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Home My WebLink About193-002MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, April 1, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC AGI-05 PRUDHOE BAY UNIT AGI-05 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/01/2025 AGI-05 50-029-22327-00-00 193-002-0 G SPT 7771 1930020 1943 3398 3392 3389 3400 15 17 16 17 4YRTST P Sully Sullivan 3/1/2025 no issues, good test 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 AGI-05 Inspection Date: Tubing OA Packer Depth 427 2295 2280 2280IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS250301140845 BBL Pumped:2 BBL Returned:1.9 Tuesday, April 1, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.04.01 13:31:49 -08'00' 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 AGI-05 Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 193-002 50-029-22327-00-00 9822 Conductor Surface Intermediate Production Liner 8490 76 3822 9289 678 9801 20" 13-3/8" 9-5/8" 7" 8470 37 - 113 36 - 3858 34 - 9323 9144 - 9822 36 - 112 36 - 3481 34 - 8006 7835 - 8490 unknown 470 1950 4760 7020 none 1490 3450 6870 8160 9516 - 9750 7-5/8" x 7" x 5-1/2" L-80 32 - 9065 8193 - 8420 Structural 7" HES TNT, 8971 ,7674 7" A-1 , 2226 , 2156 8971 , 9076 7674 , 7771 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 0034628 , 0028301 32 - 7761 0 0 148354 234527 0 0 150 125 3348 3378 324-065 13b. Pools active after work:PRUDHOE OIL 7" BKR SB-3A , 9076 , 7771 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 8:18 am, Jun 18, 2024 Digitally signed by David Bjork (3888) DN: cn=David Bjork (3888) Reason: I am approving this document. Date: 2024.06.17 15:25:37 -08'00' David Bjork (3888) RBDMS JSB 062024 DSR-6/18/24WCB 9-9-2024 ACTIVITYDATE SUMMARY 5/19/2024 T/I/O = 2766/91/11 LRS 70 (TUBING WASH/PICKLE) Pumped 10 bbls 60/40, 100 bbls 120* Diesel, and 380 bbls F-103 into TBG, let soak for 2 hours. Pump 222 bbls F- 103 followed by 15 bbls 60/40. DSO notified of well status upon departure. SV/SSV= Closed, WV/MV= Open, IA/OA=OTG FWHPs = 297/79/142 Daily Report of Well Operations PBU AGI-05 Pumped 10 bbls 60/40, 100() bbls 120* Diesel, and 380 bbls F-103 into TBG, let soak for 2 hours. Pump 222 bbls F- 103 followed by 15 bbls 60/40 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 AGI-05 Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 193-002 50-029-22327-00-00 ADL 0034628 , 0028301 9822 Conductor Surface Intermediate Production Liner 8490 76 3822 9289 678 9801 20" 13-3/8" 9-5/8" 7" 8470 37 - 113 36 - 3858 34 - 9323 9144 - 9822 36 - 112 36 - 3481 34 - 8006 7835 - 8490 unknown 470 1950 4760 7020 none 1490 3450 6870 8160 9516 - 9750 7-5/8" x 7" x 5-1/2" L-80 32 - 90658193 - 8420 Structural 7" HES TNT, 7" BKR SB-3A 7" A-1 Injection 8971 , 9076 , 2226 7674 , 7771 , 2156 Date: Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY 3-1-2023 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 1:39 pm, Feb 08, 2024 324-065 Digitally signed by Eric Dickerman (4002) DN: cn=Eric Dickerman (4002) Date: 2024.02.07 13:23:20 - 09'00' Eric Dickerman (4002) MGR13FEB24 10-404 DSR-2//13/24SFD 2/9/2024*&:JLC 2/15/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.15 14:56:44 -06'00'02/15/24 RBDMS JSB 021524 Well Work Prognosis Well Name:AGI-05 API Number:50-029-22327-00 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:1930020 First Call Engineer:Dave Bjork Office: 907-564-4672 Cell: 907-440-0331 Second Call Engineer: Gas Injection Rate: ~310,000 Mscf/Day Injection Pressure: 3,400 psi Reservoir Pressure (Estimate): 3300 psi Program Objective(s): AGI-05 is a gas cap injection well that has demonstrated a decrease in injectivity. The well has not been water washed since 2018. Water washes are designed to dissolve salts and asphaltenes in the tubing and formation. The objective is to perform a tubing water wash to increase injectivity and perform a general maintenance on Gas Injection Wells. Proposed Program: Pump diesel followed by Fresh Water and Surfactant as per attached pumping template. Well Work Prognosis Well Work Prognosis H2S Value N/A H2S Date N/A Work Desc AFE Date Engineer Phone Job Objective Pump Schedule Stage Fluid Type Pump Into Vol (bbls) Rate (bpm)Max Pres (psi) 1 Spear Methanol / Water TBG 10 1-3 2500 2 Solvent Diesel TBG 100 1-3 2500 3 Over-Flush Fresh Water TBG 600 see below 1800 4 Spear Methanol / Water TBG 15 1-3 1800 5 6 7 Detailed Procedure David Bjork (907) 564-4672 Well AGI-05 GI Water Wash 01/28/24 Increase well injectivity by performing a water wash. -Use 2 full uprights of fresh water mixed with 0.02% F-103 surfactant. Use 100 bbls of diesel from COTU. -Heat diesel to ~120*F -Order FreshWater to be at ~160*F -Freeze Protect contingent on WSL and ambient temp/seasonal pumping 1.) 10 bbl 60/40 MeOH/water spear 2.) 50 bbls COTU diesel (heated to ~120 deg F)at ~1 to 3 bpm. 3.) Pump 600 bbls of fresh water with 0.02% F-103 surfactant per following: a.) Pump 380 bbls of fresh water with 0.02% F-103 surfactant at ~5 bpm. Max pressure during this pumping can reach 1800 psi. Once 380 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 the 2 hour soak time, resume pumping at max rate/pressure (whichever is hit first) for next 220 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 380 5 76 1.27 Soak 2.00 FW flush 220 5 44 0.73 methanol cap 15 1.5 10 0.17 5.44 Soak Time of Diesel/Xylene 1 2 Diesel/Xylene Notes Note 1 Note 2 Note 3 Hot fluids recommended: Note 1 Fresh Water and Surfactant Notes Note 1 Tubing has gas in it prior to pumping, any fluids pumped first will free fall. Soak time - keep at a minimum of ~2 hours; xylene works best with longer soak times (at least on asphaltenes) SBG treatments have a 3 hour soak time as well (just an FYI) Soak time is really a time for diesel/xylene to seep through the perfs vs pushing/rushing through Max pump rates creates turbulence and has contact with the tubing walls. Also cuts down on time Use COTU "diesel" only in these treatments if available. See Craig Graff explanation below. COTU technically can’t make diesel. On good days it can make Jet A or Heating Oil. Neither meet the specs for diesel. The reason they are different is that they have a lot more aromatics and sulfur in them than diesel. Road diesel and ULSD have most of those bad components taken out, which means that they can only dissolve straight chain hydrocarbons (paraffins), and not aromatics. These will make asphaltenes precipitate instead of cleaning them up.COTU “diesel” has enough things like xylene and toluene left in it to make it a pretty good solvent even for asphaltenes. A real refinery would take all of those out to be sold for higher margins in other products. If COTU "diesel"is not available, use other available diesel and xylene at a 50/50 mixture. As you read diesel in instructions below, can substitue with diesel/xylene If xylene is used for a 50/50 diesel/xylene mixture, heated xylene to 80 deg F or higher, use pump rates of 1 to 1.5 bpm. Injectivity results have improved when all fluids pumped are at warmer temps Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:193-002 6.50-029-22327-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 9822 9801 8470 8971, 9076 7674, 7771 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 76 20" 37 - 113 37 - 113 1490 470 Surface 3822 13-3/8" 36 - 3858 36 - 3481 3450 1950 Intermediate 9289 9-5/8" 34 - 9323 34 - 8006 6870 4760 Production Perforation Depth: Measured depth: 9516 - 9750 feet True vertical depth:8193 - 8420 feet Tubing (size, grade, measured and true vertical depth)7-5/8"x7"x5-1/2" L80 32 - 9065 8971, 7674 9076, 7771Packers and SSSV (type, measured and true vertical depth) 7" HES TNT PKR, 7" BKR SB-3A Liner 678 7" 9144 - 9822 7835 - 8490 8160 7020 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 33304700 0264690 30 223789 0 3304 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Dave Bjork david.bjork@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:907.564.4672 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ 5 SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8490 Sundry Number or N/A if C.O. Exempt: 321-272 7" A-1 Injection SSSV 2226 2156 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Water Wash Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0034628 & 0028301 PBU AGI-05 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:13 pm, Jun 14, 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: 2021.06.14 12:03:05 -08'00' Bo York SFD 6/18/2021MGR29JUL2021DSR-6/14/21 RBDMS HEW 6/14/2021 ACTIVITYDATE SUMMARY 6/4/2021 T/I/O = 2681/240/105 Temp - 99*. Water Wash. Pumped a10 bbl 60/40 MW Spear, Followed by 50 bbls 120* DSL and 425 bbls Fresh water w/ F-103 down tbg. Let soak 2 hrs.. Pumped 475 bbls fresh water w/ F-103 followed by 15 bbls 60/40. SV WV closed MV open CV OTG FWHP'S T/I/O=-9/15/217 Daily Report of Well Operations PBU AGI-05 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:193-002 6.API Number:50-029-22327-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0034628 & 0028301 Property Designation (Lease Number):10. N/A 8. PBU AGI-05 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Water Wash Op Shutdown GAS GSTORWAG 5 SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 9822 Effective Depth MD: L80 11. 6/8/2021 Commission Representative: 15. Suspended Contact Name: Dave Bjork Contact Email: david.bjork@hilcorp.com Authorized Name: Bo York Authorized Title:Sr. Area 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): 8490 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 8971, 7674 9076, 7771 2226, 2156 Date: Liner 678 7"9144 - 9822 7835 - 8490 8160 7020 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 14. Estimated Date for Commencing Operations: BOP Sketch 37 - 113 Structural 6870 Proposal Summary 13. Well Class after proposed work: 7" HES TNT PKR, 7" BKR SB-3A 9516 - 9750 8193 - 8420 7-5/8"x7"x5-1/2"32 - 9065 Production 9801 8470 NONE UNKNOWN 470 9-5/8" Contact Phone:907.564.4672 Date: 4760 76 149020"Conductor GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface Intermediate 9289 34 - 9323 34 - 8006 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 3327 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. 13-3/8"36 - 3858 36 - 3481 3450 19503822 37 - 113 By Samantha Carlisle at 10:26 am, Jun 02, 2021 321-272 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.06.02 09:45:19 -08'00' Stan Golis (880) MGR02JUN21 DSR-6/2/21 X DLB06/02/2021 10-404 dts 6/3/2021 JLC 6/3/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.03 11:37:26 -08'00' RBDMS HEW 6/4/2021 Well Work Prognosis Well Name:AGI-05 API Number:50-029-22327-00 Current Status:Gas Injector Leg: Estimated Start Date:June 3rd, 2021 Rig:N/A Reg. Approval Req’d?10-403 Date Reg. Approval Received: Regulatory Contact:Carrie Janowski Permit to Drill Number:1930020 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: ~235,000 Mscf/Day Injection Pressure: 3,327 psi Reservoir Pressure (Estimate): 3250 psi Program Objective(s): AGI-05 is a gas cap injection well that has demonstrated a decrease in injectivity. The well has not been water washed since 2018. 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. -00 DLB Well Work Prognosis Well Work Prognosis IUTi �1►1 [I7.7_fi11111►� I TO: JimRegg /� (tel �1I�.G'2 P.1. Supervi�-1 sor FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, March 31, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp Nonh Slope, LLC AGI -05 PRUDHOE BAY UNIT AGI -05 Src: Inspector Reviewed By: P.I. Suprv�_ Comm Well Name PRUDHOE BAY UNIT AGI -05 API Well Number 50-029-22327-00-00 Permit Number: 193-002-0 Insp Num: mitLOL210322102248 Rel Insp Num: Inspector Name: Lou Laubenstein Inspection Date: 3/20/2021 i Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well AGI -05 'Type InjG -;TVD — 7771 ' ,Tubing 3108 3308 - 3305 3304 - 3307- -- PTD h 1930070 Type Test SPT Test psi 1943 1, 111 2208 1�.—-- 2192 2195 - 2201 BBL Pumped: 4.z BBL Returned: 4 i OA 5 d 5 7 Interval 4YRTST Notes: Presssure rising due to rate changing. v Wednesday, March 31, 2021 Page I of I fu -*071117 7:\`►I1 1 I TO: Jim Regg 4I Zc Zri2 l PJ. Supervisor FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, March 31, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC AGI -05 PRUDHOE BAY UNIT AGI -05 Src: Inspector Reviewed By: P.1. Supry Comm Well Name PRUDHOE BAY UNIT AGI -05; API Well Number 50-029-22327-00-00 Inspector Name: Lou Laubenstein Permit Number: 193-002-0 Inspection Date: 3/20/2021 Insp Num: mitLOL210322102452 Rel Insp Num: Wednesday, March 31, 2021 Page I of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well AGI -05 Type Inj G "TVD F 7771 ' Tubing 3313 3314 3314 " 3318 ---I - PTD - - 193002 -- Type Test SPT Test psi 1943 IA 1 172 2195 2186 - 2201 BBL Pumped: I 22 BBL Returned: 2 OA5 s " $- $ ' Interval 4YRTST P/F 1 Notes: Pressure rising due to changing rate. Wednesday, March 31, 2021 Page I of I MEMORANDUM TO: Jim Regg P.l. Supervisor FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, March 31, 2021 SUBJECT: Mechanical Integrity Tests Hilcmp Noah Slope, LLC AGI -05 PRUDHOE BAY UNIT AGI -05 See: Inspector Reviewed By: P.1. Supry ITC--f— Comm Well Name PRUDHOE BAY UNIT AGI -05 API Well Number 50-029-22327-00-00 Inspector Name: Lou Laubenstein Permit Number: 193-002-0 Inspection Date: 3/212021 Insp Num: mitLOL210322102755 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min - - Well AGI -01 Type Inj G TVD 7771 Tubing 3317 3316'3315 3315 �.� PTD 1930020 Type Test SPT Test psi 1943 ' IA 448 _ 2251 - 2234 2232 ' _ - -- BBL Pumped: 1 1.6 -BBL Returned: 15 OA 10 15 16 lnterva 4YRTST P/F P Notes: Good test after stable well conditions. ✓ Wednesday, March 31, 2021 Page 1 of I • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday,July 5, 2017 1:54 PM To: AK, GWO Well Integrity Engineer;AK, OPS FS1 OSM;AK, OPS FS1 Field OTL;AK, OPS FS1 DS Ops Lead;AK, OPS FS1 Facility OTL; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AKOpsProdEOCTL;AK, OPS PCC Ops Lead;AK, OPS EOC Specialists;AK, OPS Prod Controllers;AK, OPS FS1 DS18 Operator; Stone, Christopher;Wallace, Chris D (DOA);AK, OPS FS1 DS18 Operator Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R;Worthington,Aras J Subject: OPERABLE: Injector AGI-05 (PTD# 1930020) Outer Annulus Pressure Diagnostics Complete All, Gas injector AGI-05 (PTD# 1930020)was made under evaluation on 06/24/17 for an OA pressure excursion over NOL. The well has been monitored for 13 days and has shown no signs of anomalous pressure trends. The OA pressure spike seen on 06/23/17 is believed to be related to thermal effects and not to a change in the well mechanical condition. At this time the well is reclassified as Operable. Please respond if in conflict, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SCANNED JUL 1 7 2017, WO 1 O w Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday,June 24, 2017 9:05 AM To: AK, GWO Well Integrity Engineer;AK, OPS FS1 OSM;AK, OPS FS1 Field OTL;AK, OPS FS1 DS Ops Lead;AK, OPS FS1 Facility OTL; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AKOpsProdEOCTL;AK, OPS PCC Ops Lead;AK, OPS EOC Specialists;AK, OPS Prod Controllers;AK, OPS FS1 DS18 Operator; Stone, Christopher;Wallace, Chris D (DOA);AK, OPS FS1 DS18 Operator Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; Sternicki, Oliver R; Worthington,Aras J Subject: UNDER EVALUATION: Injector AGI-05 (PTD# 1930020) High Outer Annulus Pressure Over NOL All, Gas Injector AGI-05 (PTD# 1930020)was reported to have sustained outer annulus casing pressure above NOL on June 23, 2017. The pressures were reported to be TBG/IA/OA=3367/1500/1120psi. The pressure excursion appears to be related to an injection gas temperature swing. The well is now reclassified as Under Evaluation and will be monitored for 28 days to verify annulus integrity. Plan Forward: 1. DHD: Monitor Annulus Pressures 2. Well Integrity Engineer:Additional Diagnostics as needed Please respond if in conflict, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SCANNED Al1 4201.! wo 1 STATE OF ALASKA 1111kLASKA OIL AND GAS CONSERVATION COMMISSION • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate I1 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Water Wash I3 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 193-002 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory El AK 99519-6612 Stratigraphic 0 Service f3 6. API Number: 50-029-22327-00-00 7. Property Designation(Lease Number): ADL 0034628 8. Well Name and Number: PBU AGI-05 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: RECEIVED Total Depth: measured 9822 feet Plugs measured feet true vertical 8490 feet Junk measured feet N O V 2 4 2015 Effective Depth: measured 2196 feet Packer measured_ See Attachment feet 1 true vertical 2130 feet Packer true vertical See Attachment feet AO c Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 39-119 39-119 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 9289 9-5/8"47#NT8OS 36-9325 36-8008 6870 4760 Production Liner 678 7"29#L-80 9146-9824 7837-8492 8160 7020 Perforation Depth: Measured depth: 9516-9546 feet 9573-9583 feet 9606-9626 feet 9668-9688 feet 9730-9750 feet True vertical depth: 8193-8222 feet 8248-8257 feet 8280-8299 feet 8340-8360 feet 8400-8420 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 7"A-1 Injection SSSV 2196 2130 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9516-8420 Treatment descriptions including volumes used and final pressure: ��+� �L�5 2 6 � = 20 Bbls Neat Methanol,200 Bbls 50/50 Diesel/Xylene,720 Bbls Water w/F-103 Surfactant Mix,551 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 277995 260 3325 Subsequent to operation: 243362 400 3216 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations f3 Exploratory 0 Development 0 Service f3 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil ❑ Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ H SUSP 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-236 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature itkfit— Phone +1 907 564 4424 Date 11/23/15 Form 10-404 Revised 5/2015 %Ti—`6 ��7/6 RBDM4DEC 0 12015 Submit Original Only • Packers and SSV's Attachment PBU AGI-05 SW Name Type MD TVD Depscription AGI-05 SSSV 2196 2130.22 T A-1 Injection SSSV AGI-05 TBG PACKER 8975.49 7678.38 7" HES TNT Packer AGI-05 TBG PACKER 9078.19 7773.24 7" Baker SABL-3 Packer AGI-05 PACKER 9146.04 7836.75 7" H Isolation Packer • m Q o 0 0 0 0 0 0 0 0 0 0 0 O 0 N o 0 0 0 0 0 0 0 0 0 0 0 i 6) i 0 M N- C0 6) v 6) IM 3 V- - O) 00 - 00 N OO N N N- M 00 N CO U) M N- O N O) = 00 O C N M N N- M M M V O Nr = = CON-- ti CO 00 M CO CO N N N- r N- N- i F- N- CO C[) 00 CA O) M CO M Cf) V N- M M N- 00 M M OO M M M N- N N N- ti ti O Cn M O •,- CO N N ,- V N N 00 M '- E 0000 M 00 N N O7 0 0 = - M O) O) N N OO M CA M O) V 111111llllll • 2 a _ CO rnrn - VCO0�0 a)0 MM00M MNN ) OOO = I O) N N OO CA ) O) • CO C[) O C O O O O CC) 00 O CO CO O a) == -11- 00 W JCO l d *k OO A Z J J Z *k *k CO CO CO - p) 00 N _ N � N N N N N V o M M L.0N ' ) N- N Li) Li) . r MMMONN- COo 0 COMNLO 0 00 CN N- N '- 00 M Cfl O V 1 LO d ) C) O N O W O C W W •• U F a 0000000 Z Z Z Z Z ZUuuCO . . $ ƒ / � � g c = 2 o » o 0 \ /70 f & o E' in % » a_co (13f % § 2d w$ a o .E 5 > § / 2 ƒ \ a) I e 12 a ca w\ rno - R < 2 = Y o _ / / _ © .x o _o0c \ E � / / � m o / E < c ¥ E ./ c ± o / t % f o O E CO 2 F k � .c o .> / >' R / 5 2/ \ � � « O m -0 5e : $ \ — 9 t@ / £ G@ E � « : � K eo 0 < OM U) R E u e� c2 _ -o0 /� Ct � -0 / \ / / R k a IO & E / t / \ o D / - # 2 2 2 c t g 2 \ & o / oam = 2o@ ± 2 a o + N m k CO \/ .2G2ko ƒ ) / & n ,- fU ® mR = m K / \ S / f / « / \ f / / f % E/ < o G o * 2 g E O \ @ \ A 2 o : R 2 3 / 2 / 5 2 < m r / CO CNI � 0E � 2 CO \ a ^ q w « / / 0 < TREE= CNV • WH LI—EAD= FMC AGI-Q V SAFETY NOTES:WELL REQUIRES A SSSV***T' +ACTUATOR= BAKER C LNR NOT CMD. "MAL KB.REV= 49.2" 13-3/8"CSG,68#, — 79' —FA I KOP= 500' K-55, D=12.415" j 2210' —17-5/8"X r xo,D=6.253" Max Angle= 38"@ 2949' NOT LISTED / 2226' Hl'08 6 NP,D=6.00" Datum MD= 10189' ON TALLY Datum TVD= 8800'SS / 20"CONDUCTOR 91.5#,H-40,ID=19.124" --{ 106' 2242' H 7"X 7-518"XO,ID=6253" 7-5/8"TBG,29.7#,L-80 VA MTOP HC, -4 2210' -0459 bpf,D=6.875' 7"TBG,26#,L-80 VAMTOP, —{ 2242' .0383 bpf,D=6.276' • 8923* -47-5/8"X 7"XO,D=6.253' 13-318"CSG,72#,L-80,D=12.347" H 3868' 7-5/8"TBG,29.7#,L-80 VAMTOP HC, H 8923" I li 8940' H 7"R NP,D=5.963" .0459 bpf,D=6,875' Minimum ID =4.455" @ 9127' g 8971' --�s 518"X 7"HES TNT PKR,D=590* 5-1/2" OTIS XN NIPPLE1 —17"9011' �7"RN NP,ID=5.50" 7'TBG,26#,L-80 TCI, H 9023' ` 9023` H 7"X 5-1/2'XO,ID=4.850' .0383 bpf,D=6.276' — 9066" —{5 112"MULESHOE D=4.850" 7"TBG STUB(12/05/12) — 9036' j----------- Z 9076' H9-5/8"X 7"BKR SB-3A PKR,D=6.000" 7"TBG,26#,NT-80-S-PC,NSCC, H 9084' - 9084' —17"X 5-1/2"XO,ID=4,812" • .0383 bpf,D=5276' ' 9106' H5-1/2"PARKER SWS NP(9CR),D=4.562" 9127' 5-1/2-OTIS XNMP,D=4A55" 5-1/2'TBG,17#,L-80 NSCC, H 9139' .0232 bpf,D=4.892' / 9139' H 5-1/2"WLEG,D=4.892" TOP OF 7"LNR H 9144' 9135' 1 t3.MDTTLOGO05/10/93 9144' H9-5/8"X 7"BKR H ISOLATION PKR,D-6.188" 9150' —19-5/8"X 7"BKR HY-FLO I LNR HGR,ID=6.188" 9-518"CSG,47#,NT-80-S,D=8.681" —1 9323' I,--A PERFORATION SUMMARY REF LOG: BHCS AWA ON 04/20/93 ANGLE AT TOP FERE: 15"@ 9516' Note:Refer to production DB for historical pert data SIZE SPF I'ITHRVAL C n/Sqz SHOT SQZ 3-3/8" 6 9516-9546 0 ?6/13/93 3-3/8" 6 9573-9583 0 '6/13/93 3-3/8" 6 9606-9626 0 '6/13/93 3-3/8" 6 9668-9688 0 r6/13/93 3-3/8" 6 9730-9750 0 6/13/93 PBTD H 9801' 7"LNR, 29#,NT-80-S,.0371 bpf,D=6.184" H 9822' A DATE REV BY COMMHdTS DATE REV BY ODMVENfS PRUDHOE BAY UNIT 04/22/93 AUDI 2 INITIAL COMPLETION 03/10/13 RCT/PJC DB NP ID CORRECTION WH.L: AGI-05 12/12/12 DOYONI4 RWO 03/19/13 JNIJJMD ADDED SSSV(03/10/13) PERMIT NO: 1930020 12121/12 JMD DRLG DRAFT CORRECTIONS 04/20/13 PJC SSSV CORRECTION AR NO: 50-029-22327-00 01/02/13 PJC DRAWNG CORRECTIONS SEC 36,T12N,R14E,2055 FSL&2474'Fa 01/03/13 PJC DRAVVT'IG CORRECTIONS 03/08/13 SJW/JM) FUZED PXN PLUG(03/06/13) BP Exploration(Alaska) (-) or Tye �V/j, sTHE STATE Alaska Oil and Gas ��>.��, ofALASKA Conservation Commission 333 West Seventh Avenue Anchorage,nM Alaska 99501-3572 GOVERNOR BILL WALKER 9 Main: 907.279.1433 OF -AL AS*1ff', Fax: 907.276 7542 scoot) A?P„ 2 9 2-C1\5 www.aogcc.alaska.gov Spencer Morrison Petroleum Engineer 3 , 06 P— BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU AGI-05 Sundry Number: 315-236 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, fik,v0(It Cathy . Foerster Chair DATED this Z1 day of April, 2015 Encl. R C W D STATE OF ALASKA APR 2 1 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION 4( �7f/,S APPLICATION FOR SUNDRY APPROVALS ,BOG CC 20 MC 25.280 1.Type of Request' Abandon❑ Plug for Rednll❑ Perforate New Pool El Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Water Wash CI • 2.Operator Name. 4.Current Well Class: 5.Permit to Dnll Number: BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 193-002-0• 3 AddressStratigraphic ElService El • 6.API Number: P.O.Box 196612,Anchorage,AK 99519-6612 50-029-22327-00-00 . 7.If perforating' 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? PBU AGI-05 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10 Field/Pool(s). ADL0034628 - PRUDHOE BAY, PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9822 8490 • 2196 2130 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 39-119 39-119 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 9289 9-5/8"47#NT8OS 36-9325.34 36-8007.95 6870 4760 Production None None None None None None Liner 678 7"29#L-80 9146.04-9823.85 7836.75-8492.12 8160 7020 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths 7"A-1 Injection SSSV 2196',2130.22' ' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program I] BOP Sketch ❑ Exploratory El Development El Service El 14.Estimated Date for 15.Well Status after proposed work: 6/10/15 Commencing Operations' Oil ❑ Gas El WDSPL ❑ Suspended El 16.Verbal Approval: Date: WINJ ❑ GINJ El 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 j7zl/1 !S Date Prepared by Garry Catron 564-4424 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 3 k 6 ^2...2›(12 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test El Location Clearance El Other: Spacing Exception Required? Yes ❑ No LvJ Subsequent Form Required /c— 4 c 4 APPROVED BY `7 Approved by: fst4tM(/v COMMISSIONER THE COMMISSION Date. '•–Z,7...../..5.-- 1, 'T-1 7/�1, 'TL 4 z3/15- IlkiGINpAiLisc12-Z- 6--- Form 10-403 Revised 10/2012 oR valid for 12 months from the date f approval. Submit Form and Attachments'n Duplicate RBDMS APR 2 9 2015 ,� �7 if -0 O 0 0 LO O O co o 0 0 0 v co CO CO00 to co co 0o co 0o co N Q o 0 0 0 0 _O O _0 0 0 0 N F.__ N- O CO o) Tr N V O O TD V I� N CO Ln O P 'Cr 0 O O o 0 0 0 0 0 0 0 0 0 - rnN- COMu) vv � � vrnrn Co N N- N N- N CO CO CC) CO Co V co I,- ti N- N- N- CO CO a) Co N M O O N- N ' LO co m O d7 a0 N M f� M I� M Q O V 00 Co M M N- ti N- N- N r N F- Q O N-O CO CO o) CO N- CO CO V to O CO CO CO CO M CO N N L F- (a CO E N a) E O N IC) V C) N- o) CO 1- N- CO 'CI- 0,1 N CO N CO CO N `^ M p co co co CO o N- O '- N N o) ( ) O o) 0) CO 0) o) 0) 0) N CO N c J •- D a 0 (� F- a) a:) °N° o0ovCCO vim U Q CO Mo) CO CO M o) Oo) (CS: o) N o CV N C) Cl) O in O O o O co 10 C3O CO CO COO O CO 2 o O J J a0 J Y cc J J 00 # N Z J N op 4# lit*k N- N- In �$ N- M k � o) - - CO CO N EO 0\O N N N N C 00 CO N CO ~ M CO I� 7 ' (0 O N- 6) O) O O oO O co co co CO N LO L M (.0v O M M CO N w F- C) D C U w w w c < < 0000000 Z Z Z Z Z Z ZUooa Z w W IYCCOOm m m 00 m 00 OF- Z > > DD > > > DD UZ J cn L7 F- F- F- F- F- F- Perforation Attachment ADL0034628 Well Date Perf Code MD Top MD Base TVD Top TVD Base AGI-05 6/13/93 PER 9516 9546 8193 8222 AGI-05 6/13/93 PER 9573 9583 8248 8257 AGI-05 6/13/93 PER 9606 9626 8280 8299 AGI-05 6/13/93 PER 9668 9688 " 8340 8360 AGI-05 6/13/93 PER 9730 9750 8400 8420 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 ADL0034628 Well Facility Type MD Top Description TVD Top AGI-05 SSSV 2196 7"A-1 Injection SSSV 2130 AGI-05 PACKER 8975 7" HES TNT Packer 7678 AGI-05 PACKER 9078 7" Baker SABL-3 Packer 7773 AGI-05 PACKER 9146 7" H Isolation Packer 7837 Packers and SSV's Attachment ADL0034628 Well Facility Type MD Top Description TVD Top AGI-05 SSSV 2196 7"A-1 Injection SSSV 2130 AGI-05 PACKER 8975 7" HES TNT Packer 7678 AGI-05 PACKER 9078 7" Baker SABL-3 Packer 7773 AGI-05 PACKER 9146 7" H Isolation Packer 7837 TREE= ` CNV WEi.LFEAD= FMC AGI-05 SNR NOTCMT :WELL REQUIRES A SSSV"'" ACTUATOR= BAKER C NTTIAL KB.ELEV= 49.2' 13-3/8.CSG,68#, -{ 79' )( K-55, D=12.415' 2210' -17-5/8"X 7"XO,D=6.253" KOP= 500' Max Angle= 38"G 2949' NOT LISTED / 2226' -17"DB 6 NP,D=6.00" Datum MD= 10189' ON TALLY Datum TVD= 8800'SS / 20"CONDUCTOR,91.5#,H-40,D=19.124" 106' 2242' --17"X 7-5/8'XO,ID=6.253" 7-5/8-TBG,29.7#,L-80 VAMTOP HC, 2210' .0459 bpf,D=6.875' 7-TBG,26#,L-80 VAMTOP, H 2242' .0383 bpf,D=6.276' 8923' -17-5/8"X 7"XO,D=6.253" • 13-3/8"CSG,72#,L-80,D=12.347" -{ 3868' 7-5/8"TBG,29.7#,L-80 VA MTOP HC, -' 8923' 1 8940' 7"R MP,ID=5.963• .0459 bpf,D=6.875' Minimum ID =4.455" @ 9127' g 8971' -19-5/8"x 7-HES TNT PKR D=5.90• 5-1/2" OTIS XN NIPPLE 9011' -17-RN NP,D=5.50" 7"TBG,26#,L-80 TCI. H 9023' 9023' -17"X 5-1/2"X0,ID=4.850' .0383 bpf,D=6.276' 7"TBG STUB(12/05/12) -{ 9036' -_ 9066' -15-1/2"MULESHOE D=4.850" 9076' -19-5/8"X 7"BKR SB-3A PKR,D=6.000" 7"TBG,26#,NT-80-S-FC,NSCC, --{ 9084' 1-\ 9084' -17"X 5-1/2"XO,ID=4.812" .0383 bpf,D=6.276" 9106' H5-1/2"PARKER SVVS NP(9CR),D=4.562" 9127' H 5-112"OTIS XN NP,D=4.455" 5-1/2"TBG,17#,L-80 NSCC, -� 9139' .0232 bpf,D=4.892' / 9139' H5-1/2"WLEG,D=4.892" TOP OF 7"LIR H 91+44' Gam■ 9135' -J a.MD TT LOGGED 05/10/93 9144 -$9-518"X 7"BKR H ISOLATION PK R,D-6.188" 9150' H9-518"X 7"BKR HY-FLO i LM2 HGR,D 6.188" 9-5/8"CSG,47#,NT-80-S,D=8.681" -� 9323' PERFORATION SUNSAARY FEF LOG: BHS AWA ON 04/20/93 ANGLE AT TOP PERF: 15"It 9516' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SOZ 3-3/8" 6 9516-9546 0 P6/13/93 3-3/8" 6 9573-9583 0 '6/13/93 3-3/8" 6 9606-9626 0 '6/13/93 3-3/8" 6 9668-9688 0 x6/13/93 3-3/8" 6 9730-9750 0 6/13/93 PBTD --1 9801' 7"L142, 29#,NT-80-S,.0371 bpf,D=6.184• -{ 9822' DATE REV BY COM LENTS DATE REV BY C IVIVE TS PRUDHOE BAY INT 04/22/93 AUDI 2 IMT1AL COMPLETION 03/10/13 RCT/PJC D8 NPD CORRECTION WELL: AGI-05 12/12/12 DOYONI4 lW O 03/19/13 JNU.1610 ADDED SSSV(03/10/13) PEEWIT NO:'1930020 12/21/12 JIM DRLG DRAFT CORRECTIONS 04/20/13 PJC SSSV CORRECTION AR NO: 50-029-22327-00 01/02/13 PJC DRAWING CORRECTIONS SEC 36,T12N,R14E,2055'FSL&2474'FEL 01/03/13 PJC DRAWN*CQRRECT1ONS 03/08/13 SJWJM)PULED PXN PLUG(03/06/13) BP Exploration(Alaska) ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.9,DBR,LHD,EAZ 01/15/15) General Information Well Name: AGI-05 Well Type: Gas Injection Well API Number: 50-029-22327-00 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: AWGRS Job Scope: TUBING WASH/PICKLE Other regulatory None requirements? Sundry Form 10-403 Required? Yes Sundry Form 10-404 ,r Yes Primary Secondary Required? 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 ti Revisions(date,who,what changed): r Current Well Status Information Water Rate or Gas Rate or Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate FTP or Injectic Date (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Pressure (psi) '', Cut(%) (Mscf/Day) 1 4/6/2015 286,726 3,361 Current Status: Operable Flowing Inclination>70°at Depth(ft) Recent H2S (date, mMaximum Deviation (Angle and PP ) NA 0 ppm Depth) 38° 2,949' MD Datum depth,ft TVDss 8,800' TVDss Dogleg Severity(Angle and Depth) 6° 975' MD Reservoir pressure(date, 11/25/2012 3,390 psi Minimum ID and Depth 4.445"CO 9,127' psig) — — Reservoir Temp,F 115° F Shut-in Wellhead Pressure 2,400 psi Known mech. integrity None, passing MIT-IA and Passing MIT-T problems(specifics) Last downhole operation (date, operation) 1/31/2014 SL SSSV Maint. Most recent TD tag (date,depth, 11/25/2012 9,783' MD 3.5"Centralizer toolstring OD) Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, AGI-05 has 1 water wash performed in the last 15 years.The wash was performed on 7/11/2012 with 100 background information, bbls D/X at 50 F with 600 bbls of FW at 120 F with surfactant at 5 BPM. etc: We will be trying a larger volume of FW and D/X in an attempt to increase injectivity. This summer there will be an NGI restoration project that will include significant down time for the NGI wells. i nave incivaea me tentative scneauie oeiow. i o reau..- ,ne impact or naving me Nu'wens snut 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: STATE OF ALASKA ;; . a R --- p : y; y R KA OIL AND GAS CONSERVATION CCOISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: 4 ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing IS Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: J ✓nGk BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 193 - 002 ' <.; - „” ,! 3. Address: ❑ Development ® Service ' 6. API Numbe 311. 4 w k - J P.O. Box 196612, Anchorage, Alaska 99519 - 6612 4 50.029 22327 - 00 - 00 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 028301 & 034628 ' PBU AGI - • 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): Prudhoe Bay / Prudhoe Bay . 11. Present well condition summary: Total depth: measured 9822' + feet Plugs:(measured) None feet true vertical 8490' • feet Junk: (measured) None feet Effective depth: measured 9801' feet Packer: (measured) 8971' / 9076' feet true vertical 8470' feet Packer: (true vertical) 7674' / 7771' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 20" 30' - 106' 30' - 106' 1490 470 Surface 3829' 13 -3/8" 29' - 79' / 79' - 3858' 29' - 79' / 79' - 3481' 3450 / 4930 1950 / 2670 Intermediate 9289' 9 -5/8" 34' - 9323' 34' - 8006' 6870 4760 Production Liner 696' 7" 9144' - 9822' 7835' - 8490' 8160 7020 Perforation Depth: Measured Depth: 9516' - 9750' feet True Vertical Depth: 8193' - 8420' feet Tubing (size, grade, measured and true vertical depth): 7 ", 29.7# x 7 ", 26# L 9065' 7761' 7 ", 26# x 5 - 1/2 ", 17# NT - 80 / L - 80 9036' - 9139' 7734' - 7830' Packers and SSSV (type, measured and true vertical depth): A -1 � rt STN 2226' 2156' 9 -5 /8" x 7" HES TNT Packer 8971' 7674' 9 -5/8" x 7" BkR SB 3 -A Packer 9076' 7771' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: SCANNED APR y q n At .l 2 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 191523 1050 3255 Subsequent to operation: 204481 80 3255 14. Attachments: ❑Copies of Logs and Surveys run 15. Well Class after work: ❑ Exploratory ❑ Stratigraphic ❑ Development ® Service ® Daily Report of Well Operations ® Well Schematic Diagram 16. Well Status after work: ❑ Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ® GINJ ❑ SUSP ❑ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact: Sean McLaughlin, 564 -4387 312 - 414 Email: Sean.McLaughlin @bp.com Printed N e: Joe La ,yy - Title: Drilling Technologist Signature i Phone: 564 -4091 Date: 3/2 Form 10-404 Revis d 10 7 : b S APR 0 2 2013 Q _ ' " 1 PJ „ ' 4, I 'u 13 Submit Original Only ( • AGI -05, Well History (Pre Rig Work) Date Summary 11/25/12 RAN 6.16" GAUGE RING, TAG MCX AT 2186' SLM (2219' MD). PULL 7" HES MCX (s /n = BP -703) ON CA. CARRIER FROM 2186' SLM (2219' MD) (one piece of packing & one o -ring missing). RAN 3.50" CENT, 5 -1/2" TEL, 2.50" SAMPLE BAILER. LOC TT AT 9108' SLM (9,135' ELMD, +27' CORRECTION). TAG STICKY BOTTOM AT 9756' SLM (9,783' ELMD) (recovered full s. bailer of schmoo /sand). RAN SLB TANDEM SBHPS GAUGES AS PER PROGRAM (good data). 11/26/12 LRS LOADED TBG W/ 720 BBLS OF 2% KCL & 95 BBLS OF 60/40 METHANOL. SET PXN PLUG BODY AT 9108' SLM (9127' MD), SET P -PRONG AT 9104' SLM. LRS PERFORMED PASSING MIT -T TO 3000 PSI (see Irs log). LRS PERFORMED PASSING MIT -IA TO 3000 PSI (see Irs log). DUMP BAILED SLUGGITS, TOP OF SLUGGITS AT 9,098' SLM (9,117' MD). 11/26/12 Assist SL w/ TBG Load & MIT -T to 3000 psi PASSED / MIT -IA to 3000 psi PASSED (Pre Rig) Pumped 10 bbls 60/40 spear down Tbg followed by 720 bbls of 120* 2% KCL. Pumped 95 bbls of 60/40 down Tbg for FP. SL sets plug. / MIT -T- Pressure up w/ 15.7 bbls 60/40 meth. On 2nd test TBG lost 22 psi in 1st 1 5min & 11 psi in 2nd 15 min, for a total loss of 33 psi in 30 min. Pass. Bled TBGP / MIT -IA- Pressured up w/ 21 bbls 60/40 meth. On 1st test, IA lost 7 psi in 1st 15 min & 5 psi in the 2nd 15 min, for a total loss of 12 psi in 30 min. Pass. Bleed IAP. SL in control of well. FWP= 725/540/0 * *Tags hung, IA & OA= OTG * *. Page 1 of 1 • • O , Common Well Name: AGI -05 AFE No Event Type: WORKOVER (WO) Start Date: 11/26/2012 End Date: 12/12/2012 X4- 00WFH -E; (3,485,000.00 ) Project: Prudhoe Bay (various) Site: AGI Rig Name /No.: DOYON 14 Spud Date/Time: 1/18/1993 12:00:00AM Rig Release: 12/12/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 5 : 05 1/18/1993 00:00 @49.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/26/2012 12:00 - 16:00 4.00 MOB N WAIT PRE RIG DOWN RIG FLOOR, SKID FLOOR INTO MOVE POSITION 16:00 - 17:30 1.50 MOB N WAIT PRE MOVE RIG OFF OF WELL 17:30 - 22:30 5.00 MOB N WAIT PRE INSTALL REAR BOOSTER - MOVE MATS FROM WELL AREA -MOVE RIG FROM NGI PAD TO WEST DOCK STAGING AREA 22:30 - 00:00 1.50 MOB N WAIT PRE SPOT RIG ON WEST DOCK STAGING AREA -REMOVE BOOSTERS - INSTALL CELLAR DOORS - WAIT ON PRE -WELL WORK TO BE DONE AT AGI-05 - MAINTENANCE ON RIG 11/27/2012 00:00 - 06:00 6.00 MOB N WAIT PRE RIG MAINTENANCE/ STAND BY FOR AGI-05 PREP WORK. -SHIM RIG AND RIG UP HEAT AND AIR TO RIG FLOOR. -LAY DOWN CHOKE HOSE. 06:00 - 12:00 6.00 MOB N WAIT PRE BEGIN MODIFICATION OF CHOKE LINE ASSEMBLY. -CUT OUT OLD HIGH PRESSURE CHOKE LINE IN PITS. -MOBILIZE NEW FABRICATED HP CHOKE HARD LINE TO RIG FLOOR. - DISCONNECT KOOMEY HYDRAULIC LINES FROM BOP STACK AND REPOSITION STACK. - DISCONNECT KILL LINE FLANGE AND HOOK UP ON BOP STACK. -RIG UP SCAFFOLDING IN CELLAR W/ THIRD PARTY SCAFFOLDING CREW . 12:00 - 18:00 6.00 MOB N WAIT PRE -RIG UP SCAFFOLDING IN CELLAR, CONT. - WELDING WORK ON NEW CHOKE LINE INSTALL, CONT. - MECHANIC & ELECTRICIAN WORK ON BOILER #2 AND DRAW WORKS ELECTRO DYNAMIC BRAKE. -FORK LIFT DEMOB EQUIPMENT FROM NGI PAD TO AGI PAD. - WELDING WORK ON NEW CHOKE LINE INSTALL, CONT. 18:00 - 00:00 6.00 MOB N WAIT PRE WELDING WORK ON CHOKE LINE INSTALL, CONT. - START LOW PRESSURE MUD LINE MODIFICATION. - FABRICATE TEMPORARY SHELTER FOR ELECTRICAN TO WORK ON NEW FUEL STATION. -THIRD PARTY X -RAY ON HIGH PRESSURE PIPE WELDS ON CHOKE MODIFICATION. 11/28/2012 00:00 - 06:00 6.00 MOB N WAIT PRE STANDBY AND RIG MAINTENANCE, CONT. - WELDING WORK ON NEW CHOKE LINE INSTALL. - WELDING WORK ON LOW PRESSURE MUD LINE. - MECHANIC WORK ON BOILER #2. -CLEAN AND PAINT RIG EQUIPMENT. Printed 12/26/2012 9:57:02AM • i Common Well Name: AGI -05 AFE No Event Type: WORKOVER (WO) Start Date: 11/26/2012 End Date: 12/12/2012 X4- 00WFH -E; (3,485,000.00 ) Project: Prudhoe Bay (various) Site: AGI Rig Name /No.: DOYON 14 Spud Date/Time: 1/18/1993 12:00:00AM Rig Release: 12/12/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 5 : 05 1/18/1993 00:00 @49.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 12:00 6.00 MOB N WAIT PRE - WELDING ON NEW CHOKE LINE INSTALL, CONT. -BEGIN PENETRATION WELD OF CHOKE LINE THRU MID DECK. - ELECTRICAL AND WELDING WORK ON NEW FUEL STATION ON RIG, CONT. -WORK ON BOILER #2 W/ MECHANIC, CONT. - MAKE UP PRE - FABRICATED CHOKE LINE PIECES FROM MANIFOLD TO CELLAR, CONT. -INSTALL DRAW WORKS COVER. _ *FIRE DRILL, CREW RESPONSE TIME 1:46 12:00 - 18:00 6.00 MOB N WAIT PRE -CHOKE LINE PENETRATION FABRICATION & WELD OUT, CONT. - ELECTRICAL AND WELDING WORK ON NEW FUEL STATION, CONT. - FABRICATE SUPPORT BRACKETS FOR NEW CHOKE LINE. - MECHANIC WORK ON BOILER HOT WELL AUTO FILL SYSTEM. -CLEAN AND PAINT RIG EQUIPMENT. 18:00 - 00:00 6.00 MOB N WAIT PRE -CHOKE LINE PENETRATION WELD OUT, CONT. -FABRICATION AND WELD OUT ON WATER LINE TO RIG FLOOR. -FABRICATE SUPPORT BRACKETS FOR CHOKE LINE, CONT. -CLEAN AND PAINT RIG EQUIPMENT. 11/29/2012 00:00 - 06:00 6.00 MOB N WAIT PRE STANDBY AND RIG MAINTENANCE, CONT. -CHOKE LINE PENETRATION WELD OUT, CONT. - FABRICATION AND WELD OUT ON WATER LINE TO RIG FLOOR, CONT. - FABRICATE SUPPORT BRACKETS FOR CHOKE LINE, INSTALL SAME. -WORK ON LEVEL 2 PREVENTIVE MAINTENANCE WORK ORDERS -CLEAN AND PAINT RIG EQUIPMENT. 06:00 - 12:00 6.00 MOB N WAIT PRE WELD OUT ON CHOKE SUPPORT BRACKETS, CONT. - DISCONNECT DRILLER SIDE ELEVATORS ON PIPE SKATE. -WELD ON NEW STAND PIPE BLOW DOWN CONNECTION. (INSTALL NEW MALE 1502) -CLEAN AND PAINT RIG EQUIPMENT, CONT. *TABLE TOP MAN DOWN DRILL, RIG EVACUATION DRILL. 12:00 - 18:00 6.00 MOB N WAIT PRE WELD OUT ON CHOKE SUPPORT BRACKETS, CONT. -WELD ON STAND PIPE BLOW DOWN CONNECTION, CONT. - ELECTRICIAN WORK ON FUEL STATION, CONT. -CLEAN AND PAINT RIG EQUIPMENT, CONT. 18:00 - 00:00 6.00 MOB N WAIT PRE INSTALL AND WELD OUT NEW 2" HOLE FILL AND INJECTION LINE IN PITS. - CLEAN & INSPECT GATE VALVE ON STAND PIPE. - PRE -FAB ON 3" WATER LINE AND WELD OUT IN TRUCK SHOP. -CLEAN AND PAINT RIG EQUIPMENT, CONT. Printed 12/26/2012 9:57:02AM Common Well Name: AGI -05 AFE No Event Type: WORKOVER (WO) Start Date: 11/26/2012 End Date: 12/12/2012 X4- 00WFH -E; (3,485,000.00 ) Project: Prudhoe Bay (various) Site: AGI Rig Name /No.: DOYON 14 Spud Date/Time: 1/18/1993 12:00:00AM Rig Release: 12/12/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 5 : 05 1/18/1993 00:00 @49.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/30/2012 00:00 - 06:00 6.00 MOB N WAIT PRE STANDBY AND RIG MAINTENANCE, CONT. -WELD OUT NEW 2" HOLE FILL AND INJECTION LINE IN PITS, CONT. -CLEAN & INSPECT GATE VALVE ON STAND PIPE, CONT. - INSTALL PRE - FABRICATED 3" WATER LINE, WELD OUT IN PITS AND CELLAR. -RIG DOWN SCAFFOLDING IN CELLAR. -RE -XRAY CHOKE LINE WELD. -CLEAN AND PAINT RIG EQUIPMENT, CONT *INSTALL TWC ON AGI-05 W/ WELL SUPPORT. *-TEST FROM ABOVE 250 AND 4000 PSI FOR 5 CHARTED MINUTES -OK. 06:00 - 12:00 6.00 MOB N WAIT PRE -WELD OUT NEW 2" HOLE FILL AND INJECTION LINE IN PITS, CONT. - WELD WATER LINE ON RIG FLOOR, CONT. - REPAIR 4" DEMCO ON STANDPIPE. -TUBOSCOPE INSPECTION OF WELDS ON STANDPIPE BLOW DOWN LINE AND INJECTION LINE. - REPOSITION ANTENNAE ON ROOF AWAY FROM GC! ANTENNAE. -HOOK UP NEW CHOKE LINE ON BOPE STACK. -CLEAN AND PAINT RIG EQUIPMENT, CONT 12:00 - 18:00 6.00 MOB N WAIT PRE -WELD OUT WATER LINE UNDER RIG FLOOR, CONT. - CLEAN AND CLEAR RIG FLOOR OF TOOLS AND EQUIPMENT. - REMOVE MUD BUCKET HOSE AND TONG HEADS. - REMOVE ALL OLD IRON CUT OUT, OFF RIG FROM MODIFICATIONS. -CRANE INSPECTIONS. *FIRE DRILL: RESPONSE TIME 1:30. 18:00 - 00:00 6.00 MOB N WAIT PRE -WELD OUT WATER LINE UNDER RIG FLOOR, CONT. -PAINT FLOOR ON MEZZANINE LEVEL. -WORK ON RAM SEALS IN SHOP. -WORK ON INJECTION LINE. -CLEAN AND CLEAR CELLAR OF ALL TOOLS AND EQUIPMENT. - INVENTORY RIG PPE. - WELD OUT BRACING FOR NEW LINES ON RIG FLOOR. 12/1/2012 00:00 - 06:00 6.00 MOB N WAIT PRE STANDBY AND RIG MAINTENANCE, CONT. -WORK ON RAMS IN SHOP,CONT. -PRIME AND PAINT LINES, BRACKETS AND NEW FUEL STATION. -CRANE INSPECTIONS, CONT. - INSTALL SAFTEY CLAMPS ON NEW CHOKE LINE. - FABRICATE NEW HOLE FILL LINE. Printed 12/26/2012 9:57:02AM e 7 Common Well Name: AGI -05 AFE No Event Type: WORKOVER (WO) Start Date: 11/26/2012 End Date: 12/12/2012 X4- 00WFH -E; (3,485,000.00 ) Project: Prudhoe Bay (various) Site: AGI Rig Name /No.: DOYON 14 Spud Date/Time: 1/18/1993 12:00:00AM Rig Release: 12/12/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 5 : 05 1/18/1993 00:00 @49.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ _ (ft) _ 06:00 - 12:00 6.00 MOB N WAIT PRE -WELD OUT WATER LINES, CONT. -CRANE INSPECTION AND COME -ALONG INSPECTIONS, CONT. - NEEDLE GUN FLOOR BEHIND IRON ROUGHNECK. -RIG UP KILL LINE ON BOP STACK. -PRIME AND PAINT MUD LINE ON OFF DRILLER SIDE. -PAINT FUEL STATION, CONT. - INSPECT PAD EYES. -WELD ON HANDRAILS THROUGHOUT THE RIG. *NOTIFIED AOGCC AT 10:00 AM 12 -2 -12 VIA EMAIL OF UPCOMING BOPE TEST. *FIRE DRILL RESPONSE TIME: 2 MINUTES AND 11 SECONDS. 12:00 - 18:00 6.00 MOB N WAIT PRE - FINISH PAINTING FUEL STATION. -NEEDLE GUN RIG FLOOR FOR HERCULINER PRODUCT. -WELD SEAL AROUND FLOOR FROM NEW PLUMBING INSTALLATION. -WELD OUT ON INJECTION LINE. -PAINT FLOOR IN KOOMY ROOM. -REPLACE 0-RING IN CONTROL VALVE ON RIG FLOOR TUGGER. - INSTALL AIR HOSE REEL. 18:00 - 00:00 6.00 MOB N WAIT PRE - NEEDLE GUN RIG FLOOR, CONT. -PAINT SKATE CONTROL BOX. - WELD ON INJECTION LINE, CONT. - INSTALL KICK PLATE ON MUD PUMP LANDING. 12/2/2012 00:00 - 06:30 6.50 MOB P PRE - PREPARE TO SKID RIG TO MOVING POSITION. -LAY HERCULITE AND RIG MATS AT AGI -05. -MOVE BLAST SHACK FROM NGI TO AGI PAD AND POWER UP. -SKID RIG FLOOR TO MOVING POSITION. -WELD COOLANT PUMP HATCH ON RIG FLOOR. -PJSM ON INSTALLING REAR BOOSTERS. - INSTALL REAR BOOSTERS. - PREPARE RIG FOR MOVE FROM WEST DOCK TO AGI -05. 06:30 - 12:00 5.50 MOB P PRE PJSM ON RIG MOVE FROM WEST DOCK TO AGI -05. -MOVE FROM WEST DOCK INTERSECTION TO AGI-05 - ARRIVE AT PAD AGI AT 12:00 12:00 - 14:00 2.00 MOB P PRE SPOT RIG ON PAD TO REMOVE REAR BOOSTERS. - PJSM AND REMOVE REAR BOOSTERS. - INSTALL CELLAR DOORS 14:00 - 16:30 2.50 MOB P PRE PJSM MOVE RIG OVER WELL AGI-05 - MOVE RIG OVER WELL CENTER ON AGI -05. -LEVEL RIG WITH SHIMS. 16:30 - 17:30 1.00 MOB P PRE PJSM AND SKID RIG FLOOR INTO DRILLING POSITION. Printed 12/26/2012 9:57:02AM Common Well Name: AGI -05 AFE No Event Type: WORKOVER (WO) Start Date: 11/26/2012 End Date: 12/12/2012 X4- 00WFH -E; (3,485,000.00 ) Project: Prudhoe Bay (various) Site: AGI Rig Name /No.: DOYON 14 Spud Date/Time: 1/18/1993 12:00:00AM Rig Release: 12/12/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 5 : 05 1/18/1993 00:00 @49.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:30 - 00:00 6.50 MOB P PRE RIG UP FOR OPERATIONS. -HOOK UP SERVICE LINES TO RIG FLOOR. -SET MATS, LAY HERCULITE AND SPOT ROCKWASHER INTO POSTION AND BERM UP. - SECURE SUCTIONS IN THE PITS. - PREPARE MUD PUMPS -RIG BEAVER SLIDE OUT. - PREPARE PITS TO TAKE ON BRINE. *HELD RIG EVACUATION DRILL: RESPONSE TIME AT 4 MINUTES AND 45 SECONDS. AAR. *JEFF JONES, AOGCC, CALLED RIG AT 8:30 PM 12 -2 -12 AND REQUESTED 2 HOUR NOTICE FOR BOPE TEST. 12/3/2012 00:00 - 03:00 3.00 MOB P PRE PREPARE RIG FOR OPERATIONS, CONT. -LOAD PITS WITH 9.8 PPG BRINE. - INSTALL SECOND -GATE VALVE ON IA W/ 1502 FLANGE. - INSTALL 1502 FLANGE WITH VALVE ON OA. - REMOVE MATS AFTER SPOTTING ROCKWASHER. -RIG UP ROCKWASHER. -MOVE INLINE HEATER FOR CELLAR. ACCEPT RIG AT 00:00 HRS. ON 12 -3 -12 03:00 - 06:00 3.00 MOB P PRE OPEN SSV WITH PAD OPERATOR. - TUBING PRESSURE =0 PSI. -PJSM ON PRESSURE TESTING TWC. -TEST TWC 250/4000 PSI FOR 5 CHARTED MINUTES. -PJSM ON NIPPLING DOWN TREE OPERATION. -SIM OPS: - LOAD PITS WITH 9.8 PPG BRINE, CONT. (480 BBL) -MOVE SLOP TANK TO DRILLER SIDE. - RUN HARDLINE FROM CELLAR TO SLOP TANK. - PREPARE TO NIPPLE DOWN WELLHEAD. - RELOCATE 300 BBL 9.8 PPG BRINE KWF AND TANK FROM NGI PAD. - RELOCATE BREAK TRAILER. *RIG EVACUATION DRILL: RESPONSE TIME AT 4:30. AAR. 06:00 - 09:30 3.50 BOPSUR P PRE NIPPLE DOWN TUBING HEAD AND ADAPTER FLANGE. *TEST EMERGENCY SHUT DOWN SWITCHES ON SCR'S, FIRE AND GENERATORS - TESTED GOOD. *SIM OPS PRESSURE TEST HARD LINE TO FLOW BACK TANK. ��i1 - TESTED 250 PSI AND 3500 PSI FOR 5 ,\ MINUTES -OK. i Printed 12/26/2012 9:57:02AM n a s . R ti !! Common Well Name: AGI -05 AFE No Event Type: WORKOVER (WO) Start Date: 11/26/2012 End Date: 12/12/2012 X4- 00WFH -E; (3,485,000.00 ) Project: Prudhoe Bay (various) Site: AGI Rig Name /No.: DOYON 14 Spud Date/Time: 1/18/1993 12:00:00AM Rig Release: 12/12/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 5 : 05 1/18/1993 00:00 @49.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 - 18:00 8.50 BOPSUR P PRE PJSM ON LAY DOWN TREE AND ADAPTER FLANGE. - LAYDOWN TUBING HEAD AND FLANGE AND SET OUT. -CHECK 7" NCSS TUBING HANGER CROSSOVER (MADE UP W/ 7 ROUNDS). -SET IN SPACER SPOOL AND NIPPLE UP. -SET IN BOP STACK AND NIPPLE UP. - ATTACH TURN BUCKLES AND KOOMY LINES. -INSTALL RISER AND FLOW LINE. - INSTALL BLEED OFF AND HOLE FILL LINES. - CENTER STACK W/ ROTARY TABLE. 18:00 - 21:30 3.50 BOPSUR P PRE PJSM TO CHANGE OUT RAMS. - INSTALL 3 -1/2 "x 6" VBR IN UPPER RAM zh ` CAVITY OF DOUBLE RAM. jJ - INSTALL 7" RAMS IN SINGLE RAM. * AOGCC, JEFF JONES, WAIVED WITNESS VIA PHONE OF BOPE TEST AT 08:30 PM 12 -3 -12. 21:30 - 23:00 1.50 BOPSUR P PRE RIG UP AND HYDROTEST NEW CHOKE LINE AND INJECTION LINE. -TEST TO 250 PSI LOW AND 5000 PSI HIGH -GOOD. - RIG UP AND TEST NEW INJECTION LINE. - TEST TO 250 PSI LOW AND 5000 PSI HIGH -GOOD. -RIG DOWN TEST EQUIPMENT. - BLOW DOWN INJECTION LINE. 23:00 - 00:00 1.00 BOPSUR P PRE PJSM RIG UP TO TEST BOPE WITH 4" TEST JOINT. -RIG UP BOPE TEST EQUIPMENT AND 4" TEST JOINT. *WELL KILL DRILL, RESPONSE TIME: 1 MINUTE AND 25 SECONDS. 12/4/2012 00:00 - 06:30 6.50 BOPSUR P PRE BOPE TESTING, CONT. -TEST (3) RAMS TO 250/4000 PSI FOR 5 CHARTED MINUTES. - ANNULAR TO 3500 PSI. - 3 -1/2" VBR AND ANNULAR W/ 4" TEST JOINT. -7" FIXED W/ 7" TEST JOINT. -(2) FOSV: 4 -1/2" IF AND 4" XT39 -DART VALVE: 4" XT 39 - TEST BOTH CHOKES AND ALL VALVES ON CHOKE MANIFOLD. -ALL MUD VALVES, HCR AND MANUAL VALVES. -(2) TOP DRIVE VALVES. - KOOMEY DRAWDOWN TEST. -RIG DOWN TEST EQUIPMENT. -BLOW DOWN LINES *ALL TESTS IN ACCORDANCE WITH AOGCC AND ADWOP SPECIFICATIONS. 06:30 - 08:00 1.50 WHSUR P DECOMP MOBILIZE DUTCH MAN AND LUBRICATOR TO RIG FLOOR. - VACCUM OUT BOPE STACK 08:00 - 09:30 1.50 WHSUR P DECOMP PJSM ON TESTING LUBRICATOR. - TEST 250 PSI LOW AND 3500 PSI HIGH FOR 5 MINUTES -GOOD. Printed 12/26/2012 9:57:02AM Co Well Name: AGI -05 AFE No Event Type: WORKOVER (WO) Start Date: 11/26/2012 End Date: 12/12/2012 X4- 00WFH -E; (3,485,000.00 ) Project: Prudhoe Bay (various) Site: AGI Rig Name /No.: DOYON 14 Spud Date/Time: 1/18/1993 12:00:00AM Rig Release: 12/12/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 5 : 05 1/18/1993 00:00 @49.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 - 10:30 1.00 WHSUR P DECOMP PU TWO C, 0 S ON . -RIG LL DOWN WAY AND LAY HECK DOWN P LI UBRICATO TUBINGR. -BACK OUT LOCK DOWN SCREWS ON DUTCHMAN. - REPLACE DUTCHMAN LOCK DOWN SCREW SEALS. 10:30 11:30 1.00 WHSUR P DECOMP MAKE UP LANDING JOINT. =LINE UP AND PREPARE TO PUMP FREEZE PROTECT. 11:30 - 14:00 2.50 WHSUR P DECOMP CAG RZE PROTECT ON . CIRCULATE IROC:: FREEZE E OUT PROTECT. THE F EE *2 80 PSI, 2.5 180 , 3 K FOR BPM CIRCULA AT 380 PSI. AT -SHUT BPM DOWN PUMPS AND BPM AT FLOW CHE C 10 MINS - STATIC. -BLOW DOWN ALL - LINES. -RIG DOWN LAM 14:00 - 14:30 0.50 WHSUR P DECOMP PJSM SERVICE ALL AND CIRCU INSPECT TING TOP EQUIP DRIVE BLOCKS AND DRAW WORKS. 14:30 - 00:00 9.50 FISH _ P DECOMP M A MTI - ST CUTTERPJSM, KE BHA UP #1 BAKER WITH 4" UL DRILL PIPE . - TAGGED AT 9080 FEET. *PUW =175K, SOW =150K. ( WI T RESP O KICK NSE HT IME : 57 SECONDS DRILLS , 1 MINUT E 8 SECONDS. SPILL DRILL RESPONSE TIME: 1:35 12/5/2012 00:00 - 01:00 1.00 FISH P DECOMP TAG UP AT 9080' FEET. -PO RAT AT ME A SU RED DEPTH 9 071' FEET PUMP *MUD PUMP 1, OBTAIN 20 STROKES W AT 220 PSI, 30 ES STROKES AT 470 PSI. * PUMP 2, 20 230 PSI, 30 STROKES AT 470 PSI. -PULL U 44' FEET FROM STROKES TAG AT DEPTH (9080') TO 9036 P F T. EE -BEGIN MUD CUT "INTERNAL CUA PR RE E PER IRCm IN UTE WITH H 730 ESSU PSI. *ROTATING STROKS 70 RPM WTH 3.5 -5K TORQUE. 38 "`FULL CIRCULATING PRESSURE 38 SPM WITH 470 PSI. 01:00 03:00 2.00 FISH P DECOMP 10 MINUTE FLOW CHECK - STATIC RACK BACK 1 STAND DRILL PIPE. WELL BORE OUT OF BALANCE, U- TUBING. - CIRCULATE DRILL PIPE VOLUME 30 SPM WITH 500 PSI. 03:00 07:00 4.00 FISH P DECOMP FLOW CHECK WELL, NO GAIN NO LOSS WELL STABLE, -" L PIPE I *KICK DRILL STAND RESPONSE E TIME: IN 2 MINUTES DERRCK. AND POOH 39 SECONDS. -10 MINUTE FLOW CHECK - STATIC. 07:00 - 09:30 2.50 FISH P DECOMP PJSM LAY DOWN BHA #1 MOBILIZE BHA #2 TO THE RIG FLOOR. - MOBILIZE SLB SPOOLING UNIT TO RIG FLOOR. - MOBILIZE TUBULAR HANDLING EQUIPMENT TO RIG FLOOR. Printed 12/26/2012 9:57:02AM %b Common Well Name: AGI -05 AFE No Event Type: WORKOVER (WO) Start Date: 11/26/2012 End Date: 12/12/2012 X4- 00WFH -E; (3,485,000.00 ) Project: Prudhoe Bay (various) Site: AGI Rig Name /No.: DOYON 14 Spud Date/Time: 1/18/1993 12:00:00AM Rig Release: 12/12/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 5 : 05 1/18/1993 00:00 @49.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 - 10:30 1.00 FISH P DECOMP PJSM ON MAKING UP BHA # 2. - VACUUM OUT BOPE STACK. - ENGAGE SPEAR TO 7" NSCC CASING. 10:30 - 11:30 1.00 FISH P DECOMP PULL HANGER TO THE HANGER TO THE RIG FLOOR. *BROKE FREE AT 225K. 11:30 - 12:00 0.50 FISH P DECOMP PJSM ON CIRCULATING THROUGH THE CHOKE. -SHUT IN ANNULAR. -CIRCULATE ANNULAR VOLUME 50 SPM WITH 202 PSI. *LOSSES FOR TOUR 5.5. BBLS. 12:00 - 13:30 1.50 FISH P DECOMP PJSM ON CIRCULATING BOTTOMS UP ONE TIME. *GPM =220 PSI ICP, 210 GPM =200 FCP. PUW =225K, SOW =205K. - DISENGAGE SPEAR AND INSTALL FLOOR VALVE. -SHUT IN AND LINE UP TO MONITOR THE WELL THROUGH TRIP TANK. 13:30 14:30 1.00 CASING P DECOMP PJSM ASSEMBLE SUPER TONGS. -TERMINATE CONTROL LINES. 14:30 - 15:30 1.00 CASING P DECOMP LAY DOWN CIRCULATING JOINT AND TUBING HANGER. - MAKE SAFETY JOINT WITH 4" FOSV ON TOP AND 4" XT39 x 4 -1/2" IF CROSSOVER ON BOTTOM. - MAKE UP 4 -1/2" FOSV WITH 4 -1/2" IF x 7" NSCC. 15:30 - 18:00 2.50 CASING P DECOMP BP AUDIT SHUT DOWN. - INSPECT DERRICK. 18:00 - 21:30 3.50 CASING ` P DECOMP LAY DOWN 7" 26 # NT80, IPC, NSCC TUBING SINGLES. -FROM HANGER TO 2227 FEET. *(55) JOINTS RECOVERED SO FAR. *(27) SS BANDS RECOVERED. 21:30 - 22:30 1.00 CASING P DECOMP PJSM RIG DOWN AND LAY DOWN SLB CONTROL LINE SPOOL FROM RIG FLOOR. 22:30 - 23:00 0.50 CASING P DECOMP RIG SERVICE TOP DRIVE, DRAW WORKS, IRON ROUGHNECK. - INSPECT BRAKE BANDS, DRILL LINE AND DEAD MAN. 23:00 - 00:00 1.00 CASING P DECOMP LAY DOWN 7" 26# NT80, ICP, NSCC TUBING, LAYING DOWN SINGLES. *FROM 2227 FEET TO 3075 FEET. 12/6/2012 00:00 - 00:30 0.50 CASING P DECOMP INSPECT BRAKES, DRILLING LINE, DEAD MAN ANCHOR AND BOPE. - GREASE DRAW WORKS. *75 PSI ON OA AT 00:30. 00:30 - 07:30 7.00 CASING P DECOMP PULL OUT THE HOLE WITH 7" NCSS TUBING LAYING DOWN, FROM 3075 FEET TO 7230 FEET. *(228) JOINTS TOTAL LAID DOWN, PLUS (1) 15.4 FOOT CUT JOINT. Printed 12/26/2012 9:57:02AM e e o Common Well Name: AGI -05 AFE No Event Type: WORKOVER (WO) Start Date: 11/26/2012 End Date: 12/12/2012 X4- 00WFH -E; (3,485,000.00 ) Project: Prudhoe Bay (various) Site: AGI Rig Name /No.: DOYON 14 Spud Date/Time: 1/18/1993 12:00:00AM Rig Release: 12/12/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 5 : 05 1/18/1993 00:00 @49.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:30 - 09:30 2.00 CASING P DECOMP 10 MINUTE FLOW CHECK - STATIC. - RIG DOWN UHT SUPER TONGS. -LAY DOWN NSCC CROSSOVER TO 4" FOSV. - MOBILIZE TOOLS TO RIG FLOOR FOR UPCOMING BHA. - PICK UP 7" SPEAR ASSEMBLY AND SERVICE BREAK THE CONNECTIONS. 09:30 - 12:00 2.50 FISH P DECOMP " PJSM ON MAKING UP BHA #3. - INSTALL WEAR RING (ID 8.875). -MAKE UP BHA #3. 12:00 - 12:30 0.50 FISH P DECOMP INSPECT BRAKES, DRILLING LINE, DEAD MAN ANCHOR AND BOPE. -GREASE DRAW WORKS. 12:30 - 13:00 0.50 FISH P DECOMP PJSM ON MAKING UP BHA #3. - RIG UP BAKER TONGS. "FIRE DRILL RESPONSE TIME 2 MINUTES AND 15 SECONDS. 13:00 - 16:00 3.00 FISH P DECOMP MAKE UP BHA #3, CONT. - CHANGE OUT ELEVATORS TO 5 ". 16:00 - 19:00 3.00 FISH P DECOMP PJSM TO CHANGE OUT ELEVATORS TO 4". -RUN IN THE HOLE ON 4" DRILL PIPE. *71 STANDS AT 7043 FEET. 19:00 - 20:00 1.00 FISH P DECOMP PJSM MAKE UP HES RTTS. -CIRCULATE 3 BBLS MINUTE AT 720 PSI. *SLOW PUMP RATES. *MP #1 20 SPM AT 360 PSI, 30 SPM AT 720 PSI. *MP #2 20 SPM AT 350 PSI, 30 SPM AT 710 PSI. 20:00 - 21:30 1.50 FISH P DECOMP SET RTTS AT 102 FEET. - OBTAIN PARAMETERS. *PUW =167K, SOW =135K. - RIG UP TO TEST, 2000 PSI FOR 5 MINUTES- TESTED GOOD. "WAIT ON TOWN FOR OK TO CONTINUE. 21:30 - 22:00 0.50 FISH P DECOMP BLOW DOWN CHOKE. - VACUUM OUT STACK TO PULL WEAR RING. 22:00 - 23:00 1.00 FISH P DECOMP MAKE UP PACK -OFF RUNNING TOOL. -LAY DOWN OLD PACK -OFF AND INSTALL NEW ONE. *FMC TEST VOID AT 5000 PSI FOR 30 MINUTES. -LAY DOWN PACK -OFF RUNNING TOOL. 23:00 - 00:00 1.00 FISH P DECOMP LAY DOWN PACKOFF RUNNING TOOL -MAKE UP 7.625" TEST JOINT WITH UPPER TEST PLUG. 12/7/2012 00:00 - 00:30 0.50 BOPSUR P DECOMP RUN IN THE HOLE WITH 7.625" TEST JOINT AND UPPER PLUG. 00:30 - 03:00 2.50 BOPSUR P DECOMP PJSM ON CHANGING OUT BOTTOM RAMS FROM 7" SOLID TO 7.625 SOLID. -RIG UP TEST EQUIPMENT AND TEST 250 PSI LOW AND 4000 PSI HIGH FOR 5 MINUTES. *(2) SS BANDS RECOVERED IN RAM CAVITY. 03:00 - 03:30 0.50 BOPSUR P DECOMP RIG DOWN TEST EQUIPMENT. - LAY DOWN TEST JOINT AND PLUG. - INSTALL WEAR BUSHING (ID 8.875). Printed 12/26/2012 9:57:02AM d Common Well Name: AGI -05 AFE No Event Type: WORKOVER (WO) Start Date: 11/26/2012 End Date: 12/12/2012 X4- 00WFH -E; (3,485,000.00 ) Project: Prudhoe Bay (various) Site: AGI Rig Name /No.: DOYON 14 Spud Date/Time: 1/18/1993 12:00:00AM Rig Release: 12/12/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 5 : 05 1/18/1993 00:00 @49.20ft (above Mean Sea Level) Date From - To H rs Task Code NPT NPT Depth Phase Description of Operations (hr) 03:30 (ft) 06:00 2.50 FISH P DECOMP ON REI, D CHECK K FOR U 0 -PICK UP RE 167K TPSI. DISENGAGE R S. 0 O TT P BELOW. PRESS PUMP 30 BBLS THROUGH AN O PEN CHOKE. -NO GAS SU. -10 MINUTE FL SEEN OW AT C RFACE -GO. -BLOW DOWN CHOKE, TOP DRIVE AND DRAIN GAS BUSTER. 06:00 - 06:30 0.50 FISH P DECOMP , PULL OUT OF THE LE AND LAY DOWN FEET RTTS. 06:30 - 08:30 2.00 FISH P 073 DECOMP RUN IN THE HOLE FROM HO 7' TO 8974 WITH MULTI TASK BHA #3. - OBTAIN PARAMETERS. `SOW =152, PUW =203. "OBTAIN SLOW PUMP RATES AT 8974' MD. 08:30 - 09:30 1.00 FISH P DECOMP RUN IN TH1 HOLE, M C P O TO 9100' MD. RECIPROCATE SCRAPER 5 TIMES. -TAG UP JUNK CATCHER AT 9101' MD. -SET 5K DOWN TWI -PUMP 5 BPM AT 11 C O E. PSI, PICK UP 4K OVER PULL. 09:30 - 11:30 2.00 FISH P DECOMP STAND ONE STAND DRILL PIPE BACK. -DROP BALL AND ROD. 'SHEER AT 1500 PSI. - CIRCULATE SWEEP, MONITOR WELL FOR 10 MINUTES- STATIC. -BLOW DOWN TOP SINGLE DRIVE. 11:30 - 12:00 0.50 FISH N RREP 9,100.00 DECOMP LAY DOWN SUPER TONGS. OF 12:00 - 21:00 9.00 FISH P DECOMP PJSM LAY DOWN S :L PIO PIPE SHED. *KICK WHILE TRIPPING DRILL RESPONSE T TIME: 1 MINUTE AND 15 SECONDS. 21:00 - 23:30 2.50 FISH P DECOMP CC L DOWN BA - MONITOR WELL FO 10 MINUTES-STATIC. 23:30 - 00:00 0.50 FISH P DECOMP AD CLEAR RIG FLOOR FROM UNNEEDED PJSM AY TOOLS AND EQUIPMENT. 12/8/2012 00:00 - 01:00 1.00 FISH P DECOMP CLEAN N AN AND CLEAR RIG FLOOR. CONT. 01:00 - 01:30 0.50 BOPSUR P RUNCMP MAKE OPS STK WASG OO RUN INU UP PT E HOLE WITH 3 STANDS HINT OF L 4" XT -39 DRILL PIPE. 01:30 03:00 1.50 RUNCOM P RUNCMP SM SLIP AND CUT AC DRILLING LINE. SERVICE TOP DRIVE AND BLOCKS. - PJ INSTALL FOSV. HANG BLOCKS. CUT 59.5 FEET OF. DRILLING LINE. -UN HANG BLOCKS, PULL FOSV. 03:00 - 03:30 0.50 RUNCOM P RUNCMP PULL OUT OF THE HOLE LAYING DOWN DRILL PIPE SINGLES THROUGH PIPE SHED. PULL WEAR RING. MOBILIZE CASING TOOLS FOR 7 INCH AND 7 03:30 - 05:00 1.50 RUNCOM P RUNCMP 5/8 INCH CASING HANDLING SLIPS AND ELEVATORS. 05:00 - 07:30 2.50 RUNCOM P RUNCMP RIG UP TO MAKE DUMMY RUN WITH HANGER ASSEMBLEY. -MAKE UP CROSSOVER FOR SAFTEY JOINT. Printed 12/26/2012 9:57:02AM • # sr Common Well Name: AGI -05 AFE No Event Type: WORKOVER (WO) Start Date: 11/26/2012 End Date: 12/12/2012 X4- 00WFH -E; (3,485,000.00 ) Project: Prudhoe Bay (various) Site: AGI Rig Name /No.: DOYON 14 Spud Date/Time: 1/18/1993 12:00:00AM Rig Release: 12/12/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 5 : 05 1/18/1993 00:00 @49.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:30 - 08:00 0.50 RUNCOM P RUNCMP PJSM WITH HALLIBURTON AND CREW ON RUNNING COMPLETION ASSEMBLY. 08:00 - 09:30 1.50 RUNCOM P RUNCMP RUN 5 -1/2" 26# TC11 L -80 MULE SHOE -RN NIPPLE WITH RHC-M PLUG, 9 -5/8 "x 7" HES TNT PACKER, 7" R NIPPLE 09:30 - 10:00 0.50 RUNCOM P RUNCMP CHANGE OUT 7" CROSSOVER SAFTEY VALVE WITH 7 -5/8" CROSSOVER. -INSTALL STRIPPING RUBBER IN THE HOLE AFTER THE PACKER. 10:00 - 12:00 2.00 RUNCOM P RUNCMP RUN IN THE HOLE, CONT. WITH 7 -5/8" L -80 VAM TOP HC TUBING FROM 184' TO 1300' 12:00 - 12:30 0.50 RUNCOM P RUNCMP RIG SERVICE, GREASE DRAW WORKS. - INSPECT! TOP DRIVE, CHECK BRAKES, DRILLING LINE, DEAD MAN ANCHOR AND BOPE. 12:30 - 18:30 6.00 RUNCOM P RUNCMP RUN IN THE HOLE, CONT. WITH 7 -5/8" 29.7 # L -80 VAM TOP HC TUBING FROM 1300' TO 5136'. 18:30 - 19:30 1.00 RUNCOM P RUNCMP LOAD PIPE SHED WITH THE REMAINDER OF CASING (93 JOINTS). 19:30 - 00:00 4.50 RUNCOM P RUNCMP RUN IN THE HOLE, CONT. WITH 7 -5/8" 29.7 # L -80 VAM TOP HC TUBING FROM 5136' TO :8620'. 12/9/2012 00:00 - 01:30 1.50 RUNCOM P RUNCMP RUN IN THE HOLE WITH 7 -5/8" L -80 VAM TOP HC TUBING FROM 8260' TO 9083' 01:30 - 02:00 0.50 RUNCOM P RUNCMP PULL OUT OF THE HOLE TO 9009' FEET. -LAY DOWN 3 JOINTS 02:00 - 03:00 1.00 RUNCOM P RUNCMP PICK UP 9.92' AND 19.92' PUP JOINTS. MAKE UP HANGER PICK UP WEIGHT 295K, SLACK OFF WEIGHT 215K. 03:00 - 04:00 1.00 RUNCOM P RUNCMP LAND HANGER AND RUN IN AND TORQUE LOCK DOWN SCREWS. 04:00 - 05:00 1.00 RUNCOM P RUNCMP PJSM WITH ALL HANDS TO REVERSE CIRCULATE THROUGH IA TO PITS. 05:00 - 08:00 3.00 RUNCOM P RUNCMP CIRCULATE DOWN IA AT 3 BPM AT 500 PSI. 08:00 - 08:30 0.50 RUNCOM P RUNCMP RIG UP TO PUMP DOWN TUBING, TO TAKE RETURNS TO THE PITS. 08:30 - 09:00 0.50 RUNCOM P RUNCMP PUMP 5 BBLS DOWN TUBING TO CLEAN SURFACE SEAT FOR BALL AND ROD. *350 PSI AT 3 BPM. 09:00 - 10:00 1.00 RUNCOM P RUNCMP RIG UP LITTLE RED HOT OIL SERVICES TO PUMP DOWN IA. -TEST LINE 250 PSI LOW AND 2000 PSI HIGH 5 MINUTES -GOOD. 10:00 - 10:30 0.50 RUNCOM P RUNCMP LITTLE RED PUMP 2 BPM AT 350 PSI. _ *40 BBLS OF DIESEL PUMPED. 10:30 - 11:30 1.00 RUNCOM P RUNCMP LET IA AND TUBING U -TUBE FOR 1 HOUR. 11:30 - 12:00 0.50 RUNCOM P RUNCMP BREAK OFF PUMP IN SUB AND DROP BALL AND ROD. Printed 12/26/2012 9:57:02AM • e ! ., Common Well Name: AGI -05 AFE No Event Type: WORKOVER (WO) Start Date: 11/26/2012 End Date: 12/12/2012 X4 -OOWFH E; (3,485,000.00 ) Project: Prudhoe Bay (various) Site: AGI Rig Name /No.: DOYON 14 Spud Date/Time: 1/18/1993 12:00:00AM Rig Release: 12/12/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 5 : 05 1/18/1993 00:00 ©49.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 15:00 3.00 RUNCOM N DFAL 9,009.00 RUNCMP ATTEMPT TO R CASING. RECEIVING RETURNSPRESSUE UP . :PI PUMP 3 BPM WITH - 340 ON PSI UMP 3 - 6 BPM WITH 300 - 500 UMP 7 BBLS OF DIESEL 300 DOWN PSI AND IAS ALLOW TO U -TUBE. -PUMP DOWN I WITH 300 - 500 TUB PSI, RECEIVING NG AGAIN AT RETURNS BPM AGAIN. BACK OUT LOCK DOWN SCREWS, PICK UP ON CASING STRING AND SHAKE IT LIGHTLY. RUN IN LOCK DOWN SCREWS, ATTEMPT TO PUMP DOWN CASING TO SET BALL - RECEIVING RETURNS. PUMP A TOTAL OF 1813 BLS DOWN THE TUBING. 15:00 - 17:00 2.00 RUNCOM N DFAL 9,009.00 RUNCMP PJSM RIG DOWN CIRCULATING EQUIPMENT AND INSTALL DUTCH RISER SYSTEM. CLEAR CASING EQUIPMENT FROM RIG FLOOR. RIG DOWN DUTCH RISER SYSTEM. SPOT SLB WIRE LINE TRUCK. 17:00 - 00:00 7.00 RUNCOM N DFAL 9,009.00 RUNCMP PJSM RIG UP WIRE LINE TOOLS. RUN IN THE HOLE AT 18:50. -LATCH UP BALL AND ROD. -PULL ROD AT OUT 19:50. OF THE HOLE - REMOVE SLICK LINE OVERSHOT WITH WITH BALL AND BALL AND ROD. HCN PLUG PULLER. RUN IN HOLE -MAKE AT UP 21:10 R *TABLE TOP STRIPPING DRILL, MAN DOWN DRILL AND H2S HELD. PULL OUT OF THE DRILL HOLE WITH RCHN PLUG TO SURFACE AT 22:40 -RIG DOWN RCHN -MAKE UP RNR PLUG, RUN PLUG IN AND THE PULLER. AT HOLE 23:45 12/10/2012 00:00 02:00 2.00 RUNCOM N DFAL 9,009.00 RUNCMP RUN IN THE HOLE WITH RN PLUG ON SLB WIRELINE. -SET RN PLUG. -PULL OUT OF HOLE WITH SLICK LINE. 02:00 - 02:30 0.50 RUNCOM N DFAL 9,009.00 RUNCMP REMOVE RN RUNNING OK. TOOL. INSPECT TOOL FOR DAMAGE LOST PIECES -TO 02:30 04:00 1.50 RUNCOM N DFAL 9,009.00 RUNCMP RUN IN HOLE WITH PRN PRONG. SET PRONG. 04:00 05:00 1.00 RUNCOM N DFAL 9,009.00 RUNCMP PULL OUT OF HOLE WITH RUNNING TOOL. 05:00 06:30 1.50 RUNCOM N DFAL 9,009.00 RUNCMP RIG UP TO ATTEMPT TO SET THE PACKER. GETTING RETURNS BPM ITH BACK TO SURFACE. - PUMP AT 1.5 BPM WITH 340 PSI. - PUMP AT 3 W 440 PSI. - FULL RETURNS TO SURFACE. - PUMPED A TOTAL OF 12 BBLS. -LOWER BEAVER PNR SLIDE PRONG RUNNING TOOL DOWN . -SLB SLICKLINE REDRESS RUNNING TOOL. 06:30 - 07:00 0.50 RUNCOM N DFAL 9,009.00 RUNCMP PICK UP SLICK LINE RUNNING TOOLS FROM BEAVER SLIDE. Printed 12/26/2012 9:57:02AM i _e - - zz' Common Well Name: AGI -05 AFE No Event Type: WORKOVER (WO) Start Date: 11/26/2012 End Date: 12/12/2012 X4 -OOWFH E; (3,485,000.00 ) Project: Prudhoe Bay (various) Site: AGI Rig Name /No.: DOYON 14 Spud Date/Time: 1/18/1993 12:00:00AM Rig Release: 12/12/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 5 : 05 1/18/1993 00:00 @49.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:00 - 08:00 1.00 RUNCOM N DFAL 9,009.00 RUNCMP RUN IN THE HOLE WITH PRN PRONG PULLING TOOL. -PULL PLUG 08:00 - 09:00 1.00 RUNCOM N DFAL 9,009.00 RUNCMP PULL OUT OF THE HOLE WITH PRN PLUG. 09:00 - 10:00 1.00 RUNCOM N DFAL 9,009.00 RUNCMP LAY DOWN PRN PLUG DOWN BEAVER SLIDE. RUN IN THE HOLE WITH 7" HW GS TO PULL PLUG. 10:00 - 11:00 1.00 RUNCOM N DFAL 9,009.00 RUNCMP PULL OUT OF THE HOLE WITH 7" HW. GS. -LAY PLUG DOWN BEAVER SLIDE. 11:00 - 12:00 1.00 RUNCOM N DFAL 9,009.00 RUNCMP PICK UP LANDING JOINT. -SCREW INTO TC11 LANDING JOINT. -BLOW DOWN THE CHOKE AND KILL LINES. 12:00 - 16:30 4.50 RUNCOM N DFAL 9,009.00 RUNCMP SPOT LITTLE RED SERVICES. LINE UP TO PUMP DOWN THE TUBING 3 BPM AT 370 PSI. -PJSM WITH LITTLE RED TO PRESSURE TEST LINES TO 2000 PSI. -PUMP 2 BPM AT 500 PSI FCP DOWN THE IA TAKING RETURNS OUT THE TUBING. *FIRE DRILL RESPONSE TIME: 1 MINUTES AND 33 SECONDS. *TABLE TOP EVACUATION DRILL. 16:30 - 22:00 5.50 RUNCOM N DFAL 9,009.00 RUNCMP PJSM RIG UP SLICK LINE TOOLS. -RUN IN THE HOLE WITH PRN PLUG. -SET PLUG, PULL UT OF THE HOLE WITH RUNNING TOOL. -LAY DOWN RUNNING TOOL. -RUN IN THE HOLE WITH PRN PRONG. - PULL OUT OF THE HOLE WITH SLICK LINE. 22:00 - 23:00 1.00 RUNCOM N DFAL 9,009.00 RUNCMP PJSM TEST PACKER/PLUG. CAUGHT PRESSURE 20 STROKES PUMPED, 61 STROKES PRESSURE AT 500 PSI. - CLOSED HCR KILL, PRESSURE ON THE WELL, BLED OFF PUMP. PRESSURE HELD. -OPEN HCR KILL, PUMP 24 MORE STROKES - PRESSURE INCREASE TO 500 PSI. - CLOSED HCR KILL LINE, PRESSURE BLED OFF. PUMP PRESSURE HELD. - BLOW DOWN CHOKE LINE AND KILL LINE. 23:00 - 00:00 1.00 RUNCOM N DFAL 9,009.00 RUNCMP PJSM RIG UP TO RUN BELL GUIDE WITH PULLING TOOL IN IT. 12/11/2012 00:00 - 00:30 0.50 RUNCOM N DFAL 9,009.00 RUNCMP PULL OUT OF THE HOLE WITH PRN PLUG. 00:30 - 01:30 1.00 RUNCOM N DFAL 9,009.00 RUNCMP RUN IN THE HOLE WITH PLUG RETRIEVAL TOOL TO PULL SEAL ASSEMBLY. 01:30 - 02:00 0.50 RUNCOM N DFAL 9,009.00 RUNCMP PULL OUT OF THE HOLE WITH SEAL ASSEMBLY. 02:00 - 02:30 0.50 RUNCOM N DFAL 9,009.00 RUNCMP LAY DOWN SEAL ASSMEBLY. - PICK UP BAKER PACKER WITH HALLIBURTON TOOLS LOADED IN IT. 02:30 - 06:00 3.50 RUNCOM N DFAL 9,009.00 RUNCMP RUN IN THE HOLE WITH BAKER PACKER ASSEMBLY. GET ON DEPTH TO SET RBP BY TAGGING CROSS OVER. SET RBP @ 9049'. THE PURPOSE OF THE PACKER IS TO GIVE ANOTHER OPTION TO SET THE CASING PACKER. 06:00 - 07:30 1.50 RUNCOM N DFAL 9,049.00 RUNCMP PULL OUT OF THE HOLE. - SERVICE BREAK BAKER RUNNING TOOL. 07:30 - 08:00 0.50 RUNCOM N DFAL 9,049.00 RUNCMP LAY DOWN RUNNING TOOLS. Printed 12/26/2012 9:57:02AM Common Well Name: AGI -05 AFE No Event Type: WORKOVER (WO) Start Date: 11/26/2012 End Date: 12/12/2012 X4- 00WFH -E; (3,485,000.00 ) Project: Prudhoe Bay (various) Site: AGI Rig Name /No.: DOYON 14 Spud Date/Time: 1/18/1993 12:00:00AM Rig Release: 12/12/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 5 : 05 1/18/1993 00:00 @49.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:00 - 09:00 1.00 RUNCOM N DFAL 9,049.00 RUNCMP RIG UP AND PUMP DOWN TUBING AND TAKE RETURNS THROUGH IA. 09:00 - 11:00 2.00 RUNCOM N DFAL 9,049.00 RUNCMP PRESSURE UP TUBING TO 500 PSI FOR 5 MINS -GOOD. - PRESSURE UP TUBING TO 4000 PSI FOR 30 MINUTES -GOOD - TOOK 5.6 BBLS TO PRESSURE, BLED BACK 5.0 BBLS -BLEED OFF TUBING TO 1500 PSI. -RIG UP ON5 IA AND PRESSURE UP TO 500 LOW FOR 5 MINUTES AND 4000 PSI FOR 30 MINUTES -GOOD. -BLEED OFF IA, CHECK TUBING PRESSURE -GOOD. -TOOK BACK 4 .1 BBLS BILLS TO PRESSURE UP, BLED 11:00 - 11:30 0.50 RUNCOM N DFAL 9,049.00 RUNCMP BLOW DOWN CHOKE AND KILL LINE. 11:30 - 14:00 2.50 RUNCOM N DFAL 9,049.00 RUNCMP PJSM WITH SLB WIRELINE CREW. RUN IN THE'HOLE WITH BAKER RETRIEVAL TOOL. JAR ON PACKER. 14:00 - 15:00 1.00 RUNCOM N DFAL 9,049.00 RUNCMP RIG UP TO TEST PACKER. PRESSURE UPON THE TUBING TO 1500 PSI, TOOK - LINE UP 2.3 ON BBLS THE TO IA AND PRESSURE PRESSURE UP TO 4000 PSI, TOOK 4.3 BBLS TO PRESSURE UP. - HELD FOR 30 MINUTES-GOOD. -BLEED PRESSURE OFF OF IA TO TRIP TANK #3. *3.5 BBLS OF RETURNS AFTER PRESSURE BLED OFF. -BLEED P O "2 BBLS MORE OF E OE URNS OF T BING R PRESSURE BLED OFF. WTL AUTHORIZATION TO PROCEED JAMES WILLINGUHAM 15:00 - 17:00 2.00 RUNCOM N DFAL 9,049.00 RUNCMP PJSM RIG DOWN AND LAY DOWN ALL SLB WIRELINE TOOLS. -BLOW DOWN THE CHOKE AND KILL LINES. 17:00 - 21:00 4.00 BOPSUR P RUNCMP PJSM RIG UP DUTCH SYSTEM. - PICKUP LUBRICATOR AND TEST 250 PSI LOW AND 4000 PSI HIGH FOR 5 MINUTES -GOOD. -SET 40 TWO 0 P WAY HIGH FOR ECK. 5 MINUTEST FS -GOODAB E . -BLEED LUBRIC OFF TO PRESSURE AND RIG DOWN AR AND DUTCH SYSTEM. SUCK OUT OF STACK WITH RIG VACUUM CLEAN OUT BOP STACK FOR NIPPLE DOWN AND RANC M SWAPOUT. *SPILL DRILL HELD, RESPONSE TIME: 2 MINUTES AND 15 SECONDS. 21:00 23:30 2.50 BOPSUR P RUNCMP PJSM O A WIF -O ALLOW FILL TO ST SOAK FOR TH 45 SAFE - SUR MINUTES. PICK UP AND REMOVE CROSSOVERS PILL. FROM LANDING JOINT. MAKE UP STACK WASHER AND (1) JOINT OF 4 DRIL PIPE. - 30 RPM, 15 BPM AT 130 PSI. -BLOW DOWN TOP DRIVE. Printed 12/26/2012 9:57:02AM Common Well Name: AGI -05 AFE No Event Type: WORKOVER (WO) Start Date: 11/26/2012 End Date: 12/12/2012 X4- 00WFH -E; (3,485,000.00 ) Project: Prudhoe Bay (various) Site: AGI Rig Name /No.: DOYON 14 Spud Date/Time: 1/18/1993 12:00:00AM Rig Release: 12/12/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 5 : 05 1/18/1993 00:00 @49.20ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 23:30 - 00:00 0.50 BOPSUR P RUNCMP PJSM FOR CHANGING OUT BOTTOM RAMS FROM 7 -5/8" SOLIDS TO 2 -7/8" X 5" VBR'S. - VACUUM OUT STACK, REMOVE TURNBUCKLES, CLEAN DRIP PAN. 12/12/2012 00:00 - 02:00 2.00 BOPSUR P RUNCMP PJSM- CHANGE OUT LOWER RAMS FROM 7 5/8" SOLIDS TO 2 7/8" X 5" VARIABLE BORE RAMS 02:00 - 03:30 1.50 BOPSUR P RUNCMP PJSM- NIPPLE DOWN BOP STACK 03:30 - 06:30 3.00 WHSUR P RUNCMP PJSM -PICK UP ADAPTER FLANGE AND N/U SAME. 1 _ -TEST HANGER VOID TO 5000 PSI HI FOR 30 `fy� MINUTES ON ELECTRONIC GAUGE (FMC) - SIMOPS -PULL #2 CONVEYOR IN FOR RIG MOVE 06:30 - 09:30 3.00 WHSUR P RUNCMP NIPPLE UP TREE -TEST TREE WITH DIESEL TO 250 PSI LOW /5000 PSI HI FOR 5 MINUTES EACH CHARTED 09:30 - 13:00 3.50 RIGD P RUNCMP RIG DOWN MUD LINES TO RIG FLOOR IN PREPARATION TO SKID RIG FLOOR -TIE UP LINES ON STACK, REMOVE KOOMEY LINES FROM KILL HCR VALVE 13:00 - 17:00 4.00 WHSUR P RUNCMP RIG UP BACK PRESSURE LUBRICATOR AND TEST TO 250 PSI LOW /3500 PSI HI FOR 5 1, , MINUTES (CHARTED) 1 W \ -PULL TWO WAY CHECK - INSTALL BACK PRESSURE VALVE -RIG DOWN BACK PRESSURE LUBRICATOR 17:00 - 18:00 1.00 WHSUR P RUNCMP SECURE WELL - REMOVE PUMP IN FLANGE AND DOUBLE VALVES OFF OF IA AND OA - INSTALL FLANGES AND GAUGES ON IA AND OA -FINAL PRESSURES ON TUBING/IA/OA 0/0/0 ** *RELEASE RIG FROM AGI-05 @ 18:00 12/12/2012 * ** ** *SWITCH TO 11 -01 REPORT AT 1800 12/12/2012 * ** Printed 12/26/2012 9:57:02AM • • • AGI -05, Well History (Post Rig Work) Date Summary - Barriers= 12/12/12 T /I /O- 0 /0 /0. Conducted PJSM. Barriers- TWC & MV.Start barrier list. Night cap was removed prior to arrival, rigged up Cameron Lubricator onto well with pulling tool. PT'd 300 low & 3500 high for 5 min. each (Passed). Opened barriers; Pulled 6" CIW "J" TWC #423 thru tree, tagged @ 125"; S/I Barriers. Rigged off well. Rigged up setting tool with 6" CIW BPV (#401) to lubricator. Stabbed onto well, PT'd lubricator to 300 low & 3500 high 5 min. each (Passed). Set BPV @ 125 ", set good. Bled tree to 0 psi, rigged off well. 12/30/12 T /I /O =0/0/0 Conducted PJSM. Barriers = Master (with WSL approval) & SSV. Start barriers list. With WSL on location, PT'd 500 psi. against top side of SSV & Master 5 min..pass. Removed tree cap, attached lubricator, PT'd 250 /Iow..3500 /high..5 min. each..pass. PULLED 6" CIW "J" BPV #401 thru tree using 0 ext. Tagged @ 125" Shut barriers, removed lubricator, re- installed tree cap, PT'd 500 psi. /5 min. pass. Job complete, Post Doyon 14. 01/02/13 RUN 3.5" x 10' PUMP BAILER (mule shoe ball btm), SD @ 9090' SLM, WORK BAILER TO 9104' SLM (empty). RUN 4.41" CENT, 4.0" LIB, SD @ 9103' SLM, LOOKS LIKE WELL TRASH ON BTM OF LIB MAKE MULTIPLE RUNS 3.5" x 10' PUMP BAILER (mule shoe ball btm), SD AT 9101' SLM ABLE TO WORK TO 9103' SLM (- 4- 1 /2gal total sluggits recovered). 01/03/13 BAIL 2.5 GAL OF SLUGGETS FROM 9106' SLM. PULL P -PRONG FROM 5 -1/2" PXN PLUG BODY @ 9127' MD. BAIL FROM 9106' SLM TO 9110' SLM. 01/27/13 BAILED 1 -GAL OF MUD FROM 9103' SLM. RAN 5 -1/2" GR TO PXN PLUG BODY. UNABLE TO LATCH. RAN 4.51 G -RING TO 9106' SLM. 01/28/13 RAN BAILER TO PXN -PLUG BODY. CAME BACK WITH EMPTY BAILER. RAN GR UNABLE TO LATCH UP. RAN LIB TO PXN -PLUG BODY. CAME BACK WITH NO MARKS. 01/29/13 RECOVERED -2" PIECE AND -3" PIECE OF PKR RUBBER W/ 3" SAMPLE BAILER RUNS (2) @ 9107' SLM. MADE ONE ATTEMPT TO LATCH 5 -1/2" PXN @ 9107' SLM. RECOVERED -2" OF CONTROL LINE BAND W/ BUCKLE FROM 3" PUMP BAILER AT 9107' SLM. RAN 4" WIRE GRAB TO 9107' SLM AND CAME BACK WITH NOTHING. RIH W/ 2.25" PUMP BAILER. 01/30/13 MADE SEVERAL ATTEMPTS TO RECOVER WELL TRASH OFF OF 5 -1/2" PXN @ 9127' MD. RAN 2 PUMP BAILERS, 2 HYDROSTATIC BAILERS, WIRE GRAB AND A SPEAR. 01/31/13 TAGGED TOP OF 5 -1/2" LOCK AT 9107' SLM W/ 4.50" LIB; PICTURE OF G- FISHING NECK AND JUNK. RECOVER A NICKEL SIZE PIECE OF METAL FROM 9107' SLM WITH 2.69" MAGNET. RECOVER A 3" x 1" x .60" PIECE OF RUBBER WITH A 3.0" SAMPLE BAILER. 02/15/13 CTU #3 - 1.75" Coil. Job Objective : Venturi junk and Fish Plug. Preparing BOPs and Rig Up Unit. 02/16/13 CTU #3 - 1.75" Coil. Job Objective : Venturi junk and Fish Plug. Perform weekly BOP test. Issues with Double Barrier test and SSV when stabbing on well. Decision to rig down and let valve crew changeout SSV. RDMO. 02/18/13 T /I /0= 40/0/0 Conducted PJSM. Barriers = Master (w/ WSL approval) & SSV. Start barriers list. Wtih WSL on location, Performed LTI test on Master & SSV (independently)..Pass. Removed tree cap, Attached lubricator, PT'd against top of SSV & Master 250 /Iow..3500 /high..5 min. each..Pass. SET 6" CIW "J" BPV #403 THRU TREE using 1 -2' ext. Tagged @ 109" Performed LTI test on BPV..PASS. Shut barriers, R/D lubricator. Job complete. Page 1 of 2 • • AGI -05, Well History (Post Rig Work) Date Summary 03/01/13 T /I /O= 0 /0 /0. Conducted PJSM. Barriers = BPV & MV. Varrified by performing independant LTI (both Passed). Removed 6" Baker actuator & packing cartrige from bonnet. Replaced all soft goods, re installed cartrige & Baker actuator. Attempted to cycle SSV, actuator will not dump (close). WSL notified, RDMO. 03/02/13 T /I /0= 0/0/0; Conduct PJSM; Start Barriers list= SSV and MV per WSL verified by independently bleeding tubing pressure downstream of barriers. LTT passed; Rig up lubricator with pulling tool and test to 300 and 3500 psi for 5 min. LTT passed; Open barrier and pull 6 -3/8" CIW "J" BPV #403 through tree post rig work, 1 -2' ext used, tagged at 102 "; S/I barriers and RDMO; Install tree cap with new 0 -ring. 03/03/13 CTU #9 1.75" Coil Job Objective: Venturi Junk off plug / Pull Plug. Stand -by for WS to Hang P -sub and 7.06" BOPE. 03/04/13 CTU #9 1.75" Coil Job Objective: Venturi Junk off plug / Pull Plug. Rigged up, BOPE test to 4000 #, Good BOPE test. RIH w/ venturi basket, flag coil @ 9081'.Recovered some small chunks. RIH w /GS spear, sit down at 9015 ", pump meth, couldn't pass. POOH. No indication why we were not getting to plug. Pick up smaller Venturi. 03/05/13 CTU #9 1.75" coil Job Objective: Venturi Trash / Pull PXN Plug. Ran 3.125" Venturi w/ 3.75" bottom to 9112' CTM. Venturi from 9015' to 9112' CTM. POOH w/ about cup of dirt / 0 -rings/ Electrical Tape. Shorten fishing string to (BOT) 3.01" x .94' CTC, 3.13" x 1.55' DFCV, 3.16" x 7.80' U/D Jars, 3.5" x .5' X- over, 3.5" x 2.15' FA Hyd Disc (3/4" Ball), 3.5" x .5' x -over, 3.13" x .6 Rupture sub, 4.5" x 1.95' G spear (OAL= 15.99'). Seat @ 9017" tried pass on differend speeds 3 times. Pass through. Jar down in attempt to latch plug. Unsuccessful POOH. 03/06/13 Pumped 13 bbls Xylene followed by 20 bbls Diesel as directed by CTU down Coil. CTU in control of well notified pad op upon departure. FWHP = 0/0/0 SV/W /SSV /M /IA/OA = CTU. CTU #9 w/ 1.75" CT (CTV= 37.5). Objective - cleanout RWO fill and pull PXN plug. Continue RIH w/ 4.36" OD Venturi w/ wire fingers. Attempt to pass 9010' CTM w/o success. POH. LD Venturi w/ no recovery or marks. RIH w/ 2.5" DJN assy to 9113'. LRS Toad CT w/ 14 bbls xylene followed by 18 bbls diesel. CTU displace xylene w/ McOH at min rate to dissolve rubber in PXN plug. POOH. MU BOT milling assembly w/ 3.12" mill and no go w/ brass tattle tails. RIH, tagged at 9115' ctm. milled down to 9124.7' ctm with 3K wt on bit. POOH to inspect mill. Mill has indication of fishing neck. RIH w/ fishing assembly with 5" GS and latched plug at 9121' CTM. Got three weak jars licks and jars quit. Release from plug. POH for jars. Found 5 -1/2 PXN plug on bottom of BHA! LD BHA In progress. 03/07/13 CTU #9 w/ 1.75" CT (CTV= 37.5). Objective - cleanout RWO fill and pull PXN plug. Well is FP w/ 44 bbls. McOH. RDMO to SWS yard to remove 7 -1/16" BOPE equipment. 03/09/13 DRIFTED W/6.05" GAUGE RING TO SSSV NIPPLE AT 2197' SLM /2209' MD. 03/10/13 SET 6" DB LOCK, A -1 INJECT VALVE (ser HAAL -023, 3.5" orifice, * *mod. flper hsng & mod lock adpt **, 50" oal). PERFORM PASSING CLOSURE TEST. 03/17/13 T /I /0= 3250/249/480 Temp =HOT AOGCC MIT -IA PASSED to 2500 psi (witnessed by John Crisp) Pressured up IA with 2.3 bbls meth. IA lost 1 psi in 1st 15 mins and gained 10 psi in 2nd 15 mins for a total gain of 9 psi in 30 min test. Bled pressure back. Final WHPs 3200/160/420 SV= Shut MV,SSV,IA,OA= Open. Page 2 of 2 1 . 4 BEE= CIW • WEUJ RC AGI-05 - Alt NOTES: WELL REQURES A SSSV *** LNR NOT CMT'D. ACTUATOR= BAKER C SG, 68#. — I 79' FITIAL KB. EV = 13- EL 49.7 3/8" C 14>< >< 1 I3F. ELB/ = J-3 2210' H7-5/8" X r XO, D = 6253' I K-55, D= 12.415' KOP = 50' NOT LISTED I 2226' H7' o&-8 NP, D = 6.00" I M3X Angle = 38• ri 2949' 10189' Datum 10 = ON TALLY 2226 ° F-I6 DB LOCK, A-1 INJECTION SSSV (03/10/13) I Datum TVD= 8800' SS \ ,1 1 120" CONDUCTOR 91.5#, H-40, D = 19.124" 1 106' - / 2242' 1-17 X 7 XO, ID = 6.253" 1 1 7-5/8' TBG, 29.7#, L-80 VAMTOP HC, —I 2210' 111 .0459 bpi, D = 6.875' r TBG. 260, L-80 VAMTOP, —I 224r .0383 bpi, 13 = 6276' -5/r X 7' X0, D = 8253" I i 13-3/8' CSG, 72#, L-80, 13= 12.347' H 3858' ■ 1 33 8923, iiii: R NP D = 5'963" I 7-5/8' TBG, 29.70, L-80 VAMTOP HC, —I 8923' .0459 bpf, 13 = 6.875' 8971' H9- X 7" FES TNT PKR, D = 5.917' I Minimum ID =4.455" @ 9127' 2:1 5-1/2" OTIS XN NIPPLE I I 9011. Hr RN MP, 13 = 5.50" I 7' TBG. 280, L T�, —3 9023' I I 9023' 1-1 r x 5-1/2" X0,13 = 4.850' I • .0383 bpi, 0 = 8278' 9099' H5-1/2' MULESHCE. 13 = 4.850' IT TBG 511/0 (12105112) H 9036' I-- --------- 9078' I—I 9-5/8' X 7' BKR S8-3A PKR, D = 6.000' I 2K 7' TBG, 26#, NT-80-S-R, NSCC, —I 9084' 1 N --3 9084' H X 5-1/2" XO, 13=4.812' I .0383 bpf, 13 = 6.276' • I 9106' H5-1/2' PARKER MS NP (9CR), D = 4.582' I , I 9127' 1 /2' OTIS XN MP, 13 = 4.455' I I 5-1/2' TBG, 177t, L-80 NSCC, —I 9139' .0232 bpf, D =4.892' / I 9139' 1-15-12" WLEG, D = 4.892' !TOP OF 7" 1_1 1—i 9144 1 I 9135' HEIA43 TT LOGGED 05/10/93 1 9144' I-19-5/8" X 7 BKR H BOLATTON PKR, 1)- 6.188' I 9150' 1 X 7' BKR FTY-FLO 1 LM HGR, 0 = 6.188" I I 9-5/8' CSG, 470, NT-80-S, ID = 8.881' I—I 9323. 3 ■ PERFORATION %WARY FEF LOG: BRCS ANA ON 04/20/93 ANGLE AT 'PCP FERF: 15° CO 9516' Note: Fkefer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 3-318" 6 9516 - 9546 0 P 0/13/93 3-3/8' 6 9573 - 9583 0 P lY13/93 3-3/8' 6 9606 - 9626 0 F l3/13/93 3 6 9668 - 9888 0 F 6/13/93 3-3/8' 6 9730 - 9750 0 F 6/13/93 I H 9801' I A I 7' LNR, 290, NT-80-S, .0371 bpf, 13 = 8.184' H 9622. [ DATE REV BY (OLSENTS DATE REV BY COMLENTS PRUDHOE BAY LINT 04/22/93 AIM 2 INITIAL COMPLETION 03/10/13 RCT/ PJC 06 PIP 13 CORFECTION WELL: AGI-05 12/12/12 DOYON14 RIAD 03/19/13 JUAN) ADDED SSSV (03/10/13) FIT N0 1930020 12/21/12 JM) CIRLG DRAFT CORRECTIONS AR N3: 50-029-22327-00 01/02/13 PJC DRAINFIG CORRECTIONS SEC 36, T1211, R14E, 2055' FSL & 2474' F13., 01/03/13 PJC DRAWING CORRIMBONS 03/08/13 SJW/J1W) PULLED PXN PLUG (03/06/13) BP EXploration (Alaska) , . • a , „w \� �� //jj� THE STATE Alaska Oil and Gas N �, °fALAS� ;, _: Conservation Commission i GOVERNOR SEAN PARNELL 333 West Seventh Avenue 01,; P Anchorage, Alaska 99501 -3572 ALA Main: 907.279.1433 Fax: 907.276.7542 David Reem 3_ DO �-- Engineering Team Leader 1 1 / BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 SCANNED JAN 0 9 201 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU AGI -05 Sundry Number: 312 -414 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. ,01 eV o r K. :rm.. Commissioner DATED this s day of November, 2012. Encl. STATE OF ALASKA ;r °, ;>w I V« v F •r. • . x. e ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL , „. a" (3; 20 AAC 25.280 : *_� 1. Type of Request: ,, t✓ � ' ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ® Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Development ❑ Exploratory 193 402 - 3. Address: ® Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 22327 -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 AGI -05 Spacing Exception Required? ❑ Yes e No 9. Property Designation: 10. Field / Pool(s): ADL 028301 & 034628 Prudhoe Bay / Prudhoe Bay 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): 9822' 8490' 9801' 8470' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 20" 30' - 106' 30' - 106' 1490 470 Surface 3829' 13 -3/8" 29' - 79' / 79' - 3858' 29' - 79' / 79' - 3481' 3450 / 4930 1950 / 2670 Intermediate 9289' 9-5/8" 34' - 9323' 34' - 8006' 6870 4760 Production Liner 696' 7" 9126' - 9822' 7818' - 8490' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9516' - 9750' 8193' - 8420' 7 ", 26# x 5 -1/2 ", 17# NT -80S / L -80 9139' Packers and SSSV Type: 7" Camco BAL -O SSSV Packers and SSSV 2219' / 2150' 7" x 5 -1/2" Baker SB -3A Packer MD (ft) and TVD (ft): 9076' / 7771' 12. Attachments: 13. Well Class after proposed work: w Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Development ® Service ❑ Str 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: November 15, 2012 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ® GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564 -4387 ^I Printed Name Davi eem Title Engineering Team Leader Prepared By Name /Number: �- Signature 14,_ Phone 564 -5743 Date /o /ZS /Z0 /2 Joe Lastufka, 564 -4091 �, Commission Use Only 13- Conditions of approvak Notify ComTission so that a representative may witness 1 "7 J Sundry Number: 5 L.... ❑ Plug Integrity 'BOP Test in Mechanical Integrity Test ❑ Location Clearance Te, f 3 v P �v I Other: 1 1 r �- ' Cl �f r � / vi, 1 Z'G h 5 5 c1 :1 r t 3�Cl ., Li Al v - - l c ? - � & CG ,221-- h rs i r-, cl v-4 ii c. t c. f CO I-7-5-4/ Q /-1 d //) f7 ) .,.,. Subsequent Form Required: JO — 4l% ,� �.� APPROVED BY !/! / � `V Approved By: / _COMMISSIONER THE COMMISSION Date /l //""4/ P Form 10 -403 Revised 01/2010 • Su mit n Duplicate ORIGI �cT • • 0 bp G • -,/ itaArArly AGI -05 Rig Workover Revision 1 Scope of Work: Repair T -IA communication. Pull 7" Tubing. Install new 7 - injection tubing. MASP: 2,622 psi Well Type: Gas Injector Estimated Start Date: November 15, 2012 Production Engineer: Javier Farinez Intervention Engineer: Sean McLaughlin Pre -riq prep work: S 1 Pull MCV SSSV. Drift for 5 -1/2" TTP S 2 Run SBHPS -21 days prior to rig arrival S 3 Set 5 -1/2" PXN at 9,127', Dump sluggits above PXN, Set 5 -1/2" junk catcher F 4 CMIT -T to 4000 psi. MIT -OA to 2000 psi. W 5 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT -T & IC. Proposed Procedure: / f a h 1 4-'6 G Z h r s u 4 v - c 1. MIRU Doyon 14. ND tree. NU and test BOPS with four preventers configured top down (annular, 3 -1/2" x 6" VBR's, blind shears, mud cross and 7" fixed). Test the VBR's to _4 . o00 psi and the annular to 3,500 - psi. 2. Mechanically cut tubing @ 9,005'. Reference Schlumberger GL /CCL log 10 May,1993. Cut desired to be 1/4 way down first full joint above packer. Circulate well to kill weight fluid through the cut. 3. Pull and LD 7" tubing string from cut. 4. Run a scraper and drift 7" tubing stub. Set a storm packer. 5. Change out the 7" fixed rams to 7- fixed and test to 4,000 psi. Change IC pack -off. 6. Run 7- 29.7# L -80 VamTop HC IPC injection completion. 7. Displace the IA to completion fluid, freeze protect and set the packer. 8. Test tubing and IA to 4,000 psi. 9. Set TWC. ND BOPE. NU and test tree. RDMO. Post riq work: S 1 Pull DB -6 sleeve, ball -n -rod, RHC seat, bail sluggits, retrieve junk catcher, pull PX plug, install A- 1 injection valve. F 2 MIT -IA post put on injection -AOGCC • • TREE = CM/ • SAFETY NOTES: WELL REQUIRES A SSSV. LINER 'WELLHEAD = FMC At I — O 5 THREAD. CEMENTED. ALL TBG IS IPC WITH NSCC ACTUATOR = BAKER C KB. ELEV = 49' f BF. ELEV = 1 KOP = 1051' Max Angle = 38 @ 6982' X ?C Datum MD = 10239' Datum TVD = 8800' SS ECT 1 2219' I-17" CAMCO BAL -O SSSV NIP, ID = 5.937" 1 13 -3/8" CSG, 68 #, K -55, ID = 12.415" I 79' 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 3858' I--A r , Vi ^� Gv v-- 9075' I-i A NCHOR Minimum ID = 4.455" @ 9127' /I 5-1/2" OTIS XN NIPPLE S Z 9076' H9-5/8" x 7" BAKER SB -3A PKR, ID = 6.000" I I7" TBG, 26 #, NT -80 -S -IPC, NSCC, .0383 bpf, ID = 6.276" H 9084' I- / 9084' 1-1 7" X 5-1/2" XO, ID = 4.812" I 'TOP OF 5 -1/2" TBG I 9084' I I 1 1 1 9106' H5-1/2" PARKER SWS NIP, ID = 4.562" I 'TOP OF 7" LNR I 9126' 1 V4 I 9127' H5-1/2" OTIS XN NO -GO NIP, ID = 4.455" I 5 -1/2" TBG, 17 #, L -80 -IPC, NSCC, .0232 bpf, ID = 4.892" H 9139' 1 / ■ I 9139' 1-15-1/2" WLEG, ID = 4.892" I 1 9135' I-I ELMD TT LOGGED 05/10/93 I 9 -5/8" CSG, 47 #, NT -80 -S, ID = 8.681" H 9323' I PERFORATION SUMMARY REF LOG: BHCS AWA ON 04/20/93 ANGLE AT TOP PERF: 15 @ 9516' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 9516 - 9546 0 6/13/93 3 -3/8" 6 9573 - 9583 0 6/13/93 3 -3/8" 6 9606 - 9626 0 6/13/93 3 -3/8" 6 9668 - 9688 0 6/13/93 3 -3/8" 6 9730 - 9750 0 6/13/93 (PBTD 9801' I 1 7" LNR, 29 #, NT -80 -S, .0371 bpf, ID = 6.184" I-1 9822' , DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT ' 02/02/93 ORIGINAL COMPLETION 02/15/08 ? ?/TLH TTP PULLED (09/20/06) WELL: AG-05 �� ; 05/22/01 RN/KAK CORRECTIONS 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE PERMIT No: r 1930020 03/13/03 AS /TP ADD IPC/THREAD FOR TBG API No: 50- 029 - 22327 -00 • 05/12/03 JRC/KK ADD 13 -3/8 ", 68# CSG SEC 36, T12N, R14E, 2879.13' FEL & 2680.08' FNL 08/11/04 WRR/TLP TREE, WELLHEAD CHANGES 09/21/06 CJN/TLH PXN TTP SET (09 /14/06) BP Exploration (Alaska) EE AGI-05 Q.... / 1 \V /W. WI G/- /- /�GqV /IILJN JJJ � . LD ° NOT CEMENTED. ALL TBG IS IPC WITH NSCC ACTUATOR= BAKER . 1,./131C,, ., KB. ELF/ = 49' BF. ELEV = Proposed RWO KOP= 1051' Max Angle = 38 6982' X Datum M3= 10239' Datum ND = 8800' SS o 1 7' 10 DB-6 NPL SCR, for A -1 INJ Vaho 1 13 -3/8" CSG, 6511, K -55, D = 12.415" 1 79' \ , 2219' = 6.00" OD = 7.671' 1 13-3/8' CSG, 72#, L-80, D = 12.347' H 3858' 7 -5/8 ", 29.7 #, L -80, VAMTOP HC, IPC TK -7 Minimum ID = 4.455" @ 9127' i j 7" R NIP, ID = 5.770" 5 -1/2" OTIS XN NIPPLE g — 7" x 9 -5/8" HES TNT Packer • ---7" RN NIP, ID = 5.963" , zl 9075' IHANCHOR I g g` 1 9076' H9-5/8“ X 7' BAKER SB-3A PKR, D = 6.000" 17" TBG, 26 # NT- 80- S-IPC, NSCC, .0383 bpf, D = 6.276" H 9084' ` .5 -1 /2 ", 17 #, L -80, TC I I ITOP OF 5-1/2" TBG H 9084' 1 /� 9084' H7" X 5 XO, D = 4.812" 1 1 I 9106' H5-1/2" PARKER SINS NP, 113 = 4.562" TOP OF 7 LNR H 9126' - IN I 9127' H5-1/7 OTIS XN NO-GO NP, D = 4.455" I 5 -112" TBG, 17# L -80 _ PC, NSCC, .0232 bpf, D 4.892" H 8138' I / I 9139' H D 5-1/2" VVLE3, = 4.892" I 9135' H E-ND TT LOGG® 05/10/93 1 9-5/8" CSG, 47#, NT-80-S, ID = 8.681' —I 9323' 1 • , PERFORATION SUISAARY REF LOG: BHCS AWA ON 04/20193 ANGLE AT TOP PE RE 15 9516' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL Opn/Sgz I]■TE 3-3/8" 6 9516 - 9546 0 6/13/93 3-3/8" 6 9573 - 9583 0 6/13/93 3-3/8" 6 9606 - 9626 0 6/13/93 3-3/8" 6 9668 - 9688 0 6/13/93 3-3/8" 6 9730 - 9750 0 6/13/93 PBTD 9801' I 7" LNR, 29#, NT -80-S, .0371 bpf, D = 6.184" H 9822' 1 DATE REV BY CONSENTS DATE RE'/ BY CONSENTS PRU)HOE BAY UMT 02/02/93 ORIGINAL CONFLETION 02/15/08 ??/TLH Tip RJLLB) (09/20/06) VVB.L: AGI-05 05/22/01 RWKAK CORRECTIONS 02/11/11 Nt61JM3 ADDED SSSV SAFETY NOTE PBRMT No: 1930020 03/13/03 AS/TP ADD PC/THREAD FOR TBG API No: 50- 029 - 22327 -00 05/12/03 JRC/KK ADD 13 -3/8 ", 68# CSG SEC 36, T12N, R14E 2879.13' FEL & 2680.08' FNL 08/11 /04 VVRR/TLP TREE, VE LFEAD CHANGES 09/21/06 CJWTLH PXNTTP SET (09/14/06) BP Exploration (Alaska) A / RIG FLOOR 33.7 ' AGL n 1 7.00 1 ■ VALVE LEGEND i 11� ©� ©i0� © 'i0�0� 1 BYPASS i I I I 2 KILL I — 17C LJ 3 CHOKE y - 1\ 4 BOTTOM RAMS 1 5 BLIND RAMS f 6 TOP PIPE RAMS lig 3 s /e', So°o PSI. HYDRIL ARNLEAR BOP, ACCUMULATOR: NL SHAFFER, 180 GAL, 6 STATION 7 ANNULAR • STUDDED TOP /FLANGED BOTTOM TRIPLEX PUMP: 1 • VAC, F HP AIR PUMP: 1, NL SHAFFER O O O M — FLANGED TOP 4111111 i 10• 13 5/8, 5000 PSI, 10" MPL OPERATORS. HTDRIL PIPE RAM 3 I/8 5000 P51 510E OUTLET \ ill 3' CHOKE LINE I MM. 13 5/8 ". 5000 PSI. 14' UPI OPERATORS. [ - H7DRIL ELIND SHEAR RNA [ _ _ _ _ - - •III- N11 , U STUDDED BOTTOM BX 180 B0 PARS • • • ■ ■ �— 3 1/8" 5000 P51 OCR VµVE • • • I II"III ■ ' - III0II ■' II,/II 1500 J000 � 4 t 2" KILL LINE kni 3 1/8" 5000 P51 HCR VILVEJ / N 3 1/8" 5000 PSI GATE VALVE • • 3 I /a' 5000 P51 GATE VALVE JJJ _.... . HYDRI 13 5X, 5000 PSI. 10" NPL OPERATORS, I —�� i '-.. 1 11 .. I HroraL PIPE RAN STUDDED BOTTOM /FLANGED TOP B • • z 160 ACCUMULATOR MANIFOLD D : "'POUF • 1 m: + .- + - ; II 18 BOTTLES, 10 GALLONS EACH • RUN • • % BOP STACK ELEVATION [ : : : 3 • REMOTE PANEL IN DOGHOUSE ill I AND UTILITY MODULF I ling i l`71-1 `v.' NITROGEN BACKUP BOTTLES I 21 1/4*, 2000 P51, 16" 150 PSI HYDR. MSP NYORIL BOP /ONERTER _.—.____=... OPERATED KNIFE GATE VALVE STUDDED TOP /FLANGED BOTTOM I I 1 ' C/W PLUG ■■•=mll' FLANGE/FLANGE RX 73 1 ms 4 vr aLw a o018H KEM w ux v ¢ 9 4 4 PoeKwrlE PLY s Wlx 4 walw FIX aTVn anuxG i 16" FLCO VENT LINE o on iiMM - - '- -- -- � - -' — — 01/18/06 5 owe LEA uIaLTE BOP SULK � ...c. RIC 14 03/05/01 • CMS LEA UPDATE BOP STACK i ■■12N FLANGE 01/31/00 3 one LEA KO,E 0160/61 LACS 1°60 BOP SYSTEM 12 -2o -a 2 B LEA UPDATE BOP SUCK AND CONTROL MB rev SURFACE DIVERTER CONFIGURATION 11 -25 -55 1 JTH LEA 5608 To /WOO DATE CHECK PR AMMO EN LEA s SC4E 0A1E 1 DESCRIDESCRIPTION NTS ° J MC. RI 4BOPSYS&CONTROL so. 1 STATE OF ALASKA ALAIDA OIL AND GAS CONSERVATION COMIAION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Water Wash Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development ❑ Exploratory p 193 -002 -0 3. Address: P.O. Box 196612 Stratigraphic ❑ Service El 6. API Number: _ Anchorage, AK 99519 -6612 50- 029 - 22327 -00 -00 1 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0034628 PBU AGI -05 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): _ To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 9822 feet Plugs measured None feet true vertical 8490.31 feet Junk measured None feet Effective Depth measured 9801 feet Packer measured 9076 feet true vertical 8469.8 feet true vertical 7771.21 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 76 20" 91.5# H-40 30 - 106 30 - 106 1490 470 Surface 3779 13 -3/8" 68# L -80 79 - 3858 7 97-4g#. 31 5020 2260 Intermediate None None None None None None Production 9295 9 -5/8" 47# NT8OS 28 - 9323 28 - 8005.69 6870 4760 Liner 696 7" 29# NT8OS 9126 - 9822 7817.9 - 8490.31 8160 7020 Perforation depth Measured depth See Attachment feet 213 C` P 4 t? JAN 2 8 True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) 7" Baker SB -3A Packer 9076 — 7771.21 Packer None None ` None SSSV 12. Stimulation or cement squeeze summary: RECE1VEC Intervals treated (measured): SEP 2 4 2012 Treatment descriptions including volumes used and final pressure: A 13. Representative Daily Average Production or Injection Data ' "OGG O Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: „ Copies of Logs and Surveys Run Exploratory 0 Development[] Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL Li GSTOR ❑ WINJ ❑ WAG ❑ GINJ 0 SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -199 Contact Nita Summerhays Prepared by Nita Summerhays 564 -4035 Printed Name Nita Summerhays Title Petrotechnical Data Technician Signatur-. � '%i Phone 564 -4035 Date 9/24/2012 Form 10-404 Revised 11/201 � (! ' /�Z- u bmit • Original Only R 3 C3 MS SEP 25 1011 .; v 3 1\ v • S Daily Report of Well Operations ADL0034628 ACTIVITYDATE ( SUMMARY •_ •is le :i emp =nl •iese 'yene "as •umpe• • ••sme o owes •y 100 bbls diesel /xylene down TBG. Pumped 326 bbls fresh water w /.02% F -103 surfactant to flush 7/11/2012 TBG. ***Continued on 07/12/12 WSR*** " " "Confinued from 07711/12 WSR* (DTesel/Xylene TBG Wash) continued pumping 267 bbls fresh water w/ F -103 surfactant down TBG for a total of 593 bbls. Pumped 10 bbls meth down TBG to freeze protect. Valve positions upon departure: SV WV = closed. SSV MV IA OA= open. Pad Op 7/12/2012 notified. FWHPS = 0/1040/58 FLUIDS PUMPED BBLS 20 METH 100 DIESEL /XYLENE 593 FRESH WATER W/ F -103 SURFACTANT 713 TOTAL • • Perforation Attachment ADL0034628 Perf Opera Meas Meas SW Operation tion Depth Depth TVD Depth TVD Depth Name Date Code Top Base Top Base AGI -05 6/13/93 PER 9516 9546 8192.56 8221.62 AGI -05 6/13/93 PER 9573 9583 8198.59 8208.29 AGI -05 6/13/93 PER 9606 9626 8230.61 8250.03 AGI -05 6/13/93 PER 9668 9688 8290.86 8310.34 AGI -05 6/13/93 PER 9730 9750 8351.27 8370.79 AB ABANDONED MIR REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET OH 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 Casing / Tubing Attachment ADL0034628 Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 20" 91.5# H-40 30 - 106 30 - 106 1490 470 LINER 696 7" 29# NT8OS 9126 - 9822 7817.9 - 8490.31 8160 7020 PRODUCTION 9295 9 -5/8" 47# NT8OS 28 - 9323 28 - 8005.69 6870 4760 SURFACE 3779 13 -3/8" 68# L -80 79 - 3858 79 - 3481.31 5020 2260 TUBING 9057 7" 26# NT8OS 27 - 9084 27 - 7778.65 7240 5410 TUBING 55 5 -1/2" 17# L -80 9084 - 9139 7778.65 - 7830.12 7740 6280 • • TREE = • CM/ • NOTES: WELL REQUIRES A SSSV. LINER WELLHEAD = FMC A# I _ 0 NOT CEMENTED. ALL TBG IS IPC WITH NSCC ACTUATOR = BAKER C THREAD. KB. ELEV = 49' BF. ELEV = KOP = 1051' Max Angle = 38 @ 6982' Datum MD = 10239' Datum TVD = 8800' SS 2219' H7" CAMCO BAL -O SSSV NIP, ID = 5.937" I 13 -3/8" CSG, 68 #, K -55, ID = 12.415" I 79' 13 -3/8" CSG, 72#, L-80, ID = 12.347" H 3858' 1 Minimum ID = 4.455" @ 9127' 9075' 1-1 ANCHOR' 5-1/2" OTIS XN NIPPLE S E H 9076' H9-5/8" X 7" BAKER SB -3A PKR, ID = 6.000" 7" TBG, 26 #, NT- 80- S-IPC, NSCC, .0383 bpf, ID = 6.276" I-I 9084' I- ` ( 9084' I 1 7" X 5-1/2" XO, ID = 4.812" I TOP OF 5-1/2" TBG H 9084' I ' , I 9106' H5-1/2" PARKER SWS NIP, ID = 4.562" I TOP OF 7" LNR I 9126' I ' ' I 9127' H5-1/2" OTIS XN NO-GO NIP, ID = 4.455" I 5 -1/2" TBG, 17 #, L -80 -IPC, NSCC, .0232 bpf, ID = 4.892" I- 9139' I / I 9139' 1-15-1/2" WLEG, 10= 4.892" I I 9135' H ELMD TT LOGGED 05/10/93 I 1 9-5/8" CSG, 47 #, NT -80-S, ID = 8.681" H 9323' I PERFORATION SUMMARY REF LOG: BHCS AWA ON 04/20/93 ANGLE AT TOP PERF: 15 @ 9516' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 9516 - 9546 O 6/13/93 3 -3/8" 6 9573 - 9583 0 6/13/93 3 -3/8" 6 9606 - 9626 0 6/13/93 3 -3/8" 6 9668 - 9688 0 6/13/93 3 -3/8" 6 9730 - 9750 0 6/13/93 I PBTD I 9801' I 17" LNR, 29 #, NT -80 -S, .0371 bpf, ID = 6.184" H 9822' I A DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/02/93 ORIGINAL COMPLETION 02/15/08 ? ?/TLH TTP PULLED (09/20/06) WELL: AGI-05 05/22/01 RN/KAK CORRECTIONS 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE PERMIT No: '1930020 03/13/03 AS/TP ADD IPC/THREAD FOR TBG API No: 50- 029 - 22327 -00 05/12/03 JRC/KK ADD 13 -3/8 ", 68# CSG SEC 36, T12N, R14E, 2879.13' FEL & 2680.08' FNL 08/11/04 WRR/TLP TREE, WELLHEAD CHANGES 09/21/06 CJN/TLH PXN TTP SET (09/14/06) BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 20, 2012 Mr. Jim Regg A�EO AUG 0 7 2012 Alaska Oil and Gas Conservation Commission Q a 9- 333 West 7 Avenue Anchorage, Alaska 99501 t� 05 " Subject: Corrosion Inhibitor Treatments of GPB AGI Dear Mr. Regg, • Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB AGI that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) AGI Date: 01/10/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date AGI -01 1921240 50029223070000 0.6 NA 0.6 NA 3.4 7/25/2011 AGI-02 1921200 50029223110000 0.6 NA 0.6 NA 3.4 7/25/2011 AGI-03 1921350 50029223180000 3.3 NA 3.3 NA 22.1 1/10/2012 AGI -04 1921460 50029223230000 1.4 NA 1.4 NA 17.0 7/23/2011 -- �4GI -05 1930020 50029223270000 1.9 NA 1.9 NA 13.6 7/24/2011 AGI-06 1930090 50029223330000 1.8 NA 1.8 NA 11.9 1/10/2012 AGI -07 2060520 50029223430100 2.0 NA 2.0 NA 17.0 7/24/2011 AGI -08 1930330 50029223480000 1.8 NA 1.8 NA 15.3 7/24/2011 AGI-09 1930350 50029223500000 Split conductor NA NA NA NA NA AGI -10 2061350 50029223530100 Dust cover NA NA NA NA NA • • � 3 ALASIA SEAN PARNELL, GOVERNOR ALASKA OIL AND GrAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 CONSERVATION PHONE (907) 279 -1433 FAX (907) 276 -7542 Bob Chivvis 4 Petroleum Engineer n j BP Exploration (Alaska), Inc. �, P.O. Box 196612 Anchorage, AK 99519 -6612 . Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU AGI -05 Sundry Number: 312 -199 Dear Mr. Chivvis: 5L4 D JUL ' 3 `1.012 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Si cerely a , . Norman Com ' i : oner DATED this day of June, 2012. Encl. RECEIVED STATE OF ALASKA ALAIlk OIL AND GAS CONSERVATION COMMIIIDN MAY 3 0 2012 f APPLICATION FOR SUNDRY APPROVALS AOGCC AAC 25.280 AOG CC 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend p Plug Perforations ❑ Perforate❑ Pull Tubing ❑ )01 Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate❑ Alter Casing ❑ Other: WATER WASH 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 193 -0020 3. Address: P.O. Box 196612 Stratigraphic ❑ Service 0 - 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22327 -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 AGI -05 • Spacing Exception Required? Yes ❑ No El 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 034628 PRUDHOE BAY Field / PRUDHOE Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9822 - 8490 - 9801 8470 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 20" 91.5# H-40 30' 106' 30' 106' 1490 470 Surface 50' 13 -3/8" 68# K -55 29' 79' 29' 79' 3450 1950 Surface 3779' 13 -3/8" 68# L -80 79' 3858' 79' 3481' 4930 2270 Production 9295' 9 -5/8" 47# NT8OS 28' 9323' 28' 8006' 6870 4760 Liner 696' 7" 29# NT8OS 9126' 9822' 7818' 8490' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 7" 26# NT -80S 27 9084 - - 5-1/2" 17# L -80 IPC 9084 9139 Packers and SSSV Tvoe: 7" CAMCO BAL-0 SSSV Packers and SSSV MD and TVD (ft): 2219' 2150' 7" BAKER SB -3A 9076' 7771' 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service la . 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/13/2012 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ J . WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bob Chivvis Printed Name Bob Chivvis Title PE Signature �r ` Phone Date 564 -5412 5/30/2012 Prepared by Nita Summerhays 564 -4035 • COMMISSION USE ONLY t / Conditions of approval: Notify Commission so that a representative may witness Sundry Number: * 2-- e `9 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: /e, -4d APPROVED BY Approved by: 1,- t C OMMISSIONER THE COMMISSION Date: .s4"1 Y ((�� , ( rr , ^ � G� �" Submit in Du , \ - - : - i ∎ `+` 0 - 03'R ' 11 b� R G L W ( "' plicate kii AG1 -05 193 -002 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base AGI -05 6/13/93 PER 9,516. 9,546. 8,192.56 8,221.62 AGI-05 6/13/93 PER 9,573. 9,583. 8,247.79 8,257.49 AGI -05 6/13/93 PER 9,606. 9,626. 8,279.81 8,299.23 AGI-05 6/13/93 PER 9,668. 9,688. 8,340.06 8,359.54 AGI -05 6/13/93 PER 9,730. 9,750. 8,400.47 8,419.99 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED • FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • TREE = CM/ • S NOTES: WELL REQUIRES A SSSV. LINER WELLHEAD = . FMC AGI-05 NOT CEMENTED. ALL TBG IS IPC WITH NSCC ACTUATOR = BAKER C THREAD. KB. ELEV = 49' BF. ELEV = ._ KOP = 1051' Max Angle = 38 @ 6982' X X Datum MD = 10239' Datum TVD = 8800' SS I 2219' I—17" CAMCO BAL -O SSSV NIP, ID = 5.937" I 113 -3/8" CSG, 68 #, K -55, ID = 12.415" I 79' 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 3858' I Minimum ID = 4.455" @ 9127' ri 9075' I— IANCHOR 5 -1/2" OTIS XN NIPPLE S S H 9076' I—I9 -518" x 7" BAKER SB -3A PKR, ID = 6.000° I ( TBG, 26 #, NT -80 -S -IPC, NSCC, .0383 bpf, ID = 6.276" 1-1 9084' I TOP OF 5 -1/2" TBG H 9084' I I 9084' H " X 5 -1/2" XO, ID= 4.812" I 1 1 I 9106' H5_1/2" PARKER SWS NIP, ID = 4.562" I ITOP OF 7" LNR I 9126' I 1 1 1 9127' 1 OTIS XN NO -GO NIP, ID = 4.455" I 5-1/2" TBG, 17 #, L-80-IPC, NSCC, .0232 bpf, ID = 4.892" I—I 9139' I / \ I 9139' 1 WLEG, ID = 4.892" I 9135' H ELMD TT LOGGED 05/10/93 1 19 -5/8" CSG, 47 #, NT -80 -S, ID = 8.681" H 9323' I A PERFORATION SUMMARY REF LOG: BHCS AWA ON 04/20/93 ANGLE AT TOP PERF: 15 @ 9516' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 9516 - 9546 0 6/13/93 3 -3/8" 6 9573 - 9583 0 6/13/93 3 -3/8" 6 9606 - 9626 0 6/13/93 3 -3/8" 6 9668 - 9688 0 6/13/93 3 -3/8" 6 9730 - 9750 0 6/13/93 • IPBTD — I 9801' I-- 17" LNR, 29 #, NT -80 -S, .0371 bpf, ID = 6.184" H 9822' I , DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/02/93 ORIGINAL COMPLETION 02/15/08 ? ?/TLH TTP PULLED (09/20/06) WELL: AGI-05 05/22/01 RN/KAK CORRECTIONS 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE PERMIT No: ® 1930020 03/13/03 AS/TP ADD IPC/THREAD FOR TBG API No: 50- 029 - 22327 -00 05/12/03 JRC/KK ADD 13 -3/8 ", 68# CSG SEC 36, T12N, R14E, 2879.13' FEL & 2680.08' FNL 08/11/04 WRR/TLP TREE, WELLHEAD CHANGES 09/21/06 CJN/TLH PXNTTPSET(09 /14/06) BP Exploration (Alaska) Version 1.1 04/28/2010 Fullbore Pumping Design Template Welt Name AGI -05 Job Scope Select Job Scope H2S (ppm /date) WBL Cat IOR 2500 Max Pumping Pressure (psi) Well Type GI AFE APBinjec Main Fluid Type Date 5/29/2012 IOR 100 600 Main Fluid Volume (bbls) Engineer Bob Chivvis Phone 564 -5412 • Methanol (60/40) Freeze Protect Type Job Objective 10 Freeze Protect Volume (bbls) If Applicable Recent Tbg Fluid Level (ft) Improve injectivity by dissolving salts and possibly asphaltenes in the if Applicable Recent IA, Fluid Level (ft) tubing and formation. Diesel /Xylene washes have been used • If Applicable Recent OA Fluid Level (ft) successfully in the past on the NGI/WGI /AGI gas injectors to improve If Applicable Expected Tbg Fill Up Volume (bbls) injectivity. If Applicable Expected IA Fill Up Volume (bbls) If Applicable Expected OA Fill Up Volume (bbls) 357 Wellbore Volume to Perfs (bbls) Fullbore Pumping Schedule 3400 Anticipated Bottom Hole Pressure (psi) I Select Tubing /Casing within Pressure Limits? Stage Fluid Type Pump Volume Rate Into Max Size Burst /Collapse 80% Burst /Collapse (bbls) (bpm) Pressure Tubing Burst (psi) 7 7240.00 5792 I Pre -Flush I Methanol (60/40) 11 Tbg 101 51 25001 Tubing Collapse (psi) size See helpful tips tab Casing Burst (psi) size See helpful tips tab 1 Solvent 1 1 Select Fluid Type 11 Tbg 1 100 1 51 ( 25001 Casing Collapse (psi) size See helpful tips tab Load 1 1 Select Fluid Type 11 Tbg 11 60011 5 1 25001 Select Input Depth • Integrity Issues? No unknown !Freeze Protect 1 1 Methanol (60/40) 11 Tbg 1 1 10 1 51 25001 No Input Depth I 1 Select Stage 1 1 Select Fluid Type 1 Select 1 1 1 1 1 1 No 1 Tubing Caliper? Burst/Collapse ratings may need to be derated based on tubing condition I Select Production Packer within Pressure Limits? Detailed Pumping Procedure Rated Packer dp Max Anticipated dp at Packer 1 10 bbls 60/40 meoh spear 2 100 bbls 50/50 diesel / xylene I Not Necessary 1 Hold Pressure on Other Strings? 3 600 bbls of fresh water with 0.02% F -103 surfactant Tubing (psi) 4 10 bbls 60/40 meoh IA (psi) 5 RDMO. Return well to gas injection OA (psi) 6 • • Fullbore Pumping Program for Field Well Name AGI -05 Job Scope Select Job Scope Well Type GI AFE APBinjec Date 5/29/2012 IOR 100 - Engineer Bob Chivvis Phone 564 -5412 H2S Job Objective 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 NGIIWGI /AGI gas injectors to improve injectivity. Fullbore Pumping Schedule Stage Fluid Type Pump Into Volume (bbls) Rate (bpm) Max Pressure 1 Pre -Flush Methanol (60/40) Tbg 10 5 2500 2 Solvent Select Fluid Type Tbg 100 5 2500 3 Load Select Fluid Type Tbg 600 5 2500 4 Freeze Protect Methanol (60/40) Tbg 10 I 5 2500 5 Select Stage Select Fluid Type Select Detailed Pumping Procedure 1 10 bbls 60/40 meoh spear 2 100 bbls 50/50 diesel /xylene 3 600 bbls of fresh water with 0.02% F -103 surfactant 4 10 bbls 60/40 meoh 5 RDMO. Return well to gas injection 6 Additional Details If Applicable Recent Tbg Fluid Level (ft) Integrity Issues? No unknown If Applicable Recent IA Fluid Level (ft) No Input Depth if Applicable Recent OA Fluid Level (ft) • . • . Freeze Protection - see PE manual for additional information Freeze Protect to 2500' TVD in GPB. Use 60/40 Meth Water for Injectors Use 5 bbl 60/40 Meth Water spear followed by dead crude for Producers Pipe Data (L -80) dimensions mechanical inner capacity outer capacity size lb/ft od id drift id collapse burst bbls /ft ft/bbls bbls /ft ft/bbls 2.375 4.60 2.38 2.00 1.90 _ 11780.00 11200.00 0.00387 258.6 0.00548 182.5 2.875 6.50 2.88 2.44 2.35 11160.00 10570.00 0.00579 172.8 0.00803 124.5 3.188 6.40 3.19 2.81 2.68 11111.00 11111.00 0.00769 130.1 0.00987 101.3 3.500 9.30 3.50 2.99 2.87 10530.00 10160.00 0.00870 115.0 0.01190 84.0 4.500 12.60 4.50 3.96 3.83 7500.00 8430.00 0.01522 65.7 0.01967 50.8 5.000 18.00 5.00 4.28 4.15 10490.00 9910.00 0.01776 56.3 0.02429 41.2 5.500 17.00 5.50 4.89 4.77 6280.00 7740.00 0.02325 43.0 0.02939 34.0 7.000 26.00 7.00 6.28 6.15 5410.00 7240.00 0.03826 26.1 0.04760 21.0 7.000 29.00 7.00 6.18 6.06 7020.00 8160.00 0.03715 _ 26.9 0.04760 21.0 7.625 29.70 7.63 6.88 6.75 4790.00 6890.00 0.04592 21.8 0.05648 17.7 9.625 47.00 9.63 _ 8.68 8.53 4760.00 6870.00 _ 0.07321 13.7 0.08999 11.1 13.375 72.00 13.38 12.35 12.19 2670.00 5380.00 0.14809 6.8 0.17378 5.8 custom 6.000 4.000 0.01561 64.1 0.03497 28.6 Bursts OD GRADE WT Burst 3 1/2" 80 9.3# 10160 4 1/2" 80 12.6# 7500 5 1/2" 80 15.5# 7000 80 17# 7740 7" 80 26# 7240 80 29# 8160 95 29# 9690 110 29# 11220 7 5/8" 80 29.7# 6890 80 33.7# 7900 95 29.7# 8180 9 5/8" 55 36# 3520 55 40# 3950 80 40# 5750 80 43.5# 6330 80 47# 6870 80 53.5# 7930 95 47# 8150 10 3/4" 55 45.5# 3580 80 45.5# 5190 OV J . G J.J# 64JV 11 3/4" 95 60# 6920 13 3/8" 55 54.5# 2730 55 61# 3090 55 68# 3450 80 68# 5020 80 72# 5380 95 72# 6390 16" 80 84# 4330 18 5/8" 55 96.5# 2510 55 109.3# 2910 20" 40 94# 1530 55 133# 3060 Brine Design Notes Revised: 5/1/00 NaCI _ KCl CaCI NaBr Design Notes: 8.5 29 8.4 31 8.5 30 8.5 30 8.6 27 8.5 30 9.0 22 9.0 25 Design for -50 degrees from surface to 100', 10 degrees through 8.7 26 8.7 27 9.5 10 9.5 20 permafrost (approx. 2500). 8.8 24 8.9 23 10.0 -9 10.0 14 Be careful using McOH /H2H for freeze cap - McOH may mix with brine and 8.9 22 9.1 19 10.5 -36 10.5 6 dilute. 9.0 19 9.3 15 10.7 -51 11.0 2 Don't use Ca based fluids that may come in contact with the formation. 9.1 17 9.5 15 10.8 -57 11.5 -11 Be careful using CaCI in IA - may dump on formation. Corrosion Inhibitor: mix 25 gal of NEEC EC1124 per 100 bbls brine. 9.2 14 9.6 33 10.9 -35 11.7 - Note: Inhibitor has a 1 day half -life. 9.3 11 11.0 -19 11.8 -19 Be careful allowing very cold diesel to contact KCI - could form a slush. 9.4 9 11.5 36 11.9 -10 • 9.5 6 12.0 6 9.6 3 12.5 50 9.7 -1 12.7 63 9.8 -5 9.9 5 10.0 25 Crystallization Temperatures for Clear Brines KCI NaCI /iCaCt • 20 . / •. o V` 1 • o / NaBr s 0 �.44 � o / 1- / o 0 -20 - f ° a - -40 ` � / -r- CaCI \� -*--KCI -60 o NaBr 8.5 9.5 Density, PPG 10.5 11.5 12.5 I • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, February 06, 2012 4:45 PM To: 'AK, D &C Well Integrity Coordinator' Subject: RE: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for January 2012 This is to memorialize my decision regarding reporting requirements for 5 injectors as discussed with you earlier today: PBU NGI -11 (PTD 1770800); PBU AGI -08 (PTD 1930330) Weekly reporting may be discontinued based on passing MITs (1/7/12 for NGI -11; 2/5/12 for AGI -08). Intent as I communicated to Ryan Daniel on 1/20/12 was that weekly reporting was interim step while waiting for diagnostics (suspended due to extreme cold temps); TIO pressures should continue to be reported on monthly injection well integrity report for both wells until decision is made regarding need for Administrative Approval. • U AGI -05 PTD 1930020) Weekly reporting (see NGI -11) may be discontinued based on stabilization of annuli pressures that began last week of December 2011. This well can also be dropped from the monthly injection well integrity report at this time. PBU WG1 -06 (PTD 190030) Existing Admin Approval (AIO 4E.006) should be canceled based on completion of workover. AOGCC will evaluate the need for a new Admin Approval for the shallow setting depth of packer associated with approved repair. PBU W -44 (PTD 1891000) Well may be removed from the monthly report based on passing MITIA (4/12 -11), no leak found with LDL (6/26/11), and stabilized annuli pressures exhibited during past 90 days while on injection.. Jim Regg AOGCC S M D F E B 3 2.012 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWeIIIntegrityCoordinator (abp.com] Sent: Sunday, February 05, 2012 10:09 PM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer; Sauve, Mark A Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for January 2012 Jim, Phoebe, and Guy, Attached is the January 2012 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. 1 «AOGCC Inj Report 02- 12.zip» Notes on wells: Added to Report: 11 -38A (PTD #1982160) Added per requirement of AA 4E.040 issued January 9, 2012. Taken off Report: MPC -10 (PTD #1850150) Was being evaluated for TxIA communication. IAP stabilized and well returned to Operable status. Please call with any questions or concerns. Thank you, Mehreen Vazir (111cm/tie: (.;e aId l ttrrplij') Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com 2 I 0 0 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator@bp.com] Sent: Monday, January 30, 2012 6:47 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) �d 36I i Z ' Cc: Daniel, Ryan; Chivvis, Robert Subject: Gas Injector Status Update for AGI -08 (PTD #1930330), NGI -11 (PTD #1770800), and AGI -05 (PTD #1930020) Attachments: AGI -08 TIO 01- 30- 12.doc; NGI -11 TIO 01- 30- 12.doc; AGI -05 TIO 01- 30- 12.doc All, Please see attached updated TIO and Injection plots for the three subject wells. AGI -08 (PTD #1930330): No progress has been made at this time on the MCX reset due to wellwork operations being shut down for weather conditions on the North Slope. As we come back to normal operations, AGI -08 MCX change out will be a top priority job. An IA bleed was performed on 01/21/2012 and the well continues to exhibit slow IA repressurization. «AGI -08 TIO 01- 30- 12.doc» NGI -11 (PTD #1770800): Continue to monitor for thermal stabilization of the IA prior to progressing Leak Detect Log. «NGI -11 TIO 01- 30- 12.doc» AGI -05 (PTD #1930020): igpressure con mires to remain stable at 850 psi. Continue to monitor for IA repressurization. «AGI -05 TIO 01- 30- 12.doc» Please let me know if you have any questions or concerns. Thank you, Mehreen Vazir (Alternate Gerold Murphy) ) Well Integrity Coordinator Stv:MIN D FEB ;U,, 3 'L1J1 BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com From: AK, D &C Well Integri. oordinator Sent: Sunday, January , 2012 7:42 PM 1 • • PBU AGI -05 PTD # 1930020 1/30/2012 TIO Plot 4.00 • 3nro 4 I ! I - Tb 2 • . a 00► + WOO .a 1,000 11/15/11 11/12/11 11/19/11 11/2621 12/33,11 12/1411 1227/11 12/24.11 12/31/11 01/07/12 01/14/12 01/2122 01/2022 Injection Plot War - - 230000 3.300 -- •. mow : 320 3,100 � 210 000 3.000 200.000 218110✓ � \i v 90000 2,100 180/20 2600 2.900. 170140 4402 2.300 160,000 2200 15000 2100 140000 1 [ 130000 £ _ sw 1000- 110 OOO t.fi0' - w 100 11000 -OI -Ow 1,600 100.00 On 1.400 60 1300 1,200 W WO 1.100 1000 10030 9330 50,000 800 • 50000 910 603 4000 500 3 400' 300 0ON 2110: 10E00 100 11/95/11 1122/11 11119111 11 /26/11 12/93/11 122411 12/1221 12/24/11 12/3121 0160122 01/1422 01/21/12 01/28/12 • • t 3 Uoz, Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com]Q�� v3I Sent: Sunday, January 22, 2012 7:42 PM I 1 To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Daniel, Ryan; Vazir, Mehreen; Chivvis, Robert Subject: Gas Injector Status Update for AGI -08 (PTD #1930330), NGI -11 (PTD #1770800), and AGI -05 (PTD #1930020) Attachments: AGI -08 (PTD #1930330) well bore schemati ;; _Q8 330) TIO and Injection Plot.doc; NGI -11 TIO and Injection Data.xls GI -05 (PTD # 1930020) 10 and Injection Plot.doc Jim and Tom, I wanted to update you on the current status of 3 gas injectors that are either currently classified as Under Evaluation, AGI -08 and NGI -11, or we have been in communication about in the last month, AGI -05. AGI -08 (PTD #1930330) is awaiting the resetting of the MCX SSSV, which has been delayed due to weather conditions on the North Slope. The well is currently on injection, and has been showing slow TxIA communication with a rate of about 20 psi /day. The well has not exceed MOASP. The plan forward will be to change out the safety valve and monitor the IA pressure for continued build up. If continued pressure buildup is observed, a Leak Detect Log would be planned. Our plan forward would be to pursue an AA to allow for continued injection is a leak is not identified. «AGI -08 (PTD #1930330) well bore schematic.pdf» «AGI -08 (PTD # 1930330) TIO and Injection Plot.doc» NGI -11 (PTD #1770800) passed a witnessed (Matt Herrera) MIT -IA to 4200 psi with the well shut -in on 1/7/2012 but has continued to show erratic IA behavior after it was returned to injection, that appears to be thermally related as it reaches stabilization. An Excel plot is included which plots the last 3 months injection rate and temperature with the TIO plot for your review. An IA bleed performed on 1/16/2012 was recorded as all diesel. The plan forward will be to run a Leak Detect Log, then if nothing is identified, pursue an AA for the well. «NGI -11 TIO and Injection Data.xls» AGI -05 (PTD #1930020) is a well that had operated under an AA (4E.003) until it was cancelled in January, 2011 after not exhibiting IA repressurization for over a year. Shortly after the cancellation, the well began exhibiting intermittent slow IA repressurization. The well is currently not exhibiting IA repressurization since late December, as can be seen in the enclosed T10 and Injection plot. A rig workover is being planned for late 2012 to repair the well. Our plan forward is to pursue an AA since the rig workover is planned for late in 2012 to allow for continued injection until the RWO is completed. «AGI -05 (PTD # 1930020) TIO and Injection Plot.doc» All 3 wells will remain on the monthly injection reports. We are planning to continue to send weekly TIO and Injection plots to keep you informed on the status of these wells. Please call if you have any questions or concerns. r 'U1� Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 1 • • PBU AGI -05 PTD # 1930020 1/22/2012 TIO Pressures Plot Wet AGI -05 40�,)u 3,000 - ! 1 Tbg -f- IA -- 1000 1000 OA OOA j —. -- 000A On 1,000' r't.- . «...+`......m X 10/22111 11/05/11 11/19/11 12/03/11 12/17/11 12/31/11 01 /1 4112 Injection Plot WalAGI -05 - 3 410 - 7 20r - 220.000 2000 /�, i� V \ / -/--- - 200.000 2 „//�� V : 1,000 2500 2400 - 160.000 2200 2,W0 - 140,000 — SIP , Fa 1800 - 120,000 a - M ' 3 1500 � - GI - 100.000 — pMa 1.400 � en 1.200 - 00,000 1,100 -6000 000 40,000 400 - 20,00 20 10/22/11 10/29/11 11/05/11 11/12/11 11/19/11 11/26/11 12/03/11 12/10/11 12/17/11 12/24/11 12/31/11 01/07 /12 ' 01/14 /12 01/21/121 Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for Septem... Page 1 of 1 • • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] Sent: Tuesday, October 18, 2011 11:17 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); AK, D &C Well Integrity Coordinator Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for September 2011 Attachments: AOGCC Inj Report 10- 11.zip Tom, Jim, Phoebe, and Guy, Attached is the September 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. « AOGCC Inj Report 10- 11.zip» Notes on wells: Added to Report: A9 -22 (PTD #1831730): Under Evaluation for slow IAxOA repressurization. GI -05 (PTD #1930020aluation for slow IA repressunzatio Taken off Report: NS -27 (PTD #2010270): Removed after monitoring for 2 months for IA repressurization. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 10/18/2011 Well AGI -05 Injection Plot TIO Plot Well: AGI -05 ° Pressure vs. Rate o PTD # 1930020 0 . o 0 ✓ v Tbg • A AA for TxIA cancelled 01/03/11 o + 1•_ o I • OA -� o g Well Under Evaluation for IA co • ri repressurization rn a cm a o a o 0 o ° 0 O N N 0 I _ , ! r F • ♦ Last 90 days • Last Month o , , , ,- 0 0 50,000 100,000 150,000 200,000 250,000 5/12/11 8/2/11 10/23/11 Injection Rate, MCFPD • Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 10/01/11 183,005 3,252 10/01/11 3,392 750 25 09/30/11 185,478 3,246 09/30/11 3,392 700 25 09/29/11 192,342 3,308 09/29/11 3,392 700 25 09/28/11 191,121 3,305 09/28/11 3,392 700 25 09/27/11 189,263 3,295 09/27/11 3,392 660 60 09/26/11 187,546 3,283 09/26/11 3,255 650 60 09/25/11 189,086 3,282 09/25/11 3,255 620 40 09/24/11 173,194 3,260 09/24/11 3,362 600 40 09/23/11 14,820 2,694 09/23/11 0 980 20 09/22/11 10,684 3,315 09/22/11 0 600 20 09/21/11 0 3,318 09/21/11 0 600 20 09/20/11 0 3,315 09/20/11 0 600 20 09/19/11 132,627 3,280 09/19/11 3,262 600 40 09/18/11 178,373 3,231 09/18/11 3,247 500 50 09/17/11 180,584 3,249 09/17/11 3,247 1,750 100 09/16/11 177,858 3,233 09/16/11 3,210 1,680 100 09/15/11 180,176 3,252 09/15/11 3,247 1,650 100 • 09/14/11 191,691 3,314 09/14/11 3,322 1,600 100 09/13/11 179,485 3,253 09/12/11 3,245 1,580 200 09/12/11 174,687 3,242 09/11/11 3,232 1,440 100 09/11/11 173,908 3,237 09/10/11 3,232 1,420 50 09/10/11 183,019 3,260 09/08/11 3,285 1,300 50 09/09/11 188,830 3,276 09/07/11 3,232 1,250 50 09/08/11 186,870 3,273 09/06/11 3,232 1,150 50 09/07/11 183,454 3,266 09/05/11 3,232 1,100 50 09/06/11 182,659 3,263 09/04/11 3,232 1,050 50 09/05/11 181,193 3,255 09/03/11 3,232 950 20 09/04/11 178,119 3,231 09/02/11 3,232 950 20 09/03/11 181,522 3,251 09/01/11 3,232 800 50 09/02/11 187,562 3,272 08/30/11 3,232 700 80 09/01/11 182,911 3,256 08/29/11 3,232 600 100 Monthly Injection Report for GPB•PMA, Northstar, Milne Point & Endi, for March ... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] Sent: Sunday, April 03, 2011 8:00 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer; Engel, Harry R Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for March 2011 Attachments: AOGCC Inj Report 04- 11.zip Tom, Jim, Phoebe, and Guy, Attached is the March 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. « AOGCC Inj Report 04- 11.zip» Notes on wells: a .APR 1 8 2011 Added to Report: 03 -37: Added to evaluate TxIA communication while on water injection. The Well Integrity Coordinator will apply for an administrative approval pending IA repressurization. Taken off Report: AGI -05: Taken off report after slickline changed out the SSSV on 3/8/11 that mitigated the IA repressurization. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 4/18/2011 OPERABLE: Injector AGI -05 (PT, #1930020) IA Pressurization Mitigate. Page 1 of 2 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeII1ntegrityCoordinator @bp.com] Sent: Saturday, March 19, 2011 4:49 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Engel, Harry R; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Brooks, Phoebe L (DOA) Cc: AK, D &C Well Integrit 'natori Robert; Walker, Greg (D &C) Subject: OPERABLE: I jector AGI -05 (PTD #1930020) A Pressurization Mitigated Attachments: AGI -05 (PTD #1930020) TIO and Injection Plot.doc; AGI- 05.pdf; AGI -05 TIO & Injection Plot 03- 05- 11.doc All, Injector AGI -05 (PTD #1930020) has shown no signs of IA repressurization after treating the SSSV control lines with GX Sealant on 3/8/2011. The well has been reclassified as Operable. A copy of the TIO and Injection plot have been included for your reference. «AGI -05 (PTD #1930020) TIO and Injection Plot.doc» Please call if you have questions. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Saturday, March 05, 2011 7:43 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; "Schwartz, Guy (DOA'; AK, D &C Well Services Operations Team Lead; Engel, Harry R; 'Brooks, Phoebe L (DOA)'; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; Chiwis, Robert; King, Whitney Subject: UNDER EVALUATION: Injector AGI -05 (PTD #1930020) IA repressurization All, Injector AGI -05 (PTD #1930020) was shut -in on 01/08 for the TAPS pro- ration. After it was placed back on injection 01/22, there have been signs of IA repressurization as seen on the attached TIO plot. The last AOGCC MITIA passed on 09/20/10 proving two competent barriers. Therefore, the plan is to keep the well on injection, bleed the IA pressure and monitor the IA build -up -rate until slickline changes out the SSSV. The well has been reclassified as Under Evaluation. The plan forward is as follows: 4/18/2011 OPERABLE: Injector AGI -05 (P, #1930020) IA Pressurization Mitigate Page 2 of 2 1. DHD: Bleed and monitor IA BUR 2. Slickline: Troubleshoot SSSV, control and balance lines 3. WIC: Monitor TIO plot A wellbore schematic, TIO plot and injection plot have been included for your reference. «AGI- 05.pdf» «AGI -05 TIO & Injection Plot 03- 05- 11.doc» Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 AGI -05 (PTD #1930020) TIO Plot Wee:ACI - 05 4,0i: J.1 3.0 i0 - Tbg IA --A OA MOO OOA �- 000A On 1.033 `l�fly 01/22/11 01.'29/11 02/95/11 02/12/11 02/19/11 02.'?6 /11 02/05/11 03/12/11 03/10/11 1 AGI -05 (PTD #1930020) Injection Plot W.1I.AGI-05 1 241. x;31 �� ✓"` –, 2 J!;; ] 'ria 2,630 1' 10 2. ?00 tC55 i — WHIP 2: a 2,0.3 1'2001 - -5W PW 1.1 tYI.CL 3 _ GI 1.130 409 100.0(0 b' — °tn. 1 X0,000 ^30 P "),111 If0 c4 ••In • 2: 01/12/11 02!0.0/11 0^112111 - - 61/111 - - - - � 122,'11 9.':0` , 02,11.1, r 0727/11 Monthly Injection Report for GPBGPMA, Northstar, Milne Point & Endi,for Februa... Page 1 of 2 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator@bp.com] Sent: Monday, March 07, 2011 9:26 AM To: Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA) Cc: AK, D &C Well Integrity Coordinator; Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for February 2011 Attachments: AOGCC Inj Report 03- 11.zip Tom, There was a bug in the initial Monthly Injection Report that didn't identify all the wells. The bug has been fixed; please use this report for your records. Notes on wells: Added to Report: W -03A: Added to report due to sustained casing pressure on the IA noted 2/17/11, currently performing diagnostics. AGI -05: Added to report due to IA repressurization post TAPS shutdown. k Cv-2,- 0 0 Taken off Report: S -101: Taken off report due to a failing MITIA. Added to the Quarterly Not Operable Report. Thank you, Torin Roschinger (alt. Jerry Murphy) AtiMED Well Integrity Coordinator MAR 0 9 2Q Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, March 07, 2011 9:09 AM To: AK, D &C Well Integrity Coordinator Subject: RE: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for February 2011 Torin, I have just started to review the list. In the message, you list W -03 as being added. Should that be W -03A? Also, when I look at the spreadsheet I do not find W -03 or W -03A included. Could you check into this ?? Thanks in advance, Tom Maunder, PE AOGCC From: AK, D &C Well Integrity Coordinator [mailto: AKDCWeIIIntegrityCoordinator @ bp.com] Sent: Sunday, March 06, 2011 11:59 AM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L 3/7/2011 Monthly Injection Report for GPBoPMA, Northstar, Milne Point & Endi,for Februa... Page 2 of 2 (DOA); Brooks, Phoebe L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer; Engel, Harry R Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for February 2011 Tom, Jim, Phoebe, and Guy, Attached is the February 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. «AOGCC Inj Report 03- 11.zip» Notes on wells: Added to Report: W -03: Added to report due to sustained casing pressure on the IA noted 2/17/11, currently performing diagnostics. AGI -05: Added to report due to IA repressurization post TAPS shutdown. Taken off Report: S -101: Taken off report due to a failing MITIA. Added to the Quarterly Not Operable Report. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 3/7/2011 Well AGI -05 Injection Plot TIO Plot Slow IA repressurization post °o Pressure vs. Rate o TAPS shut -down. The plan q - o forward is to change out the v Tbg IA SSSV and monitor the IA for o o OA f ""fir repressurization 0 0 M co a = a o AA for TxIA cancelled 01/03/11 = N I N ^' o o o o o V_ cl • Last 90 days • Last Month 0 50,000 100,000 150,000 200,000 250,000 300,000 9/8/10 11/29/10 2/19/11 5/12/11 Injection Rate, MCFPD • Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 03/01/11 209,691 3,301 03/01/11 3,315 1,350 20 02/28/11 224,383 3,367 02/28/11 3,315 1,280 20 02/27/11 234,355 3,384 02/27/11 3,315 1,200 20 02/26/11 217,387 3,285 02/26/11 3,315 1,140 20 02/25/11 196,369 3,246 02/23/11 3,315 1,460 100 02/24/11 190,670 3,307 02/22/11 3,315 1,100 20 02/23/11 204,144 3,340 02/21/11 3,315 1,200 40 02/22/11 239,294 3,437 02/20/11 3,315 1,100 40 02/21/11 243,693 3,509 02/19/11 3,315 1,020 20 02/20/11 240,577 3,462 02/18/11 3,315 1,180 80 02/19/11 225,749 3,381 02/17/11 3,315 960 40 02/18/11 210,012 3,345 02/15/11 3,315 940 20 02/17/11 209,946 3,322 02/13/11 3,315 900 20 02/16/11 220,128 3,316 02/11/11 3,315 880 20 02/15/11 221,652 3,320 02/10/11 3,315 920 20 02/14/11 241,387 3,444 02/09/11 3,375 1,000 50 • 02/13/11 222,247 3,293 02/08/11 3,382 900 20 02/12/11 224,034 3,270 02/07/11 3,322 900 20 02/11/11 218,651 3,244 02/06/11 3,230 820 20 02/10/11 219,784 3,317 02/05/11 3,207 950 100 02/09/11 220,007 3,377 02/04/11 3,207 850 50 02/08/11 224,992 3,379 02/03/11 3,207 800 50 02/07/11 219,993 3,328 02/02/11 3,207 800 50 02/06/11 224,785 3,327 02/01/11 3,292 800 50 02/05/11 219,452 3,366 01/31/11 3,337 800 80 02/04/11 219,156 3,346 01/30/11 3,337 900 80 02/03/11 209,964 3,290 01/29/11 3,337 740 20 02/02/11 209,658 3,310 01/28/11 3,390 740 20 02/01/11 207,639 3,288 01/27/11 3,330 740 20 01/31/11 214,799 3,340 01/26/11 3,330 740 200 01/30/11 209,983 3,341 01/25/11 3,330 640 150 UNDER EVALUATION: Injecto.I -05 (PTD #1930020) IA repressurizSn Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWelIIntegrityCoordinator @bp.com] Sent: Saturday, March 05, 2011 7:43 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; Schwartz, Guy L (DOA); AK, D &C Well Services Operations Team Lead; Engel, Harry R; Brooks, Phoebe L (DOA); AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; Chivvis, Robert; King, Whitney Subject: UNDER EVALUATION: Injector AGI -05 (PTD #1930020) IA repressurization Attachments: AGI- 05.pdf; AGI -05 TIO & Injection Plot 03- 05- 11.doc All, Injector AGI -05 (PTD #1930020) was shut -in on 01/08 for the TAPS pro- ration. After it was placed back on injection 01/22, there have been signs of IA repressurization as seen on the attached TIO plot. The last AOGCC MITIA passed on 09/20/10 proving two competent barriers. Therefore, the plan is to keep the well on injection, bleed the IA pressure and monitor the IA build -up -rate until slickline changes out the SSSV. The well has been reclassified as Under Evaluation. The plan forward is as follows: 1. DHD: Bleed and monitor IA BUR L D MAR : ( 2 011 2. Slickline: Troubleshoot SSSV, control and balance lines 3. WIC: Monitor TIO plot A wellbore schematic, TIO plot and injection plot have been included for your reference. «AGI- 05.pdf» «AGI -05 TIO & Injection Plot 03- 05- 11.doc» Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 3/7/2011 S • AGI -05 TIO Plot Wet Afil-05 • • 4.000 ',.. 3,000 — - Tbg --- IA �-- OA 2.000 - OOA --A— 0005 On 1.000 • 12/11/10 12/18/10 122510 01/01/11 01/08/11 01/15/11 01/22/11 01/29/11 02/05/11 02/12/11 02/19/11 02/25/11 03/05/11 The IA pressure decrease on 2/24 was due to a lower injection rate, the IA pressure was not bled. AGI -05 Injection Plot Welk/481.05 • 3.600 - ` : 240,000 3.400 . ' 41"". , ice r � - 220.000 • 3,200 - 3.000 - - 200.000 2,800 - - 180.000 • 2,600 • 2,400 - 160.000 2,200 - — WHIP 2.000 - = 140.000 — SW pW 1.000 - - 120,000 s — MI 1.000 - q — O1 - 100,000 $ — 081s 1.400 - On 1.200 - - 80.000 1,000 - 60.000 800 - soo - 40.000 400 - 20.000 • • 200 - 12/11/10 12/18/10 12/25/10 01/01/11 01/06/11 01/15/11 01/22/11 01/29/11 02/05/11 02/12/11 02/19/11 02/26/11 03/05,11 • • Well AGI -05 Injection Plot TIO Plot Slow IA repressurization post O Pressure vs. Rate o TAPS shut -down. The plan o ° o forward is to change out the 4. v Tbg IA SSSV and monitor the IA for o • �� 0 OA repressurization 0 0 0 0 M 0,-) m O a O 0 o ° g __ AA for TxIA cancelled 01/03/11 N N II O O 1 O O O • Last 90 days • Last Month o 0 0 50,000 100,000 150,000 200,000 250,000 300,000 9/8/10 11/29/10 2/19/11 5/12/11 Injection Rate, MCFPD Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 03/01/11 209,691 3,301 03/01/11 3,315 1,350 20 02/28/11 224,383 3,367 02/28/11 3,315 1,280 20 02/27/11 234,355 3,384 02/27/11 3,315 1,200 20 • 02/26/11 217,387 3,285 02/26/11 3,315 1 ,140 20 02/25/11 196,369 3,246 02/23/11 3,315 1,460 100 02/24/11 190,670 3,307 02/22/11 3,315 1,100 20 02/23/11 204,144 3,340 02/21/11 3,315 1,200 40 02/22/11 239,294 3,437 02/20/11 3,315 1,100 40 02/21/11 243,693 3,509 02/19/11 3,315 1,020 20 02/20/11 240,577 3,462 02/18/11 3,315 1,180 80 02/19/11 225,749 3,381 02/17/11 3,315 960 40 02/18/11 210,012 3,345 02/15/11 3,315 940 20 02/17/11 209,946 3,322 02/13/11 3,315 900 20 02/16/11 220,128 3,316 02/11/11 3,315 880 20 02/15/11 221,652 3,320 02/10/11 3,315 920 20 02/14/11 241,387 3,444 02/09/11 3,375 1,000 50 02/13/11 222,247 3,293 02/08/11 3,382 900 20 02/12/11 224,034 3,270 02/07/11 3,322 900 20 02/11/11 218,651 3,244 02/06/11 3,230 820 20 I • 0 s r Li f r ' Fil ( , a i — _ SEAN PARNELL, GOVERNOR )J T. L 1 U � t ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION i ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279-1433 P FAX (907) 276 -7542 CANCELLATION ADMINISTRATIVE APPROVAL NO. AIO 4E.003 Mr. Doug Cismoski, P.E., Wells Intervention Manager Attention: Well Integrity Engineer, ,. i ,Ii �"��' BP Exploration (Alaska) Inc. sA .'- 6 P.O. Box 196612 Anchorage, AK 99519 -6612 RE: Cancellation of Administrative Approval AIO 4E.003 (Well PBU AGI -05) Dear Mr. Cismoski: Pursuant to BP Exploration (Alaska) Inc. (BPXA)'s request dated December 16, 2010, the Alaska Oil and Gas Conservation Commission (Commission) hereby cancels Administrative Approval AIO 4E.003, which allows continued gas injection in Prudhoe Bay Unit ( "PBU ") well AGI -05. This well exhibited inner annulus repressurization that could be safely managed with periodic pressure bleeds and BPXA did not at the time propose repairing the well to eliminate the problem. The Commission determined that gas injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. No IA repressurization has been evident since replacement and successful testing of the sub - surface safety valve on January 22, 2010. The well successfully passed an MIT -IA on September 20, 2010. Consequently, Administrative Approval AIO 4E.003 no longer applies to operation of this well. Instead, injection into PBU AGI -05 will be governed by provisions of the underlying AIO No. 4E. �4 ��$p DONE at Anchorage, Alaska and dated January 3, 2011. c, "fit' The Alaska Oil and G y nservation Commission 4 w r Y . iir 0,i4t-i-i-' � G � � e7` Daniel T. Seamount, . . Norman. Cathy. Foerster Commissioner, Chair Co ,'ssioner Commissioner • • �J\ bp BP ExpioraMion (Alaska) Ins. DEC 7 '7 U10 0 Attn: Weil integrity Coordinator, PRB-20 Post Office Box 196012 Anchorage, Alaska 99519 -4012 4 (A R% i3orrriligOen Anthoroe December 10, 2010 Mr. Daniel Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit Well AGI-05 (PTD #1930020) Application for Cancellation of AIO Administrative Approval 4E.003 Dear Mr. Seamount, BP Exploration (Alaska) Inc. requests cancellation of Administrative Approval number 4E.003 dated May 31, 2006. The administrative approval was for continued gas injection into Well AGI-05 with slow tubing by inner annulus communication. A subsurface safety valve was set January 22, 2010 to reduce the tubing by inner annulus communication. However, since the subsurface safety valve was set there has been no further evidence of tubing by inner annulus communication. An AOGCC witnessed MITIA passed to 4300 psi on September 20, 2010. Therefore, if is requested to cancel Administrative Approval number 4E.003 for gas injection. A plot of wellhead pressures has been included for reference. If you require any additional information, please contact me at 554 -4303 or Gerald Murphy / Twin Roschinger at 659.5102. Sincerely, Dougl A. Clsmosd, P.E. BPXA Wens Intervention Manager • Attachments: TIO Plot Wellbore Schematic Cc: Doug Cismoski Steve Rossberg Bixby /Liddelow Murphy /Roschinger Flow Station 1 Operations Team Leader Bob Chiwis Harry Engel , • • • AGI -05 (PTD #1930020) TIO Plot WA MINI 1.000 . .. . 1 .,.„..„...r.„..„.„,..,j,,, .1.1- _1 , i 1 3.000 - -- Tb9 f a —r— OA 2,000 • 00A --.— 000A /1 j , .rr. On 4 1.000 1229/09 01/29/10 03/01/10 01/0110 05/02110 06/02/10 07/03/10 08/03/10 09/03/10 10/01/10 11/04 /10 12/05/10 1 • • *MAIM BAKER A '• , ALL Gtti PC Wf NNN$CCTlR$AD. KB. ar . 49 !OP* 1061 Mum ND* 10E36 OWeaTVO® 600D' t3..Y6 -t1lr . b ■ KdS Da 12,!18' - CS0 ra.. LAD, 0. t2,36r H 385, 1 'Minimum ID* 4•A$5" 9127` I 'ice �� • 5 -112' GAS XN NIPPLE G` rx:. , : r, ra t r i4D.$p Ott, VC e ta- gow ,.y r 114' : 9.12V f ' 1111...E 'S.0 f'+. 1. .iTC f - . 0. &lir sic, 1*1. 10-C" PRIM .O2'itp1.ID• $t 'p `" 6. }; 1Ct .4A9r 9 axe 46, . M;,o•e• - -i aza 1 Iti PORPORATiOrteudiddoir RV LOG: IPI S AWA ON 04I2093 AtGtE.A'T TOP!: 13 .9816 tq6: Rifer b *adman tai for tiltarlcat data 6 td 0 61 3-3'r 6 S73-10113 0 6M1613 3416 6 11606 -8628 0 6W13161 3.36 6 166- 8866 0 61 3•39" 6 9130.9180 0 6113163 two v L ' ►6t 1 , r 6. Steal NAY MIT .:: 1 9 •• ,{. : MIN we ACi0e r 7:77 1 FT r * * * -- 1111.111111 111111111 MI= 11111111.1111•1111111111111 Four Pike 1930020 i VA ?AA !,S ° ,.JUL:;.- 7. i i I AP1t�e 7•oo 571111 i?i ij � j�,yKt Ar7t � NMI 1wi.It1atta Sora.49tIlDm 1.1-31LA 111111111111111111111111111111111111111111111111111111.1 ' ., to : AM ,444a14,—.1.k.A14,11111111 OP Itgdwidlon (Altdka) UNDER EVALUATION: Gas Inje r AGI -05 (PTD #1930020) For AOG MIT -IA Page 1 oft Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @bp.com] Sent: Monday, September 20, 2010 2:16 PM To: Maunder, Thomas E (DOA) Cc: AK, D &C Well Integrity Coordinator Subject: RE: UNDER EVALUATION: Gas Injector AGI -05 (PTD #1930020) For AOGCC MIT -IA Tom, I mentioned that we were planning to complete this state witnessed test along with a few others when we talked. This was the only one we were not able to complete over the weekend. To test this well above the maximum anticipated injection pressure as per the Administrative Approval, we needed to have a plug set in the well. We were not able to get a tubing tail plug set and pressure tested in time for yesterday. Today the plug was set and the well passed its state witnessed MIT -IA to 4300 psi. As per our conversation about NK -13, I reclassified it until the testing was complete to keep it in compliance. The well passed its state MIT -IA this morning, so I will be reclassifying as Operable. Sorry for any confusion. Please contact Well Integrity with any questions or concerns. Thank you, 414rumituMAR . 0 2011 Tiffany Quy (for the Well Integrity Coordinator Torin Roschinger /Gerald Murphy) Projects Well Integrity Engineer phone: (907) 659 -5102 AKDCWeIIlntegrityCoordinator @bp.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, September 20, 2010 8:12 AM To: AK, D &C Well Integrity Coordinator Cc: Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: RE: UNDER EVALUATION: Gas Injector AGI -05 (PTD #1930020) For AOGCC MIT -IA Tiffany, What are the "operational constraints "? Did we talk about this well? Tom Maunder, PE AOGCC FrOm:.AK, D &C Well Integrity Coordinator [mailto :AKDCWeIIlntegrityCoordinator @b• •m] Sent: Sun•. eptember 19, 2010 8:54 PM To: Regg, James : • ; Maunder, Thomas E (DOA); AK, OPS FS1 OS , K, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; Cismoski, : - e A; AK, D &C Wireline Operations - • m Lead; Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); AK, D &C Well Sery • .erations Team Le- ngel, Harry R Cc: Chiwis, Robert; King, Whitney; Holt, Rya • 'SR Subject: UNDER EVALUATION: Gas Injector AG -e " 1 #1930020) For AOGCC MIT -IA All, Gas Injector AG (PTD #1930020) has been reclassified as Under Evaluation. Due to operationa sstraints, the well ha •t completed the four year AOGCC MIT -IA due 09/19/10. The well will be reclassified pendin. state nessed MIT -IA. 3/7/2011 UNDER EVALUATION: Gas Inj. AGI -05 (PTD #1930020) For AOG IT -IA Page 1 of 1 Maunder, Thomas E (DOA) From: Quy, Tiffany [Tiffany.Quy @bp.com] Sent: Sunday, September 19, 2010 8:13 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); AK, D &C Well Services Operations Team Lead; Engel, Harry R Cc: Chivvis, Robert; King, Whitney; Holt, Ryan P (ASRC) Subject: UNDER EVALUATION: Gas Injector AGI -05 (PTD #1930020) For AOGCC MIT -IA All, Gas Injector AGI -05 (PTD #1930020) has been reclassified as Under Evaluation. Due to operational constraints, the well has not completed the four year AOGCC MIT -IA due 09/19/10. The well will be reclassified pending a state witnessed MIT -IA. Please contact Well Integrity with any questions or concerns. Thank you, Tiffany Quy (for the Well Integrity Coordinator Torin Roschinger /Gerald Murphy) Projects Well Integrity Engineer phone: (907) 659 -5102 AKDCWeII1ntegrityCoordinator @ bp.com 3/7/2011 OPERABLE: AGI -05 (PTD #193.0) IA repressurization slowed post SS,changeout Page 1 of 2 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWelllntegrityEngineer @BP.com] Sent: Tuesday, February 02, 2010 5:37 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA); GPB, FS1 DS Ops Lead; GPB, FS1 OTL; GPB, Area Mgr East (FS1 /2 /COTU /Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Sinyangwe, Nathan; Williams, Carrie; NSU, ADW Well Integrity Engineer Subject: OPERABLE: AGI -05 (PTD #1930020) IA repressurization slowed post SSSV changeout Attachments: AGI- 05.pdf; AGI -05 AA 4E.003 TJ 05- 31- 06.pdf; AGI -05 TIO Plot 02- 02- 10.doc All, Well AGI -05 (PTD #1930020) had its SSSV changed out on 01/22/10 after IA repressurization was noticed. The TIO plot attached shows that after a 10 day monitor the TxIA communication has slowed and is now in compliance with Administrative Approval 4E.003. The well has been reclassified as Operable, however, if the well needs to be bled in the future please contact Well Integrity. A wellbore schematic administrative approval and TIO plot have been included for your reference. «AGI- 05.pdf» «AGI -05 AA 4E.003 TJ 05- 31- 06.pdf» «AGI -05 TIO Plot 02- 02- 10.doc» Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) MAR 1 0 2011 Well Integrity Coordinator Office (907) 659 -5102 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer Sent: Thursday, January 14, 2010 7:58 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy L (DOA)'; GPB, FS1 DS Ops Lead; GPB, FS1 OTL; GPB, Area Mgr East (FS1 /2 /COTU /Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Quy, Tiffany; NSU, ADW WL & Completion Supervisor; NSU, ADW Wells Slickline Scheduler; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: AGI -05 (PTD #1930020) Increased rate of IA repressurization Hi all, Well AGI -05 (PTD #1930020) is approved for continued operation with IA repressurization under AOGCC AIO4E.003. Although the well is approved with a repressurization rate of approximately 25 psi /day, the IA pressure is more manageable when the SSSV is reset. Recently the rate of repressurization has increased. Therefore the well has been reclassified as Under Evaluation to pull and reset the SSSV and to monitor the 3/7/2011 OPERABLE: AGI -05 (PTD #193.0) IA repressurization slowed post SSOchangeout Page 2 of 2 wellhead pressures. The well may remain on injection with this work is being done. The plan forward for the well is as follows: 1. Slickline: Pull and reset SSSV 2. DHD: Monitor wellhead pressures A TIO plot and wellbore schematic have been included for reference. Please call with any questions. Thank you, Anna Es u6e, E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659 -5102 Pager: (907) 659 -5100 x1154 3/7/2011 • • AGI -05 (PTD# 1930020) 4.000 3 000 - Tbg - IA 2.000 "a— Q4 ODA — 4-- 000A On 1.000 .r- 11/07/09 11/14109 11/21/09 11/28/09 12/05/09 12/12/09 12/19/09 12/26/09 01/02/10 01/09/10 01/16/10 01/23/10 01/30/10 UNDER EVALUATION:. AGI-O~PTD #1930020) Increased rate of IA r~essurization Page 1 of 2 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comJ Sent: Tuesday, January 19, 2010 6:53 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Integrity Engineer; NSU, ADW Well Operations Supervisor; Roschinger, Torin T.; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 DS Ops Lead; GPB, FS1 DS Ops Lead Subject: RE: UNDER EVALUATION: AGI-05 (PTD #1930020) Increased rate of IA repressurization Hi Tom, Thank you for our discussion earlier today. We appreciate the reasonable approach of monitoring the pressures for a few days after the second bleed in a 30-day period to confirm an increased trend before sending notification. This will allow for confirming that the increased rate of repressurization is not due to an increase in injection rate. To heighten awareness of bleeds on the gas pad injectors, I will speak with Operations and place a reminder at the consoles where pressure readings are entered into the database. Operators are consistently entering bleed information that is included in auto-generated reports sent to the Well Integrity Engineers. The intent of this reminder for Operators to call the Well Integrity Coordinator will help heighten awareness of the pressure activity on these wells. Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 .~~~ ~~~~ ~ ~ zap From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, January 18, 2010 3:00 PM To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Schwartz, Guy L (DOA); GPB, FS1 DS Ops Lead; GPB, FS1 OTL; GPB, Area Mgr East (FS1/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Quy, Tiffany; NSU, ADW WL & Completion Supervisor; NSU, ADW Wells Slickline Scheduler Subject: RE: UNDER EVALUATION: AGI-05 (PTD #1930020) Increased rate of IA repressurization Anna, Based on the TIO plot, it appears that this notice looks to be late. The bleed frequency becomes more frequent beginning in early December. It would seem that your notice should have been made about mid-December after a couple of bleeds. A10 4E.03 says - BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition. In practice, requiring an injection well with known SSSV issues to be SI is unlikely however timely notice of the change in the well (as evidenced by the increased bleed frequency) needs to be made. Tom Maunder, PE AOGCC From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Thursday, January 14, 2010 7:58 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); GPB, FS1 DS Ops Lead; GPB, FS1 OTL; GPB, Area Mgr East (FS1/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr 1/21/2010 UNDER EVALUATION: AGI-PTD #1930020) Increased rate of IA r~essurization Page 2 of 2 Cc: Quy, Tiffany; NSU, ADW WL & Completion Supervisor; NSU, ADW Wells Slickline Scheduler; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: AGI-05 (PTD #1930020) Increased rate of IA repressurization Hi all, Well AGI-05 (PTD #1930020) is approved for continued operation with IA repressurization under AOGCC A104E.003. Although the well is approved with a repressurization rate of approximately 25 psi/day, the IA pressure is more manageable when the SSSV is reset. Recently the rate of repressurization has increased. Therefore the well has been reclassified as Under Evaluation to pull and reset the SSSV and to monitor the wellhead pressures. The well may remain on injection with this work is being done. The plan forward for the well is as follows: 1. Slickline: Pull and reset SSSV 2. DHD: Monitor wellhead pressures A TIO plot and wellbore schematic have been included for reference. «AGI-05.pdf» «AGI-05 TIO plot.doc» Please call with any questions. Thank you, Anna ~Du6e, ~? E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 1 /21 /2010 TREE = CNV WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = __ 49' BF. ELEV __ KOP = 1051' Max Angle = 38 @ 6982' Datum MD = 10239' Datum TV D = 8800' SS ~ AGI-05 13-3/8" CSG, 68#, K-55, ID = 12.415" ~~ 79~ 13-3/8" CSG, 72#, L-80, ID = 12.347" 3858' Minimum ID = 4.455" @ 9127' 5-1/2" OTIS XN NIPPLE 7" TBG, 26#, NT-80-S-IPC, NSCC, .0383 bpf, ID = 6.276" 90$4' TOP OF 5-1/2" TBG 90$4 I NOTES: LINER NOT CEMENTED. ALL TBG IS IPC W ITH NSCC THREAD. 2219' 1~7" CAMCO BAL-O SSSV NIP, ID= 5.937" 9075' ANCHOR 907907-6~ 9-5/8" X 7" BAKER SB-3A PKR, ID = 6.000" 90$4' ~-~ 7" X 5-1 /2" XO, ID = 4.812" ~ 5-1/2" PARKER SWS NIP, ID = 4.562" ~ OF 7" LNR ~~ 9126' 9127 ~~5-1/2" OTIS XN NO-GO NIP, ID = 4.455" ~ 5-1/2" TBG, 17#, L-80-IPC, NSCC, .0232 bpf, ID = 4.892" ~~ 9139' 9-5/8" CSG, 47#, NT-80-S, ID = 8.681" ~~ 9323 PERFORATION SUMMARY REF LOG: BHCS AWA ON 04/20/93 ANGLE AT TOP PERF: 15 @ 9516' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9516 - 9546 O 6/13/93 3-3/8" 6 9573 - 9583 O 6/13/93 3-3/8" 6 9606 - 9626 O 6/13/93 3-3/8" 6 9668 - 9688 O 6/13/93 3-3/8" 6 9730 - 9750 O 6/13/93 PBTD 9$01' 7" LNR, 29#, NT-80-S, .0371 bpf, ID = 6.184" 9$22' 9 139' 115-1/2" WLEG, ID = 4.892" I 9135 ELMD TT LOGGED 05/10/93 DATE REV BY COMMENTS DATE REV BY COMMENTS 02/02/93 ORIGINAL COMPLETION 02/15/08 ??/TLH TTP PULLED (09/20/06) 05/22/01 RN/KAK CORRECTIONS 03/13/03 AS/TP ADD IPC/THREAD FOR TBG 05/12/03 JRC/KK ADD 13-3/8", 68# CSG 08/11/04 WRR/TLP TREE, WELLHEAD CHANGES 09/21/06 CJN/TLH PXN TTP SET (09/14/06) PRUDHOE BAY UNff WELL: AGF05 PERMff No: 1930020 API No: 50-029-22327-00 SEC 36, T12N, R14E, 2879.13' FEL & 2680.08' FNL BP Exploration (Alaska) AGI-05 (PTD #1930020) TIO Plot d.DOo 3,000 2,000 1,000 f Tbg ~- to ~- OA DDA • OOOA On OPERABLE: AGI-OS (PTD #0020) IA repressurization Minimized • Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~ `r Sent: Thursday, October 16, 2008 4:03 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, FS1 DS Ops Lead; GPB, FS1 OTL; GPB, Area Mgr East (FS1/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Winslow, Jack L.; Randall, Jaclyn S; NSU, ADW WL & Completion Supervisor; NSU, ADW Well Integrity Engineer Subject: OPERABLE: AGI-05 (PTD #1930020) IA repressurization Minimized Attachments: AGI-5 TIO Plot.doc ~ ~-~v~ All, The SSSV was changed out on well AGI-05 (PTD #1930020) on 10/10/08. The well was returned to gas injection and the IA pressure was bled. The well has been monitored for several days to determine the success of the SSSV change out. As seen in the attached TIO plot, the IA repressurization has been minimal since it was bleed on 10/10108. The well has been classified as Operable to continue operation under AIO 4E.003. «AGI-5 TIO Plot.doc» Please call with any questions or concerns. Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer ~{ {~~r ~ Jr) ~ pt, /" Sent: Sunday, October 05, 2008 7:21 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, FSl DS Ops Lead; GPB, FSi OTL; GPB, Area Mgr East (FSl/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer; Wellman, Taylor T; Randall, Jaclyn S; NSU, ADW WL & Completion Supervisor; NSU, ADW Wells Slickline Scheduler Subject: UNDER EVALUATION: AGI-05 (PTD #1930020) Increased rate of IA repressurization '~ Hi all, :~ Well AGI-05 (PTD #1930020) is approved for continued operation with IA repress_yC~_rization under AOGCC A104E.003. Although the well is approved with a repressurization rate of approximately 25 psi/day, the IA pressure remains low when the SSSV is reset. Recently the rate of repressurization has increased. Therefore the well has been reclassified as Under Evaluation to pull and reset the SSSV and to monitor the wellhead pressures. The well may remain on injection with this work is being done. The plan forward for the well is as follows: 4/16/2009 OPERABLE: AGI-OS (PTD #0020) IA repressurization Minimized • Page 2 of 2 1. Slickline: Pull and reset SSSV 2, DHD: Monitor wellhead pressures A TIO plot and wellbore schematic have been included for reference. Please call with any questions. Thank you, Anna ~Du6e, P E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 4/ 16/2009 PBU AGI-OS PTD 193-002 10/16/2008 T10 Plot • PBU AGI-05 PTD 193-002 10/5/2008 TIO Pressures • TREE = CM/ WELLHEAD = FMC ACTUATOR= BAKERC KB. ELEV - - BF. ELEV = _ 49' ~_ KOP = 1051' Max Angle = 38 @ 6982' Datum MD = 10239' Datum TVD = 8800' SS L 13-3/8" CSG, 68#, K-55, ID = 12.415" ~-~ 79' 13-3/8" CSG, 72#, L-80, ID = 12.347" 3858' Minimum ID = 4.455" @ 9127' 5-1 /2" OTIS XN NIPPLE 7" TBG, 26#, NT-80-S-IPC, NSCC, .0383 bpf, ID = 6.276" 9084' TOP OF 5-1/2" TBG 90$4' A G 1 0 5 ~Y NOTES: LINER NOT CEMENTED. ALL TBG IS IPC W ITH NSCC THREAD. 2219' 7" CAMCO BAL-O SSSV NIP, ID = 5.937" 9075' ANCHOR 9076' 9-518" X 7" BAKER SB-3A PKR, ID = 6.000" 90$4' ~~ 7" X 5-1 /2" XO, ID = 4.812" 9106' ~~ 5-1/2" PARKER SWS NIP, ID = 4.562" OF 7" LNR ~'~ 9126' 27' ~~ 5-1 /2" OTIS XN NO-GO NIP, ID = 4.455" 5-1 /2" TBG, 17#, L-80-IPC, NSCC, .0232 bpf, ID = 4.892" ~~ 9139' 9-5/8" CSG, 47#, NT-80-S, ID = 8.681" ~~ 9323' PERFORATION SUMMARY REF LOG: BHCS AWA ON 04/20/93 ANGLE AT TOP PERF: 15 @ 9516' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9516 - 9546 0 6/13/93 3-3/8" 6 9573 - 9583 O 6/13/93 3-3/8" 6 9606 - 9626 O 6/13/93 3-318" 6 9668 - 9688 O 6/13/93 3-3/8" 6 9730 - 9750 O 6/13/93 PBTD 9$01' 7" LNR, 29#, NT-80-S, .0371 bpf, ID = 6.184" 9$22' 9139' -~ 5-1 /2" WLEG, ID = 4.892" 9135' ELMD TT LOGGED 05/10/93 DATE REV BY COMMENTS DATE REV BY COMMENTS 02/02/93 ORIGINAL COMPLETION 02/15/08 ??/TLH TTP PULLED (09/20/06) 05/22/01 RN/KAK CORRECTIONS 03/13/03 AS/TP ADD IPC/THREAD FOR TBG 05/12/03 JRC/KK ADD 13-3/8", 68# CSG 08/11!04 WRR/TLP TREE, WELLHEAD CHANGES 09/21/06 CJN/TLH PXN TTP SET (09/14/06) PRUDHOE BAY UNfT WELL: AGI-05 PERMff No: 1930020 API No: 50-029-22327-00 SEC 36, T12N, R14E, 2879.13' FEL & 2680.08' FNL BP Exploration (Alaska) MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Reaa'~ 00. i(" FrO," P.I. Supervisor I " '- '() /' (' ; " -r ZZACG ", I DATE: Wednesday, September 20,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC AGI-05 PRUDHOE BA Y UNIT AGI-05 ~OD?I' \~ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv 1f3ï2- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT AGI-05 Insp Num: mitCS0609I9113929 ReI Insp Num Permit Number: 193-002-0 Inspector Name: Chuck Scheve Inspection Date: 9/19/2006 API Well Number 50-029-22327-00-00 Packer Depth 7771 ! ... I 1942.75 Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wcli- i AGI-05 ¡Type Inj. i N i TVD IA I 400 ¡ 4320 4290 I 4280 ' ~ i .!:!:.! 1930020 ITypeTest i SPT I Test psi ___ I OA: 60 : 60 I 60 I 60 i :_ .1!lterval OTHER P/F P Tubing I 2240 2330 I 2330 I 2330 i~_~_ Notes Well has slow tubing x 1A communication while on gas injection. A plug had been set in the tubing tail and 2200 psi applied, the IA was then pressured up to 4300 psi verifying casing integrity. ((1t: ~;:'{ D ') ,..JJ3T2- q /zz/ ¿Ii.;; ,i\ .1,.,' ~. \" '" ,ft(\.jVl; vl, Ù"j.) ?'(.~ ,j*, ¡ì{JÑ)'!'" I,. ¡J \¡f-1 /....-,(... ''¡'''V-'- &À:.s.o 42. DO 3 .ì;; /.' ( ,. , ;'P5 "7 ,,'''I: \-)' ,L\:1T:ï=tÎ- e!.JttL( .:::1 Lf p~ s ; I '0 t~.'1/>l<.Í\U\U:::;. '1'1 CE P G). 'ì ?f!Pf \JW¥ViP¡c.¡iJ- ;;; ~ . -.' {~~ k G.i.U·,)lJ Wednesday, September 20, 2006 Page I of I • C®1~TS~It~~~®~{T C®1~II~SI®l0T Ad9~1INISTRAT'IVE APPR®VAI. 4E.003 iV1r. Steve Rossberg wells Manager BP Exploration (_Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage, AK 995 1 9-66 1 2 333 W. T" AVENUE. SUITE 700 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~~r~~~~~ ~aN ~ ~ ?oar RE: PBU AGI-OS (PTD 193-002) Request for Administrative Approval Dear Mr. Rossberg: Pursuant to Rule 9 of Area Injection Order (`'AIO") 04E.000, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA"}'s request for administrative approval to continue gas injection in the subject well. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU AGI-O5. The Commission further finds that the well demonstrates IA repressurization of about 25 psi per day, that car. be safely managed with periodic pressure bleeds. How- ever, the Commission acknowledges that events such as SSSV control line failures may allow the well's tubing pressure to communicate with the La. Accordingly, the Commis- sion believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety, if the well's operation is subject to the con- straints enumerated below. AOGCC's administrative approval to continue gas injection in PBL' AGI-OS is condi- tioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates, and shall flag the well's periodic pressure bleeds on the report; 3. BPXA shall perform an MIT - IA every four years to the maximum anticipated injection pressure, the anniversary date of which shall be this approval's effective date; rR.4N6C H. r~7LlRKOVlSKl, GQ~/ERA10R ~l 4. BPXA shall limit the well's IA operating pressure to 2000 psi; • Mr. Stzve Rossberg :stay 31, 2006 Page 2 of 2 ~i ~. BPXA shall install and operate remote pressure monitoring equipment on the well's IA; 6. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; and ?. after well shut in due to a change in the well's mechanical condition, AOGCC ap- proval shall be required to restart injection. As provided in AS 31.0.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered timely if it is received 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 Commiss~decision to Superior Court unless rehearing has been requested. ka and dated May 31, 2006. '~~ r ,- ~~ D~.n--T. Seamount Commissioner ;,; ~ i f / ~ ~ ;~~, i ~~ ("jr . may iy ~y. , , ~~ ~~ _ . ~ Cath~. Foerster Commissioner AGI-05 (pTD #1930020) Slow IA Repressurization ~~ t e e Hello Jim and Winton. Well AGI-05 (PTD #1930020) is exhibiting indications of pressure communication between the tubing and IA, as noted on the attached TIO plot. An MITIA on 9/19/04 passed to 2300 psi. The field Operators safely manage this repressurization by bleeding the IA pressure approximately once every 50 days. This pressure management maintains the IA pressure below BP's maximum allowable annular surface pressure limit of 2000 psi. Current plans are to continue gas injection operations. No repairs are planned at this time Attached is a TIO plot and wellbore schematic. Please call with any questions. «AGI-05.pdf» «AGI-05 TIO Plot.jpg» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100,x1154 Email: NSUADWWelllnteqrityEnQineer@bp.com ('~ '- Content-DescriptiQn: AGI-05.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: AGI-05 no Plot.jpg Content-Type: image/jpeg Content-Encoding: base64 1 of 1 3/20/2006 11: 16 AM - e ~ . Jt TREE = ŒN WB.LHEAD = FMC AGI-05 SAFElY NOTES: LINER NOT CEMENTED. A crUA TOR = BAKER C ALL TOO IS IPC W rrH NSCC THREAD. KB. ELEV = 49' BF. ELEV - KOP= 1051 ' Max Angle- 38 @ 6982' / DatumMD= 10239' DatumlVD= 8800' SS . 1-17" CAMeO BAL-O SSSV NIp, ID = 5.937" I 2219' 113-3/8" CSG, 68#, K-55, ID = 12.415" 7!r I J u.:t:\f f = 5D 2() ps; (6fF ) 113-3/8" CSG, 72#, L-80, ID= 12.347" I 3858' ~. ?> . 2h70-F; (7Z04-) - QX~f~ ~ Minimum ID = 4.455" @ 9127' I A 9075' -iANCHORI 5-1/2" OTIS XN NIPPLE g ~ -t 9076' H 9-518" X 7" BAKER SB-3A A<R, ID = 6.000" I 17" lBG, 26#, NT-80-S-IPC, NSCC, .0383 bpf, ID-6.276" I 9084' - \ 9084' 7" x 5-1/2" XO, ID= 4.812" I ITOPOF 5-1/2" TBG 9084' I . 9106' 1-i5-1/2" PARKER SWS NIP, ID - 4.56Z' I TOP OF 7" LNR I 9126' ~ 912T 5-1/2" OTISXN NO-GO NIP, ID =4.455" I 5-1/2" TBG, 17#, L-80-IR::, NSCC, .0232 bpf, ID =4.892" 9139' 9139' 1-15-1/2" WLffi, ID = 4.892" I I 9135' HELMD IT LOGGED 0511 0/93 I 19-518" CSG, 47#, NT-80-S, ID = 8.681" I 9323' ~ ~ ---'?> Jv~ po 08 70f~i [ Q¿,¡~ =- -4750ps; PERFORATION SUMMARY REF LOG: BHCSAWA ON 04/20/93 1 ANGLEATTOP PERF: 15@9516' Note: Refer to Production DB for his toneal erf data SIZE SPF INTERVAL Opn/Sqz DATE 1 3-3/8" 6 9516 - 9546 0 6/13/93 3-3/8" 6 9573 - 9583 0 6/13/93 3-3/8" 6 9606 - 9626 0 6/13/93 3-3/8" 6 9668 - 9688 0 6/13/93 3-3/8" 6 9730 - 9750 0 6/13/93 PBTD 9801' 17" LNR, 29#, NT-80-S, .0371 bpf, ID= 6.184" I 9822' ~ D'I TE REV BY COMM8IITS D'I TE REV BY COMMENTS PRUDHOE BA Y UNT 02/0 2/93 ORGINAL COMPLETION WELL: AGf.·05 OS/22/01 RNlKAK CORRB::TIONS PERlllrT No: 1930020 03/13/03 A SlTP ADD IPG'TI-READ FOR TBG AA No: 50-029-22327-00 05/12/03 JRC/KK ADD 1 3- 3/8", 68# CSG SEC 36, T12N, R14E, 2879.13' FB. & 2680.08' FNL 08/11/04 WRRllLP TREE, WELLHEAD CHANGES BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 7 e¿ 0:( / P.I. Supervisor )'\/L1 f TJJ C4 DATE: Monday, September 20, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC AGl-05 PRUDHOE BAY UNIT AGl-05 FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :JBf2..--- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT AGI-05 API Well Number: 50-029-22327-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG040919122429 Permit Number: 193-002-0 Inspection Date: 9/19/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well AGl-05 Type Inj. G TVD 7771 IA 120 2310 2280 2265 P.T. 1930020 TypeTest SPT Test psi 1942.75 OA 60 70 70 70 Interval 4YRTST PIF P Tubing 3450 3450 3450 3450 Notes: Jim Regg, Joe Anders in attendance. 3 bbl's. Monday, September 20, 2004 Page 1 of 1 MEMORANDb,v, State of A,aska Alaska Oil and Gas Conservation Commission TO: Julie Heusser ~"-~ DATE: May 27, 2001 Commissioner . SUBJECT: Mechanical Integrity Tests THRu: TomMaunder ~f-~~ BPX P.I. Supervisor,~-~ AGI Pad (~ [%.-O \ AGI-01, 02, 03, 04, 05 FROM: Jeff Jones PBU Petroleum Inspector PBF NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI AGI-01I Type,nj.J G I T.¥.D. 17010 I Tubing 13500 13500 J 3500 13500 l lntervall 4 P.T.D.I 192-124 ITYpetestl P ITestPsil 1978 ICasingI 450 I 21001 20901 2080 I PIE I P Notes: WellI AGI'02 I Type,nj.I G J T.V.D. 1785s I Tubingl ~00 I ~00 I~00 I~00 I lntervall 4 P.T.D.I 192-120 ITypetestl P ITestpsil 1965 ICasingI 325 I 21001 21001 21001 PIE I P Notes: WeilJ AGI-03 Type lnj.I G I T.V.D. I 7870 J Tubingl 3500 I 3500 "J 3500 J 3500 I lntervalJ 4 P.T.D.I 192-135 TyPetestI P JTestpsiJ 1968 J CasingI 600 J 2120 J 2110I 2110I PIE J P Notes: WellI AGI.04 I Typelnj. I .G I T.V.D. I ,0,0 I*u~,.,l~00 I ~00 I ~00 I ~00 I lntervall 4 P.T.D.I 192-146 Type teStI P I Testpsil 1975 ICasingI 360 I 21801 2200 I 2200 I P/F I 13 Notes: WellI AGI.05 I Typelnj. I G I T.V.D, I~,~ J Tubing [3500 '1 3500 I 3500 13500 I lntervall 4 P.T.D.I 193-002 Type testI P I TeStpsil 1936 I CasingI 600 I 21001 21001 21001 PIE I 13 Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G '- GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test 'R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Sunday, May 27, 2001: I traveled to BPX'S AGI Pad to witness 4 year MIT's on gas injection wells AGI-01, 02, 03, 04, and 05. The pre-test pressures were observed to be stable and the standard annulus pressure test was then performed with all five wells passing the MIT's. The test data above indicates these wells are suitable for continued injection. Summary.: I witnessed five successful MIT's on BPX's AGI Pad in the Prudhoe Bay Field. M.I.T.'s performed: _5 Number of Failures: _0 Total Time during tests: 3 hrs. Attachments: cc: MIT report form 5/12/00 L.G. MIT PBU AGI-01,02,03,04,05 5-27-01 JJ 6/9/01 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE DECEMBER 01, 2000 E PL W M ATE IA L U N D ER TH IS M ARK ER C:LORIgVlFILM.DOC PERMIT DATA ---567 93-002 5678 93-002 5866 93-002 407 93-002 DAILY WELL OP 93-002 SURVEY 93-002 SURVEY 93-002 BHCA/GR 93-002 BHCA/GR 93-002 BHP 93-002 BHPF 93-002 AOGCC Individual Well Geological Materials Inventory 93-002 DLL/GR/$P T DATA_PLUS T DLL/MLL/AC/GR Page: 1 Date: 04/04/95 ~f DLLMLL/AC/GR ~T~'OH-MWD,7455-9335 ~/COMP DATE:05/20/93 ~'~'01/18/93-04/22/93 '~'MWD DIRECTIONAL -~'SS DIRECTIONAL ~OH,R1,2&5" ~ OH,R1,5" COMP t-L~ RUN 1, 5" · DLL/MLL/GR/SP/CA~OH,R1,2&5" 93-002 / 93-002 GR/CCL ~/L RUN 1, 5" 93-002 GR/CCL ~-'1~' 9000-9840 93-002 SBL/GR/CCL t~ CH RUN DATE_RECVD 06/28/1993 10/29/1993 09/08/1993 09/08/1993 08/31/1993 09/08/1993 05/06/1993 07/30/1993 07/30/1993 05/06/1993 07/30/1993 07/30/1993 05/06/1993 06/28/1993 01/14/1994 03/26/1993 Are dry ditch samples required? yes ~nd received? ~s no Was the well cored? yes~_~A~nalysis & description/~ _ receiv~ yes no Are well tests required?%\ yes ~ Received? ye~o Well is in compliance ~ Initial COMMENTS ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 01-04-94 REFERENCE: 'ARC~F~ FINALS q~'"~ 5-03A ~'~--6~ · 9-31A ~'b-~ · · 9-36A ~_--i~ I * * * 16-4A r~,~oz AGI-5 :-? ¥--~ AGI-6 5/3~-~/~/~3 4/16-17/93 MWD: GR 3/31-4/6/93 MWD: GR 02-19-93 SSTVD 05-10-93 GR/CCL 05-10-93 GR/CCL z~,, ~&2, Run 1, 1"&2" Run 1, 5" Run 1, 5" Slim I GR ~5" t~ R~_m 2"&5" Ana Aha Aha Atlas Sch Sch Please sign and return the attached copy as receipt of data. RECEIVED BY ~!.~[~.',/.f ~,~.~....f /~,..~'~/'~-~- Have A Nice Day! John DeGrey ATO-1529 APPROVED__~ Trans# 94005 * ** *** # CENTRAL FILES # CHEVRON #D&M # ANO8 GEOLOGY # EXXON # MOBIL # PHILLIPS # PB WELL FILES # BPX # STATE OF ~LASKA The corrected APl# for 9-31A is 50-029-21396-01. The corrected API# for 9-36A is 50-029-21429-01. The corrected API# for 16-4A is 50-029-20561-01. Alaka Oil ,& Gas Cans. INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL 09/10/1993 PAGE: 1 93-002 BHCA/GR RUN 1 2&5" 93-002 BHCA/GR OH,R1,2&5" 93-002 BHP RUN 1, 5" 93-002 BHPF OH,R1,5" 93-002 COMP RUN 1, 5" 93-002 DLL/GR/SP RUN 1 2&5" 93-002 DLL/MLL/GR/SP/CA OH,R1,2&5" 93-002 GR/CCL 93-002 SBL/GR/CCL 93-002 407 93-002 DAILY WELL OP 93-002 SURVEY 93-002 SURVEY 93-002 5678 93-002 5678 Are well tests required? Was well cored? Yes No... Yes No RUN 1, 5" CH RI 5" COMP DATE:05/20/93 01/18/93-04/22/93 MWD DIRECTIONAL SS DIRECTIONAL DLL/MLL/AC/GR DLLMLL/AC/GR If yes, was the core analysis & description received? Yes No Are dry ditch samples required? Yes No WELL IS ON COMPLIANCE. INITIAL COMMENTS: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CON'~MISSlON WI::! ! COMPLI:::TION OR RI:::COMP LI:::TION REPORT AND LOG 1. Slatus of Well Classification of Service Well OIL I-I GAS [] SUSPENDED [] ABANDONED [] SERVICE 1::3< ADex ~.~ Iniector 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 93-02 3. Address B. APl Number P. O. Box 196612, Anchora~le, Alaska 99519-6612 50- 029-22327 4. Location of well at surface 9. Unit or Lease Name V : Prudhoe Bay Field/Prudhoe Bay At Total Depth /~.,~-~IFI~'D ~ i 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 49.2' I ADL 34628 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Deplh, if offshore 116. No. of Completions 1/18/93 4/19/93 5/20/93I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD'~ 19. Directional Survey 120. Depth where SSSV set Fl. Thickness of Permafrost 9822' MD/8490' TVD 9822' MD/8490' TVD YES [] ~0 []I 2219' feet MD ! 1900' (Approx.) 22. Type Electric or Other Logs Run ML L/BH CS/GR/DL L/TEMP/CH T 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 30' 106' 30" 11 yds Arcticset 13-3/8" 68# L-80/K-55 29' 3896' 16" 2167 cu ft PF "E'Y460 cufl Class "G" 9-5/8" 47# NTS-80 34' 9323' 12-1/4" 517 cufl Class "G" 7" 29# L-80 9126' 9822' 8-1/2" Uncemented 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET(MDI PACKER SET(MDI Gun Diameter 3-3/8" 6 s.p_f 7" X 5-1/2" 9139' 9076' MD TVD 9516'-9546' 8186'-8215' NT-80/L-80 9573'-9583' 8241'-8251' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9606'-9626' 8273'-8292' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9668'-9688' 8333'-8352' 9730'-9750' 8393'-8413' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 6/9/93 Gas Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF ;WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure 3ALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED S E P - 8 199;~ AJaska 0il & Gas Cons. Commissior~ Anchorage Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS ~-C.~MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadierochit 9355' 8029' Base Sadlerochit 9755' 8417' Alaska Oil & Gas Cons. CorrJrni.~.~inn 31. LIST OF ATTACHMENTS /4nchorage 32. I hereby certify that !he foregoin.q is true and correct to the best of my knowledge .~ '~ itle Drillino_ Engineer Suoervisor 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 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: AGI-5 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 04/17/93 03:00 SPUD: RELEASE: 04/22/93 06:00 OPERATION: DRLG RIG: AUDI 2 WO/C RIG: AUDI 2 01/18/93 ( 1) TD: 0'( 0) 01/19/93 (2) TD: 943' ( 943) 01/20/93 (3) TD: 2890' (1947) 01/21/93 ( 4) TD: 3896' (1006) 01/22/93 ( 5) TD: 3896' ( 0) 01/23/93 ( 6) TD: 6167' (2271) 01/24/93 ( 7) TD: 7507' (1340) 01/25/93 (8) TD: 8120' ( 613) 01/26/93 (9) TD: 8515' ( 395) RIGGING UP MW: 0.0 VIS: 0 MOVING RIG. ACCEPT RIG AT 2100 HRS 1/17/93. N/U DIVERTER, MIX SPUD MUD. DRILLING MW: 8.6 VIS:172 MU BHA & MIX MUD. DRLG TO 608. WIRELINE SURV, POH, CHG OUT MUD & ORIENT. SERV RIG. TIH, REAM TO 608. DRLG TO 943. DRILLING MW: 8.6 VIS:172 DRLG TO 2053. CIRC, TRIPPING. TH. CBU, SHORT TRIP. DRLG TO 2890. CIRC & COND MUD MW: 9.3 VIS:120 DRLG TO 3896. CIRC, SHORT TRIP. SROP SURV, POH. RETRIEVE SURV. RU & RUN 13-3/8 CSG. RIG CMT HEAD & CIRC. DRLG CMT. MW: 9.3 VIS: 51 CIRC. PUMP 95 BBLS WATER, 386 BBLS PERM 'E' CMT, 82 BBLS TAIL CMT W/ 2% CACL. DISP W/ MUD. NO BUMP PLUG. N/D DIVERTER. TOP JOB. INSTALL WELLHEAD. N/U BOPE. TEST BOPE. RIH W/ BHA. CIRC. TEST CSG. OK. DRLG CMT, FLOAT EQUIP. SHORT TRIP MW: 9.1 VIS: 36 DRLG CMT TO 3906, CBU & LOT. DRLG TO 4949. CBU, SHORT TRIP, DLRG TO 6167. CBU, SHORT TRIP TO 6167. TRIP MW: 9.4 VIS: 40 SHORT TRIP. DRLG TO 7290,C BU. SHORT TRIP. DRLG TO 7507, CBU. DROP SURV, POH. DRILLING MW: 9.5 VIS: 42 POH, RETR SRUV, CHG OUT MWD, BIT. TIH W/DC, CHECK MWD & MTR. RIH. REAM TO 7507. DRLG TO 7833. REPLC LINER & SWAB ON MUD PUMP. DRLG TO 8120. CUT DRILG LINE MW:10.1 VIS: 47 DRLG F/8120 TO 8264. CURC OUT GAS CUT MUD. DRLG F 8264 TO 8405. CIRC FOR SHORT TRIP, FINISH WT UP MUD. POH TO 7491. SERVICE RIG. RIH 8405. DRILG F/8405 TO 8515. TORQUED UP. CIRC & PUMP PILL. POH, DOWN LOAD TELECO. LOST CONE & 1/2 SHANK OFF BIT. MAKE UP GLOBE BASKET & TRIP IN HOLE TO 3888. CUT DRLG LINE. RECEIVED S P - 8 1993 Al;~gkrq Oil & Gas Cons. Com~$~'tog WELL : AGI-5 OPERATION: RIG : AUDI 2 PAGE: 2 01/27/93 (10) TD: 8517' ( 2) 01/28/93 (11) TD: 8690' ( 173) 01/29/93 (12) TD: 9335' ( 645) 01/30/93 (13) TD: 9335' ( 0) 0i/3i/93 (i4) TD: 9335' ( 0) 02/01/93 (15) TD: 9335' ( 0) 02/02/93 (16) TD: 9335' ( 0) MILLING MW:10.1 VIS: 44 RIH. TAG FILL @ 8508, WASH TO 8515, WORK OVER FISH. TOH. CLEAN JUNK BSKT. SERVICE RIG. WORK OVER FISH, CUT 16" W/JB. POH, NO FISH. RIH W/MILL TO 8515. MIL F/8515 TO 8517. DRILLING MW:10.0 VIS: 46 MILL ON JUNK, POH. MU BIT & RIH TO 8518. DRILL TO 8624, POH. MU BHA, TEST MTR, RIH TO 3888. TIH TO 8522. LOG W/MWD TO 8624. DRLG TO 8690. POH MW:10.0 VIS: 43 DRLG F/8690'-8988' SERV. RIG, DRLG F/8988'-9163', WORK ON #2 SCR, DRLG F/9163'-9335', CBU, SHORT TRIP, F/9335'-7464', TAG BTM, TORQUE UP, WOULD NOT ROTATE, CBU, POH SET STRM PKR MW:10.0 VIS: 45 POH, LD MTR, DOWN LOAD MWD & LD. PULL WEAR RING, TROUBLE W/LDS. SET PLUG, TEST BOPE, CHG OUT RAMS. MU FISH ASSY & RIH TO 3830. SERV RIG. RIH, WASH. POH, RECOVRD FORMATION & BEARINGS. LD JBSKT. SET STORM PKR. MILLING ON JUNK MW:10.1 VIS: 43 ND BOP. CHG OUT SPLIT SPEED & NU BOP. TEST HEAD & TBG SPOOL. RIH. WASH TO BTTM, TRY TO ROTATE, SITTING ON JUNK. CIRC & COND MUD. POH, CHG BHA, CLEAN B BASKTS. RIH TO 9335, NO FILL. MILL ON JUNK. TEST TREE MW: 8.5 VIS: 0 RUN 9-5/8" CSG, CIRC VOL, CIRC, PUMP 92 BBLS CMT, INSTALL 9-5/8" PACKOFF, TEST W/5000 PSI, INSTALL WEAR RING, RIH TO 2000', DISPLACE W/DIESEL, ALLOW TO U-TUBE, POH, PULL WEAR RING, CHG RAMS TO 5", N/D BOPE, INSTALL TBG HGR. REFELCTED COST TO DATE IS INCORRECT. CORRECT COST TO DATE = $1,375, 782. RIG RELEASED. MW: 8.5 VIS: 0 F/P AGI-3 ANNULUS. RIG RELEASED @ 09:00 HRS, 2/2/93. 04/17/93 (17) TD: 9335'( 0) N/U BOPE. MW: 8.5 VIS: 0 RIG ACCPETED @ 04:00 HRS, 4/17/93. N/D TREE. N/U BOPE. 04/18/93 (18) TD: 9368'( 33) RIH. MW: 9.6 VIS: 70 N/U BOPE. TEST BOPE. RIH TO 2000'. CIRC OUT DIESEL. RIH TO FC @ 9241' TEST CSG. DRLG FLOAT EQUIP, CMT TO 9354' CIRC. DISP WELL TO PRO=FLO. CLEAN PITS & TAKE PRO-FLO MUD. FIT (12.9 PPG EMW). DRLG F/ 9354'-9369'. CIRC. POOH. RIH W/ MILL. WELL : AGI-5 OPERATION: RIG : AUDI 2 PAGE: 3 04/19/93 (19) TD: 9430' ( 62) 04/20/93 (20) TD: 9822' ( 392) 04/21/93 (21) TD: 9822 PB: 0 04/22/93 (22) TD: 9822 PB: 9822 DRLG. MW: 9.5 VIS: 68 RIH TO 9368'. MILL ON JUNK. POOH. L/D MILL. RIH W/ GLOBE BASKET. WASHOVER JUNK. POOH. RIH W/ BIT. DRLG F/ 9372'-9430' R/U ATLAS. MW: 9.6 VIS: 68 DRLG F/ 9430'-9822' TD WELL @ 01:00 HRS, 4/20/93. CIRC. SHORT TRIP TO 9323'. CBU. POOH. R/U ATLAS. NOTE: DAILY COSTS REFLECT ADJUSTMENTS TO BRING IN LINE WITH ACTUAL FIELD COSTS DISP W/ BRINE. MW: 9.3 NaC1 LOG WELL. R/D LOGGERS. RIH. CIRC. POOH. RIH W/ 7" LNR ON DP. CBU. PUMP XANVIS, SEAWATER, BRINE, DART. DISP W/ BRINE. BUMP PLUG. SET HGR W/ 3000 PSI. SET PKR W/ 4000 PSI. TEST ANNULUS. OK. DISP W/ BRINE. PREP MOVE. MW: 9.3 NaC1 DISP TO BRINE. POOH. RIH W/ 7" TBG. M/U HGR. F/P TBG, ANNULUS. LAND TBG. SET PKR W/ 4000 PSI. SET BPV. N/D BOPE. N/U TREE. TEST TREE. OK. SECURE WELL. RIG RELEASED @ 06:00 HRS, 4/22/93. SIGNATURE: (drilling superintendent) DATE: Anchorag~ ORIGINAL SUB - S URFA CE DIRECTIONAL SURVEY ~'~ UIDANCE ONTINUOUS ~'~ OOL Alaska Oil.& Bas Cons. Commission Anchorage Company ARCO ALASKA, INC. Well Name AGI-5 (2055' FSL, 2474' FEL, SEC 36, T12N, RlqE) Field/Location PRUOHOE BAY, NORTH SCOPE, ALASKA Job Reference No. 93251 Logc]ed BV: RECOMPUTED W/DEPTH CORRECTIONS Date lO-NAY-g3 Computed Blt: SARBER SINES SCHLUMBERGER * GCT DIRECTIONAL SURVEY CUSTOMER LISTING , FOR ARCO ALASKA INC. AGI - 5 (RECOMPUTED WITH DEPTH CORRECTIONS) PRUDHOE BAY NORTH SLOPE, ALASKA SURVEY DATE' IO-MAY-lgg3 ENGINEER' G. SARBER METHODS OF COMPUTATION TOOL LOCATION: MINI~LI~ CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 83 DEG lg MIN EAST COMPUTATION DATE' 8-JUN-93 PAGE I ARCO ALASKA INC. AGI - 5 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: lO-MAY-1993 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 1OO FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 100 O0 200 O0 300 O0 400 O0 499 99 599 98 699 95 799 84 899 53 -49 O0 51 O0 151 O0 251 O0 351 O0 450 99 550 98 650 95 750 84 850 53 0 0 N 0 0 E 014 S 2 3 E 0 15 S 29 2O E 0 13 S 26 45 E 028 S 0 4 E 0 5O S 2O 2 W 1 5 S 28 4W I 4O S 25 38 E 3 40 S 63 18 E S 19 S72 5 E 0.00 100.00 200.00 300.00 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 998 77 O0 1097 O0 1195 O0 1293 O0 1391 O0 1488 O0 1585 O0 1680 O0 1775 O0 1867 949.77 8 49 32 1048.32 10 17 67 1146.67 10 32 91 1244.91 11 13 68 1342.68 13 6 72 1439.72 14 39 21 1536.21 1S 83 1631.83 18 28 05 1726.05 20 35 64 1818.64 24 15 S 83 59 E S89 11 E N 87 42 E N84 10 E N 8O 46 E N81 3 E N 82 25 E N 81 56 E N 82 50 E N 82 29 E 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000.00 1957.30 1908.30 27 35 2100.00 2045.84 1996 84 27 44 61 30 19 15 33 38 03 34 24 68 36 9 07 36 42 23 36 39 40 36 49 17 37 24 N83 1 E N84 12 E N 8O 4O E N 78 30 E N 79 24 E N80 11 E N81 33 E N 82 40 E N 83 34 E N 84 36 E 2200.00 2133.61 2084 2300.00 2218 15 2169 2400.00 2301 03 2252 2500.00 2382 68 2333 2600.00 2463 07 2414 2700.00 2543 23 2494 2800.00 ,2623 40 2574 2900.00 2703 17 2654 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH 3000.00 2782 58 2733 58 37 17 3100.00 2862 29 2813 29 36 43 3200 O0 2942 75 2893 75 36 14 FEET DEG/iO0 FEET FEEl' 0 O0 -0 05 0 O2 0 19 0 24 -0 03 -1 O1 -I 43 1 77 8 72 20 23 36 91 54 92 73 58 94 52 118 64 144 87 174 10 207 59 245 30 0 O0 0 22 0 O6 0 10 0 28 0 94 0 33 2 68 2 29 2 32 0.00 N 0.17 S 0.58 S 0.91 S 1.43 S 2.41 S 4.01 S 6.10 S 8.89 S 11.76 S O00E 0 03W OOgE 030E 041 E 0 26 E 055W 0 73W 283 E 10 16 E FEET DEG OOO N O 0 E 0 0 0 1 2 4 6 9 15 17 S 10 16 W 59 S 8 52 E 96 S 18 18 E 49 S 16 0 E 42 S 6 3 E 05 S 7 46 W 14 S 6 48 W 33 S 17 39 E 54 S 40 49 E 289 53 336 O1 383 90 437 12 492 55O 609 669 729 789 3.31 O. 93 0.84 1.42 2 2O 1 09 1 72 2 72 2 39 4 81 14 14 S 15 14 13 10 6 3 0 5 10 22 03 E 05 S 38 83 S 57 47 S 75 63 S 96 74 S 120 02 S 146 95 N 175 39 N 208 13 N 245 26 18 S 57 19 E 93 E 41 O3 E 58 67 E 76 41E 96 24 E 120 22 E 146 18 E 175 38 E 2O8 79 E 246 73 S 68 52 E 93 S 75 25 E 86 S 79 54 E 99 S 83 43 E 43 S 86 48 E 25 S 88 49 E 18 N 89 41E 45 N 88 31E O0 N 87 38 E 91 53 94 71 48 79 N 81 6 E 850 55 N 79 4O E 910 85 N 80 4 E 970 11 1 3O 0 7O 5 09 1 52 1 19 1 40 0 82 0 55 0 83 0 84 15 81N 289 66 E 290.10 N 86 53 E 20 26 36 47 57 67 75 82 88 94 N 335 86 E 336.51 N 86 26 E 79 N 383 39 E 384.32 N 86 0 E 89 N 435 79 E 437 35 N 85 10 E 62 N 490 71E 493 01 N 64 27 E 85 N 547 52 E 550 56 N 83 58 E 32 N 606.22 E 609 95 N 83 40 E · 51 N 665.45 E 669 72 N 83 32 E 69 N 724.78 E 729 48 N 83 29 E 78 N 784.79 E 789 79 N 83 33 E 1 75 I 32 1 O8 96 04 N 845 11 E 850 55 N 83 31 E 105 98 N 904 67 E 910 85 N 83 19 E 116 69 N 963 07 E 970 12 N 83 5 E 3300 3400 3500 3600 3700 3800 3900 O0 3023 O0 3104 O0 3186 O0 3269 O0 3351 O0 3433 O0 3515 56 2974 42 3055 59 3137 09 3220 61 3302 79 3384 69 3466 56 36 4 42 35 32 59 34 24 09 34 24 61 34 32 79 34 56 69 34 51 N 81 55 E 1028 N 80 39 E 1087 N 79 41E 1144 N 80 14 E 1201 N 80 47 E 1257 N 81 14 E 1314 N 81 54 E 1371 97 78 65 06 48 42 77 66 52 31 30 54 48 78 125 134 144 154 163 172 180 87 N 1021 41N 1079 48 N 1135 30 N 1191 62 N 1246 52 N 1303 97 N 1359 26 E 1028 47 E 1087 55 E 1144 2O E 1201 91E 1257 2O E 1314 95 E 1371 99 N 82 58 E 8O N 82 54 E 70 N 82 45 E 15 N 82 37 E 6O N 82 31E 57 N 82 28 E 93 N 82 25 E COMPUTATION DATE' 8-JUN-93 PAGE ARCO A~SKA INC. AGI - $ PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY' lO-MAY-1993 KELLY BUSHING ELEVATION' 49,00 FT ENGINEER' G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE ~EASURED VERTICAL VERTICAL DEVIATION AZIk~JTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOLrFH EAST/WEST DIST. AZIMLFFH FEET DEG/1OO FEET FEET FEET DEG 4000.00 3597 93 3548 93 34 38 4100 O0 3680 4200 4300 4400 4500 4600 4700 4800 4900 O0 3762 O0 3845 O0 3928 O0 4011 O0 4095 O0 4178 O0 4260 O0 4341 41 3631 41 34 19 96 3713 96 34 18 66 3796 66 34 6 62 3879 62 33 44 83 3962 83 33 39 03 4046 03 33 44 21 4129 21 33 44 79 4211.79 35 31 25 4292,25 36 54 N 82 18 E 1428.64 N 82 42 E 1485.19 N 82 53 E 1541.61 N 82 59 E 1597.84 N 83 2 E 1653.67 N 82 45 E 1709.14 N 82 42 E 1764.60 N 82 33 E 1820.11 N 82 6 E 1876.49 N 81 51E 1935.85 0.33 0.19 196 0.17 203 0.26 210 0.31 216 0.09 223 0.09 230 0.35 237 2.79 245 0.27 253 188 73 N 1416.30 E 1428 82 N 82 25 E 1472 37 E 1485 18 N 1528 10 N 1584 85 N 1639 71N 1694 72 N 1749 86 N 1804 30 N 1860 59 N 1919 35 E 1541 15 E 1598 57 E 1653 62 E 1709 64 E 1764 69 E 1820 58 E 1876 38 E 1936 37 N 82 25 E 80 N 82 26 E 02 N 82 27 E 85 N 82 28 E 32 N 82 29 E 79 N 82 29 E 30 N 82 3O E 68 N 82 29 E O6 N 82 28 E 5000 O0 4421.28 4372,28 36 50 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4501.26 4452.26 36 51 O0 4581.25 4532.25 36 50 O0 4661.29 4612.29 36 50 O0 4741.45 4692.45 36 38 O0 4821.76 4772.76 36 32 O0 4902.29 4853.29 36 17 O0 4983.25 4934.25 35 49 O0 5064.41 5015.41 35 42 O0 5145.32 5096.32 36 14 N 82 5 E 1995.79 N 82 19 E 2055,81 N 82 13 E 2115 81 N 82 5 E 2175 74 N 81 50 E 2235 52 N 81 47 E 2295 08 N 82 6 E 2354 34 N 82 24 E 2413 04 N 82 21E 2471 44 N 82 18 E 2530 20 0 29 0 15 0 15 0 21 0 25 0 36 0 56 0 18 0 27 0 11 262 02 N 1978 74 E 1996,02 N 82 27 E 27O 278 286 294 3O3 311 319 327 335 16 N 2038 2O N 2097 39 N 2157 76 N 2216 26 N 2275 57 N 2333 43 N 2392 22 N 2450 05 N 2508.25 E 2530 22 E 2056 05 N 82 27 E 68 E 2116 O7 E 2175 27 E 2235 24 E 2295 94 E 2354 12 E 2413 O0 E 2471 O5 N 82 27 E 99 N 82 26 E 78 N 82 25 E 37 N 82 24 E 64 N 82 24 E 35 N 82 24 E 76 N 82 24 E 53 N 82 23 E 6000.00 5226 02 5177 02 36 14 6100.00 5306 6200.00 5387 6300.00 5467 64OO O0 5547 6500 O0 5627 6600 O0 5707 6700 O0 5787 6800 O0 5866 6900 O0 5945 75 5257 39 5338 62 5418 78 ,.,~98 82 5578 55 .5658 03 5738 21 5817 37 5896 75 36 4 39 36 36 62 36 41 78 36 43 82 37 2 55 37 9 03 37 39 21 37 34 37 37 43 N 82 46 E 2589 26 N 82 54 E 2648 N 82 38 E 27O7 N 82 8 E 2767 N 82 12 E 2826 N 82 22 E 2886 N 82 48 E 2947 N 82 55 E 3007 N 83 6 E 3068 N 83 1E 3130 27 4O O8 86 79 14 83 91 01 0 33 0 24 0 48 0 23 0 10 0 45 0 25 0 39 0 16 0 14 342.79 N 2566.80 E 2589.59 N 82 24 E 350.08 N 2625.36 E 2648.60 N 82 24 E 357,53 N 2684.02 E 2707.73 N 82 25 E 365,45 N 2743.18 E 2767 42 N 82 25 E 373.62 N 2802.41 E 2827 21 N 82 24 E 381.67 N 2861.82 E 2887 15 N 82 24 E 389.46 N 2921.66 E 2947 51 N 82 24 E 396.97 N 2981.89 E 3008 20 N 82 25 E 404.41 N 3042.51 E 3069 27 N 82 26 E 411.80 N 3103.17 E 3130 37 N 82 26 E 7000 O0 6024 45 5975.45 37 46 7100 O0 6104 7200 O0 6185 7300 O0 6267 7400 O0 6348 7500 O0 6429 7600 O0 6511 7700 O0 6592 7800.00 6674 7900.00 6756 64 6055.64 35 37 85 6136.85 35 36 16 6218.16 35 36 46 6299.46 35 31 80 6380.80 35 33 09 6462.09 35 35 66 6543.66 35 15 54 6625.54 34 54 62 6707.62 34 37 N 82 57 E 3191.21 N 82 I E 3250.94 N 82 0 E 3309.28 N 81 54 E 3367.48 N 81 47 E 3425 68 N 81 52 E 3483 84 N 82 0 E 3542 O6 N 82 9 E 3599 89 N 82 17 E 3657 28 N 82 25 E 3714 41 O. 82 0.49 0 2O 0 O8 0 17 0 13 0 43 0 29 0 16 0 21 419.30 N 3163 91E 3191 57 N 82 27 E 427 01N 3223 435 443 451 459 468 476 483 491 14 N 3280 28 N 3338 54 N 3396 82 N 3453 06 N 3511 05 N 3568 81N 3625 4O N 3682 14 E 3251 92 E 3309 57 E 3367 20 E 3426 79 E 3484 44 E 3542 73 E 3600 61E 3657 23 E 3714 31 N 82 27 E 66 N 82 27 E 87 N 82 26 E 09 N 82 26 E 26 N 82 25 E 50 N 82 24 E 34 N 82 24 E 75 N 82 24 E 88 N 82 24 E COMPUTATION DATE: 8-JUN-93 PAGE 3 ARCO ALASKA INC. aoI - 5 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: lO-MAY-1993 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH 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 DEG MIN 8000 O0 6839 O0 6790 O0 34 22 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 6921 O0 7005 O0 7089 O0 7173 O0 7258 O0 7344 O0 7431 O0 7520 O0 7609 83 6872 15 6956 07 7040 42 7124 48 7209 52 7295 74 7382 05 7471 72 7560 83 33 49 15 33 13 07 32 39 42 32 13 48 31 16 52 29 56 74 28 40 05 27 5 72 25 28 N 82 40 E 3771 08 N 83 1E 3827 N 83 24 E 3882 N 84 11E 3936 N 84 56 E 3990 N 85 9 E 4O43 N 85 50 E 4093 N 86 3 E 4142 N 85 49 E 4189 N 85 3O E 4233 12 41 78 48 O5 95 82 67 89 0 48 0 59 0 86 0 55 0 94 0 97 1 48 I. 27 1.91 1.79 498 79 N 3738 43 E 3771 55 N 82 24 E 505 512 518 523 527 531 535 538 541 75 N 3794 28 N 3848 12 N 3902 30 N 3956 90 N 4008 92 N 4059 32 N 4108 65 N 4155 97 N 4199 O3 E 3827 94 E 3882 99 E 3937 46 E 3990 84 E 4043 63 E 4094 43 E 4143 21E 4189 35 E 4234 59 N 82 24 E 88 N 82 25 E 23 N 82 26 E 91 N 82 28 E 45 N 82 3O E 33 N 82 32 E 16 N 82 35 E 98 N 82 37 E 18 N 82 39 E 9000 O0 7700 84 7651 84 23 3 9100 9200 9300 9400 9500 9600 9700 98O0 9822 O0 7793 O0 7887 O0 7983 O0 8080 O0 8177 O0 8273 O0 8371 O0 8468 O0 8490 52 7744 52 21 4 80 7838 80 17 57 49 7934 49 15 47 09 8031 09 14 37 O1 8128 O1 14 27 94 8224 94 13 56 18 8322 18 13 4 76 8419.76 12 22 25 8441,25 12 22 N 86 30 E 4275.01 N 87 28 E 4312.47 N 87 50 E 4345.69 N 88 32 E 4374.59 N 89 19 E 4400.32 S 87 40 E 4424.75 S 86 24 E 4448.97 S 86 I E 4471.90 S 86 46 E 4493.41 S 86 46 E 4498.05 2,33 2 86 2 17 2 16 0 6O I 63 0 67 0 68 0 O0 0 O0 544 86 N 4240 41E 4275.27 N 82 41E 546 ,548 549 549 549 547 546 545 544 80 N 4277 22 N 4311 05 N 4340 57 N 4366 40 N 439O 92 N 4415 38 N 4438 02 N 4460 76 N 4464 90 E 4312.71 N 82 43 E 18 E 4345.90 N 82 45 E 18 E 4374.77 N 82 47 E 03 E 4400.48 N 82 50 E 64 E 4424.88 N 82 52 E 20 E 4449.07 N 82 56 E 47 E 4471.98 N 82 59 E 29 E 4493.46 N 83 2 E 99 E 4498.10 N 83 3 E COMPUTATION DATE: 8-JUN-93 PAGE 4 ARCO ALASKA INC. AGI - 5 PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY: lO-MAY-1993 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 1000 FEET Of MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPAR3IJRE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 9000 0 O0 O0 998 O0 1957 O0 2782 O0 3597 O0 4421 O0 5226 O0 6024 O0 6839 O0 7700 -49.00 0 0 77 949.77 8 49 30 1908.30 27 35 58 2733.58 37 17 93 3548.93 34 38 28 4372.28 36 50 02 5177.02 36 14 45 5975.45 37 46 O0 6790.00 34 22 84 7651.84 23 3 N 0 0 E S 83 59 E 20 N 83 1 E 289 N 81 6 E 850 N 82 18 E 1428 N 82 5 E 1995 N 82 46 E 2589 N 82 57 E 3191 N 82 40 E 3771 N 86 3O E 4275 0 O0 23 53 55 64 79 26 21 08 01 0 O0 3 31 1 3O I 75 0 0 0 0 0 2 33 29 33 82 48 33 0 O0 N 14 15 96 188 262 342 419 498 544 14 S 22 81N 289 04 N 845 73 N 1416 02 N 1978 79 N 2566 30 N 3163 0 O0 E 0.00 N 0 0 E 03 E 26.18 S 57 19 E 66 E 290.10 N 86 53 E 11 E 850.55 N 83 31 E 30 E 1428.82 N 82 25 E 74 E 1996.02 N 82 27 E 80 E 2589.59 N 82 24 E 91 E 3191.57 N 82 27 E 79 N 3738.43 E 3771.55 N 82 24 E 86 N 4240,41E 4275.27 N 82 41E 9822.00 8490.25 8441.25 12 22 S 86 46 E 4498.05 0.00 544,76 N 4464.99 E 4498.10 N 83 3 E COMPUTATION DATE' 8-JUN-93 PAGE ARCO ALASKA INC. AGI - 5 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' lO-MAY-1993 KELLY BUSHING ELEVATION' 49.00 FT ENGINEER' G. SARBER INTERPOLATED VALUES FOR EVEN lO0 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 HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 49 O0 149 O0 249 O0 349 O0 449 01 549 O2 649 03 749 08 849 29 0 O0 49 O0 149 O0 249 O0 349 O0 449 O0 549 O0 649 O0 749 O0 849 O0 -49.00 0 0 N 0 0 E 0.00 0 5 S 76 25 W 100.00 0 16 S 16 30 E 200.00 0 13 S 38 1E 300.00 0 17 S 13 46 E 400.00 0 32 S 5 43 W 500.00 1 4 S 26 29 W 600.00 1 11 S 11 8 W 700.00 2 36 S 51 22 E 800.00 4 30 S 68 37 E 0. O0 0. O0 -0. O2 0. O9 -0.04 0.14 0.11 0.11 0.24 0.37 0.17 0.32 -0.45 0.36 -1.45 1.12 -0.42 2.44 4.86 I .29 0 O0 N 0 065 0 38 S 0 76 S 1 10 S 1 85S 3 16S 4 92 S 7 44 S 10 31 S 0 O0 E 0 02 W 0 O0 E 0 2O E 0 37 E 0 39 E 0 09 W 0 88 W 0 45 E 6 10 E 0 O0 N 0 0 E 0 06 S 17 20 W 0 38 S 0 33 E 0 78 S 14 40 E 1 16 S 18 36 E 1 89 S 11 49 E 3 16 S 1 33 W 5 O0 S lO 8 W 7.46 S 3 28 E 11.98 S 30 38 E 949 75 1050 1152 1254 1356 1458 1562 1666 1772 1879 949.00 92 1049.00 1000 54 1149.00 1100 26 1249.00 1200 26 1349.00 1300 99 1449.00 1400 41 1549.00 1500 53 1649.00 1600 23 1749.00 1700 65 1849.00 1800 900 O0 6 52 O0 9 52 O0 10 27 O0 10 44 O0 12 6 O0 14 13 O0 15 19 O0 17 23 O0 20 0 O0 23 12 S 77 55 E S 87 9 E N 89 28 E N 85 37 E N 82 0 E N 80 38 E N 82 6 E N 82 0 E N 82 35 E N 82 39 E 13.57 28 42 46 31 64 89 84 98 108 43 134 78 163 75 197 95 237 13 4.34 I 24 0 33 0 98 2 10 I 36 1 32 3 O0 2 11 4 46 13 11S 14 15 14 12 8 4 0 4 9 15.20 E 20.07 S 49 13 E 75 S 30.35 E 33.74 S 64 4 E 05 S 48.40 E 50.68 S 72 44 E 24 S 67.01 E 68.51 S 78 0 E 07 S 86.97 E 87.81 S 82 6 E 36 S 110.15 E 110.47 S 85 40 E 39 S 136.21 E 136.29 S 88 9 E 50 S 164.93 E 164.93 S 89 SO E 17 N 198.82 E 198.86 N 88 48 E 08 N 237.69 E 237.86 N 87 49 E 1990 63 1949 O0 1900 O0 27 31 2103 2217 2337 2458 2582 2707 2832 2957 3083 57 2049 94 2149 12 2249 48 2349 45 2449 19 2549 O0 2649 74 2749 38 2849 O0 2000 O0 27 45 O0 2100 O0 31 7 O0 2200 O0 33 57 O0 2300 O0 35 27 O0 2400 O0 36 39 O0 2500 O0 36 38 O0 2600 O0 36 58 O0 2700.00 37 30 O0 2800.00 36 58 3207 74 2949 O0 2900 O0 36 13 3331 3454 3575 3696 3818 3940 4061 4183 4304 51 3049 41 3149 65 3249 83 3349 56 3449 53 3549 97 3649 09 3749 03 3849 O0 3000 O0 3100 O0 3200 O0 3300 O0 3400 O0 3500 O0 3600 O0 3700 O0 380O O0 36 13 O0 34 3O O0 34 25 O0 34 31 O0 35 0 O0 34 37 O0 34 21 O0 34 20 O0 34 6 N 82 55 E N 84 13 E N 79 49 E N 78 49 E N 79 51 E N 81 18 E N 8244 E N 84 0 E N83 6 E N 80 SE 285 19 337 67 393 09 457 70 526 28 599 46 674 O1 748 69 824 90 900 90 N 80 13 E N 82 3 E 1047 N 79 33 E 1118 N 80 9 E 1187 N 80 46 E 1255 N 81 19 E 1325 N 82 10 E 1394 N 82 34 E 1463 N 82 51E 1532 N 82 59 E 1600 974 68 55 91 33 68 04 85 74 08 10 I 49 0 72 4 74 0 93 1 95 0 88 0 53 1 O1 2 49 1 32 1.14 0.49 0.93 0.28 0.54 0.48 0.35 0.41 0.17 0.28 15.29 N 285.35 E 285.76 N 86 56 E 21.11N 337.51E 338.17 N 86 25 E 28.38 N 392,45 E 393.48 N 85 52 E 40.95 N 456 04 E 457 87 N 84 52 E 53.64 N 523 60 E 526 34 N 84 9 E 65.76 N 595 86 E 599 48 N 83 42 E 76.06 N 669 71 E 674 O1 N 83 31 E 84.78 N 743 87 E 748 69 N 83 30 E 92.49 N 819 71 E 824 91 N 83 34 E 104.24 N 894 84 E 900 90 N 83 21 E 117.47 N 967.58 E 974 69 N 83 5 E 128 46 N 1039.66 E 1047 139 151 163 174 184 193 201 210 83 N 1110.18 E 1118 96 N 1177.64 E 1187 33 N 1245.13 E 1255 13 N 1313.70 E 1325 17 N 1382.81 E 1395 36 N 1451.09 E 1463 g9 N 1518.89 E 1532 38 N 1586.39 E 1600 57 N 82 57 E 95 N 82 49 E 4O N 82 39 E 80 N 82 32 E 19 N 82 27 E 02 N 82 25 E 92 N 82 25 E 26 N 82 25 E 28 N 82 27 E COMPUTATION DATE' B-JUN-93 PAGE 6 ARCO ALASKA INC. aGI - $ PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY- lO-MAY-1993 KELLY BUSHING ELEVATION' 49.00 ET ENGINEER' G. SARBER 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 HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4424.50 3949 O0 3900 O0 33 42 4544.67 4049 4664.88 4149 4785.58 4249 4909.69 4349 5034.66 4449 5159.68 4549 5284.64 4649 5409.41 4749 5533.86 4849 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 4500 O0 4600 O0 4700 O0 4800 O0 33 41 O0 33 42 O0 34 59 O0 36 53 O0 36 57 O0 36 54 O0 36 51 O0 36 36 O0 36 22 N 82 57 E 1667.27 N 82 45 E 1733,90 N 82 35 E 1800.62 N 82 15 E 1868,.19 N 81 50 E 1941 67 N 82 10 E 2016 60 N 82 18 E 2091 62 N 82 6 E 21~6 54 N 81 50 E 2241 13 N 81 53 E 2315 18 0 23 0 O8 0 14 2 69 0 23 0 18 0 12 0 16 0 23 0 39 218.50 N 1653 07 E 1667.45 N 82 28 E 226.83 N 1719 235.33 N 1785 244.18 N 1852 254.42 N 1925 264.87 N 1999 274.94 N 2073 285.12 N 2147 295.56 N 2221 306.12 N 2295 18 E 1734 08 N 82 29 E 36 E 1800 36 E 1868 14 E 1941 36 E 2016 71E 2091 95 E 2~66 82 E 2241 15 E 2315 80 N 82 29 E 38 N 82 29 E 88 N 82 28 E 82 N 82 27 E 86 N 82 27 E 79 N 82 26 E 4O N 82 25 E 47 N 82 24 E 5657,76 4949 O0 4900 O0 35 50 5781 02 5049 5904 6028 6152 6276 6401 6526 6652 6778 56 5149 48 5249 30 5349 78 5449 52 5549 55 5649 06 5749 28 5849 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 35 41 O0 36 14 O0 36 12 O0 36 14 O0 36 39 O0 36 43 O0 37 8 O0 37 22 O0 37 35 N 82 23 E 2388 32 N 82 19 E 2460 N 82 18 E 2532 N 82 55 E 2606 N 82 45 E 2679 N 82 14 E 2753 N 82 12 E 2827 N 82 28 E 2902 N 82 55 E 2978 N 83 2 E 3055 36 89 08 09 21 77 80 64 66 0 43 0 10 0 05 0 18 0 73 0 30 0 10 0 33 0 61 0 23 316 16 N 2367 61E 2388.63 N 82 24 E 325 335 344 353 363 373 383 393 402 75 N 2439 41N 2510 88 N 2583 93 N 2655 56 N 2729 74 N 2803 78 N 2877 37 N 2952 81N 3029 02 E 2460.68 N 82 24 E 92 E 2533.22 N 82 23 E 50 E 2606,41 N 82 24 E 94 E 2679,42 N 82 25 E 45 E 2753.55 N 82 25 E 32 E 2828.12 N 82 24 E 69 E 2903.16 N 82 24 E 92 E 2979.01 N 82 25 E 37 E 3056.03 N 82 26 E 6904 59 5949 O0 5900 O0 37 43 7030 7154 7277 7400 7523 7646 7768 7890 8012 96 6049 64 6149 67 6249 66 6349 61 6449 54 6549 84 6649 74 6749 10 6849 O0 6000 O0 6100 O0 6200 O0 6300 O0 6400 O0 6500 O0 6600 O0 6700 O0 6800 O0 37 17 O0 35 47 O0 35 37 O0 35 31 O0 35 38 O0 35 17 O0 34 58 O0 34 37 O0 34 18 N 83 0 E 3132 82 N 82 55 E 3210 N 81 59 E 3282 N 81 57 E 3354 N 81 48 E 3426 N 81 46 E 3497 N 82 4 E 3569 N 82 15 E 3639 N 82 26 E 3709 N 82 43 E 3777 O7 83 48 O6 58 O4 45 15 9O 0 13 2 54 0 16 0 09 0 17 0 22 0 47 0 24 0 26 0 52 412 14 N 3105 95 E 3133.18 N 82 26 E 421 431 441 451 461 471 481 490 499 62 N 3182 46 N 3254 45 N 3325 60 N 3396 78 N 3467 81N 3538 41N 3607 71N 3677 65 N 3745 63 E 3210.43 N 82 27 E 73 E 3283.20 N 82 27 E 70 E 3354 87 N 82 26 E 58 E 3426 47 N 82 26 E 39 E 3498 O0 N 82 25 E 17 E 3569 49 N 82 24 E 93 E 3639 90 N 82 24 E 02 E 3709 62 N 82 24 E 19 E 3778 37 N 82 24 E 8132 67, 6949 O0 6900.00 33 39 8252 8371 8488 8605 8719 8832 8943 9052 9159 33 7049 10 7149 91 7249 16 .7349 65 7449 43 7549 34 7649 13 7749 07 7849 O0 7000.00 32 56 O0 7100.00 32 28 O0 7200.00 31 19 O0 7300 O0 29 51 O0 7400 O0 28 27 O0 7500 O0 26 32 O0 7600 O0 24 33 O0 7700 O0 21 58 O0 7800 O0 19 10 N 83 9 E 3845 26 N 83 52 E 3910 N 84 33 E 3975 N 85 6 E 4037 N 85 51E 4096 N 86 0 E 4152 N 85 47 E 4204 N 85 56 E 4252 N 87 6 E 4294 N 87 33 E 4332 97 02 29 52 19 28 20 93 70 0 49 0 71 0 74 0 96 I 47 1 23 1 57 2 57 1 78 3 17 507 94 N 3812 04 E 3845 73 N 82 25 E 515 521 527 532 535 539 543 545 ,547 43 N 3877 88 N 3941 41N 4003 11N 4062 97 N 4117 72 N 4169 36 N 4217 97 N 4260 70 N 4298 32 E 3911 06 E 3975 11E 4037 19 E 4096 79 E 4152 79 E 4204 62 E 4252 33 E 4295 16 E 4332 43 N 82 26 E 46 N 82 27 E 70 N 82 30 E 89 N 82 32 E 52 N 82 35 E 58 N 82 37 E 47 N 82 40 E 17 N 82 42 E 91 N 82 44 E COMPUTATION DATE: 8-JUN-93 PAGE 7 ARCO ALASKA INC. AgI - $ PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF sUrVEY: lO-MAY-1993 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 9264.09 7949.00 7900.00 16 33 N 88 31 E 4364 64 9367.87 8049.00 8000 O0 14 41 N 89 12 E 4392 24 9471.11 8149.00 8100 O0 13 56 S 89 22 E 4417 74 9574.30 8249.00 8200 O0 14 5 S 86 22 E 4442 85 9677.23 8349.00 8300 O0 13 12 S 86 3 E 4466 81 9779.77 8449.00 8400 O0 12 22 S 86 46 E 4489 9822.00 8490.25 8441 25 12 22 S 86 46 E 4498 05 2.31 O. 63 1.20 0.69 0.82 0. O0 0. O0 548 79 N 4330 19 E 4364 83 N 82 47 E 549 46 N 4357 90 E 4392 41 N 82 49 E 549 59 N 4383 56 E 4417 88 N 82 51 E 548 31 N 4408 99 E 4442 96 N 82 55 E 546 74 N 4433 31 E 4466 89 N 82 58 E 545 27 N 4455 97 E 4489 20 N 83 I E 544 76 N 4464 99 E 4498 10 N 83 3 E ARCO ALASKA INC. AGI - 5 PRUDHOE BAY NORTH SLOPE, ALASKA MARKER GCT LAST READZNG TD COMPUTATION DATE: 8-JUN-93 PAGE 8 DATE OF SURVEY: lO-MAY-1993 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 2055' FSL, & 2474' FEE, SEC36 T12N R14E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 9750.00 8419.93 8370.93 545.64 N 4449.56 E 9822.00 8490.25 844~.25 544.76 N 4464.99 E ARCO ALASKA INC. AGI - $ PRUDHOE BaY NORTH SLOPE, ALASKA MARKER COMPUTATION DATE: 8-JUN-93 PAGE 9 DATE OF SURVEY- lO-MAY-1993 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: G. SARBER ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 2055' FSL, & 2474' FEL, SEC36 T12N R14E MEASURED DEPTH 'l-VD RECTANGULAR CDORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 9822.00 8490.25 8441.25 544.76 N 4464.99 E FINAL WELL LOCATION AT 'rD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 9822.00 8490.25 8441.25 HORIZONTAL DEPARTURE DISTANCE ' AZIMUTH FEET DEG MIN 4498.10 N 83 3 E DIRECTIONAL SURVEY COMPANY ARCO ALASKA INC. FIELD PRUDHOE BAY WELL AGI - 5 COUNTRY USA RUN -1 DATE LOGGED 10 - MAY - 93 DEPTH UNIT FEET REFERENCE 93224 negligence on our part. be liable or responsible for any loss. costs, damages or expenses Incurred or su~alned by All Interpretations are opinions based on Inferences from electrical or other measurements and we canno{, and do not guarantee the accuracy or correctness of any Interpretations, and we shall not, except tn the case of gross or wtlfull anyone resulting from any tnterprat&tlon made by any of our offtcem, &g®nts or employees. These Intsrpretattons are also subject to our General Terms and Conditions as set out tn our current price ~chedule. HELL' AGZ-5 (2055' FSL, 2474' FEL, SEC 36, T12N, R14E) HORIZONTAL PROJECTION NORTH 4000 REF 93224 3000 2000 1000 - 1000 -2000 -3OO0 SOUTH -4000 -2000 WE[~T SCALE = I / 1000 IN/FT - 1000 0 1000 2000 3000 4000 5000 6000 FAST IELL' AGI-5 (2055' FSL, 2474' F-EL, SEC 36, T12N, R14E) VERTICAL PROdECTION 263 O0 ~2000 -1000 0 0 1000 2000 3000 4000 5000 6000 . . .... :: ..... ........ : . · . . : ................. :.:; ,. ., ............... ; ;..: : · :: . :: :: : , . .... : . . . : : . : : · . . 8300 PROJECTION ON VERTICAL PLANE 263.00 83.00 SCALED IN VERTICAL DEPTHS I-IC~RIZ SCALE ~ I / lOOO IN/FT 6324/6116 Alielson Way · Anchorage, AK 99518 Phone: (907) 563-3269 / Fax: (907) 563-5865 Phone: (907) 562-2646 / Fax: (907) 561-1358 EASTMAN TELECO MWD SURVEY APEX GAS INJECTION PAD - AG15 PRUDHOE BAY DRILLING GROUP Eastman Teleco appreciates the opportunity to provide our services. Please find attached a copy of the directional surveys in each of the following formats: · MWD Survey Listing · Composite 100' MD Interpolated · Composite 100' TVD Interpolated Eastman Teleco Anchorage, Alaska Prudhoe Bay Drilling Group Well Name Location Date Surveyed Survey Performed By : APEX GAS INJECTION PAD AGI5 : Apex Gas Injection Pad : : : JAN. 17, 1993 : : DON LENTZ This survey is correct to the best of my knowledge and is supported by actual field data· ~-~ JE3'C". ~_l~. COMPANY REPRESENTATIVE MEASURED DEPTH NO INTERPOLATION Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : APEX GAS INJECTION PAD AGI5 Location : Apex Gas Injection Pad : : No Interpolation Date JAN. 17, 1993 Filename : 1172AGI5 Plane of Vertical Section : 83.3° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.17°WELLSITE North Grid convergence : +0.0000° Prudhoe Bay Drilling Group Apex Gas Injection Pad Well AGI-5 +0 ° 0' 0' ' (T) Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : APEX GAS INJECTION PAD AGI5 Location : Apex Gas Injection Pad : : No Interpolation MD C~L INC DIR TVD ft ft deg deg ft 0 0 0.0 0.0 0 370 370 0.4 124.7 370 599 229 1.8 209.1 599 779 180 3.4 116.3 779 959 180 8.3 97.7 958 VS ft 0 1 -1 2 19 LAT ft 0 -1 -4 -9 -13 Page 1 of 2 Date JAN. 17, 1993 Filename : 1172AGI5 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 0 0.0 0.0 0.0 1 0.1 0.1 33.7 -0 0.8 0.6 36.9 3 2.2 0.9 -51.6 21 2.9 2.7 -10.3 1144 185 10.5 88.2 1140 1331 187 11.8 83.6 1324 1519 188 15.6 81.1 1506 1706 187 18.9 81.5 1685 1895 189 24.3 82.6 1861 49 85 130 185 255 -15 51 1.5 1.2 -5 . 1 -12 87 0.8 0.7 -2.5 -6 131 2.0 2.0 -1.3 3 186 1.8 1.8 0.2 12 255 2.9 2.9 0.6 2082 187 27.7 84.7 2029 2269 187 33.8 78.0 2189 2456 187 36.0 80.1 2343 2641 185 36.9 82.2 2492 2828 187 37.0 84.3 2641 337 432 539 648 761 21 336 1.9 1.8 1.1 36 431 3.7 3.3 -3.6 56 536 1.3 1.2 1.1 73 644 0.8 0.5 1.1 86 756 0.7 0.1 1.t 3015 187 37.4 80.4 2790 3295 280 36.1 81.8 3014 3576 281 34.4 80.1 3244 3831 255 35.2 81.1 3453 4134 303 34.5 81.5 3702 874 101 868 1.3 0.2 -2.1 1041 127 1033 0.6 -0.5 0.5 1203 153 1194 0.7 -0.6 -0.6 1349 176 1337 0.4 0.3 0.4 1522 203 1508 0.2 -0.2 0.1 4414 280 33.8 81.1 3934 4695 281 33.8 81.1 4167 4981 286 37.0 81.8 4400 5259 278 37.0 80.8 4622 5541 282 36.3 80.4 4848 1679 1835 2000 2168 2336 226 1664 0.3 -0.2 -0.1 251 1818 0.0 0.0 0.0 275 1982 1.1 1.1 0.2 301 2147 0.2 0.0 -0.4 328 2313 0.3 -0.2 -0.1 5820 279 36.0 80.8 5074 6102 282 36.1 81.8 5302 6385 283 36.9 80.8 5529 6663 278 37.8 81.5 5750 6944 281 37.9 82.2 5972 2500 355 2476 0.1 -0.1 0.1 2666 380 2640 0.2 0.0 0.4 2834 405 2806 0.4 0.3 -0.4 3003 431 2973 0.4 0.3 0.3 3175 456 3144 0.2 0.0 0.2 7226 282 35.7 80.4 6198 7511 285 35.9 81.1 6429 7791 280 35.0 82.6 6657 8075 284 33.9 82.6 6891 8357 282 32.4 84.7 7127 3344 3511 3673 3834 3988 481 3310 0.9 -0.8 -0.6 508 3475 0.2 0.1 0.2 ~ 531 3636 0.4 -0.3 0.5 552 3795 0.4 -0.4 0.0 569 3948 0.7 -0.5 0.7 8635 278 29.3 86.4 7366 8917 282 24.8 85.7 7617 9199 282 17.7 88.2 7880 9270 71 16.0 87.8 7948 4130 4258 4360 4381 580 4090 1.2 -1.1 0.6 589 4218 1.6 -1.6 -0.2 595 4320 2.5 -2.5 0.9 595 4341 2.4 -2.4 -0.6 Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : APEX GAS INJECTION PAD AGI5 Location : Apex Gas Injection Pad : : No Interpolation Page 2 of 2 Date JAN. 17, 1993 Filename : 1172AGI5 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 4381 ft 82.2° MEASURED DEPTH 100' INTERPOLATED Client Well Name Location Eastman Teleco Prudhoe Bay Drilling Group APEX GAS INJECTION PAD AGI5 Apex Gas Injection Pad Page 1 of 3 Date JAN. 17, 1993 Filename : 1172AGI5 Interpolated 100 ft of MD MD C~L INC DIR TVD ft ft deg deg ft 0 0 0.0 0.0 0 100 100 0.1 33.7 100 200 100 0.2 67.4 200 300 100 0.3 101.1 300 400 100 0.6 135.8 400 5OO 6OO 700 8OO 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 35OO 3600 3700 3800 3900 100 1.2 172.6 500 100 1.8 208.6 600 100 2.7 157.0 700 100 4.0 114.1 800 100 6.7 103.8 899 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 8.8 95.6 998 10.0 90.5 1097 10.9 86.8 1195 11.6 84.4 1293 13.2 82.7 1391 15.2 81.4 1488 17.0 81.3 1584 18.8 81.5 1679 21.6 82.0 1772 24.4 82.7 1865 26.2 83.8 1955 28.3 84.1 2044 31.5 80.5 2130 34.2 78.3 2215 35.3 79.5 2297 36.2 80.6 2378 36.7 81.7 2459 36.9 82.9 2539 37.0 84.0 2619 37.2 82.8 2698 37.4 80.7 2778 37.0 80.8 2858 36.5 81.3 2938 36.1 81.8 3018 35.5 81.2 3100 34.9 80.6 3182 34.5 80.2 3264 34.8 80.6 3346 35.1 81.0 3428 35.0 81.2 3510 VS ft 0 0 1 1 1 0 -1 1 4 14 26 42 60 79 102 125 154 183 220 257 301 346 397 450 507 565 624 684 744 804 865 925 984 1044 1102 1159 1217 1274 1331 1388 LAT ft 0 -0 -0 -1 -1 -3 -4 -7 -10 -12 -14 -14 -14 -12 -10 -6 -2 2 7 12 17 22 3O 39 5O DEP D ' LEG BUILD TURN o o o ft /100 /100 /100 0 0.0 0.0 0.0 0 0.1 0.1 33.7 1 0.1 0.1 33.7 1 0.2 0.1 33.7 1 0.4 0.3 34.6 0 0.8 0.6 36.9 -0 1.1 0.6 36.0 2 2.1 0.9 -51.6 5 2.7 1.3 -42.9 15 2.9 2.7 -10.3 28 2.4 2.1 -8.2 44 1.5 1.2 -5.1 62 1.1 0.9 -3.6 81 0.8 0.7 -2.5 103 1.6 1.6 -1.7 127 2.0 2.0 -1.3 155 1.8 1.8 -0.1 184 1.8 1.8 0.2 220 2.8 2.8 0.6 257 2.8 2.8 0.6 301 1.9 1.8 1.1 345 2.1 2.1 0.3 396 3.7 3.3 -3.6 448 2 . 9 2 . 6 -2 . 1 504 1.3 1.2 1.1 60 562 1.1 0.9 1.1 69 620 0.8 0.5 1.1 77 680 0.7 0.2 1.1 84 739 0.7 0.1 1.1 92 799 0.7 0.2 -1.2 100 1.09 118 128 137 146 155 164 174 182 859 1.3 0.2 -2 . 1 918 0.4 -0.4 0.1 977 0.6 -0.5 0.5 1036 0.5 -0.5 0.4 1093 0.7 -0.6 -0.6 1150 0.7 -0.6 -0.6 1207 0.4 -0.4 -0.4 1263 0.4 0.3 0.4 1320 0.4 0.3 0.4 1376 0.1 -0.1 0.2 Client Well Name Location Eastman Teleco Prudhoe Bay Drilling Group APEX GAS INJECTION PAD AGI5 Apex Gas Injection Pad Page 2 of 3 Date JAN. 17, 1993 Filename : 1172AGI5 Interpolated 100 ft of MD MD ft 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200 5300 5400 55OO 5600 5700 5800 5900 6OO0 6100 6200 6300 6400 6500 6600 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 CkL ft 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 INC DIR TVD VS LAT · deg deg ft ft ft 34.8 81.3 3592 1445 191 34.6 81.5 3674 1502 200 34.3 81.4 3757 1559 208 34.1 81.3 3839 1615 217 33.8 81.1 3922 1671 225 33.8 81.1 4005 1727 234 33.8 81.1 4088 1782 242 33.9 81.1 4171 1838 251 35.0 81.4 4253 1896 260 36.1 81.6 4334 1954 268 37.0 81.7 4415 2012 37.0 81.4 4495 2072 37.0 81.0 4575 2132 36.9 80.7 4655 2192 36.7 80.6 4735 2252 36.4 80.5 4816 2311 36.2 80.5 4896 2371 36.1 80.6 4977 2430 36.0 80.8 5058 2488 36.0 81.1 5138 2547 36.1 81.4 5219 2606 36.1 81.8 5300 2665 36.4 81.5 5381 2724 36.7 81.1 5461 2784 36.9 80.8 5541 2843 37.3 81.1 5621 2904 37.6 81.3 5700 2965 37.8 81.6 5779 3026 37.8 81.8 5858 3087 37.9 82.1 5937 3148 37.5 81.8 6017 3209 36.7 81.2 6097 3269 35.9 80.6 6177 3328 35.8 80.6 6258 3387 35.8 80.8 6339 3446 35.9 81.1 6420 3504 35.6 81.6 6502 3562 35.3 82.1 6583 3620 35.0 82.6 6665 3678 34.6 82.6 6747 3735 277 286 295 3O5 314 324 334 343 3'53 362 371 380 389 398 407 416 426 435 443 452 461 470 479 488 498 507 5t5 524 532 539 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 1433 0.2 -0.2 0.1 1489 0.2 -0.2 0.1 1545 0.2 -0.2 -0.0 1600 0.3 -0.2 -0.1 1656 0.3 -0.3 -0.1 1711 0.0 -0.0 -0.0 1766 0.0 0.0 0.0 1821 0.1 0.1 0.0 1878 1.1 1.1 0.2 1936 1.1 1.1 0.2 1993 0.9 0.9 0.1 2053 0.2 0.0 -0.4 2112 0.2 0.0 -0.4 2171 0.2 -0.1 -0.3 2230 0.3 -0.2 -0.1 2289 0.3 -0.2 -0.1 2348 0.2 -0.2 0.0 2406 0.1 -0.1 0.1 2464 0.1 -0.1 0.1 2522 0.2 0.0 0.3 2580 0.2 0.0 0.4 2639 0.2 0.0 0.4 2697 0.3 0.3 -0.3 2756 0.4 0.3 -0.4 2815 0.3 0.3 -0.3 2875 0.4 0.3 0.3 2935 0.4 0.3 0.3 2995 0.3 0.2 0.3 3056 0.2 0.0 0.2 3117 0.2 0.0 0.2 3177 0.4 -0.4 -0.2 3236 0.9 -0.8 -0.6 3295 0.9 -0.8 -0.6 3353 0.2 -0.2 0.0 3411 0.2 0.1 0.2 3469 0.2 0.1 0.2 3526 0.4 -0.3 0.5 3584 0.4 -0.3 0.5 3641 0.4 -0.3 0.5 3697 0.4 -0.4 0.0 Client Well Name Location Eastman Teleco Prudhoe Bay Drilling Group APEX GAS INJECTION PAD AGI5 Apex Gas Injection Pad Page 3 of 3 Date JAN. 17, 1993 Filename : 1172AGI5 Interpolated 100 ft of MD MD C~L INC DIR TVD ft ft deg deg ft 8000 100 34.2 82.6 6830 8100 100 33.8 82.8 6912 8200 100 33.2 83.5 6996 8300 100 32.7 84.3 7080 8400 100 31.9 85.0 7164 8500 100 30.8 85.6 7250 8600 100 29.7 86.2 7336 8700 100 28.3 86.2 7424 8800 100 26.7 86.0 7513 8900 100 25.1 85.7 7602 9000 100 22.7 86.4 7695 9100 100 20.2 87.3 7788 9200 100 17.7 88.2 7881 9270 70 16.0 87.8 7948 VS ft 3791 3847 3902 3957 4010 4061 4112 4160 4205 4250 4288 4324 4360 4381 LAT ft 546 553 559 566 571 575 579 582 585 588 591 5'93 595 595 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 3753 0.4 -0.4 0.0 3809 0.4 -0.4 0.2 3863 0.7 -0.5 0.7 3917 0.7 -0.5 0.7 3970 0.9 -0.8 0.7 4021 1.2 -1.1 0.6 4072 1.2 -1.1 0.6 4120 1.4 -1.4 0.1 4165 1.6 -1.6 -0.2 4211 1.6 -1.6 -0.2 4248 2.4 -2.4 0.7 4284 2.5 -2.5 0.9 4321 2.5 -2.5 0.9 4341 4.2 -4.2 0.5 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 4381 ft 82.2° TRUE VERTICAL DEPTH 100' INTERPOLATED Client Well Name Location Eastman Teleco Prudhoe Bay Drilling Group APEX GAS INJECTION PAD AGI5 Apex Gas Injection Pad Page 1 of 3 Date JAN. 17, 1993 Filename : 1172AGI5 Interpolated 100 ft of TVD MD C~L INC DIR TVD ft ft deg deg ft 0 0 0.0 0.0 0 100 100 0.1 33.7 100 200 100 0.2 67.4 200 300 100 0.3 101.1 300 400 100 0.6 135.8 400 5OO 600 700 8OO 901 1002 1103 1205 1307 1409 1512 1617 1722 1830 1939 2050 2165 2282 2404 2527 2652 2777 2902 3027 3152 3277 3400 3522 3644 3766 3888 4010 4132 4253 4373 100 1.2 172.6 500 100 1.8 208.6 600 100 2.7 157.0 700 100 4.0 114.1 800 101 6.7 103.7 900 101 101 102 102 103 103 105 105 108 109 111 115 117 122 123 124 125 125 125 125 125 123 122 122 122 122 122 122 121 121 8.8 95.5 1000 10.0 90.3 1100 10.9 86.7 1200 11.6 84.2 1300 13.4 82.6 1400 15.5 81.2 1500 17.3 81.3 1600 19.4 81.6 1700 22.4 82.2 1800 25.1 83.1 1900 27.1 84.3 2000 30.4 81.7 2100 34.0 78.1 2200 35.4 79.5 2300 36.3 80.9 2400 36.9 82.3 2500 37.0 83.7 2600 37.2 82.8 2700 37.3 80.5 2800 36.8 81.1 2900 36.2 81.7 3000 35.5 81.2 3100 34.7 80.4 3200 34.6 80.4 3300 35.0 80.8 3400 35.1 81.2 3500 34.8 81.3 3600 34.5 81.5 3700 34.2 81.3 3800 33.9 81.2 3900 VS ft 0 0 1 1 1 0 -1 1 4 14 26 43 61 81 104 128 159 191 231 274 323 379 439 509 581 655 730 806 881 956 1031 1102 1172 1242 1312 1381 1451 1520 1588 1656 LAT ft 0 -0 -0 -1 -1 -3 -4 -7 -10 -12 -14 -14 -14 -12 '--9 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 0 0.0 0.0 0.0 0 0.1 0.1 33.7 1 0.1 0.1 33.7 1 0.2 0.1 33.7 1 0.4 0.3 34.6 0 0.8 0.6 36.9 -0 1.1 0.6 35.9 2 2.1 0.9 -51.6 5 2.7 1.3 -42.8 15 2.9 2.7 -10.3 28 2.3 2.1 -8.1 44 1.5 1.2 -5.1 63 1.1 0.9 -3.5 82 0.8 0.7 -2.5 106 1.7 1.7 -1.6 -6 130 2.0 2.0 -1.3 -1 160 1.8 1.8 0.1 3 192 1.9 1.9 0.3 9 231 2.9 2.9 0.6 14 274 2 . 5 2 . 4 0.8 20 28 37 51 63 74 83 92 102 114 126 137 1-48 159 170 181 192 202 213 223 322 1.9 1.8 1.1 378 3.1 2.9 -2.3 438 3.4 3.0 -3.1 506 1.3 1.2 1.1 577 1.0 0.8 1.1 651 0.8 0.4 1.1 725 0.7 0.1 1.1 800 0.5 0.1 -0.8 875 1.1 0.1 -1.8 949 0.6 -0.5 0.5 1023 0.6 -0.5 0.5 1093 0.6 -0.6 -0.4 1163 0.7 -0.6 -0.6 1232 0.1 -0.1 -0.0 1301 0.4 0.3 0.4 1369 0.2 0.1 0.3 1438 0.2 -0.2 0.1 1507 0.2 -0.2 0.1 1574 0.3 -0.2 -0.1 1641 0.3 -0.3 -0.1 Client Well Name Location Eastman Teleco Prudhoe Bay Drilling Group APEX GAS INJECTION PAD AGI5 Apex Gas Injection Pad Page 2 Date JAN. Filename Interpolated of 3 17, 1993 : 1172AGI5 100 ft of TVD MD ft 4494 4614 4735 4858 4981 5106 5231 5356 5481 5605 5729 5852 5976 6100 6224 6349 6474 6600 6726 6853 6979 7104 7229 7352 7475 7598 7721 7843 7964 8085 8205 8324 8441 8558 8673 8785 8898 9006 9113 9220 C~L ft 121 120 121 123 123 125 125 125 125 124 124 124 124 124 124 124 125 126 126 127 126 125 125 123 123 123 123 122 121 121 119 119 117 116 115 112 112 108 107 107 INC DIR TVD VS deg deg ft ft 33.8 81.1 4000 1723 33.8 81.1 4100 1790 34.3 81.2 4200 1858 35.6 81.5 4300 1929 37.0 81.8 4400 2000 37.0 81.4 4500 2076 37.0 80.9 4600 2151 36.8 80.7 4700 2225 36.4 80.5 4800 2300 36.2 80.5 4900 2373 36.1 80.7 5000 2446 36.0 80.9 5100 2519 36.1 81.4 5200 2592 36.1 81.8 5300 2665 36.4 81.4 5400 2739 36.8 80.9 5500 2813 37.2 81.0 5600 2888 37.6 81.3 5700 2965 37.8 81.7 5800 3041 37.9 82.0 5900 3119 37.6 82.0 6000 3196 36.7 81.2 6100 3271 · 35.7 80.4 6200 3345 35.8 80.7 6300 3418 35.9 81.0 6400 3490 35.6 81.6 6500 3561 35.2 82.2 6600 3632 34.8 82.6 6700 3702 34.3 82.6 6800 3771 33.8 82.7 6900 3839 33.2 83.6 7000 3904 32.6 84.5 7100 3970 31.5 85.2 7200 4031 30.2 85.9 7300 4091 28.7 86.3 7400 4147 26.9 86.0 7500 4198 25.1 85.7 7600 4249 22.6 86.5 7700 4290 19.9 87.4 7800 4329 17.2 88.1 7900 4366 LAT DEP D'LEG ft ft °/100 233 1708 0.1 244 1774 0.0 254 1841 0.4 265 1912 1.1 275 1982 1.1 287 2056 0.2 298 2131 0.2 3i0 2204 0.2 322 2278 0.3 334 2351 0.2 BU I LD TURN o/loo °/lOO -0.1 -0.0 0.0 0.0 0.4 0.1 1.1 0.2 1.1 0.2 0.0 -0.4 0.0 -0.4 -0.2 -0.2 -0.2 -0.1 -0.2 0.0 346 2423 0.1 -0.1 0.1 358 2495 0.1 -0.1 0.2 369 2567 0.2 0.0 0.4 380 2639 0.2 0.0 0.4 391 2712 0.3 0.3 -0.3 402 2785 0.4 0.3 -0.4 414 2860 0.3 0.3 0.1 426 2935 0.4 0.3 0.3 437 3011 0.2 0.2 0.3 448 3088 0.2 0.0 0.2 459 3164 0.2 470 3238 0.9 482 3312 0.8 493 3383 0.2 505 3454 0.2 -0.2 0.0 -0.8 -0.6 -0.8 -0.6 0.1 0.2 0.1 0.2 5'15 3525 0.3 -0.2 0.5 525 3595 0.4 -0.3 0.5 535 3665 0.4 -0.3 0.3 544 3733 0.4 -0.4 0.0 553 3801 0.4 -0.4 0.1 560 3866 0.7 -0.5 0.7 567 3930 0.7 -0.5 0.7 572 3991 1.0 -1.0 0.6 577 4051 1.2 -1.1 0.6 581 4108 1.3 -1.3 0.3 585 4159 1.6 588 4210 1.6 591 4250 2.4 593 4289 2.5 595 4326 2.5 -1.6 -0.2 -1.6 -0.2 -2.4 0.7 -2.5 0.9 -2.5 0.6 Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : APEX GAS INJECTION PAD AGI5 Location : Apex Gas Injection Pad : : Page 3 of 3 Date JAN. 17, 1993 Filename : 1172AGI5 Interpolated 100 ft of TVD MD C~L INC DIR TVD VS ft ft deg deg ft ft 9270 50 16.0 87.8 7948 4381 LAT ft 595 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 4341 3.6 -3.6 0.3 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 4381 ft 82.2° ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 SEPTEMBER 7, 1993 MARION SLOAN BP EXPLORATION ALASKA INC. P O BOX 196612 ANCHORAGE, ALASKA 99518-6612 RE: 93-0002 PRUDHOE BAY UNIT AGI-5 COMPLETION REPORT. 93-0009 PRUDHOE BAY UNIT AGI-6 COMPLETION REPORT 93-0082 PRUDHOE BAY UNIT DS5-14A COMPLETION REPORT 93-0047 PRUDHOE BAY UNIT DS3-20A COMPLETION REPORT 93-0057 PRUDHOE BAY UNIT DS6-22A COMPLETION REPORT DEAR MARION SLOAN, OUR FILES INDICATE' THAT ARCO ALASKA IS THE OPERATOR OF THE REFERENCED WELLS. THESE WELLS HAVE REPORTED PRODUCTION TO US AND WE HAVE NOT RECEIVED THE APPROPRIATE COMPLETION REPORTS (407 FORMS) TO DATE. MAY AND JUNES MONTHLY PRODUCTION ?REPORTS INDICATE THAT THESE WELLS ARE GAS INJECTORS AND OIL PRODUCERS FOR YEAR 1993. WE HAVE NO PAPER WORK SHOWING THE.COMPLETIONS FOR THE MENTIONED WELLS. I AM FORWARDING THIS LETTER AS A RECORD FOR YOU AND ME. THANKS FOR YOUR QUICK RESPONSE ON THESE REPORTS. SINCERELY, STEVE MCMAINS STATISTICAL TECHNICIAN ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-10-93 REFERENCE: ARCO DIRECTIONAL DATA 12-20-92 2-25-93 2-27-93 4-19-93 4-9-93 3-19-93 3-23-93 4-18-93 2-23-93 2-26-93 3-7-93 3-13-93 4-6-93 4-15-93 3-7-93 4-1-93 12/6-23/92 1/23-2/6/93 MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MW]) Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey ~--AGI-8 ~- / A ,¥..rO~ r~/AOI-10 3-30-93 MWD Directional Please sign and return the attached copy as 12/30-1/15/93 MWD Directional Survey 12-9-91 MWD Directional Survey 1-15-92 MWD Directional Survey 1/92 MWD Directional Survey 2-9-93 MWD Directional Survey 1-16-93 MWD Directional Survey 12-27-92 MWD Directional Survey 1-18-93 MW]) Directional Survey 1-17-93 MWD Directional Survey 2-16-93 MWD Directional Survey 2-24-93 MWD Directional Survey 4-28-93 MWD Directional 'Survey 3-7-93 MWD Directional Survey 3-17-93 MWD Directional Survey Survey RECEIVED BY_, Have A Nice Day! Sonya Wallace ATO- 1529 CHEVRON # CLINT CHAPMAN # EXXON MOBIL Job#AKEI30010 Sperry Job#1209 BHI Ana Aha Job #AKEI30016 Sperry Job#AKMW30020 Sperry Job# 1188 Teleco Job#~,KEl30009 Sperry Job# 1192 Teleco Job#AKEI30012 Sperry Job#1202 BHI Ana Aha Ana Job# 1159 Teleco Job# 1175 Teleco Job# 1167 Teleco Job #AKM M911128 Sperry Job#AKMM911231 Sperry Sperry Ana Job#AKMW30003 Sperry Job#AKMM921231 Sperry Job# 1168 Teleco Job# 1172 Teleco Teleco Job# 1185-450 Teleco Job# 1185 Teleco Job#1190 Teleco Job# 1195-450 Teleco Job#1205 BHI receipt of data. ~s ~ 93059 .... ,~aO~ - .,o~(~/o~ ~ PB ~LL F~ES 9 BPX ~ ST. OF ~. {2 COP~) 9 LUC~LE JO~STON ARCO Alaskn, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 8-10-93 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS ct"6'"~c~--3-86 ~ ~''1%0° 4-22-93i)~ DLL/BCS/CNTH Run 1 J~196 8ch c~ 57_6.22A~%~l~q ~-3-93 O~ DLL/MLL/AC/CN/GR Run 1 JotS5949 Atlas ~_~c~2~9-5A ~q~ 3-16-93 9~k CDN/CDR . Run 1 J~127 8ch AGI-5 ~ll~> 4-20-930~ DLL/MLL/AC/GR 0~ ........ Run 1..Job~5900.01' Atlas c~%--°l AGI-6" 4-25-930~x DLL/MLL/AC/GR l~m ! Job~5915.01 Atlas Please sign and return ~he attached copy as receipt of data. D r F ~ ! I1 / -- /" //_ i~,EL. EIVEIJ '~' ' - . AUG ;3 1 199;~ //, AMskl Oil & (las Cons. .....-.,...,o Transit 93087 CENTRAL FILES (CH) CHEVRON D&M # BOB ~AS (OH/GCT) # EXXON MARATHON MOBIL # IqTTT.T.TT~ PB WEIJ, FILES R&D # BPX # STATE OF ALASKA TEXACO ~ ~ ~?~Thls is a revised tape, please replace one previously. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINALS 1-28 ~'~ y 6-18-93 3-25A }~'23 6-17-93 3-31 ~ V-iz 6-16-93 * 3-32 ~/~f~? 6-15-93 3-33 ~ ¥~ ~so 6-16-93 4-8 ?~-ro 6-11-93 5-14 ??-}~ 6-12-93 ** 6-22A~1.~6-6-93 6-22A ' ~ -6-10-93 7-25 ~I-Y ~. 6-6-93 9-44 f ~ ~ z~6-6-93 11-18 f/,- I~z6-7-93 14-6 ¥~- ~6-8-93 14-8 ?~,7 6-10-93 14-13 ~-'ld 16-13-93 14-15 tl-~ 6-8-93 16-4A tz-l~ 6-9-93 16-17~~'' zz~6-14-93 16-31 ~-~i 6-7-93 17-4 ~~ 6-14-93 AGI-5 5~- ~-6-13-93 AGI-6 ~-d~ 6-14-93 AGI-7 · _6-8-93 AGI-7 ~ ~ ~-t6-15-93 AGI-7 6-17,93 Prod Profile Completion Record Plug Setting Record Plug Setting Record Plug Setting Record Perf Record TBG Cutter Record Leak Detect Le~k Detect Perf Record Perf Record Production Log PITS /Le_~ k Detect Leak Detect Inj Profile Completion 'Record Prod Profile Perf Record Production Log Completion Record Completion Record Completion Record Perf Record R-n 1, 5" Sch R~_m 1, 5" Sch Run 1, 5" Sch R~_m 1, 5" Sch R~_m 1, 5" Sch R,m 1, 5" Sch Run 1, 5" Sch R~!n I 2" Sch Run 1, 5" Sch Run 1, 5" Sch Run 1, 5" Sch Run 1, 5" Sch Run 1, 5" Sch Rim 1, 2"&5" Sch Rim 1, 5" Sch Run 1, 5" Sch Run 1, 1"&5" Sch R~_~_n 1, 2"&5" Sch R~_m 1, 5" Sch Rim 1, 5" Sch R~m 1, 5" Sch Run 1, 5" Sch R~_m 1, 5" Sch R~_m 1, 5" Sch Run 1, 5" Sch AGI-8 ~3 ~$ ~/6-9-93 GR/CC~ Run 1, 5" Sch AGI-9~ ~ i~g 6-9-93 CzR/CCL Run 1, 5" Sch AGI-9i -t ~ 6-17-93 Pe~ Record R~ 1, 5" Sch ~ ~ON ~ MOB~ #BPX # STATE OF ALASKA * The correct API# for 3-32 is 504)29-I11141-00. ** The correct well -_~me for this log is 6-22A. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINALS * 1.1B~ t' °~6.20.93 1-16 ~.o:~ 6-25-93 1-22 ~--~,l 6-29-93 1-30 ~(~' ~ ~ 6-29-93 3-25A ~~ 6-27-93 3-30 ~~ 6-23-93 3-31 ~-~-23-93 3-33 ~-~/o 6-29-93 3-36 ~3~ 6-28-93 4-37 ~/~7 6-20-93 !!~'i?~AGI-6 ~ ~.o~ 4-25-93 AGI-8 ~-~6-19-93 4-40 ~ I~ !~6-20-93 5-3A ~t 6-18-93 5-26 ~q-~ ~ 6-25-93 6-4 ?~- ~z~-6-26-93 6-13 ~ -~ 6-25-93 9-49 ~ ~-~ 6-22-93 9-50 ~-~ 6-26-93 12-26¢~ 6-22-93 13-17 ¥~ 6-27-93 13-14 ?~-~ 6-28-93 13-20 ~ ~? 6-19-93 16-12 ~ 6-21-93 17-20 ~'~ff6-26-93 *** AGI-10 ~$~ 6-18-93 *** AGI-10~$ 6-18-93 Prod Profile R-n 1, 5" Sch Perf Record R~_~n 1, 5" Sch Production Log R-n 1, 5" Sch Leak Detect R.n 1, 5" Sch Perf Record R-n 1, 5" Sch Leak Detect Run 1, 2"&5" Sch Bridge Plug Setting R._n 1, 5" Sch Completion Record R.n 1, 5" Sch Perf Record Ru_n 1, 5" Sch Dual Burst TDTP (Borax) R.n 1, 5" Sch Completion Record Run 1, 5" Sch SBT/GR/CCL Run 1, 5" Atlas TDTP (Borax) Run 1, 5" Sch Production Log Run 1, 5" Sch Perf Record Run 1, 5" Sch Production Log Run 1, 1"&5" Sch -Production Log Run 1, 2"&5" Sch CNL R-n 1, 5" Sch Leak Detect Run 1, 2" Sch Leak Detect R.n 1, 2" Sch Plug Depth Record Run 1, 5" Sch Prod Profile Rlln 1, l"&5" Sch Production Log R._n 1, 5" Sch ~i..Acoustic.CBT Run 1, 5" Atlas Perf Record Run 1, 5" Sch GR/(X~ Run 1, 5" Sch Perf Record R-n 1, 5" Sch Please sign and return the attached .c~p~,. as receipt of data. .c,iv , Have A Nice Day~//~~ ~/' / Sonya Wallace APPROVED_ ATO- 1529 Trans# 93074 # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA t ECEIVED # PmZ,LZ~ 'JUL ~ 0 1993 # CLINT CHAPMAN ## ~x"XO~Mo~IL Na~ka 011 & Gas Cons. Co~i~bn AnChorage ~e c~ ~e f~ ~ I~ k 1-~. ~ ~ a ~d ~g, ple~ ~ ~~ c~ ~e~ ~e c~t ~It ~r ~I-10 ~ ~~2235~. ARCO ,~]~sk~, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-20-93 REFERENCE: ARCO OPEN HOLE FINALS 3-18A/ 4/10-17/93 MWD: DPR/GR ' 5-~,,~~ ~ 6-13-93 LWD: CDN * 5-3A 6-13-93 LWD: CDR * 5- / 6-13-93 LWD: CDN N/F * 5- .~ 6-13-93 LWD: CDN N/F OverlayRun 5-3Afl 6-13-93 LWD: CDN Run 5-3A n~6-13-93 LWI~. CDR Run ** AGI-5~ 4-20-93 BH Profile 1, AaI~'~ ~ 4-25-93 D~L/aR/SP 1, ** AGI-6/ n/° 4-25-93 BHCA/GR 1, # t~~'~ 4-~-5-93 ~H ~ofile AGI-6 ] ~ 2/11-,13/93 DPR/GR AGI-6r a~t 2/11-~3/93 DFP./GR A~-7~¢~ ~-- 2/1~4/28/93 DP~/a~ Aa~-7~ '. ;~ 2/154/28/93 A~-8~ ¢~' ~ 3/~6/93 ~R/C~ Aa~-8~ '~ ~{ 3/5~/93 - VP~/C~ AGI-9~ ~'~/~ 3/~5/7/93 DPR/GR AGI-9' 3/~5/7/93 DPR/GR A~-10~ 3/24-28/93 3/:~-:~/93 Dm~t/GR AT(~1529 Trans# 93070 # CENTRAL FILES # CHEVRON #D&M # BPX # STATE OF ~TASKA # MOBIL Runs 1-3, 2~'&5'~D BHI R~ns~ 1-3, ~'&~TVD BHI Run 1, :~'&~' Sch ~ 1, 2'~' Sch ~ 1, 2'~' ~h 1, 2"&5" ~h 1, ~'~~ Sch 1, 2'~~ Sch ~ 1, 2'~' Atlas ~ 1, 2'~' Aths ~ ~' Atlas ~ 2'~' Atlas ~ 2'~' Atlas ~ 1, ~' Aths R~ ~, 2'&~ T~o R~ ~, 2'&~~ Td~o R~ ~, 2'~~ B~ R~ ~, 2'&~~ B~ R~ 4, ~'~'~ B~ R~ 4, ~'~'~ B~ R~ ~, 2'&~ B~ R~ ~, 2'&~ B~ R~ ~4, 2'&5'~ B~ R~ ~4, 2'&~ B~ JUL ~ 0 199~ # EXXON # TEXACO The correct ~_~me for this well is 5-3A, and the logs are These logs are revised final prints, please replace previous logs. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 6-9-93 REFERENCE: \o-22,.. ~1~2~ 5-3-93 SSTVD ~-3~93 I)LL /]d:LL l aI~ I SP I Cai 5-3-93 BH Proffie 5-2-93 8STVD 5-2-93 BHCA/GR ~/~4-3X/9~ MWm. DPR/GR ~/~4.SX/9~ ~ DPt/aR 1/X1-15/96 ~ DF~/GR 1/11-15/9~ ~ DFR/GR 1/~4.~9/9S - ~ DP~/a~ 1/~4.~9/9S a~vrm. ~/~ Runs 4-7, R, mm 4-5, Rmm 4-5, Please sign and return the att~ch~ copy as receipt of datm Have A Nice Day! Sonya Wallace APPROVED ATO-1529 Trans# 9306~ ..... Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Teleco Teleco Teleco Teleco Teleco Teleco # CENTRAL FILES' # CHEVRON #D&M # CLINT CHAPMAN # EXXON M&RATHON # MOBIL PHILLIPS PB WELL FILES R&D BPX STATE OF AI2~KA TEXACO ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 6-9-93 REFERENCE: 14-22A 17-19 5-6-93 Static Pressure Run 1, 5" Sch 5-8-93 Prod Profile Run 1, 5" Sch 5-10-93 Production Run 1, 5" Sch 5-! Z-93 CBT/New Tt~/Jewelry Run 1, 5" Sch 5-10-93 Leak Detect/Spin/Temp/Press l~m 1, 2' & 5" Sch 5-4-93 USIT (Cement & Corrosion] (Color] Run 1, 5" Sch 5-3-93 InJ Proflle/Spin/Temp/Press l~m 1, 5" Sch 5-2-93 InJ Profile/PITS Run 1' [~' Sch 4-24-93 Leak Detect/Spin/Temp/Press Run 2, 5" Sch 5-7-93 D-__~! Burst/TDT-P (Borax] Run 1, 5" Sch 5-6-93 Vertilog Run 1, 5" Atlas 5-8-93 GR/ColIar Run 1, 5" Atlas 5-6-93 Perf Record Run 1, 5" Sch 5-7-93 GR/C~ Run 1, 5" Sch 5-10-93 CNL Run 1, 5" Sch 5-11-93 Leak Detect Run 1' 2' & t~' Sch 5-7-93 Peri Record Run 1, 5" Sch 5-9-93 TDT-P (Borax) Run 1, 5" Sch 5-3-93 Leak Detect/Spin/Terra_p/Press Run 1, 5" Sch 5-3-93 Perf Record Run 1, 5" Sch 5-4-93 Production Run 1, 5" Sch 5-5-93 CCL/Perf Record Run 1, 5" Atlas 5-8-93 SBT/GR/CCL ]~_m 1, 5" Atlas Run L 5" Sch Run 1, 5" Sch Run 1, 5" ~ch ]~m L 2' & 5" Atlas ~... [~_?L~~. ~I4 5-7-93 OR/CCL (Color) ~~.~GI-~ 5-10-93 G~/cci, (Color) ~~I.,6 5-10-93 GR/(XIL (Color) ~_.1 ;~..- C~ ~AGI4 5-$93 SI~T/GR/(XIL Please sign and return the attached copy as receipt of data~ RECEIVED BY__~~~ PB WELL ~ # BPX # STATE OF AIASKA ARCO/~t~ka, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-20-93 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS 18-29A-'~ ....~3'/5-2-93 ~0~2_ AGI-5~Tf~ 4-20-93~ DI.,L~.~-/~/CN/GR/ZDL/DEL2/SL DLLIACICNIGR DLLICNIZDLIGR DLLIACICNIGIt DLL/M~IACIGR Run 1 Job~~ Atlas Run 1 Job#5927 Atlas Run 1 Job~5930 Atlas Run 1 Job~ Atlas Run 1 Job~5900.01 Atlas Please sign and return ~he attac.hed copy as receipt of data. ., EiVE Have A Nice Day! Sonya W~_ll_~ce APPROVED ..... AT0-1529 Trans# 93061 CENTRAL FILES (CH) CHEVRON D&M # BOB OCANAS (OH/GC'T} # EXXON MARATHON MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO The correct APl# for 3-20A is 50-029-20980-01. ARCO Aluka, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-29-93 REFERENCE: ARCO 4-13-93 SSTVD Run 1, l"&.:~' Atlas 4-13-93 DLL/GR/SP Run 1, 2~&5' Atlas 4-13-93 BHCA/GR Run 1, 2~&5' Atlas 4-13.93 CNL/GR Run 1, 2"&b'~ Atlas 3-23-93 8STVD Run 1, l'&2' Atlas 3-23-93 DLL/GR/SP Run 1, 2"&5' Atlas 3-23-93 - BHCA/GR Run 1, 2~&5' Atlas 3-23-93 CNL/GR Run 1, 2"&5' Atlas 3-23-93 BH Profile Run 1, 5~ Atlas 3-31-93 DLL (Simultaneous) Run 1, 2"~" ach 3-31-93 BHCS/SSTVD Run 1. b'~ ~ch 3-31-93 BHC8 Run 1, 2"8:5" 8ch 3-31-93 CNL Run 1, 2"&5" 8ch 3/2631/93 MWD: DPR/GR Runs 1-3, 2"&5'~D Teleco 3/26-31/93 MWD: DPR/GR Runs 1-3, 2"&5'~rVD Teleco 4-17-93 SSTVD Run 1, 1'&2" Atlas 4-17-93 DLL/GR Run 1, 2"&5~ Atlas 4-17-93 ZDL/CNL/GR Run 1, 2"&5" Atlas 3/13-18/93 LWD: CDN Mad Pass Composite, 2"&5" 8ch 3/13-17/93 LWD: CDN Drilling Pass Composite, 2"&5" 8ch 3/13.18/93 LWD: CDR Mad Pass Composite, 2"&5' Sch 3/13-17/93 LWD: CDR Drilling Pass Composite, 2'&5" 8ch 3/13.18/93 LWD: CDN N/F Mad Pass Composite. 2"&5" 8ch 3/13.17/93 LWD: CDN N/F Drilling Pass Composite, 2"&5" 8ch 3/13-18/93 LWD: CDN Mad Pass TVD Composite, Ir'&5- 8ch 3/13-17/93 LWD: CDN Drilling Pass TVD Composite, 2"&.5" 8ch 3/13-18/93 LWD: CDR Mad Pass TVD Composite, 2'&.5" 8ch 3/13-17/93 LWD: CDR Drilling Pass TVD Composite, 2"&5" 8ch 4-6-93 SSTVD Run 1, l"&2~ Atlu 4-6-93 DLL/GR Run 1, 2"8u5" Atlas 4-6-93 BHCA/GR Run 1, 2"&5' Atlas 4-6-93 CNL/GR Run 1, 2~&5~ Atlas 4-6-93 4 Arm Cal/GR (BH Profile) Run 1, 5" Atlas 3-19-93 ~ Induction Electrolog Run 1, 2"&5" Atlas 3-20-93 CNL/GR Run 1, ~'&5" Atlas 4-20-93 DLL/MLL/GR/SP/Cal Run 1, 2~&b~ Atlas 4-20-93 BHCA/GR Run 1. lC&5' Atlas 4-20-93 BH Profile Run 1, 5" Atlas 3-28-93 SSTVD Run 1. l"&2" Atlas 3-28-93 DLL/MLL/GR/CM Run 1. 2"&5' Atlas 3-28-93 BHCA/GR Run 1, 2"&5" Atlas 3-28-93 BH Profile Run 1, 5" Atlas Please sign and return ~e ,ttach~d~copy as recegyt of data. RECEIVED BY__~ Have A Nice Day[ ~ 8onya Wallace C[i V Trans#93051 AT0-1529 ~PROVED * C~ON * PS ~LL ~ ~ D · ~ ~ka 011 & Gas Cons. Commissl~ , c~ c~ Anchorage t ~ON t STATE OF ~~ ~ MOB~ t T~CO * The lo~s for this well all say field, but axe actxmlly .finals. ARCO ;1AmkA; Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-22-93 REFERENCE: ARCO CASED HOf-~- FINALS 3-7-93 Peff Record Run 1, 2-27-93 CNL ]~m 4, 2-27-93 CNL Run 2, 2-28-93 CNL Run 2, 3-5-93 Dual Burst TDTP (Borax) Run 1, 3-1-93 CNL l~m 2, 3-1-93 CNL Run 2, 3-6-93 Dual Burst TDTP Run 1, 2-28-93 CNL Run 2, 2-25-93 Dual Burst TwrP (Borax) Run 1, 3-7-93 Collar (Jet TBG Cutter) l~m 1, 3-3-93 Vertilog l~m 1, 3-2'93 Peri Record la, m 1, ~" Please .sign and return the attached copy as receipt of data. RECEIVED BY_~7~ ~/~_/~/1~ Have A Nice Day.* Sonya Wallace ATO-1529 Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Atlas Sch Atlas Sch Sch Atlas Sch Atlas Atlas APPROVED_.~~___ Trans# 93042r # CENTRAL FILES # CHEVRON D&M # LUCILLE JoHNsTON # EXXON MARATHON # MOBIL .# PHIL~ PB WELL ~ R&D ' # BPX # STATE OF ALASKA TEXACO The correct APl# for 1-31 is 50-029-21626-00. The correct well name for this log is 16-4. /~-~" STATE OF ALASKA --'~ S~~)~ " Al_~o~, OIL AND GAS CONSERVATION COMMISS.,.,N - ' EPORT OF SUNDRY WELL OPERATION 1. Operations performed: Operation shutdown X Stimulate Plugging Perforate Pull tubing Alter casing Repair well Other' ~/'~'~.~_., 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or K ARCO Alaska, inc. Development __ feet Exploratory 3. Address Stratigraphic 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 2055' NSL, 2474' WEL, SEC. 36, T12N, R14E, UM AGI-5 At top of productive interval 9. Permit number/approval number N/A 93-02 At effective depth 10. APl number N/A 50- 029-22327 At total depth 11. Field/Pool 2650' NSL, 1886' EWL, SEC. 31, T12N, R15E, UM Prudhoe Bay Field~Oil Pool 12. Present well condition summary Total depth: measured 9335 feet Plugs (measured) true vertical 8010 feet Effective depth: measured N/A feet Junk (measured) true vertical N/A feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 76' 20" 27 cu ft Arcticset 106' 106' Surface 3856' 13-3/8" 2167 cu #"E"/460 cu # "G" 3896' 3506' Intermediate Production 9287' 9-5/8" 517 cu ft Class "G" 9323' 7999' Liner Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) None R E C E IV E a Packers and SSSV (type and measured depth) None I~/~R 0 z~ 13. Stimulation or cement squeeze summary AlasJ<a 0Jj & Gas Coils. Intervals treated (measured) Anchorage Treatment description including volumes used and final pressure 14. Representative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well,~_,Op~ratio~s x Oil Gas Suspended Service Aoex Gas Iniector 17. I herein! ce~. that t~ ~orego~ng is true an~ correet.~ thff best of my knowledge. Signed .,"~" '~/~ ~ ~'~/~ '~ ~ Title Drillin~ Engineer Supervisor Date h?''~~''s Form 10-"4'04 Rev 06/1 SUBMIT IN DUPLICATE BP/AAI SHARED SERVICE WELL: AGI-5 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: DAILY OPERATIONS PAGE: 1 ACCEPT: 01/17/92 09:00 SPUD: 01/18/93 01:30 RELEASE: 02/02/93 09:00 OPERATION: DRLG RIG: AUDI 2 WO/C RIG: 01/18/93 ( 1) TD: 0'( 0) 01/19/93 ( 2) TD: 943' ( 943) 01/20/93 (3) TD: 2890' (1947) 01/21/93 ( 4) TD: 3896' (1006) 01/22/93 (5) TD: 3896' ( 0) 01/23/93 ( 6) TD: 6167' (2271) 01/24/93 ( 7) TD: 7507' (1340) 01/25/93 (8) TD: 8120' ( 613) 01/26/93 (9) TD: 8515'( 395) RIGGING UP MW: 0.0 VIS: 0 MOVING RIG. ACCEPT RIG AT 2100 HRS 1/17/93. N/U DIVERTER, MIX SPUD MUD. DRILLING MW: 8.6 VIS:172 MU BHA & MIX MUD. DRLG TO 608. WIRELINE SURV, POH, CHG OUT MUD & ORIENT. SERV RIG. TIH, REAM TO 608. DRLG TO 943. DRILLING MW: 8.6 VIS:172 DRLG TO 2053. CIRC, TRIPPING. TH. CBU, SHORT TRIP. DRLG TO 2890. CIRC & COND MUD MW: 9.3 VIS:120 DRLG TO 3896. CIRC, SHORT TRIP. SROP SURV, POH. RETRIEVE SURV. RU & RUN 13-3/8 CSG. RIG CMT HEAD & CIRC. DRLG CMT. MW: 9.3 VIS: 51 CIRC. PUMP 95 BBLS WATER, 386 BBLS PERM 'E' CMT, 82 BBLS TAIL CMT W/ 2% CACL. DISP W/ MUD. NO BUMP PLUG. N/D DIVERTER. TOP JOB. INSTALL WELLHEAD. N/U BOPE. TEST BOPE. RIH W/ BHA. CIRC. TEST CSG. OK. DRLG CMT, FLOAT EQUIP. SHORT TRIP MW: 9.1 VIS: 36 DRLG CMT TO 3906, CBU & LOT. DRLG TO 4949. CBU, SHORT TRIP, DLRG TO 6167. CBU, SHORT TRIP TO 6167. TRIP MW: 9.4 VIS: 40 SHORT TRIP. DRLG TO 7290,C BU. SHORT TRIP. DRLG TO 7507, CBU. DROP SURV, POH. DRILLING MW: 9.5 VIS: 42 POH, RETR SRUV, CHG OUT MWD, BIT. TIH W/DC, CHECK MWD & MTR. RIH. REAM TO 7507. DRLG TO 7833. REPLC LINER & SWAB ON MUD PUMP. DRLG TO 8120. CUT DRILG LINE MW:10.1 VIS: 47 DRLG F/8120 TO 8264. CURC OUT GAS CUT MUD. DRLG F 8264 TO 8405. CIRC FOR SHORT TRIP, FINISH WT UP MUD. POH TO 7491. SERVICE RIG. RIH 8405. DRILG F/8405 TO 8515. TORQUED UP. CIRC & PUMP PILL. POH, DOWN LOAD TELECO. LOST CONE & 1/2 SHANK OFF BIT. MAKE UP GLOBE BASKET & TRIP IN HOLE TO 3888. CUT DRLG LINE. RECEIVED MAR 0 4 199, Alaska Oil & Gas Cons. 6ommissio~ Anchorage WELL : AGI-5 OPERAT-ION: RIG : AUDI 2 PAGE: 2 01/27/93 (10) TD: 8517' ( 2) 01/28/93 (11) TD: 8690' ( 173) 01/29/93 (12) TD: 9335'( 645) 01/30/93 (13) TD: 9335'( 0) 01/31/93 (14) TD: 9335' ( 0) 02/01/93 (15) TD: 9335' ( 0) 02/02/93 (16) TD: 9335' ( 0) MILLING MW:10.1 VIS: 44 RIH. TAG FILL @ 8508, WASH TO 8515, WORK OVER FISH. TOH. CLEAN JUNK BSKT. SERVICE RIG. WORK OVER FISH, CUT 16" W/JB. POH, NO FISH. RIH W/MILL TO 8515. MIL F/8515 TO 8517. DRILLING MW:10.0 VIS: 46 MILL ON JUNK, POH. MU BIT & RIH TO 8518. DRILL TO 8624, POH. MU BHA, TEST MTR, RIH TO 3888. TIH TO 8522. LOG W/MWD TO 8624. DRLG TO 8690. POH MW:10.0 VIS: 43 DRLG F/8690'-8988' SERV. RIG, DRLG F/8988'-9163', WORK ON #2 SCR, DRLG F/9163'-9335', CBU, SHORT TRIP, F/9335'-7464', TAG BTM, TORQUE UP, WOULD NOT ROTATE, CBU, POH SET STRM PKR MW:10.0 VIS: 45 POH, LD MTR, DOWN LOAD MWD & LD. PULL WEAR RING, TROUBLE W/LDS. SET PLUG, TEST BOPE, CHG OUT RAMS. MU FISH ASSY & RIH TO 3830. SERV RIG. RIH, WASH. POH, RECOVRD FORMATION & BEARINGS. LD JBSKT. SET STORM PKR. MILLING ON JUNK MW:10.1 VIS: 43 ND BOP. CHG OUT SPLIT SPEED & NU BOP. TEST HEAD & TBG SPOOL. RIH. WASH TO BTTM, TRY TO ROTATE, SITTING ON JUNK. CIRC & COND MUD. POH, CHG BHA, CLEAN B BASKTS. RIH TO 9335, NO FILL. MILL ON JUNK. TEST TREE MW: 8.5 VIS: 0 RUN 9-5/8" CSG, CIRC VOL, CIRC, PUMP 92 BBLS CMT, INSTALL 9-5/8" PACKOFF, TEST W/5000 PSI, INSTALL WEAR RING, RIH TO 2000', DISPLACE W/DIESEL, ALLOW TO U-TUBE, POH, PULL WEAR RING, CHG RAMS TO 5", N/D BOPE, INSTALL TBG HGR. REFELCTED COST TO DATE IS INCORRECT. CORRECT COST TO DATE = $1,375, 782. RIG RELEASED. MW: 8.5 VIS: 0 F/P AGI-3 ANNULUS. RIG RELEASED @ 09:00 HRS, 2/2/93. SIGNATURE: (drilling superintendent) DATE: RECEIVED M,. 0 4 t99,3 Alaska Oil & 6a:~ Oons. OommiS¢On Anchorage RECEIVED ]tlE IORANDUM STATE OFALASKF4 TO: Leigh Griffi DATE: Jan 21, 1993 Commissioner " THRU: Blair Wondzell '¢~/'?~o~ P.I. Supervisor FROM: I D~oug Amos Petroleum Inspector FILE NO: DA-121-2. DOC PHONE NO.: 279-1433 SUBJECT: BOPE Test AUDI Rig 2 AAi AGI-5 PDT No. 93-02 Pt Mclntyre Field Thursday Jan. 21,1993: John Spaulding and I traveled this date from AAI's PBOC to Pt. Mclntyre AGI-5 to witness the BOPE test at AUDI Rig 2. As the attached AOGCC BOPE Inspection report indicates there were no failures, the drilling crew was very professional and knowledgeable in the testing procedure. John had no difficulty with the test procedure and seemed to be very comfortable with the crew and rig pusher. He has a good knowledge of the rig equipment, testing procedure and the overall operation and use of the different components. In Summary, John Spaulding and I witnessed the successful BOPE test at AAI's Pt. Mclntyre AGI- 5 well on AUDI Rig No. 2. There were no failures and the rig crew was knowledgeable in the testing procedure. Attachment cc; Leigh Griffin Blair Wondzell STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover:~ Drlg Contractor: AK. UNITED DRILLING INC. Rig No.~ Operator: ARCO ALASKA INC. Well Name: PT. MclNTYRE AGI-5 Casing Size: 13 3/8" Set ¢_, 3.888 Feet Test: I,qitia X Weekl'y, Other 2 PTD # 93-02 Rep. Rep. Location: Sec. 36 T. DATE: 1/2!/93 Rig Ph.# 659-4605 JIM GAFFNEY DANNY HEBERT 1;'N R. 14E Merd. Umiat Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Qu~m. Location Gen.: X Welt Sign X Upper Kelly 1 Housekeeping: X (Gen) Drl. Rig X Lower Kelly Reserve Pit X Ball Type Inside BOP I BOP STACK: Ann. Preventer Pipe Rams Blind Rams Chk/Ln Valves HCR Valves Kill Line Valves Check Valve Test Qua. Pressure P/F 1 2,500 P 1 5,000 P I 5,000 P 2 5,000 P 2 5,000 P 1 5,000 - P 0 5,000 P MUD SYSTEM: Light Alarm Trip Tank Yes Yes Pit Level Indicators Yes Yes Flow Indicator Yes Yes Gas Detectors Yes Yes Pressure P/F 5,000 P 1 5,000 P 1 5,000 P 5,000 CHOKE MANIFOLD: No. Valves 11 No. Flanges 29 Manual Chokes 2 Hydraulic Chokes 5,000 5,000 5,000 I 5,000 P ACCUMULATOR SYSTEM: System Pressure 2,900 I P Pressure After Closure 1,600I P 200 psi Attained After Closure minutes 42 sec. System Pressure Attained 2 minutes 25 sec. Blind Switch Covers: Master: YES Remote: YES Nitgn. Btl's: 6 @ 1900 Psig. Failures None Test Time 2 1/2 Hours Repair or Replacement of failed equipment to be made within days. Notify the Inspector and follow with Written/Faxed verifioation to Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 If your call is not returned. Please contact the Petroleum Inspector Supervisor a 279-1433. REMARKS: -he drilling crew as well as John Spaulding were knowledgeable about the testing procedure and the function end use ofthe BOP equipment. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector Rev. i 2/93 ISTATE WITNESS REQUIRED? YES __ Yes NO_ 24 HOUR NOTICE GIVEN YES Yes NO Waived By: Witnessed By: BOP 121-2XLS N/A SiFned: Dou~l Amos & John Spauldin~l ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J, HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Janua~ 11 1993 Mike Zanghi, Drlg Engr Supv ARCO Alaska Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit AGI-5 ARCO Alaska Inc 93-02 2055'FSL. 2474'FEL, Sec 36, T12N. R14E, UM 2620'FSL. 2527'FEL~ Sec 31, T12N, R15E, UM Dear Mr Zanghi: 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. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of injection wells must be demonstrated under 20 AAC 25.412 and 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission at 279-1433. Yours truly, Russell A Douglass Commissioner BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill DIlb. Type of well. Exploratory E] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-11 Service [] Development Gas [] Single Zone [] Multiple Zone [] ... ;5. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 49.2feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool . .P.O. Box 196612, Anchoraae. Alaska 99519-6612 ADL 34628 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(~,e 20 ^AC 25.02s) 2055' FSI_, 2474' FEL, Section 36, T12N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well number Number 2600' FSL, 2701' FEL, Section 31, T12N, R15E, UM AGI-5 U-630610 At total depth 9. Approximate spud date Amount 2620' FSL, 2527' FEI_, Section 31, T12N, R15E, UM January 12, 1993 $200,000.00 .... 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line · 2055 feet AGI-4 @ 50' MD ,~ 119 feet 2560 9965' MD / 8492' TVDieet 16. To be completed for deviated wells 17. Anticipated pressure (,,,e 2o ,,,AC 2s.o3s (e)(2)) Kickoff depth 5oofeet Maximum hole angle 35.180 Maximum surface 2970Ps~g At total depth (TVD) 8800',/3850pslg 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) . 30" 20" 91.5# H-40 Weld 76' 30' 30' 106' 106' 11 yds ArtcticSet 16" 13-3/8" 68# L-80 BTC 3829' 29' 29' 3858' 3500' =~s,,~ pF'e/~,cu,~'/~,~' , .... 12-1/4" 9-5/8" 47# L~80 NSCC 9387' 28' 28' i 9415' 8042' 575 cu ft Class 'G' 8-1/2" 7" 26# L-80 NSCC 835' 9265! 7920' 9965' 8492' 144 cu fl Class 'G' .... 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary . Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Surface Intermediate Production ,j~,[~ - 5 '~oJe~ -Liner A~aska Oil & Gas Coi~,s. Comm~ss~o~ Perforation depth: measured true vertical Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program l~l Drilling fluid program [] Time vs depth plot [] Refraction analysis F'l Seabed report[] 20 AAC 25.050 requirements[] 21. ! herebYsigned certi~ ~hat t.l~e foregoing, , ~'~ ~ ,.-.. is true and CommissionC°rrect to t~te best. of my knowledgeT~e~tD~nguse OnlyEngineer Supervisor Date/"~'%'~-~ Permit Number IAPI nUmber IApproval date ISee cover letter 93-c .z 150- .z z 7 ! ;~//" Y~ Iforother requirements Condition~ of approval Samples required [] Yes J~No Mud log required []Yes l~ No Hydrogen sulfide measures [] Yes [] No Directional survey required J~] Yes [] No Required working pressure for BOPE 1-12M; i"I3M; /I~5M; r-IlOM; 1-115M; Other: OR~,~i~L SIGNED BY by order of Approved by .eUSSEt~L A. DouGLA~ Commissioner the comm,ssion Date / '/]'~'.. Form 10-401 Rev. 12-1-85 Submit in triplicate WELL PLAN Well: APEX GAS INJECTOR #5 (AGI #5) LOCATION: Surface: Target: T.D.: 2055' FSL, 2474' FEL, Sec. 36, T12N, R14E 2600' FSL, 2701' FEL, Sec. 31, T12N, R15E 2620' FSL, 2527' FEL, Sec. 31, T12N, R15E ESTIMATED START: 12JAN92 OPR. DAYS TO COMPLETE: 20 (1 6 days drilling, 4 days completion) CONTRACTOR: AUDI RIG #2 MAX ANGLE/SECT COURSE/KOP/BUILD/MAX DEP: 35.18°/S96.69E/500'/1.5°per 100' to 1500' md then 2.0° per 100' to 2509' md/4852' Estimated Ground level elevation is 13' AMSL. KB to ground level elevation is 36'. Item TVD(BKB~ MD(_BKB_) Hud Wt. 20" CONDUCTOR 106 106 8.5 13-3/8" SHOE 3500 3858 9.0 9-5/8" SHOE 8042 9415 TOP SADLEROCHIT 8047 9421 9,2-10.0 7" SHOE 8492 9965 9.2-10.0 TARGET 8245 9663 9.2-10.0 TOTAL DEPTH 8492 9965 9.2-10.0 CASING PROGRAM: Hole Csa Wt Grade Conn Lenath Top Btm _ -- 30" 20" 91.5# H-40 WELD 76 30 106 16" 13-3/8" 68# L-80 BTC 3829 29 3858 12-1/4" 9-5/8" 47# L-80 NSCC 9387 28 9415 8-1/2" 7" 26# L-80 NSCC 835 9265 9965 COMPLETION: Tubing: 7" GLMs: None Packer: 26# L-80 NSCC 9188 27 9215 9-5/8" x 5-1/2" PERMANENT PACKER set at 921 5 MD or +/- 50' above Top of liner LOGGING PROGRAM: Open Hole 12-1/4" hole: 8-1/2" hole GR/RESISTIVITY WHILE DRILLING TO PICK CASING POINT. GR/RESISTIVlTY WHILE DRILLING ACROSS SADLEROCHIT Cased Hole SBT IN 9-5/8" before running tubing (GR to be run up to 1 3-3/8") , RECEIVED JAN - 5 t99,l AJaska Oil & Gas Cons. CommisSion Anchorage Ar .-X GAS INJECTOR #5 (AGI DRILLING DISCUSSION AGI #5 is the fifth of a ten well program at the new Apex Gas Injection pad. All ten wells are to be gas injectors targeted to the apex of the Prudhoe Bay gas cap. They are intended to meet the additional gas injection requirements associated with the GHX-2 project and to "strip" residual liquid hydrocarbons from the gas cap. All ten bottom hole locations lie within an area where the Lower Cretaceous Unconformity truncates the top of the Ivishak Sand. Therefore the Cretaceous shales ("K" shales) will directly overlie the Ivishak sand injection interval (target interval) comprised of Zones 1,2, 3, and partially truncated Zone 4. Ivishak sand thicknesses are likely to range between 350' and 405'. None of the wells are expected to encounter Putt River, Sag River, Shublik, or an oil column. The proposed casing program is the conventional 20" conductor x 13-3/8" surface casing x 9-5/8" intermediate casing x 7" liner. Gas tight connections will be used on the 9-5/8" intermediate casing as well as the 7" liner. 7" tubing with 5-1/2" tailpipe will be the completion assembly. This assembly will be run with a completion rig after the drilling has moved off the well. ANNULAR INJECTION The 13-3/8" x 9-5/8" annulus of AGI #2, AGI #3, and AGI #4 may be available for injection purposes. Ensure any annulus has been properly permitted before commencing injection. The 13- 3/8" x 9-5/8" annulus on AGI #1 is not to be injected into. Fluids can be injected at the central CC-2 injection facility. ADEC has informed Prudhoe Bay Drilling that only associated fluids from drilling operations can be pumped down surface x intermediate annuli. Completion fluids CANNOT be injected down the aforementioned annuli. SHUTDOWN OF WELL OPERATIONS Shutdown of well operations once 9-5/8" casing has been set and cemented is planned for wells AGI #3 thru AGI #9. Wells AGI #3- AGI #9 will be drilled to 12-1/4" hole TD, 9-5/8" casing run and cemented. At this time operations will be shutdown and the rig will move to the next well and repeat the process. AGI #10 will be drilled to 8-1/2" TD, 7" liner run, and the well completed. Once AGI #10 is completed the rig will make its way back drilling 8-1/2" hole, running 7" liner and completing all the wells in which operations were shutdown. As per conversation with AOGCC (B. Wondzell) on 30DEC92 shutdown and resumption of well operations approval will be included as part of the permit approval-as long as the process is outlined in the PROPOSED DRILLING AND COMPLETION PROGRAM associated with this package-and therefore no application for sundry approval will be necessary for shutdown/resumption of operations. The decision to drill AGI #3- AGI #10 as described above is based solely on economics and therefore dictated by prudence alone. There are no known hydrocarbon bearing sands between surface and 9-5/8" casing point in any of the AGI wells. All 9-5/8" casing points are estimated to be above the top of the Sadlerochit sands. Operations on AGI #5 are expected to resume on or about 8APR93. All ten wells are estimated to be drilled and completed by 1MAY93. If there are any questions or if further information is required please contact J. E. Robertson at 564- 5510. FREEZE PROTECTION The 7" tubing along with the 7" x 9-5/8" annulus will be freeze protected with diesel before the drilling rig moves off the well. CLOSE APPROACHES WELLNAME SLOT DISTANCE DEPTH (" TVD) AGI #1 AGI #1 477' 900' TVD AGI #2 AGI #2 360' SURFACE AGI #3 AGI #3 238' 500' TVD AGI #4 AGI #4 118' 50' TVD LGI #08 LGI #08 570' 7300' TVD RECEIVED JAN - 5 '{99;5 Alaska 0il & Gas Cons. o0mmiSSi0~ Anchorage . . . . 7. 8. 9. 10. 11. 12. 13, 14. PROPOSED DRILLING AND COMPLETION PROGRAM AGI #5 Procedure MIRU drilling rig. Notify AOGCC of upcoming diverter function test. N/U diverter and function test same. Drill 16" hole to surface casing point. Run and cement surface casing. Nipple up BOPE and function test same to 5000 psi. PU 12-1/4" BHA and RIH. Test casing to 3500 psi for 30 minutes. Drill 10' of new hole and perform leak off test, Drill intermediate hole to intermediate casing point. MU and run 9-5/8 casing string and cement as per well plan. seawater RIH to 2000' MD and displace to diesel. ND BOPE. NU dryhole tree and test to 5000 psi. Release rig. Move off. SHUTDOWN OF OPERATIONS Bump cementing plug with RESUME OPERATIONS MIRU. ND dryhole tree and NU BOPE. Test BOPE. RIH. Displace diesel cap w/seawater. Drill to 9-5/8" shoe. Displace wellbore w/"drill in" mud. Continue drill/LOG 8-1/Z" hole through reservoir to TD. MU 7" liner on 5" DP. RIH to TD. Displace wellbore w/completion fluid. Set liner hanger and liner top packer. POOH. Run 7", L-80 tubing and packer assembly with SSSV. Freeze protect with diesel. Test tubing and casing to 4000 psi. Have witnessed by state. NU tree and test to 5000 psi. Release drilling rig. ° Anticipated BHP: ° Maximum Anticipated Surface Pressure: ° Planned Completion Fluid: Notes: a. 3850 psi @ 8800' TVD SS 2970 psi 9.6 ppg filtered brine The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. b. Maximum surface pressure is based on BHP and a full column of gas to TD (0,10 psi/ft). No potential productive zones are anticipated above 9-5/8" casing shoe. C. No potential hazardous levels of HZS are anticipated in this well. RECEIVED JAN - 5 993 Alaska 0il & Gas Cons. Commission Anchorage ,-.JD PROGRAM: Well AGI//5 The mud program for this well shall follow the new Mud Policy. The.following are the recommended mud parameters. MUD SPECIFICATIONS- SURFACE HOLE Surface: Casino ooint: _ . Mud Weight: ppg 8.5 - 9.5 8.5 - 9.0 Funnel Viscosity sec/qt ~300 <1 O0 YP Ibs/lOOftp 40- 60 ZO - 40 10 sec Gel lbs/100ft2. 30 - 60 15 - zO 10 rain Gel lbs/100ftZ 60 - 80 2.0 - 30 pH - 9.0 - 10 9.0 - 10 APl Fluid loss mi/30 min 15-Z5 15-25 Hardness mg/I < 2.00 <2.00 MUD SPECIFICATIONS-INTERMEDIATE HOLE Surface casing shoe to Top of Sadlerochit Sandstone: LSND Gel/Water System Mud Weight ppg 9.2.-10.0 Yield Point lbs/100ft2. 10 - 15 10 sec Gel lbs/100ft2 5 - 10 10 min Gel lbs/100ft2. 10 - 2.0 APl Fluid Loss mi/SO min 6-8 pH - 8.5 - 10.0 Hardness mg/I <2.00 MUD SPECIFICATIONS-PRODUCTION INTERVAL: Build new mud system to replace mud used in intermediate hole. Mud Weight ppg 9.0-9.5 Yield Point lbs/100ft2 20- 30 10 sec Gel lbs/100ft2 18 - 22 10 min Gel lbs/100ft2 20 - 24 APl Fluid loss mi/30 min 6.0 - 8,0 pH - 9.5 - 10.0 Hardness mg/I <2.00 RECEIVED JAN - § Alaska 0il & Gas Cons. Commission Anchorage The mud salinity should be compatible with the Reservoir logging program. The mud will be run at _+40,000 ppm chlorides. RUN LOW SHEAR RATE VISCOSITY AT 40,000+ Centipoise on mud system. AGI #5 Casing Design SURFACE CASING 13-3/8" 68#/FT K-55 & L-80 BTC CASING BURST COLLAPSE K-55 3450 1950 L-80 5020 2260 PBYS (#) 1069000 1556000 TJYS (#) 1300000 1585000 Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. Worst case will be in the K-55 casing, which has no back up gradient. LOT (ppg) TVD (FT) SI PRESSURE 14 3500 2198 Burst S.F. 1.57 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 3500 1729 Collapse S.F. 1.31 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 68 3858 PBYS Tension S.F. 4.77 Mud Wt. 9.5 ppg TJYS 5.80 String Wt. (#) 224252 RECEIVED JAN - 5 Alaska Oil & Gas Cons. Commission Anchorage AGI #5 Casing Design Production Casing 9-5/8", 47#,L-80,NSCC Casing GRADE BURST L-80 6870 COLLAPSE PBYS (#) TJYS (#) 4750 1086000 1161000 Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at the surface, which has no back up gradient. SITP 3850 Burst S.F. 1.78 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse press 10.2 8047 0.1 3463 Collapse S.F. 1.37 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 47 9415 PBYS Tension S.F. 2.91 Mud Wt. 10.2 TJYS 3.11 String Wt. (#) 373518 RECEIVED JAN - 5 t99;5 Alaska Oil & Gas Coils. Commission Anchorage AGI #5 Casing Design PRODUCTION LINER 7", 26#,L-80,NSCC Casing GRADE BURST L-80 7240 COLLAPSE PBYS (#) TJYS (#) 5410 604000 667000 Burst Pressure Calculation Burst rating based on formation pressure on top of 9.7 ppg fluid Fluid wt (ppg) back up (ppg) Burst Pressure SITP 9.7 9.5 3942 3850 Burst S.F. 1.84 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse Press 10.2 8492 0.1 3655 Collapse S.F. 1.48 Tension Calculation Based on full string weight in mud Casg Wt. (#Iff) MD (ET) 26 700 Mud Wt. String Wt. (#) 10.2 15363 Tension S.F. PBYS TJYS 39.32 43.42 RECEIVED Alaska Oil & Gas Co~s. Commission Anchorago CEMEN, PROGRAM - HALLIBURTON ,.,6RVICES 13 3/8" SURFACE CASING CASING SIZE: 13 3/8", 68# CIRC. TEMP: 60°F LEAD CEMENT TYPE: TYPE 'E' PERMAFROST ADDITIVES: n/a WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx APPROX #SACKS: 1068 PUMP TIME: 4:30 hrs MIX WATER: 11.63 gps FW Mix water temp: 50-65F TAIL CEMENT TYPE: CLASS G ADDITIVES: 2% Calcium Chloride WEIGHT: 15.8 ppg YIELD: 1.16 ft3/sx APPROX #SACKS: 400 PUMP TIME: 4 hfs MIX WATER: 5.00 gps FW Mix water temp: 50-65 F TOP JOB CEMENT TYPE: TYPE "C" PERMAFROST (if necessary) ADDITIVES: n/a WEIGHT: 15.6 ppg YIELD:0.94 ft3/sx APPROX #SACKS: 250 PUMP TIME: 2:30 hfs MIX WATER: 3.5 gps FW Mix water temp: 50-65 F SPACER: 100 bbls fresh water ahead of lead slurry. The WATER temperature should be 50-65F CEMENT VOLUME 1. Lead slurry to surface w/100% excess. 2. Tail slurry volume 400 sx 3. Top job volume +/- 250 sx. 9 5/8" INTERMEDIATE CASING CASING SIZE: 9 5/8", 47# CIRC. TEMP 135°F TAIL CEMENT TYPE: CLASS G ADDITIVES: 0.2% CFR-3 (Dispersant) + 0.25% HR-5 (Retarder) + 0.2% Halad 344 (Fluid Loss) WEIGHT: 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.00 gps FW APPROX #SACKS: 500 PUMP TIME: 4 hrs Mix water temp: 70-80 F SPACERS: Pump 20 bbls Alpha(ARCO) Preflush; 50 bbls Alpha(ARCO) spacer @ 11 ppg. OTHER CONSIDERATIONS: Continuously mix tail slurry. Displace at 12-15 bpm. CEMENT VOLUME 1. Lead Slurry will not be needed unless the WEST SAK and UGNU give a hydrocarbon show. 2. Tail Slurry to 1000' MD above shoe w/30% excess. 7" LINER RECEIVED CASING SIZE; 7", 26# ,JAN - § i993 CIRC. TEMP: 140 ° F Alaska Oil & Gas Cons. Commission CEMENT TYPE: CLASS G Anchorag~ ADDITIVES: 0.2% CFR-3 (Dispersant)+0.4% HR-5(Retarder)+0.3% Econolite (extender) + 0.4% HALAD 344 (Fluid Loss) + 2% KCI (Clay control) + +0.01% D-AIR-3 (defoamer)+0.9% LAP-1 (Fluid Loss) +0.1 gps Stabilizer 434B. WEIGHT: 15.7ppg YIELD:1.20 ft3/sx MIX WATER: 5.0 gps APPROX #SACKS: 125 PUMP TIME: 3:30 hrs + 1 hr mixing @surface FLUID LOSS: 150 cc Mix water temp: 70-80 F PREFLUSH: 20 bbls ARCO preflush + 2% KCL SPACER: 50 bbls ARCO spacer + 296 KCL, weighted to 11 ppg OTHER CONSIDERATIONS: Batch mix the cement slurry. Perform 'fluid loss test on the batch mixed slurry. Fluid loss should be 20-30cc. Displace @ 8-10 bpm. LINER CEMENT VOLUME 1. Open hole (8 1/2" X 7") annulus + 40% excess. 2. 7" 26# casing capacity below landing collar (80 feet). 3. 150' liner lap (9 5/8" x 7" liner) 4. 100' of cement on top of the liner in the 9 5/8" casing (without DP in hole). Prudhoe Bay AGI-05 Drillin TRUE $ VERTICAL VIEW SCALE 1500 F~, REFERENCE: WELL / DIVISION HEAD 0.00' @ 0 MD R.K.B. 49' (ABOYE SEA LEVEL) 0.00°@ 500 ND KDP @ 1.5/100' 3.00'e ?00 ND 6.00'~ 900 ND · . 9.00' ~ 1100 MD 12.00' ~ 1300 MD 1500 ~D BEGIN 2/100' 19.00' @ 1700 MD SHtTHI lO0 SURFACE LOCATION, SEC, 36j T12Nj R14E 2055' FSLj 2474' FEL ASP,' Y = 5979694,07 X = 688805,77 TARGET LOCATION~ SEC: 31i T12Nj Ri5E 2600' FSL; 2701' FEL ASP: Y = 5980356,89 X = 693435.89 BOTTOM HOLE LOCATION: ASP: Y = 5980381.64 X = 693608,39 4500 5000 23.00' @ t900 MD 27.00' @ 2100 MD 31.00' @ 2300 MD 35.18' @ 2509 MD END DF BUILD 1333 35.i8' e 3858 MD t3 3/78' CSG. PT. HBRIZBNTAL VIEW SCALE 500 Fi, / DIVISION REFERENCE: WELL HEAD 0 500 lO00 1500 2000 2500 3000 3500 4000 ~ ~ [KOP e 1,5/100' 500 0.00 0.00 500 0 0 ~ [BEGIN 2/100' 1500 15.00 83,31 1489 15 ]29 ~ ] END OF BUILD ~509 35.18 83.31 ~398 65 55~ ~ ~ I 13 3/78' CSG,PTO858 35.18 83.31 3500 155 13~4 528 4507 · ~ ;~ ~ ~ ~ ~ ]TOS 9421 35.1883.31 8047 ~ ~BASE SAD. ~904 35, 18 83.3~ 844~ 561 4784 ~ _%~%F4~TDTAL DEPTH 9965 35, 1883.31 9492 565 4819 ~ a{aska 0il & Gas 6ons. .c,orag / BHL DATA ~ ~ TVD ~492. Oq ~ North ~64. 4538 ~ 9.625 DD, e 94~5 MD, B04~ TVD ~ 35.18' e 9421 MD ~ 35.18' ~ gGG3 M~ TARGET ~ROP RATE, 0.00 OE6/IO0 FT ~81~ ~ 35. 18' ~ 9904 MD BASE SAD. 4~52 ~ 35. [~' E 9965 MD TDTAL DEPTH I 1500 I 3000 I I 4500 6000 VERTICAL SECTIBN PLANE: 83,31° DATE: 12/23/92 1500 HRS DRAWN BY: DBN CHECK BY: L_J~ APPROVED BY', L. ] ~ PPudhoe Bey D~i/~in9 ~ PP udhoe Bey ._Is M ~ T MI .... AGt-O5 " AGI-OSWP HBRIZSNTAL VIEW (TRUE NBRTH) SCALE 1000 f~, / DIVISION ~EFE~ENCE: WELL HEAD 4~ o ~l-O~O ~I'Ol Xv 0 1~ ~ ~ 4~ ~ RECEIVED ,JA~ - 5 t99~ Naska Oil & 6as Cons. gnchora~o PPudhoe A61-05 lmeve~Lin9 Cy/indep - Nominal Plane I~e~emence We~L- A6I-OSWP TVD: 0 - 849P £~, In~cepve~, 50 ALI Dipec~cions t~e~ {o Tmue Nopth { ISHIT I0 . I H I_ 300° 33CP t600 550 500 450 400 350 300 ~70o 240° 18CP 'Uetlpo th Slot LG]-08 LG]-C~ AG]-O1SV AG]-O AG]-CI~WD AG]-C~ ,~]-031'4~/D AG]-03 AG]-04WP AG] -04 LG]-O~ LG]-08 LG]-04 LG]-04 LG]-06 LG]-06 LG]-IO LG]-IO LG]-12 LG]-I2 210° CLOSEST F:g]NTS Dstonce 570.87 477.08 360.01 238.83 118.55 N/A N/A N/A N/A N/A Dir~ec'tlc~ 72.75 69.95 69.86 74 .~ N/A N/A N/A N/A N/A 900.73 O.00 500.00 N/A N/A N/A N/A N/A Re£ TVD 7300.00 gOO.OO 0.00 500.00 50.00 N/A N/A N/A N/A N/A RECEIVED JAN - 5 t993 Alaska 0il & 6as Cons. Commissio~ Anchorage Smith International, Inc. Proposal Report Calculated using the Minimum Curvature Method Computed by the Sii Win-CADDS System Vertical Section Plane: 83.31 deg. Survey Reference: WELLHEAD Reference World Coordinates: Lat. 70.20.57.32 N - Long. 148.28.01.45 W Reference GRID System: Alaska State Plane Zone: Alaska 4 Reference GRID Coordinates: (feet): 5979694.07 N 688805.77 E Vertical Section Reference: WELLHEAD Closure Reference: WELLHEAD North Aligned To: TRUE NORTH Prudhoe Bay Drilling Prudhoe Bay AGI AGI-05 AGI-O5WP Page 1 Date: 12/23/92 Wettpath ID: AGI-O5WP Program No: 1 Last Revision: 12/23/92 Measured I nc t Drift TVD Depth D i r. (fl) (deg.) (deg.) (fl) Subsea Depth (fl) TOTAL Rectangular Offsets (ft) (ft) Geographic Coordinates Latitude / Longitude GRID Coordinates Northing Easting (ft) (ft) Closure Dist. Dir. (fl) deg. Vertical DLS Section (ft) (dg/lOOft) R.K.B. 49' (ABOVE SEA LEVEL) 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 200.00 0.00 0.00 200.00 -49.00 0.00 N 0.00 51.00 0.00 N 0.00 151.00 0.00 N 0.00 E 70.20.57.3201 N 148.28.01.4476 E 70.20.57.3201 N 148.28.01.4476 E 70.20.57.3201 N 148.28.01.4476 5979694.07 688805.77 0.00 @ 0.00 0.00 0.00 5979694.07 688805.77 0.00 @ 0.00 0.00 0.00 5979694.07 688805.77 0.00 @ 0.00 0.00 0.00 300.00 0.00 0.00 300.00 251.00 400.00 0.00 0.00 400.00 351.00 KOP @ 1.5°/100' 500.00 0.00 0.00 500.00 451.00 0.00 N 0.00 0.00 N 0.00 0.00 N 0.00 E 70.20.57.3201 N 148.28.01.4476 E 70.20.57.3201 N 148.28.01.4476 E 70.20.57.3201 N 148.28.01.4476 5979694.07 688805.77 5979694.07 688805.77' 5979694.07 688805.77 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 0.00 0.00 0.00 0.00 0.00 600.00 1.50 83.31 599.99 700.00 3,00 83.31 699.91 800.00 4.50 83.31 799.69 550.99 0.15 N 1.30 650.91 0.61 N 5,20 750.69 1.37 N 11.69 E 70.20.57.3216 N 148.28.01.4096 E 70.20.57.3261 N 148.28.01.2957 E 70.20.57.3336 N 148.28.01.1058 5979694.26 688807.06 5979694.81 688810.95 5979695.74 688817.42 1.31 @ 83.31 1.31 1.50 5.23 @ 83.31 5.23 1.50 11.77 @ 83.31 11.77 1.50 900,00 6.00 83.31 899.27 1000,00 7.50 83.31 998.57 1100.00 9.00 83.31 1097.54 850.27 2.44 N 20.78 949.57 3.81 N 32.46 1048.54 5.48 N 46.71 1200.00 10.50 83.31 1196.09 1147.09 1300.00 12,00 83.31 1294.16 1245.16 1400.00 13.50 83.31 1391.70 1342.70 7.45 N 63.53 9.72 N 82.90 12.30 N 104.82 E 70.20.57.3441 N 148.28.00.8403 E 70.20.57.3575 N 148.28.00.4991 E 70.20.57.3740 N 148.28.00.0826 E 70.20.57.3934 N 148.27.59.5911 E 70.20.57.4157 N 148.27.59.0249 E 70.20.57.4410 N 148.27.58.3843 5979697.03 688826.48 5979698.70 688838.12 5979700.73 688852.32 5979703.12 688869.09 5979705.88 688888.40 5979709.00 688910.24 20.92 @ 83.31 20.92 1.50 32.68 @ 83.31 32.68 1.50 47.03 @ 83.31 47.03 1.50 63.96 @ 83.31 63.96 1.50 83.47 @ 83.31 83.47 1.50 105.54 @ 83.31 105.54 1.50 BEGIN 2°/100, 1500.00 15.00 83.31 1488.62 1439.62 1600.00 17.00 83.31 1584.74 1535.74 1700.00 19.00 83.31 1679.84 1630.84 15.16 N 129.27 18.37 N 156.64 21.97 N 187.33 E 70.20.57.4692 N 148.27.57.6699 E 70.20.57.5008 N 148.27.56.8699 E 70.20.57.5362 N 148.27.55.9730 5979712.49 688934.61 5979716.39 688961.89 5979720.76 688992.48 130.15 @ 83.31 130.15 1.50 157.72 @ 83.31 157.72 2.00 188.62 @ 83.31 188.62 2.00 1800.00 21,00 83.31 1773.80 1900.00 23.00 83.31 1866.52 2000.00 25.00 83.31 1957.87 1724.80 1817.52 1908.87 2100.00 27.00 83.31 2047.74 1998.74 2200.00 29.00 83.31 2136.03 2087.03 2300.00 31.00 83.31 2222.63 2173.63 25.96 N 221.30 30.32 N 258.50' 35.05 N 298.90 40.16 N 342.44 45.62 N 389.06 51.44 N 438.72 E 70.20.57.5754 N 148.27.54.9803 E 70.20.57.6183 N 148.27.53.8931 E 70.20.57.6~49 N 148.27.52.7125 E 70.20.57.7151 N 148.27.51.4402 E 70.20.57.7688 N 148.27.50.0776 E 70.20.57.8261 N 148.27.48.6264 5979725.60 689026.34 5979730.90 689063.42 5979736.65 689103.68 5979742.85 689147.07 5979749.49 689193.54 5979756;56 689243.04 222.82 @ 83.31 222.82 2.00 260.28 @ 83.31 260.28 2.00 300.95 @ 83.31 300.95 2.00 344.78 @ 83.31 344.78 2.00 391.73 @ 83.31 391.73 2.00 441.72 @ 83.31 441.72 2.00 2400.00 33.00 83.31 2307.43 2258.43 2500.00 35.00 83.31 2390.33 2341.33 END OF BUILD 2509.01 35.18 83.31 2397.70 2348.70 57.61N 491.35 64.12 N 546.88 64.72 N 552.03 E 70.20.57.8867 N 148.27.47.0884 E 70.20.57.9507 N 148.27.45.4654 E 70.20.57.9567 N 148.27.45.3150 5979764.06 689295.49 5979771.97 689350.85 5979772.70 689355.97 494.71 @ 83.31 494.71 2.00 550.63 @ 83.31 550.63 2.00 555.81 @ 83.31 555.81 2.00 Smith International, inc. Proposal Report Page 2 Date: 12/23/92 WelLpath ID: AGI-O5WP Measured [ncl Drift TVD Depth Dir. (ft) (deg.) (deg.) (ft) Subsea Depth (ft) 2609.01 35.18 83.31 2479.44 2430.44 2709.01 35.18 83.31 2561.17 2512.17 2809.01 35.18 83.31 2642.90 2593.90 2909.01 35.18 83.31 2724.64 2675.64 3009.01 35.18 83.31 2806.37 2757.37 3109.01 35.18 83.31 2888.11 2839.11 TOTAL Rectangular Offsets (ft) (ft) 71.43 N 609.25 78.14 N 666.47 84.85 N 723.70 91.55 N 780.92 98.26 N 838.14 104.97 N 895.37 3209.01 35.18 83.31 2969.84 2920.84 111.67 N 952.59 3309.01 35.18 83.31 3051.58 3002.58 118.38 N 1009.81 3409.01 35.18 83.31 3133.31 3084.31 125.09 N 1067.04 3509.01 35.18 83.31 3215.05 3166.05 131.80 N 1124.26 3609.01 35.18 83.31 3296.78 3247.78 138.50 N 1181.48 3709.01 35.18 83.31 3378.51 3329.51 145.21 N 1238.71 3809.01 35.18 83.31 3460.25 3411.25 151.92 N 1295.93 13 3/78" CSG. PT. 3857.64 35.18 83.31 3500.00 3451.00 155.18 N 1323.76 3909.01 35.18 83.31 3541.98 3492.98 158.62 N 1353.15 4009.01 35.18 83.31 3623.72 3574.72 165.33 N 1410.38 4109.01 35.18 83.31 3705.45 3656.45 172.04 N 1467.60 4209.01 35.18 83.31 3787.19 3738.19 178.74 N 1524.82 4309.01 35.18 83.31 3868.92 3819.92 185.45 N 1582.05 4409.01 35.18 83.31 3950.66 3901.66 192.16 N 1639.27 4509.01 35.18 83.31 4032.39 3983.39 198.87 N 1696.49 4065.12 205.57 N 1753.72 4146.86 212.28 N 1810.94 4228.59 218.99 N 1868.16 4609.01 35.18 83.31 4114.12 4709.01 35.18 83.31 4195.86 4809.01 35.18 83.31 4277.59 4909.01 35.18 83.31 4359.33 5009.01 35.18 83.31 4441.06 5109.01 35.18 83.31 4522.80 4310.33 225.69 N 1925.39 4392.06 232.40 N 1982.61 4473.80 239.11 N 2039.83 5209.01 35.18 83.31 4604.53 4555.53 245.81 N 2097.06 5309.01 35.18 83.31 4686.27 4637.27 252.52 N 2154.28 5409.01 35.18 83.31 4768.00 4719.00 259.23 N 2211.50 5509.01 35.18 83.31 4849.73 4800.73 265.94 N 2268.73 5609.01 35.18 83.31 4931.47 4882.47 272.64 N 2325.95 5709.01 35.18 83.31 5013.20 4964.20 279.35 N 2383.17 5809.01 35.18 83.31 5094.94 5045.94 286.06 N 2440.40 5909.01 35.18 83.31 5176.67 5127.67 292.76 N 2497.62 6009.01 35.18 83.31 5258.41 5209.41 299.47 N 2554.84 6109.01 35.18 83.31 5340.14 5291.14 306.18 N 2612.07 6209.01 35.18 83.31 5421.87 5372.87 312.88 N 2669.29 6309.01 35.18 83.31 5503.61 5454.61 319.59 N 2726.51 5536.34 326.30 N 2783.73 5618.08 333.01 N 2840.96 Geographic Coordinates Latitude / Longitude 6409.01 35.18 83.31 5585.34 6509.01 35.18 83.31 5667.08 E 70.20.58.0226 N 148.27.43.6427 E 70.20.58.0886 N 148.27.41.9704 E 70.20.58.1546 N 148.27.40.2981 E 70.20.58.2205 N 148.27.38.6258 E 70.20.58.2865 N 148.27.36.9535 E 70.20.58.3525 N 148.27.35.2811 E 70.20.58.4184 N 148.27.33.6088 E 70.20.58.4844 N 148.27.31.9365 E 70.20.58.5504 N 148.27.30.2642 E 70.20.58.6163 N 148.27.28.5918 E 70.20.58.6823 N 148.27.26.9195 E 70.20.58.7483 N 148.27.25.2472 E 70.20.58.8142 N 148.27.23.5749 E 70.20.58.8463 N 148.27.22.7615 E 70.20.58.8802 N 148.27.21.9025 E 70.20.58.9461 N 148.27.20.2302 E 70.20.59.0121 N 148.27.18.5579 E 70.20.59.0781 N 148.27.16.8855 E 70.20.59.1440 N 148.27.15.2132 E 70.20.59.2100 N 148.27.13.5408 E 70.20.59.2760 N 148.27.11.8685 E 70.20.59.3419 N 148.27.10.1962 E 70.20.59.4079 N 148.27.08.5238 E 70.20.59.4739 N 148.27.06.8515 E 70.20.59.5398 N 148.27.05.1791 E 70.20.59.6058 N 148.27.03.5068 E 70.20.59.6718 N 148.27.01.8344 E 70.20.59.7377 N 148.27.00.1621 E 70.20.59.8037 N 148.26.58.4897 E 70.20.59.8696 N 148.26.56.8174 E 70.20.59.9356 N 148.26.55.1450 E 70.21.00.0016 N 148.26.53.4727 E 70.21.00.0675 N 148.26.51.8003 E 70.21.00.1335 N 148.26.50.1279 E 70.21.00.1995 N 148.26.48.4556 E 70.21.00.2654 N 148.26.46.7832 E 70.21.00.3314 N 148.26.45.1109 E 70.21.00.3974 N 148.26.43.4385 E 70.21.00.4633 N 148.26.41.7661 E 70.21.00.5293 N 148.26.40.0938 E 70.21.00.5953 N 148.26.38.4214 GR]D Coordinates Northing Easting (ft) (ft) 5979780.85 689413.01 5979789.00 689470.04 5979797.16 689527.07 5979805.31 689584.11 5979813.46 689641.14 5979821.61 689698.18 5979829.77 689755.21 5979837.92 689812.24 5979846.07 689869.28 5979854.23 689926.31 5979862.38 689983.34 5979870.54 690040.38 5979878.70 690097.41 5979882.66 690125.15 5979886.85 690154.44 5979895.01 690211.48 5979903.17 690268.51 5979911.32 690325.54 5979919.48 690382.58 5979927.64 690439.61 5979935.80 690496.64 5979943.96 690553.67 5979952.12 690610.71 5979960.28 690667.74 5979968.44 690724.77 5979976.60 690781.80 5979984.76 690838.84 5979992.93 690895.87 5980001.09 690952,90 5980009.25 691009.93 Closure Dist. Dir. (ft) deg. Vertical DLS Section (ft) (dg/lOOft) 613.42 @ 83.31 613.42 0.00 671.04 @ 83.31 671.04 0.00 728.65 @ 83.31 728.65 0.00 786.27 @ 83.31 786.27 0.00 843.88 @ 83.31 843.88 0.00 901.50 @ 83.31 901.50 0.00 959.11 @ 83.31 959.11 0.00 1016.73 @ 83.31 1016.73 0.00 1074.34 @ 83.31 1074.34 0.00 1131.96 @ 83.31 1189.57 @ 83.31 1247.19 @ 83.31 1304.80 a 83.31 1332.82 @ 83.31 1362.42 @ 83.31 1420.03 @ 83.31 1477.65 @ 83.31 1535.26 @ 83.31 1592.88 @ 83.31 1650.49 @ 83.31 1708.11 @ 83.31 1765.72 @ 83.31 1823.34 a 83.31 1880.95 @ 83.31 1938.57 @ 83.31 1996.18 @ 83.31 2053.80 @ 83.31 2111.41 @ 83.31 2169.03 @ 83.31 2226.64 @ 83.31 5980017.41 691066.97 2284.26 @ 83.31 5980025.58 691124.00 2341.87 @ 83.31 5980033.74 691181.03 2399.49 @ 83.31 5980041.91 691238.06 2457.10 @ 83.31 5980050.07 691295.09 2514.72 @ 83.31 5980058.24 691352.13 2572.33 @ 83.31 ., 5980066.40 691409.16 2629.95 @ 83.31 5980074.57 691466.19 2687.56 @ 83.31 5980082.74 691523.22 2745.18 @ 83.31 5980090.90 691580.25 2802.79 @ 83.31 5980099.07 691637.29 2860.41 @ 83.31 1131.96 0.00 1189.57 0.00 1247.19 0.00 1304.80 0.00 1332.82 0.00 1362.42 0.00 1420.03 0.00 1477.65 0.00 1535.26 0.00 1592.88 0.00 1650.49 0.00 1708.11 0.00 1765.72 0.00 1823.34 0.00 1880.95 0.00 1938.57 0.00 1996.18 0.00 2053.80 0.00 2111.41 0.00 2169.03 0.00 2226.64 0.00 2284.26 0.00 2341.87 0.00 2399.49 0.00 2457.10 0.00 2514.72 0.00 2572.33 0.00 2629.95 0.00 2687.56 0.00 2745.18 0.00 2802.79 0.00 2860.41 0.00 Smith International, Inc. Proposal Report Page 3 Date: 12/23/92 14ettpath ID: AGI-O514P Measured [nct Drift TVD Depth Dir. (ft) (deg.) (deg.) crt) Subsea Depth (ft) 6609.01 35.18 83.31 5748.81 5699.81 6709.01 35.18 83.31 5830.55 5781.55 6809.01 35.18 83.31 5912.28 5863.28 6909.01 35.18 83.31 5994.02 5945.02 7009.01 35.18 83.31 6075.75 6026.75 7109.01 35.18 83.31 6157.48 6108.48 7209.01 35.18 83.31 6239.22 7309.01 35.18 83.31 6320.95 7409.01 35.18 83.31 6402.69 6190.22 6271.95 6353.69 7509.01 35.18 83.31 6484.42 6435.42 7609.01 35.18 83.31 6566.16 6517.16 7709.01 35.18 83.31 6647.89 6598.89 7809.01 35.18 83.31 6729.63 6680.63 7909.01 35.18 83.31 6811.36 6762.36 8009.01 35.18 83.31 6893.09 6844.09 8109.01 35.18 83.31 6974.83 6925.83 8209.01 35.18 83.31 7056.56 7007.56 8309.01 35.18 83.31 7138.30 7089.30 8409.01 35.18 83.31 7220.03 7171.03 8509.01 35.18 83.31 7301.77 7252.77 8609.01 35.18 83.31 7383.50 7334.50 8709.01 35.18 83.31 7465.24 7416.24 8809.01 35.18 83.31 7546.97 7497.97 8909.01 35.18 83.31 7628.70 7579.70 9009.01 35.18 83.31 7710.44 7661.44 9109.01 35.18 83.31 7792.17 7743.17 9209.01 35.18 83.31 7873.91 7824.91 9309.01 35.18 83.31 7955.64 7906.64 9409.01 35.18 83.31 8037.38 7988.38 TOS 9420.78 35.18 83.31 8047.00 7998.00 9509.01 35.18 83.31 8119.11 8070.11 9609.01 35.18 83.31 8200.84 8151.84 TARGET 9663.03 35.18 83.31 8245.00 8196.00 9763.03 35.18 83.31 8326.73 8277.73 9863.03 35.18 83.31 8408.47 8359.47 BASE SAD. 9904.06 35.18 83.31 8442.00 8393.00 TOTAL DEPTH 9965.23 35.18 83.31 8492.00 TOTAL Rectangutar Offsets (ft) (ft) 339.71 N 2898.18 E 346.42 N 2955.40 E 353.13 N 3012.63 E 359.83 N 3069.85 E 366.54 N 3127.07 E 373.25 N 3184.30 E 379.95 N 3241.52 E 386.66 N 3298.74 E 393.37 N 3355.97 E 400.08 N 3413.19 E 406.78 N 3470.41 E 413.49 N 3527.64 E 420.20 N 3584.86 E 426.90 N 3642.08 E 433.61 N 3699.31 E 440.32 N 3756.53 E 447.03 N 3813.75 E 453.73 N 3870.98 E 460.44 N 3928.20 E 467.15 N 3985.42 E 473.85 N 4042.65 E 480.56 N 4099.87 E 487.27 N 4157.09 E 493.97 N 4214.32 E 500.68 N 4271.54 E 507.39 N 4328.76 E 514.10 N 4385.99 E 520.80 N 4443.21 E 527.51 N 4500.43 E 528.30 N 4507.17 E 534.22 N 4557.66 E 540.92 N 4614.88 E 544.55 N 4645.79 E 551.25 N 4703.02 E 557.96 N 4760.24 E 560.71 N 4783.72 E 8443.00 564.82 N 4818.72 E Geographic Coordinates Latitude / Longitude 70.21.00.6612 N 70.21.00.7272 N 70.21.00.7931 N 148.26.36.7490 148.26.35.0766 148.26.33.4043 70.21.00.8591 N 70.21.00.9251 N 70.21.00.9910 N 148.26.31.7319 148.26.30.0595 148.26.28.3871 70.21.01.0570 N 70.21.01.1230 N 70.21.01.1889 N 148.26.26.7147 148.26.25.0424 148.26.23.3700 70.21.01.2549 N 70.21.01.3209 N 70.21.01.3868 N 148.26.21.6976 148.26.20.0252 148.26.18.3528 70.21.01.4528 N 70.21.01.5188 N 70.21.01.5847 N 148.26.16.6804 148.26.15.0080 148.26.13.3356 70.21.01.6507 N 70.21.01.7167 N 70.21.01.7826 N 148.26.11.6632 148.26.09.9909 148.26.08.3185 70.21.01.8486 N 70.21.01.9145 N 70.21.01.9805 N 148.26.06.6461 148.26.04.9737 148.26.03.3013 70.21.02.0465 N 70.21.02.1124 N 70.21.02.1784 N 148.26.01.6288 148.25.59.9564 148.25,58.2840 70.21.02.2444 N 70.21.02.3103 N 70.21.02.3763 N 148.25.56.6116 148.25.54.9392 148.25.53.2668 70.21.02.4423 N 148.25.51.5944 70.21.02.5082 N 148.25.49.9220 70.21.02.5160 N 148.25.49.7251 70.21.02.5742 N 148.25.48.2496 14 70.21.02.6402 N 148.25.46.5772 14 70.21.02.6758 N 148.25.45.6737 14 70.21.02.7418 N 148.25.44.0012 14 70.21.02.8077 N 148.25.42.3288 14 70.21.02.8348 N 148.25.41.6427 14 70.21.02.8751 N 148.25.40.6196 GRID Coordinates Northing Easting (ft) (ft) (ft) 5980107.24 691694.32 2918.02 5980115.41 691751.35 2975.64 5980123.58 691808.38 3033.25 5980131.75 691865.41 3090.87 5980139.92 691922.44 3148.48 5980148.09 691979.47 3206.10 5980156.26 692036.51 3263.71 5980164.43 692093.54 3321.33 5980172.60 692150.57 3378.94 5980180.77 692207.60 3436.56 5980188.95 692264.63 3494.17 5980197.12 692321.66 3551.79 5980205.29 692378.69 3609.40 5980213.47 692435.72 3667.02 5980221.64 692492.75 3724.63 5980229.82 692549.78 3782.25 5980237.99 692606.81 3839.86 5980246.17 692663.84 3897.48 5980254.34 692720.87 3955.09 5980262.52 692777.91 4012.71 5980270.70 692834.94 4070.32 5980278.87 692891.97 4127.94 5980287.05 692949.00 4185.55 5980295.23 693006.03 4243.17 5980303.41 693063.06 4300.78 5980311.59 693120.09 4358.40 5980319.77 693177.12 4416.01 5980327.95 693234.15 4473.63 5980336.13 693291.18 4531.24 5980337.09 693297.89 4538.03 5980344.31 693348.21 4588.86 5980352.49 693405.24 4646.47 5980356.91 693436.04 4677.60 5980365.09 693493.07 4735.21 5980373.27 693550.10 4792.83 5980376.63 693573.50 4816.46 C[osure Dist. Dir. deg. @ 83.31 a 83.31 a 83.31 @ 83.31 @ 83.31 @ 83.31 @ 83.31 @ 83.31 @ 83.31 @ 83.31 @ 83.31 @ 83.31 @ 83.31 @ 83.31 @ 83.31 @ 83.31 @ 83.31 a 83.31 @ 83.31 @ 83.31 @ 83.31 @ 83.31 @ 83.31 @ 83.31 @ 83.31 @ 83.31 a 83.31 @ 83.31 @ 83.31 @ 83.31 @ 83.31 @ 83.31 a 83.31 @ 83.31 a 83.31 @ 83.31 5980381.64 693608.39 4851.71 @ 83.31 Vertical DLS Section (ft) (dg/lOOft) 2918.02 0.00 2975.64 0.00 3033.25 0.00 3090.87 0.00 3148.48 0.00 3206.10 0.00 3263.71 0.00 3321.33 0.00 3378.94 0.00 3436.56 0.00 3494.17 0.00 3551.79 0.00 3609.40 0.00 3667.02 0.00 3724.63 0.00 3782.25 0.00 3839.86 0.00 3897.48 0.00 3955.09 0.00 4012.71 0.00 4070.32 0.00 4127.94 0.00 ~ 4185.55 0.00 ~ 4243.17 0.00 o 4300.78 0.00 ~.~ ~o 4358.40 o.oo ~ 4416.01 0.00 ~ ~ 4473.63 0.00 ~ ~ 4531.24 0.00 4538.03 O. O0 ~ 4588.86 O. O0 ~ 4646.47 0.00 ~ 4677.60 0.00 4735.21 0.00 4792.83 O. O0 4816.46 0.00 4851.71 0.00 Smith International, Inc. Travelling Cylinder Report Computed by the S# Win-CADDS System Page 1 Date: 12/23/92 NOrmal Plane Method REFERENCE WELL: Prudhoe Bay Dri l ling AG1-05 TVD, N/S and E/W are measured from the WELLHEAD Closest Points Weltpath Slot Distance AGI-OISV AGI-01 477.08 AGI-O2MWD AGI-02 360.01 AGI-O3MWD AGI-03 238.83 AGI-O4WP AGI-04 118.55 LGI-02 LG[-02 2450.90 LGI-04 LGI-04 3463.27 LGI-06 LGI-06 1959.47 LGI-08 LGI-08 570.87 LGI-IO LGI-IO 1000.54 LGI-12 LGI-12 1013.39 Direction Ref MD Ref TVD 172.75 900.73 900.00 169.95 0.00 0.00 169.86 500.00 500.00 174.22 50.00 50.00 207.55 7956.29 6850.00 166.06 100.00 100.00 131.48 7344.55 6350.00 100.22 8506.85 7300.00 102.57 6182.25 5400.00 260.53 8568.02 7350.00 RECEIVED ,.JAN -- 5 !99J ,.AJaska 0J] & Gas Cons. Anchorage Smith International, Inc. Travelling Cylinder Report Computed by the Sii Win-CADDS System Page 1 Date: 12/23/92 Least Distance Method REFERENCE WELL: Prudhoe Bay Drilling AGI-05 TVD, N/S and E/W are measured from the WELLHEAD Wellpath Slot Distance AGI-OISV AGI-01 477.08 AGI-O2MI41) AGI-02 360.01 AGI-O3MI4D AGI-03 238.83 AGI-O4WP AGI-04 118.55 LGI-02 LGI-02 2450.85 LGI-04 LGI-04 3463.27 LGI-06 LGI-06 1959.46 LGI-08 LGI-08 570.85 LGI-IO LGI-IO 1000.46 LGI-12 LGI-12 1013.35 Closest Points Direction Ref MD Ref TVD 172.75 900.73 900.00 169.95 0.00 0.00 169.86 500.00 500.00 174.22 0.00 0.00 207.59 7956.29 6850.00 166.06 100.00 100.00 131.33 7344.55 6350.00 100.58 8506.85 7300.00 103.21 6182.25 5400.00 260.24 8568.02 7350.00 RECEIVED Alaska Oil & Gas Cons. 6orf~z~is$iot'~ Anchorage Smith International, Inc. Travelling Cylinder Report Computed by the Sii Win-CADDS System Page 1 Date: 12/23/92 Horizontal Slice Method REFERENCE WELL: Prudhoe Bay Drifting AGI-05 TVD, N/S and E/W are measured from the WELLHEAD Wetlpath Slot Distance Direction AGI-O1SV AG[-01 477.08 172.75 AGI-O2MWD AGI-02 360.01 169.95 AG]-O3MWD AG[-03 238.83 169.86 AGI-O4~P AGI-04 118.55 174.22 LG[-02 LG[-02 2669.44 214.43 LG[-04 LGI-04 3463.27 166.06 LGI-06 LG[-06 2171.07 129.57 LG[-08 LG[-08 688.39 100.16 LG[-IO LGI-IO 1192.68 111.'73 LGI-12 LGI-12 1238.48 258.52 Closest Points Ref MD Ref TVD 900.73 900.00 0.00 0.00 500.00 500.00 0.00 0.00 8445.67 7250.00 100.00 100.00 5937.55 5200.00 8017.46 6900.00 5142.29 4550.00 9179.76 7850.00 JAN - 5 ~995 Alaska Oil & Gas Cons. Comr~issioU Anchorage SUb,.r :' CL~r'"'~")L= DIVER"TER SYSTEM .. .... Two lines venting go deg. apart in directions that ensure sale down wind venling, and ex- tending to a point at least 100' from any' polential source of ignilion. 10' Full Opening Valves 35' or as required · I Dresser Sleeve 1. All pipe connections 150# ANSI Flanges or welded connections and secured to prevent rnovemenL. 2.. Manual 10" lull opening valves mechanically connected to ensure that one valve is Jail-sale open at all times. 1 O' Diverter Une 3. All tums are g0 deg. and targeted. 10' Full opening ball valve w/Hydraulic Acl, u:ator 20' Diverter SFoo[ w/10' Side Culler. RECEIVED TOTAL AC l'lY~ SUCT!_O_N (,! ~L-/'.I I~( Je, L ro ~0 AAL 1 - Bra~dt= Dua:L ~an~ 5i~e 5h~e~ 1 - ~ 6-12" Cone ShaLe ~sande~ 4gll w/16 runes (~s[l~e~} ' 1 - Pr[l~ Abmsphe~[c Hud ~gasser 1 - 200 gpm Operating Capacity. Centrifuge 15 - Brandk HA5 l.lud I-iix kjitators 1- 150 bbl. Trip Ta~3k 1 - P~oordlng drilling ~luid pit level indicator with bo~'~ visual and audio warning..devices at driller's console ' 1.-Dr[lllJng fluid flcz-~ sen. sot with readouE at drill~,~.',s console AUDI #2 13 5/8" 5,000 psi Stack 12.72 4.50 3.01 2.00 r/ RKB 1 1 RIG FLOOR 4.12 DRIP PAN ,j 3.01 1.83 3.01 2.52 1.5 GROUND LEVEL L HYDRIL 17.88 PiPE RAM BLIND RAM MUD CROSS PIPE RAM MUD CROSS k'~ASE FLG/ 22.38 25.3 , I 30.23 34.25 Alaska Oil & Gas ConS. Anchorage 35.75 b AGI SOUTH ACCESS ROAD LEGEND CONDUCTOR AS-BUILT THIS SURVEY. /t10 /16 .. /12 PAD _261 \ STA?~TE\PAD 25 I-,- ......F "%~\ \ F SURVEY ~S~ N / AREA VICINITY MAP N.T.S. ?-.. F. ROBERT BELL ~ R E6EIVED · SURVEYOR'S CERTIFICATE JAbJ "' 5 ~99~ I HEREBY CERTIFY ll-IAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN Oil & Gas Cons. 6o ' STATE OF ALASKA AND THAT 'Anchorage mmisS~s PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER NIY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF NOVEMBER :24, 1992. NOTES 1. COORDINATES SHOWN ARE ALASKA STATE PLANE ZONE 4, NAD 27. 2. BASIS OF LOCATION PER MONUMENTS CCP "C" AND L1 NORTH/L1 SOUTH (BRAUN). 5. REFERENCE FIELD BOOKS: PB92-37(pgs.53-55); PB92-40(pgs. 28-40). 4. DATE OF SURVEY: NOVEMBER 10, 2`5 & 24, 1992. 5. ASP GRID SCALE FACTOR = 0.9999405 LOCATED WITHIN PROTRACTED SECTION 36, T12N, R14E, U.M., AK. IWELLJA.S.P. NO. J COORDINATES 1 lY=5979223.82 iX= 688901.48 2 JY=5979341.56 iX- 688877.98 IY=5979458.76 .3 IX= 68885.3.74 4 IY=5979576'`56 IX= 688829.57 5 IY=5979694'13 IX= 688805.68 PLANT COORDINATES N.5040ol 0 E.5000.06 N.5160.16 E.5000.50 N.5279.85 . E. 5000.11 N.5`399.92 E.4999.87 N.5520.09 E. 4999.94 GEODETIC POSITION 70'20'52.673" 148'27'58.998" CELLAR BOX ELEVATI ON 70'20'56.157" 48'28'00.8,39" SECTION OFFSETS 1583' FSL: 13.4' 2`390' FELl 70'20'53.836" 1701' FSL 148'27'59.598" 15.1' 2411' FEL 70'20'54.994" 148'28'00.22 O" 15.1' 13.3' 13.2' 70'20'57.,521 148'28'01.450" 6. REFERENCE SHEET 2 FOR WELLS 6, 7, 8, 9 & 10. ORIGINAL AS-BUILT ISSUE REVISIONS 1819' FSL ARCO Alaska Inc. 2452' FEL DRAW1N(~ NAME: 10,57' FSL AG] PAD 245~' FEL 2055' FSL CONDUCTOR AS-BUILT 2474' FEz WELLS # 1-10 I J DATL: l DRAWN: l CHECK: I j ~1/2g/92 J BARNHART I a,N]SH N.T.S. ~ ADM ¢o J I I F. ROBERT BELL & ASSOC. CADD FILE J: AGIWAB SHEET: REV#: 1 OF2 0 Well History File APPENDIX Information of detailed nature, that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. .. No special 'effort has been made to chronologically organize this category of information. LIS VERIFICATION LISTING FOR: ARCO ALASKA, INC. AGI-5 PRUDHOE BAY ATCM ATDC CADE CPDE DCCM GRAM GRCM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM Note: BELOW ARE THE MNEMONICS THAT CAN BE FOUND ON THE LIS TAPE GENERATED FOR ARCO ALASKA INC, AGI-5 Attenuation Borehole Corrected [RWD] Attenuation Dielectric Corrected [RWD] Conductivity (AT) Corrected for Dielectric Effect [RWD] Conductivity (PD) Corrected for Dielectric Effect [RWD] Calculated Dielectric Constant Gamma Ray Memory (APl) [RWD] Gamma Ray Borehole Corrected (APl) [RWD] Phase Difference Borehole Corrected [RWD] Phase Difference Dielectric Corrected [RWD] Phase Difference Elapsed Time [RWD] Resistivity (AT) Borehole Corrected [RWD] Resistivity (AT) Corrected Dielectric Effect [RWD] Rate of Penetration Averaged Rate of Penetration Resistivity (PD) Borehole Corrected [RWD] Resistivity (PD) Corrected for Dielectric Effect [RWD] CDS Temperature [RWD] AT is Attenuation PD is Phase Difference RWD is Recorded While Drilling -dB -dB mmho/m mmho/m MWD-API MWD-API deg deg rains ohm-m ohm-m fi/hr fi/hr ohm-m ohm-m deg F Copyright 1987,1988,1989,1990,1991 By WESTERN ATLAS INTERNATIONAL, INC. All rights reserved. PROGRAM: TAPESCAN REVISION: 2.64 Start of execution: Mon 4 OCT 93 11:50a != = ECHOING INPUT PARAMETERS= INPUT PARAMETER FILE: TAPESCAN.INP 1 2 3 4 5 6 7 123456789012345678901234567890123456789012345678901234567890123456789012 1 AUTOCURV = 0 , ! Automatic Curve renaming: 0=OFF, 1 =ON 2 AUTOFILE = 0 , ! Automatic FILE= generation: 0=OFF, I=ON 3 COMMENTS = I , ! Decode LIS Comment records: 0=OFF, I=ON 4 INFORECS = 1 , ! Decode LIS Information records: 0=NO, I=YES 5 LISTMETHOD = 0 , ! Listing Method: 0=depth units 1 =tape units 6 LISTFREQ = 50, ! Listing Frequency: Every n units 7 LISTMAX = 0 , ! Listing Maximum (0= no limit, value=list limit) 8 STATS = 0 , ! Statistics generation: 0= OFF, 1 =ON 9 FORCETYP = 0 , ! (1 =BIT,2=LIS ... thru 35=Array Accoustic) (see table) 10 WRITEASCll = 0 , ! If 1, all ascii files will be written (file0001.dat, etc.) 11 WRITETAP = 1 , ! Write Tape-Image File: 0=NO,1 =YES 12 SPLITLIS = I , ! If I and WRITETAP on, split LIS logical files to physical 13 SUBFILES = /0/, ! Tape Subtile write selection (WRITETAP must be on) 14 INTERPOLATE='YES' ! Set up for TAPE2WDS to interpolate datums ('YES'or'NO') 15 END USER INPUT PARAMETERS AUTOCURV = 0 , AUTOFILE = 0 , ._ COMMENTS = I , INFORECS -- 1 , LISTMETHOD = 0 , LISTFREQ = 50, " LISTMAX = 0 , STATS = 0, FORCETYP = 0 , -- WRITEASCll = 0 , WRITETAP = 1 , SPUTMS = 1, _ SUBFILES = /0/, INTERPOLATE = 'YES' END =! !-- PROCESSING INTERVAL FROM 0.000 TO 0.000 ............. CONSTANT PARAMETERS AUTOCURV= O.O00000E+O0 AUTOFILE= O.O00000E+O0 COMMENTS= 1.00000 FORCETYP= O.O00000E+O0 INFORECS= 1.00000 LISTFREQ= 50.0000 -' LISTMAX = O.O00000E+O0 LISTMETH= O.O00000E+O0 SELFTEST= O.O00000E+O0 SPLITLIS= 1.00000 STATS = O.O00000E+O0 WRITEASC= O.O00000E+O0 WRITETAP= 1.00000 dpcoef = 1.00000 dpcte = 1.00000 -.. ddength= O.O00000E+O0 listwave= O.O00000E+O0 maxrecln= O.O00000E+O0 minrecln= O.O00000E+O0 nsamples= O.O00000E+O0 numcurvs= O.O00000E+O0 numdatar = O.O00000E + O0 numrecfl = O.O00000E + O0 ffendep - O.O00000E + O0 .. tflevsp = O.O00000E+O0 tfstdep = O.O00000E+O0 wcrbot = O.O00000E+O0 wcrlevsp= O.O00000E +00 wcrtop = O.O00000E + O0 !-- ARRAY PARAMETERS SUBFILES(1) = ._ SUBFILES(3) = SUBFILES(5) = SUBFILES(7) = SUBFILES(9) = '- SUBFILES(11) = SUBFILES(13) -- SUBFILES(15) = -. SUBFILES(17) = SUBFILES(19) = SUBFILES(21) = .- SUBFILES(23) = SUBFILES(25) = SUBFILES(27) = SUBFILES(29) = -' SUBFILES(31) = SUBFILES(33) = SUBFILES(35) = ... SUBFILES(37) = SUBFILES(39) = SUBFILES(41) = SUBFILES(43) = " SUBFILES(45) = SUBFILES(47) = SUBFILES(49) = -- SUBFILES(51) = SUBFILES(53) = SUBFILES(55) = _. SUBFILES(57) = SUBFILES(59) = SUBFILES(61) = SUBFILES(63) = -' SUBFILES(65) = SUBFILES(67) = SUBFILES(69) = _. SUBFILES(71) = SUBFILES(73) = SUBFILES(75) = SUBFILES(77) = '- SUBFILES(79) = SUBFILES(81) = SUBFILES(63) = -- SUBFILES(85) = SUBFILES(87) = SUBFILES(89) = -. SUBFILES(91) = O.O00000E +00 SUBFILES( 2) = -9999.00 -9999.00 SUBFILES(4) =-9999.00 -9999.00 SUBFILES(6) =-9999.00 -9999.00 SUBFILES(8) =-9999.00 -9999.00 SUBFILES(10) = -9999.00 -9999.00 SUBFILES(12) = -9999.00 -9999.00 SUBFILES(14) = -9999.00 -9999.00 SUBFILES(16) = -9999.00 -9999.00 SUBFILES(18) = -9999.00 -9999.00 $UBFILES(20) = -9999.00 -9999.00 $UBFILES(22) = -9999.00 -9999.00 SUBFILES(24) = -9999.00 -9999.00 SUBFILES(26) = -9999.00 -9999.00 SUBFILES(28) = -9999.00 -9999.00 SUBFILES(30) = -9999.00 -9999.00 SUBFILES(32) = -9999.00 -9999.00 SUBFILES(34) = -9999.00 -9999.00 SUBFILES(36) = -9999.00 -9999.00 SUBFILES(38) = -9999.00 -9999.00 $UBFILES(40) = -9999.00 -9999.00 SUBFILES(42) = -9999.00 -9999.00 $UBFILES(44) = -9999.00 -9999.00 SUBFILES(46) = -9999.00 -9999.00 SUBFILES(48) = -9999.00 -9999.00 SUBFILES(50) -- -9999.00 -9999.00 SUBFILES(52) = -9999.00 -9999.00 SUBFILES(54) = -9999.00 -9999.00 SUBFILES(56) = -9999.00 -9999.00 SUBFILES(58) = -9999.00 -9999.00 SUBFILES(60) -- -9999.00 -9999.00 SUBFILES(62) = -9999.00 -9999.00 $UBFILES(64) = -9999.00 -9999.00 SUBFILES(66) = -9999.00 -9999.00 SUBFILES(68) -- -9999.00 -9999.00 SUBFILES(70) = -9999.00 -9999.00 SUBFILES(72) = -9999.00 -9999.00 SUBFILES(74) = -9999.00 -9999.00 SUBFILES(76) = -9999.00 -9999.00 SUBFILES(78) = -9999.00 -9999.00 SUBFILES(80) = -9999.00 -9999.00 $UBFILE$(82) = -9999.00 -9999.00 SUBFILES(84) = -9999.00 -9999.00 $UBFILES(86) = -9999.00 -9999.00 SUBFILES(88) = -9999.00 -9999.00 SUBFILES(90) = -9999.00 -9999.00 SUBFILES(92) = -9999.00 SUBFILES(93) = -9999.00 SUBFILES(95) = -9999.00 SUBFILES(97) = -9999.00 SUBFILES(99) = -9999.00 SUBFILES(101 ) = -9999.00 SUBFILES(103) = -9999.00 SUBFILES(105) = -9999.00 SUBFILES(107) = -9999.00 SUBFILES(109) = -9999.00 SUBFILES(111) = -9999.00 SUBFILES(113) = -9999.00 SUBFILES(115) = -9999.00 SUBFILES(117) = -9999.00 SUBFILES(119) -- -9999.00 SUBFILES(121 ) = -9999.00 SUBFILES(123) = -9999.00 SUBFILES(125) = -9999.00 SUBFILES(127) = -9999.00 !-- STRING PARAMETERS INTERPOL= YES SUBFILES(94) = -9999.00 SUBFILES(96) = -9999.OO SUBFILES(98) = -9999.00 SUBFILES(IO0) = -9999.00 SUBFILES(102) = -9999.00 SUBFILES(104) = -9999.00 SUBFILES(106) = -9999.00 SUBFILES(108) = -9999.00 SUBFILES(110) = -9999.00 SUBFILES(112) -- -9999.00 SUBFILES(114) = -9999.00 SUBFILES(116) = -9999.00 SUBFILES(118) = -9999.00 SUBFILES(120) = -9999.00 SUBFILES(122) = -9999.00 SUBFILES(124) = -9999.00 SUBFILES(126) = -9999.00 SUBFILES(128) = -9999.00 Input Tape Device, LU (1) is: TAPEC: Output Tape-Image file, LU (2) is: J:\1172\1172.TAP (Output Tape-Image file will be created) Listing Method ("USTMETH") = 0, Depth Unit oriented listing. Listing Frequency ("USTFREQ") is every ( 50) units of Depth. -- Usting output limiting (MSTMAX) not enabled... (to enable list limiting set LISTMAX positive) -. Data Statistics reporting ("STATS") has not been enabled. (Specify STATS = 1 to enable this feature) Automatic curve renaming has been disabled by user input (AUTOCURV=0). Automatic "FILE= n" card generation is disabled. (This is the program default, AUTOFILE=0) -- (Specify AUTOFILE= 1 to enable this feature) LIS comment record decoding (COMMENTS=l) has been enabled by user input. LIS information record decoding (INFORECS= 1) has been enabled by user input. The WRITEASC option has not been enabled... " (to write ASCII subfiles specify WRITEASC= 1) Tape Subtile 1 is type: LIS **** REEL HEADER **** MWD 93/10/4 1172 01 **** TAPE HEADER **** MWD 93/10/4 1172 01 Tape Subtile: 1 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subtile 2 is type: LIS LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: AGI-5 APl NUMBER: 50-029-22327 -. OPERATOR: Arco Alaska Inc. LOGGING COMPANY: BAKER HUGHES INTEQ TAPE CREATION DATE: 04 OCT 93 JOB DATA BIT RUN1 BIT RUN2 BIT RUN3 JOB NUMBER: 1172 1172 '- LOGGING ENGINEER: P. SMITH D. LENTZ OPERATOR WITNESS: J. GAFFANEY J. GAFFANEY _. SURFACE LOCATION SECTION: 36 TOWNSHIP: 12N RANGE: 14E " FNL: FSL: 2055 FEL: 2474 -. FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 36.00 GROUND LEVEL: 13.00 WELL CASING RECORD -- OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 30.000 20.000 116.0 .., 2ND STRING 16.000 13.375 3888.0 3RD STRING 12.250 PRODUCTION STRING -- REMARKS: $ **** FILE HEADER **** MWD .001 -' 1024 US COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 1 -' EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY · PBU TOOL CODE START DEPTH MWD 7448.0 9329.0 -- BASELINE CURVE FOR SHIFTS: GR .-- CURVE SHIFT DATA (MEASURED DEPTH)· STOP DEPTH ...... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH CADE CPDE DCCM GRAM 7425.0 7418.2 7418.2 7418.2 7418.2 7418.2 9360.0 9353.2 9353.2 9353.2 9353.2 9353.2 $ BASELINE DEPTH PDEM RACM RADE ROPA 7425.0 7418.2 7418.2 7418.2 7418.2 7418.2 9360.0 9353.2 9353.2 9353.2 9353.2 9353.2 $ BASELINE DEPTH RPCM RPDE TCDM 7425.0 7418.2 7418.2 7418.2 9360.0 9353.2 9353.2 9353.2 $ BIT RUN NO MERGE TOP 7448.0 8455.0 8456.0 9329.0 :Arco Alaska Inc. : AGI-5 : Prudhoe Bay : North Slope :Alaska # MERGED DATA SOURCE PBU TOOL CODE -- MWD 4 MWD 5 $ REMARKS: $ -' CN WN FN -, COUN STAT MERGE BASE GRCM ROPS LIS COMMENT RECORD(s): 123456789012345678,9012345678901234567890123456789012345678,9012345678901234567890 THIS FILE CONTAINS EDITED MERGED MWD DATA -- THAT HAS BEEN DEPTH SHIFTED. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(68) Datum Specification Block Sub-type is: Entry Block terminator. -. Summary of entry types encountered: 1 2 3 4 5 6 ? 8 91011 1213141516 0 0 0 1 0 0 0 000 0 1 000 1 Rep Code Count Bytes 68 4 16 Sum: 4 16 16 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod I GR MWD 68 I GAPI 4 2 RA MWD 68 I OHMM 4 3 ROP MWD 68 1 FPHR 4 4 RP MWD 68 1 OHMM 4 498660 71 6 498660 71 6 498660 71 6 498660 71 6 16 -' ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 50 FRAMES * DATA RECORD (TYPE# O) 1006 BYTES * -' Total Data Records: 76 Tape File Start Depth -- 7448.000000 Tape File End Depth -- 9329.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4228 datums Tape Subtile: 2 156 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subtile 3 is type: LIS **** FILE HEADER **** MWD .002 1024 LIS COMMENT RECORD(s): .. 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 2 '- RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 -- DEPTH INCREMENT: 0.2500 # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 7455.0 8455.0 $ -' LOG HEADER DATA DATE LOGGED: SOFTWARE _ SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (Fr'): -' TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): ,,.- HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 25 JAN 93 M1.33 M1.33 MEMORY 0.0 7455.0 8455.0 0 32.4 35.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ TOOL NUMBER 2247-39 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 0.0 BOREHOLE CONDITIONS MUD TYPE: DISPERSED MUD DENSITY (LB/G): 10.10 MUD VISCOSITY (S): 13.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 950 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 1.213 MUD FILTRATE AT MT: 1.012 136.0 MUD CAKE AT MT: 0.000 0.0 0.0 116.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (I N): 12.250 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: INTERVAL FROM 7447 TO 7507' (6377 TO 6426' TVD) WAS LOGGED 10 HOURS AFTER BEING DRILLED. $ CN : Arco Alaska Inc. WN : AGI-5 FN : Prudhoe Bay COUN : North Slope STAT : Alaska LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 4. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 0 0 0 I 0 0 0 0 O0 0 I 0 O0 1 Rep Code Count 'Bytes 68 17 68 Sum: 17 68 68 fndun a [F ] 1.00000000 ~m~ m ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units APl APl APl APl Log Crv Crv Size Length Typ Typ CIs Mod 1 ATCM MWD 68 I -dB 2 ATDC MWD 68 I -dB 3 CADE MWD 68 I MMHO 4 CPDE MWD 68 1 MMHO 5 DCCM MWD 68 1 6 GRAM MWD 68 I GAPI 7 GRCM MWD 68 I GAPI 8 PDCM MWD 68 1 DEG 9 PDDC MWD 68 I DEG 10 PDEMMWD 68 1 MINS 11 RACM MWD 68 1 OHMM 12 RADEMWD 68 1 OHMM 13 ROPAMWD 68 1 FPHR 14 ROPSMWD 68 I FPHR 15 RPCMMWD 68 I OHMM 16 RPDEMWD 68 I OHMM 17 TCDMMWD 68 1 DEGF 4 4 98660 71 6 4 4 98660 71 6 4 4 98660 71 6 4 4 98660 71 6 4 4 98660 71 6 4 4 98660 71 6 4 4 98660 71 6 4 4 98660 71 6 4 4 98660 71 6 4 4 98 660 71 6 4 4 98660 71 6 4 4 98660 71 6 4 4 98660 71 6 4 4 98660 71 6 4 4 98660 71 6 4 4 98660 ~1 6 4 4 98660 71 6 -' ** Routine LEVONE detects data discrepancy: DSB indicates: I FRAMES .. Data Record Length indicates: 14 FRAMES * DATA RECORD (TYPE# O) 1014 BYTES * '" Total Data Records: 286 -- Tape File Start Depth = 7455.000000 Tape File End Depth = 8455.000000 Tape File Level Spacing = 0.250000 -. Tape File Depth Units = Feet **** FILE TRAILER **** -" LIS representation code decoding summary: Rep Code: 68 9238 datums Tape Subtile: 3 351 records... Minimum record length: 62 bytes '- Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS **** FILE HEADER **** MWD .003 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 5 -- DEPTH INCREMENT: 0.2500 # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 8456.0 9285.0 $ -' LOG HEADER DATA DATE LOGGED: SOFTWARE _. SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): " TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): -- HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 28 JAN 93 M1.33 M1.33 MEMORY 0.0 8456.0 9285.0 0 23.0 55.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ TOOL NUMBER 2247-39 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 0.0 BOREHOLE CONDITIONS MUD TYPE: DISPERSED MUD DENSITY (LB/G)' 10.10 MUD VISCOSITY (S): 43.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 850 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 0.985 MUD FILTRATE AT MT: 0.872 142.0 MUD CAKE AT MT: 0.000 0.0 0.0 140.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 12.250 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: INTERVAL FROM 8463 TO 8515' MD (7217 TO 7262' TVD) WAS LOGGED 53 HOURS AFTER BEING DRILLED. INTERVAL FROM 8515 TO 8624' MD (7262 TO 7356' TVD) WAS LOGGED 7.5 HOURS AFTER BEING DRILLED. INTERVAL FROM 9265 TO 9335' (7958 TO 8011' TVD) WAS NOT LOGGED DUE TO SENSOR OFFSET ON LOGGING SUITE. $ CN : Arco Alaska Inc. WN : AGI-5 FN : Prudhoe Bay COUN : North Slope STAT : Alaska LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 5. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 000 1 0000000 1 000 1 Rep Code Count Bytes 68 17 68 Sum: 17 68 68 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ Cls Mod 1 ATCM MWD 68 2 ATDC MWD 68 3 CADE MWD 68 4 CPDE MWD 68 5 DCCM MWD 68 6 GRAMMWD 68 7 GRCM MWD 68 8 PDCM MWD 68 9 PDDC MWD 68 10 PDEMMWD 68 11 RACM MWD 68 12 RADE MWD 68 13 ROPAMWD 68 14 ROPSMWD 68 15 RPCMMWD 68 16 RPDEMWD 68 17 TCDM MWD 68 1 -dB 4 4 98 660 71 6 I -dB 4 4 98 660 71 6 1 MMHO 4 4 98 660 71 6 1 MMHO 4 4 98 660 71 6 1 4 4 98660 71 6 I GAPI 4 4 98 660 71 6 I GAPI 4 4 98 660 71 6 I DEG 4 4 98 660 71 6 I DEG 4 4 98 660 71 6 1 MINS 4 4 98 660 71 6 1 OHMM 4 4 98 660 71 6 I OHMM 4 4 98 660 71 6 I FPHR 4 4 98 660 71 6 I FPHR 4 4 98 660 71 6 1 OHMM 4 4 98 660 71 6 I OHMM 4 4 98 660 71 6 I DEGF 4 4 98 660 71 6 -' ** Routine LEVONE detects data discrepancy: DSB indicates: I FRAMES -. Data Record Length indicates: 14 FRAMES * DATA RECORD ('FYPE# O) 1014 BYTES * Total Data Records: 252 -- Tape File Start Depth = 8456.000000 Tape File End Depth = 9335.000000 Tape File Level Spacing = 0.250000 ,., Tape File Depth Units = Feet **** FILE TRAILER **** -' LIS representation code decoding summary: Rep Code: 68 12353 datums Tape Subtile: 4 323 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subtile 5 is type: LIS **** TAPE TRAILER **** MWD 93/10/4 1172 01 **** REEL TRAILER MWD 93/10/4 1172 01 Tape Subtile: 5 2 records... -' Minimum record length: 132 bytes Maximum record length: 132 bytes _. End of execution: Mon 4 OCT 93 11:51a Elapsed execution time = 47.18 seconds. -' SYSTEM RETURN CODE = 0 Tape Subtile 1 is type: LIS Tape Subtile 2 is type: LIS DEPTH GR RA ROP RP 7448.0000 -999.2500 -999.2500 -999.2500 -999.2500 7448.5000 43.1052 -999.2500 -999.2500 -999.2500 7450.0000 48.8354 -999.2500 -999.2500 -999.2500 7500.0000 74.8824 5.8545 93.8493 4.7972 7550.0000 54.0773 3.0841 108.9332 2.5199 7600.0000 39.9032 1.8472 178.4813 1.8864 7650.0000 48.6313 2.9773 48.5029 2.6569 7700.0000 81.1361 7.5371 19.3728 5.8376 7750.0000 69.7702 6.9014 27.7679 5.3453 7800.0000 58.8878 4.4032 57.0937 3.5736 7850.0000 79.1766 12.9068 69.1654 9.3532 7900.0000 88.4302 8.3458 49.8445 5.9061 7950.0000 89.2898 7.3236 50.8764 5.6670 8000.0000 84.5259 8.2083 47.9072 6.1131 8050.0000 90.5279 8.7569 68.7554 6.3839 8100.0000 90.1517 8.9502 48.1021 6.3483 8150.0000 92.3364 12.2446 62.9659 8.4641 8200.0000 90.0687 10.2611 57.1292 6.7102 8250.0000 90.1617 8.9487 43.5069 5.8920 8300.0000 87.4661 8.0308 47.6360 5.5592 8350.0000 85.1647 7.8213 40.8495 5.7427 8400.0000 105.2032 3.9693 46.9452 3.2330 8450.0000 61.5338 3.8059 17.0198 3.1044 8500.0000 92.0362 3.9096 15.8727 3.5171 8550.0000 95.2448 6.2867 15.5000 5.0847 8600.0000 91.31 77 7.0172 15.7500 5.7946 8650.0000 95.0451 8.0121 34.8404 5.9297 8700.0000 101.0791 6.1107 42.9125 4.9922 8750.0000 95.3700 7.0716 46.0822 5.9038 8800.0000 97.3579 6.6457 48.0072 5.3942 8850.0000 108.3080 4.6264 35.7674 3.7008 8900.0000 159.9313 4.0282 41.3815 2.9294 8950.0000 126.2690 4.5122 46.6875 3.3976 9000.0000 118.9131 16.5722 58.3074 9.6086 9050.0000 103.7867 14.1650 34.7748 7.4800 9100.0000 116.3668 7.5586 69.9877 4.9458 9150.0000 137.7767 5.4500 28.3604 3.8745 9200.0000 156.4301 6.4747 52.7408 4.2353 9250.0000 172.4605 7.3281 29.7296 4.6884 9300.0000 -999.2500 -999.2500 43.7441 -999.2500 9329.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth -- 7448.000000 Tape File End Depth = 9329.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units -- Feet Tape Subtile 3 is type: LIS DEPTH ATCM ATDC CADE CPDE DCCM GRAM GRCM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 7455.0000 1.4293 1.4890 -999.2500 -999.2500 158.4492 -999.2500 -999.2500 17.7910 17.4816 -999.2500 2.4606 -999.2500 -999.2500 -999.2500 2.0171 -999.2500 -999.2500 7455.2500 1.4290 1.4887 -999.2500 -999.2500 158.4698 43.1052 62.9328 17.7938 17.4843 -999.2500 2.4612 -999.2500 -999.2500 -999.2500 2.0166 -999.2500 -999.2500 7500.0000 0.6989 0.7615 -999.2500 -999.2500 112.8611 67.6253 98.7317 11.5297 11.2510 -999.2500 5.7152 -999.2500 -999.2500 -999.2500 4.1183 -999.2500 -999.2500 7550.0000 0.5264 0.5912 145.8023 191.7453 103.0092 79.4642 116.0163 10.1824 9.9122 59.4333 7.7614 6.8586 27.4241 26.7307 5.0030 5.2153 112.8875 7600.0000 2.2612 2.3179 767.0244 801.5287 202.0711 40.4130 59.0023 23.7665 23.4424 94.2167 1.3488 1.3037 249.2727 252.0224 1.2176 1.2476 114.9828 7650.0000 0.8491 0.9087 235.4042 257.4969 118.0885 59.7490 87.2325 12.2464 11.9633 149.2633 4.5924 4.2480 35.0226 30.5507 3.7412 3.8835 116.9375 7700.0000 0.4953 0.5588 137.2643 173.8724 98.1989 79.2357 115.6826 9.5621 9.2988 121.8000 8.2431 7.2852 15.8801 15.3290 5.5424 5.7513 123.9125 7750.0000 0.6212 0.6856 171.2836 220.7484 109.9472 65.6819 95.8652 11.1307 10.8529 118.7000 6.5022 5.6383 47.8251 50.6700 4.3538 4.5300 125.6000 7800.0000 0.6476 0.7089 177.7438 207.6489 106.6170 72.5436 105.9123 10.7089 10.4357 172.2167 6.2488 5.6261 43.0591 46.0245 4.6486 4.8158 129.0875 7850.0000 0.3237 0.3893 94.4003 130.7866 86.3853 77.2894 112.8411 7.9364 7.6884 69.3167 13.0008 10.5932 42.4294 43.2181 7.3061 7.6460 123.5750 DEPTH DCCM PDEM RPCM ATCM GRAM RACM RPDE ATDC GRCM RADE TCDM CADE PDCM ROPA CPDE PDDC ROPS 7900.0000 88.9142 65.5500 6.8638 0.4006 90.6839 10.3417 7.4817 0.4632 132.3969 8.8698 128.5250 112.7420 8.0559 48.7134 133.6601 7.8026 48.2487 7950.0000 97.6976 72.5667 5.6036 0.4528 89.3737 9.0815 5.9276 0.5182 130.4839 7.8908 131.0000 126.7295 9.3796 50.2047 168.7017 9.1160 48.9380 8000.0000 96.3464 75.8492 5.7736 8050.0000 92.6494 67.8989 6.28O6 0.4481 88.8557 9.1796 6.0456 0.3934 90.9216 10.4800 6.6313 0.5128 129.7278 7.9773 132.4625 0.4590 132.7440 8.9548 133.2500 125.3551 9.2598 47.O976 111.6715 8.7195 41.4308 165.4108 8.9983 47.8903 150.8000 8.4824 20.5129 8100.0000 91.6520 81.0492 6.4288 8150.0000 85.9509 53.7500 7.3864 0.3547 88.8233 11.6254 6.7237 0.2938 82.0501 13.9884 7.7409 0.4220 129.6804 9.7618 134.4875 0.3610 119.7916 11.4237 134.6000 102.4397 8.6392. 52.3569 87.5370 7.8706 56.1963 148.7265 8.3846 53.6952 129.1843 7.6242 53.8545 8200.0000 88.5172 83.1000 6.9306 8250.0000 81.3571 146.3167 8.3230 0.3061 92.9272 13.4422 7.2564 0.2836 89.7108 14.2276 8.7381 0.3743 135.6720 11.0191 137.1875 0.3482 130.9762 11.8426 137.9750 90.7518 8.2159 62.1060 84.4410 7.2557 46.9689 137.8096 7.9657 59.0677 114.4415 7.0166 45.0744 8300.0000 94.9044 109.7833 5.9638 8350.0000 99.1828 86.0167 5.4252 0.3754 87.5047 10.7037 6.2308 0.~56 65.6365 9.6999 5.6565 0.4436 127.7552 9.2756 138.2000 0.5029 125.3197 8.1400 139.5500 107.8092 9.0797 33.4918 122.6503 9.6610 39.1823 160.4919 8.8206 36.1621 176.7259 9.3966 38.5485 8400.0000 126.5027 286.6167 3.2346 0.7737 102.4456 5.1014 3.3524 0.8404 149.5687 4.6459 141.6875 215.2424 13.4002 37.2508 298.2932 13.1081 38.5485 DEPTH ATCM ATDC CADE CPDE DCCM GRAM GRCM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 8450.0000 0.8629 0.9267 240.8777 301.8819 127.7728 99.7704 145.6631 13.4969 13.2052 199.0667 4.5073 4.1515 16.2752 16.3180 3.1672 3.3126 138.8188 8455.0000 0.9404 1.0027 264.1221 319.7265 130.5760 59.1466 86.3530 13.9746 13.6797 201.0667 4.0815 3.7861 16.9681 17.2872 3.0256 3.1277 138.6500 Tape File Start Depth = 7455.000000 Tape File End Depth = 8455.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 4 is type: LIS DEPTH ATCM ATDC CADE CPDE DCCM GRAM GRCM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 8456.0000 0.9403 1.0029 264.1650 318.7407 130.9644 61.9040 90.3788 13.9494 13.6538 200.6833 4.0817 3.7855 16.7280 16.4362 3.0068 3.1373 138.6500 8456.2500 0.9419 1.0044 264.6478 321.2765 131.1097 61.8660 90.3233 14.0134 13.7203 200.8875 4.0739 3.7786 16.7280 16.6308 2.9998 3.1126 138.6500 8500.0000 0.7434 0.8056 205.1 633 246.2920 115.6679 65.5251 124.8652 11.9126 11.6314 3278.8667 5.3357 4.8742 16.3949 15.6681 3.9091 4.0602 142.7000 8550.0000 0.5737 0.6361 157.8360 190.3375 102.6488 108.5215 158.4394 10.1312 9.8628 15.9000 7.0808 6.3357 16.6250 17.0000 5.0406 5.2538 116.2625 8600.0000 0.5967 0.6602 164.3688 206.1014 106.5079 99.4670 145.2493 10.6563 10.3837 59.3500 6.7889 6.0839 16.0000 16.0000 4.6587 4.8520 114.6875 8650.0000 0.4464 0.5136 125.5566 168.4677 97.0391 96.8426 141.3884 9.3693 9.1074 90.2000 9.1715 7.9645 34.7383 35.4388 5.6855 5.9359 115.1375 8700.0000 0.5419 0.6055 149.5987 189.2189 102.3777 102.8816 150.2053 10.0960 9.8269 90.9000 7.5268 6.6846 40.4801 39.8189 5.0692 5.2649 118.6250 8750.0000 0.4049 0.4708 114.6582 157.9449 94.2128 100.3429 146.4989 8.9857 8.7271 74.4833 10.1792 8.7216 45.6099 44.6247 6.0584 6.3313 122.5625 8800.0000 0.5783 0.6460 160.4826 230.7683 112.2350 106.7706 155.8831 11.4437 11.1638 87.4000 7.0226 6.2312 40.2938 42.5491 4.1673 4.3333 125.6000 8850.0000 0.7077 0.7733 195.8640 263.0134 119.2643 105.7201 154.3494 12.4075 12.1230 91.6167 5.6366 5.1056 43.8520 42.6974 3.6635 3.8021 128.4125 DEPTH ATCM ATDC CADE CPDE DCCM GRAM GRCM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 8900,0000 0.3346 0,4021 97.5389 143.1529 90.0765 133.2557 194.5510 8.4260 8.1722 70.8333 12.3164 10.2523 68.6517 40.7343 6.6739 6.9855 130.8875 8950.0000 0.8346 0.8980 232.2232 290.6512 124.9738 145.6885 212.7026 13.1915 12.9009 100.4167 4.6837 4.3062 47.8117 46.1477 3.3187 3.4405 133.7000 9000.0000 0.1393 0.2052 50.9103 78.4124 68.6713 107.6107 157.1098 5.5851 5.3708 79.0667 27.9096 19.6424 63.6056 63.1398 12.0794 12.7531 131.4500 9050.0000 0.2880 0.3589 87.0537 144.0638 90.3178 109.1736 159.3915 8.4586 8.2053 99.4167 14.2588 11.4672 39.1033 38.9586 6.6355 6.9404 137.1875 9100.0000 0.5258 0.5938 146,5488 213.7133 108.2943 133.2616 194.5595 10.9022 10.6280 110.2500 7.7676 6.8237 34.8944 30.5176 4.4965 4.6792 138.8188 9150.0000 0.8598 0.9269 240.9580 340.2654 134.5362 135.1762 197.3549 14.5041 14.2092 108.6333 4.5259 4.1501 31.8029 33.5973 2.8413 2.9389 140.7875 9200.0000 0.5923 0.6620 164.8775 251.9498 116.9046 148.4104 216.6766 12.0818 11.7986 65.6655 6.8424 6.0651 61.0076 62.1734 3.8219 3.9690 138.6500 9250.0000 0.5054 0.5762 141.8785 225.3978 111.0008 179.2651 261.7530 11.2726 10.9958 117.1488 8.0973 7.0483 34.9277 35.4368 4.2664 4.4366 140.5625 9300.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 47.4611 53.0741 -999.2500 -999.2500 141.1250 9335.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 53.0740 53.0740 -999.2500 -999.2500 142.3625 Tape File Sta~ Depth = 8456.000000 Tape File End Depth = 9335.000000 Tape File Lev~ Spacing = 0.250000 Tape File Depth UnEs = Fe~ Tape Subfile 5 is type: LIS Tape Subfile 2 i's type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN1 5900.01 BRAD ESARY J. GAFFNEY 500292232700 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 01-JUN-93 RUN2 K. MARTIN 36 12N 14E RUN3 2055 2474 49.00 13.00 RECEIVED AUG 3 t 1993 AMska ~I a ~Ga$ ,C~n~. OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) lST STRING 2ND STRING 3RD STRING PRODUCTION STRING 8.500 REMARKS: 9.625 9323.0 9822.0 DLL/MLL/AC/GR CIRCULATION STOPPED @ 02:30 20-APR-93. LOG ORIGINALY TIED TO SBT DATED 24-FEB-93. IT WAS LATER DISCOVERED THAT THE SBT WAS OFF DEPTH. THERE- FOR THE OPEN HOLE LOGS WERE REVISED. THE MARKED LINE USED FOR OPEN HOLE LOGGING WAS USED AS DEPTH CONTROL. WASHED OUT AREA BELOW CASING CAUSING ACOUSTIC CYCLE SKIPS. LOGGED GAMMA RAY TO 9036' FOR TIE-IN. DRILLER REPORTED HAVING TO DRILL UP BIT CONES & SHANKS FROM 12.25" BIT RUN. CALIPER VERIFICATIONS PERFORMED IN CASING. $ FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR DLL BCS $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA 0.5000 START DEPTH STOP DEPTH 9311.0 9762.0 9313.0 9805.0 9311.0 9783.0 GR (MEASURED DEPTH) BASELINE DEPTH MLL 9311.0 9311.0 9316.5 9323.5 9347.5 9356.5 9361.0 9366.0 9366.5 9371.5 9372.0 9380.5 9382.5 9397.5 9414.0 9425.0 9434.5 9438.0 9448.5 9453.5 9456.0 9458.5 9463.5 9475.0 9479.0 9546.5 9551.0 9551.5 9553.0 9553.5 9554.0 9555.5 9558.5 9559.0 9562.0 9565.0 9578.0 9578.5 9580.5 9586.0 9590.5 9594.0 9347.5 9356.5 9360.5 9367.5 9373.0 9382.5 9397.0 9414.0 9438.0 9552.0 9553.5 9558.0 9562.0 9578.0 9586.0 9590.0 all runs merged; EQUIVALENT UNSHIFTED DEPTH LL3 9311.0 9316.5 9323.0 9348.0 9356.5 DT 9311.0 9367 9373 9382 9396 .5 .0 .5 .5 9366.5 9373.0 9380.0 9397.0 9424.5 9434.0 9438.0 9448.5 9453.5 9455.0 9457.5 9463.5 9475.0 9479.0 9547.0 9551.5 9553.5 9555.0 9554.0 9557.5 9559.0 9565.0 9578.0 9586.0 9590.0 9593.5 9578.0 9580.5 9587.0 no case 9594.5 9624.5 9647.5 9648.0 9651.0 9658.5 9660.0 9664.5 9665.0 9666.5 9669.5 9700.5 9705.0 9710.0 9738.0 9738.5 9739.5 9750.0 9750.5 9751.5 9817.0 MERGED DATA SOURCE PBU TOOL CODE GR DLL BCS $ REMARKS: CN WN FN COUN STAT 9594.5 9624.5 9647.5 9648.5 9651.5 9659.0 9658.5 9660.0 9664.5 9664.5 9664.5 9666.5 9670.0 9670.0 9701.0 9701.0 9701.0 9705.0 9705.0 9709.5 9738.0 9738.5 9739.5 9740.0 9749.5 9750.5 9751.5 9817.0 9817.0 9817.0 RUN NO. PASS NO. MERGE TOP 1 5 9311.0 1 5 9313.0 1 5 9311.0 MERGE BASE 9762.0 9805.0 9783.0 OPEN HOLE SECTION OF MAIN PASS. MTEM, CALl, TEND, & TENS WERE SHIFTED WITH MLL. LLD & SP WERE SHIFTED WITH LL3. $ : ARCO ALASKA INCORPORATED : AGI - 5 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units GR BCS 68 1 GAPI DT BCS 68 1 US/F TEND BCS 68 1 LB TENS BCS 68 1 LB MLL DLL 68 1 OHMM CALl DLL 68 1 IN LL3 DLL 68 1 OHMM Size API API API API Log Crv Crv Length Typ Typ Cls Mod 4 67 465 06 6 4 84 653 71 5 4 20 789 90 0 4 20 789 90 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 8 LLD DLL 68 1 9 SP DLL 68 1 10 MTEM DLL 68 1 * DATA RECORD (TYPE# 0) Total Data Records: 45 OHMM 4 MV 4 DEGF 4 1018 BYTES * 4 30 739 95 4 30 739 95 4 30 739 95 40 Tape File Start Depth = 9817.000000 Tape File End Depth = 9311.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 11144 datums Tape Subfile: 2 193 records... Minimum record length: 50 bytes Maximum record length: 1018 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 9064.0 9311.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) .... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: CN WN FN COUN STAT CASED HOLE PORTION OF MAIN PASS. $ : ARCO ALASKA INCORPORATED : AGI - 5 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 2 MTEM GR 68 1 DEGF 3 TEND GR 68 1 LB 4 TENS GR 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 21 990 60 6 4 4 45 987 88 5 4 4 10 579 41 1 4 4 10 579 41 1 16 * DATA RECORD (TYPE# 0) Total Data Records: 13 1006 BYTES * Tape File Start Depth = 9311.000000 Tape File End Depth = 9009.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 3026 datums Tape Subfile: 3 38 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 4 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE S~RY FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 1 5 0.2500 VENDOR TOOL CODE START DEPTH GR 9063.0 DLL 9312.0 MLL 9312.0 AC 9307.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT CABLEHEAD TENSION TEMP TEMPERATURE PCM PULSE CODE MODULATOR MIS MASS ISOLATION SUB DLL DUAL LATEROLOG GR GAMMA RAY MIS MASS ISOLATION SUB AC BHC-ACOUSTILOG KNJT KNUCKLE JOINT KNJT KNUCKLE JOINT MLL MICRO LATEROLOG $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): STOP DEPTH 9771.0 9760.0 9814.0 9791.0 20-APR-93 FSYS REV. J001 VER. 1.1 230 20-APR-93 811 20-APR-93 9822.0 9811.0 9063.0 9805.0 1500.0 TOOL NUMBER 3974XA 2806XA 3506XA 3967XA 1229EA/1229MA 1309XA 3967XA 1609EA/1603MA 3921NA 3921NA 1233XA 8.500 9323.0 9311.0 FLO PRO 9.60 68.0 9.6 6.8 MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : AGI - 5 : PRUDHOE BAY : NORTH SLOPE : ALASKA 141.9 0.091 70.0 0.047 141.9 0.115 70.0 0.000 0.0 0.410 70.0 0.000 0.0 0.00 0.000 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 2 AC AC 68 3 ACQ AC 68 4 CHT AC 68 5 TTEN AC 68 6 RMLL MLL 68 7 CAL MLL 68 8 RS DLL 68 9 RD DLL 68 10 SP DLL 68 11 TEMP DLL 68 12 SPD DLL 68 1 GAPI 4 1 US/F 4 1 4 1 LB 4 1 LB 4 1 OHMM 4 1 IN 4 1 OHMM 4 1 OHMM 4 1 MV 4 1 DEGF 4 1 F/MN 4 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 95 558 30 1 4 95 558 30 1 4 71 857 46 1 4 90 132 02 1 4 40 514 81 0 4 39 859 45 0 4 23 415 80 5 4 84 503 82 1 4 11 639 82 1 48 * DATA RECORD (TYPE# 0) 994 BYTES * Total Data Records: 171 Tape File Start Depth = Tape File End Depth = 9817.000000 9009.000000 Tape F~ile Aevel Spacing = Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 53174 datums Tape Subfile: 4 252 records... Minimum record length: 62 bytes Maximum record length: 994 bytes 0.250000 Tape Subfile 5 is type: LIS RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 4 0.2500 VENDOR TOOL CODE START DEPTH GR 9307.0 DLL 9312.0 MLL 9309.0 AC 9307.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP PCM MIS DLL GR MIS AC KNJT KNJT MLL $ CABLEHEAD TENSION TEMPERATURE PULSE CODE MODULATOR MASS ISOLATION SUB DUAL LATEROLOG GAMMA RAY MASS ISOLATION SUB BHC-ACOUSTILOG KNUCKLE JOINT KNUCKLE JOINT MICRO LATEROLOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) STOP DEPTH 9771.0 9760.0 9814.0 9791.0 20-APR-93 FSYS REV. J001 VER. 1.1 230 20-APR-93 736 20-APR-93 9822.0 9811.0 9063.0 9805.0 1500.0 TOOL NUMBER 3974XA 2806XA 3506XA 3967XA 1229EA/1229MA 1309XA 3967XA 1609EA/1603MA 3921NA 3921NA 1233XA 8.500 9323.0 9311.0 FLO PRO 9.60 68.0 9.6 6.8 141.9 MUD AT-MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : AGI - 5 : PRUDHOE BAY : NORTH SLOPE : ALASKA 0.091 70.0 0.047 141.9 0.115 70.0 0.000 0.0 0.410 70.0 0.000 0.0 0.00 0.000 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units 1 GR AC 68 1 GAPI 2 AC AC 68 1 US/F 3 ACQ AC 68 1 4 CHT AC 68 1 LB 5 TTEN AC 68 1 LB 6 RMLL MLL 68 1 OHMM 7 CAL MLL 68 1 IN 8 RS DLL 68 1 OHMM 9 RD DLL 68 1 OHMM 10 SP DLL 68 1 MV 11 TEMP DLL 68 1 DEGF 12 SPD DLL 68 1 F/MN API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 06 969 49 6 4 4 48 852 89 1 4 4 81 285 47 0 4 4 95 558 30 1 4 4 95 558 30 1 4 4 71 857 46 1 4 4 90 132 02 1 4 4 40 514 81 0 4 4 39 859 45 0 4 4 23 415 80 5 4 4 84 503 82 1 4 4 11 639 82 1 48 * DATA RECORD (TYPE# 0) Total Data Records: 172 994 BYTES * Tape File Start Depth = 9817.000000 Tape File End Depth = 9001.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 45472 datums Tape Subfile: 5 251 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 6 is type: LIS 93/ 5/ 7 01 **** REEL TRAILER **** 93/ 6/ 6 O1 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Sun 6 JUN 93 3:12p Elapsed execution time = 28.34 seconds. SYSTEM RETURN CODE = 0