Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
192-146
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, September 23, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC AGI-04 PRUDHOE BAY UNIT AGI-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/23/2025 AGI-04 50-029-22323-00-00 192-146-0 G SPT 7921 1921460 1980 3375 3379 3378 3378 29 53 53 52 4YRTST P Guy Cook 8/15/2025 Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT AGI-04 Inspection Date: Tubing OA Packer Depth 212 2395 2360 2356IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250815170620 BBL Pumped:6.7 BBL Returned:3.6 Tuesday, September 23, 2025 Page 1 of 1 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU AGI-04 Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 192-146 50-029-22323-00-00 11655 Conductor Surface Intermediate Production Liner 8491 76 3503 10945 845 11635 20" 13-3/8" 9-5/8" 7" 8478 35 - 111 35 -3538 33 - 10978 10810 - 11655 35 - 111 35 - 3538 33 - 8058 7954 - 8491 none 470 1950 4760 7020 none 1490 3450 6870 8160 11115 - 11557 7" x 5-1/2" NT80 x L80 31 - 10816 8145 - 8427 Structural 7" Baker SB-3A 7921 , 2211 10752 7921 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 0 0 291285 280524 0 0 50 50 3436 3442 324-064 13b. Pools active after work:PRUDHOE OIL 7" CAMCO WRDP-2 10752 , 2211 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 31 - 7958 By Grace Christianson at 8:37 am, Apr 16, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.04.15 16:09:44 - 08'00' Bo York (1248) WCB 2024-07-15 RBDMS JSB 041924 DSR-4/22/24 ACTIVITYDATE SUMMARY 3/16/2024 T/I/O = 3500/46/62 (WATER WASH) Pumped 10 bbls 60/40, 100 bbls 120*F DSL, 375 bbls fresh water with surfactant, and 5 bbls 60/40 down TBG. Let TBG siak for 2 hours. Pumped 215 bbls of FW with surfactant and 15 bbls of 60/40 down TBG. DSO notified upon departure FWHP =280/65/142 Daily Report of Well Operations PBU AGI-04 (WATER WASH) Pumped 10 bbls 60/40, 100 bbls 120*F() DSL, 375 bbls fresh water with surfactant, and 5 bbls 60/40 down TBG. Let TBG siak for 2 hours. Pumped 215 bbls of FW with surfactant and 15 bbls of 60/40 down TBG. 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-04 Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 192-146 50-029-22323-00-00 ADL 0034628 , 0028301 11655 Conductor Surface Intermediate Production Liner 8491 76 3503 10945 845 11635 20" 13-3/8" 9-5/8" 7" 8478 35 - 111 35 -3538 33 - 10978 10810 - 11655 3250 35 - 111 35 - 3538 33 - 8058 7954 - 8491 none 470 1950 4760 7020 none 1490 3450 6870 8160 11115 - 11557 7" x 5-1/2" NT80 x L80 31 - 108168145 - 8427 Structural 7" Baker SB-3A 7" CAMCO WRDP-2 10752 , 2211 7921 , 2211 Date: Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY 3-1-2024 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Coldiron at 1:36 pm, Feb 08, 2024 324-064 Digitally signed by Eric Dickerman (4002) DN: cn=Eric Dickerman (4002) Date: 2024.02.07 13:20:42 - 09'00' Eric Dickerman (4002) MGR13FEB24 DSR-2/13/24 10-404 SFD 2/9/2024*&:JLC 2/15/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.15 15:00:27 -06'00'02/15/24 RBDMS JSB 021524 Well Work Prognosis Well Name:AGI-04 API Number:50-029-22323-00 Current Status:Gas Injector Leg:N/A Estimated Start Date:3/1/24 Rig:N/A Reg. Approval Req’d?10-403 Date Reg. Approval Received: Regulatory Contact:Carrie Janowski Permit to Drill Number:192-146 First Call Engineer:Dave Bjork Office: 907-564-4672 Cell: 907-440-0331 Second Call Engineer: Gas Injection Rate: ~287,000 Mscf/Day Injection Pressure: 3,475 psi Reservoir Pressure (Estimate): 3300 psi Program Objective(s): AGI-04 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-04 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 375 bbls of fresh water with 0.02% F-103 surfactant at ~5 bpm. Max pressure during this pumping can reach 1800 psi. Once 375 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 ~5 bpm for next 225 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 375 5 75 1.25 Soak 2.00 FW flush 225 5 45 0.75 methanol cap 15 1.5 10 0.17 5.44 Soak Time of Diesel/Xylene 1 2 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 Diesel/Xylene Notes Note 1 Note 2 Note 3 Hot fluids recommended: Note 1 Fresh Water and Surfactant Notes Note 1 Max pump rates creates turbulence and has contact with the tubing walls. Also cuts down on time Use COTU "diesel" only in these treatments if available. See Craig Graff explanation below. COTU technically can’t make diesel. On good days it can make Jet A or Heating Oil. Neither meet the specs for diesel. The reason they are different is that they have a lot more aromatics and sulfur in them than diesel. Road diesel and ULSD have most of those bad components taken out, which means that they can only dissolve straight chain hydrocarbons (paraffins), and not aromatics. These will make asphaltenes precipitate instead of cleaning them up.COTU “diesel” has enough things like xylene and toluene left in it to make it a pretty good solvent even for asphaltenes. A real refinery would take all of those out to be sold for higher margins in other products. If COTU "diesel"is not available, use other available diesel and xylene at a 50/50 mixture. As you read diesel in instructions below, can substitue with diesel/xylene If xylene is used for a 50/50 diesel/xylene mixture, heated xylene to 80 deg F or higher, use pump rates of 1 to 1.5 bpm. Injectivity results have improved when all fluids pumped are at warmer temps MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg <? II DATE: Thursday, August 5, 2021 P.I. Supervisor +!f%13` �) SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC AGI -04 FROM: Brian Bixby PRUDHOE BAY UNIT AGI -04 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT AGI -04 API Well Number 50-029-22323-00-00 Inspector Name: Brian Bixby Permit Number: 192-146-0 Inspection Date: 8/4/2021 Insp Num: mitBDB210804151310 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60Min Well AGI -04 Type Ind G TVL 79211 Tubu ing 3291 - -- 3290 3288 ' 3289 - PTD 1921460 'Type Test SPT' Test psi I9so IA 310 zzo7 - 2171 - 2170 BBL Pumped: 6 BBL Returned: 13.5 OA 101 116 - 116 - 116 Interval 4YRTST P/F P Notes: Thursday, August 5, 2021 Page 1 of I Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:192-146 6.50-029-22323-00-00 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 11655 11635 8478 10752 7921 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 76 20" 35 - 111 35 - 111 1490 470 Surface 3503 13-3/8" 35 - 3538 35 - 3538 3450 1950 Intermediate 10945 9-5/8" 33 - 10978 33 - 8058 6870 4760 Production Perforation Depth: Measured depth: 11115 - 11557 feet True vertical depth:8145 - 8427 feet Tubing (size, grade, measured and true vertical depth)7" x 5-1/2" NT80 x L80 31 - 10816 10752 7921Packers and SSSV (type, measured and true vertical depth) 7" Baker SB-3A Packer Liner 845 7" 10810 - 11655 7954 - 8491 8160 7020 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 332427500 0229567 267 220345 0 3325 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 measured8491 Sundry Number or N/A if C.O. Exempt: 321-273 7" CAMCO WRDP-2 SCSSV 2211 2211 Junk Packer Printed and Electronic Fracture Stimulation Data 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-04 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 12:04:02 -08'00' Bo York MGR29JUL2021 SFD 6/18/2021RBDMS HEW 6/14/2021 DSR-6/14/21 ACTIVITYDATE SUMMARY 6/3/2021 T/I/O = 2681/240/105 Temp - 99*. Conduct TBG Wash. Pumped 10 bbls 60/40 into TBG for Spear. Pumped 50 bbls 120* DSL into TBG followed with 375 bbls Fresh water w/ F-103 Sufactant. Allowed 2 hours soak time. Pumped 225 bbls fresh water w/ F-103 Surfactant followed by 15 bbls 60/40. SV WV closed MV open CV OTG FWHP'S T/I/O=145/235/122 Daily Report of Well Operations PBU AGI-04 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:192-146 6.API Number:50-029-22323-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028301, ADL 0034628 Property Designation (Lease Number):10. N/A 8. PBU AGI-04 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Water Wash Op Shutdown GAS GSTOR WAG 5 SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 11655 Effective Depth MD: NT80 x L80 11. 6/8/2021 Commission Representative: 15. Suspended Contact Name: David Bjork Contact Email: David.Bjork@hilcorp.com Authorized Name: Stan Golis 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" CAMCO WRDP-2 SCSSV Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8491 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 10752, 7921 2211, 2211 Date: Liner 845 7" 10810 - 11655 7954 - 8491 8160 7020 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 35 - 3538 35 - 3538 14. Estimated Date for Commencing Operations: BOP Sketch 35 - 111 Structural 6870 Proposal Summary 13. Well Class after proposed work: 7" Baker SB-3A Packer 11115 - 11557 8145 - 8427 7" 26# x 5-1/2" 17#31 - 10816 Production 11635 8478 None None 35 - 111 470 13-3/8" 9-5/8" Contact Phone:907.564.4672 Date: 4760 76 149020"Conductor 1950 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 3503 3450 Intermediate 10945 33 - 10978 33 - 8058 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 3250 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:26 am, Jun 02, 2021 321-273 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.06.02 10:18:43 -08'00' Stan Golis (880) DSR-6/2/21MGR02JUN21 10-404 DLB06/01/2021 dts 6/3/2021 JLC 6/3/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.03 11:09:14 -08'00' RBDMS HEW 6/4/2021 Well Work Prognosis Well Name:AGI-04 API Number:50-029-22323-00 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:192-146 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: ~225,000 Mscf/Day Injection Pressure: 3,343 psi Reservoir Pressure (Estimate): 3250 psi Program Objective(s): AGI-04 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) Spear Methanol / Water TBG 10 1-3 2500 Solvent Diesel TBG 50 1-3 2500 Over-Flush Fresh Water TBG 600 see below 1800 Freeze Protect Methanol / Water TBG 15 1-3 1800 Detailed Procedure Pump Time Fluid type vol (bbls)rate (bpm)Time (min) time (hours) methanol 10 1 10 0.17 diesel 50 1.5 33 0.56 FW flush 375 5 75 1.25 Soak 2.00 FW flush 225 5 45 0.75 FP 15 1.5 10 0.17 4.89 Well AGI-04 MIT #1 Test Type GI Water Wash Target Pressure Test Fluid Max Applied Pressure 06/01/21 Test Fluid David Bjork Integrity Limits Confirmed (907) 564-4672 MIT #2 Test Type Target Pressure Max Applied Pressure Integrity Limits Confirmed Integrity Limits Confirmed MIT #3 Test Type Target Pressure Max Applied Pressure Test Fluid Increase well injectivity by performing a water wash. -Use 2 full uprights of fresh water mixed with 0.02% F-103 surfactant. Use 50 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 375 bbls of fresh water with 0.02% F-103 surfactant at ~5 bpm. Max pressure during this pumping can reach 1800 psi. Once 375 bbls has been pumped, shut -down pumps and let diesel soak across perfs for 2 hours -this should allow ~ 25 bbls of diesel to be pumped into perfs and a remaining 25 bbls to soak outside the perfs. b.) After the 2 hour soak time, resume pumping at ~5 bpm for next 225 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. See ~ pumping time schedule and notesbelow COTU diesel has xylene impurities left, treat with proper safety precautions Directions When filling out the pumping template, please note the following: If "MIT" is selected as a stage,the corresponding MIT section must be filled out. The boxes are defined as follows: Test Type:Type of test to be performed (MIT-T, MIT-IA, MIT-OA, etc) Target Pressure:This is the requested MIt test pressure (ie MIT-T to 2500 psi) Max Applied Pressure: This is the max pressure that can be applied in order to achieve a passing MIT of the target test pressure, typically 10% greater than target pressure. BP practice 100218 (10 -45) requires that the test pressure must remain above or equal to the target pressure during the entire test evaluation period. This pressure must not exceed the lowest rated working pressure (taking into account corro sion, erosion, etc) of any well barrier element in the well barrier envelope. Test Fluid:The fluid to be used for the test. Integrity Limits Confirmed:By checking this box, you have confirmed that the "Max Applied Pressure" requested is within the limits of the wells "Well Barrier Envelope". Clear • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re gg DATE: Monday,September 11,2017 C�� ' P.I.Supervisor \ L ICi 7 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. AGI-04 FROM: Guy Cook PRUDHOE BAY UNIT AGI-04 Petroleum Inspector Src: Inspector Reviewed By:j� P.I.Supry `1l NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT AGI-04 API Well Number 50-029-22323-00-00 Inspector Name: Guy Cook Permit Number: 192-146-0 Inspection Date: 8/5/2017 Insp Num: mitGDC170805184058 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well AGI-04 Type Inj G 1TVD 7921 Tubing 3326 3345 - 3350 3389 • 3358 • 3299 ' PTD 1921460 - Type Test SPT Test psi 1980 IA 57 2496 ' 2512 • 2561 2629 • 2672 :.- BBL Pumped: 5.8 • BBL Returned: 4.5 ' OA 142 154 157 159 161 164 Interval 4YRTST P/F P / Notes: MIT-IA. A fluid level shot was taken before testing to show the fluid level at 100'. Total testing time was 2 hours and 45 minutes due to thermal expansion of the cooler diesel being pumped into the well which was at 104 degrees Fahrenheit. The gas on the IA was bled off prior to testing, and until there was fluid at surface,before testing began.75 min.-3271/2688/165;90 min.-3281/2682/165;105 min.-3307/2691/166; 120 min.-3317/2721/167; 135 min.-3295/2742/168;150 min.-3296/2742/168;165 min.-3305/2730%168 SCANNED ;SEB 1 2 'U '„ Monday,September 11,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,August 09,2017 P.I.Supervisor ( Cli 6/�o( SUBJECT: Mechanical Integrity Tests ( l BP EXPLORATION(ALASKA)INC. AGI-04 FROM: Guy Cook PRUDHOE BAY UNIT AGI-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT AGI-04 API Well Number 50-029-22323-00-00 Inspector Name: Guy Cook Permit Number: 192-146-0 Inspection Date: 8/5/2017 • Insp Num: mitGDC170805184058 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well AGI-04 Type Inj G ' TVD 7921 ' Tubing 3326 - 3295 r 3296 • 3305 - PTD 1921460 Type Test SPT Test psi 1980 IA 57 2742 - 2742 2730 BBL Pumped: 5.8 BBL Returned: 4.5 OA 142 168 - 168 - 168 Intervall 4YRTST P/F P Notes: MIT-IA. A fluid level shot was taken before testing to show the fluid level at 100'. Total testing time was 2 hours and 15 minutes due to thermal expansion of the cooler diesel being pumped into the well which was at 104 degrees Fahrenheit. The gas on the IA was bled off prior to testing, and until there was fluid at surface,before testing began. SCANNED € ' Wednesday,August 09,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,August 27,2013 TO: Jim Regg -71, a j SUBJECT: Mechanical Integrity Tests �' P.I.Supervisor l� i I� I BP EXPLORATION(ALASKA)INC AGI-04 FROM: Lou Grimaldi PRUDHOE BAY UNIT AGI-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry IGr- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT AGI-04 API Well Number 50-029-22323-00-00 Inspector Name: Lou Grimaldi Permit Number: 192-146-0 Inspection Date: 8/22/2013 Insp Num: mitLG130825142541 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min _ 2540 2538 2542 2538 Well AGI-04 (Type Inj 1 0 "TVD 7921 . IA 503 2 - — ----- -I _ t- PTD i 1921460 Type Test SPT Test psi 1980 . i OA 166 174 176 176 177 . Interval 4YRTST P/F P ; ,Tubing 3152 - 3154 3158 3160 1 3161 - Notes: 3.1 bbl's diesel pumped,3.3 bbl's returned.Deep,hot well required extra 15 minutes(45 total test time)for stabilization.Otherwise good test, pertinent paperwork provided. .- TS p It'SSt: S \)lei- cd4rkatej. ,2-1. , ,CA Tuesday,August 27,2013 Page 1 of 1 410 L441)— A-66/C C 756) Pre 9--,1,49 AA;-t L 6 1306-c'S 14 is.-4 Pr3ck A-6r—64 Pri) 46;c) -4-:: Wi'a* 00149A el' 143 Notatmeamr,.......N.444,.N",.,%Posteers" *** woorsi "%"""*Issmoses!°Simmk' a 3 @ 4 t 3 a 3 /133 1101a3a ttVerAlt STATE OF ALASKA ARKA OIL AND GAS CONSERVATION COMMI.N • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon LI Repair Well U Plug Perforations U Perforate L OtherLd Water Wash Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Wei 2. Operator 4. Well Class Before Work: 5. Permit to Drill Numbers Name: BP Exploration (Alaska), Inc I o Development❑ Exploratory ❑ 192 -146 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service 0 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22323 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0034628 PBU AGI -04 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 11655 feet Plugs measured None feet true vertical 8490.54 feet Junk measured None feet Effective Depth measured 11635 feet Packer measured 10752 feet true vertical 8477.58 feet true vertical 7920.95 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 3416 13 -3/8" 68# L -80 122 - 3538 122 - 3538 5020 2260 Intermediate None None None None None None Production 10950 9 -5/8" 47# NT8OS 28 - 10978 28 - 8057.98 6870 4760 Liner 839 7" 26# NT -80 10816 - 11655 7957.89 - 8490.54 7240 5410 Perforation depth Measured depth 11115 - 11135 feet 11230 - 11250 feet 11310 - 11320 feet 11390 - 11400 feet 11460 - 11480 feet 11537 - 11557 feet True Vertical depth 8144.79 - 8157.52 feet 8218.17 - 8230.97 feet 8269 39 - 8275.79 feet 8320.5 - 8326.89 feet 8365.13 - 8377.87 feet 8414.33 - 8427.19 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 10752 7920.95 Packer None None None SSSV 12. Stimulation or cement squeeze summary: RECEIVED Intervals treated (measured): SCANNED `� JAN 2 8 2013 r� Treatment descriptions including volumes used and final pressure: P 2 Q 1 13. Representative Daily Average Production or Injection Data AOG CC Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 57 0 - 0 2588 Subsequent to operation: 0 185 0 0 3290 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratorL1 Development ❑ Service El Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas 11 WDSPIJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ p,_ SUSP ❑ SPLUC❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -200 Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature e Phone 564 -4424 Date 9/21/2012 F i 8 DMS SEP 2 5 2012 �i ■( `') ,0,7��I,. Form 10 -404 Revised 11/2011 Submit Original Only 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 839 7" 26# NT -80 10816 - 11655 7957.89 - 8490.54 7240 5410 PRODUCTION 10950 9 -5/8" 47# NT8OS 28 - 10978 28 - 8057.98 6870 4760 SURFACE 3416 13 -3/8" 68# L -80 122 - 3538 122 - 3538 5020 2260 TUBING 10733 7" 26# NT -80 27 - 10760 27 - 7925.49 7240 5410 TUBING 56 5 -1/2" 17# L -80 IPC 10760 - 10816 7925.49 - 7957.89 7740 6280 • • Daily Report of Well Operations ADL0034628 ACTIVITYDATE SUMMARY 1= • 11 .1 e oas using sic e mprove njec ivi y 'umpe• I • • s meth spear followed by 100 bbls of diesel /xylene and 728 bbls of freshwater /F -103 surfactant. Freeze protected with 10 bbls meth tail. DSO to put on injection. * * *WSR CONTINUED ON 7 -11- 7/10/2012 12 * ** wsr continued from 07- 10 -12 * ** Finish rig down SV= closed WV,MV,SSV,IA,OA =open DSO 7/11/2012 POI before LRS departure • • TREE= _? WELLHEAD = CIW Slit NOTES: WELL REQUIRES A SSSV. LN OT ACTUATOR = BAKER C AG1-04 THREAD. CEMENTED. ALL TBG IS IPC WITH NSCC ELEV = 50' 'BF. ELEV = KOP = 3951' Max Angle = 64 @ 10229' Datum MD = 12151' 1 I 2211' I -17" CAMCO BAL -O SSSV NIP, ID = 5.937" Datum 11/D = 8800' SS • 113 -3/8" CSG, 68 #, K -55, ID = 12.415" I 122' 113 -3/8" CSG, 68 #, L -80, ID = 12.415" H 3538' 1-A Minimum ID = 4.455" @ 10804' 5 -1/2" OTIS XN NIPPLE 10751' I-1 ANCHOR, ID = 4.875" I --I 10752' H 9 -5/8" X 7" BAKER SB -3A PKR, ID = 4.874" I I 7" TBG, 26#, NT -80 -IPC, NSCC, .0383 bpf, ID = 6.276" H 10760' / I 10760' H 7 -5/8" X 5 -1/2" XO, ID = 4.875" I TOP OF 5-1/2" TBG H 10760' 1078 -1 5 -1 /2" PARKER SWS NIP, ID = 4.562" I I I I 10804' H 5-1/2" OTIS XN NIP, ID = 4.455" I 15 -1 /2" TBG, 17 #, L -80 -IPC, NSCC, .0232 bpf, ID = 4.892" H 10816' / \ L 10816' H 5 -1/2" WLEG I 17" LNR TOP I--1 10816' I 10836' I-I ELM TT LOG (05/07/93) ( 19 -5/8" CSG, 47 #, NT -80S, ID = 8.681" H 10978' I- A PERFORATION SUMMARY REF LOG: SWS,GR -CLL ON 05/07/93 ANGLE AT TOP PERF: 51 @ 11115' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 3-3/8" 6 11115 - 11135 0 5/22/93 3-3/8" 6 11230 - 11250 0 5/22/93 3-3/8" 6 11310 - 11320 0 5/22/93 3-3/8" 6 11390 - 11400 0 5/22/93 3-3/8" 6 11460 - 11480 0 5/22/93 3-3/8" 6 11537 - 11557 0 5/22/93 I PBTD I 11635' I IT LNR, 26#, NT -80, .0383 bpf, D = 6.276" I-1 11655' I , DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/17/93 ORIGINAL COMPLETION WELL: AGI-04 05/24/01 RN/TP CORRECTIONS PERMIT No: 1921460 03/13/03 AS/TP ADD IPC/THREAD FOR TBG API No: 50- 029- 22323 -00 08/30/06 MSS /PAG CORRECTIONS -TT, PBTD, LNR SEC 36, T12N, R14E, 1329.62' FEL & 2942.63' FNL 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE 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 . f+41ED AUs 0 7 2012 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 -' jr `T 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: 01/102012 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 AGI -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 , Spit conductor NA NA NA NA NA AGI -10 2061350 50029223530100 Dust cover NA NA NA NA NA II • c,_, u Tr SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Bob Chivvis Petroleum Engineer n .� 1 (� BP Exploration (Alaska), Inc. I O` P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU AGI -04 Sundry Number: 312 -200 Dear Mr. Chivvis: S L N D J U L Co 3 2 . 01 Z 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 holid. ■ o weekend. 0 o r - re1; , i 1 ,. No ma • omm loner DATED this da y of June 2012. Encl. STATE OF ALASKA RECEIVED ALOA OIL AND GAS CONSERVATION COMMIWON MAY 3 O 201 APPLICATION FOR SUNDRY APPROVALS 2 20 AAC 25.280 � ���� ((��,, 1. Type of Request: Abandon El Plug for Redrill ❑ Perforate New Pool El Repair Well ❑ Change A raGogm ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing 0 p 7 / , T i m e Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: WATER WASH 0 • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 192 -1460 ' 3. Address: P.O. Box 196612 Stratigraphic ❑ Service 61 . 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22323 -00 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 0 PBU AGI -04 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): 11655 - 8491 11635 8478 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 91.5# H -40 30' 106' 30' 106' 1490 470 Surface 93' 13 -3/8" 68# K -55 29' 122' 29' 122' 3450 1950 Intermediate 3416' 13 -3/8" 68# L -80 122' 3538' 122' 3538' 4930 2270 Production 10950' 9 -5/8" 47# NT80S 28' 10978' 28' 8058' 6870 4760 Liner 839' 7" 26# NT -80 10816' 11655' 7958' 8491' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 7" 26# NT -80 IPC 27' 10760' - - 5 -1/2" 17# L -80 IPC 10760' 10816' Packers and SSSV Tvoe: 7" CAMCO BAL -0 SSSV Packers and SSSV MD and TVD (ft): 2211' 2211' 7" BAKER SB -3A PKR 10752' 7921' 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 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 0 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 Phone Date /2 564 -5412 5/30/2012 Prepared by Nita Summerhay 564 -4035 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 1 2,- 7C)O Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: j4111111 APPROVED BY Approved by: / - / COMMISSIONER THE COMMISSION Date: (p „ D AAS J UN 0 6 tit � ' �x � ,�6 r v 1 m 10 403 Revised 1/2010 ��'� ��� �,� ORIGINAL �� v cQ�� Su bmit in D uplicate AGI -04 192 -146 PERF ATTACHMENT Sw Name Operation Date Pell Operation Code Meas Depth Top Meas Depth Base 'Tvd Depth Top Tvd Depth Base AGI -04 5/22/93 PER 11,115. 11,135. 8,144.79 8,157.52 AGI -04 5/22/93 PER 11,230. 11,250. 8,218.17 8,230.97 AGI-04 5/22/93 PER 11,310. 11,320. 8,269.39 8,275.79 AGI -04 5/22/93 PER 11,390. 11,400. 8,320.5 8,326.89 AGI -04 5/22/93 PER 11,460. 11,480. 8,365.13 8,377.87 AGI -04 5/22/93 PER 11,537. 11,557. 8,414.33 8,427.19 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 _ • WELLHEAD .= CIW SA NOTES: WELL REQUIRES A SSSV. ACTUATOR = BAKER C AG 1-04 THREAD. OT CEMENTED. ALL TBG IS IPC WITH NSCC KB. ELEV = 50' BF. ELEV = KOP = 3951' Max Angle = 64 @ 10229' ` Datum MD = 12151' Datum TVD = 8800' 51 2211' H 7" CAMCO BAL -0 SSSV MP, ID = 5.937" 1 13 -3/8" CSG, 68 #, K -55, ID = 12.415" I 122' 113 -3/8" CSG, 68 #, L -80, ID = 12.415" H 3538' 1-- Minimum ID = 4.455" @ 10804' 5 -1/2" OTIS XN NIPPLE 10751' H ANCHOR, ID = 4.875" Z --I 10752' H9-5/8" X 7" BAKER SB -3A PKR, ID = 4.874" I 17" TBG, 26 #, NT -80 -IPC, NSCC, .0383 bpf, ID = 6.276" I - 1 10760' ( / I 10760' 1 - 17 - 5/8" X 5-1/2" XO, ID = 4.875" 1 TOP OF 5-1/2" TBG H 10760' • 1 10782' --15 - 1/2" PARKER SWS NIP, ID = 4.562" 1 1 1 10804' H5-1/2" OTIS XN NIP, ID = 4.455" I 15 -1/2" TBG, 17 #, L -80 -IPC, NSCC, .0232 bpf, ID = 4.892" H 10816' L.,„, 10816' J5 -1/2 " WLEG 1 17" LNR TOP I-1 10816' 1 I 1 1 10836' 1 - 1 ELM TT LOG (05/07/93) 19 -518" CSG, 47 #, NT -80S, ID = 8.681" I--{ 10978' 1 PERFORATION SUMMARY REF LOG: SWS,GR -CLL ON 05/07/93 ANGLE AT TOP PERF: 51 © 11115' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 11115 - 11135 0 5/22/93 3 -3/8" 6 11230 - 11250 0 5/22/93 3-3/8" 6 11310 - 11320 0 5/22/93 3 -3/8" 6 11390 - 11400 0 5/22/93 3-3/8" 6 11460 - 11480 0 5/22/93 3-3/8" 6 11537 - 11557 0 5/22/93 1 PBTD H 11635' 1 IT LNR, 26 #, NT -80, .0383 bpf, ID = 6.276" I-1 11655' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/17/93 ORIGINAL COMPLETION WELL: AGI 05/24/01 RN/TP CORRECTIONS PERMIT No: ® 1921460 03/13/03 AS/TP ADD IPC/THREAD FOR TBG API No: 50- 029 - 22323 -00 08/30/06 MSS /PAG CORRECTIONS -TT, PBTD, LNR SEC 36, T12N, R14E, 1329.62' FEL & 2942.63' FNL 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) Ve rs i o n l .1 04/28/2010 Fullbore Pumping Design Template Well Nam AGI -04 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 30 700 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) 421 Wellbore Volume to Perfs (bbls) Fullbore Pumping Schedule 3400 Anticipated Bottom Hole Pressure (psi) Pump Volume Rate Max 1 Select I Tubing /Casing within Pressure Limits? Stage Fluid Type Into (bbls) (bpm) Pressure Size Burst /Collapse 80% Burst /Collapse Tubing Burst (psi) 7 7240.00 5792 1 Pre - Flush I 1 Methanol (60/40) 11 Tbg 10 51 1 25001 Tubing Collapse (psi) size See helpful tips tab Casing Burst (psi) size See helpful tips tab 1 Solvent I Select Fluid Type I Tbg 1 1 1001 1 5 1 25001 Casing Collapse (psi) size See helpful tips tab 1 Load 1 1 Select Fluid Type 1 Tbg 1 1 700 1 51 1 25001 Select Input Depth Integrity Issues? No unknown 1 Freeze Protect 1 1 Methanol (60/40) 11 Tbg 1 1 101 1 51 25001 No Input Depth • 1 Select Stage 1 1 Select Fluid Type 11 Select 1 1 11 1 1 1 1 No 1 Tubing Caliper? Burst/Collapse ratings may need to be derated based on tubing condition 1 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 1 Not Necessary 1 Hold Pressure on Other Strings? 3 700 bbls of fresh water with 0.02% F -103 surfactant Tubing (psi) 4 10 bbls 60/40 meoh IA (psi) 5 RDMO. Return well to gas injection OA (psi) 6 • • Fullbore Pumping Program for Field Well Name AGI -04 Job Scope Select Job Scope Well Type GI AFE APBinjec Date 5/29/2012 IOR 30 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 NGI/WGI /AGI gas injectors to improve injectivity. Fullbore Pumping Schedule Stage Fluid Type Pump Into Volume (bbls) Rate (bpm) Max Pressure 1 I Pre -Flush Methanol (60/40) Tbg I 10 5 I 2500 2 Solvent I I Select Fluid Type Tbg 1 100 5 I 2500 3 I Load Select Fluid Type Tbg 700 1 5 2500 4 Freeze Protect Methanol (60/40) Tbg 10 5 2500 5 Select Stage Select Fluid Type I Select Detailed Pumping Procedure 1 10 bbls 60/40 meoh spear 2 100 bbls 50/50 diesel /xylene 3 700 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) i Freeze Protection - see PE mandator 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 I od id drift id collapse burst bbls /ft ft/bbls bbls /ft ft/bbis 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 80 55.5# 6450 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 s Brine Design Notes Revised: 5/1/00 < NaCI KCI 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 8.9 22 9.1 19 10.5 -36 10.5 6 and 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. Be careful using CaCI in IA - may dump on formation. 9.1 17 9.5 15 10.8 -57 11.5 -11 Corrosion Inhibitor: mix 25 gal of NEEC EC1124 per 100 bbls brine. 9.2 14 9.6 33 10.9 -35 11.7 -16 Note: Inhibitor has a 1 day half -life. 9.3 11 11.0 -19 11.8 - 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 ao KCI / CaCI • ! NaCI ,/ 20 0 "4� o / 0 NaBr s o o r zo ■ - ♦ - NaCI 1 ao - � - CaCI \ / -. KCI -so - . NaBr 8.5 9,5 Density, PPG 10.5 11.5 12 .5 ~ ~ MEMORANDUM To: Jim Regg P.I. Supervisor I ~~ ~I~~~ ~~ FROM: Jeff Jones Petroleum Inspector ~ L_J State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, September 08, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC AGI-04 PRUDHOE BAY UNIT AGI-04 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: PRUDHOE BAY IINIT AGI-04 API Well Number: 50-029-22323-00-0o Inspector Name: JeffJones Insp Num: miUJ090906181523 permit Number: 192-146-0 / Inspection Date: g~22~2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We11 T AGI-04 Type Inj. CT T~ ~921 jt1 ~ 660 2200 2195 2230 2270 i P.T.D 1921460 TypeTest SPT Test psi ~9so.zs ~ QA 260 ~ 360 360 375 400 i ~ Tubing 3320 Interval 4YRTST p~F F ' 3320 3280 3310 3300 Notes: Repeat MIT I~-~-u (e ~c~ ~ S~ ~ L ~ ~ ~ ~ ~~, ~ff~SS~U~ ~-~~3 , ;,° ; ,.z:w~ ~ ;= ~~ ~.1., ~.~ `i _~ : ~~.. ~ ~ ~:a.,~ . . ~ _ Tuesday, September 08, 2009 Page 1 of 1 ~ MEMORANDUM To: Jim Regg ~ Q P.I.Supervisor ~~~Ct C~~V~o~~ ~ FROM: Jeff Jones Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, September 08, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC AGI-04 PRUDHOE BAY iJNIT AGt-04 Src: Inspector NON-CONFIDENTIAL Reviewed B /~ P.I. Suprv , fJf'~` Comm Well Name: PRUDxoE BaY t1t~r~T aGi-o4 API Well Number: 50-029-22323-00-00 Inspector Name: Jefflones Insp Num: miUJ090906174547 Permit Number: 192-146-0 ~ Inspection Date: g/21/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We]~ , AGI'0_~-Type Inj. G~ T~ ~9Z1 It1 2360 2200 ~ 2240 ~ 2280 2305 2340 '~ P.T.D 1921460 TypeTest SPT Test psi 1980.25 QA 490 495 520 540 565 ~ 585 Intervat a~TST p~F F ~ Tubing 3400 3390 3390 3380 3360 3360 NOteS' B~ed back 0.5 BBLS fluid & repeat MIT to offset thermal effect. .~[-t~ Df~~S'l.U~ '~t v~EPJ ~ ~T~~ ( ~ Z-~ ~ ~.T~~.IA~°` Z ~/}~~~c'`. C~~'ry~1 :.~ ~ ~1""t 4.. .~. L-~1~.~4 ': ~ .. . ~. .. ~v • ~ wwx»:~ ~ ~.. ... Tuesday, September 08, 2009 Page 1 of 1 ~ MEMORANDUM To: ,Tim Regg 1 ~~ ~(~ ~ ~ P.I. Supervisor ~ FROM: Jeff Jones Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, September 08, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC AGI-04 PRUDHOE BAY iJNIT AGI-04 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: PRUDHOE BAY C1NIT AGI-04 API Well Number: 50-029-22323-00-00 Inspector Name: JeffJones Insp Num: miUJ090906174122 Permit Number: 192-146-0 .- Inspection Date: g~21/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~l AGI-04 Type Inj. G ~'~ 7921 jA 590 2210 2240 2280 2320 2360 P.T.D 1921460 TypeTest SPT Test psi 1980.25 I QA 300 415 430 450 470 490 Intervat 4YRTST P~F F ~ Tllblllg I 3410 ~ ~ 3400 - 3400 --- 3400 3400 3400 Notes: 2•6 BBLS diesel pumped, well pressure didn't stabilize ~ ;~LT~"S~l'~ 1 (', ;~n ~ ' ~; ~ i~~ _i . ~ tjli:J . .. . ».5ka _ .~. Tuesday, September 08, 2009 Page 1 of 1 u MEMORANDUM To: Jim Regg ~~~dx~ ~~~ ~~`i P.I. Sapervisor ( FRO1~1: Chuck Scheve Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservxtion Commission DATE: Tuesday, September O1, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC AGI-04 PRUDHOE BAY UNIT AGI-04 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~~ Comm Well Name: PRUDHOE BAY IINIT AGI-04 Insp Num: mitCS090828151557 Rel Insp Num: API Well Number: 50-029-22323-00-00 Permit Number: 192-146-0 ~ Inspector Name: Chuck Scheve Inspection Date: 8~2g~2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~7~/e~l AGI-04 Type Inj. G 'r~ 7921 Ip 4S0 2200 ~ 2160 2160 ~ P.T.D 1921460 TypeTest SPT Test psi 1980 ~ QA 140 160 160 160 Interval 4YRTST P~ P / Tubing i 3380 3380 3360 3370 - Notes: ~ ~,~ ~... , ; r ~~~~s F.- vs~.~~ ~^. ;.d.M t~~ ~_.. .. .. . Tuesday, September O1, 2009 Page 1 of 1 From: Regg, James B (DOA) Sent: Monday, August 24, 2009 11:09 AM To: 'NSU, ADW Well Integrity Engineer'; Maunder, Thomas E(DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Sinyangwe, Nathan; Schwartz, Guy L(DOA) Cc: Quy, Tiffany; Holt, Ryan P(ASRC); Wellman, Taylor T Subject: RE: UNDER EVALUATION: NGI-12 (PTD# 1770810) MITIA Failed Taylor - As discussed this morning, Wells NGI-12 (PTD 1770810), NGI-03 (PTD 1750610), and AGI-04 {PTD 1921460) may remain on injection for diagnostics to evaluate suspected thermal effects as the cause of failed MIT due to repressuring in IA. Please contact this office if diagnostics/subsequent MIT are not completed this week. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 ¢.,~ g `~ '~ ~. ~~ ~7~~~~~~ i ~~~t;'U~~lw t-',41, t» f ~ V..: +,<''v ~ From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Monday, August 24, 2009 10:51 AM To: Regg, James B(DOA); Maunder, Thomas E(DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater)• PB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Su rvisor; Sinyangwe, Nathan; Schwartz, Guy L(DOA) Cc: Quy, Tiffany; Holt, Ryan P(ASRC); Wellman, Taylor T; NSU, ADW Well Integrity Engine Subject: UNDER EVALUATION: NGI-12 (PTD# 1770810) MITIA Failed All, Well NGI-12 (PTD #1770810) failed a witnessed MITIA on 08/23/09 whe e inner annulus pressure built up 120 psi in 30 minutes. The well has been reclassified as Under Evaluation nd may remain online for further evaluation work. The plan forward is as follows pending AOGCC a roval: 1. Well Integrity Coordinator: Gain approval from AOGCC re ator to continue injection for AOGCC MITIA 2. DHD: Monitor pressures, rate, temp every 12 hours for -3 days 3. Pumping: AOGCC MIT-IA to 2200 psi A TIO Plot, MITIA test form and wellbore schem~ti'c have been included for reference. «NGI-12 TIO Plot.doc» «MIT PBU NGI 2 08-23-09.x1s» «NGI-12.pdf» Please call with any questions or concer s. Thank you, Taylor Wellman filling in for na Dube/Andrea Hughes Office: 659-5102 8/24/2009 From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, August 24, 2009 6:07 AM To: Regg, James B(DOA); Maunder, Thomas E(DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Sinyangwe, Nathan; Schwartz, Guy L (DOA) Cc: Quy, Tiffany; Holt, Ryan P(ASRC); Wellman, Taylor T; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: AGI-04 (PTD# 1921460) MITIA Failed Attachments: AGI-04 TIO 12 mo Plot.doc; MIT PBU AGI 02, 03, 04, 06 08-22-09.x1s; AGI-04.pdf All, / Weil AGI-04 (PTD #1921460) failed a witnessed MITIA on 08/21/09 when the inner annulus pressure built u~70 psi in 30 minutes. The well has been reclassified as Under Evaluation and need~o ~e sFi-u -i~'n pe~ ~. The p a-l'n~orw~rd is as follows pending AOGCC approvaL 1. Weil Integrity Coordinator: Gain approval from AOGCC regulator to continue injection for AOGCC MITIA 2. DHD: Monitor pressures, rate, temp every 12 hours for 2-3 days 3. Pumping: AOGCC MIT-1A to 2200 psi A TIO Plot, MITIA test form and wellbore schematic have been included for reference. ~ ~ ~ «AGI-04 TIO 12 mo Plot.doc» «MIT PBU AGI 02, 03, 04, 06 08-22-09.x1s» «AGI-04.pdf» Please call with any questions or concerns. Thank you, Taylor Wellman filling in for Anna Dube/Andrea Hughes Office: 659-5102 Pager: 659-5100 x 1154 8/24/2009 PBU AGI-04 PTD 1921460 8/23/2009 TIO Plot: 12 months 4,~00 • 3,ODU 2,000 1,000 ~ T6g -/ IA ~ OA OOA -~ OOOA ~ On • 09/20I08 10/21/08 11/21/08 12/22/08 01I22/09 02122/0q D31251Dy 04125/09 05/26/09 06126IC19 07t27/09 . • STATE OFALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Sob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhoe Bay / PBU / AGI DATE: 08/20/09 OPERATOR REP: Torin Roschinger AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well AGI-02 Type In'. G ND 7,862' Tubing 3370 3360 3360 3360 Interval 4 P.T.D. 1921200 T e test P Test psi 1965.5 Casin 870 2210 2190 2190 P/F P Notes: MIT-IA for 4 year regulatory compliance OA 600 710 710 710 Weil AGI-03 Type I~j. G TVD 7,885' Tubin 3450 3460 3460 3440 Interval 4 P.T.D. 1921350 T pe test P Test si 1971.25 Casin 475 2200 2170 2180 P/F P Notes: OA 200 390 380 375 Well AGI-04 T e In'. G TVD 7,920' Tubing 3410 3400 3400 3400 Interval 4 P.T.D. 1921460 T e test P Test psi 1980 Casin 590 ~2210 2240 ~2250 P/F F Notes: OA 300 415 430 450 Well AGI-06 T e In'. G TVD 7,883' Tubin 3360 3360 3360 3360 Interval 4 P.T.D. 1930090 T e test P Test si 1970.75 Casin 360 2200 2170 2170 P/F P Notes: OA 390 550 550 550 Well Ty e Inj. TVD Tubin Interval P.T.D. Ty e test Test si Casin P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Mnulus Monitoring P = Standard Pressure Test R= Intemal Radioactive Tracer Survey A = Temperature Momaly Survey D = Differential Temperature Test ~ ~~~ ~ ~ a ., p-~ ~ ~ ~ ~r-- INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other(describein notes) MIT Report Form BFL 9/1/05 MIT PBU AGI 02, 03, 04, 06 OS-22-09.x1s TREE _ ? WELLHEAD = CIW ACTUATOR = ~~ BAKER C KB. EIEV = ~ ~ 50' BF. ELEV = KOP = 3951' Max Angle = 64 @ 10229' Datui Datu A~ I~~ ~ ALL TBG IS IPC WITH NSCC THREQD. . ~ MD = 12151' m ND = 8800' SS 13-3l8" CSG, 68#, K-55, ID = 12.415`' 122' 13-3i8" CSG, 68#, L-80, ID = 12.415" ~°~ 3538' Minimum ID = 4.455" @ 108Q4' 5-1/2" OTIS XN IdIPPLE ~ 7" TBG, 26#, NT-80-IPC, NSCC, .0383 bpf, ID = 6.276" ~-j 10760~ TOP OF 5-1/2" TBG (-j 10760' ~r,. ~~~ 2211 ~ ~-~ 7" CAMCO BAL-0 SSSV NIP, ID = 5.937" 10751' -~ARlCHOR, ID = 4.875" ~ 10752' 9-5/8" X 7" BAKER SB-3A PKR, !D = 4.874" 10760` 7-518'" X 5-1/2" XO, ID = 4.875" 10782~ (-~5-1/2" PARKER SWS NIP, ID = 4.562" 1080~~ 5-1/2" OTIS XN NIP, ID = 4.455" ~ 5-1l2" TBG, 17#, L-80-IPC, NSCC, .0232 bpf, ID = 4.892" 7" LNR TOP -~~$1 9-58" CSG, 47#, NT-80S, ID =$.681" ~-{ 10978~ I 10816' (1 PERFQRATION SUMMARY REF LOG: SWS,GR-CLL ON 05I07/93 ANGL.E ATTQP PERF: 51 @ 11115' Note: Refer ta Production DB for historical perf data SIZE SPF INlERVAL OpniSqz DATE 3-318" 6 11115 - 11135 O 5/22/93 3-3/8" 6 11230 - 11250 O 5/22f93 3-3/8" 6 11310 - 11320 O 5(22/93 3-3(8" 6 11390 - 11400 O 5/22/93 3-3/8" 6 11460 - 11480 O 5122l93 3-3!$" 6 11537 - 11557 O 5/22/93 ~aT~ 11635 7" LNR, 26#, NT-80, .0383 bpf, ID = 6.276" 11655~ 11 as~s, I-~5-1i2" WLEG ~ 10836` EtM TT LOG (05107i93) DATE REV BY GOMMEMS DATE REV BY COMMEMS 01/17/93 ORIGINA~ COMPLETION 05/24/01 RN/TP CORRECTIONS 03/13/03 ASiTP ADD IPC/THREAD FORTBG 0$/30/06 MSSiPAG CORRECTIdNS-TT, PBTD, LNR PRUDHaE BAY UNff WELL: AG{-04 f~EF2MfT No: ~1921460 API No: 5q-029-22323-00 SEC 36, T12N, R14E, 1329.62' FEL & 2942.63' FN~ BP 6cploratian (Alaska) AGI-04 (PTD #1921460) Reclas~d as Operable • Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com) Sent: Saturday, February 09, 2008 9:10 AM ~ ~~ 16~~~ O To: Regg, James B (DOA); Maunder, Thomas E (DOA) ~~ Cc: Engel, Harry R; Rossberg, R Steven; NSU, ADW Well Operations Supervisor; NSU, ADW WI Tech; NSU, ADW Well integrity Engineer Subject: AGI-04 (PTD #1921460) Reclassified as Operable Attachments: AGI-04 30-day TIO PIot.BMP Jim and Tom, The wellhead pressures of AGI-04 have been monitored since the bleed that Was reported on 01/20108. An evaluation of the pressure trend indicates that the OA pressure has remained stable and acted independently of the IA pressure. There ~ is no further action for this well at this time and it has been removed from the February Monthly Injection report. A 30-day TIO plot has been attached for your reference. «AGI-04 30-day TIO PIot.BMP» Please call with any questions or concerns. Thank you, Andrea Hughes ~'~.>~~~~~ DEB ~ ®2~~8 From: NSU, ADW Well Integrity Engineer Sent: Tuesday, January 22, 2008 8:23 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)' Cc: NSU, ADW Wetl Integrity Engineer; Engel, Harry R; Rossberg, R Steven; NSU, ADW Well Operations Supervisor; NSU, ADW WI Tech Subject: AGI-04 (PTD #1921460) Notice of potential OA repressurization Hi Jim and Tom, Well AGI-04 (PTD #1921460) has recently shown an increase in OA pressure. The operator bleed the OA pressure from 1000 psi to 500 psi on 01/20/08. During the previous 24 hours, the ambient temperature increased by 60 degrees. Consequently, it is suspected the increase in OA pressure is due to thermal effects. A TIO plot and wellbore schematic have been included for reference. « File: AGI-04 TIO PIot.BMP » The plan forward is to: 1. DHD: Leave well on injection and monitor the OA pressure 2. WIC: Review pressure data to determine if further action is needed. The well will be added to the January Monthly Injection Report until it has been decided no further action is needed. Please let us know if you have any questions. Thank you, .~nnrt ~itbe, rP: ell Integrity Coordinator GPB Wells Group Phone: (907) 653-5102 Pager: (3f?7) 659-51Q0 x1'154 2/11 /2008 a,aaa s,aoa l~2- t~~ ~~I-0:~ TIC F'I~t -#~ Tbg , -~- i~ z,aaa ' i~ ~n,as~ -~- ~a ~ ,aao 0 11T~2aa8 ~ ~ ~r aas ~ ~ ~rzaas ~ rz2r aas ~ r~~rzaas 2~1 r aos ~r~r~aas 2~1 zrzaas 2~1 ~r~oas ~r~~r~aos 2~712oas s~r~aos ~- oao~,~ AGI-04 (PTD #1921460) Notice~otential OA repressurization Page 1 of 1 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~ 0~ Sent: Tuesday, January 22, 2008 8:23 PM ~~7Q~~ I~ To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSU, ADW Well Integrity Engineer; Engel, Harry R; Rossberg, R Steven; NSU, ADW Well Operations Supervisor; NSU, ADW WI Tech Subject: AGI-04 (PTD #1921460) Notice of potential OA repressurization Attachments: AGI-04 TIO PIot.BMP; AGI-04.pdf Hi Jim and Tom, Well AGI-04 (PTD #1921460) has recently shown an increase in OA~ pressure. The operator bleed the OA pressure from 1000 psi to 500 psi on 01/20/08. During the previous 24 hours, the ambient temperature increased by 60 degrees. _--- Consequently, it is suspected the increase in OA pressure is due to thermal effects. A TIO plot and wellbore schematic have been included for reference. «AGI-04 TIO PIot.BMP» «AGI-04.pdf» The plan forward is to: 1. DHD: Leave well on injection and monitor the OA pressure 2. WIC: Review pressure data to determine if further action is needed. The well will be added to the January Monthly Injection Report until it has been decided no further action is needed. Please let us know if you have any questions. Thank you, ,fin ~u e, ~'. E. ell Integrity Coordinator PB, ails Group Phone: (9Ct7) 659-51p2 Pager: {907) 659-5100 x1154 ~'~t~~ JAN ~ ~ 200 1/23/2008 4,aaa a,aaa 2,aaa ~ ~.4~SP 1,aao ~~,^. rn~.~.~~ a -- - -~ .~ - -~-_ . 1 a~12l2aaa 11 A5x2a0~ 11 X21 rzaa~ 1 ~ftx2aa7 12~212a07 1,~rzaaa 1 ~;vt g-~-c~4 p; tj l`~2- (4`1 z~sr~aas -~ Tbg • -# IA ~- OA oo~. aoc,~ ~~~ AGI-04 Tll~ Plot TREE _ ? WELLHEAD = CIW ACTUATOR KB. ELEV - ... BF r-~E4' _ KC-'~ -~'~- '. ~ ~RKER C 5(7` _ _ _. ' 3951` Max Angle = 64 @ 10229' Data Datu AGI-04 rn Mlj = 12151' m TVD = 8800' SS 13-3t8" CSG, 68#, K-55, ID = 12.415" 122` 13-3/8" CSG: 68#, L-80, ID = 12.415" ~--{ 353$' ~,ggirynl~^pII~~ y- ®5yy5~'y°y 1 4' III Lr~ 1 6o',i A !!'t"`E ~""~ ,~ SAFETY NOTES: LNft NOT CEMENTED. ALL TSG IS 1PC WEThI NSCC TRE,4D. ~ 7" CAI4hC0 BAL-O SSSV NIP, ID = 5.937°` j 107 51 ` ~ A NCHC3R: ID = 4.875 10752" 9-5l8" X 7" BAKER SB-3A PKR, ID = 4.874" 10760` 7-518° x 5-1iz° XO; ID = 4.875' ~ 7" TBG, 26#, NT-BQ-IPC; NSCC, .0383 bpf, ID = 6.276" I-{ 10760' TOP OF 5-1,'2" TBG N 10760' 10782' --~ ;i-112° PARKER S}aVS IVIP, !D = 4.562" 10$04" 5-1/2" OTIS XN NIP, ID = 4.455" ~5-1l2" TBG, 17#, L-80-IPC, NSCC, .0232 l~pf; ID = 4.892" I 10$16" ~" LNR TOP 10816' 9-518" CSG, 47#, NT-8Els. ID = 8.681" H 10978' 10816' S-1?2" WLEG 10836' ---ELIV rF Loo (o5ro7t93) PBTD - 1~ '1635, 7" LNR, 26#, NT-8©, .0383 bpi, ID = 6.276" 11655' DATE REV BY COM~?ENTS E11t17I93 Ol24GlNAL COEYtPLET4C3N 05!24101 RNfTP CORRECTIONS - 03/13103 AS;'TP ADD IPCfTHREAD FOR TBG 08130106 RISSIPAG CORRECTIONS-T7, PBTD, LNR BY PERFORATION SUMIvtARY REF LO{~: SVvS,GR-CLL ON 05,'07!93 ANGLE AT TOP PERF: 51U 11115` Notie: Refer to Procl~action DB ft~r hisktisical perf daka SI7~ SPF INTERVAL OpniSgr DALE 3-318" 6 11115 - 11135 O 5?22193 3-3(8" 6 11230 - 11250 O 5`22,r93 3-3r'8" 6 11310 - 11320 O 5%22193 3-3r 8' 6 11390 - 11400 O 5!22,''93 3-3/8" 6 1146U - 11480 O 5x22193 3-318' 6 11537 -11557 O 5122!93 PRUDHOEBAY UNIT 'HELL: AGl-04 PEF2Mf( Nc~: X1921460 API No: 50-029-22323-00 SEC 36: T12N, R14E, 1329.62' FEL & 2942.u3' FNL SP Exploration (Alaska) MEMORANDUM ) State of Alask~ ) Alaska Oil and Gas Conservation Commission TO: Jim Regg 0/ I I P.I. Supervisor \Qrl q 13 D<;" DATE: Tuesday, August 30, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC AGI-04 PRUDHOE BAY UNIT AGI-04 ~\LtP \<'\ FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv -SB¡L Comm Well Name: PRUDHOE BAY UNIT AGI-04 Insp N urn: mitJCr050825131120 Rei Insp Num NON-CONFIDENTIAL API Well Number 50-029-22323-00-00 Permit Number: 192-146-0 Inspector Name: John Crisp Inspection Date: 8/23/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. --.-. ,_..__._m__._.~__.~.__ '...-....-.."[.....-.. I ..--.---,..-.....--.,.. l ...----¡..........--.-.~-..---...-- Well' AGI-04 .¡IType Inj. i G ! T:yD ..___j___~__ I IA__~_.. I 21~_~..._-L_!~_. 2170.J__..____11____...__ P.T. 1921460 ,TypeTest, SPT I Test psi ! ]980.25 I OA I 175 ! 300 I 300 ' 300 I ' fu;~;~~-;~~----p~--;---· '''-''~-~'bing I 3S0Ü-r3SÕÜ+"-- 350Ö'--'l-3-S'ool' ..----1-.--.-- ..._._.___......__._._...__.. ....._.__..... .__..._____....__.______~._...._~._. ...~._.___-L.__.......__ Notes 4 bbls pumped for test :SC/~j\~N~::~ \/ SEP? 200:-i Tuesday, August 30, 2005 Page 1 of 1 MEMORANDbM State of Alaska Alaska Oil and Gas Conservation Commission .¥ TO: Julie Heusser ~q~O\ DATE: May 27, 2001 Commissioner . SUBJECT: Mechanical Integrity Tests THRu· TomMaunder ~-,,~ .,~ BPX P.I. Supervisor~--~ AGI Pad (~ [%..-O \ AGI-01, 02, 03, 04, 05 FROM: Jeff Jones '~ PBU Petroleum Inspector PBF NON- CONFIDENTIAL WellI AGI-01 P.T.D.J 192-124 Notes: ... WellI P.T.D.I Notes: WellI P.T.D.I Notes: , WellI P.T.D.I Notes: . WellI AGI-05 . P.T.D.I 193-002 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. I Typelnj. I G I T.V.D. I 7910 I Tubingl 3500 I 3500 I 3500 I 3500 I lntervall 4 Type testI P I TestpsiI 1978 I Casingl 45o I 21001 2°9°l 2°8°l P/F J P 192-120 ITyPetestl P ITestpsiI 1965.lCasingI 325 I 21001 21001 21001 p/F I P 192-135 ITypetestl P ITestpsiI 1968 ICasingI 600 I 21201 21101 21101 P/F I P AG,.04 I Type,nj.I G I T.V.D. I 7s9s"lTuuingl 3500 13500 13500 13500 I lntervall 4 192-146 ITypetestI P ITestpsil 1975 ICasingI 360 I 21801 22°01 22001 p/F I P Type testI P I TestpsiI 1936,1 Casing l 600 I 2100 I 2100 I 2100 I' P/FIB 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 MITs 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 MITs. The test data above indicates these wells are suitable for continued injection. Summa~: I witnessed five successful MITs 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 ~ BEEN 01'4 OR BEFORE ,cEMBER 01 2000 W PERMIT DATA 92-146 5865 92-146 SURVEY 92-146 SURVE¥~ 92-146 DPR/GR 92-146 DPR/GR 92-146 GR/CCL 92-146 PERF ~ 92-146 SBL/GR/CCL AOGCC Individual Well Geological Materials Inventory T DATA_PLUS T OH-MWD, 8742-11655 R MWD~ DIRECTIONAL R MWD DIRECTIONAL ~ MWD RUNS 4-7,2&5"MD ~ MWD RUNS 4-7,2&5"TVD ~"~ RUN 1, 5" ~--~"5,, RUN I Page: 1 Date: 04/11/95 RUN DATE_RECVD 10/29/1993 08/31/1993 09/13/1993 06/28/1993 06/28/1993 06/28/1993 07/30/1993 03/26/1993 Are dry ditch samples required? Was the well cored? yes ~___~.nalysis & descrip~9~~ved? Are well tests required, ii.yes ~ Received? ~no Well is in compliance , ~ Initial COMMENTS yes ~__~nd receive~ yes no yes no ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-22-93 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS 4-17-93 0~ 10-7-93 oa 3-31-93 11/18-30/92 11-23-92 4-15-93 1-29-93 2-13-93 4-28-93 3-6-93 5-8-93 3-28-93 MWD: DPR/GR nLLIAClCNIGR MWD: DPR/GR MWD '77~S-t MWD: DPR/GR MWD: DPR/GR MWD: DPR/GR MWD: DPR/GR MWD: DPR/GR. MWD: DPR/GR MWD: DPR/GR MWD: DPR/GR Job#1209 Job#6055 Job# 1202 Job#AKMM921128 Job# 1152 Job# 1168-450 Job# 1172-450 Job#1181 Job# 1185-450 Job#1190 Job#II95-450 Job# 1205-450 Sperry BHI %~\- toLTo Please sign and return the attached copy as receipt of data. /'~ RECEIVED BY__~~ Have A Nice Day! ~ek00i/ ? ~ ,~oa$ Coo. sonTawaUace aPPS:OVEI) ff.,'i,U ATO-1529 Trans# 9312~~-' # PHILLIPS # (OH/ Cr) # EXXON # BPX # STATE OF A~.&Si~ The correct APl# for 3-18A is 50-029-20421-01. The correct APl# for 9-28A is 50-029-21292-01. The correct API# for AGI-1 is 50-029-22307-00. ARCO ,P. IAska_; hie. P.O.Box 100360 Anchorage, J,1As_lrA_ 99510 DATE: 9-10-93 REFERENCE: ARCO D~ONAL DATA c{~o ~L 3-18A 4-24-93 Electronic Multi-Shot Survey Job~~ Sperry q~-4'I 3-20A 4-14-93 Electronic Multi-Shot Survey Job~3/X~2 Sperry ~-a~ 5-3A 5-26-93 MWD Directional Survey Aha c{%~2- 5-14A 6-26-93 MWD ~ Survey Aha ~%-~' 5-llIA 6-26-93 ~ Directional 8~vey Jma c~-5"7 6-22A 4-30-93 MWD DirectionM Survey Ana ~-q0 18-29A 4-26-93 MWD Directional Survey Aha q2-- ['~$ AGI-3 4-14-93 MWD Directional Survey Job~1163 BHI q~.- lt/~o AGI-4 4-14-93 MWD Directional Survey Job~1168 BHI q~-27 AGI-7 4-28-93 MWD Direc~ional Survey Job~ 1185 Telm~ /AGI-9 3-17-93 MWD Directional Survey Job#1195-450 BHI c~ ~5 <,,,AGX-9 ~ MWD Directional Survey dob~X x~ Bm Please sign and return the attached copy as receipt of dam. RECEIVED BY___~.~.~.~-~ ..... Have A Nice Day! Sonya Wallace APPROVED~. ATO- 1529 Trans# 93102 CENTRAL FIIF~ CHEVRON D&M # CLINT CHAPMAN # EXXON MARATHON MOBIL # PB WELL FILES R&D #BPX # ST. OF AIL (2 COPIES) # LUCILLE JOHNSTON ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-10-93 REFERENCE: ARCO DIRECTIONAL DATA /~21-24A 12-20-92 MWD Directional Survey Aha ._/3-15A 2-25-93 MWD Directional Survey Aha q~~3-15A 2-27-93 Electronic Multi-Shot Survey Job#AKEI30010 Sperry c}~ql--3-18A 4-19-93 MWD Directional Survey Job#1209 BHI c~b-q-~--3-20A 4-9-93 MWD Directional Survey Aha /3-25A 3-19-93 MWD Directional Survey Ana %3-25A 3-23-93 Electronic Multi-Shot Survey Job#AKEI30016 Sperry q~-Ici--3-36 4-18-93 MWD Directional Survey Job#AKMW30020 Sperry ~/~.~'4A 2-23-93 MWD Directional Survey Job# 1188 Teleco ~ 2-26-93 Electronic Multi-Shot Survey Job#AKEI30009 Sperry q~Z(o~9-SA 3-7-93 MWD Directional Survey Job#1192 Teleco ~ 3-13-93 Electronic Multi-Shot Survey Job#AKEI30012 Sperry ~9-28A 4-6-93 MWD Directional Survey Job#1202 BHI q~'-c~$-9-31A 4-15-93 MWD Directional Survey Ana cff¥-'~--9-35A 3-7-93 MWD Directional Survey Ana ~-~--9-36A 4-1-93 MWD Directional Survey Ana c~2~.~-9-49 12/6-23/92 MWD Directional Survey Job# 1159 Teleco ,,-~a~-50 1/23-2/6/93 MWD Directional Survey Job#1175 Teleco ol~_tq:i-v-o.t 12/30-1/15/93 MWD Directional Survey Job#1167 Teleco t'b~--15-23 12-9-91 MWD Directional Survey Job#AKMM911128 Sperry qt_1~3--15-26 1-15-92 MWD Directional Survey Job#AKMM911231 Sperry 15-27 1/92 MWD Directional Survey Sperry 16-4A 2-9-93 MWD Directional Survey Ana ~_ttt~.~18-27 1-16-93 MWD Directional Survey Job#AKMW30003 Sperry t-5~18-29 12-27-92 MWD Directional Survey Job#AKMM921231 Sperry ~~--AGI-4 1-18-93 MWD Directional Survey Job#1168 Teleco ~GI-5 1-17-93 MWD Directional Survey Job#1172 Teleco c~ ~-~~.-~/~GI:~ 2-16-93 MWD Directional Survey Teleco 2-24-93 MWD Directional Survey Job#II85-450 Teleco /~r-~7~GI-7 4-28-93 MWD Directional Survey Job#1185 Teleco ~-.---AGI-8 3-7-93 MWD Directional Survey Job#1190 Teleco .~AGI-9 3-17-93 MWD Directional Survey Job#II95-450 Teleco ~/AGI-10 3-30-93 MWD Directional Survey Job#1205 BHI Please sign and return the attached copy as receipt of data. ve ce Day. ~e~- ~ J / Sonya Wallace APPROVED ~ ~o~. /$~ ATO- 1529 Trans# 9305~------'~'~'~r' ~.~.~i C~~ON ~ PB ~L F~ES ~ CLOT C~~ ~ BPX ~ E~ON ~ ST. OF ~. {2 COP~} MOB~ ~ LUC~LE JO~STON ,~ iT' STATE OF ALASKA ~-~'~ ALASK,~ OIL AND GAS CONSERVATION COiViMISSION WELL COMPLETION OR R£COMP LI=TION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE E:l(x A~3e)~ ~a~ Iniector 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 92-146 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22323 !4. Location of well at surface~~ 9. Unit or Lease Name 1937' NSL, 2453' WEL, SEC. 36, T12N, R14E , .:.", f~' l ~.~,~/~~ [ Prudhoe Bay Unit At Top Producing Interval ~~i.1- i1°: Well Number 2304' NSL, 3031' EWL, SEC. 31, T12N, R15E .... ~; ,rf.~,~;;;I AGI-4 At Total Depth '~j~¢ ~,.; !~,j 11. Fioldand Pool . ' Prudhoe Bay Field/Prudhoe Bay Pool 2338' NSL, 3541' EWL, SEC. 31, T12N, R15E 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 49' I ADL 34628 12. Date Spudded 13, Date T.D. Reached 14. Date Comp., Susp. or Aband. J15. Water Depth, if offshore 116. No. of Completions I 1/2/93 4/14/93 5/31/93 N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVDi 19. Directional Survey 12.0. Depth where SSSV set 121. Thickness of Permafrost / 11655'MD/8490'TVD 11655Y8490'TVD YES [] N~ [] 2211' feet MD I 1900'(Approx.) 22. Type Electric or Other Logs Run MWD, Gyro 23. CASING, LINER AND CEMENTING RECORD SE'FI'lNG 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# K-55/L-80 ,.~7; 3538' 16" 2170 cu fl PF/464 cu fl "G" 9-5/8" 47# NTS-80 35' 10976' 12-1/4" 460 cu ft Class "G" 7" 29# L-80 10799' 11655' 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 (MD) PACKER SET (MD) Gun DiameterMD 3-3/8" 6~/fD 7"x 5-1/2" 10816' 10752' 11115'-11135' 8146'-8159' NT-80/L-80 11230'- 11250' 8216'-8229' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11310'-11320' 8265'-8271' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11390'-11400' 8314'-8320' 11460'-11480' 8356'-8369' 11537'-11557' 8403'-8416' 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etC.) 5/31/93 I Gas Injection Date of Test Hours Tested PRODUCTION FOR C)IL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED !OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dipsl and presence of oil, gas or water. Submit core chips. RECEIVED AU G 1 1993 Alaska 0il & Gas Cons. CommiSS[0~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE Top Sadlerochi! Base Sadlerochit 10990' 11598' 8070' 8441' ,..&nt,~AT~'~ TesTS ~ 30. interVal tested, pressure data, all fluids recovered and g~avit¥, include ~ o~,,, ct each phase. GOR, and t, .... R[ iVED AU G 1 Alaska 0il & Gas Cons, knowledge ~oregoing is , .... Title ~ Date signed iNS-fRUO'fIoNS a complete sad correct wel~ completion report and ~og on Irfor iniection, salt Gener': 'fh,s ,cfm is des,gned submitting ;t;'tum~°n~s°~'°~' __.. ads and leases tn Naska. ' ction, water in[ecti°n'I all typuo o! la .... Wells: Gas Iaie --*;on iaiecti°n for ' . _,:..~, nf 5ervt~ .... ;,,n obserw" ' depth measurements item 1:. u~ ~ter supPlY ~u , (,where not othe~ise shown) w~ter ~ispo~,, -' . chmenm, inteW~l (multiple elevation is used ~s felerence indicate which .._ ,~.~ ~nd [n ~ny ~tt~ ..~ more th~n oge .~ ~ntervSI reported item 5;._ ~ces on mis ,~ .... _ .... ~te oroducti°n."u';'-m~ls for only t,~ '~hnwing the n'ven ,' other sp -~,~ed tot ~up~,- . ;~ nroduCtng ~"' ~.~ v ptoduceu, ~ .... ,~ ,~,eil is comP,~[ :..~ 24 show i,d. ~ .~, m be sep~'~'~[' - . ~ -n~ 24: I1 m,o ;~ 16, ~nd m ,,~".'_ .~dition~l intew~, - tte~ ~o ~ . _~ state in itu,,, ,-.~ for e~cn ~ ~ ~_ o7 Suo~'"' ~ --' (DF KB, etc.). in item ~ · intewal- cement- data pertinent to such imm 21' indicate whether ~rom ground tevet {GL) or other elevation ' item 23; Attached supplemental records for this welt should show the details of any multiple stage water ing and the location of the cementing tool. GaS Li~t, Rod pump, Hydrau[ic pump, s~bmersible, Other-exPlain' imm 27: MethOd o[ operation: Ftowing, ~ection, Gas in~ection, Shut-in, item 2B: I~ no cores taken, indicate ,none". Form 10-407 BP/AAI SHARED SERVICE WELL: AGI-4 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: DAILY OPERATIONS PAGE: 1 ACCEPT: 04/12/93 09:00~ SPUD: RELEASE: OPERATION: DRLG RIG: AUDI 2 WO/C RIG: AUDI 2 01/02/93 (1) TD: 106' ( 0) MOVE RIG MOVE RIG. MW: 8.5 VIS: 0 01/03/93 (2) TD: 1309' (1203) 01/04/93 ( 3) TD: 3545' (2236) 01/05/93 ( .4)' TD: 3545' ( ..0) 01/06/93 (5) TD: 4363' ( 818) 01/07/93 (6) TD: 6040' (1677) 01/08/93 (7) TD: 6657' ( 617) 01/09/93 (8) TD: 7423' ( 766) 01/10/93 (9) TD: 8020' ( 597) DRLG. MW: 8.9 VIS:160 MOVE RIG. RIG ACCEPTED @ 07:00 HRS, 1/2/93. R/U DIVERTER. M/U BHA. SPUD WELL @ 15:45 HRS, 1/2/93. DRLG FR/ 106'-1306'. SHORT TRIP. MW: 9.3 VIS:126 DRLG F/ 1309'-1997' CIRC. SHORT TRIP. DRLG F/ 1997'-3545'. CIRC. SHORT TRIP. REPLACE BRAKE BANDS. MW: 9.2 VIS: 55 SHORT TRIP. CIRC. POOH. 'L/D BHA. R/U WOTCO. RIH W/ 13-3/8"'CSG. LAND @ 3538' CIRC. R/D WOTCO. R/U HOWCO. PUMP 20 BBLS WATER, 386 BBLS LEAD CMT, 83 BBLS TAIL CMT. DISP W/ MUD. BUMP PLUG. R/D HOWCO. N/D DIVERTER. PUMP 15 BBLS (93 SX) TOP JOB CMT. N/U BOPEo REPLACE BRAKE BANDS ON DRAWWORKS. DRLG. MW: 8.8 VIS: 37 REPLACE BRAKE BANDS. TEST BOPE. RIH W/ BHA. TAG FC @ 3456'. CIRC. TEST CSG. OK. DRLG FC, CMT, FS, 10' NEW HOLE. CIRC. FIT (12 PPG EMW). DRLG TO 4363'. DRLG. MW: 9.2 VIS: 41 DRLG TO 4552'. CIRC. SHORT TRIP TO SHOE. DRLG TO 5489'. CIRC. 10 STDS SHORT TRIP. DRLG TO 6040' RIH. MW: 9.3 VIS: 49 DRLG TO 6339' CBU. POOH. CHANGE BHA. RIH. WASH THRU TIGHT SPOTS & BRIDGE @ 3636'. REAM 72' TO BTM. DRLG TO 6657'. POOH. CHANGE MTR. RIH. DRLG. MW: 9.3 VIS: 40 RIH. DRLG F/ 6657'-7177' CBUo POOH. CHANGE MWD. RIH. DRLG TO 7423'. DRLG. DRLG F/ 7437'-8020'. MW: 9.4 VIS: 40 A U 6 2 6 199 x A;aska Oil & Gas Cons. Anchorage WELL : AGI-4 OPERATION: RIG : AUDI 2 PAGE: 2 01/11/93 (10) TD: 8650' ( 630) DRLG. DRLG TO 8650'. MW: 9.4 VIS: 43 01/12/93 (11) TD: 9208' ( 558) 01/13/93 (12) TD:10020' ( 812) DRLG. MW: 9.5 VIS: 41 DRLG TO 8802'. POOH. TEST BOPE. CHANGE BHA. RIH. DRLG TO 9208'. DRLG. DRLG TO 10020'. MW: 9.6 VIS: 43 01/14/93 (13) TD:10282' ( 262) 01/15/93 (14) TD:10985' ( 703) 01/16/93 (15) TD:10985' ( 0) 01/17/93 (16) TD:10985' ( 0) 01/18/93 (17) TD:10985' ( 0) 04/13/93 (18) TD:10985' ( 0) 04/14/93 (19) TD:l1360' ( 375) 04/15/93 (20) TD:11655' ( 295) DRLG. MW: 9.6 VIS: 43 DRLG TO 10282'. POOH WET. FOUND WASHOUT @ 40 STDS. POOH. CHANGE BHA. RIH. TIGHT SPOT 15 STDS OUT (8800'). WORK THRU TIGHT SPOT. RIH. REAM TO BTM. DRLG. POOH. MW: 9.9 VIS: 50 DRLG TO 10985'. CIRC. SHORT TRIP TO 8431' CIRC. SHORT TRIP TO 9022' CBU. POOH. CMT 9-5/8" CSG. MW: 9.9 VIS: 54 POOH. L/D BHA. RIH W/ 9-5/8" CSG. HOLE STICKY @ 10350'. WORK CSG TO BTM. R/U HOWCO. CIRC. CMT CSG. N/U TREE. MW: 9.9 VIS: 0 CMT CSG. POOH 10 STDS. REV CIRC. POOH. L/D DP. RIH W/ BHA. TAG LC. CIRC. POOH. RELEASE RIG. MW: 8.5 VIS: 0 R/U TOP DRIVE. POOH. F/P TOP 2000' W/ DIESEL. POOH. N/D BOPE. N/U TREE. TEST TREE. SECURE WELL. RIG RELEASED @ 18:00 HRS, 1/17/93. DISP WELL TO FLO-PRO. MW: 9.2 VIS: 55 MOVE RIG. RIG ACCEPTED @ 09:00 HRS, 4/12/93. N/D TREE. N/U BOPE. TEST BOPE. M/U & RIH TO 2000' DISP OUT DIESEL. RIH. TAG FC. TEST CSG. OK. DRLG FC, CMT, FS. CBU. DISP WELL TO FLO PRO. DRLG. MW: 9.3 VIS: 62 FIT (12.9 PPG EMW). DRLG F/ 10985'-11289'. POOH. CHANGE BIT. RIH. DRLG TO 11360'. RIH W/ LNR. MW: 9.4 VIS: 64 DRIL TO 11655'~ TD WELL @ 18:45 HRS, 4/14/93. CIRC. SHORT TRIP TO SHOE. RELOG F/ 11415'-11520'% CBU. POOH. RIH W/ 7" LNR ON DP. RECEIVED AU G 2 6 t99 Alaska Oil & Gas Cons. Anchorage WELL : AGI-4 OPERATION: RIG : AUDI 2 PAGE: 3 04/16/93 (21) TD:11655 PB:11655 04/17/93 (22) TD:11655 PB:11655 CUT DRLG LINE. MW: 9.3 NaC1 RIH W/ LNR ON DP. TAG BTM CIRC. PUMP 100 BBLS XANVIS, 200 BBLS SEAWATER, 45 BBLS BRINE, 16 BBLS LITH HYPOCHLORIDE. BUMP PLUG. SET HGR W/ 3000 PSI. SET PKR W/ 4000 PSI. ATTEMPT TO TEST BACKSIDE TO 4000 PSI. ONLY 3500 PSI. UNABLE TO TEST DP. RELEASE RUNNING TOOL. DISP WELL W/ BRINE. CIRC. POOH. RIG RELEASED. MW: 9.3 NaC1 RIH W/ 7" TBG. SPACE OUT TBG. M/U HGR. LAND TBG. TEST TBG. OK. TEST ANNULUS. OK. N/D BOPE. N/U TREE. TEST TREE. RIG RELEASED @ 03:00 H RS, 4/17/93. SIGNATURE: (drilling superintendent) DATE: AUG 2 993 Alaska Oil & AnchoraQe BP/AAI SHARED SERVICE WELL: AGI-4 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: DAILY OPERATIONS PAGE: 1 ACCEPT: 01/02/92 07:00 SPUD: 01/02/93 03:45 RELEASE: 01/17/93 06:00 OPERATION: DRLG RIG: AUDI 2 WO/C RIG: 01/02/93 ( 1) TD: 106' ( 106) MOVE RIG MOVE RIG. MW: 8.5 VIS: 0 01/03/93 (2) TD: 1309'(1203) 01/04/93 ( 3) TD: 3545'(2236) 01/05/93 (4) TD: 3545' ( 0) 01/06/93 (5) TD: 4363' ( 818) 01/07/93 ( 6) TD: 6040'(1677) 01/08/93 ( 7) TD: 6657' ( 617) 01/09/93 (8) TD: 7423' ( 766) 01/10/93 (9) TD: 8020' ( 597) DRLG. MW: 8.9 VIS:160 MOVE RIG. RIG ACCEPTED @ 07:00 HRS, 1/2/93. R/U DIVERTER. M/U BHA. SPUD WELL @ 15:45 HRS, 1/2/93. DRLG FR/ 106'-1306'. SHORT TRIP. MW: 9.3 VIS:126 DRLG F/ 1309'-1997'. CIRC. SHORT TRIP. DRLG F/ 1997'-3545'. CIRC. SHORT TRIP. REPLACE BRAKE BANDS. MW: 9.2 VIS: 55 SHORT TRIP. CIRC. POOH. L/D BHA. R/U WOTCO. RIH W/ 13-3/8" CSG. LAND @ 3538' CIRC. R/D WOTCO. R/U HOWCO. PUMP 20 BBLS WATER, 386 BBLS LEAD CMT, 83 BBLS TAIL CMT. DISP W/ MUD. BUMP PLUG. R/D HOWCO. N/D DIVERTER. PUMP 15 BBLS (93 SX) TOP JOB CMT. N/U BOPE. REPLACE BRAKE BANDS ON DRAWWORKS. DRLG. MW: 8.8 VIS: 37 REPLACE BRAKE BANDS. TEST BOPE. RIH W/ BHA. TAG FC @ 3456'. CIRC. TEST CSG. OK. DRLG FC, CMT, FS, 10' NEW HOLE. CIRC. FIT (12 PPG EMW). DRLG TO 4363' DRLG. MW: 9.2 VIS: 41 DRLG TO 4552' CIRC. SHORT TRIP TO SHOE. DRLG TO 5489'. CIRC. 10 STDS SHORT TRIP. DRLG TO 6040'. RIH. MW: 9.3 VIS: 49 DRLG TO 6339' CBU. POOH. CHANGE BHA. RIH. WASH THRU TIGHT SPOTS & BRIDGE @ 3636'_ REAM 72' TO BTM. DRLG TO 6657' POOH. CHANGE MTR. RIH. DRLG. MW: 9.3 VIS: 40 RIH. DRLG F/ 6657'-7177'. CBU. POOH. CHANGE MWD. RIH. DRLG TO 7423' DRLG. DRLG F/ 7437'-8020' MW: 9.4 VIS: 40 WELL : AGI-4 OPERATION: RIG ' : AUDI 2 PAGE: 2 01/11/93 (10) TD: 8650' ( 630) DRLG. DRLG TO 8650' MW: 9.4 VIS: 43 01/12/93 (11) TD: 9208' ( 558) 01/13/93 (12) TD:10020' ( 812) DRLG. MW: 9.5 VIS: 41 DRLG TO 8802'. POOH. TEST BOPE. CHANGE BHA. RIH. DRLG TO 9208'. DRLG. DRLG TO 10020'. MW: 9.6 VIS: 43 01/14/93 (13) TD:10282' ( 262) 01/15/93 (14) TD:10985' ( 703) 01/16/93 (15) TD:10985' ( 0) 01/17/93 (16) TD:10985' ( 0) 01/18/93 (17) TD:10985' ( 0) DRLG. MW: 9.6 VIS: 43 DRLG TO 10282' POOH WET. FOUND WASHOUT @ 40 STDS. POOH. CHANGE BHA. RIH. TIGHT SPOT 15 STDS OUT (8800'). WORK THRU TIGHT SPOT. RIH. REAM TO BTM. DRLG. POOH. MW: 9.9 VIS: 50 DRLG TO 10985'. CIRC. SHORT TRIP TO 8431'. CIRC. SHORT TRIP TO 9022'. CBU. POOH. CMT 9-5/8" CSG. MW: 9.9 VIS: 54 POOH. L/D BHA. RIH W/ 9-5/8" CSG. HOLE STICKY @ 10350'. WORK CSG TO BTM. R/U HOWCO. CIRC. CMT CSG. N/U TREE. MW: 9.9 VIS: 0 CMT CSG. POOH 10 STDS. REV CIRC. POOH. L/D DP. RIH W/ BHA. TAG LC. CIRC. POOH. RELEASE RIG. MW: 8.5 VIS: 0 R/U TOP DRIVE. POOH. F/P TOP 2000' W/ DIESEL. POOH. N/D BOPE. N/U TREE. TEST TREE. SECURE WELL. RIG RELEASED @ 18:00 HRS, 1/17/93. SIGNATURE: (drilling superintendent) DATE: Prudh0e Bay Drilling. Rpt' AFE. No: 4J0195 i No: Well: AGI-4 Contractor: Audi 2 Operation at 0600: I Depth (MD/TVD): / I Prev (MD): Phone: 4605 i Daily Costs: $28,774.00 i ILast Csg: 20"@ 115' RIG OVER HOLE. I(size/deplh) 1/2/93 @ 0700 HRS i Rig Release( hr/date): I Bit ~ata ' Rig Accept (hr/date): Mud Mud Type Weight Viscosity sec PV/YP / Gels / APl W.L. HTHP 100 psi HTHP Sand Hole Vol. )ata MBT pH Pm Pf Mf Chlorides Oil ES % LGS % Pit Vol. bbl Filter IOT~lcium Cake Daily Mud $ tal Mud $ BHA Description: Bit No. Size Make Type Serial No. Depth Out ppm MD,ri-VD Footage % ART/AST RPM Table/Mtr WOB Min/Max. Jets/TFA ppmlBit Costs I Dull IGrade / rpn / !~ Daily Drilling Report 0 ISupv. Init: i I Progress: Il:st Cum Costs: $28,774.00 INext Csg: 133/8" IShoe N/A (size) ITest: / / ft ft. / / / rprr / rprr / K~ / K~ i ti '[~rittin¢ IDepth AYe. I Drag Trq l~tm PL Pump No. ~ Liner Size SPM ! . GPM Pressure Data ...... Rot Wt. S.C. Wt. Max Drag Trq Off mD Data '1 2 5.5" ' . ,5.5",;,i Slow Pump Data ,, I I I I slow P.P. BHA No: BHA Length: Source: Volume: Type Fluid: IDate Last Inspected: Iniection Data Injection Well: Daily Volume: Freeze Protect Fluid: IH0urs On Jars: JRate: IPressu re: ¢,Pml i Cumulative bbl Volume: Volume: gal. psi Fuel Used: Daily: Fuel & Water Data I Fuel I Fuel gal[Source: BP/KUP IRecv'd: Guttinqs Data c gite: Accident? (Y/N): N JName: Contractor: ILast BOP Drill: Spill (Y/N)? PB Drlg: Last BOPE Test: Last Spill Drill: 0600-0700 OTHR I Drl. Water I Drl. Water gal Used: BBLI Source: oF Personnel & Safety/BOP Data I Empioyer: I Service: I Other: Total: I Last H2S Drill: ILast Fire Drill: Last Safety Mtg: · Volume (Gals.): Fype Spill: Report Filed? Operations From 0600 to 0600 RIG WAS OVER THE HOLE @ 0600 HRS. MISC WORK UNTIL 0700 HRS. Weather Data lWind Speed: mphl Chill Factor: VERN Rpt Filed? (Y/N): ACCEPTED RIG @ 0700 HRS. °F Prudhoe Bay Drilling, i Dail,! Drilling Report Well': AGI-4 !Depth (MD/TVD): 1309 / 1309 ]Prey (MD): 106 IPr°gress: 1203 I ,,, COntractor: Audi2 Phone: 4605 !Daily c°sts: $73,854.00 IEst cum c°sts: $105,741.00 ILast Csg: 2o"@ 115' INext Csg: 133/8" ISh~)e N/A Operation at 0600: D R ! L L I N G ](size/depth)I (size) ITest: Rig Acc'ept (hr/date): 1/2/93" ~) 0700 HRS J Rig Release( hr/date): I Mud )ate Bi!Data Drillina Data MUd MBT Bit No. Depth Rot TypesPUD 30.0 I 1306 Wt. 75 Weight 8.9 ;pH 9.2 Size 1 6 P.U. 75 S.'O. 75 PPg Wt. Wt. ViScosity 1 60 Pm 0.3 Make sMiTH Avg. Max sec .. Drag ... Draa_ PV/YP 16 / 35 Pf 0.3 Type A1JSL Trq 100 Trq 75 ..... Btm Off Gels 16 / 38 Mf 1.0 Serial No. KV8400 Pt mo Data Pump No. 1 2 Chlorides DePth Out APl W.L. 9.2 1100 ppm MD/TVD / / ... / Liner Size 5.5" 5.5" HTHP Oil 0 Footage 1200 '~100 psi % ft. ft ft. SPM 105 105 HTHP OWR 0 / 95 ART)AST 8.0 / / / 15o0 ~si GPM 371 371 fS°iids 5.0 ES RPM 150 % Table/Mtr / rprr / rpm / rprr ..... Pressure 2100 LGS WeB Sand .75 % 1.3 3O 35 Mi~M~x, / K~ / K~ / ~ ~0ie Slow Pump Data Pi't Vol. 675.0 Jets/TFA 13 16 16 V°l'216.0 bb Slow P.S. Filter Calcium Bit Costs Cake 2 1100 ppm $19983.00. ~SI w $7,463.00 $7463.00 Grade BHA Description' BIT#l, SHOCK SUB, NMLC, MWD, NM STAB, NM DC, NM STAB, 3 NM DC, STAB, JARS, XO, 15 HWDP · ,, , Iniection Data Source: AGI-4 Volume: Type Fluid: Injection AGI-2 IRate: IPressure: Well; ,I , ~p,ml psi I Daily 0 I Cumulative 5409 l. Volume: bbl! Volume: Freeze Protect Fluid' ;Volume: gal Fuel & Water Data ,Fuel 6551 IFue'' [Fuel [ Drl. Water [ Drl. Water !Used: gal [S.ource: BP/KUP 10009.00 2725 VERN Recv'd: gal Used: BBL. Source: " Gutt ngs, DFta ' Weather. D~ta ...... Daily: C;:~Sumulative: / Storage DS-5 Temp: ...,, CFI Sit,: OF[wind Speed: mph~Chill Factor: oF Personnel & Safety/BOP Data Accident? (Y/N): N ,!Name: [EmPloyer: I RptFiloO?(YIN): ,, , , PB Drlg: 1 [ Contractor: 24 IService" 20 [Other: [Total: 45 List DOPE Test: 1/2/93 't. asr BOP Drill: 12/27/92 Last H2S D~'ill: Last Fire Drill: 12/26/92 Last"Safeiy Mig: 12/27/92 Last Spill Drill: 1/2/93 Spill (Y/N)? Volume (Gals.): rype Spill: Report Filed? Time Ormration Prob Code Hr~'. O~erations From 0600 to 0600 0600-0700 OTHR 1.00 FINISHED RIG MOVE & MISC DETAILS. 070'0-1545 OTHR 8.75 ACCEPTED I~IG @ 0700 HRS. R/U DIVERTER ETC. MIXED SPUD MUD. P/U BHA. 1545-0600 DRILL 14.25 TAGGED @ 106' MD. DRILLED TO170'. HIT A REACTIVE CLAY STRINGER THAT ., INCREASED'METH BLUE BY 8 PTS & GE'I'LED MUD. CHLORIDES WERE SAME. HAD TO STOP & ClRCA FEW MINUTES. CONTINUED TO DRILL TO1306'. , ., ,,, ,, ,, .,, , ..... , .. Prudhoe Bay Drilling Daily, Drillinq Report Well: AGI-4 Depth (MD/TVD): 3545 / 3545 IPrev (MD): 1309 IPr°gress: 2236 Contractor: Audi 2 Phone: 4605 1 Daily Costs: $62,978.00 lest Cum Costs:. $168,719.00 ILast Csg: 20"@ 115' INext Csg: IShoe Operation at 0600: SHORT TRIPPING ~33,8" N/A I(siz. e/d ePth) .. .I (size) ITest: Rig Accept (hr/daie): 1/2/93 I Rig Release( hr/date): ! , Mud ')ate .Bit)ate ' Drillina Data Rot Mud TypesPUD MBT 20.0 Bit No. 1 Depth 3545 Wt. 115 Weight 9.3 [pH 8.4 Size 16 P.U. 120 S.C. 110 ViscoSity 1 26 iPm Make SMITH Avg. 5 Max sec Dra~ Dr~ PV/YP 14 / 38 Pf 0 1 Type AIJSL Trq 200 Trq 80 · Btm Off Gels 15 / 35 ;Mf 0.6 Serial No'. KV8400 PLmaData Pump No. 1 2 Chi°rides Depth Out 3545 3545 APl W.L. 16.0 700 ppm MD/'TVD / / / Liner Size 5.5" 5.5" HTHP Oil 0 Footage 3439 100 psi % ft. ft ft. SPM 110 110 HTHP OWR 0 / 93 ART/AST 20.3 / / / 500 ~si GPM 389 389 ES RPM 150 Solids 2.0 % T~ble/Mtr / rprr / rpm / rprr ' Pressure 3300 LGS WeB 35 40 Sand 1.25 % 5.5 Men/Max. / ~ / Kc / ~ Pit Vol. ' Slow Pump Data Hole Vol.852.0 bbl 675.0 Jets/TFA 13 16 16 Slow P.S. , Filter Calcium Bit Costs 2 TR $19983.00 , Cake ppm, $5,523.00 $12986.00 Grade BHA Description: BIT#l, SHOCK SUB, NMLC, MWD, NM STAB, NM DC, NM STAB, 3 NM DC, STAB, JARs, XO, 15 HWDP BHANo: I IBHA Length: 675.22 IDate Last InSpacted: 1/1/93 tH°urs On Jars: 20.25 IniectiOn Data Source: AGI-4 Volume: ;Type Fluid: Injection AGI-2 !Rate: IPressure: ,, Wall;t ~pm! psi Daily Cumulative Volume: bbl Volume: Freeze Protect Fluid: Volume: gal Fuel & Water Data Used: gal Source: !Recv'd: .. c r gal Used: . BBL Source: VERN , Cuttings Data Weather Data Daily: 792YD CiF~umulative: 792YD c~St°rage DS-5 Temp: l Wend'Speed: mphlChill Factor: site' oF: , oF Personnel ~ Safety/BOP Data /(ccident?(Y/N): N IName: IEmployer: IRptFiled?(Y/N): P'B Drlg: 1 [contractor: 26 IService: 20 IOther: :'TOtal: 47 Last DOPE Test: 1/2/93 Last BOP Drill: 12/27/92 Last H2S Drill: Last Fire Drill: 12/26/92 Lasi Safety Mtg: 12/27/92 L~st Spill Drill: 1/2/93 Spill (Y/N)? N Volume (Gals.): Type Spill: Report Filed? Time Ooer'~tion Prob Code Hrs_ Operations From 0600 to'0600 0600-1200 DRILL 6.00 DRILLED FROM i309' TO1997' 1200-1230 ClRC 0.50 CIRC HOLE CLEAN. 1230-1500 TRIP 2.50 SHORT TRIPPED. HOLE IN GOOD SHAPE. ~500-1700 DRIL 2.00 DRILLED FROM 1997-2340'. 1700-1800 PROD EFC '1.00 REPLACED PUMP CONTROL ON DRILLER'S CONSOLE. ,. 1800-0330 DRIL 9.50 DRILLED FROM 2340-3545'. 0330-0430 ClRC 1.00 CIRC. 0430-0600 TRIP 1.50 SHORT TRIPPED. ,,, ,,, ..... Prudhoe Bay Drillin, g. AFE. No: 4J0195 iHpt. No: 3 Surv. No. Depth (MD) Angle Direction T.V.D. Vert. Sec. North/Soutl' East/West Dog Leg Depth Max BGG Time Daily Drillinq Report 1/4/93 ,,-,~-4 GLC ~ Page 2 I 475 i1087 11462 11962/2466 13964 13510! i i ..... ! ! "! I · 26 1-.21 !-1'04 !.2.86 /.7.79 [-14'49r19'471 ! ! ] ! ! I ' Mud Lo.q Data ~Dc Exponent }Shale density l E~t. P0re press 06J;OP/Shale ~~ R'O P/Sand i OPeratio~ J Prob Code Hrs. OperatiOns From 0600 to Prudhoe Bay Drilling. '; ilsY Drillinq Repot1; AF~.-No~1~4 J0 95"-":"lRpt. No: IDate: "iZup,,.,o,:"' ' Well: AGI-4 IDepth (MD/TVD): 3545 / 3545 !Prev (MD): 3545 IPr°gress' 0 'C~ntractor: Audi2 Phone: 4605 I Daily Costs: $136,360.00 JEst Cum Costs: $305,079.00 IL&st Csg: 13-3/8" @ 3538' i Next Csg: 9-5/8" IShoe N/A Operation at 0600: REPLACING BRAKE BANDS [(sizeCdep!h)I(size) ITest: Rig Accept (hr/date): 1/2/93 @ 0600 HRS Rig Release( hr/date): ML~J )ata Bit )ata Drillina Dat~. Mud Type ME~T Bit No. Depth -' Rot GEL 1 Wt. ,. Weight 9.2 iPH Size 1 6 P.U. S.C. PP:J Wt, Wt. Viscosity 55 Pm Make SMITH Avg. Max sec .... Drag Draa_ pV/yp 10 / 18 IPf Type A1JSL Trq Trq Btm Off · , Gels 8 / 18 Mf Serial No. KV8400 PLmp Data . . Pump No. 1 2 APl W.I'. ;Chlorides Depth Out 3545 3545 I .... ppm MD/TVD / / / Liner Size 5.5" 5.5" HTHP 'Oil IFootage 3439 100 esi % ft. ft. ft.SPM 1 10 11 0 HTHP OWR ART/AST 20.3 5OO esi / / / / IGPM 389 389 Solias ES RPM 150 % 'Table/Mtr / rpn' / rpm / rprr ...... Pressure 3300 Sand LGS WOB % Min/Max. 35 / 40 K~ / K~ / K~ Pit Vol. . Slow Pump Data Hole Vol.530.0 bbl 900.0 Jets/TFA 13 16 16 · Slow P.S. Filter Calcium Bit COsts $19983 00 Cake ppm · DailyMud, TotalMud$ Dull 1 1"°1;o i II I" $2,797.00 $15899.00 Grade E I NO !BH'A Description: blT-,g'2,7.3/4- 1.25*DYNADRILL, XO, 2 NMLC, NM STAB, MWD, NM STAB, NMDC, NM STAB, 3 NMDC, STAB, ,. ., JARS, XO, 15 HWDP , , iBHA No: 2 !BHA Length: 705.10 IDate Last Inspdoted: 1/1/93 IH°urs On Jars: Iniection Data Sou'rce: AGI-4 Volume: 611 Type Fluid: MUD Injection AGI-2 IRate: IPressure: Well: ~pm! psi Daily 611 I Cumulative 6020 Volume: bblI Volume: Freeze Protect Fluid' DIESEL Volume: 420 gal Fuel & Water Data Fuel 5099 IFuel BP/KUP [Fuel 0.00 IDrl'Water 1600 IDrl' water Used: gal[Source: ~ Recv'd: galI Used: BBL! Source: VERN , (_;uttin.qs Data ,_ W~ther Data Daily: 281 CF~Cumulative: 1073YD 64st°rageSite: DS-5 Temp: oFI, Wind Speed: mphl Chill Factor: oF Perso;'mel & ~;afetv/BOp Accident? (Y/N): N IName: i Rpt Filed? (Y/N): I Emplbyer: Dat~, ,, PB Prig: 1 ! Contract°r: 26 !Service: 18 IOther: .... !T°tal: 45 Last DOPE Test: 1/5/93 Last BOP Drill: 12/27/92;Last H2S Drill: Last Fire Drill: 12/26/92 Last Safety Mtg: 12/27/92 Last Spill Drill: 1/2/93 Spill (Y/N)? y Volume (Gals.): 5 Type Spill: MUD Report Filed? y Time OOeration Prob Code 'Hrs. Ooeratior~ Fro~ 0600 to 0600 0600-0700 TRIP 1.00 FINISHED SHORT TRIP. NO FILL. HOLE IN GOOD SHAPE. 0700-0900 CIRC 2.00 CIRC HOLE. UNLOADED SAND. 0900-0930 cIRC 0.50 DROPPED S.S.SURVEY. ' 0930-1230 TRIP 3.00 POH & L/D BHA. '1'230-1800 CASG 5.50 R/D WOTCO. RAN 90 JTS CSG. LANDED @ 3538'. NO TROUBLE. , ,, 1800-2030 CIRC 2.50 CIRC 2 CSG VOL. = 1050+ BBL. 2030-2330 CASG 3.00 R/U HOWCO. PUMPED 20 BBLWATER & TESTED LINES 2000 PSI, DROPPED 1ST BTM PLUG, 386BBL LEAD CMT, DROPPED 2ND BTM PLUG, 83 BBL 'TAIL, DROPPED TOP PLUG, 5"B'BE WATER, 512 BBL MUD. BUMPED PLUG oN TIME & CHECKED FLOATS- HELD. CIP @ 2315 HRS. R/D HOWCO. 2330-0200 CASG 2.50 R/D FLOOR, N/D DWERTER & PREP FOR TOP JOB. D200-0245 CASG 0'.75 PUMPED 93SX= 15 BBLTOPJOB. 0245-0530 CASG 2.75 N/U SPLIT SPEEDHEAD & BOP'S. '" 0530-0600 RIGS 0.50 REPLACING DRAWWORKS BRAKE BANDS. ,., Prudhoe Drilling ,, " Daily Drilling Report Well: AGI-4 Depth (MD/TVD): 4363 / 4360 IPrey (MD): 3545 JProgress: 818 I i , , 'COntractor: Audi2 Phone: 4605 1Daily C°sts: $77,841.00. IEst Cum C°sts' $382,920.00 ILast Csg: 13-3/8"@35,..~ I Next Csg: 9-5/8"@ ]Shoe 1 2.0 Operation at 0600: D ri lli n g l(size/depth) ,,~ (size) ITes~: "Rig Accept (hr/date): 1/2/93 @ 0600'HRS I Rig Release( hr/date): Mud ')ata Bit )ara DrillingData ' Rot Mud TypeLSLD MBT 15.0 Bit No, 2 Depth 3770 Wt. 125 Weight 8.8 pH 11.3 Size 12.25 P.U. 125 S.C. 125 ppg Wt_ Wt. Viscosity 37 Pm 1.4 Make SMITH Avg. 0 Max 0 sec Drag Drag PV/YP 5 / 8 Pf 0.4 iType MFDSHC+ iTrq 150 Trq 90 Btm Off Gels 10 25 Mf Serial No. NC5932 Fh_ fpp Data / 0.7 Pump No. 1 2 Chlorides Depth Out APIWi. 12.0 800 ppm MD/TVD / .. / / ... LinerSize 5.5" 5.5" HTHP Oil 0 Footage 818 100 osi % ft. ft ft'SPM 11 0 110 HTHP DWR ART/AST 5OO osi / / / / GPM 389 ' 389 ES RPM 6O 150 SoiiSs 4.0 % Table/Mtr / rprr / rpm / rprr "' Pressure 3100 LGS WOB 0 25 Sa~d tr % 3.5 Miq/Max. / F¢ / I/¢ / Pit Vol. Slow Pump Data Hole Vol.566.0 bbl 550.0 Jets/TFA 18 12 1212 Slow P.S. 30 45 Filter 2 Calcium Bit Costs $6263.00 Cake tr' ppm Daily Mud $$3,172.00 Total M"ud $ $19070.00 Grade Dull !, ! ! J J J J ! "' SlowP.p. 180 220 i BHA DescriPtion: BIT#2,7-3/4" 1.25*DYNADRILL, )~ 2 ML , NM STAB, MWD, NM STAB, NMDC, NM STAB, 3 NMDC, STAB, , JARS, XO, 15 HWDP BHA No: 2 '1BHA Length: 705.10 JDat~ Last Inspected: 1/1/93 I Hours On Jars: i I Iniection Data Source: AGI-4 Volume: 1096 !Type Fluid: Mud Injection AGI-2 IRate: 3 JPressure: 550 Well:[ .. ~pmI psi AGI-4 225 Water Daily 1321 I Cumulative 7341 Volume: bbl! Volume: Freeze Protect Fluid: DIESEL V°lum'e: 840 gal Fuel & 'Water Data Fuet 6272 IFuel Peak IFuel 10005.00 [Drl. Water 1050 [ D,I. Water U~ed: ga!~ Source:I IReCv'd: gal Used: BBL [ Source: VERN --_ (~uttings Data Weather Beta Daily:C~umulativ°: c4Storagesite:. BALL MILL Temp: 11 o~lwind Speed: 7 mphIchill Factor: .2 oF PerSonnel & Safety/BOP Data Accident?(Y/N): N iName: IEmPI~)yOr: " IRptFiled?(Y/N): PB Drlg: 1 Icontractor: 26 I Service: 16 IOther: IT°tal: 43 l'ast'BOPE Test: 1/5/93 Last BOP Drill: 12/27/92 Last H2S Drill: Last Fire Drill: 12/26/92 I Last Safety Mtg: 12/27/92 Lasi Spill"D'rili': 1/2/93 Spill ('C/N)? N VolUme (Gals.): Type Spill: i Report Filed? Time Ooeration Prob Code Hrsl Ooerations From 0600 to 0600 0600-1200 'RIGS 6.00 REPLACED DRAWWORKS BRAKE BANDS; slip & cut drilling line. 1200-1500 bope 3.00 Test BOP's & install wear ring. 1500-1830 t'rip 3.50 P/U kick-off ass'y & RIH. Tagged FC @ 3456.' .... 1830-1900 circ 0.50 Circ. 1900-1930 casg 0.50 Test casing to 3000 psi for 30 min. 1930-2115 drill 1.75 Drill shoe track + 10' "new hole". 211"'5-2145 circ 0.50 Circ. 214'5-2200 casg 0.25 Run EMW test to 12.0 ppg EMW. '2200-0600 drill 8.00 Drilling & sliding. ,, .... _ Prudhoe Bay Drillinq AFE. No: 4J0195 I~pt. No: Jate: 5 Surv. No. Depth (MD) 1/6/93 lWell Name: Data Daily Drilling Report, Supv. Init: SRWalIs I Page2 Dog Leg Depth Max BGG · IMud Wt. tJDc Exponent prob Code ppglF°rmati°n IShale density Operation Mud Lo,q Data IBGgas uIC°nn gas lEst. pore press I ROP/Shale I o6010 Operations From 0600 to fphfRr ip gas U OP/Sand fph Prudhoe Bay Drilling. AFE. No: 4J0195 IRpt. No: Well: I Date: Depth (MD/TVD): AGI-4 Contractor: Audi 2 Phone: 4605 Operation at 0600: D r i I I I n g Rig Accept (hr/date): 1/2/93 @ 0600 HRS )2ta MBT Mud. Mud TypeLSLD Weight 9.2 Viscosity 41 sec PV/YP 9 / 13 Gels 5 19 / APl W.L. 6.4 6.5 HTHP 100 psi iHTHP 500 0si :Solids Sand tr % Hole VoE821.0 bbl Bit No. Filter Cake 1 Daily Mud $ $7,735.0O I/7/93 IDays Since, ,Est: 6040 / 5626 IPrev (MD): l Daily Costs: $71,629.00 ILast Csg: 13_3/8-@3538 1N ext Csg' {size/depth) {size) , Rig Release(hr/date)' 18.0 2 )H 9.2 Size 12.25 Pm 0.3 Make SMITH Pf 0.1 Type M FDSHC+ Mf 0.4 Serial No. NC5932 Chlorides 850 ppm Oil 0 % OWR / ES LGS 6.5 Depth Out MD/TVD Footage Bit lDat8 / / / 2502 ft. ft ft. ART/AST 10.0 5.5 / / / RPM 60 150 Table/Mtr / rprr / rpm / rprr WeB Min/Max. 0 / 25 K~ / F¢ / F¢ Jets/TFA 18 12 1212 $6263.00 Pit Vol. 625..0 Calcium 60 ppm Total Mud $ $26806.00 Bit Costs Dull Grade Da. ily Drilling Report ISupv. Init: . . 5 [ SRWaIIs 4363 IPr°gress: 1677 l Est Cum Costs: $454,549.00 9-5/8"@ IS hoe 12.0 I Test; ... Drilling Depth 5623 P.U. 160 Wt, Avg. 15 !Draa Trq- 400 Btm PL Pump No. Liner Size SPM GPM Pressure Oaia " ' Rot Wt. 145 S.O. 130 Wt. Max 60 Drag Trq 100 Off rpp Data , 110 ! 110 3891389' 3500 Slow Pump Data SlowP.S.! 30I 45 SlowP.P. J 150I 240 BHA Description: BIT #2,7-3/4" 1.25*DYNADRILL, XO, 2 NMLC, NM STAB, MWD, NM STAB, NMDC, NM STAB, 3 NMDC, STAB, I JARS, XO, 15 HWDP BHA No: 2 BHA Length: 705.10 iDate Last Inspected: 1/1/93 Hours On Jars: 27.25 Iniection Data lSource: AGi-4 Volume' 660 Type Fluid: Mud Injection AGI-2 lRate: I IPressure: 400 Well: ~pm! psi Daily 660 I Cumulative 8001 Volume: bbl ! Volume: Freeze Protect Fluid: Diesel Volume: 420 gal ,Fuel 6020 ! Fuel iUsed: gal.I Source' Outtinqs Data Daily: Cl=~Cumulative': Accident? (Y/N): N JName: !PB Drlg: I J Contractor: Last DOPE Test: 1/5/93 Last Spill Drill: 1/2/93 0600-0615 drill Fuel & Water Data Fuel 10016.00 IDrI. Water 1450 IDri' water Peak IRecv'd: gal Used: BBL Source: VERN CFIsite: Personne! & Safety/EOP Data I EmPloyer: 26 Iservice: 9 IOther: 5 ILast H2S Drill: ILast Fire Drill: 12/26/92 ,ILast BOP Drill: 12/27/92 [Volume (Gals':): [l-ypeL ISpill(Y/N)? N Spill: O.oeratioqs FrQrll 0600 to 0600 Drilling to 4552. Weather Data 1 5 mphll Chill Factor: -7 OF Rpt Filed? (Y/N): Total: 41 Last Safety Mtg: 12/27/92 Report Filed? 0615-0630 circ Circulate. Short trip to casin~ shoe. Hit lots of clay, but no swabbing or fill problems. Drilling Service rig. Drilling. Replace swab & liner in #2 pump. Drilling to 5489. Circ sweep & 10-std shod trip. 50-60k overpull 1st two std's, but ok after that. Drilling; planning a trip early this morning for BHA change. 0630-0800 trip 0800-1330 drill 1330-1400 rigs 1400-1 drill 1545-1700 prob efc 1700-1930 drill 1930-2130 trip 2130-0600 drill Prudhoe Bay Drillinq AFE. No: 4J0195 I~pt. No: Surv. No. Depth (MD) Angle Direction T.V.D. Vert. Sec. 6 ! ~ate: 1/7/93 J Well Name: Surve, Data Daily ISupv. Init: SRWalIs Page 2 East/West Dog Leg Depth Max BGG T~me IMud Wt. IDc Exponent Prob Code ppglF°rmati°n ' IShale density Operation Hrs. Mud Lo,q Data I BG gas olCOnn gas Est. pore press I ROP/Shale Old'rations From 06d'o to 060'0 .L~rip gas I ROP/Sand fph · Prudhoe Bay Drillinq Dail, l Drilling Report AFL. No: 4J0195 Rpt. No: , Date: I ~8/93 Days Since ./Est: 6 S~upv' -' ., , We,: AGI-4 Depth(MD/TVD): 6657 / 5923 JPrev(MD): 6040 JProgress: 617 Contractor: Audi 2 Phone: 4605 '.i Daily Costs: $67,018.00 lEst Cum Costs: $521,567.00 ]Last Csg: 13_3/8-@3538 JNext Csg: 9-5/8"@ JShoe 12.0 Operation at0600: Tripping for motor failure J(size/depth) J(size) ITest: Rig Accept (hr/date): 1/2/93 @ 0600 HRS J Rig Release( hr/date): I Mud )~ta " Bit ')ata D'~:'iilina Data - Rot Mud TypeLSLD MBT 22.5 Bit No. 2 3 Depth 6575 Wt. 145 '" pH Weight 9.3 9.1 Size 12.25 12.250 P.U. 165 S.C. 120 .ppc.:j Wt. Wt. Viscosity 49 Pm 0.3 Make SMITH Smith Avg. 20 Max 60 sec Drag Draa_ PV/YP 10 ! 15 iPf 0 I Type MFDSHC+ MFDSH+CEL Trq 350 Trq 250 ' Btm Off Gels 15 / 39 iMf Serial No. "~C5932 NC6942 Pump Data Chlorides 1.4 Pump No. 1 2 Depth Out 6339 5775 6657 / 5923 ,; ..... APl W.L. 6.4 1 700 ppm MD/TVD / .... / Liner Size 5.5" 5.5 HTHP !Oil 0 Footage 2794 318 .... 100 psi % ft. ft ft. SPM 11 0 110 HTHP DWR ART/AST 11.0 6.8 2.0 34.0 ..... 5oo esi / / / / GPM 389 389 SoliSs 7.0 'ES RPM 60 150 8O 150 % Table/Mtr / rprr / rpm / rprr Pressure 3400 . LGS WeB 0 25 I 25 45 Sand tr % 7.2 Mb/Max. / Slow Pu.mp Data Pit Vol. 700.0 18 12 1212 23141412 Hole Vo1.920.0 bbli Jets/TFA Slow P.S. Filter 1 Calcium 80 ppm Bit Costs $6263.00 $8927.00 Cake DailyMud$ TotalMud$ Dull ~131~1^ 'I'iNOI^ I II s,ow,.,. $5,006.00 $31812.00 Grade E 1 BHA E I NO DMF BHA Description: Bit,lOBH F2000,xo, NM Stab, NMLC, NM Stab, NMLC, MWD, NM Stab, 3xNMDC, stab, NMDC, jars, 15 HWDP BHA No: 3 IBHA Length: 707.99 ]Date Last Inspected: 1/1/93 IH°urs On Jars: 32.75 Iniection Data Source: AGI-4 Volume: 324 Type Fluid' Mud Injection AGI-2 IRate: 3 IPressure: 650 Well:J ~pmI psi AGI-4 232 Water Daily 556 J Cumulative 8557 Volume: bblJ Volume: Freeze Protect Fluid: Diesel j Volume: 420 gal Fuel & Water Data Fuel 5191 !Fuel Peak IFuel 10009.00 IDrl. Water 975 j Drl. Water Used: gal,Source: Recv'd: gal Used: BBL Source: VERN Cuttings Data Weather Data Daily: cFJCUmulative:CFj~ite:/St°rage DS-5 Temp: 25 o~=JWindSpeed: 0 mphJChillFact°r: 25 o~= Accident? (Y/N): N JName: personnel & Safe~y/BOp Dat~ [Employer: I Rpt Filed? (Y/N): I PB Drlg: 1 Contractor: 2 6 Service: 9 5 41 , Last DOPE Test: 1/5/93 !Last BOP Drill: 12/27/92 Last H2S Drill: Last Fire Drill: 12/26/92 Last Safety Mtg: 12/27/92 Last Spill Drill: 1/2/93 iSpill (Y/N)? N Volume (Gals.): Type Spill: Report Filed? Time O~eration Prob Code: Hrs. Ooerations From 0600 to 0600 0600-0930 drill 3.50 Drilling; angle buili to 61.8° & DD wanted to change BHA. ..... 0930-1000 circ 0.50 CBU. 1000-1030 surv 0.50 Drop checkshot survey,. 1030-210© trip 9.00 Tripf. BHA. Swabbed from 4334-3537. Changed mtr, bit, BHA, tested tools & RIH. prob th ' 1.50 (1.4 hr rig service) Hit bridge @ 3636-washed through with 2 singles before falling through. Tight from 5670-5730--had to work pipe down. Reamed laSt 72' to bottom. 2100-0130 drill 4.50 D~'illing to 6657. Motor failure. 0130-0600 P'rob efs 4.50 POOH, no discernable damage to motor or rest of BHA. Change motor & RIH. Prudhoe Bay Drillin~ ~ ' ' ~-, Daily Drillinq Re~rt AFE. No: 4J0195 Apt. No: 7 ! 1/8/93 . ~,,-4 Walls Page 2 Survey ..Data , Surv. No. 21 22 23 Proj Depth (MD) 6081 6268 6450 6657 Angle 58.2 61.8 62.5 62.5 I Direction 85.4 85.4 ;86.1 86.1 T.V.D. 5649 5742 5827 5923 Vert. Sec. 1222 1284 1545 1728 North/Soutt' N 79 N 92 N 104 N 116 East/West E 1220 E 1381 E 1541 E 1725 Dog Leg 0.96 1.93 0.51 Mud Lo.q Data Depth Mud Wt. Formation BG gas Corm gas Trip gas PPg U~ U U Max BGG Dc Exponent Shale density Est. pore press ROP/Shale ROP/Sand U ~ fph Time Operation Prob Code Hrs. OPerations From 0600 to 06(0 "' ._ ,,, .... , .... ,, .... ,,, ,, Prudhoe Bay Drilling, 'i ' D: Drillin¢ AFE. No: 4~J0195 Rpt. No: ,., Date: 1/9/93 Days Since ._, .,/Est: 7 Supv. init: Well: SRWalls AGI-4 Depth (MD/TVD): 7423 / 6292 JPrev (MO): 6657 [Progress: 766 Contractor: Audi 2 Phone: 4605 i Daily Costs: $263,227.00' IEst C.m' Costs: $784,794.00 I I ILast Csg: 13-3/8"@3538 }Next Csg:' 9-5/8"@ [Shoe 12.0 Operation at 0600: D r il ! i n g J('size/depth) J (size) ITest: Rig Accept (hr/date): 1/2/93 @ 0600 HRS J Rig Release( hr/date): I Mud Data Bit ')ara Drillino Data Mud TypeLSLD MBT 22.5 Bit No. 4RR3 5RR3 Depth - Rot 7400 Wt. 155 'Weight 9.3 pH 8.9 Size 12.250 12.250 P.U. 180 Is'O' 13,5 PI~ Wt, Viscosity 40 Pm 0.3 Make Smith Smith Avg. 25 Max 45 sec i Draa Draa PV/YP 8 / 8 Pf 0.1 Type MFDSH+CE MFDSH+CEL Trq- 550 Trq- 200 · . Btm Off Gels 4 / 21 Mf 0.6 Serial No. NC6942 NC6942 Pumo Data Depth Out Pump No. 1 2 APl W.L. 6.0 Chlorides 1500 ppm MD/TVD / 7177 / 6175 / Liner Size 5.5" 5.5" HTHP Oil 0 Footage 520 1 084 100 osi % ft. ft ft. SPM 100 100 HTHP OWR ART/AST 4.0 0.8 6.8 2.0 5OO psi / / / / GPM 353 353 Solids 7.0 ES RPM 80 150 80 150 % TablelMtr / rprr / rpm / rprr LGS -WOE Pressure 3600 Sand tr % . 6.6 Min/Max. / IZ¢ 25 / 45 F¢ 25 / 45 ~ Pit Vol. Slow Pump Data Hole Vol.997.0 bbl 650.0 Jets/TFA l ~2:) 141412 20 141412 !Filtercake 1 Calcium 60 ppm Bit Costs Slow P.S. 30 45 DailyMud, TotalMud, Dull ill '1'1"OI^ I J SlowP.p. 190 280 $5,429.00 $37241.00 Grade E J NO DMF BHA Description: Bit,lOBH F2000,xo, NM Stab, NMLC, NM Stab, MWD, NM Stab, 3xNMDC, NM Stab, NMDC, jars, 15 HWDP BHA No: 5 IBHA Length: 707.78 IDate Last Inspected:. 1/1/93 IHours On Jars: 37.5 Iniection Data !Source: AGI-4 Volume: 418 Type Fluid: Mud Injection AGI-2 IRate: 3 IPressure: 450 W~ll; ~pmI psi Daily 418 I Cumulative 8975 Volume: bblI Volume: Freeze Protect Fluid: Diesel ..... Volume: 840 , gal Fuel & Water Data Fuel 4895 !Fue' Peak JFuel 7100.00 IDrl. Wate, 700 ! Drl. Water Used' gal Source: Recv'd: gaJ Used: BBL Source: VERN Cuttin.qs Data Weather Data I~ 4 Iwind Speed: !Chill Fact°r: 20 umulative: 100 Storage CC_2A Temp: 20 oF oF Daily: 1 00 C c Site: 0 mph Personq¢,! & Safety/BOP Data_ Accident?(Y/N): N IName: jEmployer: JRptFiled?(Y/N): PB Drlg: I I C°ntract°r: 26 IService: 7 IOther: 5 IT°tal: 39 Last DOPE Test: 1/5/93 Last BOP Drill: 12/27/92 Last H2S Drill: Last Fire Drill: 12/26/92 Last Safety Mtg: 12/27/92 Last Spill Drill: 1/2/93 Spill (Y/N)? N Volume (Gals.): Type Spill: Report Filed? Time Oaeration!Prob CodeHrs_ Oaerations From 0600 to 06OQ 0600-0800 prob efs 3.00 RIH to bottom w. new motor. No hole trouble on trip. 0800-1530 drill 7.50 Drilling 6657-7177. MWD tool quit sending signal. 1530-1645 prob efs 1.25 CBU & drop survey. 1645-0045 prob els 8.00 Trip to change MWD. No hole problems. (1/4 hr rig service in trip time,+1/4 hr washing to bottom) No fill. 0045-0600 drill 5.75 Drilling. _ Prudhoe Bay Drillinl ,, .,, f-'--., , Daily Drillina Re.poE i ' i ' I ' I- 'A~):4J01'v --.,,- pt. No: 8 ~ [ ..'ate: 1/9/93 Well Name: .... -4 Supv. Init: SRWalls Page 2 SUrvey Data ,, Surv. No. 24 25 26 27 Depth(MD) 6630 6920 7014 7237: ,,, Angle i60.7 61.00 !61.4 61.9 Direction ,86'.4 87.8 188.5 88.2 ,,, , T.V.D. 5913 6005 ~6099 6203 ,,, ,, Vert. Sec. 1703 1869 2039 2232 North/SouthN 114 N 123 'N 128 N 134 ,, , East/West E 1699 E 1865 E 2035 E 2228 Dog Leg 1.01 0.66 0.'38 0.26 Mud L. 0~.Data Depth Mu~ Wt. Formation BG gas Corm gas trip gas ppg u L Max BGG Dc Exponent Shale density Est. pore press ReP/Shale ReP/Sand ' 'limo C~'r~eration Pr0b Code Hrs. ,, Operation's From 0600 to 06¢0 ,, ,, ,, ,, ,, ,, , , ..... Prudhoe Bay Drilling Dali,! Drillinq Report 4J0195 Rpt. No: .. Date: I/1 0/93 Days Since _, .--st: 8 Supv. Init: SRWalls well: AGI-4 Depth (MD/TVO): 8020 , 6592I (MO):7423 JPr°gress' 597 I Contractor: Audi 2 Phone' 4605 I Daily Costs: $58,534.00 lEst Cum Costs: $843,328.00 "' !Last csg: 13-3/8"@~ '"1 Next Csg: ¢-5/8"&1!000 IShoe 12.0 EMW Operation at 0600: D r il Ii n g Ifsize/de~)th) I(size) . ITest: Rig Accept (hr/date): 1/2/93 @ 0600 HRS I Rig Release( hr/date): .... Mud )ara Bit ~)ata Driltin_0'Data Rot Mud TypeLSLD MBT 25.0 Bit No. 5RR3 Depth 7959 1 60 Wt. , Weight 9.4 pH ' 8.9 Size 12.250 p.U. 180 S.Oi 140 pp~, Wt. Wt. ViScosity 40 Pm 0.2 Make Smith Avg. 20 Max 40 sec Drar'] Drao PV/YP 10 / 8 Pf 0.1 Type MFDSH+CEL Trq- 350 Trq- 200 Btm off Gels 4 / 10" Mf 0.6 Serial No. NC6942 Puree Data .... Pump No. 1 2 APl W.L. Chlorides Depth Out 6.4 1300 ppm MD/'I'~[~ / / / Liner Size 5.5" 5.5" , , HTHP Oil 0 Footage 1 681 100 .D~j % ft. ft ft.SPM 110 110 HTHP OWR A RT/AST 20.0 1.0 [5oo esi / / ..... / / GPM 389 389 ES RPM !Solids 8:0 % Ti~ble/Mtr / rprr / rpm 80 / 150 rprr ' Pressure 3600 LGS- WeB 25 45 Sand tr % 7.6 / K~ / K~ / Men/Max. Slow Pump Data Pit Vol. Hole Vol11 05.0 bbl 650.0 Jets/TFA 20 141412 Slow P.S. 30 45 Filter Calcium Bii Costs Cake 1 80 ppm Daily Mull $ Total Mud $ Dull ill I I I ]sl°wP'P' 190 280 $7,556.00 , $44797.00 Grade BHA Description: Bit,lOBH F2000,xo, NM Stab, NMLC, NM Stab, MWD, NM Stab, 3xNMDC, NM Stab, NMDC, jars, 15 HWDP BNA No: 5 ] BHA Length:.. 707.78 ]Date Last inspected: 1/1/92 ] Hours On Oars' 54.5 Iniection Data , , Source: AGI-4 Volume: 485 Type Fluid: Mud Injection AGI-2 IRate: 1 ]Pressure' 400 Well;[ ~)pmI psi Daily 485 I Cumulative 9460 . Volume: bbl! Volume: Freeze Protect Fluid: Diesel ,, Volume: 0 gal Fuel & Water Data Fuel 7066 IFuel IFuel IDrl. water IDrI' water Used: gal[Source Peak 1150 Vern Lake · JRecv'd' gal Used: ... BBL, Source: Cuttings Data W¢c~ther Data ~ lStorage CC-2A ~emp: ]Wind Speed: JChill Factor: .25 oF umulative: 190 C~site: 1 0 mph Daily: 90 C ,8 oF · Personnel & Safety/BOP Data .... Accident?(Y/N): N IName: iEmpI0yOr: !RptFiIOO?(Y/N): Last DOPE Test: 1/5/93 Last BOP Drill: 12/27/92 Last H2S Dr'ill: ' Last Fire Drill: 12/26/92 Last Safety Mtg: 12/27/92 ...... Last Spill Drill: 1/2/93 Spill (Y/N)? N Volume (Gals.): ryPe Spill: Report Filed? Time O~eration Prob Code Hrs. Operation's Fro'm 0600 to 0600 '" 0600-1915 drill 13.25 Drilling 7437-7750. 1915-1945 rigs 0.50 Service rig & adjust brakes. , 1945-0245 drill 7.00 Drilling. 0245-0400 prob efc 1.25 Repair #2 mud pump. 0400-0600, drill 2.00 Drilling. . ...... Prudhoe Bay Drillin .'--, Daily Drillinq Report.. AFE'"N°:.,, 4J0195 F~pt. No: 9 I 1 / 10/93 . ..,, .4 Survey Data ,, Surv. No. 28 29 30 Depth (MD) 7419 7606 7795 ~0.6 60.1 59.9 Angle Direction 86.8 86.4 89.2 T.V.D. 6292 6385 6479 Vert. Sec. 2395 2557 2721 North/Soutt- N 141' iN i'50 N 157 " East/West E 2391 :E 2553 E 2716 Dog Leg 0.96 0.33 1.29 , , Mud Lo,q Data Depth Mud Wt. Formation BG gas Conn gas ]'rip gas PPg Ul t. U Max BGG Dc Exponent Shale'density Est. pore press ROP/Shale ROP/Sand L fph Time IODeration Prob Code Hrs. Operations From 0600 to 06C,0 ,,, ,,, ,, , , , ,,, , . . ,, .... ,,, Prudh0e Bay Drilling D Drillin, Report AFE. Noi 4J0195 Rpt. No: ' Date: 1/1 I/93 Days Since 7, Est: 9 S"upv. Init: _ ' ' SRWalls Well: AGI-4 Depth (MD/TVD): 8650 / 6909 JPrev (MD): 8020 JProgress: 630 Contractor: Audi 2 Phone: 4605 i Daily Costs: $57,101.00 JEst Cum Costs: $900,429.00 I I Operation at 0600: Drilling ILast Csg: 13-,3/8"@35,.'.'~ INext Csg: 9-5/8"@11000 IShoe 12.0 EMW I(size/depth) (size) ITest: Rig ~,ccept (hr/date): 1/2/93 @ 0600 HRS I Rig Release( hr/date): I Mud ")ata Bit ')ara Drilling Data Rot !Mud TypeLSLD MBT 22.5 ~Bit No. 5RR3 Depth 8500 Wt. 165 Weight 9.4 pH Size P.U S.C. pp~ 9.6 12.250 · 1 90 140 Wt, Wt. Viscosity 43 Pm 0.4 Make Avg. 25 Max sec Smith Drao Drag 35 PV/YP 12 / 16 Pf 0.2 Type MFDSH+CEL Trq- 300 Trq 200 Gels 5 / 16 Mf 1 0 Serial No. ~ Btm Off · NC6942 Pt~mo Data Depth Out ~Pump No. 1 2 iAPI W.L'. 6.0 Chlorides 1 200 ppml MD/'I-V[~ / / / Liner Size 5.5" 5.5" HTHP Oil 0 Footage 1 681 23 100 esi % ft. ff. ,, ft. SPM 11 0 11 0 HTHP DWR ART/AST 41.0 1.0 5OO psi / / / / GPM 389 389 ES RPM Solids 8.5 % Table/Mtr / rprr / rpm 80 / 150 rprr LGS WOB Pressure 3600 Sand tr % 7.6 Min/Max. / F¢ ~. / F¢ 25 / 45 F¢ Pit Vol. Slow Pump Data Hole Vol1188.0 bbl 625.0 Jets/TFA : 20 141412 :Filtercake 1 Calcium 60 ppm'Bit Costs Slow P.S. 30 45 $7,176.00 $51974.00 Grade i BHA Description: Bit,lOBH F2000,xo, NM Stab, NMLC, NM Stab, MWD, NM Stab, 3xNMDC, NM Stab, NMDC, jars, 15 HWDP Jars= 1417-1118 BNA No: 5 ! BHA Length: 707.78 IDate Last Inspected: 1/1/92 IH°urs On Jars: 73.75 lniection Data Source: AGI-4 Volume: 473 Type Fluid: Mud Injection AGI-2 IRate: 1 IPressure: 450 Well;I ~pmI psi Daily 473 iCumulative 9933 Volume: bbl] Volume: Freeze Protect Fluid: Volume: ' gal Fuel & Water Data Fuel 5792 IFuel IFuel I IDrl' water Used: gal[Source: Peak Drl. Water 325 Vern Lake ,,, IRecv'd: gal Used: BBL Source: Cuttings Data Weather Data 'r~ ~Storage CC-2A Tamp: IWind Speed: I Chill Factor: 12 umulative: 214 C Site: 10 mph °F Daily: 24 C 24 °F 'Abcident? (Y/N): N IName: Personnel & Safetv/BOP Data IEmpl~)yer: J Rpt Filed? (Y/N): I PB Drlg: 11 Contractor: 26 IService: 11 IOther: 5 ITotal: 43 Last DOPE Test: 1/5/93 Last BOP Drill' 12/27/92 Last H2S Drill: Last Fire Drill: 12/26/92 Last Safety Mtg' 1/10/93 Last Spill Drill: 1/2/93 spill (Y/N)? N Volume (Gals.): Type Spill: Report Filed? Time Operation Prob Code Hrs. Ot3erations From 0600 to 0600 0800-0600 drill 23.50 Drilling. 0615-0645 prob efc 0.50 Replace 2 swabs & liners in #1 mud pump. · . Prudhoe Bay Drillin(i "' Daily Drilling Re rt AFE. No: 4J0195 l~pt. No: 10 I 1/11/93 A,.~,-4 .. Survey Data Surv. No. 31 32 33 34 Depth(MD) 7983 8171 8358 854~ , Angle 60.0 59.7 59.9 ' 59.5 Direction 86.8 87.1 86.4 87.1 ............ T.V.D. 6573 6668 6762 6856 Vert. Sec. 2884 3046 3208 3369 N North/South 162 N171 N180 N189 East/West E 2879 E 3041 E 3203 E 3364 Dog Leg 1.11 0.21 !0.34 0.39 ,,,,, , Mud Lo.q Data Depth Mud Wt. Formation BG gas Corm gas ri-rip gas PPg u u u Max BGG Dc Exponent Shale density Est. pore press ROP/Shale ROP/Sand Time O~eration Prob Code Hrs,' Operations From 0600 to 06(:'0 , ,,, , , , , ,,, ,, ,, .... ,, Prudhoe Bay Drilling. AFL. No: 4J0195 IRpt. No: Well: AGI-4 Contractor: Audi 2 Operation at 0600: Rig Accept (hr/date): Mud Mud TypeLSLD Weight 9.5 Viscosity 41 sec PV/YP 13 / 11 i 1 IDate: I Depth (MD/TVD): Phone: 4605 Drilling 1/2/93 @ 0600 HRS ~HTHP 100 psi HTHP 500 psi Solids )ate MBT 25.0 pH 9.6 Bit No. 6PR Size Pm 0.4 Make Pf 0.3 Type Gels 5 15 Mf Serial No. / 1.1 Depth Out APl W.L. 5.8 Chlorides 1200 ppm MD/TVD Footage Sand ES % 8.5 LGS 7.2 tr % ART/AST RPM Table/Mtr WeB Daily Drilling Report J Isupv. Init: ' ... I / 1 2 / 9 3 Days Since ..,pud/Est: 1 0 I S~.'Wa!!s ! 9208 , 7191I Pr~(MD): 8650 IPr°gress: 558 l J Daily Costs: $73,133.00 lEst Cum Costs: $973,562.00 ILast Csg: 13-3/8"@3538 i Next cSa: 9-5/8"@110o0 IShoe 12.0 EMW I{size/depth) I Rig Release( hr/date): I(size) ~ ITest: Bit ')ate 12.25 Smith S856KP JQ2486 / / 406 6.0 / / rpm 100 150 / rpn 12 18 5PR3 12.250 Smith MFDSH+CEL NC6942 8802 / 6987 1625 ft. 45.5 1.3 / 8O 150 / rprr 25 45 Drillina Data DePth .... -IR°t , .., ,., ~;"~ [Wt. ~/u ! P.U. 200 IS'O' 150 WL I wt. Avg. 30 IMax 50 Draa IDrao Trq- 350 ITrq- 225 Btm IOff Pcmo Data Pump No. '1 ] 2 Liner Size 5.5" 5.5" SPM 110 ! 110 I 389 [ 389 3700 GPM Pressure MiniMax, / F¢ / F¢ / K~ Hole V°11237.0 bbl Pit Vol. 650.0 Jets/TFA 16 16 16161515 20 1414 12 Slow Pump Data I I Slow P.S. J 30 J 45 DailyMud$ TotalMud$ Dull I ! I I I IJ I 8 J 8 I BTJ A ISlow [ 190 J 290 $4,338.00 $56312.00 'Grade ! I I I I I I IE ! ' ""1 P'P' BHA Description: Bit,lOBH F2000,xo, NM Stab, NMLC, NM St~.b, MWD, NM Stab, 3xNMDC, NM Stab, NMDC, jars, 5 HWDP Jars=1417-1118 BNA No: 6 BNA Length: 708.03 jDate Last Inspected: 1/1/92 ] Hours On Jars: J'S'ource' AGI-4 Volume: 453 Typo Fluid: I I Injection Data Mud Injection AGI-2 Well; Daily 453 Volume: Freeze Protect Fluid: Volume: 420 i Rate: 3 JPressure: cjpmi JCumulative b~l Volume' Diesel gal 85.5 55O psi 10386 Fuel & Water Di~t~ Fuel 5728 iFue' J~ue, j Dr,. Water J Dr,. Water IUsed: gel.[.Source: Peak 20011 950 Vern Lake Recv'd' gal Used: BBl.. Source: I uutt;n'qs Dataq Jt J Weather DataI ,~3 ,] StorageCC-2A emp: Wind Speed: Chill Factor: umulauv~: 244 C Site' 1 0 mph Daily: 30 C 6 oF Personnel & Safety/BOP iACcident? (Y/N)' N j Name: J Emplbyer: Data PB Drlg: I J Contractor: 26 JService: 15 J Other: 5 Last DOPE Test: 1/11/93 JLast BOP Drill: 12/27/92JLast H2S Drill: JLast Fire Drill: 12/26/92 Last Spill Drill: 1/2/93 'JSpill (Y/N)? N JvolUme' (Gals.): j,ypei-'- Spill: Operations From 0600 to 0600 0600-1130 drill Drilling to 8802. Pumped around sweep before POOH. Rpt Filed? (Y/N): Total: 4 7 Last Safety Mtg: 1/10/93 Report Filed? 1130-1500 trip Pump slug & POOH. Hole in good shape. Test DOPE's. Viewing waived by AOGCC-field inspectors not on ANS. M/U new BHA, test motor & MWD & RIH. Ream 40' to bottom, no fill. Drilling. ..... 1500-1700 bope 1700-2100 trip 2100-0600 drill Prudhoe Bay Drillincl ? '" Daily Drilling Re~rt Survey Data .... Surv. No. 35 36 37 Depth (MD) 873;;" 8922 9107 .... 59.3 !59.5 60.2 "' Angle Direction 86.4 186.8 86.4 T.V.D. 6951 7048 7141 ,, Vert. Sec. 3530 3694 3854 ..... North/Soutl~!N 198 N 208 N 218 IE East/West 3525 E 3688 E 3848 ., Dog Leg 10.34 0.21 0.42 ,, Mud Lo.q Data Depth Mud Wt. Formation [BG gas Conn gas trip gas PPg U L U Max BGG Dc Exponent Shale density Est. pore press ROP/Shale ROP/Sand Time OBeration Proh Code Hrs. OperatiOns From 0600 to 06(:0 i · , , · , , , I , ... .., .... .. · , .,., , , ., , ., Prudhoe Bay Ddlling l Drillinq. Report. I I - "-- ........ '='] ' I Days Sin"~e ,.,pud/ESt: ' S~up~,. Init: 'AF[E.-N0~ ",~0195 Rpt. No: 12 Date: 1/13/93 11 JG/SW Well: AGI-4 Depth (MD/TVD): 10020/ 7528 I Prey (MD): 9208 [Progress' 812 Contractor: Audi2 Phone: 4605 I Daily Costs: $62,490.00 lest Cum Costs: $1,036,052.00 IL?st Csg: 13~3/8"@3538 I Next Csg: 9-5/8"@11000 lShoe 12.0 EMW operation at 0600: D ri I ! i n g I(size/depth)~ (size) ITest: , Rig Accept (hr/date): 1/2/93 @ 0600 HRS i Rig Release( hr/date): I 'Mud 3at? Bit~)ata Drilling Data Rot Mud TypeLSLD MBT 27.5 Bit No. 6RR Depth 9801 Wt. 170 Weight 9.6 pH 9 5 Size 12.25 P.U. 210 S.C. 150 PPg ' Wt, Wt. [Viscosity 43 Pm 0.4 Make Smith Avg. 40 Max 60 se~ Drad Draa IPV/YP 14 / 13 Pf 0.3 Type S856KP Trq 300 Trq 250 Btm Off [Gels 5 / 12 Mf 1.3 Serial No. JQ2486 P[~mo Data Pump No. 1 2 Chlorides Depth Out iAPI W.L. 6.0 950 ppm MDfl-VD / / / Liner Size 5.5" 5.5" HTHP 19.4 Oil 0 Footage 1218 100 Dsi % ft. tt , ft.SPM 104 104 HTHP OWR ART/AST 20.5 2.5 .... 500 psi / I / / GPM 367 367 ES RPM 100 15O Solids 8.5 % Table/Mtr / rprr / rpm / rprr Pressure 3400 · , LGS WOB Sand tr % 7.3 12 18 Min/Ma×. / F¢ / K~ / Slow Pump Data Hole Pit Vol. 700.0 16 16 16 161515 Vo, 364.0 bbl - Jets/TFA Slow P.S. 30 45 Filter Calcium Bit Costs Cake 1/2 40 ppm $7,100.00 $63412.00 IGrade .. BHA Description: Bit, lOBH F2000,xo, NM Stab, NMLC, NM Stab, MWD, NM Stab, 3xNMDC, NM Stab, NMDC, jars, 15 HWDP Jars=1417-1118 BHA No: 6 IBHA Length: 708.03 IDate Last inspected: 1/1/92 IH°urs On oars: 100.5 ,, Iniection Data, , Source: AGI-4 Volume: 685 Type Fluid: Mud Injection AGI-2 IRate: 2 IPressure' 400 W~II;! ~lpmI psi Daily 685 cumulative 11071 Volume: bbl Volume: Freeze Protect Fluid: Volume: gal Fu¢ & Water Data Fuel 6319 IFuel Peak IFuel 0 IDrl'Wate' 1500 IDrl' water Used: gallSource: Recv°d: gal Used: BBl.: Source: Vern Lake Cuttin,qs Data Weather Data Daily: 100 o'~Umulative: 344 c~JSt°rage CC-2A~it~: Temp: 27 oFIwindspeed: 30/42 mphJChillFact°r: '9 °F Safetv/BOP Data Accident? (Y/N): N J Name: Pers°nnel'&lEmpl~yer: I Rpt Filod?"'(Y/N): PB Drlg: 2 ! Contractor: 26 {Service: 12 [Other: 5 Total: 45 Last DOPE Test: 1/11/93 Last BOP Drill: 12/27/92 Last H2S Drill: Last Fire Drill: 12/26/92 Last Safety Mtg: 1/10/93 Last Spill Drill: 1/2/93 Spill (Y/N)? N Volume (Gals.):' i-ype Spill: Report Filed? , Time Ooeration I Prob Code Hrs. Ooerations From 0600 to 0600 0600-0600 drill 23.25 Drilling & sliding. 1315-1400 prob efc 0.75 Change swivel packing. , ,, · .. ... , .. ,,, , , , ,, Prudho¢ Bay Drillin i '"-'",, *-'" Daily Drilling Report '-' ' "' I-' ' Survey Data .,, Surv. No. 38 39 40 41 , Depth (MD) 9295 9472 9660 985; , Angle 61.0 61.6 62.¢ 62.4 , Direction 86.4 86.1 85.7 85.7 T.V.D. 7233 7318 7407 7498 Vert. Sec. 4017 41 73 4338 4513 North/SouthN 228 N 238 iN 250 N 269' East/West E 4011 E 4166 ~E 4331 E 4505 I Dog Leg 0.43 0.37 0.37 0.10 , ,, Mud Lo.q Data Depth Mu8 Wt." Formation BG gas Conr~ gas Trip gas 12¢g U U U Max BGG DC Exponent Shale density .....Est. pore press ROP/Shale ROP/Sand L fph Time Oe~eratior~" Prob Cod~ Hrs. Operations From 0600 to 06C~0 ......... ,, , , , , .... ,,, ..... , _ . ... · · . ,,,,, ,, , , , , ,,, , Prudh0e Bay Drilling ilsY Drillinq Report. AFE"N°i~ ~0195 ~IRPt'N°: ~'3 ,/,4/93 I°~ Well:" AGI-4 Septh(MD/TVD): 10282 / 7650 IPrev(MD)i 10020 IP~:°gress: 262 Contractor: Audi2 :Phone: 4605 iDaily COsts: $65,509.00 IEst Cum c°sts: $1,101,561.00 ILast Csg: 13-3/8'@3538 INext Csg: 9-5/8'@11ooo Ishoe 12.0 EMW I Operation at 0600: Dril lin g l(s. ize/depth)~(size) ... JTest: Rig Accept (hr/d~ie): 1/2~/93 @ 060"0"HRS [Rig Release( hr/date): I Mud Data. Bit Data Drillina Data Rot Mud TypeLSLD MBT 27.5 Bit No. 6RR 7 Depth10282 Wt. 175 Weight 9.6 pH 9.7 Size 12.25 1214,000 P.U. 220 S.O. 155" PP~ Wt. Wt. Viscosity 43 Pm 0.4 Make Smith Hughes Avg. 45 Max 1 20 sec , 'Draa Draa 'PV/YP 14 / 13 Pf 0.3 Type S856KP ATXCMG1 iTrq 350 Trq 250 Btm Off Gels 5 / 14 Mf 1.4 Serial No. JQ2486 M65BR PL T~p Data .... Pump No. 1 2 Chi°rides Depth Out 10282 APl W.L. 6.0 900 ppm MD/'r'VD / / / Liner Size 5.5" 5.5" HTHP" 19.0 Oil 0 Footage 1480 100 esi ... % ft. ft ft.SPM 1 04 1 04 HTHp OWR ART/AST 28.0 2.5 500 ~si / / / / GPM 367 367 ES RPM 100 150 Solids 8.5 % Tabl~/Mtr / rprr / rprr / rpm I , " Pressure ] 3400 Sand tr % LGS 7.3 WOBMin/Max. 12 / 18 F¢ / Slow Pump Data Pit Vol. 700.0 16 16 16 1615 15 221515 12 Hole Vol1364.0 bbl Jets/TFA Slow P.S. 30 45 Filter 1/2 Calcium 40 ppm Bit Costs $5249.00 Cak(~ Daily Mud $ Total Mud $ Dull 4 6'""i BT! N I I I ''' SI°wP'P' 190 290 $3,141.00 $66552.00 Grade X I FC BNA BHA Description: Bit,lOBH F2000,xo, NM Stab, NMLC, NM Stab, MWD, NM Stab, 3xNMDC, NM Stab, NMD©, jars, 15 HWDP Jars=1417-1118 iBHA No: 7 IBHA Length: 705.5 JDate Last inspected: 1/1/92 J Hours On Jars: 111.75 Iniection Data Source: AGI-4 Volume: 611 Type Fluid: Mud Injection AGI-2 IRate: 3 IPressure: 500 Well;! ~pmJ psi Daily 61 1 J Cumulative 11682 Volume: bbl~ Volume: ..... 'Freeze Protect Fluid: Volume: gal Fuel & Water Data ... Fuel 4638 IFuel IFuel !Drl. wate'r IDrl' water Used: gal[Source: Peak 0 1 00 Veto Lake [Recv'd: gal Used: BBL Source: Cuttings Data Weather Data Daily: 50 C',~umulative: 394 c~St°'rage CC-2A Temp: l Wind Speed: I Chill Factor: 0 Site' J 3 oF 5 mph °F, personnel & Safetv/BOP Data , :Accident?(Y/N): N IName: IEmployer: ]RptFiled?(Y/N): PB Drlg: 2 IC0ntract°,: 26 ilService' 14 iother: 5 ITote': 47 Last BOPE Test: 1/11/93 Last BOP Drill: 12/27/92 Last H2S Drill: iLast Fire Drill: 12/26/92 Last Safety Mtg: 1/13/93 Last Spill Drill: 1/2/93 Spill (Y/N)? N Volume (Gals.): Type Spill: Report Filed? Time O~eration Prob Codel Hrs. Ooerations From 0600 to 0600 0600-1530 drill 9.50 Drilling to 10282. ROP very slow since 10215 &'angle still increasing. Just about ready to pull bit when washout developed-rapidly lost 1000 psi pump pressure. 1530-2015" prob ds 4.25 POOH wet looking for washout. Tight @+8700-8500. Found washout @ 40 std's + a single, at the lower end of the joint right where the internal upset area siarts.' POOH. 2015-2300 trip "2.75 C/O motor to 7-3/4" 1° BH w.11-1/4" sleeve;.change stab sleeves. Orient & test MWD. 2300-0015 trip 1.25 RIH. 0015-0115 rigs 1.00 Slip & cut 88' drilling line. 0115-0215 trip 1.00 RIH; hit tight spot @15 s{d's oot. (+8800)' 0215-0315 pr~)b th 1.00 Work pipe throUgh tight area for 8 stands (8800-9600). (~315-0330 trip 0.25 Finish RIH. 0330-0500 drill 1.50 Reaming to bottom w. +2-4k WOB. 0500-0600 drill 1.00 Drilling. " "' Prudhoe Bay Drillin~l' Dail Drillin~ Report AFE. No: 4J0195 ~pt. No: 13 Date: 1/14/93 Well Name: AGI-4 Supv. lint: JG/SW Page 2 Survey Data Surv. No. 42 Depth(MD) 10043 Angle 63.1 Direction 85.4 T.V.D. 7584 Vert. Sec. 4678 North/Soutl.,N 276 East/West E 4670 Dog Leg 0.4 0 Mud Lo,q Data Depth Mud Wt. Formation BG gas Conn gas Trip gas PPg U U U Max BGG Dc Exponent Shale density Est. pore press ROP/Shale ROP/Sand ,, .. L ~ ~h Time O~eration Prob Code Hrs, Operations From 0600to 0600 . , Prudhoe Bay Drilling AFE. No: 4J0195 IRpt. No: 14 IDate: , IDepth (MD/TVD): Well: AGI-4 !Ph°ne: Contractor: Audi 2 4605 Operation at 0600: POOH to run 9-5/8" Rig Accept (hr/date): 1/2/93 @ 0600 HRS Mud Mud TypoLSLD Weight 9.9 Viscosity 5 0 )ate MBT Pm 0.3 sec PV/YP 18 / 16 Gels 6 18 / APl W.L. 5.8 HTHP 19.4 1 O0 psi HTHP 500 psi ,., Solids 10.0 % ,. Sand tr % Hole Vol1519.0 bbli 25.0 9.6 Pf 0.3 Filter Cake 1/2 Daily Mud $ $7,585.OO Bit No. Size Make Type Mf Serial No. 1.2 Chlorides 800 ppm Oil Depth Out MD/TVD Footage DWR ART/AST / / ES / LGS 6.8 Pit Vol. 600.0 Calcium 40 ppm RPM Table/Mtr WOB Min/Ma>~, Jets/TFA Bit Costs Dull Grade 1/1 5/93 Days Since ,.,pud/Est: 10985 / 8065 IPrev (MD): I IDaily Costs: $71,398.00 I Last Csg: 13_3/8-@3538 i Next Csg (size/depth) (size) IRig Release(hr/date)' Bit !)ata 7 12.250 Hughes ATXCMG1 M65BR 10985 / 8065 / 7O3 ft. ft. 9.0 / / 8o 15o rprr / rprr / rpm / F¢ 5 / 45 KC / K~ 22151512 $5249.00 Total Mud $ $74137.00 Da. ily Drillinq Report, 13 I Supv. Init: JG/SW 1 0282 IPr°gress: 703 JEst Cum Costs: $1,172,959.00 ' 9-5/8"@1100o IShoe 12.0 EMW ]Test; Drilling Depth10985 P.U. 230 Wt Avg. 50 Drag Trq 3 2 0 Btm Data Rot 180 Wt. S.O. 150 Wt. Max 100 Drag Trq 280 Off PL mo Data Pump No. Liner Size SPM GPM Pressure 90 [ 90 318 I 318 3700 Slow Pump Data SIowP.S.I 30 J 45 BHA Description: Bit,lOBH F2000,xo, NM Stab, NMLC, NM Stab, MWD, NM Stab, 3xNMDC, NM Stab, NMDC, jars, 15 HWDP Jars=1417-1118 BHA No: 7 IBHA Length: 705.5 IDate Last Inspected: 1/1/92 Hours On Jars: Volume: 238 Type Fluid: Iniection Data Mud Injection AGI-2 IRate: 1 jPressure: Welt: ~pml Daily 238 I Cumulative Volume: bbl ! Volume: Freeze Protect Fluid: Volume: gal 450 11920 Source' AGI-4 121.75 Fuel 7034 IFuel Used: ga!,LSource: Cuttinqs Data Daily: 50 O.JCumulative:Y] 444 Fuel & Water Data Peak I Fuel 10004 I ! Recv'd: ,, gal[ Used: c ~ite: personnel & Safety/BOP Data I Employer: 26 IService: 14' iOther: .Drl. Water 1080 } Drl. Water BBL[ Source' Vern Lake Weather Data Wind Speed: SW24 mphJi Chill Factor: Accident? (Y/N): N IName: PB Drlg: 2 I Contractor: 5 I Last BOPE Test: 1/11/93 ILast BOP Drill: 12/27/921LastH2SDrill: ILastFireDrilh12/26/92 Last Spill Drill: 1/2/93 Ispill (Y/N)? N IVolume (Gals.): ~Type Spill: Operations From 0600 to 0600 0600-1730 drill Drilling to 10985. Launch ;o% hi-vis sweep before TD. -78 Rpt Filed? (Y/N): Total: 47 Last Safety Mtg: 1/13/93 Report Filed? 1730-1815 circ Finish pumping around sweep. 1815-2045 trip Short trip from -i'D to 8431. Stickey from 9210-9492. 2045-2230 circ Pump around another sweep. 2230-0030 trip Shod trip to 9022. No trouble this time. 0030-0230 circ CBU until shakers clean up. 0230-0600 trip POOH to run casing. Tight breaks. OF Prudhoe Bay Drillin, cj AFE. No: 4J0195 iHpt. No: Surv. No. Depth (MD) Angle Direction T.V.D. Vert. Sec. North/Soutt- East/West Dog Leg Depth Max BGG Tim~ ,'" Daily Drillinq Report j, 14 JDate: 1/15/93 IWell Name: AG,-4 ISupv' Init: JG/SW J Page 2 I43 I 44 J 45 / 46 ~ 4~ / Pr°jSirveyDaia J ! J I I I 102231104,,I ,o6o1 1079t 109115 10915 I I I I I I 1 E4831JE4998JE5164JE5319JE54191E54731 ! I ! I /'/ ! o6~ I~ ~ |~4 ~ ~ ' t''.!''i:' I~' / I,I I I I I I .... Mud Lo.q Data Operation Prob Code Hrs. 'Operations From 0600 to 060'0 Prudho¢ Bay Drilling Daily Drilling Report AFE. Noi 4J0195 Rpt. No: i5 Date:. 1 / 1 6/9 3 Days Since opud/Est: 1 4 Supv. Init: JG/SW Well: AGI-4 Depth (MD/TVD): 10985 , 8065 ]Prey (MD): 10985 !Pr°gress: 0 I I contractor: Audi2 Phone: 4605 IDa'lyc°sts: $482,227.00 IEst cum c°sts: $1,655,186.00 ]Last Csg: 13-3/8'@3'.38 ]Next Csg: 9_5'8-@~1cx)o IShoe Operation at 0600: Cementing 9-5/8" casing 12.0 EMW l(size/depthl, l(size) ITest: Rig Accept (hr/date): 1/2/93 @ 0600 HRS I Rig Release( hr/date): ! Mud [)ata Bit ~)ata 'Drillino Data ;Mud TypeLSLD MBT 27.5 Bit No. 7 Depth -Rot Wt. Weight 9.9 pH 9.5 Size 12.250 P.U. S.C. PP~ Wt. wt. Viscosity 54 Pm 0.3 Make Hughes Avg. Max sec Drao Draa PV/YP 18 / 16 Pf 0.2 Type ATXCMG1 Trq Trq- Btm Off Gels 6 / 18 Mf 1.2 Serial No. M65BR P[mo Data Depth Out Pump No. 1 2 APl W.L. 6.0 Chlorides 800 ppm MD/TVD / 10985 / 8065 / Liner Size 5.5" 5.5" HTHP lOll Footage 703 100 [:)si % ft. ft ft.SPM FITHP OWR ART/AST 9.0 !500 esi / / / / GPM SoliSs 10.0 ES' RPM 80 150 % Table/Mtr / rprr / rpm / rpm LGS WeB Pressure Sand tr % Min/Max. / Pit Vol. Slow Pump Data Hole Vol1430.0 bbl 300.0 Jets/TFA 22 15 15 12 Filter Calcium Bit Costs Slow P.S. I 40 $5249.00 Cake ppm $500.00 $74637.00 Grade E I NO BHA Description: BHA No: j BHA Length:. IDate Last Inspected: 1/1/92 IH°urs On oars: iniection Data Source: Volume: Type Fluid: In]ection AGI-2 IRate: IPressure: Well;! cjpmI psi Daily I Cumulative 11920 Volume: bblI Volume: Freeze Protect Fluid: Volume: gal Fuel & Water Data Fuel 7034 IFuel 1Fuel I Drl. Water I Drl. Water Used: gal[Source: Peak 0 300 Vern Lake _,. Recv'd' gal Used' BBL Source: Guttin.qs Dat~ Weather Data ,y~ /St°rage CC-2A Temp: IWind Speed: lChill Factor: .52 OF umulative: 464 C,~iSite: S9 mph Daily: 20 C -26 oF Personnel & Safety/BOP Data Accident?(Y/N): N IName: IEmployer: IRptFilod?(Y/N): PB Drlg: 2 I Contractor: 26 lService. 11 IOther: 5 IT°tal: 44 Last BOPE Test: 1/11/93 Last BOP Drill: 12/27/92Last H2S Drill: Last Fire Drill: 12/26/92 Last Safety Mtg' 1/13/93 Last Spill Drill: 1/2/93 Spill (Y/N)? N VolUme (Gals.): Type Spill: Report Filed? Time Oaeration Prob Codel Hrs. Ooerations From 0600 to 0600 0600-1000 trip 4.00 POOH & L/D BHA~ 1000-1100 bope 1.00 Pull wear bushing & change to 9-5/8" rams. 1100-2200 casg 11.00 R/U Weathedord & run 9-5/8", 47#, NTS80, NSCC csg. Circ volume of csg @ shoe. 2200-0030 prob th 2.50 Hole got progressively more sticky @ 10350 onwards. Worked pipe down to 10700. 0030-0145 prob efs 1.25 Csg elevators broke & egg-shaped a joint while working pipe. Installed new elevators & L/D bad joint (#272); substituted another one in the running order. 0145-0315 prob th 1.50 Worked casing to bottom; had to hook up circ hose a couple of times to flush hole. 0315-0530 casg 2.25 R/U Howco cmt head & circ 2 annular volumes while batch mixing cmt & injecting mud. 0530-0600 casg 0.50 Cementing casing. Will attempt to displace @ 12 bpm with seawater. nspected BHA after laying down-8 components needed shopping. Installing top drive today after running pipe in hole t° clear derrick. Should be moving by morning. Prudhoe Bay Drilling Daily Drillin0j R.ep0, rl;, Well: AGI-4 Depth(MD/TVD): 10985 / 8065 IPrev(MD): 10985 IPr°gress: 0 I I Contractor: Audi2 Phone: 4605 I Daily Costs: $88,832.00 lEst Cum Costs: $1,744,018.00 I ILast Csg: 95/8@1097~ INext Csg: 7 IShoe N/A operati°n at 0600: Rigging up top drive I(~ize/de..pth)~(size) ITest: ,,, Rig Accept (hr/date): 1/2/93 @ 0600 HRS i Rig Release(hr/date)' Mu8 ')ate Bit ~)ata Depth Drilling Data MUd TypeBRINE MBT i Bit No. Rot Wt. Weight 8.5 pH !Size P.U. S.C. pP~ Wt. Wt. VisCosity Pm ~Make iAvg. Max sec Drag Drar~ PV/yP pf Type i Trq Trq - / :Btm off Gels Mf ;Serial N'o. PL'mO Data / Pump No. 1 2 APl W.L. Chlorides Depth Out .,, ppm MD/I-VD / / / Liner Size 5.5" 5.5" HTHP Oil Footage .~ 100 p~j % ft. ff. ft.SPM HTHP OWR ART/AST 500 osi / / / / GPM SoliSs . . ;ES RPM l % Table/Mtr / rprr / rprr / rprr Pressure Sand LGS WOB % Min/Max. / K~ / ~ / F¢ .. , " Slow Pump Data !Hole Vol. Pit Vol. bbl Jets/TFA Slow P.S. Filter C'alcium Bit Cost~; "' !Cak~ ppm: Daily Mud $ Total Mud $ Dull $500.00 $75137.00 Grade !11 II II s,ow,.,. BHA Description: BHA No: I BHA Length: IDate Last Inspected: 1/1/92 IH°urs On Jars: , Iniection Data Source: AGI-4 Volume: 1405 Type Fluid' Mud Injection AGI-2 !Rate: 2 IPressure: 550 Well;! ~pmI .psi Daily 1405 I Cumulative 13325 Volume: ~blI Volume: Freeze Protect Fluid: Diesel Volume: 4200 gal Fuel & V~ater Data ,,. Fuel 12015 IFuel IFuel IDrl- Water IDrl' Water Used: gal[Source: Peak 10013 450 Vern Lake Recv'd: gal Used: BBL Source: " ........ L;uttin,~s Data Weatr,er Data DailY: 60 C~Umulative: 524 C~lSite:~St°rage CC-2A Temp:-24 oFIwind Speed: 1 6 mphiChillFact°r: '71 °F Personnel & Safety/BOP Data Accident?(Y/N): N IName: IEmpl°yer: iRptFiled?(Y/N): PB Drlg: 2 Jc°ntract°,: 26 IService: 12 IOther: 5 ITOtah 45 Last DOPE Test: 1/11/93 Last BOP Drill: 12/27/92 Last H2S Drill: Last Fire Drill: 12/26/92 Last Safety Mtg: 1/13/93 Last Spill Drill: 1/2/93 Spill (Y/N)? N Volume (Gals.): type Spill: Report Filed? Time Ooe}ation Prob Code Hrs. Ooerations From 0600 to 0600 0600-0800 casg 2.00 pump 20 bbl alpha preflush, F/W50 BBL ALPHA SPACER. pump 400 sax of premium cml f/w 5 bbl H20. switch to rig pumps and displace cmt W~ 792 bbl SW @12.8 bpm. , bumped plug w/200 psi & releaseed, floats held. cip @ 0745 hr. 0800-0845 casg "0.75 rig dn csg & cmt tools. 0845-1445 .prob wh 6.00 run 9 5/8 packoff ( stack a little'out of alignment )split stack set &test packoff 5000 psi. change rams to 5 ". lay down running tool. install wear bushing. 1445-1615 othr 1.50 inject 200 bbl mud down 9 5/8 x 13 3/8 down AGI-4, freeze protect w/100bbl w/dsl 1615-1945 trip 3.50 RIH 1945-0600 pr'ob efc 10.25 rig up top drive. ,., ,, ,., Prudhoe Bay Drilling -" , Daily Drillinq Report Well: AGI-4 Depth(MD/TVD): 10985 / 8065 IPrev(MD): 10985 !Pr°gress: 0 Contractor: Audi2 Phone' 4605 ! Daily Costs: $33,352.00 lEst Cum Costs: $1,777,370.00 ILast Csg: 95/8@ 10978 I Next Csg: 7 IShoe N/A !Operation at 0600: ,,, Released Rig l(size/depth) If size) ITest: 'Rig Accepi (hr/date): 1/2/93 @ 0600 'HRS I Rig Release( hr/date): 1800- 1- 17- 93 Mud Data Bit ')ati~ Drilling Data Rot !"Mud TypeBRiNE MBT Bit No. Depth 0 Wt. Weight 8.5 pH Size P.U. S.C. .. ~ .... Wt. Wt. Viscosity Pm Make Avg. Max se~ Bring Drao_ PV/YP pf Type Trq Trq / Btm Off Gels Mf Serial No. Pu 'ne Data / . Pump No. 1 2 APl W.L. Chlorides Depth Out ppm MD/TVD / / / Liner Size 5.5" 5.5" HTHP Oil Footage 100 psi % ft. ff- fi' SPM HTHP :DWR ART/AST ,500 psi / / / / GPM Solids ES IRPM % ' Table/Mtr / rprr / rpm / rprr S ~'nci i LGS WOB P ressu re % Min/Max, / KC / KC / Hole Vol. !Pit V°l. Slow Pump Data bbl Jets/TFA ~Slow P.S. IFilter Calcium Bit Costs ICake ppm Daily Mud $ Total Mud $ Dull BHA Desciiption: iniection Data , Source' Volume: Type Fluid: Injection AGI-2 !Rate: IPressure: Well; . bpm ..psi Daily I Cumulative 13325 Volume: bblI Volume: Freeze Protect Fluid' Volume: bbl Fuel& Water Data Fuel !Fuel Peak !Fuel 10015 allDrI' water IDr'' Water Used: gal[Source: Recv'd: g Used: BBL Source: Vern Lake cuttin.cjs Data Weather Data ~ ~ lWind Speed: [ Chill Factor: Storage CC-2A Temp: -32 °F mph D,~iiy: umulative: 524 C ~ite: . C 1 0 -61 Personnel & ~fety/BQp Data Aooident?(Y/N): N IName: IEmpl°yor: IRptFiIOd?(Y/N): PB Drlg: 2 I Contractor: 26 ISer,,~oo' 12 I°ther:,, 5 !T°tal: 45 Last BOPE Test: 1/11/93 Last BOP Drill: 12/27/92Last H2S Drill: Last Fire Drill: 1 2/26/92 ;Last Safety Mtg: 1/13/93 , Last Spill Drill: 1/2/93 Spill (Y/N)? N Volume (Gals.): Type SPill: Report Filed? 'Time Oaeration Prob Code Hrs. 0000-0700 EFC 1.00 Rig up top drive,Oaorati°ns From 0600 t° 0600 take on water & mix spud mud for AG.J-~,, 0700-0930 trip 2.50 POH wi5" DP to 2000 ft. ~'~ ~,~, -- 09'~0-1100 othr 1.50 Freeze protect top 2000 ft. w/diesel (150 bbl) ; 1100-1200 trip 1.00 POH 1200-1230 othr 0.50 Fill hole with diesel '¢¢~ 1230-1515 bope 2.75 Pull wear ring, nipple down BOPs 1515-1800 othr 2.75 Install dummy hanger, N U dry hole tree, test tree & hgr w/5000 psi. freeze protect tree. Install BPV and secure well. Released rig 1800 1 - 17 - 93 Had to pull tree cap off of tree to remove BPV; wrong-sized tree cap was installed when tree was assembled. New tree cap Will be installed after rig has moved off well. SUB- SURFACE DIRECTIONAL SURVEY UIDANCE ONTINUOUS OOL RECEIVED A U 6 ~ 6 199,~ Alaska Oil & Gas Cons. Cornmiss~°'~' Anchorage Company Well Name A6I-4 (1937' FSL, 2432' FEL, SEC 36, T12N, R14E) Field/Location p~UDHO£ BAY, ~ORTH SLOPE, ALASKA Job Reference No~. 7-MAY-93 -- 93217 C_omputed BVL. Loqcled BVL. SINES SARBER . SCHLUMBERGER * GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO AGI-4 PRUDHOE BAY NORTH SLOPE, ALASKA SURVEY DATE' 7-MAY-1993 ENGINEER' SARBER METHODS OF COMPUTATION TOOL LOCATION: MINIMUM CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST, PROJECTED ONTO A TARGET AZIMUTH OF NORTH 87 DEG lO MIN EAST COMPUTATION DATE' 25-MAY-93 PAGE ARCO AGI-4 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' 7-MAY-1993 KELLY BUSHING ELEVATION' 49.00 FT ENGINEER' SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG BIN DEG BIN 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700.00 800.00 900.00 0 O0 99 87 199 87 299 87 399 87 499 87 599 87 699 87 799 87 899 87 -49.00 50.87 150.87 250 87 350 87 45O 87 550 87 650 87 750 87 85O 87 0 0 N 0 0 E 0 5 N 75 45 E 0 5 S 80 25 E 0 4 N 46 23 E 0 5 N 39 46 E 0 7 N 83 28 E 0 7 S 69 59 E 0 7 N 89 29 E 0 9 S 66 43 E 0 8 S 74 52 E VERTICAL DOGLEG RECTANGULAR COORDINATES h0rIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG BIN 0 O0 0 08 0 31 0 43 0 49 0 62 0 83 '0 99 I 22 1.41 0 O0 0 10 0 16 0 12 0 11 0 10 0 09 0 O7 0 77 0 12 0 O0 N 0 02 N 0 05 N 0 04 N 0 13 N 0 22 N 0 16 N 0 15 N 0 10 N 0 04 N 0 O0 E 0 O8 E 0 31E 0 43 E 0 49 E 0 61E 0 83 E 0 98 E I 22 E 1 40 E 0 O0 N 0 0 E O9 N 75 25 E 31 N 81 15 E 43 N 84 39 E 51 N 74 38 E 64 N 70 12 E 84 N 78 47 E 99 N 81 16 E 22 N 85 29 E 41 N 88 20 E 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 999.87 950.87 O0 1099.87 1050.87 O0 1199.87 1150.87 O0 1299.87 1250.87 O0 1399 87 1350.87 O0 1499 86 1450.86 O0 1599 86 1550.86 O0 1699 86 1650.86 O0 1799 86 1750.86 O0 1899 85 1850.85 0 10 S 63 34 E 0 16 S 67'17 E 0 24 S 67 10 E 0 26 S 68 26 E 0 24 S 72 49 E 0 21 S 65 46 E 0 19 S 77 13 E 0 2O S 74 32 E 0 40 S 75 34 E o 44 S 69 10 E 1 69 1 95 2 46 3 10 3 77 4 4 5 6 7 34 87 33 13 32 0 11 0 16 0 17 0 14 0 11 0 16 0 10 0 5O 0 32 0 24 007S 0 19 S 0 41 S 0 65 S 0 92 S 1 13 S 1 34 S 1 44 S 1 65 S 2 04 S 1 69 E 1 96 E 248 E 3 13 E 3 82 E 4 40 E 4 94 E 5 41 E 6 22 E 7.43 E 1 69 S 87 38 E 97 S 84 29 E 52 S 80 42 E 20 S 78 14 E 93 S 76 27 E 55 S 75 34 E 12 S 74 48 E 59 S 75 4 E 44 S 75 10 E 71 S 74 39 E 2000.00 1999 84 1950.84 2100.00 2099 2200.00 2199 2300 O0 2299 2400 O0 2399 2500 O0 2499 2600 O0 2599 27OO O0 2699 2800 2900 83 2050.83 82 2150.82 82 2250.82 81 2350.81 79 2450.79 78 2550.78 77 2650.77 O0 2799.76 2750.76 O0 -2899.75 2850.75 3000 O0 2999.74 2950.74 3100 3200 3300 340O 3500 3600 3700 3800 3900 O0 3099.73 3050.73 O0 3199.72 3150.72 O0 3299.71 3250.71 O0 3399.71 3350.71 O0 3499.70 3450.70 O0 3599.70 3550.70 O0 3699.63 3650.63 O0 3799.11 3750.11 O0 ' 3898.15 3849.15 0 47 S 60 32 E 0 45 S 62 45 E 0 46 S 77 2 E 0 44 N 89 14 E 0 57 N 81 23 E i 1 N 83 47 E 0 44 S 87 25 E 0 44 S 75 50 E 0 52 S 61 54 E 0 55 S 51 56 E 0 46 S 45 11E 0 44 S 49 I E 0 47 S 51 25 E 0 42 S 48 55 E 0 32 S 45 11E 0 28 S 41 I E 0 31 S 54 32 E 4 2 N 71 38 E 7 17 N 73 56 E 8 42 N 79 10 E 8.48 9.59 10.77 12.02 13.43 15.18 16.77 18.01 19.28 20.54 21.55 22.45 23.41 24.35 25.07 25.65 26.14 29.34 38.96 52.57 0 18 0 16 0 18 0 29 0 23 0 60 0 25 0 27 0 26 0 23 0.22 0.08 0.71 0.13 0.16 0.10 0.17 2.36 3,90 2.11 257S 3 21 S 3 74 S 3855 371 S 3 515 3 38 S 3 57 S 4085 4 95 S 589 S 6 77 S 7 62 S 8 46 S 9 16 S 9 80 S 10 35 S 9 91 S 6 71 S 3 515 8 61 E 9 76 E 10 97 E 12 23 E 13 63 E 15 38 E 16 96 E 18 21 E 19 51 E 20 81 E 21.87 E 22.81 E 23.81 E 24 8O E 25 56 E 26 17 E 26 69 E 29 87 E 39 34 E 52 81 E 8 99 S 73 22 E 10 11 12 14 15 17 18 19 21 28 S 71 47 E 58 S 71 11E 82 S 72 30 E 12 S 74 47 E 77 S 77 8 E · 30 S 78 43 E 55 S 78 54 E 93 S 78 12 E 39 S 76 37 E 22 65 S 74 56 E ~,--"'- 23 79 S 73 29 E ~ ~ 25 O0 S 72 15 E :~- ~ 26 20 S 71 10 E _,o ~. 27 15 S 70 17 E ~ ~ 27 94 S 69 28 E ~ - co 28 62 S 68 48 E c_ 31.47 S 71 39 E 39.91 S 80 19 E 52 92 S 86 12 E co . GO. COMPUTATION DATE' 25-MAY-93 PAGE 2 ARCO AGI-4 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' 7-MAY-1993 KELLY BUSHING ELEVATION' 49.00 FT ENGINEER' SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG WIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/300 FEET FEET FEET DEG MIN 4000 O0 3996 75 3947 75 10 54 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 4094 O0 4191 O0 4287 O0 4381 O0 4473 O0 4564 O0 4654 O0 4743 O0 4831 67 4045 97 4342 65 4238 46 4332 87 4424 81 4515 77 4605 49 4694 05 4782 N 84 10 E 67 12 21 N 84 0 E 97 14 54 N 82 6 E 65 18 38 N 82 24 E 46 21 38 N 85 21 E 87 23 23 N 86 22 E 81 25 29 N 85 20 E 77 26 27 N 86 18 E 49 28 17 N 87 7 E 05 29 30 N 87 59 E 69 12 89 37 112 33 141 23 175 75 213 95 255 49 299 17 345 28 393 58 2 O4 I 34 1 69 3 15 3 O3 2 47 1 69 1 7O 1.44 0 94 S 0 3 7 11 13 17 20 23 24 87 N 89 69 N 112 61N 141 31N 175 95 N 213 13 N 254 28 N 298 05 N 344 87 N 392 44 E 89 29 E 112 02 E 141 40 E 175 53 E 213 96 E 255 53 E 299 56 E 345 83 E 393 69 25 E 69 26 S 89 13 E 44 N 89 27 E 35 N 88 7 E 23 N 86 55 E 77 N 86 19 E 98 N 86 16 E 53 N 86 9 E 22 N 86 7 E 33 N 86 10 E 61 N 86 23 E 5000 O0 4917 41 4868.41 31 32 ,5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 5000 O0 5078 O0 5154 O0 5228 O0 5300 O0 5367 O0 5430 O0 5488 O0 5544 33 4951.33 36 17 83 5029.83 39 57 52 5105.52 41 43 26 5179.26 43 13 03 5251.03 45 29 91 5318.91 49 25 40 5381.40 52 55 60 5439.60 55 42 27 5495.27 56 42 N 86 54 E N 85 28 E N 86 34 E N 86 4O E N 86 26 E N 85 28 E N 84 13 E N 83 50 E N 83 5O E N 84 39 E 1079 443 97 499 78 561 68 627 03 694 56 764 17 837 51 915 44 996 59 55 1 59 2 38 3 O2 3 29 2 69 2 02 2 58 3 22 3 57 0 68 27 14 N 443.17 E 444 O0 N 86 30 E 31 35 39 43 48 54 62 71 79 07 N 498.86 E 499 45 N 560.61 E 561 08 N 625,87 E 627 14 N 693.28 E 694 O0 N 762.73 E 764 50 N 835.84 E 837 74 N 913.45 E 915 51N 994.27 E 996 93 N 1076.92 E 1079 82 N 86 26 E 73 N 86 23 E 08 N 86 26 E 62 N 86 26 E 24 N 86 24 E 62 N 86 16 E 60 N 86 4 E 84 N 85 53 E 88 N 85 45 E 6000 O0 5598 18 5549 18 57 40 6100 O0 5651 6200 O0 5701 6300 O0 5749 6400 O0 5795 6500 O0 5841 6600 O0 5889 67OO O0 5938 6800.00 5986 6900.00 6035 11 5602 11 58 34 67 5652 67 60 53 10 5700 10 62 22 15 5746 15 62 37 21 5792 21 62 24 24 5840.24 60 38 20 5889.20 60 42 87 5937.87 61 3 15 5986.15 61 14 N 85 4 E 1163 71 N 85 36 E 1248 N 86 10 E 1334 N 86 41E 1422 N 86 44 E 1511 N 87 0 E 1600 N 87 23 E 1688 N 87 2O E 1775 N 87 19 E 1862 N 87 21E 1950 51 75 77 54 3O O0 19 55 12 .94 . O0 .43 .51 .08 .05 .88 .92 .26 87.26 N 1160 82 E 1164 09 N 85 42 E 94.28 N 1245 100.43 N 1331 lOS 86 N 1419 110 92 N 1507 115 89 N 1596 120 07 N 1684 124 14 N 1771 128 20 N 1858 132 29 N 1945 37 E 1248 41E 1335 28 E 1423 90 E 1511 52 E 1600 13 E 1688 23 E 1775 49 E 1862 97 E 1950 93 N 85 4O E 2O N 85 41E 22 N 85 44 E 97 N 85 48 E 73 N 85 51E 4O N 85 55 E 57 N 85 59 E 91 N 86 3 E 46 N 86 7 E 7000 O0 6083 15 6034.15 61 26 7100 7200 7300 7400 7500 7600 7700 '7800 7900 O0 6130 83 6081.83 61 41 O0 6178 12 6129.12 61 48 O0 6225 58 6176.58 61 4 O0 6274 76 6225.76 60 23 O0 6324 18 6275.18 60 27 O0 6373 92 6324.92 60 11 O0 6423.74 6374.74 60 O0 6473.85 6424.85 59 56 O0 6524.24 6475.24 59 58 N 87 17 E 2037 85 N 87 22 E 2125 75 N 87 23 E 2213 86 N 86 50 E 2301 88 N 86 27 E 2388 94 N 86 28 E 2475 87 N 86 32 E 2562.62 N 86 36 E 2649.32 N 86 33 E 2735.85 N 86 38 E 2822.23 0 21 0 23 0 22 0 30 0 58 0 57 0 70 0 37 0 34 0 48 136.32 N 2033.60 E 2038 16 N 86 10 E 140.42 N 2121.41 E 2126 05 N 86 13 E 144.42 N 2209.42 E 2214 14 N 86 16 E 148.59 N 2297.35 E 2302 15 N 86 18 E 153.96 N 2384 25 E 2389 21 N 86 18 E 159.26 N 2471 02 E 2476 15 N 86 19 E 164.50 N 2557 62 E 2562.90 N 86 19 E 169.77 N 2644 16 E 2649.61 N 86 20 E 174.89 N 2730 55 E 2736.14 N 86 20 E 179.92 N 2816 78 E 2822.52 N 86 21 E COMPUTATION DATE: 2S-MAY-93 PAGE 3 ARCO AGI-4 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' 7-MAY-1993 KELLY BUSHING ELEVATION' 49.00 FT ENGINEER' 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 8000 O0 6574 33 6525 33 59 50 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 6624 O0 6675 O0 6725 O0 6775 O0 6826 O0 6877 O0 6928 O0 6979 O0 7030 57 6575 57 59 51 01 6626 O1 59 41 45 6676 45 59 43 92 6726 92 59 37 61 6777 61 59 26 51 6828 51 59 23 46 6879.46 59 18 61 6930.61 59 15 58 6981.58 59 27 N 86 33 E 2908 77 N 86 35 E 2995 N 86 37 E 3081 N 86 37 E 3167 N 86 34 E 3254 N 86 33 E 3340 N 86 34 E 3426 N 86 35 E 3512 N 86 33 E 3598 N 86 36 E 3684 23 57 91 24 44 51 55 48 51 0 53 0 42 0 35 0 15 0 12 0 11 0 11 0 12 0 12 0 13 185.12 N 2903 17 E 2909 07 N 86 21 E 190.29 N 2989 195.41N 3075 200.48 N 3161 205.58 N 3248 210.72 N 3334 215.90 N 342O 221.01 N 3505 226.14 N 3591 231.27 N 3677 48 E 2995 68 E 3081 87 E 3168 05 E 3254 10 E 334O O2 E 3426 91E 3512 69 E 3598 57 E 3684 53 N 86 23. E 88 N 86 22 E 22 N 86 22 E 55 N 86 23 E 76 N 86 23 E 83 N 86 23 E 87 N 86 24 E 81 N 86 24 E 84 N 86 24 E 9000 O0 7081 13 7032 13 59 51 9100 9200 9300 9400 9500 9600 9700 9800 9900 O0 7131 O0 7180 O0 7229 O0 7277 O0 7324 O0 7371 O0 7418 O0 7464 O0 7511 O5 7O82 35 7131 O1 7180 02 7228 65 7275 82 7322 43 7369 95 7415 20 7462 05 60 13 35 60 39 O1 61 6 02 61 26 65 61 41 82 62 2 43 62 23 95 62 13 20 62 36 N 86 32 E 3770.79 N 86 28 E 3857.43 N 86 23 E 3944..42 N 86 16 E 4031 78 N 86 6 E 4119 49 N 85 59 E 4207 40 N 85 51 E 4295 55 N 85 38 E 4384 O0 N 85 34 E 4472 48 N 85 24 E 4561 11 0 22 0 29 0 36 0 43 0 43 0 39 0 36 0 35 0 33 0 45 236 45 N 3763 70 E 3771 12 N 86 24 E 241 247 252 258 264 27O 277 284 291 74 N 3850 15 N 3937 72 N 4024 54 N 4111 56 N 4199 84 N 4287 43 N 4375 2O N 4463 19 N 4552 19 E 3857 O2 E 3944 21E 4O32 74 E 4119 46 E 4207 41E 4295 64 E 4384 89 E 4472 28 E 4561 77 N 86 24 E 77 N 86 24 E 13 N 86 24 E 86 N 86 24 E 78 N 86 24 E 95 N 86 23 E 42 N 86 22 E 93 N 86 21 E 59 N 86 20 E 10000 O0 7556 76 7507 76 63 5 10100 10200 10300 10400 10500 10600 10700 10800 10900 O0 7601 O0 7646 O0 7690 O0 7736 O0 7785 O0 7836 O0 7891 O0 7948 O0 8008 80 7552 16 7597 25 7641 66 7687 29 7736 79 7787 37 7842 21 7899 47 7959 80 63 28 16 63 55 25 63 18 66 61 32 29 60 11 79 57 49 37 55 59 21 54 25 47 51 37 N 85 21 E 4650.08 N 85 23 E 4739.32 N 85 13 E 4828.90 N 85 21 E 4918.60 N 85 1 E 5007.12 N 84 36 E 5094.42 N 84 44 E 5180.05 N 85 8 E 5263.76 N 86 4 E 5346.00 N 86 8 E 5425.78 0 46 0 43 0 44 0 45 0 87 1 21 1 77 1 87 1 72 2 O9 298 36 N 4641 O1E 4650 59 N 86 19 E 3O5 312 32O 327 335 343 351 357 362 52 N 4730 85 N 4819 29 N 4908 67 N 4997 62 N 5084 63 N 5169 12 N 5252 46 N 5334 81N 5414 01E 4739 33 E 4829 78 E 4919 04 E 5007 05 E 5095 39 E 5180 83 E 5264 86 E 5346 47 E 5426 86 N 86 18 E 47 N 86 17 E 21 N 86 16 E 77 N 86 15 E 12 N 86 13 E. 80 N 86 12 E 56 N 86 11E 82 N 86 10 E 61 N 86 10 E 11000.00 8071.54 8022.54 50 43 11100.00 8134.87 8085.87 50 28 11200.00 8198.64 8149.64 50 21 11300.00 8262.62 8213.62 50 6 11400.00 8326.52 8277.52 50 17 11500.00 8390.29 8341.29 50 13 11600.00 8454.54 8405.54 49 37 11655.00 8490.29 8441.29 49 37 N 86 34 E 5503 37 N 86 20 E 5580 76 N 86 14 E 5657 78 N 86 9 E 5734 62 N 85 58 E 5811 53 N 85 52 E 5888 54 N 85 45 E 5965 14 N 85 45 E 6007 02 2 31 1 63 0 88 0 31 0 27 0 31 0 02 0 O0 367 57 N 5491 92 E 5504.21 N 86 10 E 372 44 N 5569 16 E 5581.60 N 86 10 E.; 377 37 N 5646 03 E 5658.63 N 86 11E~ 382 45 N 5722 72 E 5735.49 N 86 11 387 74 N 5799 46 E 5812.40 N 86 11 393 08 N 5876 30 E 5889.43 N 86 10 E 398 69 N 5952 72 E 5966.05 N 86 401 80 N 5994 50 E 6007.95 N 86 10 E · COMPUTATION DATE: 2S-MAY-g3 PAGE 4 arco AGI-4 PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY: 7-MAY-1993 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN iO00 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 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 9000 0 O0 O0 999 O0 1999 O0 2999 O0 3996 O0 4917 O0 5598 O0 6083 O0 6574 O0 7081 87 950 84 1950 74 2950 75 3947 41 4868 18 5549 15 6034 33 6525 13 7032 -49 O0 0 0 87 0 10 84 0 47 74 0 46 75 10 54 41 31 32 18 57 40 15 61 26 33 59 50 13 59 51 n 0 0 E 0.00 S 63 34 E 1.69 S 60 32 E 8.48 S 45 11 E 21.,55 N 84 10 E 69 12 N 86 54 E 443 97 N 85 4 E 1163 71 N 87 17 E 2037 85 N 86 33 E 2908 77 N 86 32 E 3770 79 O. O0 0 11 0 18 0 22 2 04 1 59 0 94 0 21 0 53 0 22 0 O0 N 0 2 5 0 27 87 136 185 236 000 E 07 S 1 57 S 8 89 S 21 94 S 69 14 N 443 26 N 1160 32 N 2033 12 N 2903 45 N 3763 69 E 1 61E 8 87 E 22 25 E 69 17 E 444 82 E 1164 60 E 2038 17 E 2909 70 E 3771 0 O0 N 0 0 E 69 S 87 38 E 99 S 73 22 E 65 S 74 56 E 26 S 89 13 E O0 N 86 30 E 09 N 85 42 E 16 N 86 10 E 07 N 86 21E 12 N 86 24 E 10000.00 7556.76 7507.76 63 5 11000.00 8071.54 8022.54 50 43 11655.00 8490.29 8441.29 49 37 N 85 21 E 4650.08 N 86 34 E 5503.37 N 85 45 E 6007.02 0.46 2.31 O. O0 298.36 N 4641.01 E 4650.59 N 86 19 E 367.57 N 5491.92 E 5504.21 N 86 10 E 401.80 N 5994.50 E 6007.95 N 86 10 E COMPUTATION DATE' 2S-MAY-93 PAGE 5 ARCO AGI-4 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' 7-MAY-1993 KELLY BUSHING ELEVATION' 49.00 FT ENGINEER' 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 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 13 149 13 249 13 349 13 449 13 549 13 649 13 749 13 849 13 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 N B1 31 E 100.00 0 11 N 81 4 E 200.00 0 5 S 77 35 E 300.00 0 4 N 18 9 E 400.00 0 5 N 50 8 E 500.00 0 8 S 72 39 E 600.00 0 4 S 89 59 E 700.00 0 9 S 77 52 E 800.00 0 5 S 73 25 E 0 O0 0 01 0 21 0 37 0 46 0 54 0 72 0 91 I 10 I 31 0 O0 0 O0 0 13 0 14 0 09 0 09 0 09 0 09 0 09 0 41 0 O0 N 0 O0 N 0 05 N 0 03 N 0 09 N 0 19 N 0.20 N 0.14 N 0.14 N 0.06 N 0 O0 E 0 01 E 021 E 0 37 E 045 E O54 E 072 E 0 90 E 1 10 E 1 31 E 000 N 0 0 E 01 N 84 13 E 21 N 77 28 E 37 N 85 41E 46 N 79 2O E 57 N 7O 57 E 74 N 74 3 E 91 N 81 2 E 10 N 82 41E 31 N 87 22 E 949 13 1049 1149 1249 1349 1449 1549 1649 1749 1849 949.00 900.00 13 1049.00 1000.00 13 1149.00 1100.00 13 1249.00 1200.00 13 1349.00 1300.00 13 1449.00 1400.00 14 1549.00 1500.00 14 1649.00 1600.00 14 1749.00 1700.00 15 1849.00 1800.00 0 12 S 7O 26 E 0 7 S 66 46 E 0 19 S 68 28 E 0 24 S 7O 55 E 0 26 S 65 26 E 0 19 S 69 27 E 0 20 S 66 54 E 0 13 S 83 8 E 0 27 S 75 56 E 0 44 S 72 47 E I 54 I 79 2 17 2 76 3 43 4 05 4 60 5 09 5 64 6 71 0 13 0 12 0 18 0 13 0 12 0 13 0 13 0 79 0 27 0 3O 0 O0 S 0 12 S 0 29 S 0 51S 0 80 S 1 O1S 1 25 S 1 38 S I 52 S 1 82 S 1 54 E 1 80 E 2 19 E 2 79 E 3 48 E 4 11 E 4 67 E 5 16 E 5 72 E 6 81 E 1 54 S 89 58 E 80 S 86 15 E 21 S 82 34 E 83 S 79 33 E 57 S 77 0 E 23 S 76 9 E 83 S 75 4 E 34 S 75 2 E 92 S 75 9 E 05 S 75 I E 1949 15 1949 O0 1900.00 2049 2149 2249 2349 2449 2549 2649 2749 2849 16 2049 17 2149 18 2249 19 2349 2O 2449 22 2549 23 2649 23 2749 24 2849 O0 2000 O0 O0 2100 O0 O0 2200 O0 O0 2300 O0 O~ 2400 O0 O0 2500 O0 O0 2600 O0 O0 2700 O0 O0 2800 O0 2949.26 2949.00 2900.00 3049.27 3049 O0 3000.00 3149.27 3149 O0 3100 O0 3249.28 3249 O0 3200 O0 3349.29 3349 O0 3300 O0 3449.29 3449 O0 3400 O0 3549.30 3549 O0 3500 O0 3649.31 3649 O0 3600 O0 3749.55 3749.00 3700.00 3850.33 3849.00 3800.00 0 45 S 68 56 E 0 46 S 6O 4 E 0 46 S 64 36 E 0 43 S 85 29 E 0 48 N 82 53 E 1 1 N 83 35 E 0 55 N 84 40 E 0 43 S 81 43 E 0 48 S 68 44 E 0 56 S 55 53 E 0 47 S 48 18 E 0 43 S 46 59 E 0 45 S 49 3O E 0 45 S 49 39 E 0 36 S 46 17 E 0 31 S 43 57 E 0 24 S 39 25 E 1 35 N 86 48 E 5 43 N 70 8 E 7 55 N 76 24 E 7 89 9 O2 10 16 11 37 12 66 14 28 16 04 17 39 18 63 19 91 21 08 21 99 22 23 24 25 25 26 33 45 91 88 74 37 89 89 39 49 0 14 0 18 0 12 0 29 0 26 0 41 0 33 0 28 0 19 0 28 0 27 0 2O 0 O8 0 4O 0 15 0 14 0 11 0 86 3.38 2.82 2.27 S 2.89 S 3.51 S 3.83 S 3.81 S 3.62 S 3.43 S 3.44 S 3.77 S 4.48 S 5.41 S 6.34 S 7.19 S 8.04 S 8.82 S 9.48 S 10.08 S 10.49 S 8.48 S 5.02 S 8 O1 E 9 18 E 10 34 E 11 58 E 12 87 E 14 48 E 16 23 E 17 58 E 18 84 E 20 16 E 21 37 E 22 33 E 23 30 E 24 31E 25 21E 25 87 E 26 42 E 27 44 E 33 85 E 45 79 E 8 32 S 74 12 E 9 10 12 13 14 16 17 19 62 S 72 3O E 92 S 71 15 E 19 S 71 42 E 42 S 73 31 E 92 S 75 59 E 59 S 78 5 E 92 S 78 55 E ---: 21 S 78 41 E ~, ~ 20 65 S 77 29 E ~3~ c~ G'~ 22 05 S 75 47 E ~ ~ 23 21 S 74 10 E 24 38 S 72 52 E 25 6O S 71 42 E 26 7O S 7O 43 E 27 55 S 69 52 E 28 27 S 69 7 E 29 38 S 69 5 E 34.90 S 75 56 E 46.07 S 83 45 E COMPUTATION DATE' 25-MAY-93 PAGE 6 ARCO AGI-4 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' 7-MAY-1993 KELLY BUSHING ELEVATION- 49.00 FT ENGINEER' SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG giN DEG giN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIgUTH FEET DEG/IO0 FEET FEET FEET DEG giN 3951 50 3949 O0 3900.00 4053 4155 4259 4365 4472 4582 4693 4806 492O 9 29 30 4049 71 4149 35 4249 17 4349 96 4449 49 4549 56 4649 26 4749 66 4849 O0 4000.00 11 46 O0 4100 O0 13 13 O0 4200 O0 17 19 O0 4300 O0 20 50 O0 4400 O0 22 51 O0 4500 O0 25 18 O0 4600 O0 26 20 O0 4700 O0 28 21 O0 4800 O0 29 43 N 80 39 E N 85 27 E N 82 52 E N82 16E N 84 25 E N 86 21 E N 85 13 E N 86 17 E N87 16 E N 87 43 E 60 61 79 61 101 63 128 67 163 14 203 34 247 98 296 30 348 25 403 81 1 58 1 25 1 41 2 26 2 97 3 16 2 63 1 71 1 69 1 42 2 10 S 0 2 5 10 13 16 2O 23 25 05 S 79 28 N 101 93 N 128 19 N 162 27 N 202 51N 247 10 N 295 19 N 347 27 N 403 71E 79 65 E 101 54 E 128 83 E 163 94 E 2O3 47 E 248 67 E 296 53 E 348 05 E 403 60 79 E 60 82 S 88 1 E 71 S 89 58 E 67 N 88 43 E 67 N 87 21E 15 N 86 25 E 37 N 86 16 E 02 N 86 11E 35 N 86 7 E 31 N 86 11E 84 N 86 25 E 5037 44 4949 O0 4900 O0 33 23 5161 5292 5428 5571 5731 5908 6095 6299 6516 38 5049 O0 5000 62 5149 O0 5100 54 5249 O0 5200 28 5349 O0 5300 20 5449 O0 5400 69 5549 O0 5500 95 5649 O0 5600 78 5749.00 5700 82 5849.00 5800 N 86 4 E O0 38 55 N 86 3 E 537 O0 41 35 N 86 43 E 622 O0 43 36 N 86 15 E 714 O0 47 58 N 84 40 E 815 O0 53 51 N 83 48 E 940 O0 66 51 N 84 44 E 1086 O0 58 32 N 85 34 E 1245 O0 62 22 N 86 41 E 1422 O0 62 9 N 87 10 E 1615 464 06 16 13 16 92 43 84 O6 58 21 .89 .81 .27 .42 14 35 71 99 53 99 28 38 N 463 22 E 464 09 N 86 30 E 33 38 44 52 65 80 94 105 116 86 N 536 80 N 620 38 N 712 39 N 814 44 N 938 59 N 1084 02 N 1241 85 N 1419 14 E 537 97 E 622 84 E 714 32 E 816 35 E 940 18 E 1087 93 E 1245 08 E 1423 67 N 1611.41E 1615 21 N 86 23 E 18 N 86 25 E 22 N 86 26 E O1 N 86 19 E 63 N 86 1E 17 N 85 45 E 48 N 85 4O E 02 N 85 44 E 63 N 85 52 E 6722 10 5949.00 5900 O0 60 47 6928 7138 7347 7550 7750 7949 8148 8346 8544 79 6049 O0 6000 37 6149 87 6249 O1 6349 41 6449 51 6549 48 6649 69 6749 02 6849 O0 6100 O0 6200 O0 6300 O0 6400 O0 6500 O0 6600 O0 6700 O0 6800 O0 61 16 O0 61 47 O0 60 18 O0 60 6 O0 59 54 O0 59 57 O0 59 39 O0 59 42 O0 59 24 N 87 20 E 1794 48 N 87 24 E 1975 N 87 25 E 2159 N 86 16 E 2343 N 86 33 E 2519 N 86 37 E 2692 N 86 30 E 2865 N 86 36 E 3037 N 86 37 E 3208 N 86 32 E 3378 36 55 63 28 94 10 11 22 33 0 88 0 22 0 23 0 53 0 63 0 34 0 55 0.40 0.12 0.12 125.03 N 1790.49 E 1794 85 N 86 0 E 133.44 N 1971 18 E 1975 141.96 N 2155 151.09 N 2339 161.89 N 2514 172.33 N 2687 182.48 N 2859 192.78 N 3031 202.85 N 3202 213.00 N 3371 17 E 2~59 03 E 2343 36 E 2519 71E 2693 57 E 2865 29 E 3037 12 E 3208 93 E 3378 69 N 86 8 E 84 N 86 14 E 90 N 86 18 E 56 N 86 19 E ~ 23 N 86 20 E % 39 N 86 21E ~ 41 N 86 22 E 53 N 86 23 E 65 N 86 23 E 8740 18 6949 O0 6900 O0 59 14 8936 9136 9341 9551 9765 9982 10206 10425 10622 31 7049 26 7149 51 7249 47 7349 78 7449 85 7549 47 7649 74 7749 82 7849 O0 7OOO O0 59 35 O0 7100 O0 60 25 O0 7200 O0 61 18 O0 7300 O0 61 51 O0 7400 O0 62 12 O0 7500 O0 63 6 O0 7600.00 63 56 O0 7700.00 61 13 O0 7800.00 57 22 N 86 36 E 3547.09 N 86 34 E 3715.79 N 86 28 E 3888.93 N 86 12 E 4068.15 N 85 56 E 4252.73 N 85 36 E 4442.22 N 85 21 E 4634.79 N 85 13 E 4834.71 N 84 52 E 5029.69 N 84 46 E 5199.31 0.13 0.17 0.32 0.44 0 38 0 34 0 47 0 44 0 94 1 83 223 06 N 3540 39 E 3547.41 N 86 24 E 233 243 255 267 281 297 313 329 13 N 3708 69 N 3881 11N 4060 76 N 4244 87 N 4433 12 N 4625 33 N 4825 67 N 5019 345.40 N 5188 81 E 3716 13 N 86 24 E 63 E 3889 27 N 86 24 E 51 E 4068 52 N 86 24 E 69 E 4253 13 N 86 23 E 71 E 4442 66 N 86 22 E 76 E 4635 30 N 86 19 E 12 E 4835 28 N 86 17 E 54 E 5030.35 N 86 15 E 58 E 5200.07 N 86 11 E COMPUTATZON DATE: 2S-MAY-93 PAGE 7 ARCO AGI-4 PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY: 7-MAY-1993 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE BEASURED VERTICAL VERTICAL DEVIATION AZIBlJTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIBlJTH DEPTH DEPTH DEPTH DEG BIN DEC BIN FEET DEC/lOC FEET FEET FEET DEG BIN 10801 36 7949.00 7900 O0 54 23 N 86 5 E 5347 11 10964 38 8049.00 8000 O0 50 43 N 86 38 E 5475 80 11122 20 8149.00 8100 O0 50 27 N 86 17 E 5597 87 11278 75 8249.00 8200 O0 50 10 N 86 12 E 5718 31 11435 25 8349.00 8300 O0 50 27 N 86 1 E 5838 67 11591 42 8449.00 8400 O0 49 44 N 85 41 E 5958 59 11655 O0 8490.29 8441 29 49 37 N 85 45 E 6007 02 1 72 2 34 1 45 0 31 0 27 0 71 0 O0 357.54 N 5335.96 E 5347 93 N 86 10 E 365.94 N 5464.40 E 5476 64 N 86 10 E 373.55 N 5586.24 E 5598 72 N 86 10 E 381.37 N 5706.44 E 5719 17 N 86 11 E 389.63 N 5826.53 E 5839 55 N 86 10 E 398.20 N 5946.18 E 5959 50 N 86 10 E 401.80 N 5994.50 E 6007 95 N 86 10 E RECEIVED AU G G 199,3 Aiaska 0il & Gas Cons. Cornm~'ss~°~ Anchorage ARCO AGI-4 PRUDHOE BAY NORTH SLOPE, ALASKA MARKER GCT LAST READING TD COMPUTATION DATE' 25-MAY-93 DATE OF SURVEY' KELLY BUSHING ELEVATION' ENGINEER' PAGE 8 ?_MAY-1993 49.00 FT SARBER iNTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 1937' FSL & 2432' FF_.L, SEC36 T12N R14E RECTANGULAR cOORDINATES TVD NORTH/SOUTH EAST/WEST MEASURED DEPTH BELOW KB FROM KB SUB-SEA 398.69 N 5952.72 E 11600.00 8454.54 8405.54 401.80 N 5994.50 E 8490.29 8441.29 11655.00 RECEIVED A, U G 2 6 !99;~ Alaska Oil & Gas Cons. Commission Anchorage ARCO aGI-4 PRUDHOE BAY NORTH SLOPE, ALASKA MARKER COMPUTATION DATE: 2S-MAY-93 Page 9 DATE OF SURVEY: ?-MAY-1993 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: SARBER · ~~~ STRATIgRAPHIC SUMMARY ~~~ SURFACE LOCATION = 1937' FSL & 2432' FEL, SEC36 T12N R14E MEASURED DEPTH TV'D RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 11655.00 8490.29 8441.29 401.80 N $994.50 E FINAL WELL LOCATION AT TI): TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 11655.00 8490.29 8441.29 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 6007.95 N 86 10 E '~/aska 0i~ ,~ ~as tl/ZCbora#~e' Commission DIRECTIONAL SURVEY COMPANY FIELD ARCO PRUDHOE BAY WELL AGI-4 COUNTRY USA RUN DATE LOGGED DEPTH UNIT FEET REFERENCE FSl A. RECEIVED AUG 2 6 1993 AJaska Oil & Gas Cons. Uurnmissior' Anchorage All tnter13retatlons am opinions based on Inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any Interpretetlons, end we shell mot. except ~n the case of gross or wllfull negligence on our part. be liable or responsible for any loss, costs, damages or expenses incurred or su~:alned by anyone resulting from any Intsrpretatlort made by any of our officers, agents or employees. These interpretations are also subject to our General Terms and Conditions as set out in our current price ~ch®dula, i/ELL: AG]:-4 (1937' FSL, 2432' FEL, SEC 36, T12N, R14E) HORIZONTAL PROdECT~ON NORTH 4000 REF F$1 A, SCALE= 1/ 1000 IN/FT 3000 2000 1000 - 1000 -2000 -3000 SOUTH -4000 - 1000 WEST 0 1000 2000 3000 4000 5000 6000 ECEIVED A U G 2 6 1993 Alaska Oil & Gas Cons. Commissio, Anchorage 7OOO WELL: AGI-4 (1937' FSL, 2432' FEL, SEC 36, T12N, R14E) VERTICAL PROJECTION -4000 -2000 0 0 2000 4000 6000 8000 10000 12000 .. ::: :.: .: . . _ .................................. ...... .... ~ j ~..~.~...~ .... ~..f...~..~ .... ~...~...~..~..~...~...~...~.. ~...~..~.~.,.~..~...~..~..,..~.~...~..~ .... ~¢=.~ ~?~..~ .... ~..~...; ?~.-~ ~..~..~. ~.-~.;:. ~ .... :~ .~.;~ ...... ~.~.~ ~]~.[ .~..~..[ ~.~.~..~.::..~ ~.~.~. :~.~: ~:~ "~' ~"~'~ ...... ~"~"~'"~" ~1~66~"~'"~"~'"~ "'~ ' ..... ~ ...... ~'~ ~"~ ...... ~"~' ~' ~ ~"'~"~"~ ..... : ~ ~ ·: : 87.00 PROJECTION ON VERTICAL PLANE 2~7,00 87.00 SCALED IN VERTICAL DEPTHS HORIZ SCALE = I / 2000 IN/FT RECEIVED ,41aska Oil & Gas C, nr~,:, ,,, .......... TELECD Baker Hughes company 6324/6116 Nielson Way · Anchorage, AK 99518 Phone: (907) 563-3269/Fax: (907) 563-5865 Phone: (907) 562-2646/Fax: (907) 561-1358 EASTMAN TELECO MWD SURVEY WELL #AGI-4 APEX GAS INJECTION PAD 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 MEASURED DEPTH NO INTERPOLATION Eastman Teleco Anchorage, Alaska Prudhoe Bay Drilling Group Well Name Location Date Surveyed Survey Performed By : Apex Gas Injection Well AGI-4 : Apex Gas Injection Pad : : : Jan. 18, 1993 : : Ron Gehres This survey is correct to the best of my knowledge and is supported by actual field data. ~.~...~I,~ ..... COMPANY REPRESENTATIVE Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : Apex Gas Injection Well AGI-4 Location : Apex Gas Injection Pad : : No Interpolation Date Jan. 18, 1993 Filename : l168ETAK Plane of Vertical Section : 87.2° 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 :+30.18°WELLSITE North Grid convergence : +0.0000° Prudhoe Bay Drilling Group Apex Gas Injection Pad Well AGI-4 +0° 0' 0'' (T) Eastman Teleco Client Well Name Location : Prudhoe Bay Drilling Group : Apex Gas Injection Well AGI-4 : Apex Gas Injection Pad : No Interpolation Page 1 of 2 Date Jan. 18, 1993 Filename : l168ETAK MD CkL INC DIR ft ft deg deg 0 0 0.0 0.0 475 475 0.1 52.0 1087 612 0.3 119.8 1462 375 0.4 105.1 1962 500 0.9 110.3 TVD ft 0 475 1087 1462 1962 VS ft 0 0 2 4 9 LAT ft 0 0 -0 -1 -3 DEP D ' LEG BUILD TURN ft °/100 °/100 °/100 0 0.0 0.0 0.0 0 0.0 0.0 10.9 2 0.0 0.0 11.1 4 0.0 0.0 -3.9 10 0.1 0.1 1.0 2466 504 1.1 137.4 2964 498 0.9 144.4 3510 546 0.4 141.3 3643 133 1.1 87.1 3829 186 7.7 75.2 4017 188 11.2 85.4 4204 187 13.7 83.6 4392 188 21.3 83.6 4581 189 25.2 85.0 4768 187 27.9 85.7 4956 188 30.1 87.8 5144 188 37.1 86.1 5330 186 42.3 86.8 5517 187 45.5 86.1 5705 188 52.6 84.3 5894 189 56.5 84.7 6081 187 58.2 85.4 6268 187 61.8 85.4 6450 182 62.5 86.1 6630 180 60.7 86.4 6820 190 61.0 87.8 7014 194 61.4 88.5 7233 219 61.9 88.2 7419 186 60.6 86.8 7606 187 60.1 86.4 7795 189 59.9 7983 188 60.0 8171 188 59.7 8358 187 59.9 8545 187 59.5 89.2 86.8 87.1 86.4 87.1 8732 187 59.3 86.4 8922 190 59.5 86.8 9107 185 60.2 86.4 9295 188 61.0 86.4 9472 177 61.6 86.1 2466 2964 3510 3643 3828 4014 4196 4375 4549 4716 4881 5037 5180 5315 5438 5548 5649 5742 5827 5913 6005 6099 6203 6292 6385 6479 6573 6668 6762 6856 6951 7048 7141 7233 7318 16 21 25 26 40 71 111 168 242 326 417 521 639 769 911 1065 1222 1384 1545 1703 1869 2039 2232 2395 2557 2721 2884 3046 3208 3369 3530 3694 3854 4017 4173 -8 -14 -19 -20 -16 -12 -8 -2 6 13 17 0.1 0.0 5.4 22 0.0 -0.0 1.4 26 0.1 -0.1 -0.6 27 0.7 0.5 -40.8 41 3.6 3.5 -6.4 72 2.1 1.9 5.4 112 1.4 1.3 -1.0 168 4 . 0 4 . 0 0.0 242 2.1 2.1 0.7 325 1.5 1.4 0.4 65 1063 2.1 2.1 0.2 79 1220 1.0 0.9 0.4 92 1381 1.9 1.9 0.0 ~04 1541 0.5 0.4 0.4 114 1699 1.0 -1.0 0.2 123 1865 0.7 0.2 0.7 128 2035 0.4 0.2 0.4 134 2228 0.3 0.2 -0.1 141 2391 1.0 -0.7 -0.8 150 2553 0.3 -0.3 -0.2 157 2716 1.3 -0.1 1.5 162 2879 1.1 0.1 -1.3 171 3041 0.2 -0.2 0.2 180 3203 0.3 0.1 -0.4 189 3364 0.4 -0.2 0.4 198 3525 0.3 -0.1 -0.4 208 3688 0.2 0.1 0.2 218 3848 0.4 0.4 -0.2 228 4011 0.4 0.4 0.0 238 4166 0.4 0.3 -0.2 18 416 1.3 1.2 1.1 23 520 3.8 3.7 -0.9 31 639 2.8 2.8 0.4 39 768 1.7 1.7 -0.4 51 910 3.8 3.8 -1.0 Eastman Teleco Client Well Name Location : Prudhoe Bay Drilling Group : Apex Gas Injection Well AGI-4 : Apex Gas Injection Pad : No Interpolation MD C~L INC DIR TVD ft ft deg deg ft 9660 188 62.2 85.7 7407 9857 197 62.4 85.7 7498 10043 186 63.1 85.4 7584 10223 180 63.9 86.4 7664 10411 188 61.7 85.4 7750 VS ft 4338 4513 4678 4839 5006 10604 193 58.2 85.7 7846 10790 186 54.9 86.8 7949 10915 125 51.7 87.1 8024 5173 5328 5429 LAT ft 250 263 276 287 299 312 322 328 Page 2 Date Jan. Filename DEP ft 4331 4505 4670 4831 4998 5164 5319 5419 D' LEG o/lOO 0.4 0.1 0.4 0.7 1.3 1.8 1.8 2.6 of 2 18, 1993 : l168ETAK BUILD °/100 0.3 0.1 0.4 0.4 -1.2 -1.8 -1.8 -2.6 TURN °/lOO -0.2 0.0 -0.2 0.6 -0.5 0.2 0.6 0.2 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 5429 ft 86.5° MEASURED DEPTH 100' INTERPOLATED Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : Apex Gas Injection Well AGI-4 Location : Apex Gas Injection Pad : : Date Jan. 18, 1993 Filename : l168ETAK Interpolated 100 ft of MD Plane of Vertical Section : 87.2° 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 :+30.18°WELLSITE North Grid convergence : +0.0000° Prudhoe Bay Drilling Group Apex Gas Injection Pad Well AGI-4 +0° 0' 0' ' (T) Client Well Name Location Eastman Teleco Prudhoe Bay Drilling Group Apex Gas Injection Well AGI-4 Apex Gas Injection Pad Page 1 of 3 Date Jan. 18, 1993 Filename : l168ETAK Interpolated 100 ft of MD MD C~L INC DIR TVD VS LAT ft ft deg deg ft ft ft 0 0 0.0 0.0 0 0 0 100 100 0.0 10.9 100 0 0 200 100 0.0 21.9 200 0 0 300 100 0.1 32.8 300 0 0 400 100 0.1 43.8 400 0 0 5OO 6O0 700 8OO 9O0 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3OO0 3100 3200 3300 3400 35OO 3600 3700 3800 3900 100 0.1 54.8 500 0 100 0.1 65.8 600 1 100 0.2 76.9 700 1 100 0.2 88.0 800 1 100 0.2 99.1 900 2 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 0.3 110.2 1000 2 0.3 119.3 1100 2 0.3 115.4 1200 3 0.4 111.5 1300 3 0.4 107.5 1400 4 0.4 105.5 1500 5 0.5 106.5 1600 6 0.6 107.6 1700 7 0.7 108.6 1800 8 0.8 109.7 1900 9 0.9 112.3 2000 10 1.0 117.7 2100 11 1.0 123.1 2200 13 1.0 128.5 2300 14 1.1 133 . 9 2400 15 1.1 137 . 9 2500 17 1.0 139.3 2600 18 1.0 140.7 2700 19 1.0 142.1 2800 20 0.9 143.5 2900 21 0.9 144.2 3000 22 0.8 143.6 3100 22 0.7 143.1 3200 23 0.6 142.5 3300 23 0.5 141.9 3400 24 0.4 141.4 3500 25 0.9 104.6 3600 26 3.1 83.5 3700 31 6.7 77.1 3799 38 9.0 79.1 3898 52 0 0 0 0 -0 -0 -0 -0 -1 -1 -1 -2 -2 -2 -3 -3 -4 -5 -6 -7 -8 -10 -11 -12 -14 -15 -16 -17 -18 -18 -19 -20 -19 -17 -15 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 0 0.0 0.0 0.0 0 0.0 0.0 10.9 0 0.0 0.0 10.9 0 0.0 0.0 10.9 0 0.0 0.0 10.9 0 0.0 0.0 11.0 1 0.0 0.0 11.1 1 0.0 0.0 11.1 1 0.0 0.0 11.1 2 0.1 0.0 11.1 2 0.1 0.0 11.1 2 0.1 0.0 9.1 3 0.0 0.0 -3.9 3 0.0 0.0 -3.9 4 0.0 0.0 -3.9 5 0.1 0.1 -2.0 6 0.1 0.1 1.0 7 0.1 0.1 1.0 8 0.1 0.1 1.0 9 0.1 0.1 1.0 10 0.1 0.1 2.7 12 0.1 0.0 5.4 13 0.1 0.0 5.4 14 0.1 0.0 5.4 16 0.1 0.0 5.4 17 0.1 0.0 4.0 18 0.0 -0.0 1.4 19 0.0 -0.0 1.4 20 0.0 -0.0 1.4 21 0.0 -0.0 1.4 22 23 24 24 25 26 27 32 39 53 0.1 -0.1 0.7 0.1 -0.1 -0.6 0.1 -0.1 -0.6 0.1 -0.1 -0.6 0.1 -0.1 -0.6 0. 1 -0.1 -0.6 0.6 0.5 -36.7 2.3 2.2 -21.2 3.6 3.5 -6.4 2.4 2.4 2.0 Client Well Name Location Eastman Teleco Prudhoe Bay Drilling Group Apex Gas Injection Well AGI-4 Apex Gas Injection Pad Page 2 Date Jan. Filename Interpolated of 3 18, 1993 : l168ETAK 100 ft of MD MD ft 4000 4100 4200 4300 4400 CkL ft 100 100 100 100 100 INC DIR TVD VS deg deg ft ft 10.9 84.5 3997 68 12.3 84.6 4095 89 13.6 83.6 4192 110 17.6 83.6 4288 140 21.5 83.7 4383 171 4500 100 23.5 84.4 4475 210 4600 100 25.5 85.1 4566 251 4700 100 26.9 85.4 4655 295 4800 100 28.3 86.1 4744 341 4900 100 29.4 87.2 4832 390 5000 100 31.7 87.4 4917 441 5100 100 35.5 86.5 5000 496 5200 100 38.7 86.3 5080 556 5300 100 41.5 86.7 5157 620 5400 100 43.5 86.5 5231 688 5500 100 45.2 86.2 5303 757 5600 100 48.6 85.3 5369 832 5700 100 52.4 84.3 5435 907 5800 100 54.6 84.5 5493 988 5900 100 56.6 84.7 5551 1070 6000 100 57.5 85.1 5605 1154 6100 100 58.6 85.4 5658 1238 6200 100 60.5 85.4 5708 1325 6300 100 61.9 85.5 5757 1412 6400 100 62.3 85.9 5804 1501 6500 100 62.0 86.2 5851 1589 6600 100 61.0 86.3 5898 1677 6700 100 60.8 86.9 5947 1764 6800 100 61.0 87.7 5995 1851 6900 100 61.2 88.1 6044 1939 7000 100 61.4 88.4 6092 2027 7100 100 61.6 88.4 6139 2115 7200 100 61.8 88.2 6187 2203 7300 100 61.4 87.7 6235 2290 7400 100 60.7 86.9 6283 2378 7500 100 60.4 86.6 6332 2465 7600 100 60.1 86.4 6382 2552 7700 100 60.0 87.8 6432 2639 7800 100 59.9 89.1 6482 2725 7900 100 60.0 87.9 6532 2812 LAT ft -12 -10 -8 -5 -1 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 69 2.1 1.9 5.4 89 1.4 1.4 0.1 111 1.4 1.3 -1.0 140 3.9 3.9 -0.0 171 3.9 3.9 0.1 19 441 2.3 2.3 0.2 22 496 3.8 3.7 -0.9 25 556 3.2 3.2 -0.2 29 620 2.8 2.8 0.4 34 687 2.0 2.0 -0.1 38 756 1.7 1.7 -0.4 44 831 3.5 3.4 -0.9 50 906 3.8 3.8 -1.0 58 987 2.2 2.1 0.2 66 1068 2.0 2.0 0.2 73 1152 1.0 0.9 0.4 80 1236 1.1 1.1 0.3 87 1322 1.9 1.9 0.0 94 1409 1.4 1.4 0.1 101 1497 0.5 0.4 0.4 107 1585 0.4 -0.3 0.3 113 1673 1.0 -1.0 0.2 117 1761 0.5 -0.2 0.6 122 1848 0.7 0.2 0.7 125 1935 0.4 0.2 0.4 128 2023 0.4 0.2 0.4 1'30 2111 0.2 0.2 -0.1 133 2199 0.3 0.2 -0.1 136 2286 0.6 -0.4 -0.5 140 2374 1.0 -0.7 -0.8 145 2461 0.4 -0.3 -0.3 150 2548 0.3 -0.3 -0.2 154 2634 1.2 -0.1 1.4 157 2721 1.2 -0.1 1.3 160 2807 1.1 0.1 -1.3 3 210 2.1 2.1 0.7 6 251 2.0 1.9 0.7 10 295 1.5 1.4 0.4 13 341 1.4 1.4 0.6 16 389 1.3 1.2 1.1 Client Well Name Location Eastman Teleco : Prudhoe Bay Drilling Group : Apex Gas Injection Well AGI-4 : Apex Gas Injection Pad : : Page 3 of 3 Date Jan. 18, 1993 Filename : l168ETAK Interpolated 100 ft of MD MD CkL INC DIR TVD VS ft ft deg deg ft ft 8000 100 60.0 86.8 6582 2898 8100 100 59.8 87.0 6632 2985 8200 100 59.7 87.0 6682 3071 8300 100 59.8 86.6 6733 3158 8400 100 59.8 86.6 6783 3244 8500 100 59.6 86.9 6833 3330 8600 100 59.4 86.9 6884 3416 8700 100 59.3 86.5 6935 3503 8800 100 59.4 86.5 6986 3589 8900 100 59.5 86.8 7037 3675 9000 100 59.8 86.6 7087 3761 9100 100 60.2 86.4 7137 3848 9200 100 60.6 86.4 7187 3935 9300 100 61.0 86.4 7236 4022 9400 100 61.4 86.2 7284 4109 9500 100 61.7 86.0 7331 4197 9600 100 62.0 85.8 7379 4285 9700 100 62.2 85.7 7425 4374 9800 100 62.3 85.7 7472 4462 9900 100 62.6 85.6 7518 4551 10000 100 62.9 85.5 7564 4640 10100 100 63.4 85.7 7609 4729 10200 100 63.8 86.3 7654 4819 10300 100 63.0 86.0 7699 4908 10400 100 61.8 85.5 7745 4996 10500 100 60.1 85.5 7794 5083 10600 100 58.3 85.7 7844 5170 10700 100 56.5 86.3 7899 5253 10800 100 54.6 86.8 7955 5336 10900 100 52.1 87.1 8015 5417 10915 15 51.7 87.1 8024 5429 LAT ft 163 168 172 177 182 1.87 192 197 202 207 212 217 223 228 234 240 246 253 259 266 273 279 286 292 299 3O5 312 318 323 327 328 DEP D'LEG BUILD TURN o ft °/100 °/100 /100 2894 0.9 0.0 -1.0 2980 0.2 -0.2 0.2 3066 0.1 -0.1 0.0 3153 0.3 0.1 -0.4 3239 0.1 -0.0 -0.1 3325 0.4 -0.2 0.4 3411 0.2 -0.2 -0.0 3497 0.3 -0.1 -0.4 3583 0.0 0.0 0.0 3669 0.2 0.1 0.2 3755 0.3 0.3 -0.1 3842 0.4 0.4 -0.2 3928 0.4 0.4 -0.0 4015 0.4 0.4 -0.0 4103 0.4 0.3 -0.2 4191 0.4 0.3 -0.2 4279 0.4 0.3 -0.2 4367 0.3 0.2 -0.1 4455 0.1 0.1 0.0 4543 0.2 0.2 -0.1 4632 0.4 0.4 -0.2 4721 0.5 0.4 0.2 4810 0.7 0.4 0.6 4899 0.8 -0.8 -0.3 4988 1.3 -1.2 -0.5 5074 1.7 -1.7 0.1 5161 1.8 -1.8 0.2 5244 1.8 -1.8 0.6 5327 1.9 -1.9 0.6 5407 2.6 -2.6 0.2 5419 3.0 -2.9 0.3 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 5429 ft 86.5° TRUE VERTICAL DEPTH I00' INTERPOLATED Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : Apex Gas Injection Well AGI-4 Location : Apex Gas Injection Pad : : Date Jan. 18, 1993 Filename : l168ETAK Interpolated 100 ft of TVD Plane of Vertical Section : 87.2° 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 :+30.18°WELLSITE North Grid convergence : +0.0000° Prudhoe Bay Drilling Group Apex Gas Injection Pad Well AGI-4 +0 ° O' O' ' (T) Client Well Name Location Eastman Teleco Prudhoe Bay Drilling Group Apex Gas Injection Well AGI-4 Apex Gas Injection Pad Page 1 of 3 Date Jan. 18, 1993 Filename : l168ETAK Interpolated 100 ft of TVD MD ft 0 100 200 3OO 4O0 5OO 600 700 8OO 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3OOO 3100 3200 3300 3400 3500 3600 3700 3801 3902 CkL INC DIR TVD VS ft deg deg ft ft 0 0.0 0.0 0 0 100 0.0 10.9 100 0 100 0.0 21.9 200 0 100 0.1 32.8 300 0 100 0.1 43.8 400 0 100 0.1 54.8 500 0 100 0.1 65.8 600 1 100 0.2 76.9 700 1 100 0.2 88.0 800 1 100 0.2 99.1 900 2 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 101 0.3 110.2 1000 2 0.3 119.3 1100 2 0.3 115.4 1200 3 0.4 111.5 1300 3 0.4 107.5 1400 4 0.4 105.5 1500 5 0.5 106.5 1600 6 0.6 107.6 1700 7 0.7 108.6 1800 8 0.8 109.7 1900 9 0.9 112.3 2000 10 1.0 117 · 7 2100 11 1.0 123 · 1 2200 13 1.0 128.5 2300 14 1.1 133.9 2400 15 1.1 137.9 2500 17 1.0 139.3 2600 18 1.0 140.7 2700 19 1.0 142.1 2800 20 0.9 143.5 2900 21 0.9 144.2 3000 22 0.8 143.6 3100 22 0.7 143.1 3200 23 0.6 142.5 3300 23 0.5 141.9 3400 24 0.4 141.4 3500 25 0.9 104.5 3600 26 3.1 83.4 3700 31 6.7 77.0 3800 38 9.1 79.2 3900 52 LAT ft 0 0 0 0 0 0 0 0 0 -0 -0 -0 -0 -1 -1 -1 -2 -3 -4 -5 -6 -7 -8 -10 -11 -12 -14 -15 -16 -17 -18 -18 -19 -'20 -19 -17 -15 DEP D'LEG BUILD TURN ft °/100 °/100 °,/100 0 0.0 0.0 0.0 0 0.0 0.0 10.9 0 0.0 0.0 10.9 0 0.0 0.0 10.9 0 0.0 0.0 10.9 0 0.0 0.0 11.0 1 0.0 0.0 11.1 1 0.0 0.0 11.1 1 0.0 0.0 11.1 2 0.1 0.0 11.1 2 0.1 0.0 11.1 2 0.1 0.0 9.1 3 0.0 0.0 -3.9 3 0.0 0.0 -3.9 4 0.0 0.0 -3.9 5 0.1 0.1 -2.0 6 0.1 0.1 1.0 7 0.1 0.1 1.0 8 0.1 0.1 1.0 9 0.1 0.1 1.0 10 0.1 0.1 2.7 12 0.1 0.0 5.4 13 0.1 0.0 5.4 14 0.1 0.0 5.4 16 0.1 0.0 5.4 17 0.1 0.0 4.0 18 0.0 -0.0 1.4 19 0.0 -0.0 1.4 20 0.0 -0.0 1.4 21 0.0 -0.0 1.4 22 23 24 24 25 26 27 32 39 53 0.1 -0.1 0.7 O. 1 -0.1 -0.6 O. 1 -0. 1 -0.6 O. 1 -0.1 -0.6 O. 1 -0.1 -0.6 0.1 -0.1 -0.6 0.6 0.5 -36.8 2.3 2.3 -21.1 3.6 3.5 -6.4 2.4 2.3 2.1 Client Well Name Location Eastman Teleco Prudhoe Bay Drilling Group Apex Gas Injection Well AGI-4 Apex Gas Injection Pad Page 2 of 3 Date Jan. 18, 1993 Filename : l168ETAK Interpolated 100 ft of TVD MD ft 4003 4106 4208 4313 4419 4528 4638 4750 4864 4979 5099 5226 5358 5496 5647 5812 5991 6184 6392 6603 6809 7017 7227 7435 7637 7837 8036 8235 8434 8631 8828 9025 9227 9434 9646 9861 10080 10302 10511 10701 CkL ft 101 102 103 105 106 109 110 112 114 115 120 126 132 139 151 165 179 193 208 211 206 207 211 208 202 200 200 199 199 197 196 198 202 207 212 215 219 222 209 190 INC DIR TVD VS deg deg ft ft 10.9 84.7 4000 69 12.4 84.5 4100 90 13.9 83.6 4200 112 18.1 83.6 4300 144 21.9 83.8 4400 178 24.1 84.6 4500 221 26.0 85.2 4600 268 27.6 85.6 4700 318 29.0 86.8 4800 372 31.0 87.6 4900 430 35.4 86.5 5000 496 39.4 86.4 5100 573 42.8 86.7 5200 659 45.1 86.2 5300 755 50.4 84.9 5400 867 54.8 84.5 5500 998 57.4 85.1 5600 1146 60.2 85.4 5700 1311 62.3 85.9 5800 1494 61.0 86.4 5900 1680 61.0 87.7 6000 1860 61.4 88.5 6100 2041 61.9 88.2 6200 2227 60.6 86.8 6300 2409 60.1 86.9 6400 2584 59.9 88.7 6500 2757 59.9 86.9 6600 2930 59.8 86.9 6700 3102 59.7 86.7 6800 3273 59.4 86.8 6900 3443 59.4 86.6 7000 3612 59.9 86.6 7100 3783 60.7 86.4 7200 3958 61.5 86.2 7300 4139 62.2 85.7 7400 4326 LAT ft -12 -10 -8 -4 -1 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 69 2.1 1.9 5.4 91 1.4 1.4 -0.1 113 1.5 1.4 -0.9 144 4.0 4.0 0.0 178 3.5 3.5 0.2 4 221 2.1 2.1 0.7 8 268 1.8 1.7 0.6 12 317 1.5 1.4 0.4 15 372 1.3 1.2 1.0 18 429 1.7 1.7 0.7 ,22 27 32 38 47 59 72 86 100 113 122 128 134 142 151 158 165 174 184 1.94 203 213 224 236 249 62.4 85.7 7500 4516 263 63.3 85.6 7600 4711 278 63.0 86.0 7700 4909 292 59.9 85.6 7800 5093 306 56.5 86.3 7900 5254 318 496 3.8 3.7 -0.9 572 3.1 3.1 -0.1 658 2.6 2.6 0.2 754 1.7 1.7 -0.4 866 3.6 3.5 -0.9 996 2.7 2.7 -0.2 1144 1.5 1.4 0.3 1308 1.5 1.5 0.2 1490 1.0 1.0 0.2 1676 0.7 -0.6 0.2 1856 0.6 0.0 0.7 2038 0.4 0.2 0.4 2223 0.3 0.2 -0.1 2405 0.9 -0.6 -0.7 2580 0.2 -0.2 0.0 2752 0.8 -0.1 0.9 2925 0.8 -0.0 -0.9 3097 0.1 -0.1 -0.0 3268 0.1 -0.0 -0.1 3438 0.2 -0.2 0.0 3607 0.1 -0.0 -0.1 3777 0.2 0.2 -0.0 3952 0.4 0.4 -0.1 4133 0.4 0.4 -0.1 4319 0.4 0.3 -0.2 4508 0.1 0.1 -0.0 4703 0.4 0.4 -0.0 4901 0.2 -0.1 0.2 5084 1.5 -1.5 -0.2 5245 1.8 -1.8 0.4 Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : Apex Gas Injection Well AGI-4 Location : Apex Gas Injection Pad : : Page 3 of 3 Date Jan. 18, 1993 Filename : l168ETAK Interpolated 100 ft of TVD MD CkL INC DIR TVD VS ft ft deg deg ft ft 10876 174 52.7 87.0 8000 5397 10915 39 51.7 87.1 8024 5429 LAT ft 326 328 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 5387 2.2 -2.2 0.4 5419 2.8 -2.7 0.5 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 5429 ft 86.5° 6324/6116 Niels0n Way Anchorage, AK 99518 907-563-3269 Fax: 907-563-5865 907-562-2646 Fax: 907-561-1358 BAKER HUGHES INTEQ MWD SURVEY WELL #AGI-4 APEX GAS INJECTION PAD ORIGINAL Eastman Teleco now Baker Hughes INTEQ appreciates the opportunity to provide our services. Please find attached a copy of the directional surveys' in each of the following formats: · No Interpolation · 100' MD Interpolated · 100' TVD Interpolated i IC Oi:ILi ED Eastman Teleco Anchorage, Alaska Prudhoe Bay Drilling Group Well Name Date Surveyed Survey Performed By : Apex Gas Injection Well AGI-4 : Apex Gas Injection Pad : North Slope, Alaska : : April 14, 1993 : : Don Lentz This survey is correct to the best of my knowledge and is supported by actual field data. ..¢;;.(. . COMPANY REPRESENTATIVE Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : Apex Gas Injection Well AGI-4 : Apex Gas Injection Pad : North Slope, Alaska : Date April 14, 1993 Filename : l168ETAK No Interpolation Plane of Vertical Section : 87.2° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat : Dep Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft 0.000ft 0.000ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.15°WELLSITE North Grid convergence : +0.0000° Prudhoe Bay Drilling Group Apex Gas Injection Pad Well AGI-4 +0° 0' 0' ' (T) E'0- [ '0 P'0 99IP 0'0 P'0 P'0 II0P SEE ~'0- P'0 P'0 8P8[ ~'0 I'0 E'0 889[ 80E P'0- I'0- ['0 §E§£ 86I [ATP 8I[£ I '98 9 'I9 ALI £IOP [[EL P '98 0 'I9 88I PSS[ IPI£ P'98 E'09 SST P69[ 8P0£ 8'98 S '6S 06I 0[§[ IS69 P ' 98 [ ' 6S £8I £016 EE68 E£A8 P '0 E '0- P '0 P9£[ 68I P'O- I '0 [ '0 JOE[ 08I ~'0 E'O- E'O IPO[ ILI £'I- I '0 I 'I 6£8E E9I g'I I '0- ['I 9IA[ /.SI 69[[ 9§89 I'L8 S'6§ L8I 80ES E9/.9 P'98 6'6S L8I 9PO[ 8999 I'L8 L'6S 88I P88E £LS9 8'98 0'09 88I IELE 6LP9 E'68 6'6S 68I 8§[8 IAI8 [86/. E'0- 8'0- /-'0- 0 'I I6[E I '0- E'0 ~'0 E'0 P '0 S[0E 8EI £'0 ~'0 L'0 S98I LSSE §8[9 P'98 I'09 /.8I S6[E E6E9 8'98 9'09 98I E£EE JOE9 E'88 6'I9 6JOE 6609 S'88 698I S009 8'L8 0'I9 06I 909L 6IP£ PIOL 0E89 ~'0 0'0 ~'0 ~'0 O'I-- P'O 6'I 6'0 I'E 0'I S'O 6'I 0'I I'E 669I PII IPSI P0I I8£I E6 0EEI 6L g90I S9 [OLI [I6S P'98 L'09 08I SPSI LE8S I'98 S'E9 E8I P8gI EPLS P'S8 8'I9 L8I EEEI 6P9S P'S8 E'8S L8I S90I 8PSS £'P8 S'9S 68I 0[99 OSP9 89E9 I809 O'I- 8'£ 8'£ 016 IS P'O- L'I L'I 89L P'O 8'E 8'E 6£9 6'0- £'g 8'[ OES CE I 'I E 'I [ 'I 9IP 8I II6 8[PS ['P8 9'ES 88I 69L SICS I'98 S'SP L8I 6[9 08IS 8'98 ['EP 98I IES L[OS I'98 I'Ll 88I LIP I88P 8'/.8 I'0[ 88I LISS PPIS 9§6P ~'0 P'I S'I SEC [I L'0 I'E I'E EPE 9 0'0 0'P 0'P 89I E- 0'I- £'I P'I [II 8- P'~ 6'I I'E EL EI- 9El 9ILP L'S8 6'/.E L8I EPE 6PSP 0 'S8 ['SE 68I 89I §LIP 9'[8 ['IE 88I III 96IP 9 ' [8 £ ' £I L8I IL PIOP P 'S8 E 'II 88I 89LP I8SP LIO~ 8'0P- 9'0- ~'~ S'£ 9'£ I~7 9I- S '0 L'0 LE 0E' I '0- I '0 9E 6I- 0 '0- 0 '0 EE 0'0 I'0 LI 8- 0P 8E8[ E'S/. /.'/. 98I 9E [P9[ I'/.8 I'I IE P96E P'PPI 6'0 86P 9I 99PE P'/.[I I'I 6E8£ O'I 6'£- I'II 6'0I 0'0 oOZ/o I '0 I '0 OI £- 0 '0 0 '0 P I- 0 '0 0 '0 E 0- 0 '0 0 '0 0 0 0 '0 0 '0 0 0 oOt/o oOt/o ~ ~ 6 E96I ['0Il 6'0 00g P [9PI I'SOI P'0' gL[ E LSOI 8'6II £'0 EI9 0 SLP O'ES I'0 gAP 0 0 0'0 0'0 0 ~ ~ hap 6ap SA GAL E96I L80I 0 UOT%plodaasuI oN m~seI~ 'adoIS q%~ON : ped UOT$Oa[uI s~O xad~ : P-ID~ IIaM UOT$Oa[uI smd xad~ : dno~D BuTII!aO X~S aoqpnad : amen TTaM ~UaTT3 oo~I~L ummssez Client Well Name Eastman Teleco : Prudhoe Bay Drilling Group : Apex Gas Injection Well AGI-4 : Apex Gas Injection Pad : North Slope, Alaska : MD CkL INC DIR TVD VS ft ft deg deg ft ft 9660 188 62.2 85.7 7407 4338 9857 197 62.4 85.7 7498 4513 10043 186 63.1 85.4 7584 4678 10223 180 63.9 86.4 7664 4839 10411 188 61.7 85.4 7750 5006 10604 193 58.2 85.7 7846 5173 10790 186 54.9 86.8 7949 5328 10915 125 51.7 87.1 8024 5429 11111 196 50.6 85.0 8147 5581 11300 189 50.2 85.7 8267 5727 11485 185 50.4 85.0 8385 5869 11620 135 49.8 85.0 8472 5972 Page 2 of 2 Date April 14, 1993 Filename · l168ETAK No Interpolation LAT DEP D'LEG BUILD ft ft °/100 °/100 250 4331 0.4 0.3 263 4505 0.1 0.1 276 4670 0.4 0.4 287 4831 0.7 0.4 299 4998 1.3 -1.2 312 5164 1.8 -1 322 5319 1.8 -1 328 5419 2.6 -2 338 5571 1.0 -0 350 5716 0.4 -0 .8 .8 .6 .6 .2 TUR}? ° / 100 -0.2 0.0 -0.2 0.6 -0.5 0.2 0.6 0.2 -1.i 0.~. 362 5858 0.3 0.1 -0.4 371 5961 0.4 -0.4 0.0 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 5973 ft 86.4° (J,) ~ ~0 ~0 o0+ P-ID~ IIaM pa6 uo!~oa[uI sad xad~ dnoaD bu!II!aG XeS aoupn~d o0000'0+ : aouaDlaAUOO pTlD U$ION HilS%%lMoSI'0£+: uoT%euIIoaG OT~aUbeM HH~MAH~D NflI4ININ : poq~a~ uoT~einmIeD ~g 00'0 : ~ooIM IIT~ ~e q%daq H&HON M~Hi : ot paoua~aga~ suoT%oaa!q ~000'0 da~ : Sg000'0 ~e% : saSpu!paooD ~oIs H~NHD ~O~S : ~e sa~euIbT~O uoT~oas IeOT~aA HA&N~D ~0%S : o~ a~eIaa aan~Iedaq ~ apn~T~e% oE'L8 : uoTsoaS ie~TSaaA ~o aueId G~ ~o ~ 00I paseIod~asuI MV~M89II : a[eUaITA £66I 'PI IT~d¥ aSeG e~seI~ 'adols q$~ON : pad uol~oa[Ul sad xad~ : P-ID~ IIaM uol$oa~uI sad xad~ : amen IIaM dnoaD bu!II!~q XeS aoqpnad : ~uaIIO ooaIa$ uemsseM 0'E ~'E ~'E ~'9- S'£ 9'[ 6£ E'TE- E'E £'E £'9£- S'0 9'0 9 '0- I '0- I '0 9E 9 '0- I '0- I '0 SE 9 '0- I '0- I '0 ~E 9 '0- I '0- I '0 ~E 9 '0- I '0- I '0 6E £'0 I '0- I '0 EE ~'I 0 '0- 0'0 ~'I 0 '0- 0 '0 0E ~ 'I 0 '0- 0 '0 6I ~'I 0 '0- 0 '0 0'~ 0'0 I'0 £I §I- £I- 6I- 0E- 6I- 8I- 8I- £I- 9I- ~I- El- II- 0I- 8- ~ 'g 0 '0 I '0 9I £- ~'g 0 '0 I '0 ~I 9- ~'~ 0'0 I '0 6I ~- ~'~ 0'0 I '0 ~I ~- L'E I '0 I'0 0I 6- 0 'I I '0 I '0 6 0 'I I '0 I '0 8 0 'I I '0 I '0 £ 0 'I I '0 I '0 9 0'~- I'0 I'0 g 6'[- 0'0 0'0 6'[- 0'0 0'0 £ 6'[- 0'0 0'0 I '6 0'0 I '0 I'II 0'0 i'II 0 '0 I '0 I'II 0'0 0 '0 I'II 0 '0 0 '0 I'II 0'0 0'0 I 0 'II 0 '0 0 '0 0 6'0I 0'0 0'0 0 6'0I 0'0 0 '0 0 6'0I 0'0 0 '0 0 6 '0I 0 '0 0 '0 0 0 '0 0 '0 0 '0 0 oO~/o oOt/o oot/o ~ lltlfl,I, (lq !fl~ D,q'q, (] cI~tG E- E- E- I- I- 0- 0- 0- Om 0 0 0 0 0 0 0 0 0 q,.g:' ,T,'WI Eg 868£ I'6L 0'6 00I 8£ 66L£ I'LL L'9 00I 16 00L6 S'68 I'6 00I 9E 009£ 9'~0I 6'0 00I gE OOg£ ~'I~I ~'0 00I ~E 00~6 6'I~I g'0 00I SE 00££ g'E~I 9'0 00I £E 00E£ I'£~I L'O 00I EE 0016 9'£~I 8'0 00I EE 000£ E'9~T 6'0 00I IE 006E g'£~I 6'0 00I 0E 00SE I'E~I 0'I 00I 6I 00LE L'0~I 0'I 00I 8I 009E £'6£I 0'I 00I LI 00gE 6'L£I I'I 00I SI OOZE 6'£gI I'I 00I 91 00£E g'SEI 0'I 00T E1 00EE I'£EI 0'1 00T II 00IE £'£II 0'I 00I 0I 000E 6'EII 6'0 00I 6 006I L'60I 8'0 00I 8 008I 9'80I L'0 00I L 00LI 9'LOI 9'0 00I 9 009I g'90I g'0 00I g OOgI g'§OI 9'0 00I ~ 00~I g'LOI 9'0 OOI £ 008I g'IlI ~'0 OOl £ OOEI ~'glI £'0 OOI E 00II £'6II £'0 00I E 000I E'0II £'0 00I 006£ 008£ OOL£ 009£ 00§6 00~£ 00££ 00gE 00I£ 000£ O06E O08E OOLE O09E 00~E 00£E 00EE 00IE 000E 006I 0081 00LI 009I 00gI 00~I 00£I 00EI 00II 000I 006 I'66 E'0 00I 006 008 0'88 E'0 00I 008 00£ 6'9£ E'0 00I 00£ 009 8'g9 I'0 00I 009 OOg 8'9g I'O OOI OOg 0 00~ 8'£~ I'0 00I 0 00£ 8'E£ I'0 00I 0 00E 6'IE 0'0 00I 0 00I 6'01 0'0 00I 0 0 0'0 0'0 0 ~ ~ Bep hep ~ SA OAL HIO OMI TkO 00% 00£ 00g 00I 0 MVLZ89II : emeUeIT~ £661 '~I II~dv e%e~ e~smI~ 'edoIS q~ON : ped UOT$Oa¢uI seD xadv : ~-IDV IIaM UOT~Oa¢uI seD xadv · dnoao Bu!II!ZG XeS eoupn~d : amen IIaM SUaTIO g 'I- I '0 I 'I /.08E 09I ~'I I '0- E'I ~£9E ~§I ~'0- £ '0- [ '0 99§~ O~I £ '0- [ '0- 9'0 I9~g SgI 8'0- £'0- 0 'I 9L£E 09I _c'0- ~'0- 9'0 98EE 9£I I '0- ~'0 g '0 66I~ ££I I '0- ~ '0 E '0 IIT~ ~ '0 E'0 9'0 £EOE EI8E 6£9E 06EE £0EE §IIE £EOE ~'0 E'0 9'0 ~£6I ~EI 6£6I £'0 E'0 £'0 898I EEl I98I 9'0 ~'0- ~'0 I9£I £II 99£I ~'0 0'I- 0'I £L9I III ££9I 5'0 ['0- ~'0 ~8~I £0I 68~I t'0 ~'0 g'0 £69I I0I i'0 ~'I 0'0 6'I 6'I EE£I £8 £'0 I'I I'I 9£EI 08 ?'0 6'0 0'I E~II I0~I 8gEI 9§TI E'0 0'E 0'E 890I 99 0£0I E'0 I'E E'E £86 8§ 886 0'I- 8'£ 8'£ 906 0G £06 6'0- 9'£ S'£ I£8 99 E£8 ~'0- £'I £'I 9§£ 8£ ASA I'0- 0'E 0'E L89 9£ 889 ~'0 8'E 8'E 0E9 6E 0E9 E'0- E'£ E'£ 9§~ ~E 9~§ 6'0- L'£ 8'£ 969 EE' 969 E'0 g'E ['E I99 6I I99 I 'I E 'I £ 'I 68[ 9I 06£ 9'0 9'I t '0 9 'I S 'I ~6E OI S6E £'0 6'I 0'E £ ' 0 T ' E §- 8- 0I- EI- ,m,~f'I i'0 6'£ 6'£ ILl 0'0- 6'£ 6'5 0 'I- 5 'I 9 'I III I '0 9'I 9'I 68 ~'~ 6'I I 'E 69 oo~:/c oot/o 0ot/o [£~9 6'L8 0'09 OOI 006£ E899 I'68 6'6~ OOI 008£ E£99 8'L8 0'09 00I OOLL [8£9 9'98 I'09 OOI 009£ ~££9 9'98 9'09 OOT 00~£ g8~9 6'98 £'09 OOI S£E9 t't8 9'I9 OOI £819 E'88 8'I9 OOI 6£I9 9'88 9'T9 00I E609 9'88 9'I9 00I 009£ 00££ OOE£ 00I£ 000£ 9909 I'88 E'I9 OOI 0069 S66S t't8 0'I9 OOI 0089 L96S 6'98 8'09 OOI 00£9 868§ £'98 0'19 00T 0099 IS8§ E'98 0'g9 00I 00~9 908S 6'~8 £'~9 OOI 0099 L§L§ ['~8 6'I9 OOI 00£9 80L§ 9'~8 ~'09 OOI OOE9 8~9~ 9'~8 9'8~ 00I 0019 §09~ I'§8 ~'t~ OOI 0009 I~§ £'98 9'9~ OOI £69~ S'98 9'9~ OOI S£9§ £'~8 9'ES OOI 69£~ £'S8 9'8~ 00T £0£~ E'98 E'~ 00I O06g O08S 00£~ 009~ 00~ I£ES g'98 g'£9 OOI 009S £gIS L'98 g'I9 OOI 00£~ 080~ £'98 L'8£ OOI OOE~ O00S S'98 S'S£ OOI OOIS tI6~ ~'t8 t'I£ 00I O00S ~£89 E'L8 9'6E OOI 0069 99£9 I'98 £'8E OOI 0089 SS99 9'§8 6'9E OOI OOL9 99~9 T'S8 ~'S~ 00l 0099 SL~9 9'~8 S'£E OOI 00S9 IAI £8£9 £'£8 ~'IE OOI 09I 88E9 9'£8 9'ti OOI OII E619 9'£8 9'[I OOI 68 S609 9'98 £'~I 00I 89 £66£ ~'98 6'0I 00I ~j ~ hap Dap ~ SA GAL HIG ONI qkO OO99 00£9 0019 0009 ~M jo 1j 00I pa~elodla~uI m~{seItf 'adoIS UlaON : peal uoI~oa,[uI seD xed1/ : 9-IDtf IIaM uoT.%oa.[uI sPD xad¥ : dnoaD BuIIITaG AmS soupn~d : amen IIaM ~UaTI3 Client Well Name Eastman Teleco : Prudhoe Bay Drilling Group : Apex Gas Injection Well AGI-4 : Apex Gas Injection Pad : North Slope, Alaska : Page 3 of 4 Date April 14, 1993 Filename : l168ETAK Interpolated 100 ft of MD MD ft 8000 8100 8200 8300 8400 85OO 8600 8700 8800 8900 9000 9100 9200 9300 9400 9500 9600 9700 9800 9900 10000 10100 10200 10300 10400 10500 10600 10700 10800 10900 11000 11100 11200 11300 11400 11500 11600 11620 CkL INC DIR TVD VS LAT ft deg deg ft ft ft 100 60.0 86.8 6582 2898 163 100 59.8 87.0 6632 2985 168 100 59.7 87.0 6682 3071 172 100 59.8 86.6 6733 3158 177 100 59.8 86.6 6783 3244 182 100 59.6 86.9 6833 3330 100 59.4 86.9 6884 3416 100 59.3 86.5 6935 3503 100 59.4 86.5 6986 3589 100 59.5 86.8 7037 3675 100 59.8 86.6 7087 3761 100 60.2 86.4 7137 3848 100 60.6 86.4 7187 3935 100 61.0 86.4 7236 4022 100 61.4 86.2 7284 4109 100 61.7 86.0 7331 4197 100 62.0 85.8 7379 4285 100 62.2 85.7 7425 4374 100 62.3 85.7 7472 4462 100 62.6 85.6 7518 4551 100 62.9 85.5 7564 4640 100 63.4 85.7 7609 4729 100 63.8 86.3 7654 4819 100 63.0 86.0 7699 4908 100 61.8 85.5 7745 4996 100 60.1 85.5 7794 5083 100 58.3 85.7 7844 5170 100 56.5 86.3 7899 5253 100 54.6 86.8 7955 5336 100 52.1 87.1 8015 5417 100 51.2 86.2 8077 5495 100 50.7 85.1 8140 5573 100 50.4 85.3 8203 5650 100 50.2 85.7 8267 5727 100 50.3 85.3 8331 5804 100 50.3 85.0 8395 5880 100 49.9 85.0 8459 5957 20 49.8 85.0 8472 5972 187 192 197 202 207 212 217 223 228 234 240 246 253 259 266 273 279 286 292 299 305 '312 318 323 327 332 338 344 350 356 363 369 371 DEP D'LEG BUILD TURN o o o ft /100 /100 /100 2894 0.9 0.0 -1.0 2980 0.2 -0.2 0.2 3066 0.1 -0.1 0.0 3153 0.3 0.1 -0.4 3239 0.1 -0.0 -0.1 3325 0.4 -0.2 0.4 3411 0.2 -0.2 -0.0 3497 0.3 -0.1 -0.4 3583 0.0 0.0 0.0 3669 0.2 0.1 0.2 3755 0.3 0.3 -0.1 3842 0.4 0.4 -0.2 3928 0.4 0.4 -0.0 4015 0.4 0.4 -0.0 4103 0.4 0.3 -0.2 4191 0.4 0.3 -0.2 4279 0.4 0.3 -0.2 4367 0.3 0.2 -0.1 4455 0.1 0.1 0.0 4543 0 · 2 0 · 2 -0 · ! 4632 0.4 0.4 -0.2 4721 0.5 0.4 0.2 4810 0.7 0.4 0.6 4899 0.8 -0.8 -0.3 4988 1.3 -1.2 -0.5 5074 1.7 -1.7 0.1 5161 1.8 -1.8 0.2 5244 1.8 -1.8 0.6 5327 1.9 -1.9 0.6 5407 2.6 -2.6 0.2 5485 1.1 -0.9 -0.9 5563 1.0 -0.6 -1.1 5640 0.3 -0.3 0.2 5716 0.4 -0.2 0.4 5793 0.3 0.1 -0.4 5870 0.2 0.0 -0.3 5946 0.4 -0.4 0.0 5961 0.5 -0.5 0.0 · 0~ ~nsoI3 ~IOH ~o~o~ go u~B~O M~89TT : am~UaTT~ £66I '~T TT~dV a~G ~s~I~ 'adoIS qSaON : P~d uo!~oa[uI s~D xad~ : ~-ID~ IIaM UOT~Oa~uI s~D xad~ : amen IIaM dno~D bUTIII~G X~ aoqpn~d : ~uaTIO (~) ~ ~0 ~0 o0~ ~-ID~ IISM P~d uo!$s~[uI s~D x~d¥ dnoaD Bu!II!aG X~S ~oqpn~ o0000'0+ : aouaBza^uo3 q%aoN 2~IS%%2Mo§I'0£+: uo!$eu!Ioaq poqss~ uo!$~InmI~D Sg 00'0 : ~ooIg IIT~O %~ usdeG Hi,ON ~O~ : oi peoue~ege~ suoT~oe~TO ~000'0 deo : Sg000'0 ~p% : ss$~u!p~ooD %ois ~2iNZD iO%S : ~e se;eUTbiao UOT;Oe$ IeoTSaaA og'L8 : uoT~oaS IPDT~aA ~o auwId 2Ai ~o ~ 00I p~Ioda~$uI ~¥~R89II : ampuaI!~ £66I '~I IT~d~ a~eG ~s~I~ '~doIS qSaON : P~d uoI~m~[uI s~D x~d~ : ~-ID¥ ITeM uo!~o~[uI s~D x~d~ : Sm~N ITeM dno~D Bu!II!~ X~8 ~oupn~ : ~u~!IO Client Well Name Eastman Teleco : Prudhoe Bay Drilling Group : Apex Gas Injection Well AGI-4 : Apex Gas Injection Pad : North Slope, Alaska : Page 1 of 3 Date April 14, 1993 Filename : l168ETAK Interpolated 100 ft of TVD MD CkL INC DIR TVD VS ft ft deg deg ft ft 0 0 0.0 0.0 0 0 100 100 0.0 10.9 100 0 200 100 0.0 21.9 200 0 300 100 0.1 32.8 300 0 400 100 0.1 43.8 400 0 5OO 6OO 700 8OO 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2OOO 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3801 3902 100 0.1 54.8 500 0 100 0.1 65.8 600 1 100 0.2 76.9 700 1 100 0.2 88.0 800 1 100 0.2 99.1 900 2 100 0.3 110.2 1000 2 100 0.3 119.3 1100 2 100 0.3 115.4 1200 3 100 0.4 111.5 1300 3 100 0.4 107.5 1400 4 100 0.4 105.5 1500 5 100 0.5 106.5 1600 6 100 0.6 107.6 1700 7 100 0.7 108.6 1800 8 100 0.8 109.7 1900 9 100 0.9 112.3 2000 10 100 1.0 117.7 2100 11 100 1.0 123.1 2200 13 100 1.0 128.5 2300 14 100 1.1 133.9 2400 15 100 1.1 137.9 2500 17 100 1.0 139.3 2600 18 100 1.0 140.7 2700 19 100 1.0 142.1 2800 20 100 0.9 143.5 2900 21 100 0.9 144.2 3000 22 100 0.8 143.6 3100 22 100 0.7 143.1 3200 23 100 0.6 142.5 3300 23 100 0.5 141.9 3400 24 100 0.4 141.4 3500 25 100 0.9 104.5 3600 26 100 3.1 83.4 3700 31 100 6.7 77.0 3800 38 101 9.1 79.2 3900 52 LAT ft 0 0 0 0 0 0 0 0 0 -0 -0 -0 -0 -1 -1 -1 -2 -2 -2 -3 -3 -4 -5 -6 -7 -8 -10 -11 -.12 -14 -15 -16 -17 -18 -18 -19 -20 -19 -17 -15 DEP D ' LEG BUILD TURN o o o ft /100 /100 /100 0 0.0 0.0 0.0 0 0.0 0.0 10.9 0 0.0 0.0 10.9 0 0.0 0.0 10.9 0 0.0 0.0 10.9 0 0.0 0.0 11.0 1 0.0 0.0 11.1 1 0.0 0.0 11.1 1 0.0 0.0 11.1 2 0.1 0.0 11.1 2 0.1 0.0 11.1 2 0.1 0.0 9.1 3 0.0 0.0 -3.9 3 0.0 0.0 -3.9 4 0.0 0.0 -3.9 5 0.1 0.1 -2.0 6 0.1 0.1 1.0 7 0.1 0.1 1.0 8 0.1 0.1 1.0 9 0.1 0.1 1.0 10 0.1 0.1 2.7 12 0.1 0.0 5.4 13 0.1 0.0 5.4 14 0.1 0.0 5.4 16 0.1 0.0 5.4 17 0.1 0.0 4.0 18 0.0 -0.0 1.4 19 0.0 -0.0 1.4 20 0.0 -0.0 1.4 21 0.0 -0.0 1.4 22 0.1 -0.1 0.7 23 0.1 -0.1 -0.6 24 0.1 -0.1 -0.6 24 0.1 -0.1 -0.6 25 0.1 -0.1 -0.6 26 0.1 -0.1 -0.6 27 0.6 0.5 -36.8 32 2.3 2.3 -21.1 39 3.6 3.5 -6.4 53 2.4 2.3 2.1 ~ '0 8 'I- 8'1 ~E~ E'O- S 'I- ~'I ~80~ ~'0 I '0- E'O I06~ 0'0- ~'0 ~'0 £OL~ 0'0- I '0 I '0 80S~ ~ '0- £ '0 P'O 6I£P I '0- 9'0 9'0 ££I9 I '0- 9'0 9'0 ES6£ 0'0- g '0 g'O LLg£ I '0- 0 "0- I '0 L09£ 0 '0 E '0- E'O 8£9£ I '0- 0 '0- I'O 89E£ 0'0- I '0- I '0 L60£ 6'0- 0 '0- 8'0 c:J E6E 6'0 I '0- 8'0 ESLE 0'0 E'O- E'O 08SE L'O- 9'0- 6'0 §O~E I'O- E'O £'0 £EgE ~'0 ~'0 9'0 8£0E L'O 0'0 9'0 9~8I E'O 9'0- L'O 9L9I E '0 0 'I 0 'I 069I E'O g 'I S'I 80£I £'0 9'I S 'I 9911 g'O- L'g L'E 966 8I£ 905 E6E 595 955 £0E 8SI 00I 98 6C5 6'0- C5'£ 9'£ 998 7'0- L'I L'I 9SL 8£ ~'0 9'E 9'E 8S9 I'O- I'£ I'£ ELS LE 6'0- L'£ 8'£ 969 L'0 L 'I L'I 659 8I 0 'I E 'I £ 'I EL£ SI P'0 9'I CS'I LI£ 9 '0 L 'I 8'I 895 8 L'O T'E T'E TEE E'O C5'£ S'£ 8LI 0'0 0'9 0'~ 99I 6'0- 9'I CS'I 5II I '0- 9 'I 9'I I6 ~'~ 6'I I'E 69 oO~/o oOi/o ooz/o ~ 8- OI- EI- 9SEC5 O06L 5'98 S'9S 06I £60C5 O08L 9'S8 6'6S 6069 OOLL 0'98 0'£9 gEE IIL9 009L 9'C58 £'£9 9g£9 009L L'C58 g'g9 6£I9 00gL E'98 C5'I9 LOg 8§6£ 00EL 9'98 L'09 E0E £8L£ 00IL 9'98 6'6S 86I EI9£ O00L 9'98 9'6S 961 £99£ 0069 8'98 9'6S L6I £LE£ 0089 L'98 L'6S 66I EOI£ OOL9 6'98 8'6S 66I 0£6E 0099 6'98 6'6C5 OOE LSLE 00S9 L'88 6'6S OOE 98SE 0099 6'98 I'09 E0E 609g 0059 8'98 9'09 80g LEEE 00g9 g'88 6'I9 lie I905 0019 S'88 9'I9 L0E 098I 0009 £'£8 0'I9 905 089I 006C5 9'98 0'I9 lie 969I 008S 6'S8 £'59 805 II£I 00£S 9'C58 E'09 £6I 991I 009S I'S8 9'£S 6£I 866 00C5C5 C5'98 8'9C5 C59I L98 009C5 6'98 9'0C5 IC5I C5C5L 00£C5 E'98 I'C59 6£I 6S9 00ECS L'98 8'59 gAS OOIS 9'98 9'6£ 9EI 969 000C5 C5'98 9'S£ OgI 059 0069 9'L8 0'I£ EL£ 0089 8'98 0'65 8I£ 00L9 9'S8 9'LE Eli 895 0099 E'S8 0'95 0II IEE 00C59 9'98 I'95 60I 8LI 0099 8'£8 6'IE 90I 99I 00£9 9'£8 I'8I CS01 Eli 0059 9'58 6'£I £0I 06 0019 C5'98 9'EI E0I 69 0009 £'98 6'0I I0I SA GAL ~IG ONI 7kO IOLOI E0£0I 0800I I986 9996 9£96 LEE6 SE06 8E88 I£98 9£98 9£08 tg8t t£9t LEEL LIOL 6089 £099 56£9 9819 L99C5 8C5£C5 660C5 6L69 9989 8£99 80E9 9019 £009 GAl ~o j~ 00I paJelod~aJuI XV~H89II : ameUaT!~ £66I 'PI llad~ aSeQ eMseI~ 'adoIS q%aON : P~d uol$oa[uI seD xad~ : 9-IO~ IIaM uol$oa[uI seo xad~ : dno~D ~u!II!aG X~S aogpnmd : SUallO Client Well Name Eastman Teleco : Prudhoe Bay Drilling Group : Apex Gas Injection Well AGI-4 : Apex Gas Injection Pad : North Slope, Alaska : Page 3 of 3 Date April 14, 1993 Filename : l168ETAK Interpolated 100 ft of TVD MD CkL INC DIR TVD VS ft ft deg deg ft ft 10876 174 52.7 87.0 8000 5397 11037 161 51.0 85.8 8100 5523 11195 158 50.4 85.3 8200 5646 11352 157 50.3 85.5 8300 5766 11508 156 50.3 85.0 8400 5887 11620 112 49.8 85.0 8472 5972 LAT ft 326 334 344 353 363 DEP D ' LEG BUILD TURN ft °/100 °/100 °/100 5387 2.2 -2.2 0.4 5514 1.2 -1.1 -0.8 5636 0.4 -0.4 -0.3 5756 0.1 -0.1 0.1 5876 0.2 0.0 -0.3 371 5961 0.4 -0.3 -0.3 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 5973 ft 86.4° ARCO Alaska, Inc. P.O.Box 1OO360 Anchorage, ,p.;~,=k,, 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINALS a-18A~ 5-18-90 5-13 77- ~ 5-28-93 5-247/*/~ 5-22-93 5-32 ~ l-~ ~ 5-27-93 6-12A f2'~ 5-29-93 6-14A ~/~75-19-93 7-147~81 5-25-93 9-3 78~ 7~- 5-18-93 9-3 5-24-93 * 9-4A 9~-z ¥ 5-26-93 9-5A ~ ~-~- ~ 5-30-93 ** 9-28A ~$~ 5-28-93 9-31A ~5~5-19-93 9-32 ~/~'5-30-93 12-15 ~-~ ~- 5-27-93 12-23 ~-~5-27-93 4-22 .~. 5-23-93 14-22AA~l ~5-23-93' 8-29A ~5-18-93 AGI- 1~.~ ~ 5-20-93 AGI-1 5-20-93 AGI-2 q~-~¢~5-23-93 AGI-2 /5-23-93 Perf Record AGI-3 ~ ~5s 5-20-93. GR/~ AGI-3' , ~5-21-93 Prim_~ry Perf Record ' AGI-4 ~A~ 5-22-93 Initial Perf Record Completion Record Run 1, 5" TDTP (Borax) Run 1, 5" GR/Colt~r Run 1, 5" TDTP (Borax) R~_m 1, 5" TDTP (Borax) Run 1, 5" Production Log Run 1, 5" Prod Profile Run 1, 5" Perf Record R~_~_n 1, 5" Frod Profile Run 1, 5" Production Log Run 1, 5" Completion Record R~_~_n 1, 5" Production Log R~_n 1, 5" CBT R~_m 1, 5" Completion Record Run 1, 5" Completion Record Run 1, 5" Leak Detection Run 1, 2" Perf Record Run 1, 5" PITS Run 1, 5" Perf Record Run 1, 5" Jewelry Rim 1, 5" Perf Record Run 1, 5" Jewelry Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Please sign and return ~che~ as receipt of data. Sonya Wallace ATO-1529 Sch Sch Arias Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch ' Sch Sch # C~rl'aAL #CHEVRON #BPX # STATE OF ALASKA Sch Sch Sch Sch Sch Sch Sch Sch Sch # CLINT CHAPMAN The correct well name for this log is 9-4A. The correct APl# for 9-28A is 50-029-21292-01. S~l;V ,,.q '! '~rp ~o ~dtooo~ ss ~doo poqos:~s oq~ u.m~o~ pus u~s oswold S6-6-9 :b :0 OI !166 m~ 'ol~szoqouv 09gO0! xoiI'O'& · ouI :u~,,~l~/' OOHV' OOala& ooei~ --- / l ~'/~ --([:iIAO H,,:Id:V a;)eEl'e~ iA:eCl aollq V '~ep ~to ~d~aoaz ss ~Ioo pat[oal~ eq~ u.-z,~az p~ u3ts ass"eEl ~.1: °1: tml:I g6-6-9 :3.LVCI O! g66 ~rJ[selV 'a~zoqouv 09gOOl zola'O'& · ouI 'wJ[ssIV O011V ARCO Alaska, Inc. (('"'"~ Post Office Box ..O360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 June 7, 1993 Mr. David W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 95501 EN~ A-~'~'T-I i ~NG AS~~T~ GEOL AS;5 t,3 _. ! F~LE ! Re: Notice of Gas Injection Dear Mr. Johnston: This is to info~ you that on May 30, 1993 ~CQ beg~._gas in~¢cQon on the Apex Gas Injection pad. AGI wells ~1, ~2, ~rf6rated ana gas iS being injected at ~iS"ume. Injection volumes, tubing and easing pressure information will be reported with the other gas injection wells on form 10-406. Donald F. Scheve Manager, Prudhoe Bay Operations Engineering DFS:llp c: M. L. Bill C. J. Phillips S. J. Wysocki AAI, ATO- 1528 BPX, MB9-2 AAI, ATO- 1554 ARCO Alaska, Inc. is a Subsidiary of Ailantic Richfield Company REEEIVED JUN - 9 199 Alaska 011 & Gas Cons. CommiSSiOn Anchorage, ARCO .~IA-;~; ].tlC. P.O.Box 100360 Anchorage, Alaska 99~ 10 DATE: 3-22-93 REFERENCE: ARCO CASED HOI.~ FINALS c~9..-'lqlc' AGI-4 3-7-93 Peff Record Run 1, 5" 2-27-93 CNL Run 4, 5" 2-27-93 CNL Rml 2, 5" 2-28-93 CNL Run 2, 5" 3-5-93 Dual Burst TDTP (Borax) Run 1, 5" 3-1-93 CNL Run 2, 5" 3-1-93 CNL Run 2, 5" 3-6-93 Dual Burst TDTP Run 1, 5" 2-28-93 CleF.., Ran 2, 5" 2-25-93 Dual Burst TDTP (Borax) Run 1, 5" 3-7-93 Collar (Jet TBG Cutter) Run 1, 5" 3-3-93 Vertflog Run 1, 5" 3-2-93 PeffRecord l~m 1, 5" 2-25-93 CCL (II]G Cutter) l~m 1, 5" 3-9-93 Peff/GR/CCL l~m 1, 5" 2-25-93 8BL/~~ l~m 1. 5" 2-24-93 8BL/~(X/, la,_m 1, 5" Please sign and return the attached copy u receipt of data. RECEIVED BY_.~ ~/~_~_/~_~~ Have A Nice Day! Sonya Wallace ATO-1529 ~ch Sch Sch 8ch Sch Sch Sch Sch Sch Sch Sch Atlas ~ch Atlas Sch Sch Atlas 5ch Atlas Atlas APPRoVED.~~_'__ Trans# 93042- # CENTRAL FILES # CHEVRON D&M # LUCILLE JOHNSTON # EXXON M_-,qRATHON # MOBIL # PHILLIPS PB WELL FILES R&D ' #BPX # STATE OF ALAS~ TEXACO The correct API# for 1-3 1 is 50-029-2 1626-00. The correct well name for this log is 16-4. STATE OF ALASKA A~,SKA OIL AND GAS CONSERVATION COMMISc,,ON REPORT OF SUNDRY WELL OPERATIONS 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 KB) ARCO Alaska, Inc. Development w KBE = 36 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 1937' NSL, 2453' WEL, Section 36, T12N, R14E, UM AGI-4 At top of productive interval 9. Permit number/approval number N/A 92-146/93-00 7 At effective depth !10. APl number N/A 50- 029-22323 At total depth 11. Field/Pool 2268' NSL, 3022' EWL, SEC. 31, T12N, R15E, UM Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured 10985 feet Plugs (measured) true vertical 8066' 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 3497' 13-3/8" 2170 cu ft 'E', 464 cu ft 'G' 3538' 3538' Intermediate 10941' 9-5/8" 460 cu ft Cl 'G' 10978' 8062' Production Liner Perforation depth: measured None true vertical None R~C~.I~ ~,0 Tubing (size, grade, and measured depth) None I~R 0 ~ Packers and SSSV (type and measured depth) None ~|aska 0it & Gas ~0t~$. ~13t~'~-~~ 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. RePresentative Daily Averaqe 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~Vel rOpeptions _z_ Oil Gas ... Suspended Service ADex Gas Iniector 17. I herebl c.~y~! :he~.~egoing is ~,ue and ~ect t,~e best of my knowledge.~.~/'-~ Date~,~r4./~.c, Signed t.../, r....~, ;),v~/~ --! --,' ~.a,~j~ Title Drillin~ Engineer Supervisor Form 10-404 Rev 0E~/15/88 SUBMIT IN DUPLICATE . MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: Leigh GriffiO~ Commissioner thru: o z Blair E W nd ell Sr Petr Engineer date: January27, 1993 file: subject: from: ~OU Grimaldi Petr Inspector LOU01071.DOC Rig BOPE Inspection Audi Rig 2 Arco AGI 4 Prudhoe Bay Unit PTD 92-146 Thursday, January 7, 1993: I made a rig BOPE Inspection on Audi Rig 2 drilling Arco's gas injector AGI 4. I found the rig to be in good shape with its BOPE equipment in place and well maintained. This rig continuously impresses me with its cleanliness even though the rigs crew compliment has been reduced. I discussed with Steve Walls (Arco Representative) that when these wells are completed~ the mechanical integrity test on the casing could be state witnessed at the same time. SUMMARY: Inspection. I found Audi Rig 2 to be in good shape during my RIG/BOPE Attachment ,, STATE OF ALASKA ALASKA Oi L AND GAS CONSERVAT ! ON COMM I SS ION Rig/BOPE Inspection Report OPERATION: Drlg /~ Comp1 Wkvr UIC~ Location: TrnA/ R /~' 'M U ~ ~g :ont~ ~Obl R~g~ ~ Location {gert'l) ~~ Well sign 0 ~ IN COMPLIANCE; yes n~o n/~. A. DIVERTER 1. ( ) ( ) Z.() () 3.() () 4.() () 5.() () 6.() () 7.() () 24. (~)- ( ) zs. (~) ( ) 26. (q) ( ) 2?. (yj ( ) 28. O0 ( ) 29. (X) ( ) 3o. (yQ ( ) (k() line sz & length ~ line conn& anchored (~(} bi furcated & dwn wi nd {t~Q 90~ targeted turns (~) vlvs: auto & simultaneous (X} annular pack-off {)(O condition B. BOP STAC~ { ) wellhead flg wkg press ( ) stack wkg press ( ) annul ar 'preventer ( ) pipe rams -. ( ) blind rams ( ) stack anchored ( ) chke/kill li~e sz ( ) 90~ turns targeted (chke & kill ln) ( ) HCR vlvs (chke & kill) ( ) manual vlvs (chke & kill) ( ) connections (flgd, whd, clmpd) ( ) drl spool ( ) flow nipple ( ) fl ow monitor ( ) ~ control lines fi re protected C. CLOSING UNITS ( ) wkg press ( ) fluid level ( ) oprtg press ( ) press gauges ( ) sufficient vlvs ( ) regulator bypass ( ) 4-way vlvs (actuators) ( ) blind handle cover ( ) driller control panel Representative Representative-- I N COMPL ! ANCE; yes no .nla. 33. (~(~ ( ) ( ) fi rewall 34. ~ ( ) ( ) nitrogen power source (back-up) 35.~ ( ) ( ) condition (leaks, hoses, etc) D. MUD SYSTEM 36. (~ { } ( } pit level floats installed 37.~ ( ) ( ) flow rate sensors 38. ~J) ( ) ( ) mud gas separator 39. ~ ( ) ( ) degasser 40, J;)~) ( ) ( ) separator bypass 41. j~ ( ) ( ) gas sensor 42. ~) ( ) ( ) chke In conn 43. {3~i) ( ) ( ) trip tank E. RIG FLOOR 44. ~ ( ) ( ) kelly cocks (upper,lower, IBOP) 45. ~ ( ) ( ) floor vlvs (dart vlv, ball vlv) 46.~ ( ) ( ) kelly & floor vlv wrenches 47. ( ) ( ) driller's console (flow monitor flow rate indicator, pit leve indicators, gauges) 48. ~ ( ) ( ) kill sheet up-to-date 49.(~ ( ) ( ) gas ~etection monitors (H S & methane) 50. ~(~ ( ) ( ) hydr chke panel 51. (~ ( ) ( ) chke manifold F. MISC EQUIPMENT 52. (/<) ( ) ( ) flare/vent line 53.~ ( ) ( ) 90~ turns targeted (dwn strm choke lns) 54. ( ) ( ) ~ reserve pit tankage 55. ()~) ( ) ~ ) personnel protective equip avai 56.~}~ ( ) { ) all drl site suprvs trained . / 2for procedures · 57. ( ) ( ) ~k} H S probes 32. (~)- ( ) ( ) remote control panel 58. ~ ( ) ( ) rig housekeeping RECORDS: Date of last BOP inspection: Date of last BOP test: Resulting non-compliance: L ~4~( JAJ Odt~7~-'('~P'' /-lt~7.~''' C m~C~~ Non-compliances not corrected & ~y: Date corrections will be complete: BOP test & results properly entered on daily record? ~~ Kill sheet current? .~~ AL~,~KA OIL AND GAS CONSERVATION COMMIS,.,,',)N APPLICATION FOR SUNDRY APPROVALS Abandon Suspend __ Operation Shutdown x Re-enter suspended well Alter casi~gg Repair well Plugging :Time extension StirnuJa-~ 1. Type of Request: Change approved program __ Pull tubing __ Variance__ Perforate Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska, Inc. Development ~ KBE = 36 feet Exploratory __ 3. Address Stratigraphic__ 7. Unit or Property name P. 0. Box 196612, Anchorage, Alaska 99519-6612 Service x Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1937' FSL, 2453' FEL, Section 36, T12N, R14E, UM At top of productive interval 2220' FSL, 1620' FEL, Section 31, T12N, R15E, UM At effective depth N/A At total depth 2233' FSL, 1347' FEL, Section 31, T12N, R15E, UM 12. Present well condition summary Total depth: Effective depth: measured 11671' feet Plugs (measured) true vertical 8502 feet measured N/A feet Junk (measured) true vertical N/A feet Casing Length Size Cemented Structural Conductor 76' 20" 11 yds ArcticSet Surface 3471' 13-3/8" ~o~6¢u~.~.~,~.~.~,~.~ Intermediate 10958' 9-5/8" 575 cu ft CI 'G' Production Liner 835' 7" 157 cu ft Cl 'G' Perforation depth: measured None AGI-4 9. Permit number 92-146 10. APl number 50- 029-22323 11. Field/Pool Prudhoe Bay Field/Oil Pool **Projected Measured depth 106' 3500' 10986' true vertical None Tubing (size, grade, and measured depth) None 10836'- 11671' RECEIVED JAN 1 3 199; Packers and SSSV (type and measured depth) None True verticalde~h 106' 3500' 8057' 8022'-8502' Alaska 0il & Gas Cons. C0mmissi0 Anchorage 13. Attachments Description summary of proposal x Detailed operations program BOP sketch 14. Estimated date for commencing operation January 15, 1993 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas ~ Suspended Service Apex Gas Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ned ,LJ[,. ~ Title Drillin~t Engineer Supervisor FOR COMMISSION USE ONLY Conditions of approval' Notify~Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance__ Mechanical Integrity Test~ Subsequent form required 10- ~./d ,~/' Approved by order of the Commission ~avid "~v~ ~ d.::;!nnston Form 10-403 Rev 06/15/88 Date IApproval No. ,~-~0 d__~ ? Commission/et .... Date / --/".,~~'~ SUBMIT IN TRIPLICATE SHUTDOWN OF WELL 0PERATION~ Attached is an APPLICATION FOR SUNDRY APPROVAL to shutdown well operations on AGI #4 once 9-5/8" casing has been set and cemented. 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/Z" TD, 7" liner run, and the well completed. Once AGI #10 is completed the rig will make its way back drilling 8-1/Z" hole, running 7" liner and completing all the wells in which operations were shutdown. The decision to drill AGI #4 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 #4 are expected to resume on or about 13APR93. 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. RECEIVED JAN 1 1993 Alaska 0il & Gas Cons. C0m~issio~ Anchorage WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 December 23, 1992 Michael Zanghi Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit AGI-4 ARCO Alaska, Inc. Permit No. 92-146 Sur. Loc 1937'FSL, 2453'FEL, Sec. 36, T12N, R14E, UM Btmhole Loc. 2233'FSL, 1347'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 the injection wells must be demonstrated under 20 AAC 25.412 and 20 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 petroleum field inspector on the North Slope pager at 659-3607. David W. Johh~on ~~ Chairman BY ORDER OF THE COMMISSION dlf/Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. f7TM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill Dll b. Type of well. Exploratory l-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenF-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 36'feet 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(see 20 AAC 25.025) 1937' FSL, 2453' FEL, Section 36, T12N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well number Number 2220' FSL, 1620' FEL, Section 31, T12N, R15E, UM AGI-4 U-630610 At total depth 9. Approximate spud date Amount 2233' FSL, 1347' FEL, Section 31, T12N, R15E, UM December 26, 1992 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(UDandmVD)' property line 1347feet AGI#2@ 1150'MD= 118 feet 2560 11671'MD/8502' TV~eet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 ,~c 25.035 (e)(2)) Kickoff depth ~eoofeet Maximum hole angleeo.,~° Maximum surface 2970psig At total depth (TVD) 8~(~{)'/3850psig 18. Casing program Specifications Setting Depth s~ze 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 Arcticset 16" 13-3/8" 68# L-80 B TC 3471' 29' 29' 3500' 3500' 2o16 cu ft 'E', 464 cu ft 'G' & 235 cu ft 'C' 12-1/4" 9-5/8" 47# L-80 NSCC 10958' 28' 28' 10986' 8057 575 cu fl Cl 'G' 8-1/2" 7" 26# L-80 NSCC 835' 10836' 8022' 11671' 8502' 157 cu ft Cl '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 Surface Intermediate Production Liner Perforation depth: measured ~.~~ true vertical Alaska OLL & Gas Con~ 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drillin.(jf~JS"r~'a~'T~ Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed "~'~~ -/~, /~."~,e~; Title Dr#ling Engineer Supervisor Date '(,,.~/ I ' Commission Use Only Permit Number IAPI number IA val. d~t~_ . ~- · ISee cover letter ~'~_/~, ~ J50-o>__?- 2_~'~..,~', ~~.__~ ~_ Jfor other requirements Conditions of approval Samples require, d [] Yes ~ No Mud log required 'l-lYes ~i No Hydrogen sulfide measures [] Yes ~ No Directional survey requlreo ~ Yes [] No Required working pressure for BOPE [] 2M; 1-13M; j~if~5M; I-I10M; I-I15M; Other: Origin~ ~.~i~nect By by order of Approved by Davici W. Johnston Commissioner the comm,ssion_ .Da!e./'.~_ Form 10-401 Rev. 12-1-85 Submit in triplicate AGI-4CMT.XLS State: Well: Field: State Permit Af,~,tka AGI.4 PRUDHOE ~qA Y ,.q2.145 Work Date: /~. Cemet~ Vdume Cdculation.e i2t21t~2 Casing Type Casing Size Casing Length Hole Diameter Cement-Sacks Cement- Yield Cement- Cubic It Cement- Cubic ft Cement- Sacks Cemerfl - Yield Cement- Cubic It Cement- Cubic It Cement-Sacks -Inches - Feet -Inches 111 111 111 111 112 112 112 112 113 Cement- Yield 113 Cement- Cubic ft 113 Cement- Cubic fl 1~3 Cement- Cubic It / Vol Cement- Fill Factor Cuing Type Casing Size -Inches Casing Depth- Feet Hole Diameter -Inches Cement- Sacks 111 Cement- Yield 111 Cement- Cubic t~t 11! Cement- Cubic tt Cement- Sacks 112 Cement- Yield 112 Cement-Cubic fl 112 Cement- Cubic Il 112 Cement- Sacks 113 Cement- Yield 113 Cement- Cubic ti 113 Cement- Cubic tt Cement- Cubic It /Vol Cement Intewai ft Top of Cement - Feet Conductor 20.000 76.000 30000 0.000 0.000 0.000 297.000 0.000 0.000 0.000 Q0O0 297.000 1.433 I~e~mediate 111 0.000 0.000 0.000 0.09 0.00 0.00 0.O0 0.00 0.00 0. O0 0.00 0.00 0.00 0.00 0.00 0.00 :I:IDIV/O! ~DIV/0! Surlace 13.375 3,471.O00 16.000 929.000 2.170 2,015.930 2,015.930 400.000 1.160 464.000 0.000 0.000 0.000 0.000 1.381 oK Intermediate 112 0.000 0.000 0.000 0.09 0.00 0.O0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIVt0! IIDIV,,"0! Prir, l~_r117/71 Lirlel 7.0OO 835.O00 8.500 0.000 0.000 O000 157.000 0.000 0.000 0.000 0.000 157.000 1.483 Production 9.625 10,986.000 12.250 0.00 0.00 0.00 575.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 575.00 1,835.99 9,150.0 1,4~,..,r~d Depth State: Alaska Borough: Well: AGI-4 Field: Prudhoe 19ay St. Perm ~ 92-146 Date 12/21/92 Engr: M. Minder AGL4.XLS Casing Interval Interval Size Boffom Description escription escription Tension Top Length lA 13.375 3500 29 3471 2A 9.625 8057 28 ~ 3A 7 8502 8022 835 4A 0 0 0 0 5A 0 0 0 0 6A 0 0 0 0 7A 0 0 0 0 8A 0 0 0 0 9A 0 0 0 0 10A 0 0 0 0 Lbs Grade Thread 68 ~ BTC 47 NSCC 26 L-80 NSCC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Lbs 0 0 0 0 0 0 0 0 0 0 Mud Hydraulic Wieght Gradient ppg psi/ff lB 9.5 0.494 2B 10.2 0.530 319 9.5 0.494 419 0.0 0.000 5B 0.0 0.000 6B 0.0 0.000 7B 0.0 0.000 8B 0.0 0.000 919 0.0 0.000 1 OB 0.0 0.000 Maximum Minimum Pressure Yield psi psi BDF 2970 ~ 1.2 2970 6870 2.3 2970 7240 2.4 0 0 #DlVl0! 0 0 #DIVIO! 0 0 #DIVIO! 0 0 #DIVIO! 0 0 #DIV/O! 0 0 #DIVIO! 0 0 #DIV/O! Tension Strength K/Lbs K/Lbs 2C 516.342 1086 3C 21.71 4C 0 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 'I'DF 4.53 2.10 604 27.82 0 #DIV/O! 0 #DIV/O! 0 #DIV/0! 0 #DIVIO! 0 #DlVlO! 0 #DIVIO! 0 #DIV/0! Collapse Collapse Pr-Bot-Psi Resist. CDF 1729 ~.~ 1.128 4273 4750 1.112 4200 5410 1.288 0 0 #DIV/O.I 0 0 #DIV/O! 0 0 #DIV/O.I 0 0 #DIVIO! 0 0 #DNIO! 0 0 #DIVi0! 0 0 #DIV/0! Peoe 1 WELL PLAN Well: APEX GAS INJECTOR #4 (AGI #4) LOCATION: Surface: Target: T.D.' 1937' FSL, 2453' FEL, Sec. 36, T12N, R14E 2220' FSL, 1620' FEL, Sec. 31, T12N, R15E 2233' FSL, 1347' FEL, Sec. 31, T12N, R15E ESTIMATED START: 26/DEC/92 OPR. DAYS TO COMPLETE: 20 (16 days drilling, 4 days completion) CONTRACTOR: AUDI RIG #2 MAXANGLE/SECT COURSE/KOP/BUILD/MAX DEP: 60.46°/S92.83E/3600'/2.5/5940' Estimated Ground level elevation is 13' AMSL. KB to ground level elevation is 36'. Item TVD(BKB) MD(BKB) Mud Wt. 20" CONDUCTOR 106 106 8.5 13-3/8" SHOE 3500 3500 9.0 9-5/8" SHOE 8057 10986 TOP SADLEROCHIT 8062 10994 9.2-10.0 7" SHOE 8502 11671 9.2-10.0 TARGET 8257 11305 9.2-10.0 TOTAL DEPTH 8502 11671 9.2-10.0 CASING PROGRAM: Hole Csg Wt Grade ,Conn Length ToD Btrrl 30" 20" 91.5# H-40 WELD 76 30 106 16" 13-3/8" 68# L-80 BTC 3471 29 3500 12-1/4" 9-5/8" 47# L-80 NSCC 10958 28 10986 8-1/2" 7" 26# L-80 NSCC 835 10836 11671 COMPLETION: Tubing: 7" GLMs: None Packer: 26# L-80 NSCC 10786 29 10735 9-5/8" x 5-1/2" PERMANENT PACKER set at 10786 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/RESISTIVITY WHILE DRILLING ACROSS SADLEROCHIT Cased Hole SBT IN 9-5/8" before running tubing (GR to be run up to 1 3-3/8") A'~i' ~.A GAS INJECTOR #4 (AGI #,. DRILLING DISCUSSION AGI #4 is the fourth 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 and AGI #3 may be available for injection purposes. Ensure any annulus has been properly permitted before commencing injection. The 1 3-3/8" 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. AOGCC 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. FREEZE PROTE(;TION 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 WEL, LNANIE SLOT DISTANCE DEPTH (' TVD) AGI # 1 AGI # 1 360' 900' TVD AGI #2 AG! #2 118' 1150' TVD AGI #3 AGI #3 122' 700' TVD LGI #12 LGI #12 578' 6550' TVD LGI #08 LGI #08 501' 7300' TVD PROPOSED DRILLING AND COMPLETION P OGRAM AGI #4 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 Bump cementing plug with 6. RIH to 2000' MD and displace to diesel. , 10. 11. ND BOPE. NU dryhole tree and test to 5000 psi. Release rig. Move off. 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 8-1/2" 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. 12. NU tree and test to 5000 psi. Release drilling rig. ° Anticipated BHP: ° Maximum Anticipated Surface Pressure: ° Planned Completion Fluid: 3850 psi @ 8800' TVD SS 2970 psi 9.6 ppg filtered brine Notes: a. 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/fi). c. No potential productive zones are anticipated above 9-5/8" casing shoe. d. No potential hazardous levels of H2S are anticipated in this well. PROGRAM: Well AGI #3 The mud program for this well shall follow the new Mud Policy. The following are the recommended mud parameters. MUD SPECIFICATIONS- SURFACE HOLE Surface: Casing point: Mud Weight: ppg 8.5 - 9.5 8.5 - 9.0 Funnel Viscosity sec/qt ~300 < 100 YP lbs/100ft2 40 - 60 20 - 40 10 sec Gel lbs/100ft2 30 - 60 15 - 20 10 min Gel Ibs/lO0ft2 60 - 80 20 - 30 pH - 9.0- 10 9,0- 10 APl Fluid loss mi/30 min 15-25 15-25 Hardness mg/I < 200 <200 .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/100ftZ 10 - 15 10 sec Gel lbs/10Oft2 5 - 10 10 min Gel lbs/100ft2 10 - 20 APl Fluid Loss mi/30 min 6-8 pH - 8.5 - 10.0 Hardness mg/I <200 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/10OftZ z0 - 30 10 sec Gel lbs/100ft2 18 - 2Z 10 min Gel Ibs/lO0ft2 20- 24 APl Fluid loss mi/30 min 6.0 - 8.0 pH - 9.5 - 10.0 Hardness mg/I <2:00 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 #4 Casing Design SURFACE CASING 13-3/8" G8#/FT K-55 & L-80 BTC CASING BURST COLLAPSE K-55 3450 1950 L-80 5020 2260 PB¥S (#) 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 3500 PBYS Tension S.F. 5.Z5 Mud Wt. 9.5 ppg TJYS 6.39 String Wt. (#) 203442 AGI #4 Casing Design Production Casing 9-5/8", 47#,L-80, NSCC Casing GRADE BURST L-80 6870 COLLAPSE PBYS (If) TJYS (If) 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 $.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/fi) Collapse press 10.2 8057 O. 1 3468 Collapse S.F. 1.37 Tension Calculation Based on full string weight in mud Casg Wt. (If/fi) MD (FT) 47 10986 PBYS Tension S.F. 2.49 Mud Wt. 10.2 TJYS 2.66 String Wt. (#) 435844 AGI #4 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 8403 O. 1 3617 Collapse S.F. 1.50 Tension Calculation Based on full string weight in mud Casg Wt. (#/f) MD (FT) 26 800 Mud Wt. String Wt. (#) 10.2 17557 Tension $.F. PBYS TJYS 34.40 37.99 .CE.MEN'C' ',iii .,OGRAM - HALLIBURTON . _ RVICES 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: 929 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 hrs 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 hrs MIX WATER: 3.5 gps FW Mix water temp: 50-65 F ~ 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. 5/8" INTERMEDIATE CASIN6 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" UNER CASING SI;~E; 7", 26# .CIRC. TEMp: 140° F CEMENT TYPE: CLASS G 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: 131 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 + 2% 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 ]}ax Drilling ~ [S ITHI Prudhoe Bay, Alaska ] Well' AGI-04 · VERTIC'AL VIEW SCALE 500 Ft, / DIVISION REFERENCE: WELL HEAD HDRIZ[]NTAL VIEW SCALE 1000 Ct, / DIVISION REFERENCE: WELL HEAD 3OOO~ --lOgO ! 13.375 OD, ~ 3500 MD, 3500 3500~__ _ k KOP BUILD RATE, 2.50 9EO/iO0 FT 9.625 OD, e 10986 MD, B05~~~ 3600--' , ? ~ .. ~ ' ~ h ~, ~ ~' ' ~ ~ t ~ooo 4500~~ 5O0 ~00 ' ]500 ' ~500 3500 4500 5500 ' 6500 5000~ i 1937' FSL; a453' FEL m ~ Inc AZl TVD ~th East ~ e~P q~, ~l~*. ~l~ ~ [R.K.B. [LEV 49' 0 0.00 0.00 0 0 0 ~ ) ~SP, Y = 5979576.47 : )END ~ BUIL~ 6018 60.46 87.17 ~)94 ~7 ~ ' Z - 6888~0 67 START DF ~ 10688 60 46 B7.17 78~4 ~58 ~ - ' )TOP SAO [0994 )4 ~l 87 17 806~ ~71 )47) ~ ' J TARGET 11305 48.00 97.17 8~57 ~B~ 5717i ~00~ ~a= ~ TARGET LOCATION, ' ~AVlK Z~S~ ~e. OO e7.~7 8453 ~93 5933 5594~- ....... ~ ~ - -~ ~,END OF BUILD ~a~O' FSL; 16EO' PEk TOTAL DEPTH 11671 48.00 87.17 850a ave ~ · SEC. 31; TI~N; R15E ~~ ASP, Y = 5~80004.~98 ~ X = 6945~7.8~7 m~ ~H~ ~ATA 6000~~ ~ BOTTOM HOLE LOCATION: ~v~ D 11671,1' ' ~ A~P, Y = 59800E5.49 vs 5~95 6i ~ [ X = 694799.34 North a95]8( E~s~ ~988.3~ 6500~ ~ 7500~ _ - 7894~ RT OF DROP ~ap RATE, e. O0 DEG/IO0 FT 8000~ 548~ ~ 9,6~5 OD, 8 10986 MD, 8057 TV9 806~ ~TOP SADLEROCHIT 57E4~ ~ TARGET 8~57 '" 845~ .... 5940 .... KAV]K 8500~~ TOTAL ~EPTH 850~ 5996 0 500 I000 1500 8000 ~500 3000 3500 4000 4500 5000 5500 6000 GSO0 VERTICAL SECTION PLANE', 87, 17° .,.~, CHECKED APPROVE~ , ,, .., 9.6a5 OD, e ~ , r ~'-~"--'"'-'-'~ .... ! I ~1 I z,. I ~ I' I': I Prudhoe Prudhoe AGI-04 Bay Bay Drilling HF1RIZ[]NTAL SCALE 1 000 REFERENCE: VIEW F't, / DIVISIF]N WELL HEAD TRUE 30.17 deg. East Oecl,nat~on I I00 1000 0 1000 2000 3000 4000 5000 6000 7000 8000 I000 000 000 000 'PPddhoe Bey Dpi~in9 Ppudhoe ~ey AOI-04 T~ave(~in9 C}4indeP - Re~epence ~e~/- AG-O4WP TVD: 0- 845~ F~, ~n~e~ve~ A~/ Directions Re~ ~o T~ue 0o 600 550 500 450 ' 400 350 P[one 50 £{, No~ {h 1i 270° 240o 120° 210° 180o 150° Smith International, Inc. Proposal Report Calculated using the Minimum Curvature Method Computed by the Sii Win-CADDS System Vertical Section Plane: 87.17 deg. Survey Reference: WELLHEAD Reference World Coordinates: Lat. 70.20.56.16 N - Long. 148.28.01.10 W Reference GRID System: ALaska State Plane Zone: ALaska 4 Reference GRID Coordinates: (feet): 5979576.47 N 688820.67 E Vertical Section Reference: WELLHEAD CLosure Reference: WELLHEAD North ALigned To: TRUE NORTH Page 1 Date: 12/16/92 We[Lpath ID: AGI-O4WP Last Revision: 12/16/92 Prudhoe Bay DriLLing Prudhoe Bay, ALaska WELL: AGI-04 Measured Inct Drift TVD Depth Oir. (ft) (deg.) (deg.) (ft) R.K.B. ELEVATION 49,0' ABOVE SEA LEVEL 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900:00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1900.00 2000.00 2100.00 2200.00 2300.00 2400.00 2500.00 2600.00 2700.00 2800.00 Subsea Depth (ft) 0.00 0.00 0.00 -49.00 0.00 0.00 100.00 51.00 0.00 0.00 200.00 151.00 0.00 0.00 .300.00 251.00 0.00 0.00 400.00 351.00 0.00 0.00 500.00 451.00 TOTAL Rectangular Offsets (ft) (ft) 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 N 0.00 N 0.00 0.00 600.00 551.00 0.00 0.00 0.00 700.00 651.00 0.00 0.00 0.00 800.00 751.00 0.00 0.00 0.00 900.00 0.00 0.00 1000.00 0.00 0.00 1100.00 0.00 0.00 1200.00 0.00 0.00 1300.00 0.00 0.00 1400.00 0.00 0.00 1500.00 0.00 0.00 1600.00 0.00 0.00 1700.00 0.00 0.00 1800.00 0.00 0.00 1900.00 0.00 0.00 2000.00 851.00 951,00 1051.00 1151.00 1251.00 1351.00 1451.00 1551.00 1651.00 1751.00 1851.00 1951.00 2051.00 2151.00 2251.00 2351.00 2451.00 2551.00 2651.00 2751.00 0.00 0.00 2100.00 0.00 0.00 2200.00 0.00 0.00 2300.00 0.00 0.00 2400.00 0.00 0.00 2500.00 0.00 0.00 2600.00 0.00 0.00 2700.00 0.00 0.00 2800.00 0.00 E 0.00 E : 0.00 E 0.00 E 0.00 E , 0.00 E 0.00 0.00 0.00 N ....... 0.00 E N 0.00 E N 0.00 E 0.00 0.00 0.00 N 0.00 E N 0.00 E N 0.00 E 0.00 0.00 0.00 N 0.00 E N 0.00 E N 0.00 E 0.00 0.00 0.00 N 0.00 E N 0.00 E N 0.00 E 0.00 0.00 0.00 N 0.00 E N 0.00 E N 0.00 E 0.00 0.00 0.00 N 0.00 E N 0.00 E N 0.00 E 0.00 ~: 0.00 a 0.00 E 0.00 E Geographic Coordinates Latitude / Longitude 70.20.56.1601 70.20.56.1601 70.20.56.1601 70.20.56.1601 70.20.56.1601 70.20.56.1601 70.20.56.1601 70.20.56.1601 70.20.56.1601 70.20.56.1601 70.20.56.1601 70.20.56.1601 70.20.56.1601 70.20.56.1601 70.20.56.1601 70.20.56,1601 70.20.56.1601 70.20.56.1601 70.20.56.1601 70.20.56.1601 70.20.56.1601 70.20.56.1601 70.20.56.1601 70.20.56.1601 70.20.56.1601 70.20.56.1601 70.20.56.1601 70.20.56.1601 70.20.56.1601 N 148.28.01.0988 W N 148.28.01.0988 W N 148.28.01.0988 W N 148.28,01.0988 N 148.28.01.0988 N 148.28.01.0988 N 148.28.01.0988 N 148.28.01.0988 N 148.28.01.0988 N 148.28.01.0988 W N 148.28.01.0988 W N 148.28.01.0988 W N 148.28.01.0988 W N 148.28.01.0988 W N 148.28.01.0988 W 148.28.01.0988 148.28.01.0988 148.28.01.0988 N 148.28.01.0988 W N 148.28.01.0988 W N 148.28.01.0988 W N 148.28.01.0988 N 148.28.01.0988 N 148.28.01.0988 N 148.28.01.0988 N 148.28.01.0988 N 148.28.01.0988 N 148.28.01.0988 N 148.28.01.0988 GRID Coordinates Northing Easting (ft) (ft) 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 5979576.47 688820.67 CLosure Dist. Oir. (fL) deg. 0.00 g 0.00 0.00 a 0.00 0,00 a 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 a 0.00 0.00 @ 0.00 0.00 a 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 a o.oo 0.00 a 0.00 0.00 @ 0.00 0.00 a 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 8. 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 0.00 @ 0.00 Vertical DLS Section (ft) (dg/lOOft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 O. O0 O. O0 0.00 0.00 0.00 0.00 0.00 0.00 Smith International, Inc. Proposal Report Page Z Date: 12/16/92 WeLLpath ID: AGI-O4WP Heasured lnc[ Drift TVD Subsea Depth Dir. Depth (ft) (deg.) (deg.) (ft) (ft) 2900.00 0.00 0.00 2900.00 2851.00 3000.00 0.00 0.00 3000.00 2951.00 3100.00 0.00 0.00 3100.00 3051.00 3200.00 0.00 0.00 3200.00 3151.00 3300.00 0.00 0.00 3300.00 3251.00 3400.00 0.00 0.00 3400.00 3351.00 3500.00 0.00 0.00 3500..00 3451.00 KOP 3600.00 0.00 0.00 3600.00 3551.00 3700.00 2.50 87.17 3699.97 3650.97 3800.00 5.00 87.17 3799,75 3750.75 3900.00 7.50 87.17 3899.14 3850.14 4000.00 10.00 87.17 3997.97 3948.97 4100.00 12.50 87.17 4096.04 4047.04 4200.00 15.00 87.17 4193.17 4144.17 4300.00 17.50 87.17 4289.17 4240.17 4400.00 20.00 87.17 4383.85 4334.85 4500.00 22.50 87.17 4477.05 4428.05 4600.00 25.00 87.17 4568.57 4519.57 4700.00 27.50 87.17 4658.25 4609.25 4800.00 30.00 87.17 4745.92 4696.92 4900.00 32.50 87.17 4831.40 4782.40 5000.00 35.00 87.17 4914.54 4865.54 5100.00 37,50 87.17 4995.18 4946.18 5200.00 40.00 87.17 5073.16 5024.16 5300.00 42.50 87.17 5148.34 5099.34 5400.00 45.00 87.17 5220.57 5171.57 5500.00 47.50 87.17 5289.72 5240.72 5600.00 50.00 87.17 5355.64 5306.64 5700.00 52.50 87.17 5418.23 5369.23 5800.00 55.00 87.17 5477.36 5428.36 5900.00 57.50 87.17 5532.91 5483.91 6000.00 60.00 87.17 5584.78 5535.78 END OF BUILD 6018.21 60.46 87.17 5593.82 5544.82 6118.21 60.46 87.17 5643.14 5594.14 6218.21 60.46 87.17 5692.45 5643.45 6318.21 60.46 87.17 5741.76 5692.76 6418.21 60.46 87.17 5791.07 5742.07 6518.21 60.46 87.17 5840.38 5791.38 '6618.21 60.46 87.17 5889.69 5840.69 6718.21 60.46 87.17 5939.00 5890.00 TOTAL Rectangutar Offsets (ft) (ft) 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.11 N 2.18 E 0.43 N 8.71 E 0.97 N 19.58 E 1.72 N 34.78 E 2.68 N 54.26 E 3.85 N 78.00 E 5.23 N 105.94 E 6.82 N 138.05 E 8.61 N 174.24 E 10.60 N 214.47 E 12.78 N 258.64 E 15.15 N 306.67 E 17.71 N ':~358.48 E 20.45 N 413.97 E 23.37 N 473.02 E 26.46 N 535.53 E 29.71 N 601.38 E 33.12 N 670.44 E 36.69 N 742.59 E 40.40 N 817.67 E 44.25 N 895.56 E 48.23 N 976.10 E 52.33 N 1059.14 E 56.55 N 1144.52 E 57.33 N 1160.30 E 61.62 N 1247.20 E 65.91 N 1334.09 E 70.20 N 1420.98 E 74.50 N 1507.87 E 78.79 N 1594.76 E 83.08 N 1681.65 E 87.38 N 1768.54 E Geographic Coordinates Latitude / Longitude 70.20.56.1601 N 148.28.01.0988 70.20.56.1601 N 148.28.01.0988 70.20.56.1601 N 148.28.01.0988 70.20.56.1601 ~ 148.28.01.0988 70.20.56.1601 N 148.28.01.0988 70.20.56.1601 N 148.28.01.0988 70.20.56.1601 N 148.28.01.0988 W 70.20.56.1601 N 148.28.01.0988 70.20.56.1612 N 148.28.01.0351 70.20.56.1643 N 148.28.00.8442 70.20.56.1696 N 148.28.00.5265 70.20.56.1770 N 148.28.00.0825 70.20.56.1865 N 148.27.59.5131 70.20.56.1980 N 148.27.58.8194 70.20.56.2116 N 148.27.58.0027 70.20.56.2272 N 148.27.57.0646 70.20.56.2448 N 148.27.56.0068 70.20.56.2643 N 148.27.54.8313 70.20.56.2858 N 148.27.53.5405 70.20.56.3091 N 148.27.52.1367 70.20.56.3343 N 148.27.50.6226 70.20.56.3613 N 148.27.49.0011 70.20.56.3899 N 148.27.47.2754 70.20.56.4203 N 148.27.45.4485 70.20.56.4523 N 148.27.43.5242 70.20.56.4859 N 148.27.41.5060 70.20.56.5209 N 148.27.39.3977 70.20.56.5574 ~ 148.27.37.2034 70.20.56.5953 N 148.27.34.9272 70.20.56.6344 N 148.27.32.5735 70.20.56.6747 N 148.27.30.1468 70.20.56.7162 N 148.27.27.6517 70.20.56.7239 N 148.27.27.1904 70.20.56.7661 N 148.27.24.6511 70.20.56.8084 N 148.27.22.1118 70.20.56.8506 N 148.27.19.5725 70.20.56.8928 N 148.27.17.0332 70.20.56.9350 N 148.27.14.4939 70.20.56.9772 N 148.27.11.9546 70.20.57.0195 N 148.27.09.4153 GRID Coordinates Ctosure Northing Easting Dist. Dir. (ft) (ft) (ft) deg. 5979576.47 688820.67 0.00 @ 0.00 5979576.47 688820.67 0.00 a 0.00 5979576.47 688820.67 0.00 ~ 0.00 5979576.47 688820.67 0.00 a 0.00 5979576.47 688820.67 0.00 @ 0.00 5979576.47 688820.67 0.00 @ 0,00 5979576.47 688820.67 0.00 @ 0.00 5979576.47 688820.67 0.00 a 0.00 5979576.63 688822.85 2.18 a 87.17 5979577.12 688829.37 8.72 5979577.93 688840.22 19.61 5979579.06 688855.39 34.82 Vertical DLS Section (ft) (dg/lOOft) 5979580.52 688874.84 5979582.29 688898.54 5979584.37 688926.45 0.00 0.00 0.00 0.00 0.00 0.00 5979586.77 688958.50 5979589.47 688994.64 5979592.47 689034.80 0.00 0.00 0.00 0.00 0.00 0.00 5979595.76 689078.90 5979599.35 689126.86 5979603.22 689178.58 0.00 0.00 5979607.36 689233.98 5979611.76 689292.94 5979616.43 689355.35 0.00 0.00 2.18 2.50 5979621.35 689421.10 5979626.50 689490.05 5979631.89 689562.08 87.17 8.72 2.50 87.17 19.61 2.50 87.17 34.82 2.50 5979637.50 689637.04 5979643.32 689714.81 5979649.33 689795.22 54.33 @ 87.17 54.33 2.50 78.09 a 87.17 78.09 2.50 106.07 @ 87.17 106.07 2.50 138.21 @ 87.17 138.21 2.50 174.46 @ 87.17 174.46 2.50 214.73 @ 87.17 214.73 2.50 258.95 @ 87.17 258.95 2.50 307.05 a 87.17 307.05 2.50 358.92 ~ 87.17 358.92 2.50 414.47 8 87.17 414.47 2.50 473.60 @ 87.17 473.60 2.50 536.19 ~ 87.17 536.19 2.50 602.12 @ 87.17 602.12 2.50 671.26 a 87.17 671.Z6 2.50 743.49 a 87.17 743.69 2.50 818.67 a 87.17 818.67 2.50 896.65 a 87.17 896.65 2.50 977.29 a 87.17 977.29 2.50 5979655.54 689878.12 1060.43 @ 87.17 5979661.92 689963.37 1145.92 @ 87.17 5979663.10 689979.13 1161.72 a 87.17 87.17 87.17 87.17 5979669.59 690065.88 1248.72 5979676.09 690152.63 1335.71 5979682.59 690239.38 1422.71 87.17 87.17 87.17 5979689.08 690326.13 1509.71 5979695.58 690412.89 1596.70 5979702.08 690499.64 1683.70 5979708.58 690586,39 1770.70 ~ 87.17 1060.43 2.50 1145.92 2.50 1161.72 2.50 1248.72 0.00 1335.71 0.00 1422.71 0.00 1509.71 0.00 1596.70 0.00 1683.70 0.00 1770.70 0.00 Smith International, Inc. Proposal Report Page 5 Date: 12/16/92 WeLLpath ID: AGI-O4WP Measured Inc[ Drift Depth Dir. (ft) (deg.) (deg.) 6818.21 60.46 87.17 6918.21 60.46 87.17 7018.21 60.46 87.17 7118.21 60.46 87.17 7218.21 6~.46 87.17 7318.21 60.46 87.17 7418.21 60.46 87.17 7518.21 60.46 87.17 7618.21 60.46 87.17 7718.21 60.46 87.17 7818.21 60.46 87.17 7918.21 60.46 87.17 8018.21 60.46 87.17 8118.21 60.46 87.17 8218.21 60.46 87.17 8318.21 60.46 87.17 8418.21 60.46 87.17 8518.21 60.46 87.17 8618.21 60.46 87.17 8718.21 60.46 87.17 8818.21 60..46 87.17 8918.21 60.46 87.17 9018.21 60.46 87.17 9118.21 60.46 87.17 9218.21 ' 60.46 87.17 9318.21 60.46 87.17 9418.21 60.46 87.17 9518.21 60.46 87.17 9618.21 60.46 87.17 9718.21 60.46 87~17 9818.21 60.46 87.17 9918.21 60.46 87.17 10018.21 60.46 87.17 10118.21 60.46 87.17 10218.21 60.46 87.17 10318.21 60.46 87.17 10418.21 60.46 87.17 105{8.21 60.46 87.17 10618.21 60.46 87.17 START~OF DROP 10682.23 60.46 87.17 10782.23 58.46 87.17 TVD (ft) 5988.31 6037.62 6086.93 6136.24 6185.55 6234.86 6284.17 6333.48 6382.79 6432.10 6481.41 6530.72 6580.03 6629.34 6678.65 6727.96 6777.28 6826.59 6875.9O 6925.21 6974.52 7023.83 7073.14 7122,45 7171.76 7221.07 7270.38 7319.69 ?369. O0 7418.31 7467.62 7516.93 7566.24 7615.55 7664.86 7714.17 7763.48 7812.79 7862.10 Subsea Depth (fL) 5939.31 5988.62 6037.93 6087.24 6136.55 6185.86 6235.17 6284.48 6333.79 6383.10 6432.41 6481.72 6531.03 6580.34 6629.65 6678.96 6728.28 6777.59 6826.90 6876.21 6925.52 6974.83 7024.14 7073.45 7122.76 7172.07 7221.38 7270.69 ?320.00 7369.31 7418,62 7467.93 7517.24 7566.55 7615.86 7665.17 7714.48 7763.79 7813.10 TOTAL Rectangular Offsets (ft) (ft) 91.67 N 1855.43 E 95.96 N 1942.32 E 100.26 N 2029.21E 104.55 N 2116.11E 108.84 N 2203.00 E 113.13 N 2289.89 E 117.43 N 2376.78 E 121.72 N 2463.67 E 126.01N 2550.56 E 130.31N 2637.45 E 134.60 N 2724.34 E 138.89 N 2811.23 E 143.18 N 2898.13 E 147.48 N 2985.02 E 151.77 N 3071.91E 156.06 N 3158.80 E 160,36 N 3245.69 E 164.65 N 3332.58 E 168.94 N 3419.47 E 173.23 N 3506.36 E 177.53 N 3593.25 E 181.82 N 3680.14 E 186.11 N -3767.04 E 190.41 N 3853.93 E 194.70 N 3940.82 E 198.99 N 4027.71 E .203.29 N 4114.60 E 207.58 N 4201.49 E 211.87 N 4288.38 E 216.16 N 4375.27 E 220.46 N 4462.16 E 224.75 N 4549.05 E 229.04 N 4635.95 E 233.34 N 4722.84 E 237.63 N 4809.73 E 241.92 N 4896.62 E 246.21N 4983.51E 250.51 N 5070.40 254.80 N 5157,29 E 7893.67 7844.67 257.55 N 5212.92 E 7944.49 7895.49 261.80 N 5298.93 E Geographic Coordinates Latitude / Longitude 70.20.57.0617 ~ 148.27.06.8760 70.20.57.1039 N 148.27.04.3367 70.20.57.1461 ~ 148.27.01.7974 70.20.57.1883 ~ 148.26.59.2581 70.20.57.2306 N 148.26.56.7188 70.20.57.2728 N 148.26.54.1795 70.20.57.3150 ~ 148.26.51.6402 70.20.57,3572 N 148.26.49.1009 70.20.57.3995 N 148.26.46.5616 70.20.57.4417 N 148.26.44.0222 70.20.57.4839 N 148.26.41.4829 70.20.57.5261 N 148.26.38.9436 70.20.57.5683 N 148.26.36.4043 70.20.57.6106 N 148.26.33.8650 70.20.57.6528 N 148.26.31.3257 70.20.57.6950 N 148.26.28.7863 70,20.57.7372 N 148.26.26.2470 70.20.57.7794 N 148.26.23.7077 70.20.57.8217 N 148.26.21.1684 70.20.57.8639 N 148.26.18.6290 70.20.57.9061 N 148.26.16.0897 70.20.57.9483 N 148.26.13.5504 70.20.57.9906 N 148.26.11.0110 70.20.58.0328 N 148.26.08.4717 70.20.58.0750 N 148.26.05.9324 70.20.58.1172 N 148.26.03.3930 70.20.58.1594 N 148.26.00.8537 70.20.58.2017 N 148.25.58.3144 70.20.58.2439 N 148.25.55.7750 70.20.58.2861 N 148.25.53.2357 70.20.58.3283 N 148.25.50.6963 70.20.58.3705 N 148.25.48.1570 70.20.58.4128 N 148.25.45.6176 70.20,58.4550 H 148.25.43.0783 70.20.58.4972 H 148.25.40.5389 70.20.58.5394 N 148.25.37.9996 70.20.58.5817 H 148.25.35.4602 70.20.58.6239 H 148.25.32.9209 70.20.58.6661 N 148.25.30.3815 70.20.58.6931 N 148.25.28.7559 70.20.58.7349 N 148.25.26.2421 GRID Coordinates CLosure Northing Easting Dist. Dir. (fL) (fL) (ft) deg. 5979715.08 690673.14 1857.70 a 87.17 5979721.59 690759.89 1944.69 @ 87.17 5979728.09 690846.64 2031.69 a 87.17 5979734.60 690933.39 2118.69 a 87.17 5979741.10 691020.15 2205.68 @ 87.17 5979747.61 691106.90 2292.68a 87.17 5979754.12 691193.65 23?9.68 a 87.17 5979760.62 691280.40 2466.67 a 87.17 5979767.13 691367.15 2553.67 @ 87.17 5979773.65 691453.90 2640.67 @ 87.17 5979780.16 691540.65 2727.67 @ 87.17 5979786.67 691627.40 2814.669 87.17 5979793.18 691714.15 2901.66 @ 87.17 5979799.70 691800.90 2988.66 @ 87.17 5979806.21 691887.65 3075.65 @ 87.17 5979812.73 691974.40 3162.65 5979819.25 692061.15 3249.65 5979825.77 692147.90 3336.65 87.17 87.17 87.17 5979832.29 692234,65 3423.64 @ 87.17 5979838.81 692321.40 3510.64 @ 87.17 5979845.33 692408.16 3597.64 @ 87.17 5979851.85 692494.91 3684.63 @ 87.17 5979858.38 692581.65 3771.63 @ 87.17 5979864.90 692668.40 3858.63 @ 87.17 5979871.43 692755.15 3945.62 @ 87.17 5979877.95 692841.90 4032.62 @ 87.17 5979884.48 692928.65 4119.62 @ 87.17 5979891.01 693015.40 4206.62 @ 87.17 5979897.54 693102.15 4293.61 @ 87.17 5979904.07 693188.90 4380.61 @ 87.17 5979910.60 693275.65 5979917.14 693362.40 5979923.67 693449.15 4467.61 @ 87.17 4554.60 @ 87.17 4641.60 @ 87.17 5979930.20 693535.90 5979936.74 693622.65 5979943.28 693709.40 4728.60 @ 87.17 4815.59 @ 87.17 4902.59 @ 87.17 5979949.81 693796.15 4989.59 @ 87.17 5979956.35 693882.89 5076.59 @ 87.17 5979962.89 693969.64 5163.58 @ 87.17 5979967.08 694025.18 5219.28 @ 87.17 59799?3.56 694111.05 5305.40 @ 87.17 Vertical DLS Section (ft) (dg/lOOft) 1857.70 0.00 1944.69 0.00 2031.69 0.00 2118.69 0.00 2205.68 0.00 2292.68 0.00 2379.68 0.00 2466.67 0.00 2553.67 0.00 2640.67 0.00 2727.67 0.00 2814.66 0.00 2901.66 0.00 2988.66 0.00 3075.65 0.00 3162.65 0.00 3249.65 0.00 3336.65 0.00 3423.64 0.00 3510.64 0.00 3597.64 0.00 3684.63 0.00 3771.63 0.00 3858.63 0.00 3945.62 0.00 4032.62 0.00 4119.62 0.00 4206.62 0.00 4293.61 0.00 4380.61 0.00 4467.61 0.00 4554.60 0.00 4641.60 0.00 4728.60 0.00 4815.59 0.00 4902.59 0.00 4989.59 0.00 5076.59 0.00 5163.58 0.00 5219.28 0.00 5305.40 2.00 Smith International, Inc. Proposal Report Page 4 Date: 12/16/92 Weltpath ID: AGI-O4WP Measured Inct Drift TVD Depth Oir. (ft) (deg.) (deg.) (ft) Subsea Depth (ft) 10882.23 56.46 87.17 7998.28 7949.28 10982.23 54.46 87.17 8054.99 8005.99 TOP SADLEROCHIT 10994.26 54.21 87,17 8062.00 8013.00 11082.23 52.46 87.17 8114.53 8065.53 11182.23 50.46 87.17 8176.84 8127.84 11282.23 48.46 87.17 8241.84 8192.84 TOTAL Rectangutar Offsets (ft) (ft) 265.96 N 5383.12 E 270.02 N 5465.39 E 270.50 N 5475.15 E 273.99 N 5545.62 E 277.85 N 5623.74 E 281.60 N 5699.63 E TARGET 11304.98 48.00 87.17 8257.00 8208.00 282.43 N 5716.58 E 11404.98 48.00 87.17 8323.91 8274.91 286.10 N 5790.81 E 11504.98 48.00 87.17 8390.83 8341.83 289.77 N 5865.03 E KAVIK 11596.41 48.00 87.17 8452.00 8403.00 293.12 N 5932.89 E TOTAL DEPTH 11671.13 48.00 87.17 8502.00 8453.00 295.86 N 5988.35 E Geographic Coordinates Latitude / Longitude 70.20.58.7758 H 148.25.23.7817 70.20.58.8158 N 148.25.21.3776 70.20.58.8205 N 148.25.21.0923 70.20.58.8548 N 148.25.19.0327 70.20.58.8927 N 148.25.16.7499 70.20.58.9296 N 148.25.14.5319 70.20.58.9379 N 148.25.14.0365 70.20.58.9739 N 148.25.11.8673 70.20.59.0100 N 148.25.09.6981 70.20.59.0430 N 148.25.07.7150 W 70.20.59.0699 N 148.25.06.0941 GRID Coordinates C[osure Northing Easting Dist. Dir. (ft) (ft) (ft) deg. 5979979.90 694195.10 5389.69 @ 87.17 5979986.09 694277.23 5472.05 @ 87.17 5979986.83 694286.98 5481.83 @ 87.17 5979992.13 694357.34 5552.39 @ 87.17 5979998.02 694435.32 5630.60 @ 87.17 5980003.74 694511.09 5706.58 @ 87.17 5980005.01 694528.02 5723.55 @ 87.17 5980010.61 694602.12 5797.87 @ 87.17 5980016.20 694676.22 5872.18 @ 87.17 5980021.31 694743.97 5940.12 @ 87.17 5980025.49 694799.34 5995.66 @ 87.17 Vertica[ DLS Section (ft) (dg/lOOft) 5389.69 2.00 5472.05 2.00 5481.83 2.00 5552.39 2.00 5630.60 2.00 5706.58 2.00 5723.55 2.00 5797.87 0.00 5872.18 0.00 5940.12 0.00 5995.66 0.00 I 00LU -015 ~,,,~zzzzzz ~:~ZZ~ZZZ ~1 I I I I I I I I Smith International, Inc. Travelling CYlinder Report Computed by the Sii Win-CADDS System Normal Plane Method Page 1 Date: 12/16/92 REFERENCE WELL: Prudhoe Bay Drilling Prudhoe Bay, Alaska Weft: AG[-04 TVD, N/S and E/N are measured from the WELLHEAD Wet[path Stot AGI-OISV ' AGI-01 AGI-O2MWO AGI-02 AGI-O3WP AGI-03 LGI-02 LGI-02 LGI-04 LGI-04 LGI-06 LGI-06 LGI-08 LGI-08 LGI-IO LGI-IO LGI-12 LGI-12 Closest Points Distance Direction Ref MD Ref TVD 359.58 168.92 900.00 241.96 167;85 0.00 122.11 165.80 700.00 1936.01 189.20 7754.50 3345.96 165.77 100.00 1457.90 72.17 11058.25 501.37 4~.16 9478.28 1745.29 60.01. ~ 8058.70 577.87 199.93 7957.30 900.00 0.00 700~00 6450.00 100.00 8100.00 7300.00 6600.00 6550.00 su , Two lines venting 90 deg. apart in directions that ensure sale down wind venting, and tending to a point at least 100' from any petenti~l'"'" source ol ignition. 10' Full Opening Valves 35' or ss required ,._1 Dresser Sleeve 10' Diverter Line 1. All pipe connec'lJons 150¢ ANSI Ranges or welded connections and secured to prevent movemenL 2_ Manual 10" lull opening valves mechanically connected to ensure that one valve is fail-sate open at all times. 3. All tums are 90 deg. and targeted. 10' Full opening ball valve w/Hydraulic Actuator Cellar 20' Diverter Spool w/10' Side Outlet MEM 1/'3/90 etosuoo o! -t ~assuBt<l PnH o5~tldscuq~/ ooI~.:~G - I cc:m-oCl (I) "] s~uco ~I/~'~ 11911' cour'~ .~apues~(l aImlS aUOD ,,EI-9 oou,~x] - I :~a~mtiS ~IPtlS uraptreA itn~] qptmn~l - I AUDI #2 13 5/8" 5,000 psi Stack 2.00 4.12 RKB ~ I DRIP PAN . RIG FLOOR 12.72 4.50 I 3.01 .,,i 3.01 1.83 3.01 2.52 1.5 Ill I GROUND LEVEL i i i ii ii i i i i J HYDRIL 17.88 PIPE RAM BLIND RAM I'~U'D ' CROSS PIPE RAM 22.38 25.3 30.23 34.25 I MUI~ ' ~~)~] CROSS 35.75 ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE [2 thru le 2. 3. 4. 5~ 6. 7. 8. 9. 10. 11. 12. //&¢/,¢'¢. -r,'- ? '[-§ ~-hru 1~]'-' [10 & 13] 13. [14 thru 22] 15. [23 thru 28] 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. (5) BOPE (6) Other /~(__. /"L/~,¢.~,~..~ 29. [ 29 thr~u '~ 1] 30. ~7) Contact /~/~ 31. 32. . %32] (8) Addl ~~.¢~,¢./,I~.~.~-~.._. 33. geology: enaineering: DWd~ MT~, BEW ' JDH LG_~-)-~ Company Lease & Well rev 12/92 jo/6.011 YES Is permit fee attached ............................................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............. Is well to be deviated $ is wellbore plat included ................... Is 'operator the only affected party .................................. .~ . Can permit be approved before 15-day wait ............................ NO Does operator have a bond in force ................................. '.. Is a conservation order needed ....................................... ~__ Is administrative approval needed ..................... ............... Is lease ncrnber appropriate .......................................... Does well have a unique name & ntrnber ................................ Is conductor string provided ......................................... Will surface casing protect al 1 zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface $ intermediate or production strings ...... /~' Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. .~... Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter System required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~O~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLOPJ~TORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone ncrnber of contact to supply weekly progress data ...... Additional requirements ............................................. Additional remarks' REMARKS / ./ UM HERIDIAN' SM Exp/Dev Inj WELL ,TYPE.: Redri 1 l-- Rev .... 'IN'IT'IAL GEOL UNIT O'N/OFF POOL CLASS STATUS AREA ~ SHORE , , ...... 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-4 PRUDHOE BAY Date ~..__ ATCC ATCl ATDC ATD1 CADE CAD1 CPDE CPD1 DCCC DCC1 GRAC GRA1 PDCC PDCl PDDC PDD1 PDEM PDE1 RACC RACl RADE RAD1 ROPA ROPS RPCC RPCl RPDE RPD1 TCDC TCD1 Note: BELOW ARE THE MNEMONICS THAT CAN BE FOUND ON THE US TAPE GENERATED FOR ARCO ALASKA AGI-4 Attenuation Borehole Corrected [RWD + MWD] Attenuation Borehole Corrected Relog I [RWD] Attenuation Dielectric Corrected [RWD + MWD] Attenuation Dielectric Corrected Relog 1 [RWD] Conductivity (AT) Corrected for Dielectric Effect [RWD] Conductivity (AT) Corrected for Dielectric Effect Relog 1 [RWD] Conductivity (PD) Corrected for Dielectric Effect [RWD] Conductivity (PD) Dielectric Corrected Relog 1 [RWD] Calculated Dielectric Constant [RWD + MWD] Calculated Dielectric Constant Relog 1 Gamma Ray Memory (APl) [RWD + MWD] Gamma Ray Memory (APl) Relog I [RWD] Phase Difference Borehole Corrected [RWD + MWD] Phase Difference Borehole Corrected [RWD] Phase Difference Dielectric Corrected [RWD + MWD] Phase Difference Dielectric Corrected Relog 1 [RWD] Phase Difference Elapsed Time [RWD] Phase Difference Elapsed Time Relog 1 [RWD] Resistivity (AT) Borehole Corrected [RWD + MWD] Resistivity (AT) Borehole Corrected Relog 1 [RWD] Resistivity (AT) Corrected Dielectric Effect [RWD] Resistivity (AT) Corrected for Dielectric Effect Relog 1 [RWD] Rate of Penetration Averaged Rate of Penetration Resistivity (PD) Borehole Corrected [RWD + MWD] Resistivity (PD) Borehole Corrected Relog 1 [RWD] Resistivity (PD) Corrected for Dielectric Effect [RWD] Resistivity (PD) Corrected for Dielectric Effect Relog 1 [RWD] CDS Temperature [RWD + MWD] CDS Temperature Relog 1 [RWD] AT is Attenuation PD is Phase Difference MWD is Measurement While Drilling RWD is Recorded While Drilling -dB -dB -dB -dB mmho/m mmho/m mmho/m mmho/m MWD-API MWD-API deg deg deg deg mins rains ohm-m ohm-m ohm-m ohm-m fi/hr fi/hr ohm-m ohm-m ohm-m ohm-m deg F deg F Copyright 1987,1988,1989,1990,1991 By WESTERN ATLAS INTERNATIONAL, INC. All rights reserved. PROGRAM: TAPESCAN REVISION: 2.64 Start of execution: Fri 1 OCT 93 2:04p != = ECHOING INPUT PARAMETERS INPUT PARAMETER FILE: TAPESCAN.INP =! 1 2 3 4 5 6 7 123456789012345678901234567890123456789012345678901234567890123456789012 I AUTOCURV = 0 , I Automatic Curve renaming: 0=OFF, 1 =ON 2 AUTOFILE = 0 , ~ Automatic FILE= generation: 0--OFF, 1 =ON 3 COMMENTS = I , ~ Decode US Comment records: 0=OFF, 1 =ON 4 INFORECS = 1 , ! Decode US Information records: 0=NO,1 =YES 5 LlSTMETHOD = 0 , ~Usting Method: 0=depth units 1 =tape units 6 LISTFREQ = 100, I Usting Frequency: Every n units 7 LlSTMAX = 0 , ! Usting Maximum (0=no limit, value=list limit) 8 STATS = 0 , ! Statistics generation: 0=OFF, 1 =ON 9 FORCETYP = 0 , I (1 = BIT,2= US ... thru 35=Array Accoustic) (see table) 10 WRITEASCIi = 0 , I If 1, all ascii files will be written (file0001.dat,etc.) 11 WRITETAP = 1 , ~ Write Tape-Image File: 0=NO,1 --YES 12 SPLITES = 1 , ~ If I and WRITETAP on, split US logical files to physical 13 SUBFILES = /0/, ~ Tape Subfile 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 = 1 , INFORECS = 1 , LISTMETHOD = 0 , LISTFREQ = 100, LISTMAX = 0, STATS = 0, FORCETYP = 0 , WRITEASCII = 0 , WRITETAP = 1 , SPMTMS = 1, SUBFILES = /0/, INTERPOLATE = 'YES' END !-- PROCESSING INTERVAL FROM 0.000 TO 0.000 !- CONSTANT PARAMETERS 00'6666- = (~6)S~'II.-IEII'IS 00'6666- = (m)Sa31USnS 00'6666- = (06)S~'II_-ISI'IS 00'6666- = (68)S~Ii_-IEIi'IS oo'eeee- = (es)s~asns oo'6eas- = (zs)sa~usns oo'eeee- = (ge)sa31aans oo'6e~- = (ss)S~laans oo'eeee- = (~)sa31aans oo'eeee- = (ee)sa31aans oo'6eee- = (se)sa31aans oo'eeee- = (m)Sa~laans oo'eeee- = (os)sa~uans oo'eeee- = (sz)sa~aans oo'6eee- = (ez)sa~usns oo'eeee- = (zz)sa~usns oo'eeee- = (gz)sa~usns oo'eeee- = (sz)sa~usns oo'6eee- = (~z)sa~usns oo'eeee- = (~z)sa~usns oo'6eee- = (~z)sa~usns oo'eeee- = (~z)sa~usns oo'6eas- = (oz)sa~usns oo'eeee- = (69)s~usns oo'eeee- = (e9)sa~usns oo'eeee- = (z9)sa3usns oo'eeee- = (99)sa~usns oo'eeee- = (s9)sa3usns oo'r~ee- = (~9)sa~usns oo'eeee- = (e9)sa~usns oo'6eee- = (~9)sa~uans oo'r~ee- = (m)sa~uans oo'6eee- = (o9)sa~usns oo'eeee- = (6s)sa~usns oo'6eee- = (ss)sa3usns oo'eeee- = (zs)sa~usns oo'eeee- = (gs)s~usns oo'eeee- = (ss)sa3usns oo'eeee- = (rs)sa~usns oo'eeee- = (es)sa~usns oo'6eee- = (~s)sa~usns oo'eeee- = (~s)sa~usns oo'eeee- - (os)sa~uans oo'eeee- = (6~)sa31aans oo'6eee- = (er)s~usns oo'eeee- = (z~)s~usns 00'6666- = (9~)sa~usns oo'eeee- = (s~)sa~asns oo'6ee~- = (~,)sa~usns oo'6eee- = (~)s~usns oo'6eee- = (~)sa3usne oo'eeee- = (~)s~usns oo'6eas- = (w)sa~usns oo'eeee- = (6~)sa~uans oo'eeee- = (ee)sa~usns oo'eeee- = (ze)s~uans oo'eeee- = (9e)sa~usns oo'eeee- = (se)sa~usns oo'6eee- = (~e)sa~asns 00'666~- = (~)s~asns oo'eeee- = (~)sa~usns oo'6eee- = (~)sa3usns oo'eeee- = (oe)sa~usns oo'66ee- = (6s)s:musns oo'eeee- = (ss)sa31asns oo'6ee6- = (z~)s~asns oo'eeee- = (9~)sa~usns oo'eeee- -- (s~)sa~usns oo'66ee- = (~)s~usns oo'eee6- = (~s)sa3usns oo'eeee- = (~)sa3~asns oo'6eee- = (~s)sa~usns oo'eeee- = (os)sa31asns oo'eeee- = (6~)Sa~lasns oo'6eee- = (s~)Sa~lasns oo'eeee- = (z~)sa~asns oo'6ee~- = (9~)sa~asns 00'6666- = (s~)sa~usns oo'eeee- = (~)s~usns oo'eeee- = (~)s~usns oo'66ee- = (~ ~ )sa~usns oo-eeee- = (~ ~ )s~usns oo'6eee- = (0~)s~asns oo'eeee- = (6)sa~asns oo'6eas-= (s)sa3usns oo'eeee- = (z)s~usns oo'eeee-= (9)sa~asns o0'6666- = (s)s~usns oo'eeee- = (t,)sa31asns oo'eeee- = (~)sa3usns oo'eee6- = (~)sa~uans oo+aoooooo'o = (~)s~usns SEI:I I:l~VblYd AVE:II:IV -i 00'6666- = (~O~)S~iI=IaNS 00'6666-= (OOL)S~'Ii.dEINS 00'6666- = (86)S~II.-IEINS oo'asas- = (gs)sa3~aans oo'ssss- = (~)sa~aans S:lA ='IOdEI:I.I.NI SEI:I I:::IIAIVEIVd IDNIEI.I.S--i 00'6666- = (LOL)S~iaaNS 00'6666- = (66)Sa31aans 00'6666- = (Z6)S~laans oo'asss- = (ss)sa~aans oo-ssss- = (as)sa3~aans Input Tape Device, LU (1) is: TAPEC: Output Tape-Image file, LU (2) is: J:\1168\1168.TAP (Output Tape-Image file will be created) Usting Method ("USTMETH") = O, Depth Unit oriented listing. Usting Frequency ("USTFREQ") is every ( 100) units of Depth. Usting output limiting (MSTMAX) not enabled... (to enable list limiting set ESTMAX 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 = 1) 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 I is type: US **** REEL HEADER **** MWD 93/10/1 1168 01 **** TAPE HEADER **** MWD 93/10/1 1168 01 Tape Subtile: 1 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subtile 2 is type: US US COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: APl NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA AGI-4 50-029-22323 Arco Alaska Inc. BAKER HUGHES INTEQ 01 OCT 93 RUN1 RUN2 RUN3 JOB NUMBER: 1168 1168 1168 LOGGING ENGINEER: R. GEHRES D.LENTZ I~ LENTZ OPERATOR WITNESS: S. WALLS J. GAFFANY S. WALLS RUN4 RUN5 RUN6 JOB NUMBER: 1168 LOGGING ENGINEER: S. BURKHARDT OPERATOR WITNESS: J. GAFFANEY SURFACE LOCATION SECTION: 36 TOWNSHIP: 12N RANGE: 14E FNL: FSL: 1937 FEL: 2453 FWL: ELEVATION(I~ FROM MSL 0) KELLY BUSHING: 50.00 DERRICK FLOOR: 49.00 GROUND LEVEL: 13.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1 ST STRING 30.000 20.000 106.0 2ND STRING 16.000 13.375 3537.0 3RD STRING 12.250 9.625 10978.0 PRODUCTION STRING 8.500 REMARKS: $ **** FILE HEADER **** MWD -.001 1 O24 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 STOP DEPTH MWD 8742.0 11655.0 $ BASEMNE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) ~ EQUIVALENT UNSHIFTED DEPTH BASEMNE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD -' REMARKS: ,- $ CN WN FN COUN STAT BIT RUN NO MERGE TOP MERGE BASE 4 8742.0 10223.0 5 10223.0 10927.0 6 10983.0 11270.0 7 11274.0 11 655.0 :Arco Alaska Inc. : AGI-4 : Prudhoe Bay : North Slope :Alaska LIS COMMENT RECORD(s): 1234567890123456789012345678,9012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS EDITED MERGED MWD (MEMORY & REALTIME) DATA. " * 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: -999.25~ Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: I 2 3 4 5 6 7 8 91011 1213141518 0 0 0 I 0 0 0 0 00 0 1 0 00 1 Rep Code Count Bytes 68 4 Sum: 4 fndun a [F ] 16 16 16 1.00000000 -- ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units APl APl APl APl Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 2 RA MWD 68 3 ROP MWD 68 4 RP MWD 68 1 GAPI 1 OHMM 1 FPHR 1 OHMM 16 4 4 98660 71 6 4 4 98660 71 6 4 4 98660 71 6 4 4 98660 71 6 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length Indicates: 50 FRAMES * DATA RECORD (TYPE# O) 1006 BY'rES * Total Data Records: 117 Tape File Start Depth = 8742.000000 Tape File End Depth = 11655.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6420 datums Tape Subfile: 2 193 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 3 is type: LIS **** FILE HEADER **** MAD .002 1024 US COMMENT RECORD(s): 123456789~123456789~123456789~123456789~123456789~123456789~123456789~123456789~ FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH MAD 11410.0 11503.0 $ MERGED DATA SOURCE PBU TOOL CODE MAD 1 $ REMARKS: $ CN :Arco Alaska Inc. WN : AGI-4 FN : Prudhoe Bay COUN : North Slope STAT :Alaska MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE 1 11410.0 11503.0 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS EDITED MERGED MAD PASS DATA. * 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 I 0000000 1 000 1 RepCode Count Bytes 68 3 12 Sum: 3 12 12 fndun a [F ] 1.00000000 " ONE DEPTH PER FRAME Tape depth ID: F 3 Curves: Name Tool Code Samples Units I GR MAD 68 1 2 RA MAD 68 1 3 RP MAD 68 1 GAPI OHMM OHMM 12 APl APl APl APl Log Crv Crv Size Length Typ Typ CIs Mod 4 33 821 O0 0 4 4 33 821 O0 0 4 4 33 821 O0 0 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 63 FRAMES * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 3 Tape File Start Depth = 11410.000000 Tape File End Depth = 11503.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 206 datums Tape Subfile: 3 27 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subtile 4 is type: LIS **** FILE HEADER **** MAD .003 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 3 EDITED MAD PASSES Depth shifted and clipped curves for each pass of each run in separate files. MAD RUN NUMBER: 1 1 0.5000 MAD PASS NUMBER: DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE START DEPTH MAD 11410.0 11503.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASEUNE DEPTH $ REMARKS: $ STOP DEPTH EQUIVALENT UNSHIFTED DEPTH CN : Arco Alaska Inc. WN : AGI-4 FN : Prudhoe Bay COUN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS EDITED MAD PASS DATA. * 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 910111213141516 000 1 0000000 1 000 1 Rep Code Count Bytes 68 3 12 Sum: 3 12 12 fndun a [F ] 1.00000000 3 '- ONE DEPTH PER FRAME Tape depth ID: F 3 Curves: Name Tool Code Samples Units 1 GR MAD 68 1 2 RA MAD 68 1 3 RP MAD 68 1 GAPI OHMM OHMM __ 12 APl APl APl APl Log Crv Crv Size Length Typ Typ CIs Mod 4 33 821 00 0 4 4 33 821 00 0 4 4 33821 00 0 ** Routine LEVONE detects data discrepancy: DSB Indicates: 1 FRAMES Data Record Length Indicates: 63 FRAMES * DATA RECORD (TYPE# O) 1014 BYTES * Total Data Records: 3 Tape File Start Depth = 11410.000000 Tape File End Depth = 11503.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6626 datums Tape Subtile: 4 30 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subtile 5 is type: US **** FILE HEADER **** MWD 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 4 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 STOP DEPTH MWD 8742.0 10223.0 $ LOG HEADER DATA DATE LOGGED: 13 JAN 93 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 INCMNATION (DEG) MINIMUM ANGLE: 59.5 MAXIMUM ANGLE: 63.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 0.0 BOREHOLE CONDITIONS MUD TYPE: DISPERSED ~ MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S): 0.0 MUD PH: 0.0 MUD CHLORIDES (PPM): 850 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) M1.33 M1.33 MEMORY 0.0 8742.0 10223.0 0 TOOL NUMBER 2247-39 MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 1.101 MUD FILTRATE AT MT: 1.060 140.0 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 8743 TO 8802' MD (6957 TO 6986' TVD) WAS LOGGED 10.5 HOURS AFTER BEING DRILLED. MEMORY LOG INCOMPLETE FROM 9620 TO 10306' MD (7388 - 7703' TVD) DUE TO MEMORY SUB RECORDING PROBLEM. REALTIME LOG DISPLAYED BETWEEN THESE POINTS. $ CN : Arco Alaska Inc. WN : AGI-4 FN : Prudhoe Bay COUN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 12345678901234567890123456789012345678,901234567890123456789012345678901234567890 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 0001 00000001 0001 Rep Code Count Bytes 68 16 64 Sum: 16 64 64 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units APl APl APl APl Log Crv Crv Size Length Typ Typ Cls Mod 1 ATCC MWD 68 1 -dB 4 2 ATDC MWD 68 1 -dB 4 3 CADE MWD 68 1 MMHO 4 4 CPDE MWD 68 1 MMHO 4 5 DCCC MWD 68 I 4 6 GRAC MWD 68 1 GAPI 4 7 PDCC MWD 68 I DEG 4 8 PDDC MWD 68 1 DEG 4 9 PDEC MWD 68 1 MINS 4 10 RACC MWD 68 1 OHMM 4 11 RADE MWD 68 I OHMM 4 12 ROPAMWD 68 1 FPHR 4 13 ROPSMWD 68 1 FPHR 4 14 RPCCMWD 68 1 MMHO 4 15 RPDEMWD 68 1 MMHO 4 16 TCDCMWD 68 1 DEGF 4 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 498660 71 6 ** Routine LEVONE detects data discrepancy: DSB Indicates: 1 FRAMES Data Record Length indicates: 14 FRAMES * DATA RECORD (TYPE# O) 958 BYTES * Total Data Records: 424 Tape File Start Depth = 8742.000000 Tape File End Depth = 10223.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 13168 datums Tape Subtile: 5 493 records... Minimum record length: 62 bytes Maximum record length: 95~ bytes Tape Subtile 6 is type: LIS **** FILE HEADER **** MWD .005 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 5 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 STOP DEPTH MWD 10223.0 10927.0 $ LOG HEADER DATA DATE LOGGED: 14 JAN 93 SOFTWARE SURFACE SOFTWARE VERSION: M1.33 DOWNHOLE SOFTWARE VERSION: M1.33 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 0.0 TOP LOG INTERVAL (FT): 10223.0 BOTTOM LOG INTERVAL (FT): 10927.0 BIT ROTATING SPEED (RPM): 0 HOLE INCMNATION (DEG) MINIMUM ANGLE: 51.7 MAXIMUM ANGLE: 63.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 0.0 BOREHOLE CONDITIONS MUD TYPE: DISPERSED MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S): 0.0 MUD PH: 0.0 MUD CHLORIDES (PPM): 900 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) TOOL NUMBER 2247-39 MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 1.245 MUD FILTRATE AT MT: 1.190 130.0 MUD CAKE AT MT: 0.000 0.0 0.0 130.0 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 10223 TO 10283' MD (7664 TO 7691' TVD) WAS LOGGED 14 HOURS AFTER BEING DRILLED. $ CN : Arco Alaska Inc. WN : AGI-4 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) Emry 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 0001 00000001 0001 Rep Code Count Bytes 68 16 64 Sum: 16 64 64 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: APl APl APl APl Log Crv Crv Name Tool C,(x~e Samples Units Size Length Typ Typ CIs Mod 1 ATCC MWD 68 1 -dB 4 2 ATDC MWD 68 1 -dB 4 3 CADE MWD 68 1 MMHO 4 4 CPDE MWD 68 1 MMHO 4 5 DCCC MWD 68 1 4 6 GRAC MWD 68 1 GAPI 4 7 PDCC MWD 68 1 DEG 4 8 PDDC MWD 68 1 DEG 4 9 PDEC MWD 68 1 MINS 4 10 RACCMWD 68 1 OHMM 4 11 RADE MWD 68 1 OHMM 4 12 ROPAMWD 68 1 FPHR 4 13 ROPSMWD 68 I FPHR 4 14 RPCCMWD 68 1 MMHO 4 15 RPDE MWD 68 I MMHO 4 16 TCDCMWD 68 I DEGF 4 __ 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 ** Routine LEVONE detects data discrepancy: DSB Indicates: 1 FRAMES Data Record Length Indicates: 14 FRAMES * DATA RECORD (TYPE# O) 958 BYTES * Total Data Records: 202 Tape File Start Depth = 10223.000000 Tape File End Depth = 10927.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 12820 datums Tape Subtile: 6 267 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subtile 7 is type: LIS **** FILE HEADER **** MWD .006 1 O24 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 6 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 10983.0 11270.0 $ LOG HEADER DATA DATE LOGGED: 13 APR 93 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (Fr): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCUNATION (DEG) MINIMUM ANGLE: 50.6 MAXIMUM ANGLE: 51.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 0.0 BOREHOLE CONDITIONS MUD TYPE: KCL FLO PRO MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 62.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 48000 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) M~.33 M1.33 MEMORY 0.0 10983.0 11270.0 0 TOOL NUMBER 1939-35 MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 0.070 MUD FILTRATE AT MT: 0.000 0.0 MUD CAKE AT MT: 0.000 0.0 0.0 110.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 8.500 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: INTERVAL FROM 10928 TO 10985' (8030 TO 8067' 'I'VD) WAS NOT LOGGED UDE TO SENSOR OFFSET AT CASING POINT. INTERVAL FROM 10968 TO 10983' MD (8057 TO 8067' TVD) WAS LOGGED BEHIND CASING. $ CN :Arco Alaska Inc. WN : AGI-4 FN : Prudhoe Bay COUN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 123456789012345678,90123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 6. * 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: -999.25(X)00 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 1 0 0 0 0 00 0 1 00 0 1 Rep Code Count Bytes 68 16 64 Sum: 16 64 64 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 Name Tool Code Samples Units APl APl APl APl Log Crv Crv Size Length Typ Typ Cls Mod ATCC MWD 68 1 ATDC MWD 68 1 CADE MWD 68 1 CPDE MWD 68 1 DCCC MWD 68 1 GRAC MWD 68 1 PDCC MWD 68 1 PDDC MWD 68 1 PDEC MWD 68 1 RACC MWD 68 1 RADE MWD 68 1 ROP^ MWD 68 1 ROPS MWD 68 1 RPCC MWD 68 1 RPDE MWD 68 1 TCDC MWD 68 1 -dB 4 -dB 4 MMHO 4 MMHO 4 4 GAPI 4 DEG 4 DEG 4 MINS 4 OHMM 4 OHMM 4 FPHR 4 FPHR 4 MMHO 4 MMHO 4 DEGF 4 4 98660 71 6 4 98660 71 6 498660 71 6 498660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 ** Routine LEVONE detects data discrepancy: DSB Indicates: 1 FRAMES Data Record Length indicates: 14 FRAMES * DATA RECORD (TYPE# O) 958 BYTES * Total Data Records: 83 Tape File Start Depth = 10983.000000 Tape File End Depth = 11270.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 15746 datums Tape Subtile: 7 151 records,.. Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subtile 8 is type: US **** FILE HEADER **** MWD .~7 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 11274.0 11655.0 $ LOG HEADER DATA DATE LOGGED: 14 APR 93 SOFTWARE SURFACE SOFTWARE VERSION: M1.33 DOWNHOLE SOFTWARE VERSION: M1.33 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 0.0 TOP LOG INTERVAL (FT): 11274.0 BOTTOM LOG INTERVAL (FT): 11655.0 BIT ROTATING SPEED (RPM): 0 HOLE INCUNATION (DEG) MINIMUM ANGLE: 49.8 MAXIMUM ANGLE: 50.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 0.0 BOREHOLE CONDITIONS MUD TYPE: KCL FLO PRO MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 11.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 48000 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) TOOL NUMBER 1639-35 MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 0.060 MUD FILTRATE AT MT: 0.050 136.0 MUD CAKE AT MT: 0.000 0.0 0.0 124.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 8.500 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: INTERVAL FROM 11270 TO 11291' MD ( 8248 TO 8262' TVD) WAS LOGGED 10.5 HOURS AFTER BEING DRILLED. INTERVAL FROM 11638 TO 11655' MD (8484 TO 8494' TVD) WAS NOT LOGGED DUE TO SENSOR OFFSET AT CASING POINT. $ CN : Arco Alaska inc. WN : AGI-4 FN : Prudhoe Bay COUN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM BIT RUN 7. * 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 12 13 14 15 16 0001 00000001 0001 RepCode Count Bytes 68 16 64 Sum: 16 64 64 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units APl APl APl APl Log Crv Crv Size Length Typ Typ CIs Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 ATCC MWD 68 1 ATDC MWD 68 1 CADE MWD 68 1 CPDE MWD 68 1 DCCC MWD 68 1 GRAC MWD 68 1 PDCC MWD 68 1 PDDC MWD 68 1 PDEC MWD 68 1 RACC MWD 68 1 RADE MWD 68 1 ROPA MWD 68 1 ROPS MWD 68 1 RPCC MWD 68 1 RPDE MWD 68 1 TCDC MWD 66 I -dB 4 -dB 4 MMHO 4 MMHO 4 4 GAPI 4 DEG 4 DEG 4 MINS 4 OHMM 4 OHMM 4 FPHR 4 FPHR 4 MMHO 4 MMHO 4 DEGF 4 _ 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 498660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 4 98660 71 6 ** Routine LEVONE detects data discrepancy: DSB Indicates: I FRAMES Data Record Length indicates: 14 FRAMES * DATA RECORD (TYPE# O) 958 BYTES * Total Data Records: 105 Tape File Start Depth = 11274.000000 Tape File End Depth = 11638.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 16054 datums Tape Subtile: 8 173 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subtile 9 is type: US **** FILE HEADER **** MAD .008 1024 LIS COMMENT RECORD(s)' 123456789012345678901234567890123456789012345678,90123456789012345678901234567890 FILE HEADER FILE NUMBER: 8 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: 1 -- MAD PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH MAD 11410.0 11503.0 $ -- # 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 INCENATION (DEG) MINIMUM ANGLE: _ MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE '- MWD DUAL PROPAGATION $ -- BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G)' MUD VISCOSITY (S)' MUD PH: MUD CHLORIDES (PPM): -- FLUID LOSS (C3): STOP DEPTH 14 APR 93 M1.33 M1.33 MEMORY 0.0 11410.0 11503.0 0 0.0 0.0 TOOL NUMBER 1639-35 8.500 0.0 KCL FLO PRO 0.00 0.0 0.0 48000 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 0.000 MUD FILTRATE AT MT: 0.000 0.0 MUD CAKE AT MT: 0.000 0.0 0.0 0.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 8.500 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: INTERVAL FROM 11410 TO 11503' (8337 TO 8396' TVD) WAS LOGGED 10.5 HOURS AFTER BEING DRILLED WHILE PERFORMING A SHORT TRIP. ORIGINAL DATA WAS TAGGED WITH INCORRECT DEPTHS DUE TO SURFACE SENSOR PROBLEMS. NO ROP DATA WAS OBTAINED THROUGHOUT THIS INTERVAL $ CN : Arco Alaska Inc. WN : AGI-4 FN : Prudhoe Bay COUN : North Slope STAT :Alaska US COMMENT RECORD(s): 1234567890123456789012345678~cj012345678.901234567890123456789012345678901234567890 THIS FILE CONTAINS RAW MWD DATA FROM MAD PASS 1. * 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 12 13 14 15 18 O0 0 I O0 000 0 0 1 0 0 0 1 Rep Code Count Bytes 68 14 56 Sum: 14 56 56 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units 1 ATC1 MAD 68 1 2 ATD1 MAD 68 1 3 CAD1 MAD 68 1 4 CPD1 MAD 68 1 5 DCC1 MAD 68 1 6 GRA1 MAD 68 1 7 PDC1 MAD 68 1 8 PDD1 MAD 68 1 9 PDE1 MAD 68 1 10 RACl MAD 68 1 11 RAD1 MAD 68 1 12 RPClMAD 68 1 13 RPD1 MAD 68 1 14 TCD1 MAD 68 I -dB -dB MMHO MMHO GAPI DEG DEG MINS APl APl APl APl Log Crv Crv Size Length Typ Typ CIs Mod MMHO MMHO MMHO MMHO DEGF _ 56 4 4 4 4 4 4 4 4 4 4 4 43382100 0 4 33 821 00 0 4 33821 00 0 4 33821 00 0 433821 00 0 4 33 821 00 0 4 33 821 00 0 4 59 6O2 51 0 4 33 821 00 0 4 33821 00 0 4 33 821 00 0 4 33 821 00 0 433821 00 0 4 33821 00 0 ** Routine LEVONE detects data discrepancy: DSB indicates: I FRAMES Data Record Length indicates: 16 FRAMES * DATA RECORD (TYPE# O) 966 BYTES * Total Data Records: 24 Tape File Start Depth = 11410.000000 Tape File End Depth = 11503.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 16498 datums Tape Subtile: 9 93 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subtile 10 is type: LIS **** TAPE TRAILER **** MWD 93/ 0/ 1168 01 **** REEL TRAILER **** MWD 93/10/I 1168 01 Tape Subfile: 10 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri I OCT 93 2:06p Elapsed execution time = 1 minute, 14.8 seconds. SYSTEM RETURN CODE = 0 Tape Subtile 1 is type: US Tape Subtile 2 is type: US DEPTH GR RA ROP RP 8742.0000 81.3596 -999.2500 -999.2500 -999.2500 8742.5000 79.0829 -999.2500 -999.2500 -999.2500 8800.0000 89.6008 27.5671 -999.2500 15.8354 8900.0000 80.9206 18.5189 52.8938 11.8937 9000.0000 87.5878 9.5135 70.3697 7.2466 9100.0000 94.7019 6.7381 80.5428 5.9147 9200.0000 101.5652 4.9845 89.3197 4.8058 9300.0000 99.9365 5.8567 58.1287 5.5624 9400.0000 102.8754 6.8543 58.0965 5.8929 9500.0000 95.6572 7.9600 33.4329 6.5302 9600.0000 103.2207 8.9446 72.2653 7.0734 9700.0000 105.9041 9.6830 53.8546 7.4236 9800.0000 112.4192 8.7878 68.1899 7.2807 9900.0000 100.4610 8.4579 81.7746 6.3720 10000.0000 92.6642 10.4865 78.7605 7.1306 10100.0000 102.9620 6.2756 79.6665 6.1032 10200.0000 145.1339 9.8164 60.9731 7.3107 10300.0000 154.1277 10.4520 61.0161 9.7608 10400.0000 150.9968 22.2134 63.1398 15.5553 10500.0000 127.9677 20.6288 43.7517 16.8011 10600.0000 109.9639 8.1141 77.8559 9.5987 10700.0000 161.4686 9.1710 73.8309 7.6707 10800.0000 172.~621 12.0892 90.7949 10.2904 10900.0000 160.6138 2.5740 93.8263 2.9982 11000.0000 21.4584 2.1187 64.3818 4.6754 11100.0000 14.7388 -999.2500 30.5507 164.8117 11200.0000 20.0130 -999.2500 33.8817 160.7126 11300.0000 24.5692 -999.2500 58.1287 81.0092 11400.0000 18.7974 -999.2500 52.1159 137.8430 11500.0000 28.8186 -999.2500 -999.2500 61.0713 11600.0000 126.3555 -999.2500 10.4037 8.9383 11 655.0000 -999.2500 -999.2500 9.4252 -999.2500 Tape File Start Depth = 8742.000000 Tape File End Depth = 11655.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subtile 3 is type: US DEPTH GR RA 11410.0000 115.9750 16.0043 11410.5000 106.8948 16.1165 11500.0000 -999.2500 -999.2500 11503.0000 -999.2500 -999.2500 RP 9.2378 9.1183 61.0713 -999.2500 Tape File Start Depth = 11410.000000 Tape File End Depth = 11503.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subtile 4 is type: LIS DEPTH GR RA 11410.0000 115.9750 16.0043 11410.5000 106.8948 16.1165 11500.0000 -999.2500 -999.2500 11 503.0000 -999.2500 -999.2500 RP 9.2378 9.1183 61.0713 -999.2500 Tape File Start Depth = 11410.000000 Tape File End Depth = 11503.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 5 is type: US DEPTH ATCC ATDC CADE CPDE DCCC Gl:lAC PDCC PDDC PDEC RACC RADE ROPA ROPS RPCC RPDE TCDC 8742.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 81.3596 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8742.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 79.8272 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8800.0000 0.0741 0.1412 36.2751 63.1497 62.3388 89.6008 4.7813 4.5816 -999.2500 48.3761 27.5671 -999.2500 -999.2500 14.9882 15.8354 -999.2500 8900.0000 0.1520 0.2186 53.9987 84.0780 70.7599 80.9206 5.8650 5.6462 41.1000 25.9570 18.5189 51.1282 52.8938 11.3043 11.8937 124.8125 9000.0000 0.3684 0.4327 105.1138 137.9960 88.4963 87.5878 8.2219 7.9716 63.9000 11.2447 9.5135 68.5914 70.3697 6.9341 7.2466 126.5000 9100.0000 0.5403 0.6009 148.4108 169.0691 97.1210 94.7019 9.3894 9.1275 59.6167 7.5828 6.7381 79.8716 80.5428 5.6752 5.9147 129.2375 9200.0000 0.7317 0.7899 200.6237 208.0830 106.8954 101.5652 10.7217 10.4483 70.1494 5.4525 4.9845 85.3572 89.3197 4.6228 4.8058 130.1000 9300.0000 0.6249 0.6835 170.7442 179.7786 99.9206 99.9365 9.7701 9.5031 74.9659 6.4866 5.8567 56.2332 58.1287 5.3397 5.5624 132.6875 9400.0000 0.5302 0.5915 145.8944 169.6955 97.2857 102.8754 9.4117 9.1498 72.3000 7.7773 6.8543 58.0835 58.0965 5.6546 5.8929 133.6437 9500.0000 0.4515 0.5138 125.6276 153.1344 92.7981 95.6572 8.8041 8.5480 162.7137 9.1486 7.9600 33.9745 33.4329 6.2589 6.5302 135.7250 DEPTH ATCC ATDC CADE CPDE DCCC GRAC PDCC PDDC PDEC RACC RADE ROPA ROPS RPCC RPDE TCDC 9600.0000 0.3961 0.4594 111.7999 141.3741 89.4748 103.2207 8.3539 8.1023 70.3667 10.4542 8.9446 72.8524 72.2653 6.7712 7.0734 136.4000 9700.0000 0.3613 0.4252 103.2742 134.7047 87.5237 105.9041 8.0909 7.8422 -999.2500 11.6053 9.6830 54.4240 53.8546 7.1019 7.4236 138.0000 9800.0000 0.4054 0.4673 113.7944 137.3488 88.3076 112.4192 8.1964 7.9460 -999.2500 10.2139 8.7878 65.9875 68.1899 6.9662 7.2807 139.9999 9900.0000 0.4202 0.4850 118.2327 156.9366 93.8742 100.4610 8.9493 8.6903 -999.2500 9.8482 8.4579 82.3203 81.7746 6.1055 6.3720 141.13,33 10000.0000 0.3258 0.3932 95.3609 89.1323 92.6642 8.3112 8.0602 12.7052 10.4865 75.0646 78.7605 7.1306 138.0000 140.2411 -999.2500 6.8276 10100.0000 0.5839 0.6418 159.3483 163.8472 95.7497 102.9820 9.2039 8.9420 -999.2500 6.9800 6.2756 63.9064 79.6665 5.8512 6.1032 1 40.0000 10200.0000 0.3549 0.4197 101.8706 136.7849 88.1521 145.1339 8.1763 7.9256 -999.2500 11.6761 9.8164 54.5777 60.9731 6.9928 7.3107 142.0000 10223.0000 0.4903 0.5499 134.9447 148.1030 91.4877 123.7680 8.6153 8.3609 -999.2500 8.3596 7.4104 15.8978 14.5322 6.4538 6.7521 142.0000 Tape File Start Depth = 8742.000000 Tape File End Depth = 10223.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units -- Feet Tape Subtile 6 is type: US DEPTH ATCC ATDC CADE CPDE DCCC GRAC PDCC PDDC PDEC RACC RADE ROPA ROPS RPCC RPDE TCDC 10223.0000 0.4903 0.5499 134.9447 148.1030 91.4877 123.7680 8.6153 8.3609 -999.2500 8.3596 7.4104 15.8978 14.5322 6.4538 6.7521 142.0000 10223.2500 0.5039 0.5631 138.3867 91.8890 122.1915 8.6700 8.4134 8.1299 7.2261 15.8978 15.4426 6.6892 142.0000 10300.0000 0.3311 0.3892 95.6757 76.7132 154.1277 6.6370 6.4054 12.4430 10.4520 61.3817 61.0161 9.7608 124.1600 149.4946 -999.25OO 6.3931 102.4509 -999.2500 9.4634 10600.0000 0.4461 0.4987 123.2419 104.1810 77.2938 109.9639 6.7138 6.4820 60.8159 9.2187 8.1141 87.8968 77.8559 9.3084 9.5987 132.4625 10700.0000 0.3814 0.4429 109.0392 130.3657 85.6374 161.4686 7.8268 7.5808 49.9167 10.8106 9.1710 72.7234 73.8309 7.4452 7.6707 134.7125 10800.0000 0.2758 0.3360 82.7184 97.1780 74.8884 172.3621 6.3961 6.1686 56.9333 14.8630 12.0892 107.6330 90.7949 9.9767 10.2904 136.5125 10900.0000 1.3180 1.3706 388.5027 333.5364 132.6803 160.6138 14.2497 13.9554 39.6333 2.7225 2.5740 92.7173 93.8263 2.9255 2.9982 136.8500 10927.0000 1.4848 1.5429 450.8406 480.8221 157.8127 269.7944 17.7040 17.3960 41.6667 2.3454 2.2181 116.7975 122.0703 2.0341 2.0798 1 38.8500 Tape File Start Depth = 10223.000000 10500.0000 0.1317 0.1907 48.4760 59.5201 60.0974 127.9677 4.4890 4.2944 55.0659 29.3218 20.6288 49.1259 43.7517 16.2747 16.8011 131.4500 10400.0000 0.1130 0.1757 45.0178 64.2866 62.1903 150.9968 4.7528 4.5529 58.1500 33.5197 22.2134 62.3754 63.1398 15.0686 15.5553 128.7500 Tape File End Depth = 10927.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 7 is type: US DEPTH ATCC ATDC CADE CPDE DCCC GRAC PDCC PDDC PDEC RACC RADE ROPA ROPS RPCC RPDE TCDC 10983.0000 0.3951 0.4400 108.3082 62.4431 113.6712 4.5973 4.3954 10.1819 9.2329 63.2488 66.8657 16.2954 137.4125 61.3671 -999.2500 14.9321 10983.2500 0.1777 0.2286 57.2613 45.6155 55.0534 114.2511 3.6739 3.4930 -999.2500 21.5746 17.4638 63.2488 64.4544 19.8554 21.9224 137.4125 11000.0000 1.5419 1.5994 471.9863 213.8845 159.7437 21.4584 10.9606 10.5477 28.3333 1.8172 2.1187 52.0773 64.3818 1.9832 4.6754 113.0562 11100.0000 -999.2500 -999.2500 -999.2500 5.4109 25.1538 14.7388 0.5458 0.4800 36.7667 -999.2500 -999.2500 29.3426 30.5507 140.9368 184.8117 116.0375 11200.0000 -999.2500 -999.2500 -999.2500 14.9635 20.0130 0.5960 0.5598 -999.2500 -999.2500 32.5347 33.6817 160.7126 122.3375 6.2223 33.5333 956.2338 11270.0000 -999.2500 -999.2500 -999.2500 5.5829 25.3861 15.2273 0.5638 0.4971 42.0833 -999.2500 -999.2500 39.8911 46.9501 137.2687 179.1168 125.4875 Tape File Start Depth = 10983.000000 Tape File End Depth = 11270.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 8 is type: LIS DEPTH ATCC ATDC CADE CPDE DCCC GRAC PDCC PDDC PDEC RACC RADE ROPA ROPS RPCC RPDE TCDC 11274.0000 -999.2500 -999.2500 -999.2500 14.5086 17.5199 0.5023 0.4685 -999.2500 -999.2500 28.1715 25.2022 188.8313 125.8250 11274.2500 -999.2500 -999.2500 -999.2500 14.6963 16.9139 0.5136 0.4791 -999.2500 -999.2500 28.1715 27.1818 185.1365 125.8250 5.2957 143.6024 1154.0833 5.4014 182.2057 1063.8486 11500.0000 -999.2500 -999.2500 -999.2500 16.3743 -999.2500 28.8186 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 61.0713 133.6678 11600.0000 0.1279 0.2059 -999.2500 111.8784 81.1945 126.3555 7.0260 6.7845 84.0167 28.4385 -999.2500 11.5900 10.4037 8.3593 8.9383 132.0969 11638.0000 0.2992 0.3613 -999.2500 106.5439 79.4504 -999.2500 6.7926 6.5538 86.3167 13.2920 -999.2500 12.1230 13.2666 8.7648 9.3858 135.1625 Tape File Start Depth = 11274.000000 Tape File End Depth = 11638.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet 11400.0000 -999.2500 -999.2500 -999.2500 7.2546 27.6730 18.7974 0.7150 0.6385 75.5500 -999.2500 -999.2500 50.5320 52.1159 107.9587 137.8430 122.0000 11300.0000 -999.2500 -999.2500 -999.2500 12.3443 32.9310 24.5692 1.2192 1.1190 16.2333 -999.2500 -999.2500 60.8342 58.1287 68.2053 81.0092 127.6250 lee4 = s~.un qlde(3 elL-I ede. L O000S~'O = §u!o[~ls le^e'l ella edej. 000000'~0~1. I, = qlde(3 pu~ ella ede. L 000000'0~ I. = qldeQ iJmS el!J ed~l OCj/.lz'~ L 00~'C~:::~3- OOCj~'GG6- OOCj~'GG6- 00~'~::~13- 00G~'886- 00~'886- 00cj~'8813- OOCj~'GG6- 00~'886- 00cJ~'666- 00~:~'666- 00~'~- 00cJ~'666- 0000'1~0~ I. I. 8Z99"8.8 I. .8 I./.0' 1.9 6(:JG'P"9(:J 00(:J~"666- 00cJ8"666- 00cj:~'666- 9P'~' I. '1~ .8'¢' I. O0~Z'~- G98'I~'(:JI~ ~-'~/.l~'9 t 00~'666- 00g~'666- 00g~'666- O000'OOS I. I. 00g~'666- ~9 I. L'6 ~JS6'~ 1~'~00'9 I. Gq~O~' I.~ O(:j~ ~' L (:jZ'i~ ~1~S~'9 /.069'9 ~ L(:J L' L L L ~0/.9'1~/. 6'P69'60 I. 1.88P"~9 Cj6'P,;~'O Z~Z I.'0 OOS8:'O I.'P'I. i. 00CjZ'666- 8/...8~"6 88¢J6'8 00cJ~'666' 00cj8:'666' O00CJ'9/.81rl~906g'9 8'8Z9'9 OCJZ.6'CJ I.I.GSL9'8/.. I. ~gi~'80 ~ 00~'~=~:~- OOg~'~- OOg~'C~:~- 0000'0 H~ I. I. ~:1(3cl LQ(Id LO(Id L~:19 ~OOQ ~(3c10 L(3¥0 L(31¥ LO/¥ SI-I :ed/q si 6 elgqns ede~ Tape Subtile 10 is type: US
