@BP.wm Authorized Signature: "i ll rl Date: j� yid (i Contact Phone: +19075644675 Form 10404 Revised 04/2017 Submit Original Only,f�.��o/^����9 RBDMS— DEC 1 7 Amo PBU T/1/0=2700/145/0 Temp= Hot (LRS Unit 42 -Tubing Wash/Pickle) Pumped 10bbls 60/40 and 215 bbls of 100" Diesel/Xylene down TBG, flushed out coils with 3 bbls 60/40, swapped to FW -w/ F-103 surfactant and pumped 290 bbls, freeze protected surface lines with 2 bbls 60/40. Let soak for 2 hrs. Pumped 270 bbls FW- w/F-103 surfactant down TBG for overflush and capped with 10 bbls 60/40. Notified DSO to POI. SV WV SSV= closed. MV IA OA= ooen. Final Who's=vac/105/vac FTREE= ■ WELLHEAD= 68#, K-55 XO MCEVOY ACTUATOR= BA KERC KB. ELEV = 61' BF. ELEV - 8403-8447 KOP = 5800' Max Angle = 31" @ 8600' um MD = 9199' Dat 8554-8574 TO L-80 BTC um ND= 8800SS 'CONDUCTOR 91.5 #, H-40, ID = 19.124" — 9-5/8" CSG, 47#, L-80 HYD 563 XO TO L-80 BTC 9-5/8" BOWEN CSG PATCH, 47#, — L-80 BTC, ID=8.681" 13-3/8" CSG, 68#, L-80 BTC, ID = 12.415" — 7-5/8" TBG, 29.7#, L-80 VAM TOP, --1 7973- .0459 bpf, ID = 6.875" Minimum ID = 5.770" @ 8053' 7" HES RN NIPPLE L-80 I11101IN 9-5/8" CSG, 47#, L-8 .0732 bpf, ID = 8.681" PERFORATION SUMMARY REF LOG: FINAL CNP ON 03/30/90 ANGLE AT TOP PERF: 30° @ 8403' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8403-8447 O 05/31/90 3-3/8" 4 8504-8547 O 05/31/90 3-3/8" 4 8554-8574 O 05/31/90 3-3/8" 4 8580-8747 O 05/31/90 3-3/8" 4 8754-8799 O 05/31/90 3-3/8" 4 8803-8852 O 05/31/90 3-3/8" 4 8857-8887 O 05/31/90 3-3/8" 4 8892-8896 O 05/31/90 3-3/8" 4 8899-8906 O 05/31/90 3-3/8" 4 1 8911-8927 1 O 1 05/31/90 ID = 6.184" W I 0 SAFETY NOTES: WELL REQUIRES A SSSV. DO NOT PRESSURE OA ABOVE 3000 PSI. W11111m DATE REV BY COMMENTS DATE REV BY COMMENTS 05/23/90 D91 N2ES ORIGINAL COMPLETION 07124/09 N4ES RIND 07/26/09 PJC DRLG HO CORRECTIONS 07/30/09 MNIJMD DR -G DRAFT CORRECTIONS 09/28/09 MWJMD DRAWING CORRECTIONS 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE I -D/0 A( AV, IU = 0.Z0J 7" X 7-5/8" XO, ID = 6.253" 9-5/8" BTC ES CEMENTER 9-5/8" BKR ECP. ID = 6.861" 17-5/8" X 7" XO, ID = 6.253" 7" HES R NIP, ID = 5.963" 19-5/8" X 7" S-3 BKR PKR, ID = 6.000" 1 7" HES RN NIP, ID = 5.770" 17-5/8" BKR MILLOUT D(TENSION, ID = 6.625" 1 7" WLEG, ID = 6.253" 1 9-5/8" X 7" BOT HYD II HGR I FISH: FASDRILL DEBRIS (07/24/09) 1 PRUDHOE BAY UNIT WELL: WGI-07 PERMIT No: 9900400 API No: 50-029-22031-00 SEC 11, T11 N, R1 4F 846' FNL & 1085' FEL BP Exploration (Alaska) THE STATE 01ALA V KA GOVERNOR MIKE DUNLEAVY Don Brown Petroleum Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU WGI-07 Permit to Drill Number: 190-040 Sundry Number: 319-479 Dear Mr. Brown: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.cogcc.claska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, V ce Chair DATED thin day of October, 2019. RBDMS v OCT 15 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 San 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other Water Wash 0 ' 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number: 190-040 ' 3, Address. P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 0 6. API Number: 50-029-22031-00-00 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Numb Will planned perforations require a spacing exception? Yes ❑ No 0 PBU WGI-07 ' 9. Property Designation (Lease Number): 10. Field/Pools: "' ' y ADL 0283022 ,Q / PRUDHOE BAY, PRUDHOE OIL , �'� IhI23J17 11. PRESENT WELL CONDITION SUMMARY AQGCr Total Depth MD (fl): Total Depth TVD(fi): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD). 9005 8690 8958 8649 None 8937 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 43-123 43-123 1490 470 Surface 3443 13-3/8" 42-3485 42 - 3485 5020 2260 Intermediate 8355 9-5/8" 40-8394 40-8163 6870 4760 Production Liner 915 7" 8085-9000 7891-8686 1 8160 7020 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Tubing Grade: Tubing MD (ft): 8403- 8927 8170 - 8622 ;518"29# 7- 7" 26# L-80 38-8098 Packers and SSSV Type: 7" Baker S-3 Packer Packers and SSSV MD (ft) and ND (ft): 8038, 7849 7"A-1 lnjemion SSSV 2208, 2208 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 14. Estimated Date for Commencing Operations: 11/25/2019 15, Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ 0 ' Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Brown, Don L. be deviated from without prior written approval. Contact Email: bmwd20BP.mm Authorized Name: Brown, Don L. Contact Phone: +1 9075644675 Authorized Title: Petroleum Engineer Authorized Signature: Q&11 C Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. UI] Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMSIL" OCT 2 5 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No 6 Subsequent Form Required: to-44C)(J THE APPROVED/COMMISSION P� ,n zhq Approved by: COMMISSIONER COMMISSION Date. �l X11, V , U0\ - I 9A= 42-;W"' ORIGINAL dVl�1�pGT") y Submit Form and Form 10-003 Revised 04/2017 Approved application is valid for 12 months from the date of approval. G Attachments in Duplicate 10-403 Sundry Application for Well PBU WGI-07 PTD #190-040 Expected Start Date: November 25, 2019 Current condition of well: Gas Injection Well, Operable, Online: Gas Injection Rate: 196115 Mscf/Da Injection Pressure: 3608 psi Reservoir Pressure: 3427 psi Program Objective(s): WGI-07 has had several successful water washes historically, the most recent being on 6/26/16. These water washes have been successful and injectivity in this well has decreased since the 2016 water wash. Injectivity should improve as the process is designed to dissolve salts and possibly asphaltenes in the tubing and formation. Proposed Program: 1. Pump diesel/xylene water wash as per attached pumping template. BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU WGI-07 PTD 4*190-040 Pump Schedule: Wei WGI-07 Work Desc AFE 0 Data 1011&19 En neer Don Brown Phone 9D7 564-4675 N2s value r N/A H2s Date r run If Increase well injectivity by performing a water wash. Use 2 full uprights of fresh water mixed with 0.02%F-103 surfactant. Use 200 bbis of diesel/xylene. Pump Schedule Stage Fluid Type Pump into Vol bbis Rate b m Max Pres i Spear Methanol/Water TBG 1D 1-3 2-100 Solvent DieselOC lene TBG 200 Max 2500 Over -Flush f%KCI TBG 600 See Below 2500 Freeze Protect Methanolt'Nater TBG 10 1-3 2500 1.110 bbl 60/40 McOH/water spear 2) 200 bbis 50/50 diesel/xylene heated to 90 degrees F or as hot as LRS can heat it. 3.) Pump 600 bbisof fresh water with 0.02% F-103 surfactant per following: a.) Pump 303 bbis of fresh water with 0.02% F-103 surfactant at 1-3 bpm, shutdown pumps and Let diesel/xyiene soak across perfs for 4 hours - this should allow -100 bbis of D/X to be pumped into perfs and a remaining 100 bbis to soak. b.) Resume pumping at 0.5 bpm for next 200 bbis of fresh water with 0.02% F-103 surfactant. c.) Once 503 bbis of fresh water with 0.02% F-103 surfactant has been pumped resume pumping at 1-3 bpm for remainder of dverflush (-97 bbis). 4.)10 bbls of 60/40 McOH/water freeze protect 5.)RDMO. Return well to gas injection. filling out the pumping template, please note the following. If "MIT" is selected as a stage, the corresponding MIT section must be filled out. The loxes are defined as follows: Test Type: Type of test to be performed (MIP -T, MIT -IA, MIT -OA etc) Target Pressure: This is the requested Mit test pressure (ie MIT -T to 2500 psi) Max Applied Pressure. This M the max pressure that can be applied in order to achieve a passing MIT of the target test pressure, typically 10% greater than target pressure. BP practice 100218 (10-45) requires that the test pressure must remain above or equal to the target pressure during the entire test evaluation period, This pressure must not exceed the lowest rated working pressure (taking into account corrosion, erosion, etc) of any well barrier element in the well barrier envelope. Test Fluid: The fluid to be used for the test. InWgrity Limits Confirmed: By checking this box you have confinned that the 'Max Applied Pressue requested is svithihe the limits of the wells BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU WGI-07 PTD #190-040 Wellbore Schematic: BTC STC. D-8.881' MX. L-80 OTC, 155 XO 481 BTC Minimum ID = S.770" @ 8053' 7" HES RN NIPPLE D=8.681' PEFFC11ATDNSUMW+RY REF LOG: MAL(NPON0Y3090 AhGLEATTOPPIFF: 30' g 84UP Not.. Rotor W P,o ctv, C8 for 1Y5toroM Pmt ,Stta SIZE SPP I N EWAL C>R.SV_ DATE 3-318' 4 8403.0447 O 05,31."!0 3-3/6• 4 8504-8547 O 0513190 3-3/6 4 8554-8574 O OW31M 3-3/8• 4 8580-8747 O 05/31/90 3-318' 4 8754-8793 O 05/31/30 3-Y8' 4 8503.8852 O 05/31/90 3 -XS 4 8857-8857 O 0513190 3-3/8' 4 8092-811% O 05/3190 3-318' 4 8809-8908 O 05Q190 3-318' 4 8911-8927 O 051311-9(1 WGI- 07 PARESSURE A ASME3800 PSL I OdESASSSV 00 NOr __._ 219(7 TD68 NP,D=8.0' ' — 2208' 09 / WES 0RIG1t4AL COMPLETION ' X7 -S9' XO, D - 8253• - - 2585' 9518' BTC ES C(3.5NTER -- 2603 9518'OWi ECP."b=8Sbr /931' - FER6597124.09) DATE REV SY I CCMMENT3 I CATS I REV G W2390 09 / WES 0RIG1t4AL COMPLETION 07,24,09 NOES RWO URLGHDCCRR55% . J URLG DRAFT CORW4UTDN5 .. [. [%tAINM CORRECTKMS It AUCED SSW SAFETY NOTE BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 41ULME SAY INR HELL: WG407 NUVR N. 1900400 APIND. 50.02922031-00 T11N. RI4E. 846'FNL 8 1005 FEL OPE.ploration (Alaska) Ww I O SAFETY NOTES: WELL REQUIRES A SSSV. DO NOT (v= PRESSURE OA ABOVE 3000 PSI. 3/8" CSG, 66' K-55 XO 1 2175' —I7-5/8" X 7" XO, ID = 6.253" L-80 BTC CONDUCTOR, 91.5 #, H-40, ID = 19:124" 9-5/8" CSG, 47#, L-80 HYD 563 XO TO L-80 BTC I9-5/8" BOW CSG PATCH, 47#, I1 2629' L-80 BTC, ID = 8.681" 13-3/8" CSG, 68#, L-80 BTC. ID = 12.415" y -URR' 7-5/8" TBG,.29.7#, L-80 VAMTOP, h 7973' f .0459 bpf, ID = 6.875" Minimum ID = 5.770" @ 8053' 7" HES RN NIPPLE L-80 TCII, .0383 bpf, ID = 6.276" TOP OF 7" LNR 9-5/8" CSG, 47#, L-80 BTC -M,.0732 bpf, ID = 8.681" 1 8085' 1 PERFORATION SUMMARY REF LOG: FINAL CNP ON 03/30/90 ANGLE AT TOP PERF: 30° @ 8403' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8403-8447 O 05/31/90 3-3/8" 4 8504-8547 O 05/31/90 3-3/8" 4 8554-8574 O 05/31/90 3-3/8" 4 8580-8747 O 05/31/90 3-3/8" 4 8754-8799 O 05/31/90 3-3/8" 4 8803-8852 O 05/31/90 3-3/8" 4 8857-8887 O 05/31/90 3-3/8" 4 8892-8896 O 05/31/90 3-3/8" 4 8899-8906 O 05/31/90 3-3/8" 4 8911-89271 O 1 05/31/90 LNR, 29#, L-80 BTC -M, .0371 bpf, ID = DATE REV BY COMMENTS DATE REV BY COMMENTS 05/23/90 D9 / N2ES ORIGINAL COMPLETION 07/24109 N4ES RWO 07/26/09 PJC DRLG HO CORRECTIONS 07/30/09 MN/JMD DRLG DRAFT CORRECTIONS 09/28/09 MWJMD DRAWING CORRECTIONS 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE 7" DB -6 NIP, ID = 6.0" 1 7" X 7-5/8" XO, ID = 6.253" BTC 19-5/8" BKR ECP, ID = 6.861" 17-5/8" X 7" XO, ID = 6.253" 1 7" HES R NIP, ID =5.963" 19-5/8" X 7" S-3 BKR PKR, ID = 6.000" 1 17" HES RN NIP, ID = 5.770" 1 7-5/8" BKR MILLOUT 7" WLEG, ID = 6.253" 9-5/8" X 7" BOT HYD I FISH: FASDRILL DEBRIS (07/24/09) 1 PRUDHOE BAY UNIT WELL: WGI-07 PERMIT No: '1900400 API No: 50-029-22031-00 SEC 11, T11N, R14F, 846' FNL 8, 1085' FEL BP Exploration (Alaska) • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday,August 18,2017 TO: Jim ReggJ'Zl P.I.Supervisor "Net/ 1 7 SUBJECT: Mechanical Integrity Tests i BP EXPLORATION(ALASKA)INC. WGI-07 FROM: Brian Bixby PRUDHOE BAY UNIT WGI-07 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv- --- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT WGI-07 API Well Number 50-029-22031-00-00 Inspector Name: Brian Bixby Permit Number: 190-040-0 Inspection Date: 8/16/2017 Insp Num: mitBDB170816140810 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well WGI-07 Type Inj G TVD 7832 Tubing 3441 3439 3439 3438 PTD 1900400 Type Test SPT Test psi 1958 - IA 92 2502 2489 - 2487 BBL Pumped: 2.6 BBL Returned: 3 OA 5 4 " 5 - 6 Interval [ 4YRTST P/F P ,/ Notes: SCANNED FEB 2 3 �7 ? Friday,August 18,2017 Page 1 of 1 STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMIS", ` REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 121 Alter Casing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Water Wash Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 190-040 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory ❑ AK 99519-6612 Stratigraphic 0 Service f3 6. API Number: 50-029-22031-00-00 7. Property Designation(Lease Number): ADL 0028302 8. Well Name and Number: PBU WGI-07 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL RECEIVED 11.Present Well Condition Summary: Total Depth: measured 9005 feet Plugs measured feet JUL 6 2016 true vertical 8690 feet Junk measured 8937 feet Effective Depth: measured 8958 feet Packer measured 8038 feet true vertical 8649 feet Packer true vertical 7849 feet Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 43-123 43-123 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 915 7"29#L-80 8090-9005 7895-8690 8160 7020 Perforation Depth: Measured depth: 8403 8447 feet feet 8504-8547 feet 8554-8574 feet 8580-8747 feet 8754-8799 feet 8803-8852 feet 8857-8887 feet 8892-8896 feet 8899-8906 feet 8911-8927 feet True vertical depth: 8170-8208 feet feet 8258-8295 feet 8301-8318 feet 8323-8466 feet 8472-8510 feet 8514-8556 feet 8561-8587 feet 8591-8595 feet 8597-8604 feet 8608-8622 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 7"Baker S-3 Packer 8038 7849 true vertical depth) 7"A-1 Injection SSSV 2208 2208 12.Stimulation or cement squeeze summary: Intervals treated(measured): 8403'-8447',8504'-8547',8554'-8574',8580'-8747',8754'-8799',8803'-8852',8857'-8887',8892'-8896',8899'-8906',8911' -8927'. Treatment descriptions including volumes used and final pressure: FC JP.I\! (l! f? 24 Bbls 50/50 Methanol/Water,100 Bbls Diesel,100 Bbls Xylene,727 Bbls Fresh Water w/0.02%F-103 Surfactent,1590 psi. � � e` 4 t f 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 163983 400 3415 Subsequent to operation: 226776 1100 3556 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Ed Exploratory ❑ Development 0 Service RI Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ H SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-240 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature M / Phone +1 907 564 4424 Date 7/27/16 Form 10-404Revised 5/2015viz_ .1-12,11c, �RBDMS t/ AUG - 1 2016 Submit Original Only 72( • • • p• 0 CD 0 0 0 0 0 0 0 cvr, Ls? COCOCOcC;I Nr O N f� O 0 N Ln V LO U j p CD CD O p C) p O CD p i 0) CO N N- N- CO O) O) V • 'd' CD CO CO CO N CO N m M CO CO CO CO CO N- CO I- CA I- N- O N LC) co N O co r p O C7) N O O I- vtCO '- CO N CO 0) CO N CO 00 N N N- I- 0 I 1 1 1 1 1 1 1 1 1 COX) N CO N- M N Co O Nr O) CO CA N CD f� 1' CO CO CO c- N CO N N- N N N- 4.4 M0 CO O co d O O ON) N CT ti V CO 'vY O — N (J) CO N CO 0) N N N- CO (.) p ++ Q I CO O N CO w MN O O CA CO CA N CA (J V d' N- CO O M N 0) N CO N N N- F- M W b y CD O a p O O CC) (0 CO CO CO CO C;) ' Y J J J CO J CO CIO H • W CO CO .(� N t? (fl CO *k Cl) O M 6) 00 00 00 N N N N N U O co CV co co (7) LC) LO CA .0 CD CO CD LOCr)O CO v- O LO U co CO co (N V CO I- ' — m— a 0) CO N LC) O N LO -J W W I— Q Cn= O w LuCI121 ca— U W W V LaL Le22 i Z Z Z Z Z W W W co co co m ODDHHZDDDD UcAcnzZ 1- 1- f- • • o \ 0 / _ ® o_^ / � / _/C E C ® o / O E S aD O o co / ? 0 O _ « + / c o \ \ qo / ./ k / 2 (1) 4 � o ( = o = ooaeeo .-6)- » ® N- e c = a Ee % \ oc = o k ° ° ® / #/ $ / \ .0 c a) -C co k @ G ¢ < k 7 > o 0 sa/ = * E'/ _ ° E -0 / § Da) / c @ c E \ / / k / / k ± o * a_ o en o e £ c o e co < \ f \ o § 4- a Em 1- 2 e ' ' a)\ a _ o_ > D 0 \ m k \ ID % f \ R E - _ © 2 — 9 ƒ ) EE ƒ f2t \ o 3 q q .� 5 q o \ co o E _ w n 4 > �0 \/ 0/ - 5 / \ o D c = g .c F 7 = m $ •[ .// f ELL o 0 \ § / / \ > / / ©Ce 7 .c S \ 7 a ) m ,, . C C 11 2 § s / / e R a o 2 ,— R o J § � � § ® = o/ b y p G — P \ R - $ .R 0 4 m CO / co a) // / / Co / \ % f ƒ � / o_/ \ / C \ 2 / ECO t a 0 / \ > w = m / 5 » 5 / I a — > o ¢ O > O / \ / / \ § t e ƒ c w / o > f / E / / $ \ \ X/ 2 < co e >-®5 \ \ k7 / \ \ ® e / 6 o < TREE= CMJ WELLHEAD'--: SAFOIOTES: WELL REQUIRES A SSSV. DO NOT " ACTUATOR= McEVo " BAKER C KB.ELEV= 61' BF.ELEV= KOP= Max Angle= Datum MD= Datum TVD= 8800'SS 'S - 31°@ 85680000,' 13-3'868#,K"55 XO CSG, —I 66' 9199' TO L-80 BTC ±Wei G 1-07 „ 41 /4 44 14 41 A • I 4" 4. 4 1 • PRESSURE OA ABOVE 3000 PSI. 2175' —7-5/8"X 7°XO,ID=6.253" 2190' H7"DB-6 NIP, ID=6.0" I. . 20"CONDUCTOR,91.5#,H-40. ID=19.124" 119' .4 14 . +4 . 44 • 2208' H 7"X 7-5/8"X0ID=6.253" 9-5/8"CSG,47#,L-80 HYD 563 XO H 2585' :.!...; 4 rA. • TO L-80 BTC 2585' —19-5/8"BTC ES CEMENTER Ivi 1 14 I I 1 • 9-5/82603' 1 - 9 5/8"BKR ECP, ID=6.861" "BOWEN CSG PATCH,47#, — 2629' —1 ... VI / L-80 BTC, ID=8.681" k 13-3/8"CSG,684. L-80 BTC, ID=12.415" —1 3485' ,---------- 7973' 1-17-5/8"X 7"XO, ID=6.253" 7-5/8"TBG,29.74,L-80 VAM TOP, —1 7973' .0459 bpf, ID=6.875" I I 7988' —Jr"HES R NIP,ID=5.963" Minimum ID = 5.770" @ 8053' z IX-- 8019' H9-5/8"X 7"S-3 BKR PKR, ID=6.000" 7" HES RN NIPPLE I I 8053' -17"HES RN NIP, ID=5.770" 8075' —17-5/8"BKR MILLOUT EXTENSION, ID=6.625" _ 7"TBG.26#, L-80 TCII, .0383 bpf,ID=6.276" H 8080' , %.__, 8080' —17"WLEG. ID=6.253" TOP OF 7"LNR H 8085' F' '..% 8085' —9-5/8"X 7"BOT HYD II HGR 9-5/8"CSG.47#,L-80 BTC-M, H 8394' .0732 bpf, ID=8.681" k PERFORATION SUMMARY REF LOG: FINAL CNP ON 03/30/90 ANGLE AT TOP PERF:30°@ 8403' I Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE I 3-3/8" 4 8403-8447 0 05/31/90 3-3/8" 4 8504-8547 0 05/31/90 3-3/8" 4 8554-8574 0 05/31/90 3-3/8" 4 8580-8747 0 05/31/90 I 3-3/8" 4 8754-8799 0 05/31/90 3-3/8" 4 8803-8852 0 05/31/90 I 3-3/8" 4 8857-8887 0 05/31/90 3-3/8" 4 8892-8896 0 05/31/90 3-3/8" 4 8899-8906 0 05/31/90 I 3-3/8" 4 8911-8927 0 05/31/90 1111, 8937' —J FISH: FA SDRILL DEBRIS(07/24/09) PBTD —1 8958' 44144041 444004 •••••••••••.•V 7"LNR,29#,L-80 BTC-M,.0371 bpf,ID=6.184" — 9000' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/23/90 D9/N2ES ORIGINAL COMPLETION WELL: WGI-07 07/24/09 N4ES RWO PERMIT No:r1900400 07/26/09 PJC DRLG HO CORRECTIONS API No: 50-029-22031-00 07/30/09 MN/JMD DRLG DRAFT CORRECTIONS SEC 11,T11N,R14E,846'FNL&1085'FEL 09/28/09 MN/JMD DRAWING CORRECTIONS 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE : BP Exploration (Alaska) 6\ D- 0Li y OF Tye yw\� I�j:cv THE STATE Alaska Oil and Gas ofALASI�:A iM Conservation Commission _ i= _= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279.1433 OF ALAS�� Fax: 907.276.7542 www.aogcc alaska.gov SOO° APR 2 9 2015 Spencer Morrison Petroleum Engineer O ' r Q BP Exploration(Alaska), Inc. t { t V `'�' P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU WGI-07 Sundry Number: 315-240 Dear Mr. Morrison: 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, PrnL Cathy '. Foerster Chair PnteDATED this c- d y of April, 2015 Encl. STATE OF ALASKA 'a P R 2 1 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION �.f 1LI2.,I/5 APPLICATION FOR SUNDRY APPROVALS A )GC�,� 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well Change Approved Program CI Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other Water Wash El• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number BP Exploration(Alaska),Inc. _Exploratory ❑ Development ❑ 190-040-0 ' 3.Address. Stratigraphic ❑ Service LI 6.API Number. P.O Box 196612,Anchorage,AK 99519-6612 50-029-22031-00-00 . 7 If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? _ PBU WGI-07 • 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). 9005 • 8690 • 8958 8649 None 8937 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91 5#H-40 42.73-122.73 42.73-122.73 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate r See Attachment See Attachment See Attachment r See Attachment See Attachment r See Attachment Production None None None None None None Liner 915 7"29#L-80 8089.84-9004.75 7895 14-8690.22 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 TVD(ft)' See Attachment for Packer Depths 7"A-1 Injection SSSV 2208',2208' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 ' 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 6/10/15 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ I] WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Spencer Morrison Email Spencer.Morrison@BP.Com Printed Name Spencer Morrison Title Petroleum Engineer Signature // Phone 564-5773 ! L//'Sate Prepared by Garry Catron 564-4424 COMMISSION USE ONLY 3 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: (6 - 2 4 V Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other Spacing Exception Required? Yes ❑ No h Subsequent Form Required: APPROVED BY / Approved by: aiPAlt4416 - COMMISSIONER THE COMMISSION Date: 4 ..Z7-[ 5 ,- v7-t- 3//s N AL yz. �Ri GI Form 10-403 Revised 10/2012 0 pra4ed application is valid for 12 months from the datp�pproval. Submit orm� and Attachments in Duplicate RBDM9�C` APR 2 9 2015 .t• &-.rte 00 co 0 0 0 LO 0 0 0 0 mvCOCOCOCOLO00000 co = J J J J Y J J J J (1) 0 o CD 0 0 0 0 0 0 0 0 (6 N- (O O N (O LO C) O) 0 V N- (NI LO tt Lc) U 0 0 0 0 0 0 0 0 0 0 Cr) N- N- (oNLC) vCS) C) v V c0 CO — O - N CD CO N m N— co co CO LO CO N- co co N- 0 (0 N- N- O (3) M N m - d co O co O O O O N co — (o *1C N- (3) '- CO N N CO CO M N- H 0 0 H CO O t O) O N O CO N O V Co CO V CO (h N N— L H N E 0 0 M N �,.) N- O LO O) co N o LO co —N d 0 0 co O 6) O) O) N (/) O Q ' N co O) () co N N- N Q C •— a 0 OD 0 LO H coNa) o Q v co O N v o ('') N N CO N- N N O o o O in O O CO LO CO CO 1CO CO O Y O _J J = J J 00 co co N co 4t O) 6) k O - - CO CO 0 N CO F:0N N N O LO M ti L co (oir) O U) V LO 0 O O LO CO O LO CO M N 00 CO N J N LO O M N L) W W I— < Q mI— QQ WW U W W c� � � � QQCOOCDCD U Q rY CLLLLZZZZ Z W W W c m m m O I— I— ZDDDDDD U z Z U) U) HHHH Perforation Attachment ADL0028302 Well Date Perf Code MD Top MD Base TVD Top TVD Base WGI-07 5/31/90 PER 8403 8447 8170 8208 WGI-07 5/31/90 PER 8504 8547 8258 8295 WGI-07 5/31/90 PER 8554 8574 8301 8318 WGI-07 5/31/90 PER 8580 8747 8323 8466 WGI-07 5/31/90 PER 8754 8799 8472 8510 WGI-07 5/31/90 PER 8803 8852 8514 8556 WGI-07 5/31/90 PER 8857 8887 8561 8587 WGI-07 5/31/90 PER 8892 8896 8591 8595 WGI-07 5/31/90 PER 8899 8906 8597 8604 WGI-07 5/31/90 PER 8911 8927 8608 8622 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-07 SSSV 2208 7"A-1 Injection SSSV 2208 WGI-07 PACKER 2621 9-5/8" BOT External CSG PKR 2621 WGI-07 PACKER 8038 7" Baker S-3 Packer 7849 WGI-07 PACKER 8066 7-5/8" FB-1 Perm Packer 7874 ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.9,DBR,LHD,EAZ 01/15/15) General Information Well Name: WGI-07 Well Type: Gas Injection Well API Number: 50-029-22031-00 Well Activity Conventional 4 Classification: Activity Description: Water wash Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: TREAMENTS Estimated Cost, $K: Other regulatory AWGRS Job Scope: TUBING WASH/PICKLE None requirements? Sundry Form 10-403 Required? Yes Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Spencer Morrison Contact numbers: (907) 564-5773 (713) 557-281 Well Intervention Engineer: Contact numbers: No Data No Data Lead Engineer: Chris Stone Contact numbers: (907) 564-5518 (907)440-401 Date Created: April 6, 2015 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate FTP or Injectic Date Pressure (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Cut(%) (Mscf/Day) (psi) 4/5/2015 227,085 3,560 Current Status: Operable Flowing Inclination>70°at Depth (ft) Maximum Deviation (Angle and Recent H2S (date, ppm) NA 0 ppm Depth) 31° 8,600' MD Datum depth,ft TVDss 8,800' TVDss Dogleg Severity(Angle and Depth) 4° 6,100' MD Reservoir pressure(date, psig) 3,400 psi Minimum ID and Depth 5,770'1@ 8,053' Reservoir Temp, F 130° F Shut-in Wellhead Pressure 2,400 psi Known mech. integrity None, has passing MIT-IA and MIT-T problems(specifics) Last downhole operation(date, operation) 8/10/2013 Pressure test for integrity, set plug for pressure test Most recent TD tag (date,depth, 7/29/2009 8,931' MD 4.25"centralizer toolstring OD) Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, WGI-07 has had 2 successful water washes. The most recent being on 12/26/2011 with 196 bbls D/X and background information, 400 bbls of 90 F FW with .02% F-103 surfactant at a rate of 5 BPM. The earlier water wash was on etc: 11/10/2006 where 743 bbls of FW at 110 F was pumped at 5 BPM. These water washes were 5 years apart and the one after 5 years was a successful water wash. It has peen ai. ,t 4 years since me last water wasn ana i expect ,same results. This summer there will be an NGI restoration project that will include significant down time for the NGI wells. I have included the tentative schedule below.To reduce the impact of having the NGI wells shut in for work, water washes are needed on good candidates on AGI and WGI. NGI Restoration schedule: 1.Well lateral line work starts April 15 when we will take 2 NGI wells down at a time for repairs lasting 7-9 days per set. We will start with wells 13/14 and work south until complete with pre-TAR scope. 2. Starting on June 26th we will take down NGI wells 1-12 to support blinding and repairs in the vicinity of FV6302/6203 for 9 days-This is outage one. 3. Following outage one and roughly on July 4th we will restart NGI wells 8-12 (13 and 14 were already on line)and wells 1-7 will remain down for approximately 30 days for outage 2. 4. Following completion of outage 2 we will restart wells 1-7 and take down NGI wells 8-14 and begin repairs on the north end of NGI headers/laterals. This is outage 3 and duration is roughly 30 days. 5. Following outage 3 we will need to restart NGI wells 11-14 and take down NGI wells 1-10 to allow for blind removal at FV6302/6203. This is outage 4 and I estimate 2 days for this outage. 6. Finally we then will restart all of the NGI pipelines and wells that were down for blind removal and be back to normal with repairs in place. This is the base schedule and if we find additional corrosion damage the extends our scope of work then we could have some wells off line for longer duration. If the water washes go to plan, we will improve injectivity by dissolving salts and possibly asphaltenes in • the tubing and formation. Diesel/Xylene washes have been used 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 injectivity by cleaning the tubing and perforations 2 3 Key risks,critical issues: Mitigation plan: 1 2 3 Summary Service Line Activity Step# 1 Pump Water Wash as per attached template 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) BOPD: MMSCFD: BWPD: Expected Production Rates: 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: TREE= CNV WELLHEAD= McEVOY ��' O S. I NOTES: WELL REQUIRES A SSSV. DO NOT ACTUATOR= BAKER C PRESSURE OA ABOVE 3000 PSI. KB.ELEV= 61' BF.ELEV= KOP= 5800' 13-3/8"CSG, -J 66' 1-1—/1 J 1 1 ! I Max Angle= 31°@ 8600' 684, K-55 XO 144 ; 2175' 7-5/8"X 7"XO, ID=6.253" Datum MD= 9199' TO L-80 BTC /•.4 •• 2190' —17"DB-6 NIP,ID=6.0" Datum TVD= 8800'SS ,14 '. 20"CONDUCTOR,91.5#, H-40,ID=19.124" 119' ►'f' . -11 2208' —17"X 7-5/8"XO, ID=6.253" 9-5/8"CSG,47#, L-80 HYD 563 XO -1 2585' ?.' 1 TO L-80 BTC ��� .. 2585' —9-5/8"BTC ES CEMENTER 11' • 9-5/8"BOWEN CSG PATCH,47#, — 2629' ��' �' 2603' 9-5/8"BKR ECP, ID=6.861" L-80 BTC, ID=8.681" 13-3/8"CSG,68#,L-80 BTC, ID=12.4151-1 3485' I\ ,_---------- 7973' —17-5/8"X 7"XO, ID=6.253" 7-5/8"TBG,29.7#,L-80 VAM TOP, —I 7973' .0459 bpf,ID=6.875" , ' 7988' —17"HES R NIP, ID=5.963" Minimum ID = 5.770" @ 8053' z 8019' —19-518"X 7"S-3 BKR PKR,ID=6.000" 7" HES RN NIPPLE 8053' 1-1 7"HES RN NIP, ID=5.770" 8075' _-17-5/8"BKR MILLOUT EXTENSION, ID=6.625" 7"TBG,264,L-80 TCII, .0383 bpf,ID=6.276" —I 8080' v- 8080' -17"WLEG, ID=6.253" TOP OF 7"LNR —I 8085' 8085' —I9-5/8"X 7"BOT HYD II HGR 9-5/8"CSG,47#,L-80 BTC-M, —1 8394' .0732 bpf, ID=8.681" PERFORATION SUMMARY , REF LOG: FINAL CNP ON 03/30/90 I ANGLE AT TOP PERF:30°@ 8403' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE I 3-3/8" 4 8403-8447 0 05/31/90 3-3/8" 4 8504-8547 0 05/31/90 3-3/8" 4 8554-8574 0 05/31/90 I 3-3/8" 4 8580-8747 0 05/31/90 3-3/8" 4 8754-8799 0 05/31/90 3-3/8" 4 8803-8852 0 05/31/90 I 3-3/8" 4 8857-8887 0 05/31/90 3-3/8" 4 8892-8896 0 05/31/90 I 3-3/8" 4 8899-8906 0 05/31/90 3-3/8" 4 8911-8927 0 05/31/90 ilk 8937' —IFISH: FASDRILL DEBRIS(07/24/09) PBTD — 8958' 111111111 1 X1111111/11111111 7"LNR,29#, L-80 BTC-M, .0371 bpf, ID=6.184" —I 9000' '•••••••• DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/23/90 D9/N2ES ORIGINAL COMPLETION WELL: WGI-07 07/24/09 N4ES RWO PERMIT No: 1900400 07/26/09 PJC DRLG HO CORRECTIONS API No: 50-029-22031-00 07/30/09 MN/JMD DRLG DRAFT CORRECTIONS SEC 11,T11 N,R14E,846'FNL&1085'FEL 09/28/09 MN/JMD DRAWING CORRECTIONS 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE , BP Exploraltion (Alaska) 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. I ~0- 0~) ~i~ ~.m~r o~ W~, ~i~or~ ~i~ 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:~ Bren Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Beverly Bren Vincent Nathan Lowell Date: Is~ NOTScanned.wpd • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 EIS FEB 2 2 2012 Mr. Tom Maunder ( b - 014-0 Alaska Oil and Gas Conservation Commission - I 333 West 7 Avenue r Anchorage, Alaska 99501 \ l� " 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, M ehreen 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: 09/15/11 Corrosion 1 Initial top of Vol. of cement Final top of Cement top Corrosion inhibitor/ 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 9/15/2011 ' 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 9/15/2011 WGI-09 2061460 500292332700 1.3 NA 1.3 NA 10.2 9/15/2011 ~ MEMORANDUM To: Jim Regg P.I.Supervisor ~J ' ~~~~~~~ (y FROM: Jeff Jones Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, September 10, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI-07 PRUDHOE BAY UNIT WGI-07 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ Comm Well Name: PRUDHOE BAY LTNIT WGI-07 Insp Num: mitJJ090824131940 Rel Insp Num: API Well Number: 50-029-22031-00-00 Permit Number: 190-040-0 Inspector Name: JeffJones Inspection Date: 8~20/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. we~~ WGI-07 TyPe Inj. G' 'j'~ 7833 `~ jA 1500 2200 ~ 2190 2190 ~ P.T.D 1900400 TypeTest SPT Test psi 1958.25 QA i 20 i 20 i 20 20 Interval INITAL ~ p~ _ P ,i Tubing 3640 3640 3640 3640 - I NOtes: 1 BBL 60/40 methanol pumped. 1 well inspected; no exceptions noted ,~ .,~.~`~.~~} ~~~~ ..~. _ ,. ,~~.j4~;; Thursday, September 1Q 2009 Page 1 of 1 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ION REPO T OF SUNDRY WELL OPE~IONS ~~~~iv~~~~~: ~,~~r z ~ zoo~g "°~ 5.,.~ ~ ~~~. ~~ ~r:.4 ~~t~~r'~~6Tltfti~'~i~ir~ 1. Operations Performed: 5 c.~.,':+. $. ' ~ ^ Abandon -~ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ~ Alter Casing ~~ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ 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 190-040 ~ 3. Address: _~ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22031-00-00 _ 7. KB Elevation (ft): 61, 9. Well Name and Number: PBU WGI-07 , 8. Property Designation: 10. Field / Pool(s): _ ADL 028302 - Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 9005' - feet true vertical 8690' - feet Plugs (measured) None Effective depth: measured 8958' feet Junk (measured) 8937' true vertical 8649' feet Casing Length Size MD ND Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 3485' 13-3/8" 3485' 3485' 3450 1950 Intermediate 8394' 9-5/8" 8394' 8162' 6870 4760 Production Liner 915' 7" 8085' - 9000' 7891' - 8686' 8160 7020 °~ i.ti R~~f ~1 ~ ic .~ ic.:~ t~.l t~ = i s ~.~° `) I`~ C? . ~' ~`~' ' Perforation Depth MD (ft): 8403' - 8927' " ` PerForation Depth ND (ft): 8170' - 8622' 7-5/8", 29.7# x 7", 26# x 4-1 /2", 12.6# ~-80 8125' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 7" Baker'S-3' packer 8019' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and fin al pressure: Cut and pulled 7" tubing from ~8055'. Cut, pull and dress off 9-5/8" Casing to -2625'. Run 9-5/8" Tieback to 2629'. Cement w/ 183 Bbls of Class'G' Yield 1.16 . Pull remainin 5-1/2" Tubin . Run 7-5/8" 29.7# x 7", 26#, L-80 tubin to 8080'. ~3. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ~ Copies of Logs and Surveys run 15. Well Class after work: ~ ^ Exploratory ^ Development ~ Service ~ Daily Report of Well Operations 16. Well Status after work: ~ Well Schematic Diagram ^ Oil ^ Gas ^ WAG ~ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mehrdad Nadem, 564-5941 309-207 Printed Name Terrie Hubble Title Drilling Technologist ~ ~~/ / Prepared By Name/Number. Signature Phone 564-4628 Date ~~J ~/ Terrie Hubble 564-4628 Form 10-404 Revised 04/2006 ~ . ~ ~~. µ~,~~ ~ ~ 2~0~ Submit Original Only ~"~~ ~"~ ' ~'l"~~~s . • WGI-07, Well History (Pre Rig Workover) Date Summary 6/20/2009 WELL S/I ON ARRIVAL. RUN 2' 1-7/8" STEM & 6.07' GAUGE RING. TAG DSSSV C~ 2,176' SLM. PULLED 7" DSSSV FROM 2 176' SLM. ALL PACKING INTACT. 6/21/2009 DRIFT W/ 4.41" GUAGE RING & TAG 5-1/2" x 4-1/2" XO Q 8,049' SLM. WELL LEFT S/I, TURN OVER TO WGI OPERATOR. 6/26/2009 WELL SHUT-IN ON ARRIVAL. INITIAL: T/I/O = SSV/460/240, MV=O, SW=C, SSV=C, WV=C, IA/OA=OTG. SPOT EQUIPMENT, RU ELINE FOR TUBING CUT. 6/27/2009 RU ELINE FOR TUBING CUT. POWER JET CUT 5-1/2" TUBING AT 8055', POSITIVE SURFACE INDICATION OF FIRE. RD ELINE. JOB COMPLETE. FINAL T/I/O = 150/280/220 MV=C, SW=C, SSV=C, IA/OA=OTG . WELL SHUT-IN ON DEPARTURE, 7/5/2009 T/I/0= 200/260/180, Temp= S/I. Circ Out well & CMIT TxIAxOA *"PASS'*" to 1000 si Pre RWO . Pumped 10 bbls ambient methanol, 755 bbls 110° seawater, and 130 bbls 50° diesel down the IA threw jet cut at 8035' up the TBG out hardline taking returns to tanks. U-tube diesel for an hour. CMIT TxIAxOA. Pumped 3.9 bbls of 50° diesel down IA to pressure up TxIAxOA. CMIT lost 40/20/0 psi in 1 st 15 minutes and 20/20/0 psi in 2nd 15 minutes for a total loss of 60/40/0 psi in 30 minute test. Bled down WHPs to 0/0/0. FWHP= 0/0/0. Wing, Master, Swab, SSV = Closed, IAV, OAV = Open. 7/6/2009 T/I/O = Vac/0/0 Set 6-3/8" CIW "J" BPV # 422 thru tree, 1-2' ext. used, tagged C~3 108". pre-rig, no problems. 7/6/2009 T/I/0= 10/80NAC. Temp= SI. Bleed WHPs to 0 psi. Assist WH Tech w/ PPPOT. Integral installed on IA. T FL near surface, IA FL ~ surface. Bled IAP from 80 psi to 0 psi in 25 min (all fluid). During bled TP decreased to 0 psi. Assisted WH Tech with PPPOT. Monitored for 30 min. Final WHPs= 0/ONAC. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 7/6/2009 T/IA/OA= 100/50/0 Temp=Sl PPPOT-T (PASS) PPPOT-IC (PASS) PPPOT-T DHD bled WHP to 0 psi. RU 1 HP BT onto THA 0 psi, in void flushed void until clean returns achieved. Pressure void to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bled IC void to 0 psi, cycle and torque LDS "Standard" all were in good working and visual condition, (1) LDS was in out position cycled with no problems, left in correct position, LDS C~ 5:00. RD all test equipment. PPPOT-IC RU 1 HP BT onto IC test void, 0 psi in void. Flushed void until clean returns achieved. Attempted to pressured IC void, would not pressure above 2000 psi, bled void to 0 psi cycle and torqued LDS "Standard" all were good working and visual condition, (2nd) test same results. RU Elephant gun onto packing port re energized secondary seals, void was packed. (3rd) test pressured to 3500 psi for 30 minute test, 3500/ 15 minutes, 3500/ 30 minutes. Bled IC void to 0 psi, RD all test equipment. ~"` Internal checks previously removed "'" ~"' All LDS cycled out 1" ran in and torqued`*' 7/7/2009 T/I/O = 0/0/0 Tested gate of 2 1/16 IA valve to 500 psi. Good test. Removed Intergal flange and replaced with 2 1/16 5K. API flange. Tested to 5000 psi for 15 min. Good test. Page 1 of 1 • ~ BP'~~ EXPLC)RATIQN'~ Page i c~f ~1 '~ Operations Summary Report Legal Well Name: WGI-07 Common Well Name: WGI-07 Spud Date: 3/19/1990 Event Name: WORKOVER Start: 7/8/2009 End: 7/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/24/2009 Rig Name: NABORS 4ES Rig Number: ~ ~ ~ i i i i 7/7/2009 18:00 - 21:00 3.00 MOB P PRE R/D and prepare to move off of D-01 a. Organize units for move. 21:00 - 00:00 3.00 MOB P PRE Move from D pad to WGI pad 7/8/2009 00:00 - 06:00 6.00 MOB P PRE Arrive on location at 05:00 hours, Prep around well for spotting rig. 06:00 - 10:00 4.00 MOB P PRE Lay Mats and spot Rig over WGI-07. Raise and scope up Derrick, RU lines. Rig accepted at 10:00 hrs on 7/8/2009. 10:00 - 11:00 1.00 WHSUR P WHDTRE RU and test lubricator to 500 psi, pull BPV and lay down lubricator. WHP's = Tbg 20 psi, IA 10 psi. 11:00 - 12:00 1.00 WHSUR P WHDTRE RU second annulus vale on the IA, 2" hard line to Choke / Tiger tank and Kill line. Pressure test line to 4,000 psi. 12:00 - 16:00 4.00 KILL P DECOMP Pump 554 bbls 120 Deg F seawater down the tubing"through the Choke to the Tiger tank at 3-4 BPM / 600 psi, recovered a total of -554 bbls at surface. 16:00 - 16:30 0.50 KILL P DECOMP Flow check well for 30 minutes. 16:30 - 18:00 1.50 WHSUR P DECOMP Set and test TWC from above to 4,000 psi and from below to 1,000 psi for 10 charted minutes eac . 18:00 - 18:30 0.50 WHSUR P DECOMP Crew change, Rig Service, Derrick Inspection, Set and Test PVT's 18:30 - 20:30 2.00 WHSUR P DECOMP N/D Tree and Adaptor Flange, remove from cellar. Inspect hanger threads and function Lock Down Screws. LH Acme lifting threads are bad, could not screw XO into hanger. 20:30 - 22:00 1.50 BOPSU P DECOMP Remove lower air boot flange from top of Hydril to provide clearance for lifting BOP stack over hanger neck. 22:00 - 00:00 2.00 BOPSU P DECOMP N/U DSA, BOP Stack, Kill Line and Choke Line. 7/9/2009 00:00 - 01:00 1.00 BOPSU P DECOMP Re-install lower air boot flange from top of Hydril. 01:00 - 02:00 1.00 BOPSU P DECOMP M/U BOP test assemblies. Fill BOPE with water and purge air. 02:00 - 06:00 4.00 BOPSU P DECOMP Test Choke Manifold Blinds 7" Rams Manual Choke, HCR Choke, Manual Kill, HCR Kill, Floor Valves, to 250 psi low and 4,000 psi high. Test Hydril Annular to 250 psi low and 3,500 psi high. Used 7" Test Joint on Rams and 3-1/2" Test Joint on Annular. Each test was held for 5 charted minutes. Perform Bleed down test on Koomey System. AOGCC witness of test was waived by John Crisp. Test was witnessed by Nabors Toolpusher and BP WSL. 06:00 - 07:30 1.50 BOPSU P DECOMP R/U Dutch system to top of Annular preventor. 07:30 - 08:30 1.00 WHSUR P DECOMP R/U and test lubricator to 500 si, DSM ull TWC and la down u ricator. 08:30 - 09:00 0.50 WHSUR P DECOMP Crew change, Rig Service, Derrick Inspection, Set and TesY PVT's 09:00 - 11:00 2.00 PULL P DECOMP PU / MU 7" Spear with TIW safety valve. Pump out BOP stack to void of fluid. Engage Spear and comfirmed set in the first joint below tubing hanger with 25 K PUW. IA static, Cameron rep BOLDS. Pull 7" tubing with Spear at 210 K, SOW 175 K. Well is static. BO / LD 7" Spear assembly and tubing hanger. 11:00 - 12:30 1.50 PULL P DECOMP MU TIW valve with XO and circulate bottoms up at 5.5 bpm / 300 psi. RU floor to lay down 7" tubing with Dual-control line. 12:30 - 16:00 3.50 PULL P DECOMP ~ POH and la down 52 'oints of 7" tubin and Dual-control line. UD SSSV. Recovered 53 control line bands. 16:00 - 16:30 0.50 PULL P DECOMP R/D Camco control line spooler and remove from floor. 16:30 - 00:00 7.50 PULL P DECOMP POOH laying down 7" LTC completion. Tubing was in good condition. 7/10/2009 00:00 - 00:30 0.50 PULL P DECOMP Crew change, rig service, derrick inspection, set and test Printed: 7/29/2009 3:05:31 PM ! ~ ar c~rwrtr~: i ~viv ~-~yc ~ Operations Summary Repor# Legal Well Name: WGI-07 Common Well Name: WGI-07 Spud Date: 3/19/1990 Event Name: WORKOVER Start: 7/8/2009 End: 7/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/24/2009 Rig Name: NABORS 4ES Rig Number: i i i i i i i 7/10/2009 00:00 - 00:30 0.50 PULL P DECOMP PVT's. 00:30 - 01:30 1.00 PULL P DECOMP POOH laying down 7" LTC completion. Tubing was in good condition. Recovered 196 joints of 7", 7" x 5-1/2" XO and 1.66' cut joint of 5-1/2" tubing. 01:30 - 02:00 0.50 BOPSU P DECOMP Install ancake st le test lu and test to 1,000 si from above. 02:00 - 04:00 2.00 BOPSU P DECOMP Remove 7" rams from BOP stack and re lace with 2-7/8" x 5" VBR's 04:00 - 06:00 2.00 BOPSU P DECOMP M/U 3-1/2" test assembly and test VBR's to 250 psi low and 4,000 psi high. Test Hydril to 250 psi low and 3,500 psi high and test door seals to 250 psi low and 4,000 psi high. 06:00 - 11:00 5.00 CLEAN P DECOMP PU / MU 8-1/8" bit, Boot basket, 9-5/8" csg scraper, bit sub, 6-1/4 bumper sub, XO, 6 ec 6-1/4" DC's, XO, XO. PU 3-1/2" DP and RIH to 4,034'. 11:00 - 12:00 1.OQ CLEAN P DECOMP Cirrculate bottms up 5.5 BPM /650 psi. 12:00 - 12:30 0.50 CLEAN P DECOMP Crew change from town, rig service, derrick inspection, set and test PVT's. 12:30 - 13:30 1.00 CLEAN P DECOMP POH from 4 034' with 9-5/8" scra er assembly. 13:30 - 15:00 1.50 CLEAN P DECOMP BO / LD 9-5/8" scraper assembly. 15:00 - 16:30 1.50 EVAL P DECOMP PU / MU HES 9-5/8" RTfS and 3 more 6-1/4" DC's from pipe shed 16:30 - 18:30 2.00 EVAL P DECOMP RIH with 9-5/8" RTTS to 2,586' 18:30 - 19:30 1.00 EVAL P DECOMP Set HES 9-5/8" RTTS at 2,658' and test below to 4,000 psi for 30 minutes on the chart. Good test 19:30 - 20:00 0.50 EVAL P DECOMP R/D circulating line and release HES 9-5/8" RTTS, Let elements relax. 20:00 - 21:00 1.00 EVAL P DECOMP POOH with HES 9-5/8" RTTS standing back 3-1/2" DP in derrick. 21:00 - 21:30 0.50 EVAL P DECOMP Crew change, rig service, derrick inspection, set and test PVT's. 21:30 - 22:00 0.50 EVAL P DECOMP L/D 9-5/8" RTTS. Slips and elements were intact. 22:00 - 00:00 2.00 EVAL P DECOMP R/U Lubricator and sheaves for Schlumberger E-line. 7/11l2009 00:00 - 02:00 2.00 EVAL P DECOMP Run USIT log from 3,800' to surface in cement mode. 02:00 - 03:30 1.50 EVAL P DECOMP R/U Schlumberger E-line unit and lubricator. 03:30 - 04:00 0.50 EVAL P DECOMP Wait on decission on depth to cut 9-5/8" casing and to set 9-5/8" RBP. 04:00 - 06:00 2.00 CASE P DECOMP M/U HES 9-5/8" RBP and RIH with 3-1/2" DP from derrick. 06:00 - 06:30 0.50 CASE DECOMP Crew change, rig service, derrick inspection, set an test PVT's. 06:30 - 08:00 1.50 DHB P DECOMP Set 9-5/8" RBP at 2,722' MD, POH 6 joints and pressure test to 1 000 si 1.0 bbis for 10 charted minutes. an W= 63 K. 08:00 - 12:00 4.00 DHB P DECOMP f 20 / 40 mesh river sand down DP on to of RBP -50' . Pump 17 bbls seawater to clear drill string. 12:00 - 14:00 2.00 CASE P DECOMP Cut and slip Drilling line. 14:00 - 16:00 2.00 CASE P DECOMP Ta to of sand at 2,666'. POH and L/ D RBP running tool. 16:00 - 20:30 4.50 BOPSU P DECOMP ND and remove the 13-5/8" X 11" 5K McEvoy Gen - 4 tubing s ool and D A wit ameron re . arriers are p ug at 8,113' and 9-5/8" RBP at 2,722' 20:30 - 22:30 2.00 BOPSU P DECOMP N/U BOP stack, Choke and Kill lines 22:30 - 23:00 0.50 BOPSU P DECOMP Test breaks on BOPE / Wellhead to 1,000 psi for 10 minutes, Good test. 23:00 - 00:00 1.00 CASE P DECOMP M/U BHA #2, 8-1/4" Multi-string cutter, XO, 8-1/2" Stablizer, XO, (9) 6-1/4" DC's, XO, XO. Total BHA Length = 287.31' Printed: 7/29/2009 3:05:31 PM ~ ! BP EXPLORATIUN Page 3~f 1 y Operations Summary Re~ort Legal Well Name: WGI-07 Common Well Name: WGI-07 Spud Date: 3/19/1990 Event Name: WORKOVER Start: 7/8/2009 End: 7/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/24/2009 Rig Name: NABORS 4ES Rig Number: I ~ I 1 I ~ I', 7/12/2009 00:00 - 01:00 1.00 CLEAN P DECOMP RIH with BHA #2 on 3-1/2" DP from derrick. Tag Top of Sand at 2,666'. 01:00 - 02:00 1.00 CLEAN P DECOMP P/U Kelly and establish parameters, P/U 65K, S/O 65K, Rotating Weight 65K, 3 bpm with 250 psi. Locate bottom coliar at 2,654' and upper collar at 2,614. Space out to cut 10' below upper collar. Cut will be ai 2,624'. 02:00 - 03:00 1.00 CLEAN P DECOMP Displace well to 9.8 ppg brine at 5-1/2 bpm 950 psi. 03:00 - 04:00 1.00 CLEAN P DECOMP Cut 9-5/8" Casing at 2,624'. Bring rotary up to 80 rpm at 1,800 fUlbs, bring pump on line 3 bpm at 250 psi, raising pump rate to 5-1/2 bpm with 1,000 psi. Rotary torque going to 5,000 fUlbs at 80 rpms. Lost 60 psi of pump pressure and Rotary torque dropped to 3,000 Wlbs. Showing 200 psi on the 9-5/8" x 13-3/8" Annulus 04:00 - 06:00 2.00 CLEAN P DECOMP Pump 125 bbls of 120 degree diesel down the DP then close bag to force it into the 9-5/8" x 13-3/8" annulus at 1-1/2 bpm with 250 psi. Good returns out the annulus. Arctic Pack appears to be dead crude. 06:00 - 10:00 4.00 CLEAN P DECOMP Let diesel soak for -1 hour, displace 9.8 ppg Brine with heated seawater at 2 bpm. Pump 40 bbls Safe-Surf-O down DP and displace with seawater. Flow check well. Blow down lines. 10:00 - 12:00 2.00 CLEAN P DECOMP POH with 9-5/8" csg-cutter from 2,624', rack 3-1/2" DP in Derrick. BO / LD csg-cutter. 12:00 - 14:00 2.00 CLEAN P DECOMP Clean and clear Rig after Arctic Pack job. 14:00 - 15:00 1.00 CLEAN P DECOMP Held weekly safety meeting. 15:00 - 16:00 1.00 CASE P DECOMP PU / MU 6-1/4" spear / packoff for 9-5/8" 47# csg, 8-1/4" Itco spear w/ Bull nose, Spear eMension, spear stop sub, 6-1/4" Bumper jar. 16:00 - 18:00 2.00 CASE P DECOMP En a e s ear in 9-5/8" casin , BOLDS with Cameron rep, unseat hanger with 140 K PUW, pull to Rig floor with 120 K PUW, remove casing slips, LD first joint with Spear. 18:00 - 19:00 1.00 CASE P DECOMP Circulate bottoms up 5-1/2 bpm with 190 psi. 19:00 - 00:00 5.00 CASE P DECOMP POOH la in down 9-5/8" L-80 BTC casin the casing was in good condition. Recovered 61 joints, Triple Connect, Upper Cut joint of 9-5/8" casing 27.80', lower cut joint of 11.57' and one bow type centrilizer on joint below Triple connect. 7/13/2009 00:00 - 01:00 1.00 CASE P DECOMP R/D casing handling equipment. 01:00 - 02:00 1.00 CASE P DECOMP Clean up rig floor and equipment. 02:00 - 03:00 1.00 CASE P DECOMP Hold weekly safety meety with rig crew. Discussed BP, Nabors and IADC stats. Discussed attitudes affecting safety. 03:00 - 05:00 2.00 CASE P DECOMP P/U and M/U BHA #3, BHA = Dress Off Shoe, Extension, Inner Mill, W/O Boot basket, XO, 13-3/8" Casing Scraper, Bit Sub, Float Sub, Bumper Sub, XO, (6) 6-1/4" DC's, XO, XO. Total BHA Length = 308.29' 05:00 - 06:00 1.00 CASE P DECOMP RIH with BHA #3 on 3-1/2" DP from the derrick. 06:00 - 09:00 3.00 CASE P DECOMP Ta at 2,624'. Dress-off 9-5/8" cs to 2 625'. PUW / SOW / FRWT = 67 K, 60/80 RPM, 3-7 K WOB, 3-5 BPM / 340 PSI. 09:00 - 11:00 2.d0 CASE P DECOMP Pumped 40 bbls Safe-Surl-O surface to surface and 20 bbls Flow-Vis sweep surface to surface. Flow check well. 11:00 - 13:00 2.00 CASE P DECOMP POH from 2,625' with dress-off assembly, stand 3-1/2" DP in Derrick. 13:00 - 14:00 1.00 CASE P DECOMP BO/LD BHA #3 14:00 - 15:30 1.50 CASE P DECOMP Clear and clean rig floor 15:30 - 17:30 2.00 CASE P TIEB1 RU to Run 9-5/8" csg patch. Printed: 7l29f2009 3:05:31 PM • . _ __ BP EXRLQRATiC}N' Pag~e 4 af 1 ~ Qperations Summary Report Legal Well Name: WGI-07 Common Well Name: WGI-07 Spud Date: 3/19/1990 Event Name: WORKOVER Start: 7/8/2009 End: 7/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/24/2009 Rig Name: NABORS 4ES Rig Number: Da#e From - TQ Hours Task Code NPT Phase D~scription of Operatit~ns 7/13/2009 17:30 - 00:00 6.50 CASE P TIEB1 Run 9-5/8" #47 L-80 H dril 563 Tieback. Ran Patch ECP ES cementer, and 68 joints of 9-5/8" casing. Ran centrilizers on joints 1-67. P/U 119K, S/O 119K. Tag top of casing stub at 2,625'. Set 25K onto stub, P/U 30K to engage grapples, Pull test patch to 250K. 7/14/2009 00:00 - 01:00 1.00 CASE P TIEBi R/U and ressure u on 9-5/8" casin to 1,000 si for 10 minutes on the chart, ood test. O en ECP and fill, o ened at 1,550 si, Pressure u to 2,000 psi for 10 minutes on the chart, good test. Pressure up and shear open ES Cementer. Opened at 2,800 psi. ~ 01:00 - 02:30 1.50 CEMT P TIEB1 Circulate heated seawater around at 5-1/2 bpm with 180 psi. Circulate till 80 de ree seawater returns. Hold PJSM for cement job with alf parties involved. 02:30 - 04:00 1.50 CEMT P TIEBi R/U lines and pump 5 bbis of seawater, pressure test to 4,000 psi, pump 183 bbls of 15.8 ppq, yield 1.16 ft3/sk, 867 sks Class G cement. drop plug and displace with seawater at 7-1/2 bpm with 200 psi, caught cement at 83 bbls of displacement, 7-1/2 bpm with 600 psi. Cement to surface at 173 bbls of dis lacement. Bum ed lu at 192 bbls of dis lacement. Pressure u to 2,220 si to close ES cementer. Bleed off pressure and check floats, floats are holding. CIP at 03:45 hours. Apox 19 bbls of cement back to surface. 04:00 - 05:00 1.00 CEMT P TIEB1 R/D cementers, Flush lines and valves. 05:00 - 06:00 1.00 WHSUR P TIE61 Split BOP stack and raise off of spool. 06:00 - 11:30 5.50 WHSUR P TIEB1 Set 100K on slips and cut 9-5/8" at the csg head with "Wach-cutter" and UD 23.96" of joint #68. 11:30 - 13:30 2.00 BOPSU P TIEBi NU BOP to tbg spool and install second annulus valve. • 13:30 - 14:30 1.00 BOPSU P TIE61 Test 2-7/8" X 5" VBR with 3-1/2" test joint and Blind rams to test kill and choke line, 250 psi / 4,000 psi or 5 charte minutes. Install wear ring. AOGCC witness of test was waived by Jeff Jones. Test witnessed by WSL & TP. 14:30 - 18:00 3.50 DRILL P TIE61 M/U BHA #4: -Used 8-1/2" bit, (3) 7" Boot baskets, Bit sub, -6 1/4" Bumper sub, XO, (9) 6 1/4" D.C's, XO & XO. 18:00 - 18:30 0.50 DRILL P TIEB1 Service Rig. Test PVT alarms. Inspect derrick. 18:30 - 19:30 1.00 DRILL P TIEB1 RIH w/ BHA # 4. Wash last Std to bottom. -Ta top of cement @ 2,554' md. 19:30 - 22:30 3.00 DRILL P TIEB1 Kelly up. Obtain parameters: -PUW 63k, SOW 64k, ROT wt 65k. 198 gpm / 260 psi. -WOB 5-10k. 70 RPM / 2k Tq. -Drill green cement f/ 2,554' to ES Cmtr C~3 2,585' md. -Drill ES Cmtr & cement stringers to 2,666' md. -Dry drill on sand to 2,673' md. 22:30 - 00:00 1.50 DRILL P TIEB1 Circulate & condition fluid. -Pump 40 bbl Hi Vis Sweep. 101 gpm / 300 psi. 7/15/2009 00:00 - 01:00 1.00 DRILL P TIEB1 Stand back kelly; monitor well - static. POOH. 01:00 - 02:00 1.00 DRILL P TIEB1 LD BHA #4: -8-1/2" bit, (3) 7" Boot baskets, Bit sub, -6 1/4" Bumper sub, XO, (9) 6 1/4" D.C's, XO & XO. 02:00 - 03:00 1.00 DRiLL P TIE61 Clean out Boot baskets, clean and clear Rig floor. -Retrieved 2-1/2 gallons of Cmt cuttings from baskets. 03:00 - 04:00 1.00 DRILL P TIEB1 PU/MU BHA #5: Printed: 7/29/2009 3:05:31 PM • ~ BP EXRLORATEQN Page 5 of 11 Qperations Summary R+epc~rt Legal Well Name: WGI-07 Common Well Name: WGI-07 Spud Date: 3/19/1990 Event Name: WORKOVER Start: 7/8/2009 End: 7/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/24/2009 Rig Name: NABORS 4ES Rig Number: Date Fram - Tc~ Hours Task G~de NPT Phase De~cription of Operations 7/15/2009 03:00 - 04:00 1.00 DRILL P TIE61 -7 7!8" RCJB, (3) 7" Boot baskets, 9 5/8" Csg scraper, -Bit sub, 6 1/4" Bumper sub, XO, (9) 6 1/4" D.C's, -XO & XO. 04:00 - 06:30 2.50 DRILL P TIEB1 RIH with BHA #5 on 3-1/2" DP to 2,673' md. -Wash to 2,683' md. -Pump 20 Hi-Vis sweep 147 gpm / 1,200 psi 06:30 - 07:00 0.50 DRILL P TIEB1 Service Rig. Check alarms. Inspect Derrick. 07:00 - 08:30 1.50 DRILL P TIEB1 POH from 2,683' md with BHA #5 to 309' md. 08:30 - 09:30 1.00 DRILL P TIEB1 Service Junk baskets. -Recovered 3.5 gallons sand with rubber. -Large metal - 14" long X 1.25". 09:30 - 15:00 5.50 DRILL P TIEB1 Make second run with BHA #5 (W/O Csg scraper) -RIH tag ~ 2,683' md. -Wash & rotate down to 2,698' md w/ RCJB. -Circulate 20 bbl Hi-Vis Sweep. -168 gpm / 1650 psi. -POH. -Recoverd: 2 gallons of sand, cement and rubber. 15:00 - 16:00 1.00 DRILL P TIEB1 LD BHA #5: -7 7/8" RCJB, (3) 7" Boot baskets, -Bit sub, 6 1/4" Bumper sub, XO, (9) 6 1/4" D.C's, -XO & XO. -Clean out Junk baskets. Clear Rig floor. -Recovered 1/2 gallon of Cmt & small metal pieces. 16:00 - 18:00 2.00 DRILL P TIEBi Pressure Test 9-5/8" casing. -Test to 4,000 si for 30 charted minutes. Pass. -Volume required (3.17 bbis) 18:00 - 18:30 0.50 DRILL P TIE81 Service Rig. Check alarms. Inspect Derrick. 18:30 - 19:00 0.50 DRILL P TIEB1 PU & RIH w/ RBP runnin Tool on 3 1/2" DP. -RIH to 2,698' md. 19:00 - 20:30 1.50 DRILL P TIEB1 Reverse circulate 25 bbl Hi Vis Sweep. -Wash down from 2,698' to 2,717' md. -Reverse sand off the top of the RBP. -210 gpm / 660 psi. 20:30 - 21:00 0.50 DRILL P TIEB1 J- in and release RBP. 21:00 - 23:00 2.00 DRILL P TIE61 POH w/ RBP on 3 1/2" DP from 2,717' md. -LD RBP. 23:00 - 00:00 1.00 DRI~L P TIE61 Clear Rig floor of RBP & running Tool. -Clean Rig floor. 7/16/2009 00:00 - 02:00 2.00 FISH P TIEB1 PU/MU BHA #6: -Bowen "C" Dimension Spear, 6-1/4" LBS, -6-1/4" Oil jar, Pump-out sub, XO sub, -(9) 6-1/4" D.C's, XO sub, Accelerator jar & XO sub. -Total length = 315.27'. RIH. 02:00 - 02:30 0.50 FISH P TIE61 PJSM for PU 3-1/2" DP singles from pipeshed and RIH. 02:30 - 05:30 3.00 FISH P TIEB1 RIH w/ BHA #6 on 3-1/2" DP. PU sin les from ipeshed to top of fish ~ 8,055' md. 05:30 - 07:00 1.50 FISH P TIEB1 Spear fish consisting of: -Remainder of 5-1/2" tubing stub and seal assembly. -Establish circulation. 07:00 - 08:00 1.00 FISH P TIE61 CBU at 210 gpm / 1,060 psi. 08:00 - 11:30 3.50 FISH P TIEB1 POH from 8,055' md to surface. Printed: 7/29/2009 3:05:31 PM • ~ BP EXPLOR~4TIfJN Page 6 of 11 ~perations Summary Report Legal Well Name: WGI-07 Common Well Name: WGI-07 Spud Date: 3/19/1990 Event Name: WORKOVER Start: 7/8/2009 End: 7/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/24/2009 Rig Name: NABORS 4ES Rig Number: Qate From - TQ Hours Task Gode NPT Phase D~scription of Op~ratians 7/16/2009 11:30 - 12:30 1.00 FISH TIEB1 LD spear with fish from BHA #6. -Recovered (4.50' Pin end) of the 5-1/2" pup. -Seal assembl to is (~ 8,060' m. 12:30 - 13:30 1.00 BOPSU P TIEB1 Pull Wear ring. RU to test BOPE. 13:30 - 18:00 4.50 BOPSU P TIE61 Test BOP's and related equipment. -Test to BP & AOGCC rocedures & re ulations. -BOP configuration: -13 5/8" Hydril GK 5000. -Blind Shear Rams. -Spacer spool. -2-7/8" X 5" Variable Bore Rams. Test Choke Manifold, Blinds, 2-7/8" X 5" VBR's, -Manual Choke, HCR Choke, Manual Kill, HCR Kill, -Floor Valves. -Test to 250 psi low and 4,000 psi high. -Test Hydril Annular to 250 psi low and 3,500 psi high. -Used 3-1/2" Test Joint on Rams and Annular. -Each test was held for 5 charted minutes. 18:00 - 18:30 0.50 BOPSU P TIEB1 Service Rig. Test alarms. Inspect Derrick. 18:30 - 19:30 1.00 BOPSU P TIEB1 Continue BOP test: -Perform Draw-Down test on Koomey System. -200 psi build up = 46 seconds. -Full pressure = 171 seconds. -4 bottles X 1700 psi. -AOGCC witness of test was waived by Chuck Scheve. -Test was witnessed by Nabors TP and BP WSL. -All tests Pass. RD test equipment. 19:30 - 20:30 1.00 FISH P TIEB1 Pull Test plug. install Wear ring (9 1/8" ID). 20:30 - 22:00 1.50 FISH P TIEB1 PU BHA #7: -Bowen "C" Dimension Spear, 6-1/4" LBS, -6-1/4" Oil jar, Pump-out sub, XO sub, -(9) 6-1/4" D.C's, XO sub, Accelerator jar & XO sub. -PU BHA to 315' md. 22:00 - 00:00 2.00 FISH P TIEB1 RIH w/ BHA #7 on 3 1/2" DP from 315' to 7,976' md. 7/17/2009 00:00 - 01:00 1.00 FISH P TIEB1 PU 2 singles from 7,976' to 8,040' md. -Kelly up. Obtain parameters: PUW 138k, SOW 123k. -Work down. Tag Fish (~ 8,055' md. -En a e Fish Seal assembl . 01:00 - 01:30 0.50 FISH P TIEB1 Jar Fish free. - arre up o 12k over (250k). -50 hits required to free Fish. 01:30 - 03:00 1.50 FISH P TIE61 Circulate bottoms up. -210 gpm / 1080 psi. -Stand back Kelly. 03:00 - 06:00 3.00 FISH P TIEB1 POH w/ FISH from 8,055' to BHA C~ 315' md. 06:00 - 06:30 0.50 TIEB1 Service Rig. Test alarms. Inspect Derrick. 06:30 - 08:00 1.50 FISH P TIEB1 Resume POH to BHA #7. 08:00 - 09:30 1.50 FISH P TIEB1 LD Seal assembly. -Clean and clear ig floor. 09:30 - 11:30 2.00 FISH P TIEB1 MU BHA #8: -8 1/2" PRT-(3) 7" Boot baskets, Bit sub, Printed: 7/29/2009 3:05:31 PM • • BP EXPLQRATIQN Page ~ of 1~ i ; Qperations Summary Repor# Legal Well Name: WGI-07 Common Well Name: WGI-07 Spud Date: 3/19/1990 Event Name: WORKOVER Start: 7/8/2009 End: 7/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/24/2009 Rig Name: NABORS 4ES Rig Number: ' Date Fr4m - To Hcaurs Task Cad~ NPT Phase Deseription of Operations 7/17/2009 09:30 - 11:30 2.00 FISH P TIE61 -6 1/4" Bumper sub, 6 1/4" Oil jar, pump out sub, XO, -(9) 6 1/4" D.C's, XO, Acc Jar, XO. = 328.59 11:30 - 14:00 2.50 FISH P TIE61 RIH with Mill out assembly to 8,040' md. 14:00 - 18:30 4.50 FISH P TIE61 Mill on 9 5/8" Packer ~ 8 040' md. -PUW=136K, SOW=122K, FRW=125K. -WOB=(0-15K), RPM=60-80, TQ=2,400 fUlb. -168 gpm / 730 psi. -Mill to 8,043' md. Push Pkr to Liner Top C~3 8,085' md. 18:30 - 19:00 0.50 FISH P TIEB1 Fill hole w/ Seawater initial loses ~ 90 bbls/hr. -Bull head 100 bbls of Seawater. -ICP = 126 gpm / 510 psi. FCP = 252 gpm / 1290 psi. -Observe well, losses ~ 42 bbls/hr. 19:00 - 20:30 1.50 FISH P TIE61 CBU 252 gpm / 1350 psi. -Observe well, loses ~ 40 bbls / hr. 20:30 - 22:00 1.50 FISH P TIE61 Re-tag bottom w/ Fishing assembly. -Final no-go at 31' DOK, which is 8,065' md. -Standback Kelly -POH w/ Fishing assembly. -Experienced 30K overpull on second stand out. 22:00 - 00:00 2.00 FISH P TIEB1 -POH w/fish. -POH w/ 3 1/2" DP from 7,885' to 5,000' md. 7/18/2009 00:00 - 01:30 1.50 CASE P TIEB1 POH w/fish. -POH from 5,000' to 328' md. 01:30 - 03:00 1.50 CASE P TIEB1 LD BHA #8: -8 1/2" PRT-(3) 7" Boot baskets, Bit sub, -6 1/4" Bumper sub, 6 1/4" Oil jar, pump out sub, XO, -(9) 6 1/4" D.C's, XO, Acc Jar, XO. = 328.59 03:00 - 07:30 4.50 CASE P TIEB1 RU Tubing punch and perforate 4 1/2" tailpipe. -Punch tail in several laces. -LD packer and tailpipe assembly. -Retrieve p ug. -recovered 7 gallons metal shavings. 07:30 - 09:00 1.50 CASE P TIE61 Clean and clear Rig floor. 09:00 - 10:30 1.50 CASE P TIE61 MU BHA #9 w/ Dual Csg scrapers: ~ -5 3/4" Bit, 7" sg scraper, i su , s) 3 1/2" DP, -Pin by Pin XO, 9 5/8" Csg scraper, Bit sub, 6 1/4" Oil jar, -XO, (9) 6 1/4" DC's, XO, XO to 458' md 10:30 - t3:00 2.50 CASE P TIEB1 RIH with BHA #9 on 3 1/2" DP to 8,234' md. 13:00 - 13:30 0.50 CASE P TIEB1 Work Scrapers across zones of interest: -Work 9 5/8" Cs scraper (4) X f/ 7,945' to 8,070' md. -Work 7" csg scraper (4) X/ 8,109' to 8,23 m. 13:30 - 17:30 4.00 CASE P TIEB1 Monitor well -16 bph loss rate. -POH w/ BHA #9 from 8,234' md to the BHA ~ 458' md. 17:30 - 18:00 0.50 CASE P TIEBi Lay down BHA: -9 5/8" Csg scraper, Bit sub, 6 1/4" Oil jar, -XO, (9) 6 1/4" DC's, XO, XO to 164' md. 18:00 - 18:30 0.50 CASE P TIEB1 Service Rig. Test alarms. Inspect Derrick. 18:30 - 19:00 0.50 CASE P TIEB1 Continue to LD BHA # 9: -5 3/4" Bit, 7" Csg scraper, Bit sub, (5 Jts) 3 1/2" DP, -Pin by Pin XO. 19:00 - 20:00 1.00 CASE P TIEB1 PU & MU Fas Drill running Tool. -MU Fas Drill on running Tool. Printed: 7/29/2009 3:05:31 PM ~ . BP EXPLC~R~TEON Page 8 caf 11 ' Operations Summary Report Legal Well Name: WGI-07 Common Well Name: WGI-07 Spud Date: 3/19/1990 Event Name: WORKOVER Start: 7/8/2009 End: 7/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/24/2009 Rig Name: NABORS 4ES Rig Number: Date Fr4m - Tca Haurs Task Code NPT Phase '' Description of Operations ~I7/18/2009 20:00 - 23:00 3.00 CASE P TIEB1 RIH w/ Fasdrill on 3 1/2" DP to -7,802' md. ' 23:00 - 00:00 1.00 CASE P TIEB1 PU 6 Jts. of 3 1/2" DP. to -8,150' md. ' -Obtain parameters: PUW 114k, SOW 105k. -Set 7" Fas Drill ~ 8,150' md. -Set w 27 RH tums. -Shear out w/ 150k up weight. -LD 1 Jt of 3 1/2" DP. 7/19/2009 00:00 - 01:30 1.50 CASE P TIE61 RU & test Fas Drill from above. -Test to 1000 psi for 10 charted minutes.-Pass. -RD test equipment. 01:30 - 03:00 1.50 CASE P TIE61 Slip & cut 91' of 1 1/8" Drlg line. -Check brakes. 03:00 - 04:00 1.00 CASE P TIEB1 Sunday safety meeting: -w/ WSL, TP, and Brandenburg's crew. 04:00 - 06:00 2.00 CASE P TIEB1 POH w/ Fas Drill running Tool on 3 1/2" DP. -POH from 8,119' to 4,000' md. 06:00 - 06:30 0.50 CASE P TIE61 Service Rig. Test alarms. Inspect Derrick. 06:30 - 09:30 3.00 CASE P TIEB1 POH w/ FasDrill running tool on 3-1/2" DP. -POH from 4,000' and LD running tool on rig floor. 09:30 - 10:00 0.50 CASE P TIEB1 RU to C/O rams and test BOP breaks. 10:00 - 11:00 1.00 CASE P TIEB1 MU running tool, pull wear ring, and set lower test plugy -Test plug to 1,000-psi for 10 charted minutes. -Pass. 11:00 - 11:30 0.50 CASE P TIEB1 PJSM for changing BOP rams. 11:30 - 14:30 3.00 CASE P TIE61 Chan e BOP i e rams from 2-7/8" X 5" VBR to 7-5/8". -Test 7-5/8" rams to 4,000- si for 5 charted minutes. -Test breaks to 4 000- si for 5 charted minutes. -Witness of test waived by Chuck Scheve AOGCC. 14:30 - 15:30 1.00 CASE P TIE61 Sunday safety meeting: -w/ WSL, TP, and Tinsley's crew. 15:30 - 18:00 2.50 CASE P TIEB1 RU TQ-turn casing equipment to run 7-5/8" tubing. 18:00 - 18:30 0.50 CASE P TIEB1 Service Rig. Test alarms. Inspect Derrick. 18:30 - 19:00 0.50 CASE P TIE61 PJSM for RIH with 7-5/8" tubing. 19:00 - 00:00 5.00 CASE P TIEBi RIH with 7-5/8" Tb assembly to 2,080' md. -MU the (3) -7" bottom jewelry assemblies. -(1)-WLEG, XO, RN nipple w/ RHC-M. -(2)-XO to Pup, S-3 Pkr, Pup. -(3)-Pup, R nipple, Pup & XO. Utilize "Jet Lube Seal Guard" Thread compound. -Optimum Torque: -7", 26#, TCII = 10,100 ft/Ibs. -7 5/8", 29.7#, Vam Top HC = 14,450 fUlbs. 7/20/2009 00:00 - 03:00 3.00 RUNCO RUNCMP Continue to run 7 5/8" Tbg from 2,080' md -RIH with 7-5/8" tubing f/ 2,080' to 3,107' md. Utilize "Jet Lube Seal Guard" Thread compound. -Optimum Torque: -7 5/8", 29.7#, Vam Top HC = 14,450 ff/Ibs. 03:00 - 07:00 4.00 RUNCO RREP RUNCMP Repair Rig: -Air leak in Draw-works clutch assembly. 07:00 - 16:00 9.00 RUNCO P RUNCMP Resume RIH with 7 5/8" Tbe completion assembly. -RIH with 7-5/8" tubing f/ 3,107' md to 8,083'. ~ -Utilize "Jet Lube Seal Guard" Thread compound. -Optimum Torque: Printed: 7/29/2009 3:05:31 PM ~ • BP' EXPLQRAT[QN Page 9 of 11 Qperations Summary Reporf Legal Well Name: WGI-07 Common Well Name: WGI-07 Spud Date: 3/19/1990 Event Name: WORKOVER Start: 7/8/2009 End: 7/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/24/2009 Rig Name: NABORS 4ES Rig Number: Date From - To Hc~urs Task Code NPT Phase Description caf Operations 7/20/2009 07:00 - 16:00 9.00 RUNCO RUNCMP -7 5/8", 29.7#, Vam Top HC = 14,450 ff/Ibs 16:00 - 17:30 1.50 RUNCO RUNCMP Space out to 8,083' md. -RIH with joint # 197 and tag @8,083' md. 17:30 - 18:00 I 0.501 RUN 18:00 - 18:30 0.50 RU 18:30 - 22:30 4.00 RU 22:30 - 00:00 I 1.50 7/21 /2009 I 00:00 - 02:30 I 2.50 02:30 - 03:30 1.00 03:30 - 04:00 0.50 04:00 - 06:00 2.00 06:00 - 07:00 1.00 07:00 - 08:30 1.50 08:30 - 10:00 1.50 10:00 - 11:30 1.50 11:30 - 14:00 I 2.50 -LD joint #197,#196,#195. -MU RIH with pup's 9.93' and 5.89'. -RIH with joint #195. RUNCMP Land tubing hanger at 8,080' md. -Drain BOP stack. -MU and land tubin han er. -PUW 228k. SOW 209k RUNCMP RILDS. RU to Reverse Circulate. -LD Landing Jt. RUNCMP Reverse Circulate down IA: -390 bbls Seawater ~ 130 degrees F. -110 bbls Inhibited Seawater. -126 gpm ~ 260 -280 psi. -After 200 bbls away, take returns through Gas buster, -Returns are aired up and surging ~ Riser. -Gave courtesy call to Chuck Scheve AOGCC.-OK. -Monitor well - Static. RUNCMP RU LRS Hot Oil. -Pressure test lines to 4500 psi. -Pass. -Reverse circulate in: -37 bbls of diesel ~ 80 degrees F. -76 gpm / 380 psi. RUNCMP Dro Ball & Rod to set Packer (1 3/8" fishing neck). -Test w/ LRS / Hot il. -Test Pkr X 7 5/8" Tbg. -Test to 4000 psi f/ 30 charted minutes - Pass. -Bleed to 1500 psi. -Test IA to 4000 si f/ 30 charted minutes - Pass. -Bleed down all pressure. -RD test equipment. RUNCMP Drain Stack. Install TWC. -Test TWC from above to 1000 si / iQ minutes - Pass. RUNCMP PJSM for C/O rams. RUNCMP Chan e Rams to 3 1/2" X 6" variables. -2 barriers are Fas Drill ~ 8,150' md and TWC. -Test breaks to 250 low psi & 4,000 psi high pressure. -Test w/3-1/2" test joint. -All test -Pass. -Chuck Scheve AOGCC waived witness of Ram test. RUNCMP Service rig. Inspect derrick. Check PVTs. RUNCMP RU Dutch s stem & DSM Lubricator. -Test Lubricator to 500 psi - Pass. RUNCMP RU slickline to retrieve ball and rod and RHC-M plug. RUNCMP RIH w/ 2" JUC tool and bell guide to 8,058' md. -Fish ball and rod. -POH and LD ball and rod. RUNCMP C/O tools on slickline. -RIH w/7" GS pulling tool to 8,064' md. -Fish RHC-M olua. Printed: 7/29/2009 3:05:31 PM • • BP EXPLORATf4N ` Page 10 4fi 11 Operations Summary Report Legal Well Name: WGI-07 Common Well Name: WGI-07 Spud Date: 3/19/1990 Event Name: WORKOVER Start: 7/8/2009 End: 7/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/24/2009 Rig Name: NABORS 4ES Rig Number: ~~~~ Date' Fr~m - To Hours Task Cede N~~~~PT Phase '~~~~~ Description of Operatians 7/21/2009 11:30 - 14:00 2.50 RUNCO RUNCMP -Jar three times to free fish. -POH and LD RHC-M plug. 14:00 - 15:00 1.00 RUNCO RUNCMP RD slickline and dutch system. -Clean and clear rig floor. 15:00 - 16:00 1.00 RUNCO RUNCMP MU BHA #10, as follows: -5 11/16" OD Junk Mill, Bit Sub, 6~ 4 3/4" DC's, OJ's. 16:00 - 18:00 2.00 RUNCO RUNCMP RIH w/BHA #10 to 8,150' md and to of FasDrill Plu~. 18:00 - 18:30 0.50 RUNCO RUNCMP Service Rig & Pre Tour Checks 18:30 - 19:30 1.00 RUNCO P RUNCMP Continue RIH to 8,150' md. -85 Stands DP total. 19:30 - 21:00 1.50 RUNCO RUNCMP Mill 7" Fas Drill Plug C~ 8,150' md. -PU 131 k, SO 123k, ROT 125k. ~I - 3 bpm ~ 410 psi. ' -60 rpm ~ 120-150 Amp. 5-8k Tq. -Chase down to 8,168' md. -4 bbl loss C~ 10 min. 21:00 - 22:00 1.00 RUNCO P RUNCMP RIH chasing Fas Drill to 8,900' md. -19' down #280. -Picking up Singles from Pipe Shed. 22:00 - 23:30 1.50 RUNCO P RUNCMP -Continue Chasing Fas Drill to TD. -Rotate throu h Tiqht Spots in Perfs to 8,937'. 23:30 - 00:00 0.50 RUNCO P RUNCMP 24 bbl Pit Gain noticed. -S/I annular and Choke. -Notify Superintendent, AOGCC Rep, Day WSL, 7/22/2009 00:00 - 04:30 4.50 RUNCO P RUNCMP After Notifications, Circulated out Gas. -66 spm ~ 750 psi DP / 1300 psi Cas. -11,974 Stks. -Monitor Well. 04:30 - 06:00 1.50 RUNCO P RUNCMP POH LDDP. -18 Jts. to above top of perfs @ 8,403' md. 06:00 - 07:00 1.00 RUNCO P RUNCMP CBU. -6 BPM, 1620 PSI. -Monitor well for flow; fluid losses = 15-30 BPH. 07:00 - 07:30 0.50 RUNCO P RUNCMP Service rig. Inspect derrick. Check PVTs. 07:30 - 11:30 4.00 RUNCO P RUNCMP POH LD 3-1/2" DP singles. -Jts 19-181 to stand 27 C~ 2,727' md. 11:30 - 13:00 1.50 RUNCO P RUNCMP POH standing back 3-1/2 DP to BHA #10. 13:00 - 13:30 0.50 RUNCO P RUNCMP LD BHA #10. 13:30 - 14:00 0.50 RUNCO P RUNCMP Set TWC. -Test annular reventer used in well control event. 14:00 - 14:30 0.50 RUNCO P RUNCMP Pressure test annular reventer. -Test to 250 psi low and 3,500 psi high. -Test good. 14:30 - 15:00 0.50 RUNCO P RUNCMP RU DSM lubricator and rig Dutch system. 15:00 - 15:30 0.50 RUNCO RUNCMP Pull TWC. 15:30 - 18:00 2.50 RUNCO RUNCMP RU slickline to RIH w/RN plug to 8,053' md. 18:00 - 18:30 0.50 RUNCO RUNCMP Service Rig. Inspect Derrick. Check alarms. 18:30 - 20:00 1.50 RUNCO RUNCMP RU Slick line. -Discuss testing Lubricator & Rams. -Call out Cameron to set TWC. -Stand back Slick line BOP's. Printed: 7/29/2009 3:05:31 PM • ~ BP E~CPLORATION Page 11 of 11 Operations Summary Report Legal Well Name: WGI-07 Common Well Name: WGI-07 Spud Date: 3/19/1990 Event Name: WORKOVER Start: 7/8/2009 End: 7/24/2009 Contractor Name: NABORS ALASKA DRlLLING I Rig Release: 7/24/2009 Rig Name: NABORS 4ES Rig Number: ' I , I__ " I ! ' I'._ I : I . - -- ; . ' 7/22/2009 20:00 - 20:30 0.50 RUNCO RUNCMP Cameron: Install TWC. 20:30 - 22:00 1.50 RUNCO P RUNCMP MU Slick line BOP's. -Test Lubricator & Rams to 2900 psi - Pass. 22:00 - 23:00 1.00 RUNCO RUNCMP RU DSM lubricator. Test lubricator to 500 psi - Pass. -Pufl TWC. LD TWC & lubricator. 23:00 - 00:00 1.00 RUNCO RUNCMP RU to run RN plug. 7/23/2009 00:00 - 02:00 2.00 RUNCO P RUNCMP RIH w/ RN plug to 2,190' md on slickline. -Attempt to get RN plug through DB-6 nipple profile. -Work several times. No-Go. POH check RN plug. -POH w/plug. Plug OD = 5.95" -RIH w/ RN plug. -Work several times to get through DB-6 nipple. 02:00 - 07:OQ 5.~0 RUNCO RUfVCMP New Plug nose for RN plug = 5.87" -MU & RIH w/new RN plug. -Work several times (20 min) to get through DB-6 nipple @ 2,190' md. -Work several times (45 min) to get through R nipple C~ 7,988' md. -Workin in lu into RN ni le -- successful seat. -POH w/ plug running tool. 07:00 - 08:00 1.00 RUNCO P RUNCMP RIH w/ equalizinp prong and set in RN plug. -Set successful. -POH. 08:00 - 08:30 0.50 RUNCO RUNCMP Pressure test RN plug. -Test to 1 000 si for 10 charted minutes. -Test good. 08:30 - 09:00 0.50 RUNCO P RUNCMP Service rig. Inspect derrick. Check PVTs. 09:00 - 09:30 0.50 RUNCO RUNCMP PJSM for RD slickline BOPE and lubricator. 09:30 - 11:30 2.00 RUNCO RUNCMP RD slickline BOPE and lubricator. -LD same. -RDMO slickline unit from rig. 11:30 - 13:30 2.00 RUNCO P RUNCMP RIH w/ 27 stands of 3-1/2" DP to 2,526' md. 13:30 - 14:00 0.50 RUNCO P RUNCMP PJSM for RU LRS and freeze protecting tubing. 14:00 - 16:00 2.00 RUNCO P RUNCMP Freeze protect 7-5/8" tubing. -Reverse in 100 bbls 80 degree F diesel. 16:00 - 20:00 4.00 RUNCO RUNCMP POH and LD 81jts. 3-1/2" DP singles. 20:00 - 22:00 2.00 WHSUR P WHDTRE Set & test TWC. -Test to 3,500 psi from above for 10 charted minutes. -Test qood. 22:00 - 00:00 2.00 WHSUR P WHDTRE ND BOP's. 7l24t2009 00:00 - 00:30 0.50 WHSUR P WHDTRE Continue to ND BOP's. Note: Tbg hanger top threads are galled. Will need to spear to pull Tbg hanger on next workover. 00:30 - 05:00 4.50 WHSUR P WHDTRE NU Adaptor flange: -Test Adaptor to 5000 psi f/ 30 charted minutes.- Pass. -NU Tree: -Test Tree to 5000 psi f/ 30 charted minutes. - Pass. 05:00 - 06:00 1.00 WHSUR P WHDTRE Secure well. -Release Ri ~ 06: hrs on 7/24/2009. -T/I/O = 0/0/0. -Per Wells Group, left TWC installed in wellhead. Printed: 7/29/2009 3:05:31 PM IELLHEAD= McEVOY ~ WG I O CTUA~OR = BAKER C ~ B.ELEV - 61' F. ELEV = __ OP - . 5800' 13-3/8" CSG~ 66' ~ I, !ax Angle = 31 °@ 8600' 68#, K-55 XO atum MD = atum ND = 9199' TO L-80 BTC 8800' SS 0" CONDUCTOR, 91.5 #, H-40, ID = 19.124" I-1 119~ ~ 9-5/8" CSG, 47#, L-80 HYD 563 XO 2585~ TO L-80 BTC 9-5/8" BOWEN CSG PATCH, 47#, 2629~ L-80 BTC, ID = 8.681 " 13-3/8" CSG, 68#, L-80 BTC, ID = 12.415" 3485~ 7-5/8" TBG, 29.7#, L-80 VAM TOP, 7973~ .0459 bpf, ID = 6.875" Minimum ID = 3.725" @ 8113' 4-1/2" OTIS XN NIPPLE 7" TBG, 26#, L-80 TCII, .0383 bpf, ID = 6.276" I 8080' TOP OF 7" LNR I-I 8085' 4-1/2" TBG-IPC, 12.6#, L-80, 8125~ .0152 bpf , iD = 3.958" 9-5/8" CSG, 47#, L-80 BTGM, 8394' 0732 bpf, ID = 8.681" PERFORATION SUMMARY REF LOG: FINAL CNP ON 03/30/90 ANGLE AT TOP PERF: 30° @ 8403' Note: Refer to Production DB for historical perf data SIZE SPF INTE42VAL Opn/Sqz DATE 3-3/8" 4 8403-8447 O 05/31/90 3-3/8" 4 8504-8547 O 05/31/90 3-3/8" 4 8554-8574 O 05/31/90 3-3/8" 4 8580-8747 O 05/31/90 3-3/8" 4 8754-8799 O 05/31/90 3-3/8" 4 8803-8852 O 05/31/90 3-3/8" 4 8857-8887 O 05/31/90 3-3/8" 4 8892-8896 O 05/31 /90 3-318" 4 8899-8906 O 05/31 /90 3-3/8" 4 8911-8927 O 05/31/90 PBTD " LNR, 29#, L-80 BTGM, .0371 bpf, ID = 6.184" I 9000~ SAFEfY NOTES: DO NOT PRESSURE OA ABOVE 3000 7 ~ PS~. . I 2175~ 7-5/8" X 7" XO, ID = 6.253" 2~ 9~' 7" DB 6 NIP ID = 6 0" - , . ' " X 5/8" XO D = " 22Q$ 7- , I 6.253 7 2585~ 9-5/8" BTC ES CEMENTER 2603' 9-5/8" BKR ECP, ID = 6.861" 7973~ ~ 7-5l8" X 7" XO, ID = 6.253" I 79$$' 7" HES R NIP, ID = 5.963" 8019' 9-5/8" X 7" S-3 BKR PKR, ID = 6.000" 8053~ -17" HES RN NIP, ID = 5.770" I 8075' 7-518" 8KR MILLOUT DCTENSION, ID = 6.625' 8080' 7" WLEG, ID = 6.253" 8~81 ~ 7-5/8" X 4-1/2" XO, ID = 3.958" 8085~ 9-5/8" X 7" BOT HYD II HGR 8113~ 4-1/2" OTIS XN NIP, ID = 3.725" 8124' 4-1/2" BKR SHEAROUT SUB, ID = 3.875" 8125~ 4-1/2" WLEG, ID = 3.875" 8110~ ELMD TT LOGGm 06/02/90 8937~ ~~ FISH: FASDRILL DEBRIS (07/24/09) DATE REV BY COMMENTS DATE REV BY COMMENTS 05/23/90 D9 / N2ES ORIGINAL COMPLETION 07/24/09 N4ES RWO 07/26/09 PJC DRLG HO CORRECTIONS 07/30/09 MD/JMD DRLG DRAFT CORRECTIONS ^ 1 1 PRUDHOE BAY UNff WE1L: WGF07 PERMIT No: ~1900400 API No: 50-029-22031-00 SEC 11, T11 N, R14E, 846' FNL & 1085' FEL RP Fvnlnra4inn (Alackal 07/20/09 $Chli~b~t'g~l' , ,;,~r,~~ ~~~s Alaska Data & Consulting Services ,,. ,, Com an State of Alaska p Y~ 2525 Gambell Street, Suite 400 x ~ ; ~ ~ ~t '` s~ r~ ~., ~ ~ ~:s ~' ,~~ ~-= , 3~; Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ~ Attn: Christine INahnken ATTN: eeth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 4-04AlT-30 AYTO-00023 PRODUCTION PROFILE - O6/30/09 1 1 L3-31 AXBD-00030 MEM INJECTION PROFILE - / 07/01/09 1 1 G-31 B ANHY-00100 LDL ( 07/07/09 1 1 Z-326L1 AV1H-00018 SBHP RVEY 07/02/09 1 1 14-10 AY3J-00033 PRODUCTION PROFI~E ~'$(s, 07/01/09 1 1 A-20 AV1H-00021 SBHP SURVEY - "~ 07/07/09 1 1 01-30 AY3J-00034 lDL {0 07l04/09 1 1 M-26A BOCV-00021 PRODU TION LOG ^ 07/12/09 1 9 06-23C AXBD-00031 MEMORY PROD PROFILE - 07/03/09 1 1 L3-31 BOCV-00019 PRODUCTION LOG ~ 07/09/09 1 1 L2-20 AYKP-00031 LDL 07/10/09 1 9 E-09B 604C-00064 SCMT - 07/01/09 1 1 04-33 AY3J-00036 USIT ~ 07/07/09 1 1 WGI-07 80CV-00020 USIT Q~/1 ~~pg ~ 1 - 1-31/M-21 B14B-00063 PRODUCTION PROFIL~ ~ O6/16/09 1 1 L3-02 AZCM-00028 RST OW15/09 1 1 W 1-31/M-21 814B-00063 RST ' 06/17/09 1 9 18-18B ANHY-00097 RST a- ' 06/09/09 1 1 DI PACC AI~I[nl(1W1 Cn~c oc rc~oT nv c~n_wu ~~n eun ncr~.'..~..~., .. _ - - ------------- --------°'-- -..- ~~. . ~.-.~.. .... BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ~--~' !~.~.1 ~.,:;} Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 • • • • ~ i ~ a ~ I ~ ~} _ ~ 4 ~ F ' ~ ~.~~~ ~ ~ f'z~~ SARAH PALIN, GOVERNOR AJ4t1-7~A OIL ~ ~ ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA'I`IO1~T COl-i1~II55101~ ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ~ ~ (~ ~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, WGI-07 Sundry Number: 309-207 ~.~,~ ,~~r~ ~; ~ 200 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30' PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair h DATED this2? day of June, 2009 Encl. ALAS~IL AND GAS CONSERVA ON COMMI N EE~~ED ~' ~~~~i~~ i ~ zao9 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 AfaSka fill ~ Cap rnn~ f'P~rnrn:nn:.~ri 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extgt~~rjbf'aQt3 ® Alter Casing ®Repair Wetl ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program , ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 190-040 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22031-00-00 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-07 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028302 61' Prudhoe Bay Field / Prudhoe Bay Oil Pool 12• PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9005' - 8690' 8958' 8649' 8113' None asin n h Si a MD TVD B r oll se Structural n r 110' 2 11 110' 14 47 Surfa 3485' 13-3/8" 85' 3485' 450 1 5 Intermedia 8394' 9-5/8" 83 4' 162' 6870 476 Pr i n Liner 915' 7" 8085' - 9000' 7891' - 8686' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Pluq: 8403' - 8927' 8170' - 8622' 7", 26# x 5-1 /2", 17# x a-1 /2", 12.6# L-80 8125' Packers and SSSV Type: 9-5/8" x 7" Baker'FB-1' packer Packers and SSSV MD (ft): 8061' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ®Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: July 1, 2009 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ®GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mehrdad Nadem, 564-5941 Printed Nam avid Reem Title Engineering Team Leader I I D _ ~7 Prepared By Name/Number: Signature Phone 564-5743 Date Terrie Hubble, 564-4628 Commission Use Onl ~~~~~5~ `Z'~ ~~ Sundry Number: ~~~ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity BOP Test Mechanical Integrity Test ^ Location Clearance Other: ~•{~~ ~S`~ 't~°t"`~A~-.,~ ~~~~ pS~ e~~ ~` ~~ ~~ G°n`l~`~1 ~C~.~"_~5~ Subsequent Form Required: APPROVED BY / 1 ZZ J A roved B : COMMISSIONER THE COMMISSION Date to Form 10-403 Rev si ed b6/2006 ~ Submit In Duplicate • by cn,~~ w~~o~ Well Type: Gas Injector • Current Status: This well is currently shut-in due to T X IA x OA communication. BPXA requests approval to restore production casing and tubing integrity on WGI-07 ° Scope of Work: Repair IA x OA communication by cutting and pulling 9-5/8" surface casing, replacing it and fully cementing it to surface. Pull 7" Tubing. Mill Baker 9-5/8" x 7" packer. Pull packer and tubing tail. Install new 7-5/8" x 7" injection tubing. MASP: 2,700 psi Estimated Start Date: Production Engineer: Intervention Engineer: Pre-riq prep work: July 2009 Nathan Sinyagwe Mehrdad Nadem F 1 CM1T T x IA x OA to 2,000 si. Done -Passed on 5/10/2009 E 2 Jet cut the 5-1/2" 17#, L-80 pup joint as close to the collar at 8,053' as possible. (Reference tubin tall of 5/23/90 . F 3 Pressure test the T x IA x OA to 1,000 si to ensure the PXN Plu remains a com etent barrier. F 4 Circulate well with seawater. FP with diesel throu h the cut. D 5 Bleed casin and annulus ressure to 0 si. W 6 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. V 7 Set a BPV in the tubin han er. Secure well. O 8 Remove the wellhouse & flow fine. Level the ad as needed for the ri . Proposed Procedure: 1. MIRU Rig. ND tree. NU and test BOPE to 250 psi low, 4000 psi high. Test 7" fixed rams with 7" test joints. Circulate out freeze protection fluid and circulate well to clean seawater. 2. Pull and LD 7" tubing string from cut. 3. Change out 7"fixed rams to VBR and test. 4. RU E-line, Run USIT in the 9-5/8" casing to determine TOC in the 9-5/8" x 13-3/8" annulus. 5. Set retrievable bridge plug 100' below the top of cement and pressure test to 4,000 psi for 10 min. 6. Cut and Pull 9-5/8" surface casing. Note: Pipe rams will not be changed to 9-'/s" as the well has two tested barriers (FasDrilt plug and RBP) to the reservoir. 7. Run and fully cement new 9-5/8" L-80 47# Hydri1563 casing with ECP, ES Cementer and casing patch to surface. ~e ."_~ <,L~c car. c~ c~-c~~e?~~=~,~~c~v`~ A ~`r~cc v~~ 'r fj~SSJCY~-`~s~ • C~ 8. Mill 9-5/8" x 7" Baker FB-1 Packer. 9. RIH and spear the packer and tubing tail. 10. RIH with RTTS above 7" liner top and pressure the 9-5/8" casing to 4,000 psi for 30 minutes. 11. Run 7-5/8" 29.7# L-80 Vam Top HC IPC injection completion. 12. Displace the IA to completion fluid and freeze protect and set the packer. 11. Test tubing and IA to 4,000 psi. 13. Set BPV. ND BOPE. NU and test tree. RDMO. ATTACH: Current and proposed Schematics TREE= 6-3/8" CAMERON WELLHEAD = McEVOY GEN4 ACTUATOR= BAK KB. ELEV - 61' BF. ELEV KOP = 5800' 13-3/8" CSG, Max Angle = 31 @ 8600' 68#, K-55 XO • ~~' -O ~ SAFETY DO NOT PRESSURE OA ABOVE 3000 PSI. Datum MD = WA TO L-80 BTC Datum TVD = 8800' SS 20" CONDUCTOR 91.5 #, H-40, ID = 19.124" 119' 13-3/8" CSG, 68#, L-80 BTC, ID = 12.415" 3485' 7" TBG-IPC, 26#, L-80, .0383 bpf, ID = 6.276" Minimum ID = 3.725" @ 8113' 4-1/2" OTIS XN NIPPLE 15-1/2" TBG-IPC, 17#, L-80, .0232 bpf, ID = 4.892" I~ $053' 2209' ~CAMCO DSSSV NIP, ID = 5.937" $o~' I-~ 7" X 5-1/2" XO, ID = 4.875" 8059' 5-1/2" BKR LOC SEAL ASSY, ID = 4.875" 8061, 1-{ 9-5/8" X 7-1/2" BKR FB-1 PERM PKR I I w / SEA L BORE EXTENSION, ID = 6.00" 8075' 7-5/8" BKR MILLOUT EXTENSION, ID = 6.625" 8081' I-I7-5/8" X 4-1/2" XO, ID = 3.958" TOP OF 7" LNR I-I 8085' ~~ 4-1/2" TBG-IPC, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ ${ 113 ~~4-1/2" OTIS XN NIP, ID = 3.725" I 8113' 4-1/2" PXN PLUG SET (07/13/07) $124' 4-1/2" BKR BREAKOUT SUB, ID = 3.875" $125' 4-1/2" WLEG, ID = 3.875" $110' F1MD TT LOGGED 06/02/90 9-5/8" CSG, 47#, L-80 BTGM, I $394' .0732 bpf, ID = 8.681" PERFORAT~N SUMMARY REF LOG: FINAL CNP ON 03/30/90 ANGLEATTOPPERF: 29 @ 8403' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8403-8447 C 05/31 /90 3-3/8" 4 8504-8547 C 05/31/90 3-3/8" 4 8554-8574 C 05/31/90 3-3/8" 4 8580-8747 C 05/31/90 3-3/8" 4 8754-8799 C 05/31/90 3-3/8" 4 8803-8852 C 05/31/90 3-3/8" 4 8857-8887 C 05/31/90 3-3/8" 4 8892-8896 C 05/31/90 3-3/8" 4 8899-8906 C 05/31/90 3-3/8" 4 8911-8927 C 05/31/90 PBTD 17" LNR 29#, L-80 BTGM, .0371 bpf, ID = 6.184" I DATE REV BY COMMBVTS DATE REV BY COMMENTS 05/23/90 D9 / N2 ORIGINAL COMPLETION 07/29/07 RCT/SV SET PXN PLUG (07/13/07) 07/29/07 RCT/SV SET DSSSV (07/25/07) 08/07!07 DSM/SV TREE GO 12/12/08 DS/PJC DRAWING CORRECTIONS PRUDHOE BAY UNff WELL: WGI-07 PERMff No: 1900400 API No: 50-029-22031-00 SEC 11, T11 N, R14E, 846' FNL & 1085' FEL BP Exploration (Alaska) TREE= 6-3/8" CAMERON WELLHEAp = McEVOY GEN4 ACTUATOR = BAKER K8. ELEV = 61' BF. ELEV = KOP = 5800' D W G ~ ~ 7 Proposed SAFETY : DO NOT PRESSURE OA ABOVE 3000 PSI. 13-3/8" CSG, ~--~ 66~ Max Angle = 31 @ 8600' 68#, K-55 XO ' atum MD = NIA TO L-80 BTC Datum TV D = 8800' SS 20" CONDUCTOR, 91.5 #, H-40, ID = 19.124" 119' 13-3/8" CSG, 68#, L-80 BTC, ID = 12.415" 2000` 7" DBS Nipple 2580` 9-5/8" 47#, L-80 Hydril 563 2580` ES Cementer 2600` 9-5/8" x 13-3/8" Bowen Patch 8048` 7-5/8", 29.7# Vam Top IPC, 8078° 7" x 7-5/8" Crossover 8008` 7" HES R Nipple 8038` 9-5/8" x 7" S-3 Baker PKR 8068` 7" HES RN NIPPLE 7" Liner Top 8085` 9-5/8" CSG, 47#, L-80 BTGM, .0732 bpf, ID = 8.681" PERFORATION SUMMARY REF LOG: FINAL CNP ON 03/30/90 A NGLE AT TOP PERF: 29 @ 8403' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpnlSgz DATE 3-3/8" 4 8403-8447 C 05/31/90 3-3/8" 4 8504-8547 C 05/31 /90 3-3/8" 4 8554-8574 C 05/31 /90 3-3/8" 4 8580-8747 C 05/31 /90 3-3/8" 4 8754-8799 C 05!31/90 3-318" 4 8803-8852 C 05/31/90 3-3/8" 4 8857-8887 C 05/31/90 3-3/8" 4 8892-8896 C 05/31/90 3-3/8" 4 8899-8906 C 05/31/90 3-3/8" 4 8911-8927 C 05/31/90 I PBTD I ~ 7" LNR, 29#, L-80 BTGM, .0371 bpf, ID = 6.184" ~ 8083` 7" WLEG DATE REV BY COMMEMS DATE REV BY COMMENTS 05/23/90 D9 / N2 ORIGINAL COMPLETION 07/29/07 RCT/SV SET PXN PLUG (07/13/07) 07/29/07 RCT/SV SET DSSSV (07/25/07) 08/07/07 DSM/SV TREE GO 12/12/08 DS/PJC DRAWING CORRECTIONS PRUDHOE BAY UNIr WELL: WG4-07 PERMfr No: 1900400 API No: 50-029-22031-00 SEC 11, T11 N, R14E, 846' FNL 8 1085' FEL BP Exploration (Alaska) WGI-07 (PTD #1900400) IA repressurization Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, June 19, 2009 1:22 PM To: 'Reem, David C' Cc: 'Nadem, Mehrdad' Subject: RE: WGI-07 (PTD #1900400) Thanks Dave. From: Reem, David C [mailto:ReemDC@BP.com] Sent: Friday, June 19, 2009 1:19 PM To: Maunder, Thomas E (DOA) Subject: RE: WGI-07 (PTD #1900400) Tom, I'll give 'er a shot at answering your questions... Page 1 ~ Sr 1. 4ES gets the honor 2. The current tubing tail plug (4-1/2" PXN plug) wil- remain in the hole and will actin conjuration with the packer as our deep mechanical barrier. There will be no Fasdrill plug. The PXN will get extracted when the packer is milled and fished. 3. After tying the new 9-5/8" 47# L-80 Hydril-563 casing back to surface and fully cementing the tie-back we will: a) drill out the 9-5/8" shoetrack with 8-1/2" medium tooth rock bit until we get thru the HES cementer. Should be able to wash down to the 50' sand plug we placed earlier on top of the 9-5/8" RBP. b) We'll then dry drill on top of the sand plug in an effort to grind up ES-cementer remnants. c) next we'll run a reverse junk basket to hoover the trinkets off the san top, then d) we'll retrieve the RBP before proceeding with packer milling. 5/10/2009 we had a passing combo MIT TxIAxOA to 2000 psi 8/17/2007 leak detect log indicated that the IAxOA communication was at 2573'slm which 1 conjecture might be at a cementing stage tool (I do not have the wellfile handy to verify). Hope these attempts at answering your questions are adequate. Have a fine weekend. DCR From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, June 19, 2009 11:52 AM To: Nadem, Mehrdad Cc: Reem, David C Subject: FW: WGI-07 (PTD #1900400) Mehrdad, I left you and Dave voice messages. FYI, here is the message I sent to Problem Wells regarding any recent work that might have been accomplished on this well. also have some questions ... 1. What rig is planned? 2. It is stated that there is/will be a FasDrill plug in the wellbore (step 6), but earlier a PXN plug is mentioned (pre- rig step 3) and that is shown on the drawing. What plugs will be in the well? 3. It also appears some operation steps are missing to cleanout the cementing equipment and recover the RBP prior to milling the FB-1 packer (step 8). I look forward to your reply. Call or message with any questions. Tom Maunder, PE AOGCC 6/19/2009 WGI-07 (PTD #1900400) IA repressurization Page ~ ~,~. `~ • Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, June 19, 2009 7:27 PM To: Maunder, Thomas E (DOA) Subject: RE: WGI-07 (PTD #1900400) Tom, WGI-07 was found to have IAxOA communication shortly after the passing MIT-IA on 6/5/09. An LDL run on 08/17/07 confirmed both a tubing and productuion casing leak. The well has been shut-in since 6/30/07 when the diagnostics were completed. Thank you, Torin F :Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sen . riday, June 19, 2009 11:15 AM To: NS ADW Well Integrity Engineer Cc: Regg, mes B (DOA) Subject: RE: GI-07 (PTD #1900400) Anna or Torin, I am reviewing a sun application to workover this well. Work is below is the last commu ~ ation I find in the file about potential IA Prior to that I found the MI onducted 6/5/07, but then nothing p correspondence available in r files? According to the production/injection report, the II has been SI since 6/7/07 Thanks in advance. Call or mess with any questions. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Monday, July 02, 2007 1:39 PM To: NSU, ADW Well Integrity Engineer; g, James (DOA) Subject: RE: WGI-07 (PTD #1900400 A repressuriza Andrea, Thanks for the information. Go luck with the diagnostics. Inv ig, appropriate. It appears that e IA and OA track which is not a goo Keep us informed of the di nostic results. Tom Maunder, PE AOGCC ~~ied to start ~ July 1. The message trail A communication. to January 2000. Is there some other g any IA by OA communication is __ _ _ __ __ Prom: NSU, Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@ .con Sent: Mon ,July 02, 2007 1:33 PM To: Reg ames B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FSiJ2/COT OTL; , FSi pS Ops Lead; Senden, Leslie B; Engel, Harry R; Rossberg, R Steven; NSU, NSU, ADW Well Integrity Engineer ' jest: WGI-07 (PTD #1900400) IA repressurization ater); GPB, FSl Well Operations 6/22/2009 WGI-07 (PTD #1900400) IA repressurization Page 3~:~~ From: Maunder, Thomas E (DOA) Sent: Friday, June 19, 2009 11:15 AM To: NSU, ADW Well Integrity Engineer Cc: Regg, James B (DOA) Subject: RE: WGI-07 (PTD #1900400) Anna or Torin, 1 am reviewing a sundry application to workover this well. Work is planned to start ~ July 1. The message trail below is the last communication I find in the file about potential IA x OA communication. Prior to that I found the MIT conducted 6/5/07, but then nothing prior to January 2000. Is there some other correspondence available in your files? According to the production/injection report, the well has been SI since 6/7/07. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Monday, July 02, 2007 1:39 PM To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA) Subject: RE: WGI-07 (PTD #1900400) IA repressurization Andrea, Thanks for the information. Good luck with the diagnostics. Investigating any IA by OA communication is appropriate. It appears that the IA and OA track which is not a good sign. Keep us informed of the diagnostic results. Tom Maunder, PE AOGCC From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Monday, July 02, 2007 1:33 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2JCOTUJSeawater); GPB, FSl OTL; GPB, FSi DS Ops Lead; Senden, Leslie B; Engel, Harry R; Rossberg, R Steven; NSU, ADW Well Operations Supervisor Cc: NSU, ADW Well Integrity Engineer Subject: WGI-07 (PTD #1900400) IA repressurization Jim and Tom, Well WGI-07 (PTD #1900400) is exhibiting signs of pressure communication between the tubing and IA. GX sealant was pumped on the control and balance lines in an attempt to mitigate the communication, but was unsuccessful. In addition to the noted IA repressurization, the OA pressure also increased during this time. The well has been shut-in. The current plan forward is to replace the SSSV and put the well back on injection to monitor for possible IAxOA communication. An AOGCC witnessed MITIA passed to 2500 psi on 06/05/07. Attached is a TIO plot and wellbore schematic for reference. «WGI-07 90-day TIO plot.BMP» «WGI-07.pdf» «WGI-07 Injection PIot.BMP» Please call with any questions. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 6/19/2009 WGI-07 (PYD #1900400) IA .essurization Page 1 of 1 . Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, July 02, 2007 1 :39 PM To: 'NSU, ADW Well Integrity Engineer'; Regg, James B (DOA) Subject: RE: WGI-07 (PTD #1900400) IA repressurization Andrea, Thanks for the information. Good luck with the diagnostics. Investigating any IA by OA communication is appropriate. It appears that the IA and OA track which is not a good sign. Keep us informed of the diagnostic results. Tom Maunder, PE AOGCC From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWellIntegrityEngineer@BP.com] Sent: Monday, July 02, 2007 1 :33 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FSlj2jCOTUjSeawater); GPB, FSl OTL; GPB, FS1 DS Ops Lead; Senden, Leslie B; Engel, Harry R; Rossberg, R Steven; NSU, ADW Well Operations Supervisor Cc: NSU, ADW Well Integrity Engineer Subject: WGI-07 (PTD #1900400) IA repressurization Jim and Tom, Well WGI-07 (PTD #1900400) is exhibiting signs of pressure communication between the tubing and IA. GX sealant was pumped on the control and balance lines in an attempt to mitigate the communication, but was unsuccessful. In addition to the noted IA repressurization, the OA pressure also increased during this time. The well has been shut-in. The current plan forward is to replace the SSSV and put the well back on injection to monitor for possible IAxOA communication. An AOGCC witnessed MITIA passed to 2500 psi on 06/05/07. Attached is a TIO plot and wellbore schematic for reference. «WGI-07 90-day TIO plot.BMP» «WGI-07.pdf» «WGI-07 Injection Plot.BMP» Please call with any questions. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 S~ED JUL 0'2 2007 / 7/2/2007 . . State of Alaska MEMORANDUM Alaska Oil and Gas Conservation Commission TO: Jim Regg ~ P.I. Supervisor /~t {, (7/07 DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI-07 PRUDHOE BAY UNIT WGI-07 o/E)l{O \C\ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv , T8e- Comm NON-CONFIDENTIAL Well Name: PRUDHOE SAY UNIT WGI-07 API Well Number: 50-029-22031-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070606075915 Permit Number: 190-040-0 Inspection Date: 6/5/2007 ,/ Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well WGI-07 Type Inj. G TVD 7870 IA 220 2500 2380 2320 2310 P.T.D 1900400 TypeTest SPT Test psi 19675 OA 100 100 100 100 100 Interval 4YRTST P/F P ./ Tubing 3600 3600 3600 3600 3600 Notes: Pretest pressures observed and found stable. ../ SCANNED JUN ,2 1 2007 Wednesday, June 06, 2007 Page I of 1 . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email 10:Winton_Aubert@admin.slale.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.slate.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay I PBU I WGI pad 06105/07 Anna Dube Chuck Scheve \ qO'" o4'D Packer Depth Weill WGI-07 I Type Ini. 1 G TVD 1 7,87C1 P.T.D.I 1900400 I Typelesl 1 P Test psi 1 1,968 Notes: AOGCC State witnessed MlT -IA for UIC compliance Extended lest 15 minutes. Weill I Typelnj. I 1 TVD I P.T.D.I I Typelest I I Test psi I Notes: Pretest Initial 15 Min. 30 Min. Tubing 1 3600 36001 36001 36001 Interval 1 Casing 1 220 25001 23801 23201 P/FI OAI 100 1001 100 1001 45 mins - 3600 /2310 /100 Tubing Casing OA 4 P Weill I Type Inj.1 1 TVD I Tubing I P.T.D.I I Type lest I 1 Test psi 1 Casing I Notes: OA Weill I Type Ini.! I TVD I Tubing PTD.I I Type lestl I Test psil Casing Notes: OA Weill 1 Type Ini.1 I TVD I 1 Tubing PTD.I I Type lest 1 I Test psi I Casing Notes: I OA Interval I P/FI I I Inlervall P/FI 1 Interval I I P/FI Interval I P/FI TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standald Pressure Test R = Internal Radioactive TIaCef Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) SCANNED JUN 1 2 2007 MIT Report Form BFL 911105 MIT P6U WGI'{ 7 06-05-07.x1s MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas conservation Commission DATE: Julia Heusser, Commissioner Tom Maunder, P. I. Supervisorb~ i~._~. FROM: John Crispi 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. Atta. chm.en~: SVS PBU WGI Pad 1-15-01jc cc; NON-CONFIDENTIAL SVS PBU WGI Pad 1-15-Oljc.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, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE WGI-01 17903'~ 0 3400 2900 2440 P P P ' ' GINJ WGI-02 1790430 3400 2900 2650 P P P ' GINJ WGI-03 1790490 3400: 2900 2350 P P P GINJ WGI-04 '1790500 3400! 2900 2350 P 'P P' GINJ WGI-05 1900250 .... 3400' 2900 2500 P P P GINJ 4~GI-06 [1900300 3400 2900 2460[ P 4 9 ' GINJ WGI-07 i 1900400 3400 2900 2480 P P P ' GINJi ~4~I-08 1'900490 3400 2900 2620: P P P GINJ , Wells: 8 Components: 24 Failures: 2 Failure Rate: 8.3% 12300 var Remarks: wGI-07 Shut in untill repaired & re-tested. Paee 1 of 1 SVS PBU WGI Pad 1-15-0 ljc.xls THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE ,OCTOBER 27, 2000 P M C:LORI~Ii~LM.DOC E E L E W A T E R IA L U N D E TH IS M ARK ER R A_. ,,SKA OIL AND GAS CONSERVATION C,-,,,;MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well GAS INJECTOR OIL F-"] GAS E~] SUSPENDED r~ ABANDONED r~ SERVICE F~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90~40 , . 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50~029-22031 4 Location of well at surface r"~~ 9 unit or Lease Name 845' FNL, 1085' FEL, SEC 11, TllN, R14E UM ....... ~ PRUDHOE BAY UNIT At Top Producing Interval ~_~__~~ ;[ ; '""'?[::'~ i 10 Well Number 773' EEL, 2207' EEL, SEC 11 T11N, R14E ua .,,J/J~RIFIED I! i'''~.:'~ :...~t WGI-7 At Total Depth ~ 11 Field and Pool 754'FNL, 2458'FEL, SEC 11, T11N, R14E UM PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. PRUDHOE BAY OIL POOL RKB 61'I ADL 28302 ALK 2313 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 116 No. of Completions 03/19/90. 03/30/90. 06/02/90'I N/A feet MSLI 1 !9005' MD/8690' TVD 8958' MD/8649' TVD YES ~ NO E~I 2210' feet MDI 1900' (approx) 22 Type Electric or Other Logs Run GR/CCL, CET, CBT, 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 110' 30" 2150 POLESET 13-3/8" 68.0# L-80/K-55 SURF 3485' 17-1/2" 2200 SX AS III & 121 SX CLASS G TOP JOB W/37 BBLS AS I 9-5/8" 47.0# L-80 SURF 8394' 12-1/4" 485 SX CLASS G 7" 29.0# L-80 8085' 9000' 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) SIZE DEPTH SET {MD) PACKER SET (MD) PERFORATED W/4 SPF: 7" / 4-1/2" 8125' 8061' 8403'-8447'MD/8170'-8208'TVD 8803'-8852'MD/8512'-8525'TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 8504'-8547'MD/8257'-8294'TVD 8857'-8887'MD/8526'-8534'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8554'-8574'MD/8300'-8318'TVD 8892'-8896'MD/8535'-8536'TVD N/A 8580'-8747'MD/8323'-8465'TVD 8899'-8906'M D/8537'-8539'TVD 8754'-8799'MD/8471 '-8510'TVD 8912'-8928'MD/8540'-8544'TVD 27 N/A PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas liE, etc.) I , , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ,,~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATF ,~- Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. "-' i!i:' i! ~;i~"' ," NONE *NOTE: DRILLED RR 4/2/90. TUBING RUN 5/23/90. PERFORATED WELL 6/2/90. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ,~' ~'~ ~ m U e ~ V 30. GEOLOGIC MARKERS FORMATION TESTS NAIVE Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP SADLEROCHIT 8503' 8428' GOC 8944' 8637' BASE SADLEROCHIT 8994' 8681' NONE ., · , 31. LIST OF ATTACHMENTS WELL HISTORY (DRILL & COMPLETE), GYROSCOPIC SURVEY (2 COPIES), ADDENDUMS (SIGNED 4/27/90 & 6/20/90) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed L[~ {/~//~'~,/~--~J Title DRILLING ~,NALY~T Date ~-~-~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection', air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 WELL HISTORY ADDENDUM WELL WORK LOG Well # WGI-7 Work performed: INITIAL PERFORATIONS Cost: ~ Date: 5/31/90-6/2/90 AFE: AS2033 Time 1930 O040 0340 O525 0710 O845 1015 1210 1440 1630 1825 2045 2230 0050 0240 0430 DRILLING SUPERINTENDENT Summary RU SWS. RIH RIH RIH w/ gun RIH w/ gun RIH w/ gun RIH w/ gun RIH w/ gun RIH w/ gun RIH w/ gun RIH w/ gun #11, shoot f/ RIH w/ gun #12, shoot f/ RIH w/ gun #13, shoot f/ RIH w/ gun #14, shoot f/ RIH w/ gun #15, shoot f/ RIH w/ gun #16, shoot f/ Pump 85 bbls 60/40 meth/wtr. Summary: 8912-8928 8899-8906 8892-8896 8857-8887 88O3-8852 8754-8799 8580-8747 8554-8574 8504-8547 8403-8447 RIH w/gun #1, shoot f/8911.5-8927.5. POH, all shots fired. w/ gun #2, shoot f/ 8867-8887(no current), rebuilt & perf'd. POH, asf. w/ gun #3, shoot f/ 8892-8896, 8899-8906, 8857-8867. POH, asf. #4, shoot f/ 8842-8852, 8822-8842. #5, shoot f/ 8803-8822, 8789-8799. #6, shoot f/ 8779-8789, 8759-8779. #7, shoot f/ 8754-8759, 8727-8747. #8, shoot f/ 8717-8727, 8697-8717. #9, shoot f/ 8687-8697, 8667-8687. #10, shoot f/ 8657-8667, 8637-8657. 8627-8637, 8607-8627. 8597-8607, 8580-8597. 8554-8574, 8537-8547. 8527-8537, 8507-8527. 8504-8507, 8427-8447. 8422-8427, 8403-8422. Freeze protect WHP--1020. Perforated all w/ 4 spf 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. POH, all shots fired. POH, all shots fired. POH, all shots fired. Well secured. ADDENDUM DALLY DRILLING REPORT Well # WGI-7 Date: 4/8/90 Work performed: Cost: AFE: AS2033 Summary Ran CET, CBT Ran Gyro 7" bond shows good cmt f/PBTD to 9-5/8". CET shows some gas cut intervals at 8712'-8716' & 8631'-8635'. Small channels are present throughout the 7" liner. Cmt is fair f/liner top to 7740' w/top of cmt at 7620' (SOS calls cmt top at 7320'). Above 7620', csg collars are present on CBT. Poor cmt is present f/ 9-5/8" bottom to the top of the liner. Micro annulus is apparent in 9-5/8" but not in the 7" liner when pressured up to 1000 psi. Gyro shows a 27' different in the north and a 12' difference in the west with the SOS Gyro indicating not being as far north or west as the MWD tool. DRILLING SUPERINTENDENT ARCO O,, and Gas Company Well History- Initial Report - Daily IneL, uctlona: Prepare and submit the ',iniUa.I Rep@ri" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to ~padcUng ~hould be summarized on the form giving inclusive dates only. Title COMPLETE Auth. or W.O. no. AS2033 API: 50-029-22031 Operator ARCO Spud-dad or W.O. [IJI~EP T IDate 05/09/90 IH°ur 0900 HAS 05/10/90 ( TD: 0 Date and depth as of 8:00 a.m. PB: 8958 SUPV: RWO Complete record ARCO W.I. 21. 0000 Prior status if a W,O. 17) RIH W/7" COMPLETION ASS'Y 7"@ 9000' MW: 9.2 NaCl ACCEPT RIG @ 0900 HRS, 5/9/90. ND TREE. NU BOPE. PULL BPV. MU LANDING JT AND PULL DUMMY HANGER. PU 7" TEST JT. MU AND aTORQUE UP X~ AND SAFETY VALVE. LD TEST JT. RIH W/7 STDS DP TO 669'. MU TEST JT ON TEST PLUG AND LAND TEST PLUG AND BACK OUT TEST JT. TEST BOPE. OK. DISPLACE OUT DIESEL W/9.2 PPG BRINE. POOH W/7 STDS. INSTALL WEAR BUSHING. BLOW DOWN CHOKE MANIFOLD. RU ATLAS WL. TEST LUBRICATOR TO 1000 PSI. MU AND WLIH W/8.5" GR/JB. RIH TO TOL @ 8085'. WLOH. NO RECOVERY IN JB. MU 9-5/8" X 5-1/2" BAKER FB-1 PERMANENT PACKER AND TAIL ASSEMBLY AND WLIH. SET PACKER AT 8046' WLM. WLOH. RD ATLAS. RU TO RUN 7" COMPLETION ASSEMBLY. BEGIN RIH W/7" COMPLETION ASSEMBLY. DAiLY:S44,691 CUM:$1,617,434 ETD:S1,844,691 EFC:$2,416,743 05/11/90 (18) LAND 7" COMPLETION TBG 7"@ 9000' MW: 8.5 FSW TD: 0 RIH W/7" COMPLETION ASS'Y. REMOVE AND REPAIR SKATE ON PIPE PB: 8958 HANDLER. CONT' RIH W/7" COMPLETION ASS'Y. BREAK CIRC. SUPV:RWO TUBING BACKFLOWING. WELLBORE OUT OF BALANCE. FINISH RIH W/7" COMPLETION ASS'Y. VERIFY SEAL ASS'Y STUNG IN. PRESSURE TO 500 PSI. OK. BLEED OFF PRESSURE. MU TUBING HANGER AND :. ALL CONTROL LINES. TEST SAME 5000 PSI. OK. DISPLACE OUT 9.2 PPG NACL W/8.5 PPG INHIBITED SEAWATER. FREEZE PROTECT ,i/-~i~!' TOP 2250' OF WELLBORE W/DIESEL. LAND TBG AND RILDS. J'!?i ~! DAILY:S284,075 CUM:$1,901,509 ETD:SO EFC:$4,545,509 05/12/90 ~ :~9)i;~?~;:~.'i CIRC HEATED BRINE @ 2009' MD 7"@ 9000' MW: 8.5 FSW TD: 0 RU TO PRESSURE TEST 7" TBG TO 4000 PSI F/30 MIN. OK. BLEED PB: 8958 DOWN TO 1500 PSI. PRESSURE UP ON 9-5/8" X 7" ANNULUS. AT SUPV:RWO 2800 PSI PRESSURE DROPPED TO 200 PSI. 13-3/8" X 9-5/8" AND 9-5/8" X 7" ANNULUS PRESSURES TRACKING. TEST 9-5/8" PACKOFF TO 5000 PSI. OK. PUMP 2 GAL RED HYDRAULIC OIL W/25 BBL DIESEL DOWN 13-3/8" X 9-5/8" ANNULUS TO GET IDEA WHERE LEAK IS. NEVER SAW HYDRAULIC FLUID RETURN. REPRESSURE 7" TBG TO 2500 PSI. OK. ESTABLISH INJECTION RATE DOWN 13-3/8" X 9-5/8" ANNULUS @ 2.4 BPM W/1000 PSI. RU TO INJECT OIL BASE MUD DOWN 13-3/8" X 9-5/8" ANNULUS. PRESSURE UP TO 2200 PSI. NO INJECTION. BLEED PRESSURE TO 0 PSI. WELL NOT FLOWING. BOLDS. PREPARE TO UNSTING W/7". NOTICE 100 PSI ON 13-3/8" X 9-5/8" ANNULUS. RILDS. ATTEMPT TO INJECT DOWN 13-3/8 X 9-5/8" ANNULUS AGAIN. REACH 2200 PSI W/NO INJECTION. BLEED OFF PRESSURE. BOLDS. ATTEMPT TO UNSTING. HAD TO PULL 220K TO UNSTING(PU BEFORE INITIAL STING-IN 198K). PULL UP TO 230K. COLLAR HANGING UP. ATTEMPT TO RESEAT HGR. COLLAR HANGING UP. SLACKOFF ALL WT. RESEAT HANGER. RILDS. PRESSURE UP 13-3/8" X 9-5/8" ANNULUS TO 2500 PSI. NO INJECTION. RIH W/7 STDS DP AND CIRC HOT BRINE. DISPLACE The above is corr~ For form ~preparetlon and distribution, OUT DIESEL. (SHUT DOWN AND CLEAN UP DIESEL SPILL). CONT' CIRC HOT/B~F/NE @ 700'. ~T4~3T 2009'. ~IRC @ 2009'J il,lllim~a[ see Procedures Manual, Section 10, Drilling, Pages 86 and 87. DOWN. PU DP AND RIH W/DP TO AR3B-459-1-D INumber all daily well history forms consecutively las they are prepared for each well. I Page no. ARCO Oi; rind 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 ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lntarlm" 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 etrhlg is set. Submit weekly for workovers and following setting of oil strin§ until completion. District A~.CO AI~l%S~(.A INC. rC°unty°rParish NORTH SLOPE Jstate I I Field PR. UD['{OE BA~' ILease or Unit WGI-7 I complet ...... df ..... h~l~11~ d r ~ ~1~t~ ..... k .... in prog .... Date and deptll as of 8:00 a.m. 05/13/90 TD: 0 PB: 8958 SUPV:RWO 05/14/90 TD: 0 PB: 8958 SUPV:RWO 05/15/90 TD: 0 PB: 8958 SUPV:RWO 20) 21) 22) AK IWell no. DAILY:S23,948 CUM:$1,925,457 ETD:S1,925,457 EFC:$2,644,000 CONT CIRC HEATED BRINE @ 2009' 7"@ 9000' MW: 9.3 NaC1 CONT' CIRC HOT BRINE @ 2009'MD. 13-3/8" X 9-5/8" ANNULUS THAWED. INJECT 200 BBL HOT DIESEL (150 DEGREES) DOWN 13-3/8" X 9-5/8" ANNULUS @ 2.5 BPM AND 1000 PSI. INJECT 185 BBL OIL BASE MUD AT 1 BPM AND 900 PSI. POOH W/DP. PU LANDING JOINT AND MU IN TBG HG~i CHECK 13-3/8" X 9-5/8" ANNULUS. ON VACUUM. CHECK 9-5/ CONT CIRC HOT 9.2 BRINE. THAW OUT 13-3/8" X 9-5/8" ANNULUS. FREEZE PROTECT SAME. RU ATLAS WL. RIH W/ TEMP LOG. 9-5/8" CSG PARTED 3 JTS BELOW HANGER. POOH W/ TEMP LOG. RIH W/PERF GUN. PERF AT 4SPF IN FIRST JOINT ABOVE PACKER. CIRC HEATED 9.2 PPG BRINE DOWN ANNULUS TAKING RETURNS UP 7" TUBING THROUGH CHOKE AT 4 BPM AND 1200 PSI. DISPLACE OUT 8.5 PPG BRINE DOWN 9-5/8" ANNULUS AND UP 7" TUBING AT 4 BPM AND 2200 PSI THROUGH CHOKE. DAILY:S40,622 CUM:$1,966,079 ETD:S2,193,336 EFC:$2,416,743 STRAP AND PU 6-1/4 DC'S 7"@ 9000' MW: 9.2 NaCl FINISH CIRC HEATED 9.2 PPG BRINE DOWN 13-3/8" X 9-5/8" ANNULUS AND UP THE 7" TUBING AT 4BPM AND 2200 PSI THROUGH CHOKE. OBSERVE WELL. NO FLOW. BOLDS. POOH W/7" TUBING AND SEAL ASSEMBLY. CLEAR FLOOR. STRAP AND PU 6-1/4" DC'S FOR WEIGHT BELOW 9-5/8" 47# RBP. DAILY:S23,460 CUM:$1,989,539 ETD:S2,216,796 EFC:$2,416,743 POOH W/9-5/8" CASING 7"@ 9000' MW: 9.2 NaC1 PU 6-1/4" DC'S TO HANG BELOW SV(*).SET RBP AT 30' MD. ND BOPE. REMOVE 7" TBG SPOOL AND 11" X 13-5/8" MUDCROSS. NU 13-5/8" X 13-5/8" MUDCROSS AND NU BOPE. RU AND TEST BOPE AND FLANGES TO 2000 PSI. PU GBR CASING TOOLS. RETRIEVE STORM VALVE. LD STORM VALVE. POOH W/DC'S AND RACK BACK IN DERRICK. MU 9-5/8" LANDING JOINT AND ENGAGE 9-5/8" TUBING HANGER. PULL 100K. NO MOVEMENT. CHANGE TO 350 TON ELEVATORS. PU TO 125K AND PIPE COMING. LD LANDING JOINT AND HANGER. LD 3 JOINTS 9-5/8" CASING. CIRC OUT OIL BASE MUD W/9.3 PPG BRINE. CONT' POOH. LD TOTAL OF 58 JOINTS 9-5/8", 47#, L-80, IPC, BTC-MOD CASING. SV(*): STORM VALVE RECOVERED TOTAL OF 22 CENTRALIZERS RECOVERED TOTAL OF 27 STOP RINGS SEVERAL JOINTS WERE NOT TORQUED UP PROPERLY. SOME WERE HANDY INCLUDING HANGER SOME WERE CROSS THREADED. CASING RUN BY GBR. DAILY:S22,131 CUM:$2,011,670 ETD:S2,238,927 EFC:$2,416,743 The above is corre~ ~ Sig n~.~ ~ For forr~ preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Title Drilling SUpt. AR3B-459-2-B Number all daily well history forms consecutively IPage no. as they are prepared for each well. ARCO Oi~,,nd 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 ail cores. Work performed by Producing Section will be reported on "lnlarlm" 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 ~et. Submit weekly for workovers and following setting of oil string until completion. District A~CO ALASKA TNC. IC°unty°rParish NORTH SLOPE IState AK I I Field PRUDHOE BAY IL ...... Unit WGI-7 Jweu no. Date and depth Complete record f .... C~Nd~:R~sdr~..~;or work .... in prog .... as of 8:00 a.m. 05/16/90 TD: 0 PB: 8958 SUPV:RWO 05/17/90 TD: 0 PB: 8958 SUPV:RWO 05/18/90 TD: 0 PB: 8958 SUPV:LP 05/19/90 TD: 0 PB: 8958 SUPV:LP 05/20/90 TD: 0 PB: 8958 SUPV:LP The above is corrqCt For fotm preparation and distribution 23) 24) 25) 26) 27) RIH W/9-5/8", 47# SPEAR 7"@ 9000' MW: 9.2 NaCl FISH APPROXIMATELY 4 BROKEN CENTRALIZERS OUT OF STACK (CENTRALIZERS BROKEN IN HALF ACROSS THE MIDDLE). PU, MU, AND RIH W/TAPERED MILL. TAG FISH (CENTRALIZER) AT 2493' MD. PUSH TO 2610. TAKING APPROXIMATELY 5,000# WEIGHT. POOH W/TAPERED MILL. RIH W/BACKOFF TOOL ON 5" DP. KEEP DP FULL OF DIESEL. SET BACKOFF TOOL AT 2534' MD. MAKE BACKOFF. POOH W/BACKOFF TOOL. MU 9-5/8",47#, SPEAR AND RIH. 9-5/8" CASING STARTED TO ~ACKOUT WITH BACKOFF TOOL AT 1500 PSI (15000 FT*LB) DAILY:S34,896 CUM:$2,046,566 ETD:S2,046,566 EFC:$2,644,000 BACKOFF 9-5/8" CSG JT #60 7"@ 9000' MW: 9.2 NaC1 SPEAR CASING, BACK OUT AND POOH W/1 JT 9-5/8" CASING, STOP COLLAR AND CENTRALIZER. RIH W/ 9-5/8" CASING (61 JTS). DISPLACE 13-3/8" X 9-5/8" ANNULUS WITH 9.3 PPG OIL BASE MUD. STAB IN. MU 16 TURNS @ 11,000 FT-LB. WORKING TORQUE DOWN STRING F/ll0K DOWN TO 130K UP. PU ON STRING TO SET SLIPS. PICKED UP TO 225,000# AND CASING CAME APART AGAIN. DISPLACE OIL BASE MUD. POOH W/CASING. RECOVERED 61 JTS (CAME APART SAME PLACE SCREWED INTO). PIN HAD VERTICAL CUTS ABOUT 1-1/2" APART AND 2" LONG. RD CASING CREW. PU BACKOFF TOOL AND RIH WITH SAME. SET BACKOFF TOOL CENTER AT 2580'. BEGIN BACKOFF AT JOINT #60 OF ORIGINAL 9-5/8" CASING. INITIAL BREAK AT 1500 PSI (15000 FT-LB). DAILY:S40,765 CUM:$2,087,331 ETD:SO EFC:$4,731,331 RU TO DISPLACE ANNULUS W/ OBM 7"@ 9000' MW: 9.2 NaC1 FINISH BACKOFF JT 9-5/8" CSG. TEST STACK. SPEAR 9-5/8" CSG AND UNSCREW SAME. POOH. RIH W/9-5/8" CSG. DISPLACE ANNULUS W/OBM. DAILY:S22,057 CUM:$2,109,388 ETD:SO EFC:$4,753,388 PU AND RIH W/3-1/2" DP 7"@ 9000' MW: 9.2 NaCl RIH W/TRI-STATE TRIPLE CONNECTION SUB ON 9-5/8" CSG. SCREW IN. TEST CSG TO 4000 PSI F/1HR. OK. ND BOPE. SET SLIPS. NU TBG SPOOL. TEST PACKOFF. OK. NU BOPE. TEST BOPE. OK.RIH W/ROPE SPEAR TO FISH OUT 9-5/8" CENTRALIZER @ 2610'MD DAILY:S89,529 CUM:$2,198,917 ETD:S2,426,174 EFC:$2,416,743 POOH W/6" SEAL ASS'Y 7"@ 9000' MW: 9.2 NaC1 RIH W/ROPE SPEAR. TAG UP ON FISH (9-5/8" CENTRALIZER). POOH. NO FISH. RIH W/ROPE SPEAR. CHASE FISH TO TOP OF PACKER AT 8046'WLM. GO INTO PACKER 1'. POOH. NO RECOVERY. MU AND RIH W/DUMMY SEAL ASS'Y. WORK SEAL ASSEMBLY INTO PACKER. PRESSURE UP AND BLOW OUT SOS. CBU. POOH. DAILY:S25,225 CUM:$2,224,142 ETD:S2,224,142 EFC:$2,644,000 see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B J Numberas they arealt dailYpreparedWell forhiStorY'each ........... well. tively JPage no. ARCO Oil ,.,rd Gas Company Dai!y 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 "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ARCO ALASKA INC. Field PRUDHOE BAY County or Parish NORTH SLOPE ]state AK Lease or Unit WGI-7 Iwe~l no. Date and depth Complete record for each~dri~l~8or workover in progress as of 8:00 a.m. 28) 05/21/90 TD: 0 PB: 8958 SUPV:LP 05/22/90 TD: 0 PB: 8958 SUPV:LP 05/23/90 TD: 0 PB: 8958 SUPV:LP The above is correct \ Sign at u~ ~..~.. For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 29) 30) CBU 7"@ 9000' MW: 9.2 NaCl POOH AND LD DUMMY SEAL ASS'Y (SEALS BADLY CUT). RIH W/2 3-1/8" DC'S W/SEAL ASS'Y SPACED OUT. TAG PKR. WORK DOWN TO XN NIPPLE. CAN'T GO ANY FURTHER. POOH. MU PRT AND 8-1/2" MILL. RIH TO CUT OUT PACKER. DAILY:$34,583 CUM:$2,258,725 ETD:S2,258,725 EFC:$2,644,000 POOH W/ATLAS WL 7"@ 9000' MW: 9.2 NaCl FINISH MILL PACKER AND POOH W/~AME. JUNK AT XN NIPPLE. RIH W/SCRAPER TO TOL. CIRC. POOH [/)DP. RU ATLAS WL. WLIH, TIE-IN, AND SET BAKER FB-1 PERMANENT AT 8049 WLM. WLOH. DAILY:S75,525 CUM:$2,334,250 ETD:S2,334,250 EFC:$2,644,000 TESTING 7" TBG @ 4000 PSI 7"@ 9000' MW: 8.5 FSW SET BAKER 9-5/8" X 5-1/2" FB-1 PACKER AT 8049' WLM. RD ATLAS WL. RU AND RUN 7" COMPLETION ASS'Y. TESTING TUBING TO 4000 PSI AT 0600 HRS. NOTE: CAMCO 'BAL-0' SSSV @ 2210', BAKER 'FB-i' @ 8061', & TT @ 8125'. DAILY:S33,217 CUM:$2,367,467 ETD:S2,367,467 EFC:$2,644,000 Drilling Supt. AR3B-459-2-B Number all daily well history forms consecutively as they are prepared for each well. IPage no. ARCO .,tl and Gas Company Daily Well History-Final Report Instructions: Prepare and submit !; ..~.~l~il~t" oil the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submltt~~~t{~$ lire suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion,.re~;~ntatlve test data in blocks provided. The "Final Report" form may be used for repo~tlng the entire operation if space is availab!~: : ~-: ~/~. ~::.~ · Accounting cost center code District ~CO ~~-~?;_ ~; ' - ICounty or Parish NORTH SLOPE State AK I Auth. or W,O. no. AS2033 ITM CO~LETE I ~I: 50-029-22031 operator ~l~.CO IA.R.Co. W.~.21. 0000 I Spudded or W.O. ~--PT IDate 05/09/90 I Complete record fo[~l~ro~sre~,d Date and depth as of 8:00 a.m. 05/24/90 TD: 0 PB: 8958 SUPV:LP (31) Iotal number of wells (active or inactive) on this ost center prior to plugging and 1 bandonment of this well I our 0900 J'IRS IPrlor status if a W.O. I RIG RELEASED 7"@ 9000' MW'I 8.5 FSW FINISH TESTING TUBING AND TUBIN6 X 9-5/8" ~/~3LUS TO 4000 PSI. OK. TEST TREE AND PACKOFF. OK. ATTEMPT TO SHEAR OUT SOS. PRESSURE UP TO 5000 PSI. DID NOT SHEAR. BLEED OFF PRESSURE. SET BPV. RELEASE RIG @ 1500 HRS, 5/23/90. DAILY:S178,890 CUM:$2,546,357 ETD:S2,546,357 EFC:$2,644,000 Old TD ] New TO I Released rig I Date I Classifications (oil, gas, etc.) Producing method IPB Depth Kind of rig Type completion (single, dual, etc.) Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production OII on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected Signatl~e~ ~ ~ Title Supt. For form ~3reparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well hlsto~ forms consecutively as they are prepared for each well, Page no. Olvl.ion of AtlanllcRtchfleldCompany ARCO ~..,, and Gas Company Well History- Initial Report - Daily Inatructiona: Prepare and submit the "initial RelN3rl" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. ICounty. parish or borough NORTH SLOPE Lease or Unit ADL: 28302 Title DRILL JState AK Field PRUDHOE BAY IWell no. WGI-7 Auth. or W.O. no. AS2033 API: 50-029-22031 Operator ARCO Spudded or W.O. begun SP~TD JOate 03/1~0 I ARCO w.i. 01: 1~TM status if a W.O. 21.0 Date and depth as of 8:00 a.m. 03/1! TD: SUPV 03/2( TD: : SUPV: 03/2: TD: ~ SUPV ', 03/2: TD:: SUPV 03/2; TD: , SUPV: Complete record for each day ~N 9 /90 (1) 536' ( 536) DBJ DRLG AHEAD AT 536'. MW: 8.7 VIS:300 MOVE RIG FROM WGI-6 TO WGI-7, NU AND TEST DIVERTER, MIX MUD, FILL HOLE, FIX LEAKY FLOWLINE, SPUD HOLE AT 0130 HRS ON 19-MAR-90, DRLG 17-1/2" HOLE FROM 110' TO 536' DAILY:S63,900 CUM:$63,900 ETD:S100,000 EFC:$2,607,900 1/90 (2) .989'(1453) DBJ DRLG AT 1989' W/ 17-1/2" BIT. MW: 9.3 VIS:265 DRILL 17-1/2" HOLE F/ 536' TO 566', SURVEY, POOH, CHANGE BHA AND BIT, RIH, DRILL FROM 566' TO 1989'. DAILY:S61,004 CUM:$124,904 ETD:S180,000 EFC:$2,588,904 ./90 (3) ~515' (1526) DBJ RUNNING 13-3/8 CSG 13-3/8"@ 3485' MW: 9.4 vis:300 DRILLED 17.5 INCH HOLE FROM 1989 TO 3515 FT., CBU, SHORT TRIP, CBU, POH TO RUN CSG. DAILY:S56,465 CUM:$181,369 ETD:S250,000 EFC:$2,575,369 /90 ( 515'( DBJ 4) N/U BOP 13-3/8"@ 3485' MW: 9.4 VIS: 0 FINISHED RUNNING 13-3/8 CSG, C&C MUD, CMT 10 BBLS, TEST LINES 2500PSI, 90 BBLS H20, DROP PLUG, PUMP 2200 SX AS III SLURRY @ 12.1 PPG, 1.94 YIELD, DROP PLUG#2 MIX & PUMP 25 BBL SLURRY, RECIRC., TUB PLUGGED, ABORT CMT JOB AFTER PUMPING 121 CLASS G CMT, DROP TOP PLUG, DISP W/5BBLS H20 AND 505 BBLS 9.4 PPG MUD, C.I.P., FLUSH DIVERTER SYSTEM, R/U TO RUN TOP JOB, PUMP 21 BBLS H20 FLUSH+37 BBLS AS.I, R/D TOP JOB LINES, SET SLIPS,MAKE CUT ON 13-3/8 CSG, WELD ON 9-5/8 CSG HD HOT TEST, INSTALL DRLG SPOOL CHOKELINE ON BOP STACK, TEST WELD TO 1500 PSI, REMOVE COMPANION FLANGE +VRPLUG INSTALL CIW VALVE, N/U INSTALL BOP STACK, FLANGES, R/U TURNBUCKLES, FLOWLINES. DAILY:S225,993 CUM:$407,362 ETD:S750,000 EFC:$2,301,362 /90 ( 5) t884'(1369) RJB DRILLING 13-3/8"@ 3485' MW: 9.3 VIS: 38 R/U TO TEST BOP'S, INSTALLED TEST PLUG, TEST ANNULAR AND ALL LINES,MANIFOLD, VALVES, RAMS, PULL TEST PLUG, INSTALLED WEAR BUSHING, L/O SECOND BHA, TEST UPPER AND LOWER KELLY VALVES, TIH TO 3399', CIRC. AND TEST CASING, DRILLED OUT FLOAT COLLAR AND CONTAMINATED MUD, CIRC. AND CONDITIONED WITH 9.0 PPG, TEST CSG, PERFORMED L.O.T. TO 11.8 PPG EMW W/ 9.0 PPG MI/D, CIRCULATE, START DRILLING TO 4884', SURV. W/MWD. DAILY:S61,160 CUM:$468,522 ETD:S875,000 EFC:$2,237,522 03/2 /90 ( 6) DRLG W/ STEERABLE MOTOR 13-3/8"@ 3485' MW: 9.5 VIS: 40 TD: ,701' ( 817) DRLD F/4884 TO 5400, CBU, DROP SURVEY, POH, HOLE TIGHT AND SUPV RJB SWABBING F/4531- 4242, TIH TO 5400, P/U WT 180K, MAX DRAG 250K, CIRC AND COND MUD, LARGE CUTTINGS OF COAL AS WELL AS SLIVERS OF COAL IN THE MUD,MUD WT 9.4 IN/OUT, BTMS UP WAS 9.0PPG CL 1200, JUST BEFORE BTMS UP 9.2 PPG CL 1150, POH WITH P/U WT AT 160K AND MAX DRAG AT 300K~ BHA ROTR. SURV The above is~orrect t~-~- '~ .._ 5308 .5 DEGREES 545W~ CLEANED STABS TOP STAB HEAVILY BALLED Sign, re .~ ,~ ~'~ UP Da, HA 4 DEGREE For form p~Paratl0n and distribution, - ~ · ~ A __~ see Procedu~s Manual, Section 10. ~ ~, ~*1~ ~H~ Drilling, Pages 86 and 87. ~ j(IIIIH~ ~ye AR3B-459-1-D Number all daily well hlstow forms consecutively , no. aa they are prepared for each well. IPage I ARCO (,,,, and 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 "lnlerim" sheets until tinal 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§ until completion. District Field ARCO ALASKA INC. County or Parish NORTH SLOPE Istate Lease or Un t WG1-7 IWell no. AK PRUDHOE BAY Date and depttl as of 8:00 a.m. 03/; TD: SUP~ 03/ TD: SUP' 03/; TD: SUP~ O3/ TD: SUP' 03/: TD: SUP~ The above is correct ~'% For form p'l~parati~n and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Complet ...... d f ..... h day while d~(j~w~:~k .... in prog .... :5/90 ( 7) 6858' (1157) RJB 6/90 (8) 7489'( 631) ':RJB 7/90 ( 9) 8420'( 931) ':RJB ~8/90 (10) 8410'( 0) RJB 9/90 (11) 8420'( 10) r:DBJ BH F/5400- 5701, SURV W/MWD. DAILY:S70,188 CUM:$538,710 ETD:S925,000 EFC:$2,257,710 DRILLING 13-3/8"@ 3485' MW: 9.6 VIS: 42 DRLD W/ 3/4 DEGREE BHPDM F/5701 TO 6858. SURV W/ MUD AST=12.7 HRS, ART=9.7 HRS DAILY:S47,638 CUM:$586,348 ETD:S1,020,000 EFC:$2,210,348 DRILLING 13-3/8"@ 3485' MW: 9.8 VIS: 45 DRLD FROM 6858 TO 7079, SURV W/MUD, CIRC AND COND., DROP SURVEY, POH, TIGHT THRU 6563-6077, BHA-1 SET BACK, CLEAN STABS, TOP STAB BALLED UP, L/D DRILEX MOTOR (STAB WAS BACKED OFF), P/U 3/4 DEGREE BH DYNA DRILL, STAB SLEEVE, M/U DYNA DRILL, C/O STAB SLEEVE, TIH WITH BHA #5, SURFACE TEST MUD OK, TIH TO 6978 KELLY UP, WASH AND ROAM F/6978-7079, WORK PIPE THRU TIGHT HOLE, FIN CIRC FOR BTMS UP, CLEAN OUT HOLE, DRLD FROM 7079 TO 7489, SURV. W/MUD. NOTE: EASED WT UP F/ 9.6 TO 9.8 PPG, HOLE TIGHT AND STICKY. DAILY:S70,219 CUM:$656,567 ETD:S1,020,000 EFC:$2,280,567 POH 9-5/8"@ 8394' MW: 9.8 VIS: 40 DRLD W/ 3/4 BH PDM F/ 7489 TO 8406, CIRC BTMS UP, 9.8 PPG IN AND OUT, DRLD F/ 8406 TO 8420, CIRC BTMS UP, SHORT TRIP TO 6946, NORMAL DRAG ON TRIP OUT, HIT TIGHT SPOT AT 8336, WASH AND REAM FROM 8336 TO 8420, CIRC AND COND. HOLE, 9.8 PPG IN/OUT, DROP SURV, SLUG PIPE, POH W/ 35 STDS. DAILY:S55,555 CUM:$712,122 ETD:S1,130,000 EFC:$2,226,122 N/U TBG SPOOL 9-5/8"@ 8394' MW: 8.3 VIS: 0 FINISHED POH, L/D BHA, FOUND A 10' MISTAKE IN ORIGINAL PIPE TALLEY, CORRECTED DEPTH SHOULD BE 10' SHALLOWER, MISTAKE MADE ON 23-MAR-90 WITH CORRECTION AT TOP OF SAG BEING 8399' NOT 8404', PULLED WEAR BUSHING, C/D TOP PIPE RAMS TO 9-5/8, TEST SEALS TO 2500 PSI, R/U GBR TO RUN 9-5/8 CSG, RUN 196 JTS OF 9-5/8 CSG, CIRC AND COND RECIPROCATING CSG, PUMPED 485 SX CLASS G CMT, R/D CIRC HEAD, P/U 1 JT DP, M/U CIW R/T AND PACK OFF, SET PACK OFF, N/D BOP, DRILL SPOOL, N/U TBG SPOC DAILY:S285,412 CUM:$997,534 ETD:S1,525,000 EFC:$2,116,534 PREP FOR F.I.T. 9-5/8"@ 8394' MW: 9.2 VIS: 41 FINISH N/U TOP SPOOL AND FLANGE TESTING, N/U BOP, CHANGE RAMS, TEST BOP, SET WEAR RING, L/D 12.25" BHA AND P/U 8.5" BHA, RIH TO 7000', SLIP AND CUT DRLG LINE, HOOK UP WT. INDICATOR, RIH TO 8288', P/U KELLY AND TAG CMT. @ 8304', CIRC. AND COND., TEST CSG TO 4000#,DRLG CMT, PLUGS, FC, CMT, FS, AND 10' OF NEW HOLE. DAILY~S164:000 CUM:S1~161~534 ETD:Sl.525~000 ~'~2.280.534 Da Drilling SupL AR3B-459-2-B INumber all daily well history forms consocutively as they are prepared for each well. no. ARCO ,,. _ and 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 "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less Irequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. ARCO ALASKA INC. NORTH SLOPE PRUDHOE BAY WGI-7 Complete record for each day while drilling or orkover in progress DOYON ~ Date and depttl as of 8:00 a.m. 03/3 TD: SUPV 03/3 TD: SUPV O4/O TD: SUPV 04/C TD: SUP~ ~/90 (12) 1870'( 450) DBJ /90 (13) ,005' ( 135) :DBJ /90 (14) 005' ( DBJ AK 2/90 (15) )005' ( DBJ DRILLING 9-5/8"@ 8394' MW: 9.2 VIS: 40 DRLG TO 8420', CIRC AND COND, PERFORM F.I.T., DRLG TO 8735, CBU, POH W/NORMAL DRAG, SET BACK JARS, ONE COLLAR SET BACK, UNLOAD SERVICES AND'DUMP DATA FROM MWD, BREAK BIT ANd M/U BIT, SERVICE WEAR BUSHING, M/U MONEL L.C., CALIBRATE AND LOAD SOURCES INTO LOGGING TOOL, RIH W/ 1 SET BACK, SHALLOW MWD TEST, RIH, BREAK CIRC AND REAM FROM 8650-8732, DRLG TO 8870'. DAILY:S51,953 CUM:$1,213,487 ETD:S1,525,000 EFC:$2,332,487 The above is correct CIRC & RECIP. LINER @ TD 7"@ 9000' MW: 9.2 VIS: 45 DRLG TO 9005, ADT=5, CBU, PULL INTO 9-5/8" CSG, L/D 8 JARS, RIH TO 8750, P/U KELLY, WASH AND REAM MWD REPEAT PASS FROM 8750 TO 9005, CBU, DROP SURVEY, SLUG PIPE, DROP RABBIT W/100' .092 WIRE ATTACHED, POH, RETRIEVE SURVEY, UNLOAD SOURCES FROM MWD, DROP DATA, RECALIBRATE TOOL, BREAK BIT & SET COLLAR BACK, R/U GBR CSG TOOLS, RUN 23 JTS OF 7',M/U HGR, BREAK CIRC, TIH W/LINER ON 5" DP TAG BOTTOM AT 9005', CIRC AND RECIPROCATE LINER PRIOR TO CMT. JOB. DAILY:S82,260 CUM:$1,295,747 ETD:S1,525,000 EFC:$2,414,747 For form preparatioJ~,,and dis%h-ibution see Procedures Manual Section 10, Drilling, Pages 86 and 87 POH 7"@ 9000' MW: 9.2 VIS: 44 CIRC AND RECIP 7" LINER, BATCH UP DOWELL CMT, PUMP SPACER 300.0,PUMP__325 sX,.CLA_SS G, LAUNCH DART, DISPL RECIP UNTIL LAST 10 BBLS DISPLACED, BUMP PLUG, SLACK OFF, LINER HUNG, BLEED OFF, RELEASE FROM LINER, OBSERVE 25K LBS WT LOSS, POH, L/D TOOLS A/TD PLUG DROP HEAD, L/D STABS, COLLAR, ANADRILL AND MWD, INSTALL WEAR RING, P/U DC'S AND HWDP, M/U RR 8.5 BIT, 9-5/8 SCRAPER, RIH, SLIP AND CUT RIH TO 7590', CIRC AND W.O.C., NOT YET 12 HRS SINCE CIP, WASH TO 7697, TAG SOFT CMT., WASH AND REAM, TAG HARD CMT,DRLG HARD CMT FROM 7750-TOL @ 8085 (ONE HOUR TIM~ CHANGE), CBU, POH. DAILY:S185,797 CUM:$1,481,544 ETD:S1,800,000 EFC:$2,325,544 DISPLACE TOP 600' TO DIESEL 7"@ 9000' MW: 9.2 VIS: 0 0) FINISH POH, L/D 15 JTS DP, M/U 6" BIT, 7" CSG SCRAPER, B/S, TIH W/ 3-1/2 HW, RIH TO 8041, P/U KELLY, BREAK CIRC, TAG T.O.L. @ 8085, WASH AND REAM AT 8116, SET KELLY BACK, RIH TO 8919,-CBU, TEST 7" LINER TO'4000# FO~ 3.0__.~FLIN,. L~T_~50 PSI, ..... ~LC ANXf]9?~X~-~6'~'~A¥ 'COn'L~R-; CIRC, TEST LINE~ ~0M~ .... VISC. PILL, 150 BBL FLUSH H20 AND DISPLACE TO 9.2 ~/GAL BRINE, POH, L/D DP, RIH W/ 6-1/4 DC, RIH W/ 5" HWDP TO 600', DISPLACE TOP 600' TO DIESEL. DAILY:S58,199 CUM:$1,539,743 ETD:S1,800,000 EFC:$2,383,743 AR3B-459-2-B Number all daily well history forms as they are prepared for each well. consecutively JPage no. ARC~..)il and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Rel~ort" on the first Wednesday after allowable has been assigned or welt is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report coml~letio~l end representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ARCO ALASKA INC. Field PRUDHOE BAY Auth. or W.O, no. AS2033 Operator ARCO I !AcCountJng cost center code County or Parish NORTH SLOPE State AK Lease or Unit ADL: 28302 we~ no. WGI-7 ITte DRILL API: 50-029-22031 A.R.Co. W.I. Date Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 04/03 TD: 9 SUPV: Complete record for each day]j~n~ 9 /90 (16) 005' ( 0) DBJ 1 ~1~'~9~1 number of wells (active or inactive) on this ~ ' "l'd%~t center prior to plugging and labandonment of this well 03/1t~/~0 01: 3~(~rlor status if a W,O. RIG RELEASED 7"@ 9000' MW: 9.2 VIS: 0 FINISH L/D HWDP, PULL WEAR RING, SET HGR WITH BPV, N/D STACK, M/U DRLG SPOOL TO STACK, N/U CIW, T/A CAP AND VALVE + TSA, TEST TO 5000# FOR 15 MIN., R/U AND INJECT 132 BBL 50/50 CRUDE/DIESEL INTO WGI-6 AND WGI-7 13-3/8 X 9-5/8 ANNULUS, PBTD IS 8958' MD, RIG RELEASED AT 1500 HRS ON 4/2/90. DAILY:S33,000 CUM:$1,572,743 ETD:S1,800,000 EFC:$2,416,743 Old TD Released rig Classifications (oil, gas, etc.) Producing method INew TD Date PB Depth K nd of rg Type completion (single, dual, etc,) JOff cial reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump si~e, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected Theabovei t ....... ~- For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. iPsge no. Dlvll~on of AtlantlcRIchfleldCompany ORIGINAL SUB.SURFACE DIRECTIONAL SURVEY ~----] UIDANCE ~'~ONTINUOUS ~]OOL Company ARCO ALASKAa INC. W~ll m~Jl'lO WGI-7 {845' FNL,~108$' FEL,SEC ll,TllN,R14E,UMI FieldlLocatlon PRUDHOE BAY, N(~RTH $~OPE, ALASKA Job Reference No. 73853 WARNER Date 8-APR-90 Computed By: KRUWELL GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCD ALASKA, INC. WGI - 7 PRtJDHOE BAY NORTH SLOPE, ALASKA SURVEY DATE: 08-APR-1990 ENGINEER: g. WARNER METHODS OF COMPUTATION TOOL LOCATION: TANGENTI.~L- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 85 DEG 39 MIN WEST COMPUTATION DATE: 15-MAY-90 PAGE ARCO ALASKA, INC. WGI - 7 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 08-APR-199. KELLY BUSHING ELEVATION: 61.00 FT ENGINEER: O. WARNER INTERPOLATED VALUES FOR EVEN ZOO FEET OF MEASURED DEPTH TRUE sUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -61.00 0 0 N 0 0 E 100.00 100.00 39.00 0 7 S 0 26 W ZO0.O0 ZO0.O0 139.00 0 7 N ZB 26 E 300.00 300.00 Z39.00 0 15 S 24 29 ~ 400.00 400.00 339.00 0 16 S 55 24 E 500.00 500.00 439.00 0 18 S 3 27 W 600.00 ' 599.99 538.99 0 28 S 30 57 E 700.00 699.99 638.99 0 27 S 7 52 W 900.00 799.99 738.99 0 24 S 17 11 E 900.00 899.99 838.99 0 32 S 13 24 E 0.00 0.00 0.00 N 0.00 0.01 0.47 O.OB S 0.02 -0.09 0.34 0.15 S 0.08 -0.12 0.23 0.25 S 0.11 -0.50 0.17 0.62 S 0.46 -0.67 0.33 0.92 S 0.60 -0.94 0.37 1.65 S 0.81 -1.02 0.26 2.25 S 0.85 -1.21 1.07 2.95 S 0.99 -1.29 0.55 3.67 S 1.02 0.00 N 0 0 E. 0.09 S 13 56 W 0.17 S 27 56 E 0.27 S 23 25 E 0.77 S 36 21 E 1.10 S 33 11 E 1.84 S 26 15 F 2.42 S 20 33 ' 3.11 S 18 33 Ir. ' 3.81 S 15 27 E 1000.00 999.99 938.99 1100.00 1099.98 1038.98 1200.00 1199.98 1138.98 1300.00 1299.98 1238.98 1400.00 1399.97 1338.97 1500.00 1499.97 1438.97 1600.00 1599.97 1538.97 1700.00 1699.97 1638.97 1800.00 1799.97 1738.97 1900.00 1899.97 1838.97 0 25 S 11 54 W 0 22 S 19 50 E 028 S 8 16 W 0 18 S 10 ¢ E 0 28 S 4 26 E 0 9 S 10 34 E 0 22 S 19 12 E 0 6 S 4 32 E 017 S 40 11E 0 16 S 27 11 W -1.45 0.61 4.28 S 1.13 E -1.59 0.42 5.10 S 1.21 E -1.61 0.26 5.74 S 1.18 E -1.78 0.41 6.47 S 1.30 E -1.76 0.48 7.14 S 1.23 E -1.97 0.39 7.65 S 1.40 E -2.02 0.39 8.12 S 1.41 E -2.31 0.50 8.46 S 1.67 E -2.40 0.32 8.84 S 1.73 E -2.51 0.45 9.05 S 1.83 E 4.42 S 14 47 E 5.24 S 13 20 E 5.86 S 11 34 E 6.60 S 11 2.0 E 7.25 S 9 45 E 7.77 S 10 21 E 8.24 S 9 50 E 8.62 S 11 11 E 9.01 S 11 5 E 9.23 S 11 24 E 2000.00 1999.97 1938.97 ZlO0.O0 2099.97 2038.97 2200.00 2199.96 2138.96 2300.00 2299.96 2238.96 2400.00 2399.96 2338.96 2500.00 2499.96 2438.96 2600.00 2599.96 2538.96 2700.00 2699.96 2638.96 2800.00 2799.95 2738.95 2900.00 2899.94 2838.94 0 4 5 58 W 026 ~ ~7 19 W 0 23 N 66 8 W 0 29 N 65 7 W 0 17 N 14 33 W 0 13 N 38 43 W 0 17 N 63 3 E 015 N 76 2 E 0 53 S 63 0 E I 2 S 61 3 E -2.43 0.30 9.42 S 1.72 E -1.95 0.08 9.40 S 1.24 E -1.26 0.40 9.35 S 0.55 E -0.49 0.14 8.90 S 0.18 W -0.01 0.51 8.57 S 0.64 W 0.21 0.42 8.08 S 0.83 W 0.10 0.10 7.99 S 0.71 W -0.27 0.40 7.76 S 0.32 W -1.09 0.54 8.00 S 0.49 E -2.73 0.56 8.78 S 2.07 E 9.58 S 10 20 E 9.48 S 7 30 E 9.37 S 3 23 E 8.90 S 1 10 W 8.60 S 4 16 W 8.13 S 5 51 W 8.02 S 5 5 W 7.76 S 2 24 ~ 8.01 S 3 30 E 9.02 S 13 17 E 3000.00 2999.92 2938.92 3100.00 3099.91 3038.91 3200.00 3199.91 3138.91 3300.00 3299.90 3238.90 3400.00 3399.89 3338.89 3500.00 3499.89 3438.89 3600.00 3599.89 3538.89 3700.00 3699.89 3638.89 3800.00 3799.89 3738.89 3900.00 3899.88 3838.88 0 56 S 34 9 5 0 46 S 40 22 E 0 36 S 26 27 E 0 42 S 40 I E 0 26 S 53 54 E 0 21 S 10 27 E 0 29 S 14 51 E 0 21 S 21 19 E 0 23 S 16 32 W 0 23 S 0 37 W -3.96 0.03 9.88 S 3.22 E -5.02 0.06 11.08 S 4.20 E -5.71 0.50 11.99 S 4.82 E -6.40 0.35 13.03 S 5.43 E -7.16 0.58 13.62 S 6.15 E -7.52 0.25 14.03 S 6.47 E -7.68 0.00 14.77 S 6.58 E -7.97 0.16 15.48 S 6.81 5 -8.04 0.04 16.06 S 6.84 E -7.93 0.38 16.75 S 6.68 E 10.39 S 18 4 E 11.84 S 20 45 E 12.92 S 21 53 E 14.11 S 22 37 E 14.94 S 24 17 E 15.45 S 24 46 E 16.1T S 24 i E 16.92 S 23 45 E 17.46 S 23 4 E 18.03 S 21 45 E COMPUTATION BATE: 15.-MAY-90 PAGE ARCO ALASKA· INC. WGI - 7 PRUDHOE BAY NORTH SLOPE· ALASKA TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEPTH DEG MIN DEG MIN KELLY BUSHING ELEVATION: 61.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST OIST. AZIMUTH FEET gEG/IO0 FEET FEET FEET OEG MIN 0 12 S 11 17 E -8.08 0.14 17.26 S 6.79 0 20 S ;26 51 W -7.94 0.19 17.68 S 6.62 0 20 S 5 0 E -7.85 0.00 18.31 S 6.48 0 14 S 15 30 W -7.92 0.65 18.80 S 6.52 0 30 S 22 26 W -7.66 0.16 19.43 S 6.21 0 22 S 4 16 E -7.60 0.30 20.19 S 6.09 0 18 S 4 35 W -7.67 O.Z7 Z0.75 S 6.11 0 21 S 34 14 W -7.51 0.0-3 21.2¢ S 5.91 0 20 S 18 17 W -7.Z4 0.18 Z1.79 S 5.61 0 18 S 17 47 W -7.16 0.10 ,?.2.32 S 5.48 4000.00 3999.88 3938.88 4100.00 6099.88 4038.88 4200.00 6199.88 4138.88 4300.00 6299.88 4238.88 4600.00 6399.87 4338.87 4500.00 6499.87 4438.87 4600.00 6599.87 4538.87 4700.00 ¢699.87 4638.87 4800.00 6799.86 4738.86 4900.00 ~899.86 4838.86 0 28 S 52 ,? W -6.82 0.23 22.72 S 5.11 E 0 38 S 51 39 W -6.12 0.00 23.27 S 4.37 E 0 34 S 35 38 W -5.42 0.26 24.05 S 3.61 E 0 25 S 47 I W -4.99 0.17 24.69 S 3.13 E 0 49 S 55 6 W -¢.21 0.68 25.27 S 2.30 E 2 29 N 75 43 W -1.85 3.34 25.55 S 0.09 W 4 56 N 59 27 W 4.23 2.26 22.72 S 5.98 W N 57 49 W 13.47 3.19 17.19 S 14.82 W N 65 19 W 27.44 3.42 9.87 S 28.27 W N 71 55 W 46.39 1.84 2.78 S 46.76 W 5000.00 6999.86 4938.86 5100.00 5099.86 5038.86 5200.00 5199.85 5138.85 5300.00 5299.85 5238.85 5600.00 5399.84 5338.84 5500.00 5499.81 5438.81 5600.00 5599.59 5538.59 5700.00 5699.03 5638.03 7 19 5800.00 5797.84 5736.~4 10 18 5900.00 5895.86 5834.86 12 10 6000.00 5993.31 5932.31 13 50 6100.00 6089.93 6028.93 16 6 6200.00 6185.20 6124.20 19 17 6300.00 6279.05 6218.05 20 46 6600.00 6372.27 6311.27 21 42 6500.00 6464.91 6403.91 22 33 6600.00 6557.00 6496.00 23 22 6700.00 6648.53 6587.53 24 2 6800.00 6739.75 6678.75 24 21 6900.00 6830.74 6769.74 24 38 N 78 51 W 68.44 2.60 N 89 14 W 94.14 3.47 S 87 49 W 124.34 2.91 S 86 46 W 158.57 0.60 S 86 51 W 194.46 0.84 S 87 0 W 231.80 0.73 S 87 23 W 270.46 0.99 S 87 38 W 310.64 0.52 S 88 28 W 351.17 0.42 N 88 37 W 392.51 Z.B5 N 83 45 W 434.24 1.17 N 82 33 W 476.63 0.37 N 82 41 W 519.74 0.47 N 82 53 W 563.59 0.46 N 83 4 W 608.12 0.30 N 83 24 W 653.09 0.21 N 83 28 W 698.40 0.23 N 83 41 W 744.05 0.08 N 83 36 W 789.80 0.17 N 83 46 W 835.73 0.54 7000.00 6921.61 6860.61 24 50 7100.00 7012.16 6951.16 25 20 7200.00 7102.36 7041.36 25 51 7300.00 7192.20 7131.20 26 15 7400.00 7281.72 7220.72 26 40 7500.00 7371.02 7310.02 26 49 7600.00 7460.14 7399.14 27 7 7700.00 7549.10 7488.10 27 13 7800.00 7638.01 7577.01 27 16 7900.00 7726.82 7665.82 27 24 DATE OF SURVEY: 08-APR-199.~ 18.55 S 21 29 E 18.87 S 20 31 E 19.42 S 19 30 E 19.89 S 19 7 E 20.39 S 17 64 E 21.09 S 16 47 E 21.63 S 16 25 22.04 S 15 33 22.50 S 14 26 I::: 22.98 S 13 48 E 23.29 S 12 40 E 23.67 S 10 38 E 24.32 S 8 32 E 24.89 S 7 14 E 25.37 S 5 12 E 25.55 S 0 13 W 23.49 S 14 44 W 22.70 S 40 46 W 29.95 S 70 45 W 46.82 S 86 36 W 2.82 N 68.42 W 68.48 N 87 38 W 5.37 N 94.00 W 94.15 N 86 64 W 4.73 N 124.36 W 124.43 N 87 49 W 3.02 N 158.80 W 158.83 N 88 55 W 0.98 N 194.95 W 194.95 N 89 43 W 1.04 S 232.55 W 232.55 S 89 45 W 2.96 S 271.47 W 271.48 S 89 22 W 4.73 S 311.70 W 311.74 S 89 8 ) ~ 6.13 S 352.65 W 352.71 S 89 0 k ~ 6.52 S 394.16 W 394.20 S 89 3 W 3.44 S 435.76 W 435.77 S 89 33 W 1.74 N 477.87 W 477.87 N 89 47 W 7.35 N 520.68 W 520.73 N 89 11 W 12.84 N 564.26 W 564.39 N 88 42 W 18.31 N 608.48 W 608.76 N 88 17 W 23.63 N 653.18 W 653.61 N 87 56 W 28.81 N 698.22 W 698.82 N 87 38 W 33.93 N 7¢3.61 W 744.39 N 87 23 W 38.98 N 789.11 W 790.08 N 87 10 W 64.08 N 834.79 W 835.95 N 86 59 W COMPUTATION DATE: 1S-MAY-90 PAGL ARCO ALASKA, INC. WGI - 7 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 08-APR-19~. KELLY BUSHING ELEVATION: 61.00 FT ENGINEER: D. HARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE ~EASURED VERTICAL VERTICAL DEVIATION AZIHUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET OEG HIN 8000.00 7815.46 7754.46 27 43 8100.00 7903.90 7842°90 27 56 8200.00 7992.10 7931.10 28 22 8300.00 8079.89 8018.99 28 50 8400.00 8167.25 8106.25 29 29 8500.00 8253.91 8192.91 30 23 8600.00 8339.68 8278.68 31 29 8700.00 8425.00 8364°00 31 17 8800.00 8510.91 8449.91 30 7 8900.00 8598.09 8537°09 28 41 N 84 3 W 881.99 N 84 14 W 928.65 N 84 29 ~ 975.76 N 84 46 W 1023.65 N 84 55 H 1072.29 N 85 17 W 1122.19 N 85 29 ~ 1173.60 N 85 39 W 1225.77 N 85 45 W 1276.94 N 85 55 W 1325.91 0.13 0.21 0 0.37 0.86 1.04 0 0.58 1.47 1.84 49.01 N 880.81 ~ 882.18 N 86 49 53.76 N 927.25 14 928.80 N 86 41 S8.42 N 974.13 ~ 975.88 N 86 34 62.90 N 1021.82 14 1023.76 N 86 29 67.27 N 1070.27 ~ 1072.39 N 86 71.53 N 1119.99 14 1122.28 N 86 21 75.67 N 1171.24 14 1173.68 N 86 18 ~ · ~ 1225.84 N 86 L6 79.73 N 1223.2~, 83.50 N 1274.2~J t~ 1277.01 N 86 15 87.11 N 1323.12 ~1 1325.98 N,86 14 9000.00 8685.81 8624o81 28 42 9005.00 8690.19 8629.19 28 42 N 85 56 W 1373.99 N 85 56 14 1376.39 0.00 0.00 90.52 N 1371.07 W 13'74.06 N 86 13 W 90.69 N 13r3.47 W 1376.46 N 86 13 14 COMPUTATION DATE:' 15-MAY-90 PAGE ARCO ALASKA, INC. WGI - 7 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 08-APR-199~ KELLY BUSHING ELEVATION: 61.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 1000 FEET'OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -61.00 0 0 1000.00 999.99 938.99 0 25 2000.00 1999.97 1938.97 0 4 3000.00 2999.92 2938.92 0 56 ~000.00 3999.88 3938.88 0 12 5000.00 4999.86 4938.86 0 28 6000.00 5993.31 5932.31 13 50 7000.00 6921.61 6860.61 24 50 8000.00 7815.46 7754.46 Z7 43 9000.00 8685.81 862¢.81 28 42 N 0 0 E O. O0 0. O0 S 11 54 W -1.45 0.61 S 55 58 W -2.43 0.30 S 34 9 E -3.96 0.03 S 11 17 6 -8.08 0.1~+ S 52 2 W -6.82 0.23 N 78 51 W 68.44 2.60 N 83 45 W 43¢.24 1.17 N 84 3 W 881.99 0.13 N 85 56 W 1373.99 0.00 0.00 N 0.00 E 0.00 N 0 0 E 4.28 S 1.13 E 4.42 S 14 47 E 9.42 S 1.72 E 9.58 S 10 20 E 9.88 S 3.ZZ E 10.39 S 18 4 E 17.26 S 6.79 E 18.55 S 21 29 E 22.72 S 5.11 E 23.29 S 12 40 E 2.82 N 68.42 W 68.48 N 87 38 I~ 3.44 S 435.76 W 435.77 S 89 33 : ~ 49.01 N 880.81 W 882.18 N 86 49 W 90.52 N 1371.07 W 1374.06 N 86 13 W 9005.00 8690.19 8629.19 28 42 N 85 56 W 1376.39 0.00 90.69 N 1373.47 W 1376.46 N 86 13 W COMPUTATION OATE: 15-MAY-90 PAGE ARCO ALASKAs INC. WG! - 7 PRUDHOE BAY NORTH SLOPEs ALASKA DATE OF SURVEY: 08-APR-199. KELLY 9USHING ELEVATION: 61.00 FT ENGINEER: O. NARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEPTH DEG MIN DEG MIN 0.00 0.00 -61.00 0 0 N 0 0 E 61.00 61.00 0.00 0 8 S 37 51 W 161.00 161.00 100.00 0 8 S 77 9 E 261.00 261.00 ZO0.O0 0 6 S 11 45 W 361.00 361.00 300.00 0 19 S 47 49 E 461.00 461.00 ¢00.00 0 10 S 14 2 E 561.00 561.00 500.00 0 30 S 19 30 E 661.01 661.00 600.00 0 19 S 11 46 W 761.01 761.00 700.00 0 22 S 22 12 E 861.01 861.00 800.00 0 29 S 2 26 W 961.01 961.00 900.00 1061.02 1061.00 1000.00 1161.02 1151.00 1100.00 1261.02 1261.00 1ZO0.O0 1361.02 1361.00 1300.00 1461.03 1461.00 1400.00 1561.03 1561.00 1500.00 1661.03 1661.00 1600.00 1761.03 1761.00 1700.00 1861.03 1861.00 1800.00 1961.03 1961.00 1900.00 2061.03 2061.00 ZO00.O0 2161.03 2161.00 2100.00 2261.04 2261.00 ZZO0.O0 2361.04 2361.00 2300.00 2661.04 2461.00 2400.00 2561.04 2561.00 2500.00 2661.04 2661.00 Z60O.O0 2761.04 2761.00 2700.00 2861.06 2861.00 7800.00 2961.07 2961.00 2900.00 3061.08 3061.00 3000.00 3161.09 3161.00 3100.00 3261.10 3261.00 3200.00 3361.10 3361.00 3300.00 3461.11 3461.00 3400.00 3561.11 3561.00 3500.00 3661.11 3661.00 3600.00 3761.11 3761.00 3700.00 3861.12 3861.00 3800.00 016 S 9 3 E 0 32 S 12 32 E 0 23 S 12 38 W 0 25 S 18 21 E 0 26 S 12 1 W 0 14 S 30 39 E 019 S 2 16 W 0 14 S 52 I E 017 S 8 0 E 0 4 S 14 48 E 0 13 S 6 27 W 0 21 N 83 47 W 0 23 N 85 22 W 0 33 N 56 43 W 015 N 53 6 W 0 18 N 26 27 W 0 8 N 84 38 E 0 15 N 53 22 E 0 32 S 72 51 E I 3 S 64 53 E 0 54 S 42 13 E 0 53 S 41 47 E 0 33 S 31 30 E 0 43 S 30 71 E 0 29 S 55 28 E 0 15 S 36 47 E 0 27 S 7 30 E 0 25 S 19 29 E 0 20 S 0 16 E 0 25 S 13 15 W VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N 0.00 E 0.02 1.24 0.01 S O.OZ W -0.01 0.57 0.18 S 0.00 W -0.09 0.51 0.13 S 0.08 E -0.33 0.17 0.50 S 0.30 E -0.66 0.40 0.77 S 0.60 E -0.77 0.41 1.35 S 0.67 E -1.05 0.56 2.00 S 0.90 E -1.11 0.63 2.73 S 0.90 E -1.24 0.40 3.32 S 0.99 E -1.45 0.41 4.07 S 1.15 E -1.48 0.57 4.81 S 1.12 E -1.64 0.40 5.46 S 1.23 E -1.70 0.24 6.24 S 1.23 E -1.76 0.33 6.83 S 1.25 E -1.91 0.94 7.54 S 1.35 E -1.97 0.34 7.88 S 1.37 E -2.24 0.30 8.39 S 1.61 E -2.31 0.36 8.67 S 1.65 E -2.55 0.43 8.96 S 1.87 E -2.44 0.35 9.33 S 1.74 E -2.22 0.38 9.40 S 1.51 E -1.50 0.30 9.41 S 0.79 E -0.82 0.14 9.07 S 0.13 E -0.11 0.60 8.71 S 0.55 W 0.11 0.41 8.23 S 0.73 W 0.24 0.76 8.05 S 0.85 W -0.13 0.11 7.83 S 0.66 W -0.64 1.01 7.80 S 0.05 E -2.07 0.00 8.46 S 1.43 E -3.54 0.58 9.38 S 2.84 E -4.63 0.39 10.66 S 3.83 E -5.50 0.00 11.66 S 4.63 E -6.09 0.00 12.63 S 5.15 E -6.89 0.06 13.44 S 5.89 E -7.43 0.34 13.85 S 6.40 E -7.60 0.03 14.46 S 6.52 E -7.86 0.78 15.25 S 6.72 E -8.06 0.54 15.82 S 6.88 E -7.95 0.08 16.49 S 6.72 E 0.00 N 0 0 E 0.02 S 62 0 W 0.18 S 0 3 W 0.15 S 30 19 E 0.58 S 30 47 E 0.97 S 38 5 E 1.50 S 26 18 F 2.20 S 24 13 ( ) 2.88 S 18 14 E 3.47 S 16 37 E 4.22 S 15 45 E 4.94 S 13 3 E 5.59 S 12 45 E 6.36 S 11 8 E 6.94 S 10 22 E T.66 S 10 8 E 8.00 S 9 53 E 8.54 S 10 52 E 8.82 S 10 48 E 9.15 S 11 48 E 9.49 S 10 34 E 9.52 S 9 7 E 9.44 S 4 49 E 9.07 S 0 48 E 8.73 S 3 38 W 8.27 S 5 6 W 8.09 S 6 3 W 7.84 S 3 24 W 7.80 S 0 21 E 8.58 S 9 35 E 9.80 S 16 51 E 11.33 S 19 45 E 12.54 S 21 38 E 13.64 S 22 11 E 14.67 S 23 39 E 15.26 S 24 48 E 15.86 S 24 16 E 16.67 S 23 47 E 17.26 S 23 30 E 17.80 S 22 11 E COMPUTATION DATE: 15-MAY-90 PAGE ARCO ALASKA, [NC. WG! - 7 PRUDHOE BAY NORTH SLOPE, ALASKA TRUE SUB-SEA COURSE MEASURED VERTICAL VERTZCAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG DATE OF SURVEY: 08-APR-19b. KELLY BUSHING ELEVATION: 61.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL OOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE SECTZON SEVERZTY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG NIN 0 17 S 18 43 E -8.02 0.12 17.11 S 6.75 E 0 19 S 30 2¢ W -8.03 0.22 17.48 S 6.72 E 0 24 S 6 43 W -7.84 0.38 18.06 S 6.49 E 0 17 S 4 53 E -7.92 0.17 18.62 S 6.52 E 0 28 S 26 13 W -7.78 0.21 19.13 S 6.34 E 0 26 S 5 44 W -7.58 0.36 19.92 S 6.09 E 0 19 S 2 39 E -7.66 0.12 20.54 S 6.12 E 0 21 S 29 12 W -7.62 0.43 21.03 S 6.04 E 0 22 S 27 56 W -7.32 0.23 21.57 S 5.70 E 0 18 S 10 55 W -7.19 0.00 22.12 S 5.53 E 3961.12 3961.00 3900.00 4061.12 4061.00 4000.00 4161.12 ¢161.00 4100.00 4261.12 4261.00 4ZO0.O0 4361.12 4361.00 4300.00 4461.13 4461.00 4400.00 4561.13 4561.00 4500.00 4661.13 4661.00 4600.00 4761.13 4761.00 4700.00 4861.14 4861.00 4800.00 0 19 S 51 0 W -7.01 0.39 22.55 S 5.32 E 0 32 S 54 17 W -6.42 0.40 23.02 S 4.69 E 0 39 S 40 28 W -5.65 0.11 23.73 S 3.86 E 0 26 S 36 14 W -5.17 O.ll 24.48 S 3.32 E 0 35 S 56 51 W -4.58 0.32 25.01 S 2.69 E I 32 S 83 41 W -3.17 2.51 25.68 S 1.23 E 4 2 N 62 40 W 1.49 2.36 24.20 S 3.34 W 6 12 N 57 29 W 9.51 2.89 19.60 S 11.02 W N 62 16 W 21.56 3.17 12.67 S 22.59 W N 69 47 W 39.26 1.53 5.21 S 39.76 W 5762.62 5761.00 5700.00 9 14 5864.37 5861.00 5800.00 11 45 4961.14 ~961.00 4900.00 5061.14 5061.00 5000.00 5161.15 5161.00 5100.00 5261.15 5261.00 5200.00 5361.15 5361.00 5300.00 5461.17 5461.00 5400.00 5561.30 5561.00 5500.00 5661.70 5661.00 5600.00 N 76 31 W 60.73 2.37 N 86 41 W 86.01 3.45 S 88 12 W 116.14 3.32 S 86 52 W 151.82 0.67 S 86 50 W 190.02 0.95 S 86 59 W 230.20 0.77 S 87 23 W 272.t9 0.96 S 87 43 W 315.97 0.50 S 88 42 W 360.76 0.53 N 86 31 W 406.37 2.55 5966.76 5961.00 5900.00 13 14 6069.95 6061.00 6000.00 15 20 6174.43 6161.00 6100.00 18 29 6280.70 6261.00 6200.00 20 36 6387.87 6361.00 6300.00 21 36 6495.77 6461.00 6400.00 22 31 6604.36 6561.00 6500.00 23 24 6713.65 6661.00 6600.00 24 5 6823.33 6761.00 6700.00 24 26 6933.29 6861.00 6800.00 24 37 N 82 58 W 452.57 0.77 N 82 29 W 499.84 0.81 N 82 53 W 548.28 0 N 82 59 W 597.73 0.42 N 83 22 W 648.03 0.20 N 83 28 W 698.84 0.23 N 83 42 W 750.16 0.11 N 83 35 W 801.67 0.31 N 83 51 W 853.48 0.66 N 84 11 W 905.96 0.31 7043.45 6961.00 6900.00 25 5 7154.09 7061.00 7000.00 25 36 7265.23 7161.00 7100.00 26 6 7376.82 7261.00 7200.00 26 36 7488.78 7361.00 7300.00 26 48 7600.96 7461.00 7400.00 27 7 7713.38 7561.00 7500.00 27 14 7825.88 7661.00 7600.00 27 20 7938.52 7761.00 7700.00 27 31 8051.46 7861.00 7800.00 27 49 18.39 S 21 31 IE 18.73 S 21 2 E 19.19 S 19 45 E 19.73 S 19 18 E 20.15 S 18 21 E 20.83 S 17 0 E Zl.44 s 16 35 ~ 21.89 S 16 1 [ 22.31 S 14 48 E 22.80 S 14 2 E 23.17 S 13 16 E 23.49 S 11 31 E 24.04 S 9 15 E 24.71 S 7 43 E 25.15 S 6 8 E 25.71 S 2 44 E 24.42 S 7 51 W 22.49 S 29 21 W 25.90 S 60 43 W 40.10 S 82 32 W 1.16 N 60.82 W 60.83 N 88 55 W 5.09 N 85.87 W 86.02 N 86 36 W 5.01 N 116.10 W 116.21 N B7 32 W 3.40 N 15Z.00 W 152.04 N 88 43 W 1.23 N 190.47 W 190.47 N 89 38 W 0.96 S 230.94 W 230.94 S 89 46 W 3.04 S 273.20 W 273.22 S 89 22 W 4.96 S 317.26 W 317.30 S 89 6 W ,~ 6.37 $ 362.28 W 362.34 S 89 0 ¼ ~ 5.86 S 407.99 W 408.03 S 89 11W 1.32 S 453.91 W 453.97 S 89 50 W 4.77 N 500.92 W 500.94 N 89 27 W 10.94 N 549.03 W 549.14 N 88 52 W 17.05 N 598.16 W 598.40 N 88 22 W 23.05 N 648.15 W 648.56 N 87 58 W 28.86 N 698.66 W 699.25 N 87 38 W 34.6! N 749.70 W 750.50 N 87 21 W 40.31 N 800.92 W 801.93 N 87 7 W 46.00 N 852.45 W 853.69 N 86 55 W 51.47 N 904.67 W 906.13 N 86 45 W COMPUTATION DATE: 15-MAY-90 PAGE ARCO ALASKA, INC. WGI - 7 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 08-APR-19~. KELLY BUSHING ELEVATION: 61.00 FT ENGINEER: O. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8164.69 7961.00 7900.00 28 9 8278.45 H061.O0 8000.00 28 45 8392.B2 H161.O0 8100.00 29 25 8508.2Z 9261.00 8200.00 30 28 8625.00 8361.00 8300.00 31 31 8742.05 8461.00 8400.00 30 56 8857.64 8561.00 8500.00 29 9 8971.72 9661.00 8600.00 28 42 9005.00~8690.19~ 8629.19 28 42 N 84 22 W 959.05 N 84 44 W 1013.27 N 84 54 W 1068.76 N 85 18 W 1126.35 N 85 30 W 1186.66 N 85 50 W 1247.49 N 85 47 W 1305.45 N 85 56 W 1360.41 N 85 56 W 1376.39 0.60 0.39 0.85 1.09 0 1.22 I .85 0.00 0.00 56.79 N 957.50 W 959.18 N 86 36 ~ 61.94 N 1011.48 W 1013.38 N 86 30 W 66.96 N 1066.76 W 1068.86 N 86 25 W 71.87 N 1124.14 W 1126.43 N 86 21 W 76.70 N 11~4.26 W 1186.74 N 86 18 W 81.35 N 1244.91 W 1247.56 N 86 16 W 85.61 N 1302.71 W 1305.52 N 86 14 W 89.56 N 1357.53 W 1360.48 N 86 14 ' ] 90.69 N 1373.47 W 1376.46 N 86 13 W ..... COMPUTATION DATE: 15-MAY-90 PAGE ARCO ALASKA~ INC. WGI - 7 PRUDHOE BAY NORTH SLDPE~ ALASKA NARK~R 13 3/8" CASING 7" CASING TOP SaG 9 5/8" CASING SHUBLIK TOP SAD ZONE 4 ZONE 3 ZONE 2 ZONE ~B LAST GCT READING GOC PBTD BASE SAD 7# CASING BTM TO DATE OF SURVEY: 08-APR-195. KELLY BUSHING ELEVATION: 61.00 FT ENGINEER** 0. WARNER INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 8¢5e FNL ~ 1085~ FEL~ SEC1! TllN R14E~UH MEASURED DEPTH TVO BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 8903.00 8600.72 8539.72 87.21 N 1324.62 8944.00 8636.69 8575.69 88.61 N 1344.25 8958.00 8648.97 8587.97 89.08 N 1350.96 8994.00 8680.54 8619.54 90.31 N 1368.20 9000.00 8685.81 8624.81 90.52 N 1371.07 9005.00 8690.19 8629.19 90.69 N 1373.47 3485.00 3484.89 3423.89 13.95 S 6.45 E 8085.00 7890.65 7829.65 53.06 N 920.26 W 8387.00 8155.93 8094.93 66.70 N 1063.92 W 8394.00 8162.03 8101.03 67.01 N 1067.33 N 8450.00 8210.68 8149.68 69.42 N 109~.96 W 8503.00 8256.50 8195.50 71.65 N I121.51 W 8503.00 8256.50 8195.50 71.65 N 1121.51 W 8596.00 8336.26 8275.26 75.51 N 1169.16 W 8672.00 8401.08 8340.08 78.62 N 1208.72 W 8887.00 8586.69 8525.69 86.66 N 1316.89 W COMPUTATION DATE: 15-MAY-90 PAGE ARCO ALASKA, WGI - 7 PRUOHOE BAY NORTH SLOPE, INC. ALASKA MARKER 13 3/5" C~SING 7" CASING TOP SAG 9 5/8" CASING SHUBL[K TOP SAD ZONE ~ ZON~ 3 ZONE 2 ZONE lB L~ST GCT READING GOC PBTO BaSE SAD 7" CASING BTM TO ***********', STRAT[GRAPHIC SURFACE MEASURED DEPTH BELOW KB 3485.00 8085.O0 8387.00 8394.00 8450.00 8503.00 8503.00 8596.00 8672.00 8887.00 ssOs.oo 8944.00 8958.00 8994.00 9000.00 9005.00 DATE OF SURVEY: 08-APR-19gu KELLY BUSHING ELEVATION: 61.00 FT ENGINEER: O. WARNER SUMMARY ************ LOCATION = 845' FNL & TVD FROM KB SUB-SEA 3484.89 3423.89 7890.65 7829.65 8155.93 8094.93 8162.03 8101.03 8210.68 13149.68 8256.50 8195.50 8256.50 ~195.50 8336.26 8275.26 8401.08 8340.08 8586.69 8525.69 8600.71 8539.71 8636.69 8575.69 8648.97 8587.97 8680.54 8619.54 8685.~! 86Z4.St 8690.19 8629.19 1085' FEL, SECll TllN R14E,UM RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 13.95 S 6.45 E 53.06 N 920.26 W 66.70 N 1063.92 W 67.01N 1067.33 W 69.42 N 1094.96 W 71.65 N 1121.51 W 71.65 N 1121.51 W 75.51 N 1169.16 W 78.62 N 1208.72 W 86.66 N 1316.89 W 87.21 N 1324.62 W 88.61 N 1344.25 W 89.08 N 1350.96 W 90.31 N 1368.20 W 90.51 N 1371.07 W 90.69 N 1373.47 W FINAL MEASURED DEPTH WELL LOCATION AT TD: TRUE SUB-SEA VERTICAL VERTICAL DEPTH DEPTH 9005.00 8690.19 8629.19 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 1376.46 N 86 13 W SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA, !NC. NELL NOI - ? FIELD PRUDHOE BAY COUNTRY USA RUN ONE DATE LOOOED 08 - APR - 90 REFERENCE f WELL · WGI-7 (845' FNL, 1085' SEC ll, TllN, R14E, UM) HORIZONTAL PROJECTION ~CRLE --. l ! ~ I N/FT I60I:l lO00 SOUTH -2000 -ISO0 -lO00 -600 0 500 1500 WELL- WGI-7 (845' FNL, 1085' F'~'-~ SEC ll, TllN, R14E, UM) VERTICAL PROJECTION 0 0 600 lO00 2OOO 274. F~O,~CTI~ ON VERTICAL PL~ L~74. - 94. 6Q:)LED IN VERTICal. OEPTH~ HORIZ SCALE = I/,~00 IN/FT ORIGINAL W~Gi(~'TIC 1)t~LI~TI~ 30,75 AT. IRLrI"H ~ ~p~l lA~l~ TO IARGEi I$ 274,35 ~ I~ DEF'~H DEPIq~ ft ft ft 0,~ 0,0 0°00 991.76 ~5.8 991 °72 1485.31 493,5 1485,26 19~.52 498.2 1983.~ 24~,97 3010.53 3444.69 3780.63 40?3,88 4433,91 4775,3~ 5087.35 5338.67 5467,64 5530,59 ~91,07 b'7~,~ 5-/52.65 57~,29 5~,20 59(79,12 5~'.J8,86 5969.76 6001.83 6033,38 6064,58 492.5 2475,90 534.6 3010,44 434.2 3~,60 335.9 37~,53 313,3 4(3~73,78 ~.0 4433,~ ~1,5 4775,28 312.0 ~7,~ ~1,3 5~.54 1~,0 5467,47 62,9 5530,~ dK3,9 5594,01 96,6 5690,01 31,5 5,/721,17 30,1 5750,9~ 30,6 5'/81,15 31,6 5812,19 31,3 5042,89 31,7 5873,89 31,2 29,7 59'33,42 30,9 5963,53 32,1 5~4,70 31,5 6025,26 31,2 6055,41 ~96.1.4 31.6 6085,81 612.7.9<3 31,8 6116,31 61~,11 2)0,2 6145,10 6220,67 62,6 6204,25 6408,23 187.6 ~79,51 6586,93 178,7 6544,55 6775,38 188,4 6716,92 7003,41 ~8,0 6924,20 7247.82 244.4 7144.70 7556.31 308,5 7420128 ~DI-? SL~:~Y CAI~'3JLATIONS TAR~G~ 5'TATI C)N AZIMLrI'H LATITUDE $i~1'I0~ INCLH, ft d~ deg ft 0,00 0,00 0,00 0,00 2.Z7 0,75 201,01 -0,43 3.53 0.49 195,19 -5,45 2,16 0,15 107,14 -7,64 2,76 0,30 ~8,50 -6,43 DEPA~URI~ DISPLACE)RENT at F../-W ft ft 0,00 -2,31 2,35 -3,~ 6,73 -2,75 8.11 -3,~ 7.21 2,30 0,35 31.67 -4,01 -1,41 0.63 157,51 -4.31 -2.74 0,16 156,33 -7,07 -2,84 0.52 196,81 -9,01 -2,49 0,15 192,08 -10,77 AZIMUTH 0,00 259,~ 215.95 1~.78 2O6,82 DLS lOOft 0,00 0,15 0.05 0,10 7,51 3.55 302,38 -14,78 11,70 4,99 302,43 -12,~ 21.33 7,88 300,69 -6.57 25.26 8,20 ~1,~ -4,30 29,30 8,97 29'7,32 -2,02 -8,65 17,13 210,34 2,26 -12,67 17,61 225,99 2,26 -21,89 22,~. 253,30 3,00 -~,66 26,02 260,50 1,07 -29,~ ~,61 2~,08 2,76 33,97 10,34 298,90 0,~ 39,44 11,10 292,~ 3,03 45,37 11,76 2?0,39 5,2)0 51,73 12,29 289,49 7,55 58,I9 12.40 287,6.~ 9.69 -34,03 34,03 2.70.~ 4,48 -3~,32 39,44 274.40 4,43 -45,0~ 45,40 2.76,70 2,52 -51,30 51.~ 278,38 1,~ -57,~ 58,43 279,55 1,17 ~,~ 12,~ 286,07 11,5-/ 71,32 13,27 283,31 13,33 78,82 14.05 281,26 14,94 86,6I 14,68 279.38 16.~ 94o~ 15.19 274.19 17,2)0 -~,80 ~,84 280,28 1,61 -70,51 71,76 2~,71 2,77 -77,91 79.33 280,~ -85,6I 87,16 280,81 2.48 -93,59 95.18 280.47 4,59 103.~ 15.88 272.47 17,79 112,04 16,86 ~'0.61 18,03 121.07 18,03 ~70.70 18,13 141,~ 19,97 269.69 18,06 207,81 21,75 267,28 16,30 Z75.~ 23,33 269,30 14,25 ~1,76 24,36 268,58 12.04 446,67 24,~ 277,14 17,58 551.89 26,20 Z78,56 31.98 690.2.7 2.7,21 276.94 50,67 -102,03 103,5-/ 279,89 2,63 -110,99 112,45 279,~ 3,5'5 -1~.~ 121,41 278.59 3,81 -140,41 141,57 277,33 3.I4 -2t)7,I7 207,81 274,~ !,05 -Z'~,63 276.00 272.96 0,98 -351,80 352,~ 272,09 0,57 -4~5,63 4~,97 272,Z5 1,~ -551,05 551,97 2.73,~ 0,59 -688,41 690,27 274,21 0,40 -1,86 0,40 222,62 -12,20 0,~ 12,24 1~,62 0,08 -1,01 0,15 208,21 -13,55 -0,02 13.55 180,09 0,07 0,11 0.62 ~4.~ -15,~ -1,27 15.28 104.76 0,15 1,61 0,37 231,55_ -16,67 -2,88 16,91 189,81 0,10 4,50 2,32 288.19 -16,16 -5,74 17.15 199,50 1,66 -2,6I 4,78 213.03 0.10 1.09 4,44 165.80 0,16 2,21 7,41 162,63 0,1! 2,16 9.26 1~.49 0,12 1,~ 10,90 171.15 0,12 PAG£ ,mw~,m~,m, SURV~ ANALYSIS ~'ANY AR'CO ALASKA I~. WHI.L MAM~ WGI-7 LOCATI~ 1 PRUDHOH BAY ~TION 2 ALASKA DATE: 28-MAR-~ MA(iMk'YIC DF. CI. IMA'I'ION WElL MUMB~ P~-~ NO, 3 WGI-7 ~ II~t~L ~EI~IC~L T~g~T ~ATI~ ~ZI~ DBq]4 ~ ~I~ I~. ft ft ft ft d~ 7872.~ 316,0 ~01.~ ~.~ ~.~ ~,~7 ~1~,~ ~3.0 7~.14 ~2.37 ~,77 ~6.66 8~',74 214.4 8113,51 1~,71 ~,10 ~6.74 ~18,16 ~8.4 ~3,52 11~,71 31.79 ~5,02 LATIll~£ I)~ARTI~ DI~IY~ at AZIMUTH DIS ~/-S ~-W deg./ ft ft ft ~ lOOft 67.3'J -832,12 &..qS.01 274,76 0,15 ~4.21 -94~,71 ~2.~ 27%07 0,32 96,16 -1050,44 1054.83 275,~ 0,S3 110,62 -1190.75 1195.~8 275,31 1,01 126,77 -1332,12 1338.14 275,44 1,25 9004,00 102,8 8~,42 137,02 28,60 2.76,30 132,90 ~ AT iK)04 IS A Ff,~i~ SLRt~Y AT 8.5 ~I.~ 'I'D -1380,92 1387.30 2.75,50 0,80 ft 1tm i~c_c~ 0,0 0,00 506.0 505.99 0,75 991,8 991,72 -0,26 1485.3 1485,26 -0.35 1983,5 1983,46 0,15 2476.0 3010.5 3444,7 37~0.6 4093,9 4433.9 4775.4 5087.4 5'338.7 5467,6 5530,6 5594.5 5691,1 57~2.5 5752,6 5783.3 5814,9 5846,2 5877.9 5909,1 5~,9 5969,8 6~)01.8 6.033.4 6064,6 60%,1 6127,9 6158,1 6220,7 64~.2 6586,9 6775,4 7003,4 7247.8 7556.3 2475.90 0,05 3010.44 0,28 3444,60 -0,48 3780,53 0,~ 4093.78 -0,37 4433,80 0.25' 4775,28 -0,25 5O87.23 0,46 53~8,54 -0,25 5467,47 5530,33 1,23 5594,01 1,44 5690,01 2,89 5721,17 0,32 b-~.95 0,77 578!.I5 1,37 5812,19 0,76 5842.89 0.66 5873,89 0,53 5904,39 0,11 5933,42 0,28 5963,53 0.59 5994.70 0.78 6025.26 0.63 6055.41 0.51 6085,81 0,69 6116,31 1,00 6145,10 1,15 6~,25 1,94 (..3.79,511,78 6544.55 1,58 6716.~ 1,03 6924,~ 0,~ 7144,70 1,30 7420,28 1,01 CL~I~_CHG I_RAT~ AZM_CHG CU~.CHG deg deg/lOOft d~ deg deg/lOOft 0,00 0.00 0.00 0.00 0,00 0.75 0.15 ~.!.01 201.01 39,73 0.49 -0,05 -5.82 195.19 -1,20 0,15 -0.07 -88.05 107.14 -17,84 0,30 0.03 191.36. 298.~0 38.4I 0,35 0.0! 93.17 391.67 0,63 0,05 125,84 517,51 0.16 -0.11 0.83 5i6.~ 0,52 0.11 40.48 ~8,8I 0.15 -0,12 -6.73 552.08 18.92 23,54 0.19 12,06 -2.15 0,40 0,07 30.54 582.62 0,15 -0,07 -t4.41 56.8,21 0,62 0,I5 16.79 584.99 0.37 -0.10 6.~ 591.55 2,~ 1,51 ~.~ 6.4.8.19 8.98 -4,22 5.38 2,61 43,92 3,55 1.95 14.t9 66.2.38 4.99 2.25 0.0~ 662.43 7,86 2,?? -1.74 660.69 8,20 1,02 0.75 661.44 8,97 2.56 -2.12 659,~ 2,38 -7,04 10,34 4+47 -0.42 6~.90 11,10 2,41 -6.32 652.58 11,76 2.11 -2.19 12.29 1,67 -0.?0 64~.49 12,40 0,35 -1.63 647,86 -1,37 -20.01 -6,9~ -2,84 -5,22 12,68 0,94 -1,79 646.07 13.27 1,91 -2.76 643,31 14,05 2.43 -2,~ 641,26 14.6a 2.00 -1,~ ~.38 15,I9 1,63 -5.19 634.19 -6,02 -8,~ -6,~ -5.96 -16.~ 15,88 2,19 -1,72 632.47 16,88 3.15 -1,~' 690.61 18,03 3,81 0.~9 630.70 19,97 3,10 -1,01 629,69 21.75 0,~5 -2.41 627,28 -5,45 -5,85 0,~ -1,61 -1,28 23.33 0,86 2.02 629,~ 24,36 0.55 -0.72 626.~ 24,~ 0.24 8.56 637.14 26,20 0,53 1.42 638,56 17,21 0.~ -1.62 636,94 1,13 3,75 0.58 -0,53 CI~ TOOL_FACE DIS ft deg deg/lOOft deg/lOOft~2 0.00 0,00 0,00 0,00 0.60 0,00 0,15 0,03 5,73 169,74 0,05 0.02 7,82 162,96 0,10 0,01 0,00 0,00 0,09 4,20 132.09 0.10 0,00 4.21 144.25 0,16 0.01 6.86 0,00 0,11 0.01 8,82 53.29 0,12' 6,66 170.13 0.12 12,10 45.03 0,08 0.01 13,51 171.62 0,07 O,OO 15.28 20,06 0,15 0,02 16.84 171.07 0,10 0.02 10,61 176.74 1.66 1,21 15.40 37.78 2,26 0,95 13,16 0.00 2,26 0,00 8,21 4.75 3,00 0,77 6,23 17.94 1.07 6,14 16,54 64,92 2,76 5~63 2.11 3.00 4,48 5.59 -0,04 60,24 4.43 0,16 -1,87 34.35 2.52 6.(YP -3.64 19,75 1.77 2,36 4,26 23,34 1,17 1,93 -6.70 55,09 1,61 1.49 -7.95 47,76 2,77 3.75 -8,99 32,80 2,86 0.29 -9,81 37.41 2,48 1.20 -5,29 73,24 4.59 6,74 -10.00 34.52 2,63 6.21 -9,56 28,54 3,55 2.90 -8,97 0,69 3.81 0,66 -7,36 10,08 3.14 1,06 -10,15 71.65 1,05 1,12 6,6? 27,02 0.98 0,04 13,88 16.05 0.57 0.22 16.35 85.30 1,58 0.44 9.91 ~.83 0.59 0.41 -0,54 26,85 0.40 0.06. P~E NO, 3 ~GI-7 f~ f~ d~ deg de~y'lOOft cle~ deg de~/lOO~t f~ d~j deg/lO(~f~ 7872,3 7701.0~ 0.18 27.39 0.06 0,93 637.87 0.29 -6.03 67,52 0.15 0.08 8125.3 7925,14 0,58 27.97 0.23 -1.21 636,66 -0.48 -12,01 44.61 0,32 0,07 &339.7 8113,51 1.13 29,10 0.53 0,~ 636,74 0.04 -16.21 1,48 0.53 0.10 8618.2 8353.52 2,69 31.79 0,97 -1,72 65,02 -0,62 -19,98 18.66 1,01 0,18 8901,2 8598,13 -3.20 28,59 -1.13 2,~ 638.01 1.06 1,69 36,49 1,25 0,08 9004.0 8688.42 0,01 28.60 0,01 -1,?! 636,30 -1,67 -27,77 ?0.01 0,80 0,44 S%FdJEY AT 9004 IS A PRCk~ SUFUJEY AT 8,5 {-tCI~ TD, COMPLETION DATE t~ I ~ ! ~O CO. COt~-ACT I ........ ^o~c'c 'G~)LOGICAE'MATERiALs INVEI~ToRY LIST .............. ,, [ check off or,!is~t~lata' as it is re~7.e.ived ] .,co,re.d irlt~ ,rvals co,r,e,.allalySis ......... dry,ditch !nterva, is ,, dig.ital data ....................... iiiiii ii i i i il iiiiii ill _ i i i ii i iiii i i i iiiii ii . i i ii i i ii ii i i i i i i! i iii i i ii i i i ,! .................... ! ................................ I , , , .... E0G T~PE .... RUN iNTER~AL~ ...... SCALE NO. ~'1 ,,~r~ .z:,~. ,~./ £~..,/e I.-~ .. " .,9 "~ .r' " ...... ~ ....... c~,~ .... ~ , ~ ..... Sl Co//~- Z../ / ?~,~ '- ~o ~,' .<-" ............ ~ ..................... ...... ..... ~l c~?. ." / .,, ~2~/- fi~x~ ~ .... i OI .... I . , ,, · _ .... ................. ~ ..................... ~ al .................. ~ . , ......... ~! ........... ...... ...... ~ ,,, ..... , .... ,, .... , .......... i iiii i i ii iii i LIIII IIIIII III lllll I I I I III I IIII Il I I I I I IIII ARCO ALASKA, INC. P.O. BOX i00S60 ANCHORAGE, ALASKA 995 t O DATE' 6/12/90 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 COMP. NEUI'RC)N G/R 2-i3 6-9-90 COLLAR 2-23 6-8-90 COLLAR 3-20 6-7-90 COMP. NEUTRON G/R S-22 6-7-90 CONF'. NEUTRON G/R 4-t6 6-7-90 COMP. NEUTRON G/R 4-23 6-8-90 COMP. NEUTRON G/R 4-24 6-8-90 COMP. NEUTRON G/R 5-6 6-i0-90 COMP. NEUIRON G/R 7-9 6-9-90 COMP. NEUTRON G/R 7-9 6-9-90 DIFF. TEMPERATURE 7-34 6-9-9~ COMP. NEUTRON G/R i2-i8 6-4-90 CET t2-t8 6-4-90 CBT 6-~ 5-29-90 CBT 6-~ 5-29-90 G/R 6-~ 5-29-9~ CET WGI-5 6-3-9~ PERF RECORD WGI-6 5-30-9~ PERF RECORD WGI-7 6-i-9~ PERF RECORD WGI-8 6-2-90 PERF RECORD RUN i, 5' RUN ~, 5' RUN i, 5' RUN i, RUN i, 5' RUN RUN RUN t, 5' RUN t, 5' RUN RUN RUN RUN t, 5' RUN RUN i, RUN t, RUN i, RUN RUN i RUN RUN i, S' RUN i, 5' RUN i, 5' PLEASE SIGN AND RETURN THE ATtAiNTED RECEIVED BY __~ COPY AS RECEIPT OF DATA. HAVE A NICE DAY! SALLY HOFFECKER ATO- i 529 AFiF'ROVED~ TRANSA 9~218 ATLAS ATLAS A'I'LAS Al'LAS A'f'LA$ ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS Al'LAS A I'LAS ATLAS SCH SCH $CH SCH $CH SCH SCH SCH SCH DISTRIBUTION CENTRAL FILES CHEVRON D&M EXTENSION EXPLORATION EXXON MARATHON MOBIL ¢ PHILLIPS F'B WELL F'ILES R & D -,-"' BPX STATE OF- ALASKA TEXACO F':. 0 ~ BOX A N C' I'-I 0 F.' A C; E A L A DATE' REFERENCE' ARCO CA~ED HOLE F'INAL~ t -7 5-23-.90 COLLAR t -.9 5-2S-.9~ PFC 5-4 5-27-.90 COLLAR &-t 2 5-26-~(~ F'DK-t ~](~ G/L CCI_ 9-i 5-2t-9¢ PERF' RECORD 9-S 5-21-9¢ F'ERF RECORD t.t-5 5--27-9(~) F'DK-t ¢¢ G/R CCL t~-tS 5-2'7-9e PDK-tee G/R CCI_ tt-t6 5:-28-9¢ COMF'., NEUTRON G/R i4-7 5-26-9¢ CONF'. NEUTRON G/R t5-4 5-24--9(~ 5'ONAN t5-4 5-24-9(D DIFFERENTIAL TEMF'. WGI-7 ~-22-9~ COLLAR WG]:-8 5-24-9c~ COL. LAR RUN RtJN RUN RUN R U N F,:. U N RUN R U N RUN I:;: tJ N RUN RLIN F;: U N RLIN PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIF'T OF DATA. RECEIVED BY __~_ HAVE A NICE DAY! ~ - 4 1990 .?ALLY HOF-FECK ER A $ o- t s 2.9 Alas~ Ol~ & Gas Gons. ,,om~lssto~ AF'F'ROVED~ TRAN~'~ 9~'Jt98 DISTRIBUTION ~ CENTRAL FILE£ .,- PHILLIPS ~ CHEVRON F'B WELL F:'IL. ES' D & M R.& D ~ E,.TEN$ION EXF'LORATION ' ~ BF'X ~ EXXON ~ STATE OF ALA,~'KA HARATHON ]E,.ACO · ~ MOBIL ARCO AI_A~'I<A, ]:NC:. F' .,. 0 ,, BOX 'i () ,:) S 6 ,:.'} ANCHORAGE, AI_A~KA DATE' 5-t 5-90 f. EF ERENCE ARCO 995i0 CA,S'ED HOLE F'INALS' 2-29A 4-29-9,?) AFTER FRAC SURVEY RUN 5.--t 4-24-9(-.'). F'RODtJCTION F'ROFILE RUN 5-t 7 4--27-9,r'.) PRODUCT]:ON PROFILE RUN 5-t9 4-25-9G F'RODUCTION PROF'ILE RUN 5-25 4-27-9¢ PRODLJCTION PROFILF RUN t I -t 6 5--i t -90 COL. LAR/F'ERF RUN t t -i 7 5-t I --90 COI..LAR/PERF RUN i t t-2'2 5-S-9~) CBT RUN t t o,') ' , -.~.~. 5-3'-c;'0 CET RUN tl-'24 4-25-9e LEAK DETECTION SURVEY RUN i 3-t 0 3-25-9¢ TEMP RUN t3-26 4-28-9¢ LEAK DETFjCTION SURVEY RUN t6'-4 4-28-9e GAS LIFT SURVEY RUN WC,, I-7 ~/9-t ¢/9¢ CCL RUN C A H C. 0 C.. A H C 0 C A H C. 0 C A M C 0 C A M C 0 ATLA'? ATLA.? ~ C I--I SCFt CAMCO FILS' (]ANCO C, AMCO Al'LA;:,,* F'LEAS'E £'IGN AND RETURN THE ATTACHED COPY A~' RECEIPT OF DATA, RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-i529 DISTRIBUTION CENTRAL FILE~ CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIF'S PB WEL. L FIL. E~' R & D BF'X STATE OF ALA~'KA I'EXACO RECEIVED MAY 1 81990 ~s~, Oil & Gas Cons. Commission ..... , ~omge ARCO ALASKA, INC. P.O. BOX 't00360 ANCHORAGE, ALASKA DATE' .4-24-9~ REFERENCE' ARCO CASED HOLE FINALS 5-4 4-i 5-90 COLLAR/F'ERF RUN 7- i 0 4-9-90 CCL/PERF RUN t 3-26 4-t :2-90 COLLAf;,'/F'ERF' RUN t 4-i 5 4-t i -90 COLLAR/PERI-- RUN t 4-t 7 4-t 5-9() COLLAR RUN t 4-:54 4-t 4-90 COLLAR/F'ERF RUN W(.;. ]:--7 4-8-90 GR/CCL RUN 1¢,161-7 4-8-90 CBT RUN WGI-7 4-8-9¢ CET RUN F'LEA3'E ZIGN AND RETURN 'THE ATTACHED COF'Y AZ RECEIPT OF DA'FA. RECEIVED BY ....... HAVE A NICE DAY! A TO- ATLAZ ATI_A3~ ATL..AZ ATI_ASJ A"f'LAZ A TI.,A 5; ,'.;.' C H L9 CI--t SCI--I DISTRIBUTION CENTRAL FILES ~ · , PHILLIPS CHEVRON PB WELL. FILES D & M R & D EXTENSION EXPLORATION ~ BF'X EXXON ~ STATE OF ALA~'KA MARATHON TEXACO MOBIL ARCO ALA2KA, ]:NC. F'~O. BOX i00S60 ANCHORAGE, AL. AS'KA 99Ei0 DATE' 4-19-90 REFERENCE- ARCO MAGNETIC TAPE(Y) WITH WGI--7 3/29-S0/90 MW][) ~ rTZ'~~ JOB,S76884 JOB~:9~OS~i~ PL. EASE &~IGN AND RETURN THE ATTACHED COPY A2 RECEIPT OF DA'I'A. RECEIVED BY HAVE A NICE DAY! !'A/.LY HOFFECKER ATO- i 529 APPROVED .......... HI_£ ,S P ti!: DISTRIBUTION CENTRAL FILEY (CI4) CHEVRON D & M TAMMA$ BROWN (OH) EXXON MARATHON MOBIL PHIl_LIPS F'B WELL FILES R & D BPX STATE OF ALASKA TEXACO r-~l',~ C L AL..A,S'K A INC I::~ O~ BCIX i (-),,")S6':~) ANC::HOF:..'AC;E, AL..A'2.'I<A 995i 6' DATE · 4-t 9-9~ R [:' 1::' E R E N C E ' A R C 0 0 P ['"' N 1"! 0 L.. E: F I N A L. S 2 '"' 29 A W 61 -'? W G I -" 7 W (;- I -'? WI.;. I '"7 2 .... i 2-9'2) SI"IF;..'D 3 / 28 '-:3 '."D/" 9 () (;. R / F< E $ I ,$,' 'T' I V :1: 'f' Y "J~/'28-S (i),.'" 9 () [-;.F;~/F.:E ~S' i ~,'"f' I V I 'i"Y 3/29 .... 36'/9,:') DGR/EWI:;,' 3/29-'S()/9(:',, D C.;. F(' / C N F:' / S F:' I) I":'I_EA,S'IE eIfY, N AND IxEI[JI"~N t- COF'Y A;&' CE: ]: .t:.,.Y ............ HAY E A N :[ CE DA ¥ ~ ~ 0il & au t~on~. Commis~ion .anchorage ,?.;A L.L Y HOFF'E:CK E:.F. ATO'-i 529 RECEIF'i" OF:' DATA. qF' F' RC. VEI) I) ISTRIBUT]:ON '"' CENTRAl_ !:' I L..EE$ 'lr Jl. ... I".:: H E VI"~ 0 N ~ D & M · .. EX'I"EN,S' I ON EXPLORATION · '~ EXXON -,- MARATHON :~ H ["1B I L. · .. F'I-i l i_L I PS; PB WELL F:'IL. ES :~ R & D -~ BF'X '.-'"' ,.,el'ATE. OF" AL.A,.q/I< A. · ,.~i'EXACC) 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-builts for your information. If you have any questions, please call me at 263-4618. Sincerely, Engineering Aide DW cc: File W1-1 REC£1VE ARCO Alaska Inc.. is a subsidiary of Atlantic Richfield Company AR3B-6001-A ~ E C E I V E D NOT TO SCALE APR 2 3 ~ OCA TED WITHIN PRO TRA~~ & ~as Cons. core--LEGEND' SECTION I1~ T. II N.~ R. I~ E.~ UMIA T MERIDIAN~ ALASKA Anchom~ e CONDUCTORS AS~ T T~S SURVEY · EXISTING CONDUCTOR WELL A.S.P. COORDINATES PLANT GEODETIC POSITION EgEV. LOCATION c~ IN SEC TION NO. NORTHING EASTING COORDS. LA T. LONG. ~ ~9.9~ ~' 5 5~971~1~.~ ~1~.~ 70"19'~.5~1'1~'~9'53.~' ~.~ 6 5~971~535.~ ~~.~ ~"19'~.01~'t~"~'~.~'~ , 7 5~971~18.9~ ~1~.~1 N ~.~ ~"19'~.~'1~"~'~.~ 21.~ ~' · . ............ NOTES - k , ~ OF '~ ~A ~ I.~ BASIS ~R I NGI ~~NTS ~C 4 i M ] m~ ~ ~ ~ ~ ~r mis ~r N~D. ~ ~ : ~ ~ ~.) ALASKA STA T[ ~A~ ~ · I 4, ~ 0.9999390. .~ j , ~.~, ~ 13, I~ . ~co o~r~ ~Lc.wi I F.R. BELL ~ ASSOCIATES CONDUCTOR A S-BUlL T WGi PAD~ WELLS 5~6~ 7 ~ DA~ ~VISI~ ~ N~ I~ I ~~~~ 0 ~- -- .... III II I III I ! ~ Imm I ' II I I' I I I I I ARCO ALA.~'KA, ]:NC). P~O. BOX ~O,r-;S60 ANCFIC)RAGE, AL.A,~'KA 995~ (~ DATE · 4-~ ~ -9(') RFF:ERENC~:E' ARCO DIREC;TIONAL DATA WG.I .... 6 S"-5:'-9~'3 HWD DIRFCTIONAI_ .'gURYEY ANA W[~:l:-"7 S-28""9() MWD DIREC'.TIONAI.. SURVEY ANA FLEA,..E ,"~IC.N AN[)RETURN '/HE ATTACHED COF'Y Ao~ RECEIPT OF-" DATA. F;.'. Ii!: C ii: I VE D BY ,S'ALL. Y HC)F:'FECKER ~.PR 1 8 A'TO-t 529 ' _ .... ,~n'/RANS:~ 9 Alaska Oil & Gas ~ns. ~chorage D I S' l'R I B U T I 0 N C~-NTRAL I:' I LI:.,S CHEVRON D & M EXTE'N,.glON E:.XFI_..ORA1 ION EXXON HARATHON MOBIL PHILLIPS F'B WEL. L FILES (2 CC)F:'IE~') R & D BF'X STATE OF ALAS'KA TEXACO MEMORANDUM State of Alaska ALASKA OIL AiqD GAS CONSERVATION COMMISSION TO: Lonnie C. Sm : March 29, 1990 Co~issioner /,..~ DATE: FILE NO: JT. BF. 329.2 TELEPHONE NO: THRU: SUBJECT: Bobby D. Petroleum InspeCtor FROM: BOP Test AAI PBU WGI 7 Permit No. 90-40 Prudhoe Oil Pool ~arch 22. 1990: The BOPE test began at 6:30 a.m. and conc~-~-~a.m. As the attached BOPE test report shows, there was one failure which was corrected before I departed the location. The upper and lower kelly valves could not be tested while I was on location due to drill collars being racked in front of kelly. I am to be notified when they are tested which will be before the shoe is drilled out. In summary, I witnessed the BOPE Test on on Doyon Rig 9 drilling AAI's WGI #7. Attac.hment: I was notified by Richard Bordes, AAI drilling foreman, that the valves had been tested and were OK on 3/23/90. 02-001A (Rev. 8/85) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Inspection Report ,, Operator -~-~~ ' Well ~¢) ~ .~-' ,, ~ Drlg contrctr~OyO~~__ Location (general) ~ Well sign Rig # General housekeeping (// pi t //~/~ Reserve Rig m ~ DATE MUD SYSTEMS: Trip .tank Pit gauge Flow monitor Gas detectors Vi sual Audio BOPE STACK: Annular preventer Pipe rams Blind rams Choke line valves HCR valve Kill line valves Check valve Test Pressure ._ ! Representative ft ACCUMULATOR SYSTEM: Full charge pressure Press after closure Pump incr clos press 200 psig Full charge press attained Controls:Master / Remote L~ ~ Blind switch cover / KELLY AND FLOOR SAF~Y VALVES: psig psig ~min ~sec , min / ? sec psig. Upper Kelly - Test pressure Lower Kelly -- Test pressure Ball type / Test pressure Inside BOP J Test pressurec~,) Choke manifold :~~ Test Number valves Number flanges Adjustable chokes / Hydraulically operated choke , / TEST RESULTS: Failures . / Test time / /~ hrs Repair or replacement of failed equipment to be made within and Inspector/Commission office notified. __days Distribution: orig - AOGCC c - Operator c - Supervisor Inspec . C.004 (rev 03/17/89) ? ? March 13, 1990 Telecopy No. (907) 276-7542 J D Gillespie Regional Drilling Engr ARCO Alaska, Inc P O Box 100360 Anchorage, AK 99510-0360 Prudhoe Bay Unit WGI-7 ARCO Alaska, Inc Permit ~ 90-40 Surf Loc 846'FNL, 1084'FEL, Sec 11, TllN, R14E, DM Btmhole Loc 741'FNL, 2469'FEL, Sec 11, TllN, R14E, UM Dear Mr Gillespie: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 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. Where a diverter 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. Ver. y truly %ours, C V Chatterton Alaska Oil and Gas Conservation Co~ission BY O~ER OF THE COMMISSION jo Enclosure C: Department of Fish & Game, Habitat Section - w/o encl Department of Environmental Conservation - w/o encl la. Type of work Drill Re-Entry ALASKA STATE OF ALASKA AND GAS CONSERVATION C~ ,MISSION PERMIT TO DRILL 20 AAC 25.005 Gas Injection Well Redrill ZI lb. Type of well. Exploratory ~ Stratigraphic Test ~ Development Oil L? DeepenCI Service ~_ 2. Name of Operator ARCO Alaska, Inc. ,, 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of wellatsurface 846'FNL, 1084'FEL, Sec.ll, TllN, RI~E, UM Attop ofproductiveinterval 750'FNL, 2350'FEL, Sec.ll, TllN, R14E, UM Attotaldepth 741'FNL, 2469'FEL, Sec.ll, TllN, R14E, UM feet 13. Distance to nearest well WGI-6 from 0-4000'MD 120 ' feet 12. Distance to nearest property line 2811' 16. To be completed for deviated wells Kickoff depth3400' feet28o2 Maximum hole angle 18. Casing program size Hole Casing 30" 20" 17-1/2" 13-3/8" ~..§... 5 / 8" 8-1/2" 7" Developement Gas ~_ Single Zone ~ Multiple Zone 5. Datum Elevation (DF or KB) Pad 19' RrB 58 feet 6. Property Designation ADL 28302 ALK 2313 BHL 7. Unit or property Name Prudhoe Bay Unit 8. Well number WGI-7 9. Approximate spud date 04/15/90 14. Number of acres in property 10. Field and Pool rudhoe Bay Field rudhoe Bay Oil Pool 11. ~pe Bond(see20AAC25.025) Statewide Number No. U-630610 Amount $200,000 17. Anticipated pressure (see 20 A^C 25.035 (e)(2)) Maximum surface 2812 psig At total deDth (/VD) 3656 ' 15. Proposed depth(MDandTVD) 9025'MD feet 8707'TVD psig Setting Depth Specifications Weight I Grade ! Coupling 91.5# IH-40 /Wel~ 68# ~.-180/K-~5 ~c 47# 1~,-80 f~C/~o~ l~ngth 80' 3462' 8392' 896' , 19. To be completed for Redrill, Re-entry, and Deepen O Present well condition summary Top )erations. Total depth: measured true vertical Bottom 19' 00' 29' 25' I feet Plugs (measured) feet Quantity of cernent TVD (include stage data) 119' 3500' 2 2000# Poleset 000 sx CS III&600 sx C! 8183' 450 sx G 8707' 300 sx Latex G Effective depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length measured true vertical Size Cemented Measured depth True Vertical depth RECEIVED MAR - 6 1990 Alaska Oil & Gas Cons. cQmmisslQ~ Anchoraoe 20. Attachments Filing fee 1~ Property plat [] BOP Sketch ~ Diverter Sketch ~ Drilling program ~ Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report ~ 20 AAC 25.050 requirements ~', 21. I hereby certify that the foregoing is true and correct to the beSt of my knowledge /~~~/~ ~ ¢ Regional Dr~ll~n En ~ne S~gned' . .... g g ' e r ,, ,(//// - Commission Use Only (Jps) ,PD3/108 ,, PermiLNumber p'API number J App,r,o,¥a,l~d, St¢,,,, J See cove ?o I 50--~29~ ~2C~,,~/' j-U~.L.J,.~I 51~U I.for other Conditions of approval Samples required ~ Yes ..~No Mud log required L-] Yes ~'"No Hydrogen sulfide.measures rq Yes ~'No Direcfron~l.survey required )~;'Yes [] N'6 ' Required workingj;,r,e~sure/~or BOP.~E E],?,N~ [] 3M; ~ 5M; [] 10M; ~E3 15M Other: j/ /.,.-~'/ /.,/ / / / / / // /"~ // // ///~-/.-. ' ~/ ~ by orderof Approved by ~ ~,..~/,. ( ~//,'/~_~,,~~, Commissioner the commission Form 10-401 Rev. 12-1-85 Date r letter requirements Submit il~tripli~t-~ PRUDHOE BAY DS WGI-7 PRELIMINARY DRILLING PROCEDURE 1. MIRU drilling rig. NU diverter and function test same. 2. Drill 17-1/2" vertical hole to 3500' TVD/MD. J . 3. 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. 5. Drill 12-1/4" hole to 5400' TVD/MD and kick off. Build angle at 2.0 derees per 100' to 28 degrees 7' at 6750' TVD/6806' MD. 6. Drill 12-1/4" hole to 9-5/8" casing point at 8183' TVD/8429' MD maintaining the 28 o 13' hole angle in a N 85 39' 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. Drill 8-1/2" hole to 8707' TVD / 9025' MD in a N 85 39'W direction using MWD logs. 11. Set 7" liner and cement same. 12. 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. 13. Release drilling rig. Run cement bond logs 7 days after rig release. 14. MI and RU completion rig. Run 7" tubing and packer assembly. Notify State to witness Mechanical Integrity tests as per requirements for a Class 2 Gas Injection well. NU 7" tree and test to 5000 psi. Test tubing and casing to 4000 psi. Release completion rig. 15. Rig up wireline unit and perforate. RECEIVED MAR - 6 1990 Alaska 0ii & Gas Cons. Commissi0~ Anchorage 0- ,, RKFI FI.Ih'~VATION 5g' ,~--~, 20" Casing TVD=I19 ~119 I ) AR{20 · -. wgi-' SHL:UllN14ElI846'~ 1084'FEL THL: U 11N 14E 11 750' ~ ~ 2350' FEL BHL: U 11N 14E 11 742' ~L 24~' FEL N 85 39' ~ 2~ 13-3~" C~g ~ )=35~ ~D=3500 D] :P~ 4~ ......... ~D~5~ ~D ~5~ D~=0 K-15 ~758 '~758 DEP=0 5000 KOP ~D=5400 ~.o 4.o I~O ~1~0 6~0 ~a.o ~16.0 ~1S.0 ~ ~4.o ~ ~.o , ,,~oE~ ~=6750 ~D=68~ DEI'=338 7000 X K. i0 ~=705~ TM~7i54 D~=502 [-5 ~=7558 ~D=3720 D~=769 LCU ~8138 T~=8378 DB=107~ 9-5/8'C~g T~=8183 ~D=~29 I SAG River ~E=8193 ~ID=~0 DE '=1108 BL~ ~':8243 TMD:~¢ DEr:Il35 M/kR --6 1990 Sadl~hit T~=8283 m~8542 D~=1156 Alaska Oil & Gas Cons. Coma TARGET ~D:U93 m~8782 ~=1269 6/0 Com{t ~=8633 mD=8~9 DE~lg~ Anchorage 9000 n~.. g~d~r~h!t ~69~ ~.~-90~3 DE~377 .. ~ ~ :87~ TM~9025 D~ =I3M 10000 0 1~ 2~ 3~0 4~ 5~ ~ 7000 ~RTICAL SECTION ARCO ALASKA, INC. wgi-7 N 85 39' W °5000 4000 3000 2000 E - W COORDINATES -4000 -3000 -2000 -1000 0 1000 2000 3000 0- 0 ~r~ 1000 < 0 o -1000- -2000- -3O00- -5000 }-r i i i 7 i i i IT I t I I I I I II I I ~ I I I I TI I I I ~ I T t II I [ I I I I I II I I I I I I I I I I I I I I I I II I i I I I I I I WGI-03 9 / 9:~ WGI-( /__ WGI-02 ~N8412 / 6147 6~8231251 3~0/4227 3800 9000 w~I- 7 wgi-5 ~oooo -~ 98~ 10168 10357 , , ...................................... ~ ................................. ,, 4OOO -3000 -2000 1000 '-1000 -2000 -4000 -3000 -2000 -1000 0 1000 2000 -3000 3000 RECEIVED MAR -,:, !990 Alaska 0il & Gas Cons. Commissio[~ Anchorage ?1- 02 8 8 7 6 5 6 10 9 10 ,..,..,. 11 12 5 8 O/-OS Alaska Oil & Gas Cons. Comm'~ssio.e Anchorag~ / // ' DOYON 9 -~' MUD SYSTEM 32 BBLS 32 RBLS TRIP TANKS I [ DEGASSER} (30 BBLS) (83BBLS) ATM DESILTER (9? BBLS) BUSTER GAS (97 BBLS) PILL PIT (36 BBLS) (36 BBLS) SHAF~.R DESANDER SHAF~.R MIX PIT SUCTION PIT (448 BBLS) (122 BBLS) RECEI ~AR -6 VED 1990 ia Oil ~ Gas Co~ s. Commissio.~ Anchorage OTPmR EQUIPTMENT - DRILLING FLUID SYSTEM(3) DERRICK FLO-LINE (1) PVT SENSOR PER PIT w/ visual and au~{o warning devices (1) AGITATOR PER PIT (1) DRILLING FLOW sHow SENSOR w/ readout convenient to the driller's console SURFACE HOLE DIVERTER SYSTEM SCHEMATIC ARCO ALASKA, INC. FILL-UP LINE I 2000 PSI DIVERTER RISER I FLOWLINE 10" BALL VALVE 10" BALL VALVE RECEIVED MAR - 6 1990 C O N D U C'~a 0il & Sas Co.s. CommissiQ~ Anchorage 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 WELL O , m I I , RIG MODULES NOTE: 100' FROM ANY IGNITION SOURCE ALL TURNS 90 DEGREE TARGET TEES RESERVE PIT JG 7/27/87 ACCUMULATOR CAPACITY TEST , . IPE RA 2. -~ DFllLLING ~ 5. SPOOL 6. CHECK AND FILL ACCUMULATOR RESERVIOR TO THE PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT THE ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI-DOWNSTREAM OF THE REGULATOR. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH THE CHARGING PUMP OFF. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRES- SURE. 13-5/8" STACK TEST FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING FLUID. 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. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. FUNCTION TEST CHOKES. IN EACH TEST, FIRST HOLD 250 PSI FOR 3 MINUTES PRIOR TO THE HIGH PPRERSSURE TEST. INCREASE PRESSURE ON ANNULAR TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. CASING SPOOL PIPE RAMS 13-3/8" ~---~r~ BRADEN ~ HEAD A 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 BOTTOM 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. PBU DS WG~7 MUD PROGRAM DEPTH DENSITY VIS YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) GELS GELS CC/30MIN (%) (%) MUD TYPE SPUD 8.8 300 70 30+ 50+ 25 0 2 to to to to to 13-3/8 9.2 100 40 6 csg pt. SET 13.3/8" CASING GEL-BENEX SPUD MUD DEPTH DENSITY PV YP INT 10 min FL OIL SOLIDS MUD (TVD) (PPG) (CP) (#/ft GEL GEL cc/30min (%) (%) TYPE 1 3-3/8" 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 10 min 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 DRILLING SUPERINTENDENT OR DRILLING MANAGER. RECEIVED MAR - ~, I990 Alaska 0il & Gas Cons. CommiSSiOP Anchorage NOTE; PRUDHOE BAY DS WGI-7 PRELIMINARY DRILLING PROCEDURE CONT. a. 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 dudng any extended pedod. The annulus will be sealed with 300 sx of cement followed by Arctic Pack. b. WGI-6 is about 120' from the proposed well down to approximately 4000' MD where it departs. c. The ddlling 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 CONRROL EQUIPMENT Shale shaker Mud cleaner Centrifuge Trip tank Degasser Pit level indicators (visual and audio) Fluid flow sensor Fluid Agitators RECEIVED MAR - 6 1990 Alaska 0il & Bas Cons. Comm~ss~g Anchorage C~ECK LIST FOR NEW WELL PERMITS ITEM A~,.PROVE DATE L - (2 thru 8') (3) Admin/~C ..... ~3/)~ ~ 9. (9 thru ' 10. (10 aad 13)12. 13. (14 thru 22) (23 thru 28) Company Is the permit fee attached .......................................... 2. Is well td be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. (6) OTHER~z~ 29. '~9_ thrd ~l~ 30. 31. rev: 01/30/89 6.011 32. 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 & Well No. /q~ ~ ~ ~2OV~~6/~~-s ~ PZ~/-// NO · · 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 Are necessary diagrams and descriptions of diverter Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (May 84) Is the presence of H2S gas probable ............... eeeeeeeeeeeeeeeeee equipment adequate and BOPE attached. ~Oo~ psig .. leeeeeeele~eeeeee 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 I o/nj , Additional Remarks 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 APPENDIXi .. No special effort has been made to chronologically organize this category of information. (NOTE: **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 90/04/16 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: RLL DATE: 90/04/16 ORIGIN OF DATA: WGI7 TAPE NAME: PBU/EOA CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** Bate ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: WGI-7.MWD SERVICE NAME: RLL VERSION #: V 2.00 DATE: 90/04/16 MAX. RECORD LENGTH: 1024 FILE TYPE: E1 PREVIOUS FILE NAME: ** COMMENTS ** COMPANY: ARCO ALASKA INC. WELL: WGI-7 FIELD: PRUDHOE BAY (EOA) LOCATION: ARCTIC NORTH SLOPE, ALASKA, U.S.A. COMPANY REP.: JACKSON & REDMAN RIG: DOYON 9 RLL ENGINEERS: M. HANIK & D. WESLEY PROCESSING DATE: 4/16/90 COMMENTS: ALL MWD LOGS HAVE BEEN DEPTH SHIFTED TO SCHLUMBERGER CASEDHOLE (CCL) GAMMA RAY. MWD NEUTRON AND DENSITY LOGS ARE CALIPER COMPENSATED AND CORRECTED FOR TOOL WEAR USING POST-JOB SHOP CALIBRATION FACTORS. ** 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 ORDER# DEPT GR MWD EWR MWD ROP MWD FXE MWD NFO MWD NFl MWD NN0 MWD NN1 MWD CAL MWD RHOB MWD DRHO MWD NPSC MWD LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 AAPI 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 FT/H 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 INCH 0 0 0 0 1 4 0 1 68 G/C3 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 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY DESCRIPTION 4 1 66 255 LOG DIRECTION, DOWN 0 1 66 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 1 4 0 1 68 GR ENR ROP FXE NF0 NFl NN0 NN1 CAL RHOB DRHO NPSC MWD .MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD AAPI OHMM FT/H HOUR CTS CTS CTS CTS INCH G/C3 G/C3 P.U. 0 0 0 0 0 0 0 0 0 0 0 0 1 1 1 1 1 1 1 1 1 1 1 1 68 68 68 68 68 68 68 68 68 68 68 68 DEPT NN0 ** DATA VERIFICATION 8250.000 -999.250 GR NN1 8300.000 2312.000 -999.250 -999.250 8400.000 2215.570 -999.250 2200.000 8500.000 3080.675 164.627 2168.859 8600.000 3813.856 103.789 2923.736 8700.000 3821.314 20.604 3633.568 8800.000 3798.361 25.829 3980.271 8900.000 3290.292 43.538 3852.312 9000.000 -999.250 90.346 3225.174 -999.250 -999.250 EWR CAL (every 100 FT) ROP RHOB -999.250 -999.250 -999.250 8.410 32.744 13.830 19.261 8.440 147.202 8.480 238.400 8.490 26.182 8.720 12.115 8.610 -999.250 -999.250 -999.250 -999.250 -999.250 3.250 343.125 2.082 21.856 2.484 90.892 2.264 49.267 2.203 11.726 2.276 11.738 2.253 -999.250 -999.250 ** 85 DATA RECORDS ** FROM ** FILE TRAILER** FILE NAME: WGI-7.MWD SERVICE NAME: RLL VERSION #: V 2.00 DATE: 90/04/16 MAX. RECORD LENGTH: FILE TYPE: E1 NEXT FILE NAME: 1024 ********** END OF FILE (EOF FXE DRHO -999.250 -999.250 -999.250 .000 1.340 -.002 .537 .002 .464 .008 12.452 .001 .588 .000 1.670 .003 -999.250 -999.250 NF0 NPSC -999.250 -999.250 481.000 35.381 627.322 10.306 845.736 28.288 1120.856 16.260 1296.343 13.572 1073.361 14.046 891.246 23.148 -999.250 -999.250 8250.00 TO 9050.00 FT # 2) ********** NFl -999.250 461.000 546.678 810.429 1116.952 1249. 121 1064.951 825.248 -999.250 ** FILE HEADER ** FILE SEQUENCE # 2 FILE NAME: WGI-7.RPT SERVICE NAME: RLL VERSION #: V 2.00 DATE: 90/04/16 MAX. RECORD LENGTH: 1024 FILE TYPE: WG PREVIOUS FILE NAME: ** COMMENTS ** ***** REPEAT (MAD) DATA ***** 1. ALL MED DATA IS CALIPER AND WEAR CORRECTED. 2. ALL MWD DATA DEPTH SHIFTED TO CASEDHOLE CCL GAMMA RAY. ** 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 EWR REPEAT FXE REPEAT CAL REPEAT DRHO REPEAT RHOB REPEAT NPSC REPEAT GR REPEAT RATE REPEAT NFO REPEAT NFl REPEAT NN0 REPEAT NN1 REPEAT ORDER# LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 2 4 0 1 68 OHMM 0 0 0 0 2 4 0 1 68 HOUR 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 G/C3 0 0 0 0 2 4 0 1 68 P.U. 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 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 ** 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 EWR FXE CAL DRHO RHOB NPSC GR RATE NF0 NFl NN0 NN1 REPEAT REPEAT REPEAT REPEAT REPEAT REPEAT REPEAT REPEAT REPEAT REPEAT REPEAT REPEAT FT OH/VIM HOUR INCH G/C3 G/C3 P.U. AAPI FT/H CTS CTS CTS CTS 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 68 68 68 68 68 68 68 68 68 68 68 68 68 ** DATA VERIFICATION (every 100 FT) DEPT EWR FXE CAL DRHO RHOB GR RATE NF0 NFl NN0 NN1 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 8650.000 -999.250 243.030 22.279 8.410 .006 2.180 -999.250 1098.223 1037.836 3921.284 3676.125 8700.000 -999.250 33.060 9.097 8.680 .004 2.318 113.599 976.617 884.677 3396.765 3334.588 8800.000 34.866 7.969 7.314 8.570 -.015 2.282 128.244 671.000 687.000 2792.000 2888.000 8900.000 77.828 -999.250 -999.250 -999.250 -999.250 -999.250 159.579 -999.250 -999.250 -999.250 -999.250 9000.000 -999.250 ** 43 DATA RECORDS ** FROM 1024 ** FILE TRAILER** FILE NAME: WGI-7. RPT SERVICE NAME: RLL VERSION #: V 2.00 DATE: 90/04/16 MAX. RECORD LENGTH: FILE TYPE: WG NEXT FILE NAME: (EOF # ********** END OF FILE 8650.00 TO 9050.00 FT NPSC -999.250 18.808 19.336 24.893 -999.250 ** FILE HEADER ** FILE SEQUENCE # 3 FILE NAME: CASEDHOLE SERVICE NAME: SWS VERSION #: CCL DATE: 90/04/16 MAX. RECORD LENGTH: 1024 FILE TYPE: E3 PREVIOUS FILE NAME: ** COMMENTS ** ****** CASEDHOLE DATA ****** 1. SUPPLIED BY SCHLUMBERGER ** 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 ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 3 4 0 1 68 GR CCL1 GAPI 0 0 0 0 3 4 0 1 68 GR CCL2 GAPI 0 0 0 0 3 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY DESCRIPTION 4 1 66 255 LOG DIRECTION, DOWN 0 1 66 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 3 4 0 1 68 GR CCL1 GAPI 0 0 0 0 3 4 0 1 68 GR CCL2 GAPI 0 0 0 0 3 4 0 1 68 ** DATA VERIFICATION (every 100 FT) ** DEPT GR GR 8250.000 64.500 64.500 8300.000 53.094 53.094 8400.000 108.000 108.000 8500.000 67.625 67.625 8600.000 11.781 11.781 8700.000 12.508 12.508 8800.000 38.781 38.781 8900.000 58.594 58.594 9000.000 -999.250 -999.250 ** 20 DATA RECORDS ** FROM 8250.00 ** FILE TRAILER** FILE NAME: CASEDHOLE SERVICE NAME: SWS VERSION #: CCL DATE: 90/04/16 };~X. RECORD LENGTH: 1024 FILE TYPE: E3 NEXT FILE NAME: ********** END OF FILE (EOF TO 9050.00 FT # 4) ********** ** TAPE TRAILER** SERVICE NAME: RLL DATE: 90/04/16 ORIGIN OF DATA: WGI7 TAPE NAME: PBU/EOA CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 90/04/16 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT
