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192-120
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-02 PRUDHOE BAY UNIT AGI-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/23/2025 AGI-02 50-029-22311-00-00 192-120-0 G SPT 7863 1921200 1966 3398 3395 3388 3388 10 14 17 16 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-02 Inspection Date: Tubing OA Packer Depth 0 2403 2343 2322IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250815170237 BBL Pumped:4.4 BBL Returned:3.2 Tuesday, September 23, 2025 Page 1 of 1 PBU AGI-02 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 192-120 50-029-22311-00-00 10215 8557 80 3712 9623 700 10164 20" 13-3/8" 9-5/8" 7" 8510 38 - 118 38 - 3750 35 - 9658 9513 - 10213 38 - 118 38 - 3482 35 - 8056 7927 - 8554 None None 1490 5020 6870 7240 9710 - 10149 7" 26# x 5-1/2" 17# NT-80 x L-80 33 - 9517 8101 - 8497 5-1/2" Baker FB-1 Packer 2219, 2202 9437 7863 Bo York Operations Manager Dave Bjork david.bjork@hilcorp.com 907-564-4672 PRUDHOE BAY, Prudhoe Oil ADL 0028301 , 0034628 33 - 7932 N/A N/A 257504 253600 20 20 3454 3450 325-167 Prudhoe Oil 7" HES MCX 9437, 7863 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.05.09 09:49:36 - 08'00' Bo York (1248) By Grace Christianson at 10:10 am, May 09, 2025 DSR-5/9/25JJL 6/13/25 ACTIVITY DATE SUMMARY 4/28/2025 T/I/O=2550/6/20 WATER WASH Pump 5 bbls 60/40, 77 bbls 180* diesel, & 362 bbls fresh water w/ surfactant down tbg. Soak for 2 hrs. Pump 238 bbls ( 600 bbls total ) & 15 bbls 60/40. FWHPs=100/20/80 Daily Report of Well Operations PBU AGI-02 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-02 Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 192-120 50-029-22311-00-00 ADL 0028301 , 0034628 10215 Conductor Surface Intermediate Production Liner 8557 80 3713 9624 700 10161 20" 13-3/8" 9-5/8" 7" 8508 35 - 115 35 - 3748 33 - 9657 9511 - 10212 35 - 115 35 - 3480 33 - 8055 7927 - 8554 none 470 2260 4760 5410 none 1490 5020 6870 7240 9710 - 10149 7" x 5-1/2" NT-80 x L-80 31 - 95178101 - 8497 Structural 7" Baker FB-1 , 7" Baker H 7" HES MCX 9436 , 7862 / 9519 , 7934 2217 , 2200 Date: Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com 907-564-4672 PRUDHOE BAY 5-1-2025 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 11:17 am, Mar 25, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.03.25 06:59:50 - 08'00' Bo York (1248) A.Dewhurst 10APR25 10-404 DSR-4/1/25 325-167 SFD JJL 4/7/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.14 16:50:12 -08'00'04/14/25 RBDMS JSB 041725 Well Work Prognosis Well Name:AGI-02 API Number:50-029-22311-00 Current Status:Gas Injector Leg: Estimated Start Date:May 1, 2025 Rig:N/A Reg. Approval Req’d?10-403 Date Reg. Approval Received: Regulatory Contact:Carrie Janowski Permit to Drill Number:192-1200 First Call Engineer:Dave Bjork Office: 907-564-4672 Cell: 907-440-0331 Second Call Engineer:Jerry Lau Cell: 907-360-6233 Gas Injection Rate: 230,672 Mscf/Day Injection Pressure: 3,377 psi Reservoir Pressure (Estimate): 3500 psi Program Objective(s): AGI-02 is a gas cap injection well that has demonstrated a decrease in injectivity. The well has not been water washed since 2021. Water washes are designed to dissolve salts and asphaltenes in the tubing and formation. The objective is to perform a tubing water wash to increase injectivity and perform a general maintenance on Gas Injection Wells. Proposed Program: Pump diesel followed by Fresh Water and Surfactant as per attached pumping template. Well Work Prognosis Well Work Prognosis MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 5, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC AGI -02 PRUDHOE BAY UNIT AGI -02 Well Name PRUDHOE BAY UNIT AGI -02 API Well Number 50-029-22311-00-00 Permit Number: 192-120-0 Insp Num: mitBDB210804150658 Rel Insp Num: Packer Well AGI -022 Type Inj I G 'TVD - PTD 1921200 Type Test SPT'Test psi BBL Pumped: T 4.4 BBL Returned: Intervals 4YRTST -PIF Notes: Src: Inspector Reviewed Byj`��, P.I. Supry �' 1� Comm Inspector Name: Brian Bixby Inspection Date: 8/4/2021 �, Depth P Pretest Initial 15 Min 30 Min 45 Min 60 Min 7863 - Tubing 3298 - 3297 "1 3296 3297 , 1966 IES 283 2212, 2168 ' 4.4 OA 33 48 - 47, 7 - 47- P ✓ Thursday, August 5, 2021 Page I of 1 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:192-120 6.50-029-22311-00-00 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 10215 10161 8508 none none 7862 , 7934 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 35 - 115 35 - 115 1490 470 Surface 3713 13-3/8" 35 - 3748 35 - 3480 5020 2260 Intermediate 9624 9-5/8" 33 - 9657 33 - 8055 6870 4760 Production Perforation Depth: Measured depth: 9710 - 10149 feet True vertical depth:8101 - 8497 feet Tubing (size, grade, measured and true vertical depth)7" x 5-1/2" Nt-80 x L-80 31 - 9517 9436 7862Packers and SSSV (type, measured and true vertical depth) 7" Baker FB-1 Packer Liner 700 7" 9511 - 10212 7927 - 8554 7240 5410 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 00 00 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Dave Bjork David.Bjork@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:907-564 - 4672 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ 5 SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8557 Sundry Number or N/A if C.O. Exempt: 320 - 457 7" MCX SSV 2217 2200 Junk Packer Printed and Electronic Fracture Stimulation Data 5 water wash Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 034628 , 028301 PBU AGI-02 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 245,379 249,928 3352 3373 160 175 9436 , 9519 NT-80 x L-80 By Samantha Carlisle at 5:29 pm, Dec 02, 2020 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.12.02 15:38:04 -09'00' Bo York DSR-12/2/2020 RBDMS HEW 12/3/2020 MGR04FEB2021 ACTIVITYDATE SUMMARY 11/15/2020 Tbg Flush (TUBGING WASH/PICKLE) Pumped 10 bbls 60/40 meth, 50 bbls 120* DSL and 359 bbls 140* fresh water w/ F-103 down Tbg. Let soak for 2 hours. Pumped 217 bbls 140* fresh water w/ F-103 and 15 bbls 60/40 meth down Tbg. DSO notified to bring well back on injection. SV,WV=C SSV,MV=O IA,OA=OTG Daily Report of Well Operations PBU AGI-02 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:192-120 6.API Number:50-029-22311-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 034628 Property Designation (Lease Number):10. n/a 8. PBU AGI-02 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 10215 Effective Depth MD: NT-80 x L-80 11. 11-7-2020 Commission Representative: 15. Suspended Contact Name: Dave Bjork Contact Email: David.Bjork@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 7" MCX SSV Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8557 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 9436, 9519 / 7862 , 7934 2217, 2200 Date: Liner 700 7"9511 - 10212 7927 - 8554 7240 5410 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 35 - 3748 35 - 3480 14. Estimated Date for Commencing Operations: BOP Sketch 35 - 115 Structural 6870 Proposal Summary 13. Well Class after proposed work: 7" Baker FB-1 & 7" Baker H 9710 - 10149 8101 - 8497 7 x 5-1/2"31 - 9517 Production 10161 8508 none none 35 - 115 470 13-3/8" 9-5/8" Contact Phone:907-564-4672 Date: 4760 80 149020"Conductor 2260 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 3713 5020 Intermediate 9624 33 - 9657 33 - 8055 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 2:23 pm, Oct 26, 2020 320-457 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.10.26 13:38:45 -08'00' Bo York 10-404 ; ADL0028301 DLB X MGR28OCT2020 DLB10/26/2020 DSR-10/27/2020 Yes n Required? Comm. 10/28/2020 dts 10/28/2020 JLC 10/28/2020 RBDMS HEW 11/9/2020 Well Work Prognosis Well Name: AGI-02 API Number: 50-029-22311-00 Current Status: Gas Injector Leg: Estimated Start Date: Nov 7, 2020 Rig: N/A Reg. Approval Req’d? 10-403 Date Reg. Approval Received: Regulatory Contact: Carrie Janowski Permit to Drill Number: 192-120 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: 216,255 Mscf/Day Injection Pressure: 3,367 psi Reservoir Pressure (Estimate): 3500 psi Program Objective(s): AGI-02 is a gas cap injection well that has demonstrated a decrease in injectivity. The well has not been water washed since 2017. Water washes are designed to dissolve salts and asphaltenes in the tubing and formation. The objective is to perform a tubing water wash to increase injectivity and perform a general maintenance on Gas Injection Wells. Proposed Program: Pump diesel followed by Fresh Water and Surfactant as per attached pumping template. Well Work Prognosis Well Work Prognosis * STATE OF ALASKA : • •LASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate RI Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other Water Wash m 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 192-120 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service m 6. API Number 50-029-22311-00-00 7. Property Designation(Lease Number): ADL 0034628 8. Well Name and Number PBU AGI-02 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 10215 feet Plugs measured feet true vertical 8557 feet Junk measured feet SEP 1 3 2017 Effective Depth: measured 10161 feet Packer measured 9436 feet //�� sv true vertical 8508 feet Packer true vertical 7862 feet ,t �ti,K�J 'C Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 35-115 35-115 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 9624 9-5/8"47#NT-80 33-9657 33-8055 6870 4760 Production Liner 700 7"26#NT-80 9511-10212 7927-8554 7240 5410 Perforation Depth: Measured depth: 9710-9720 feet feet 9723-9786 feet 9789-9925 feet 9995-10015 feet 10050-10149 feet True vertical depth: 8101-8110 feet feet 8113-8169 feet 8171-8293 feet 8356-8374 feet 8406-8497 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 7"Baker FB-1 Packer 9436 7862 true vertical depth) 7"MCX SSSV 2217 2200 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9710'-10149'. Treatment descriptions including volumes used and final pressure: �¢� F NOV 2�17� 215 Bbls Diesel/Xylene,587 Bbls 1%KCL,20 Bbls 50/50 Methanol/Water,706 psi. s `- ,; 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: -201936 254 3332 Subsequent to operation: -41943 0 212 3452 14.Attachments:(required per 20 AAc 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations H Exploratory 0 Development 0 Service ® Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ I! SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-313 Authorized Name: Oestgaard,Finn Contact Name: Stone,Christopher Authorized Title: Production - gineer Challenger Contact Email: Christopher.Stone@bp.com An\A Authorized Signature: q C, - Date: !� 1-1--i 7 Contact Phone: +1 907 564 5518 Form 10-404 Revised 04/2017 viz- 1 0/(!/ AriyAil R B D J1S 1"/SEP 2 5 2017 ff6 ___ / Submit Original Only Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RECEIVED SEP 1 3 2017 RE: BP Exploration (Alaska), Inc. A OGcc Report of Sundry Well Operations Summary September 7, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Water Wash Stimulation for Well AGI-02, PTD # 192-120. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • • d • o 0 0 0 0 0 0 catiLaCO0 CO - O N r tt V 0 N d' LU LC) CO U y o 0 0 0 0 0 0 I,- 6) Ln N I- V V V 7 V O 00 N N ti m c- CO 10 CO f- N- ti Ln ch N V LC) 00 O CO Ln LU CO 01 `- `- O LO CO a) �- �- Cr) CO CO N j 1 1 1 1 1 H N- N (0 Ln CO N CO CO CO M 6) CO c0 ti Lr) Lc)c- �- N- CO O Lf) co 6) a) O1 V NE 1111111 Q I w1- a)Ln LO Cr) LC) =, a CO LC) MV • d Ln O oln , co c)ZHcoco = d * 00 4# Z Z • °° = N N N N co M L C)O d N N O N C CO CO CO CO • CO 0) co 6) O) J W C)0 — U • W W LU LNa QQ 0 0 U 0 W LL Z_ Z_ Z L Q W W m m O > > ~ Z D D OWv) ZJHH 0 0 $ 1 1 a £ » Cl) eyo E \ > i 2Loc) a % / in � > c >\ 8U)/ //\ co co 3 \Ea E @ / @ _ _ o Eo7 in k \ \ I 0 w 0 .— 5 » o >- a E 0 5 n U -± (/) .0 E 03 < e m $ Lt E _ a) / 1 \ •• ? \ H O q /Om < O ) \ \ / _ o $ 2 \ 0 5 O / TD- / LI < z R / o 0 « o ca / : t/ / 1 � — & Ti) aa % c .$ -co1. / CD m E : co � 2 � E / a k / \ o G C2-(1) 6 a o co / ) ? \ 777C) / / / a E 7 - e ƒ # E / � 2j TREES , WELLHEA,D= CIW 0 SPei NOTES: WELL REQUIRES A SSSV. LINER ACTUATOR= BAKER C AGI-02 NOT EMENTED. ALL TBG IS IPC WITH NSCC KB.ELEV = 49' BF.ELEV= KOP= 1851' Max Angle= 43 @ 6635' Datum MD= 10566' 2219' —17"CAMCO BAL-0 SSSV NIP. ID=5.937" 1 ati I Datum TVD= 8800'SS 13-3/8"CSG, 68#, K-55, ID= 12.415" —1 121' I- 13-3/8"CSG,68#, NT-80, ID= 12.415' — 3750' I--A k 7"TBG. 26#. NT-80-IPC, NSCC. .0383 bpf, ID=6.276" — 9430' \ / _ 9430 —17"X 5-1/2"XO. ID=4.875" TOP OF 5-1/2"TBG H 9430' r„</, 9435' —I ANCHOR. ID=4.875" Minimum ID = 4.455" @ 9505' CE:1 9437' H - ' "X 5-1/2"BAKER FB-1 PKR, ID=6.000" 5-1/2" OTIS XN NIPPLE I I 9483' H 5-1/2"PARKER SWS NIP, ID=4.562" I I 9505' —5-1/2"0115 XIV NIP, ID=4.455" 5-112"TBG, 174,L-80-IPC,NSCC. .0232 bpi, ID=4.892" — 9517' / \ 9517' —15-1/2"WLEG, ID=4.892" 9527' HELMD TT LOGGED 05/23/93 TOP OF 7" LNR H 9531' I—. 9-5/8"CSG,47#, NT-80, ID=8.681" — 9658' 1-4 [ k PERFORATION SUMMARY REF LOG: BHCS ON 05/23/93 ANGLE AT TOP PERF: 28 @ 9710' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9710-9720 0 5/23/93 3-3/8" 6 9723-9786 0 5/23/93 3-3/8" 6 9789-9925 0 5/23/93 3-3/8" 6 9995-10015 0 5/23/93 3-3/8" 6 10050-10149 0 5/23/93 PBTD — 10117' 7"LNR, 264. NT-80, .0383 bpf, ID=6.276" H 10213' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/17/92 ORIGINAL COMPLETION WELL: AGI-02 01/29/01 SIS-LG REVISION PERMIT No:F1921200 05/22;01 RN/KAK CORRECTIONS AR No: 50-029-22311-00 03/13/03 AS/TP ADD IPCITHREAD FOR TBG SEC 36,T12N, R14E. 2361.5'FEL&3775.99'FNL 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,August 09,2017 Jim Regg P.I.Supervisor '4' 6110 f`7 SUBJECT:Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. AGI-02 FROM: Guy Cook PRUDHOE BAY UNIT AGI-02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry ,T6/2— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT AGI-02 API Well Number 50-029-22311-00-00 Inspector Name: Guy Cook Permit Number: 192-120-0 Inspection Date: 8/5/2017 - Insp Num: mitGDC170805183036 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well AGI-02 ' Type Inj G TVD 7863 Tubing 3382 3383 3381 - 3389 - PTD 1921200 Type Test SPT Test psi 1966 - IA 370 2487 - 2433 2413 - BBL Pumped:j 6.1 fBBL Returned: 3.4 OA , 77 109 109 106 Interval 4YRTST P/F P Notes: MIT-IA. A fluid level shot was done directly before the test and showed the fluid level to be at 120'. Diesel was heated by Little Red Services to 100 degrees Fahrenheit before pumping to help with thermal expansion issues during the test. • Wednesday,August 09,2017 Page 1 of 1 • • • 41"I v7, ,& THE STATE Alaska Oil and Gas tv OfALAsKA Conservation Commission . 2_^_ ,— 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 wR • Main: 907.279.1433 ALAS� Fax: 907.276.7542 www.aogcc.alaska.gov Christopher Stone DS2and18PE BP Exploration (Alaska), Inc. NE® Jt)i: 2 025i P.O. Box 196612 SCAN Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU AGI-02 Permit to Drill Number: 192-120 Sundry Number: 317-313 Dear Mr. Stone: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, d2Ca-sr-Th Hollis S. French Chair DATED this day of July, 2017. RBDMS JUL 1 3 2017 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COM N • APPLICATION FOR SUNDRY APPRO S 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate H ' Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Water Wash EI • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 192-120 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service RI• 6. API Number: 50-029-22311-00-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No ® PBU AGI-02 9. Property Designation(Lease Number): 10. Field/Pools: Jul. 0 2 07 1 ADL 0034628) ,db L ovz`0,7c)/ ,/ -7,et.i7 PRUDHOE BAY,PRUDHOE OIL • 1 1 I f Pg-5 •7 ) I z/17 11. PRESENT WELL CONDITION SUMMARY ,AQP �„� ~+.CC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): ,.un'k D�1T`'�"����(� 10215 . 8557 • 10161 8508 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 35-115 35-115 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 9624 9-5/8"47#NT-80 33-9657 33-8055 6870 4760 Production Liner 700 7"26#NT-80 9511-10212 7927-8554 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: 7"Baker FB-1 Packer Packers and SSSV MD(ft)and TVD(ft): 9436, 7862 7"MCX SSV 2217, 2200 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program H BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service ®. 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR ❑ SPLUG 0 Commission Representative: GINJ Il • Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Stone,Christopher be deviated from without prior written approval. Contact Email: Christopher.Stone@bp.com Authorized Name: Stone,Christopher Contact Phone: +1 907 564 5518 Authorized Title: DS 2JJPE Authorized Signature: ��4 ^LVVVDate: 4/,0 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3t-1 -3 k3 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No ❑ / Spacing Exception Required? Yes 0 ' No Subsequent Form Required: 'V--404 APPROVED BYTHE Approved by: OL___ eMMISSIONER COMMISSION Date: ,Zlt4 dY,LA ti �� RIGINAL RBDMS G-JUL 1 3 1017 O -7't�"",1 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. ` Attachments in Duplicate fit 7./�b7./(. /7 • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572FiCEIVED 1 0 2017 RE: BP Exploration (Alaska), Inc. CC Report of Sundry Approvals (10-403) July 7, 2017 To Whom it May Concern: • Attached please find the Sundry Application for a Water Wash on Well AGI-02, PTD # 192-120. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-403 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0, DBR, LHD,EAZ. BPG 10/12/15) General Information Well Name: AGI-02 Well Type: Gas Injection Well API Number: 50-029-22311-00 Well Activity Conventional 4 Classification: Activity Description: Water Wash Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: TREAMENTS Estimated Cost, $K: AWGRS Job Scope: TUBING WASH/PICKLE Other regulatory None requirements? Sundry Form 10-403 Required? Yes Sundry Form 10-404 Yes Primary Secondary Required? Engineer: Chris Stone Contact numbers: (907)564-5518 (907)440-4011 Well Intervention Engineer: Jamin Laplante Contact numbers: 907-365-9140 907-564-4137 Lead Engineer: Chris Stone Contact numbers: (907)564-5518 (907)440-4011 Date Created: June 20. 2017 Revisions(date,who,what changed): Current Well Status Information 1 Water Rate or Gas Rate or Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate FTP or Injection Date Pressure (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Cut(%) (Mscf/Day) psi) 6/25/2017 172.764 3,419 Current Status: Operable Flowing Inclination>70°at Depth(ft) N/A Recent H2S (date, ppm) NA 0 ppm Maximum Deviation(Angle and 43° 6,634' MD Depth) Datum depth,ft TVDss 8,800'TVDss Dogleg Severity(Angle and Depth) 43° 1.218' MD Reservoir pressure(date, Est 3.407 psi Minimum ID and Depth 4.455" 9,505' MD psig) Reservoir Temp, F 163° F Shut-in Wellhead Pressure Est. 2525 psi Known mech. integrity None problems(specifics) Last downhole operation(date, operation) 8/6/2013 Set 7"MCX Most recent TD tag(date, depth, 8/26/2006 10178'ELMD 3.25"Cent, TEL&Sample Bailer toolstring OD) Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, AGI-02 was drilled in 1992 as part of the GHX project. The well is completed with 7"injection tubing and background information, liner and is perfd in all present Ivishak sands. AGI-02 has had 4 water washes with the most recent on etc: 7/11/11 using 300 bbls of 50 F diesel. soaking for 1 hour and then pumping 220 bbls freshwater with 0.02% F-103 surfactant for the overflush-this"water wash"saw minimal effect on the overall injectivity. On 11/24/06 50 bbls of diesel/xylene was pumped w/600 bbls of freshwater with 0.02% F-103 surfactant for the overflush-this water wash was successful in increasing hte injectivity of the well. A lower wellhead injection pressure was required to inject a similiar volume of gas as prior to the wash. This wash will use D/X to try and mimic the success of the November 2006 wash. We are intentionally choosing to increase the soak time of the diesel/xylene solvent on the perfs in an attempt to see if positive results can be achieved. • • Well Intervention Details Please contact the SOR author if 1 There is a change in work scope to the approved SOR 2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. Suspected Well Problem: Reduced injectivity due to depositions. Specific Intervention or Well Objectives: 1 Pump diesel/xylene water wash to restore injectivity by cleaning perfs and tubing. 2 3 Key risks, critical issues: Mitigation plan: 1 High pressure pumping Use pressure cross check checklist fUse extreme caution and ensure all personal on 2 Gas Injection Well location are aware of pressure sources and well barriers. Follow well entry gas pad weliwork section 3.8 Hydrostatically the well will be underbalanced during the soak period, expect to see tubing pressure climb 3 Soaking diesel/xylene during pumping process during 4 hour soak as gas comes into well to balance hydrostatically,we will push this back into reservior when we come back on with the pumps Review MSDS pre-job, discuss safety precautions/gear, 4 Working with Xylene how to handle spills, how to handle contact to personal to ensure personal know how to respond Summary Service Line Activity Step# 1 FB Pump diesel/xylene water wash as per attached pumping template. 2 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 FB Pump diesel/xylene water wash as per attached pumping template. 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: Expected Production Rates: FTP(psi): Choke setting: PI(bfpd/psi dp) Post job POP instructions: Post water wash return well to gas injection service. Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form, logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc • S a) Q o 0 0 0 0 0 0 _m ' LUCD (ID Co CN CNO N in in Co C.) y 0 0 0 0 0 0 0 i O) in N N- t1' V CO LC) CO N- N- h- p Ln V N V 00 in oo Ch V' O LC) co a) co cc CO i i I— r` N In L() CO N CO CO CO Cr) 0) CO CO t- ti 4-0 (L) oo CO r` CNI C)) CA r` O NO C) LC) M CA O (A V N E Qco Ln Ln C)O CO CO CO Ln C) V Q a) C) a cLc) c) O a) = •L F- co °o ZF_ F_. = N * Z Z • (.0co OO N U w co ° N (Ni N co Lc) ti 11 • C)) � co O t N N 0 CN O C CO 00 M C a) (3) J W 01 Q cU W W uj co < O CA 0 W W Z Z Z C W W m CO UU) U) z __IF- I— • 410 U) N co m r� N- CO in .0 � co0vco Q o CO C 4 ro m co 0) N- a) O v- N co 4 O co co co co co > 1- a a O F d' N V Cr) M t Cr) CO M CO G c- N ,- CO a N O .- i,- LC) OCO W O c- r- c- CO > O CO CO CO CO co 0 > 2 1- w x 0 w 0 w O Luz O 1- FJ- W g Y U 0 > Cn Ca U U ~ c .F0 LU Z 0 CO LC) J J J < < Cn W a. C 0 N- N 0) 0 0 _U _U U_ J W W CL D Z U CD y N- .- Z Z Z O p p J 0 J E c. y 2 2 I Z O O O H O Ss. 00 0 W C Z Q Z w W W a l- H Q J Q C,) C 2 2 2 O co co cn co co 'nL 0. Q V F C CD CO CD LC) LCD O = , N Cf0 O) M (71- of cm cm CA c) ice+ LY � O) � 6) CA c) 03aa) co cr NO- m m -1 2 1- 0 a J CI- L. L 2 2 O cn cn cn cn cn a) Q. y O 0 c t 1z m W W W W W `m a. a. a. a. a. C. O a) a m I- D• CO M CO CO Cr) 0 020 O CA CT 6) Cr) 6) O D 7 CA O) CT C3) W J J Z p \ \ Z 1 1 W N LL '_' C`') Ch M M M 9 W J O JJ J N N N CN N U d W 7 O W CC Q In LO LC) LC) L{) Q 0 � J - f- J J w W LL d O m O Y 2 1 W -IQ 0 W W < < T) a 71 CO Lt. LL. LL (n a CC a) E Z N N N N CV 0 0 0 0 0 (000000 mit_ a a oo -� 0 NU' w - < < < < < < m m LL it co co a TREE_ WELLHEAD= CNV • AG1-02NOTES:WELL N>�'CEMENTED. ALL BG IS IPC WITH NSCC INER ACTUATOR= BAKER C •KB.ELEV= 49' BF.ELEV = KOP= 1851' Max Angle= 43 @ 6635' Datum MD= 10566' 2219° H7"CAMCO BA L-0 SSSV NIP, ID=5.937" Datum TVD= 8800'Si 13-3/8"CSG, 68#, K-55, ID= 12.415" 121' 13-3/8"CSG,68#. NT-80,ID=12.415" 3750' 7"TBG, 26#, NT-80-IPC, NSCC, .0383 bpf, ID=6.276" —, 9430' \ / 9430' _-17"X 5-1/2"XO, ID=4.875" TOP OF 5-1/2"TBG H 9430' 9435° H ANCHOR, ID=4.875" Minimum ID = 4.455" @ 9505' 9437° -19-5/8"X 5-1/2"BAKER FB-1 PKR, ID=6.000" 5-1/2" OTIS XN NIPPLE 1 1 9483' -15-1/2" NIP, ID=4.562" I 0 9505' -15-1/2"OTIS XN NIP, ID=4.455" 5-1/2"TBG, 17#,L-80-IPC,NSCC, .0232 bpf,ID=4.892" H 9517' ---/ \ 9517' H5-1/2"WLEG,ID=4.892" 9527° -ELMD TT LOGGED 05/23/93 TOP OF 7"LNR —$ 9531' 9-5/8"CSG,47#, NT-80, ID=8.681" — 9658' 4 [ II, PERFORATION SUMMARY REF LOG: BHCS ON 05/23/93 ANGLE AT TOP PERF: 28 @ 9710' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9710-9720 0 5/23/93 3-3/8" 6 9723-9786 0 5/23/93 3-3/8" 6 9789-9925 0 5/23/93 3-3/8" 6 9995-10015 0 5/23/93 3-3/8" 6 10050-10149 0 5/23/93 PBTD — 10117' 7"LNR, 26#, NT-80, .0383 bpf, ID=6.276" — 10213' J DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/17/92 ORIGINAL COMPLETION WELL: AGI-02 01/29/01 SIS-LG REVISION PERMIT No: 1921200 05/22/01 RN/KAK CORRECTIONS API No: 50-029-2231 1-00 03/13/03 AS/TP ADD IPC/THREAD FOR TBG SEC 36,T12N, R14E, 2361.5'FEL&3775.99'FNL 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate I3 Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Water Wash I3 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 192-120 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service f3 6. API Number: 50-029-22311-00-00 7. Property Designation(Lease Number): ADL 0034628 8. Well Name and Number: PBU AGI-02 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL RECEIVED 11.Present Well Condition Summary: Total Depth: measured 10215 feet Plugs measured feet true vertical 8557 feet Junk measured feet NOV y O N`t 2 4 2015 Effective Depth: measured 10161 feet Packer measured 9436 feet true vertical 8508 feet Packer true vertical 7861.57 feet 3 C Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 37-117 37-117 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 9624 9-5/8"47#NT-80 33-9657 33-8055 6870 4760 Production Liner 700 7"26#NT-80 9511 -10212 7927-8554 7240 5410 Perforation Depth: Measured depth: 9710-9720 feet 9723-9786 feet 9789-9925 feet 9995-10015 feet 10050-10149 feet True vertical depth: 8101 -8110 feet 8113-8169 feet 8171-8293 feet 8356-8374 feet 8406-8497 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 7"Baker FB-1 Packer 9436 7861.57 true vertical depth) 7"MCX SSSV 2218 2200.92 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9710-10149 Treatment descriptions including volumes used and final pressure: 746 Bbls Fresh Water+F-103,20 Bbls Neat Methanol,103 Bbls Diesel,103 Bbls Xylene,572 psi. C dip ' r' i, I-+ ', :'`r I'{ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 243.993 300 3343 Subsequent to operation: 244,852 300 3390 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations IZI Exploratory ❑ Development 0 Service 113 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ Iii SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-235 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature )104A41 Phone +1 907 564 4424 Date 11/23/15 Form 10-404 Revised 5/2015 `� �!� io�% RBDM�7 6EC 0 1 2015 Submit Original Only • • m Q 0 0 0 0 0 CO Ln Co CO r- c- 00 — (A N P. V V N 0 N L1) CO U N o 0 0 0 0 0 0 3 V 0 CO N N f-- m r CO LC) CO f— I- N- O N LC) Cr C CO Ln Ln CO M V O Lf) CO O) CO CO CO I- N- 1 1 1 1 1 1 1 I- I� N (.0 O CO N r- CO CO M M O) CO CO N- N- Q� O O N- " O) O 'tCUV CNI c 1111111 Q ' 0 rn 0 [n M CO =M Ln CO rn rn C m CO � = Y Z ~ °O CO Z F J cl)oo Z Z N co U o\o � NNN N L2 M d 10 O +' 01 ctCO O N N ON O C CO CO CO CO O V CO d M C) O) J w EtF- rnO = ._ Uwww O t Z Z Z w w m m O /) ZJHF- 0 • _ \ \ 2 2 » n $ \/ = U ƒ ) o a) < \ S q l \ _ f/ o � a = � / / \ o § (13 >-a) ▪ ± $ k 2 E a▪ s 7 —k �[ k CD ƒ m Om q m H / k\O q . > 70 ƒg . - co R 2 / \ _ -tM �� / o _ q » 0 2e ® II = 2 \ 2 RS I— a) i c n O ¢ C, \ \ k if)- ( CN E � / © _�(Na) / $ a ° 2 — a) / / / 5 % / \ £ E / k / > L I- < m a \ = o nn in 70 •:I- Q / 0 < TREE= • S4bY NOTES:WELL REQUIRES A SSSV. LINER WELLA = CNV ACTUATOR= BAKER C AGI-02 NOT CEMENTED. ALL TBG IS IPC WITH NSCC KB.ELEV= 49' BF.ELEV= KOP= 1851' Max Angle= 43 @ 6635' Datum MD= 10566' 2219' -f7"CA MCO BAL-O SSSV NIP, ID=5.937" Datum TVD= 8800'SS 13-3/8"CSG,68#, K-55, ID= 12.415" H 121' 13-3/8"CSG,68#,NT-80, ID=12.415" —f 3750' I---, 7"TBG, 26#, NT-80-IPC, NSCC, .0383 bpf, ID=6.276° — 9430' \ / 9430' —17"X 5-1/2"XO, ID=4.875" TOP OF 5-1/2"TBG —I 9430' /{ 9435' -ANCHOR, ID=4.875" Minimum ID = 4.455" @ 9505' �/ 943T H9-5/8"X5-1/2"BAKER FB-1 PKR, ID=6.000" 5-1/2" OTIS XN NIPPLE ' ' 9483' —I5-1/2"PARKER SWS NIP,ID=4.562" I I 9505' -15-1/2"OTIS XN NIP, ID=4.455" 5-1/2"TBG, 17#,L-80-IPC,NSCC,.0232 bpf,ID=4.892" --J 9517' 1---/ \ 951r 1-15-1/2"WLEG,ID=4.892" 952T —ELMD TT LOGGED 05/23/93 TOP OF 7"LNR —1 9531 I--11 9-5/8"CSG,47#, NT-80, ID=8.681" —I 9658' 4--, [ IL PERFORATION SUMMARY REF LOG: BHCS ON 05/23/93 ANGLE AT TOP PERF: 28 @ 9710' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9710-9720 0 5/23/93 3-3/8" 6 9723-9786 0 5/23/93 3-3/8" 6 9789-9925 0 5/23/93 3-3/8" 6 9995-10015 0 5/23/93 3-3/8" 6 10050-10149 0 5/23/93 PBTD —1 10117' 7"LNR, 26#, NT-80, .0383 bpf, ID=6.276" —1 10213' 4 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/17/92 ORIGINAL COMPLETION WELL: AGI-02 01/29/01 SIS-LG REVISION PERMIT No: 1921200 05/22/01 RN/KAK CORRECTIONS AR No: 50-029-22311-00 03/13/03 AS/TP ADD IPC/THREAD FOR TBG SEC 36,T12N, R14E,2361.5'FEL&3775.99'FNL 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE milimummiimmiiiiimmommw \q2- 120 of Tom, Alaska Oil and Gas �w\��\��j,�s� THE STATE �� —Y� �, of Conservation Commission -•_ _ . ALASIc:A . ' }fix2.- .3---_:-. _=JO 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 04k, AL Fax: 907.276.7542 www.aogcc.alaska.gov Spencer Morrison �E� � rp9 2921 Petroleum Engineer / I° BP Exploration(Alaska), Inc. fla- P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU AGI-02 Sundry Number: 315-235 Dear Mr. Morrison: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cath . Foerster tyChair DATED this 27 of April, 2015 Encl. ED STATE OF ALASKA APR 2 1 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION tf 4/2? APPLICATION FOR SUNDRY APPROVALS AOO C C 20 MC 25.280 1.Type of Request. Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: Water Wash E 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development El 192-120-0 • 3.Address: Stratigraphic ❑ Service 0 • 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-22311-00-00 • 7.If perforating. 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? PBU AGI-02 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0034628 ' PRUDHOE BAY, PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft). Plugs(measured): Junk(measured). 10215 • 8557 • 10161 8508 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 36.62-116.62 36.62-116 62 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 9624 9-5/8"47#NT-80 33.32-9657.06 33.32-8054.74 6870 4760 Production None None None None None None Liner 700 7"26#NT-80 9511.49-10211.62 7927.31 -8553 92 7240 5410 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size. Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft). See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12 Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work. Detailed Operations Program 2 BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 6/10/15 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date. WINJ ❑ GINJ 2 • WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Spencer Morrison Email Spencer.Morrison@BP.Com Printed Name Spencer Momson Title Petroleum Engineer Signature Phone 564-5773 7z/7f Date Prepared by Garry Catron 564-4424 , ;*.......... ..7.:7_ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 1 S -2--.2. S Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No d Subsequent Form Required: / — 46 4-. n APPROVED BY J Approved by. ! COMMISSIONER THE COMMISSION Date:4 "Z7/S l7-G 4/ 3,1/i I /--1-5 Y ZZ sForm 10-403 Revised 10/2012 0 p r slid for 12 montl�frBomDtM date pproval. Submit Form andme sin Duplicate �R S_ APR 29 2015 ,e0��5— a_) 000 0 o LO o N CO CO CO CO co C� = ZZZYJz a) 0_ 0 0 0 0 0 0 _ — V � V N N o V U) N CD LU 0 ) 0 0 0 0 0 0 0 L- 6) N V N t1) ' V 7 V CO N O V ti N m c- CO N- to CO N- N- v7 cv • N- to LoCO O CO a) CNI O to V 6) co > 00 00 M ti ti Q 0 H O N- M N CD a0 O M M C) CO(NI CO CO s— (13 (13 co E N m E co N m N N U) O O ' co co o o p 2 J , eL 0 0 co co to N co co 2 rn rn � O O Ln co co O In O 'TraO O ZHZ �# JH o *k Zoo Z O r N bp co N O M N Ln N M j f— O M com O N O N V O N N CO CO N CO CO CO V J 0) CO 6) W (7) - w0 U C D 2 « °0 U O r u i Z Z Z W W 00 00 O H Z O O > UZ � WO) HH Ii Perforation Attachment ADL0034628 Well Date Perf Code MD Top MD Base TVD Top TVD Base AGI-02 8/6/13 BPP 9710 9720 8101 8110 AGI-02 8/6/13 BPP 9723 9786 8113 8169 AGI-02 8/6/13 BPP 9789 9925 8171 8293 AGI-02 8/6/13 BPP 9995 10015 8356 8374 AGI-02 8/6/13 BPP 10050 10149 8406 8497 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0034628 Well Facility Type MD Top Description TVD Top AGI-02 PACKER 9436 7" Baker FB-1 Packer 7862 AGI-02 PACKER 9519 7" Baker H Packer 7934 ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.9,DBR,LHD,EAZ 01/15/15) General Information Well Name: AGI-02 Well Type: Gas Injection Well API Number: 50-029-22311-00 Well Activity Conventional 4 Classification: Activity Description: Water wash Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: TREAMENTS Estimated Cost, $K: - AWGRS Job Scope: TUBING WASH/PICKLE Other regulatory None requirements? Sundry Form 10-403 _ Required? Yes Sundry Form 10-404 Yes Primary Secondary 1 Required? Engineer: Spencer Morrison Contact numbers: (907) 564-5773 (713) 557-281 Well Intervention Engineer: Contact numbers: No Data No Data Lead Engineer: Chris Stone Contact numbers: (907) 564-5518 (9071 440-401 Date Created: April 6, 2015 Revisions(date,who,what changed): Current Well Status Information ( Water Rate or Gas Rate or i Oil Rate lnj Rate Gas Injection GOR Gas Lift Rate FTP or Injectic Date (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Pressure t (psi) Cut(%) (Mscf/Day) 4/5/2015 248,569 3,352 Current Status: Operable Flowing Inclination>70°at Depth (ft) ; NA 0 Maximum Deviation(Angle and 4. Recent H2S (date, ppm) ppm Depth) 43° 6,635' MD Datum depth,ft TVDss d Dogleg Severity(Angle and Depth) 7° 1,932' MD Reservoir pressure(date, psig) 3,400 psi Minimum ID and Depth 4.445"@ 9,505' Reservoir Temp, F 130° F Shut-in Wellhead Pressure 2,400 psi Known mech. integrity None, passing MIT-IA and MIT-T problems(specifics) Last downhole operation(date, operation) 8/6/2013 Pressure test for integrity, set plug at 9,505' and pulled after. Most recent TD tag (date,depth, 8/26/2006 10,178' MD 3.25"Centralizer toolstring OD) Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, AGI-02 had 2 water washes with the most recent on 7/11/2011 being 300 bbls of 50 F diesel followed by background information, 220 bbls of 90 F FW with surfactant at 5 BPM. The earliest water wash was on 11/24/2006 with 50 bbls of etc: 50/50 D/X followed by 600 bbls of 110 F FW with surfactant at 5 BPM. The most recent failed water wash used only diesel for a preflush and the ealier successful wash was aiesevxy. ,�e. i nis wasn wilt use U/A to try aria mimic me e, ,r wasn s success. • This summer there will be an NGI restoration project that will include significant down time for the NGI wells. I have included the tentative schedule below.To reduce the impact of having the NGI wells shut in for work, water washes are needed on good candidates on AGI and WGI. NGI Restoration schedule: 1.Well lateral line work starts April 15 when we will take 2 NGI wells down at a time for repairs lasting 7-9 days per set. We will start with wells 13/14 and work south until complete with pre-TAR scope. 2. Starting on June 26th we will take down NGI wells 1-12 to support blinding and repairs in the vicinity of FV6302/6203 for 9 days-This is outage one. 3. Following outage one and roughly on July 4th we will restart NGI wells 8-12(13 and 14 were already on line)and wells 1-7 will remain down for approximately 30 days for outage 2. 4. Following completion of outage 2 we will restart wells 1-7 and take down NGI wells 8-14 and begin repairs on the north end of NGI headers/laterals. This is outage 3 and duration is roughly 30 days. 5. Following outage 3 we will need to restart NGI wells 11-14 and take down NGI wells 1-10 to allow for blind removal at FV6302/6203. This is outage 4 and I estimate 2 days for this outage. 6. Finally we then will restart all of the NGI pipelines and wells that were down for blind removal and be back to normal with repairs in place. This is the base schedule and if we find additional corrosion damage the extends our scope of work then we could have some wells off line for longer duration. If the water washes go to plan,we will improve injectivity by dissolving salts and possibly asphaltenes in • the tubing and formation. Diesel/Xylene washes have been used successfully in the past on the NGI/WGI/AGI gas injectors to improve injectivity. Well Intervention Details Suspected Well Problem: Oragnic deposition Specific Intervention or Well Objectives: 1 Increase well injectivity by cleaning the tubing and perforations 2 3 Key risks,critical issues: Mitigation plan: 1 2 3 Summary Service Line Activity Step# 1 Pump Water Wash as per attached template 2 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: Expected Production Rates: FTP(psi): Choke setting: Post job POP instructions: Bring back well to injection Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: TREE_ WELLHEAD= CNV ��' O TY NOTES:WELL REQUIRES A SSSV. LINER •ACTUATOR= BAKER C NOT CEMENTED. ALL TBG IS IPC WITH NSCC KB.ELEV= 49' BF.ELEV= KOP= 1851' Max Angle= 43 @ 6635' Datum MD= 10566' 2219' —1 7"CAMCO BAL-O SSSV NIP, ID=5.937" Datum TVD= 8800'SS • III I- 13-3/8"CSG,68#, K-55, ID= 12.415° — 121' 13-3/8"CSG,68#,NT-80,ID=12.415" H 3750' 1--, 7"TBG,26#, NT-80-IPC, NSCC, .0383 bpf, ID=6.276" —I 9430' / \ 9430' _H 7"X 5-1/2"X0, ID=4.875" TOP OF 5-1/2"TBG —I 9430' 9435' ANCHOR, ID=4.875" Minimum ID = 4.455" @ 9505' S 943T H9-5/8"x 5-1/2"BAKER FB-1 PKR,ID=6.000" 5-1/2" OTIS XN NIPPLE 1 ' 9483' —15-1/2"PARKER SWS NIP, ID=4.562" 9505' —5-1/2"OTIS XN NIP, ID=4.455" 5-1/2"TBG 17#,L-80-IPC,NSCC,.0232 bpf, ID=4.892" — \ _ , p , 9517' � 951 T �5 1/2"WLEG, ID 4.892" 9527' —)ELMD TT LOGGED 05/23/93 TOP OF 7"LNR —I 9531' 1-1. 9-5/8"CSG,47#, NT-80, ID=8.681" — 9658' 1.____/ ' PERFORATION SUMMARY REF LOG: BHCS ON 05/23/93 ANGLE AT TOP PERF: 28 @ 9710' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9710-9720 0 5/23/93 3-3/8" 6 9723-9786 0 5/23/93 3-3/8" 6 9789-9925 0 5/23/93 3-3/8" 6 9995-10015 0 5/23/93 3-3/8" 6 10050-10149 0 5/23/93 PBTD — 10117' 7"LNR, 26#, NT-80, .0383 bpf, ID=6.276" -J 10213' , DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/17/92 ORIGINAL COMPLETION WELL: AGI-02 01/29/01 SIS-LG REVISION PERMIT No: 1921200 05/22/01 RN/KAK CORRECTIONS API No: 50-029-22311-00 03/13/03 AS/TP ADD IPC/THREAD FOR TBG SEC 36,T12N,R14E,2361.5'FEL&3775.99'FNL 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE I i XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /¢5,¢_.--/~_/() File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: GrayScale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED .~- Logs-of various kinds [] Other COMMENTS: Scanned by: Beverly Dianl~~~athan Lowell [] TO RE-SCAN Notes: - Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: ~si • • 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 Alaska Oil and Gas Conservation Commission SLAN14E0 AUG 0 7 2012 333 West 7 Avenue Anchorage, Alaska 99501 1 9-g° 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 • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) AGI Date: 01/10/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date AGI -01 1921240 50029223070000 0.6 NA 0.6 NA 3.4 7/25/2011 - ►GI-02 1921200 50029223110000 0.6 NA 0.6 NA 3.4 7/25/2011 AGI-03 1921350 50029223180000 3.8 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 153 7/24/2011 AGI-09 1930350 50029223500000 Split conductor NA NA NA NA NA AGI -10 2061350 50029223530100 Dust cover NA NA NA NA NA ~ MEMORANDUM To: Jim Regg ~~ ~ f ~~~ ~~ P.I. Supervisor ~ FROM: leff 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-02 PRUDHOE BAY LJNIT AGI-02 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv 1~ Comm Well Name: PRUDHOE BAY iJNIT AGI-02 Insp Num: mitJJ090906173246 Rel Insp Num: API Well Number: 50-029-22311-00-00 Permit Number: 192-120-0 ~ Inspector Name: Jeff Jones Inspection Date: 8~20/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well AGI-0 y e Inj. c~~ 7863 IA 970 2210 ~ 2190 2190 s - P.T.D 192~20o TypeTest SpT j Test psi 1965.75 OA 60o i ~io ~to ~~o Interval 4YRTST P~ P -~ Tubing ~ 3370~ 3360 I 3360 3360 NOtes' 2 BBLS 60/40 methanol pumped. '1;~ni;# ~ ~ h~ }~w ~., ~ ~ .) ~.i .i',~ar. ~1~Y '~iw.+Y+' ~ a .. _.. _ Tuesday, September 08, 2009 Page ] of 1 • ! STATE OFALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_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: OS/20/09 OPERATOR REP: Torin Roschinger AOGCC REP: ~~'~~ ~ ~°I ~, - o ~~ Packer De th Pretest Initial 15 Min. 30 Min. Well AGI-02 T e In'. G ND 7,862' Tubin 3370 3360 3360 3360 Interval 4 P.T.D. 1921200 Ty e test P Test si 1965.5 Casin 970 ~2210 2190 ~2190 P/F P Notes: MIT-IA for 4 year regulatory compliance OA 600 710 710 710 Well AGI-03 Type in'. G TVD 7,885' Tubin 3450 3460 3460 3440 Interval 4 P.T.D. 1921350 T e 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 ND 7,920' Tubin 3410 3400 340~ 3400 Interval 4 P.T.D. 1921460 T e test P Test psi 1980 Casing 590 2210 2240 2280 P/F F Notes: OA 300 415 430 450 Well AGI-06 Ty e Inj. 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 Weil T pe Inj. TVD Tubin Interval P.T.D. Type test Test psi Casin P/F Notes: OA TYPE INJ Codes D = Driliing Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R= Intemal Radioactive Tracer Survey A = Temperature Momaly Survey D = Differential Temperature Test ~• ~~~c. ~ i_ ~ ~+.' ;r~,q~) ~~ t ,;~, ~ W ~H ~+ tlW4 ~~~ ~I~~~~~ 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, O6 OS-22-09.x1s MEMORANDUM ) TO: Jim Regg. ~dc' cY¡'í3/C/-' P.I. Supervisor l t ':J FROM: John Crisp Petroleum Inspector Well Name: PRUDHOE BAY UNIT AGI-02 Insp Num: mitJCr050825130821 Rei Insp Num ".-.- rm Well AGI-02 !Type Inj. . G P.T. 19212~~J!xpeT;~tl SPT Int~ry..ª1.__4YRTST J:>Œ Notes 2.3 bbls pumped for test. Tuesday, August 30, 2005 ') State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 30, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC AGI-02 PRUDHOE BAY UNIT AGI-02 Src: Inspector NON-CONFIDENTIAL API Well Number 50-029-22311-00-00 Permit Number: 192-120-0 , \ 'J..;Ú \ C\'ð Reviewed By: P.I. Suprv _~G!L Comm Inspector Name: John Crisp Inspection Date: 8/23/2005 30 Min. 45 Min. 60 Min. Packer Depth Pretest Initial 15 Min. I .--_.'~~-_. . TVD 7863 ' IA 580 2170 2160 ~_._---_._- -- Test psi 1965.75 ¡ OA 100 100 100 P Tu ~!.~.~.J 3500 3500 3500 _w....,,__..·._._·_.__ .u_..... _.. .'_~_.._._ (::;f·cl~N~»¡FU-'11 «"E"P '"" .~ 2r:'ní' \'i~ 'I~/..r~..~.. R",1 'i;";.~,,~j \.),~ r~J ('I JL U Ur] 2160------------ I --- ---+ ---- . -1-·------- ._.___----1_.......______ 100 3500 Page 1 of 1 MEMORANDU~ State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser ~"-t,q~' DATE: May 27, 2001 Commissioner . SUBJECT: Mechanical Integrity Tests THRu: TomMaunder Zf',,~ .,~..~ BPX P.I. Supervisor/~, ~o.~- ~ AGI Pad (~ [c,,...-O \ AGI-01, 02, 03, 04, 05 FROM: Jeff Jones PBU Petroleum Inspector PBF NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. w~,I ^~,_o~ i~,~.1 ~ i ~.v.~. i~o i~,~1~oo i~oo i '~oo i~oo I,n,~a,I 4 P.T.D.I 192-124 ITypetestl P ITestpsiI 197S I CasingI 450 I 21001 20901 2°e°l P/F I P: Notes: w~,,I AG,-02 I Type,~j.I G I T.V.D. 17SS8 I T~b,ngl~5oo'1 ~oo i ~oo i3~oo I,nter~,J 4 P.T.D.] 192-120 Imypetestl F; 'JTestpsiI 1965 J CasingI 325 J 2100J 2100I 2100I P/F J P Notes: WellI AGI-03 P'.T..D.I 192-135 Notes: P.T.D.I 192-146 Notes: We,,I AG,-05 I Type,nj.I G I T.V.D'17745 I Tubing J 3500 13500 13500 13500l lntervall 4 P.T.D.I 193-002ITypetestl P I Testpsil 1936 I CasingI 600 I 21001 21001 21001 P/F I P Notes: [TypetestI P ITestpsiI 1968 I CasingI 600 '1 21201 2110l 2110l p/F I P I Type,nj.I GI T.V.D. I ~,~, I Tubing 13500 I~00 I~00 I~00 l~nte"'~'I 4 Type testI PI Testpsil ~7~ IC~mI 3~0 I 2~SOI 22001 ~200 I' P/~ I P Type IN J. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Sunday, May 27, 2001: I traveled to BPX's AGI Pad to witness 4 year MIT's on gas injection wells AGI-01, 02, 03, 04, and 05. The pre-test pressures were observed to be stable and the standard annulus pressure test was then performed with all five wells passing the MIT's. The test data above indicates these wells are suitable for continued injection. Summary,: I witnessed five successful MIT's on BPX's AGI Pad in the Prudhoe Bay Field. M.I.T.'s performed: _5 Number of Failures: _0 Total Time during tests: 3 hrs. Attachments: cc: MIT report form 5/12/00 L.G. MIT PBU AGI-01,02,03,04,05 5-27-01 JJ 6/9/0t THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON O.R BEFORE DECEMBER 01, 2000 E PL W M ATE IA' LU N D E R T H IS M A R K E R "-'-, STATE OF ALASKA ALASI'., OILAND GAS CONSERVATION t. MMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed' Operation shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 1701' NSL, 2411' WEL, Sec. 36, T12N, R14E, UM At top of productive interval 1528' NSL, 2299' EWL, Sec. 31, T11N, R15E, UM At effective depth 10 1995 At total depth 1517' NSL, 2520' EWL, Sec. 31 T12N R15E, 12. Present well condition summary Total depth: measured 10215 feet Plugs(measured) true ve~ical 8551 feet 6. Datum of elevation(DF or KB) 49' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number AGI-2 9. Permit number/approval number 92-120 10. APl number 50 - 029-22311 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured 10161 feet true vertical 8500 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 75' 20" 11 Yds Arcticset 75' 75' Surface 3709' 13-3/8" 2386 cuft PF 'E' & 460 cuft Gl 'G' 3750' 3483' Production 9621' 9-5/8" 500 Sx CI 'G' 9658' 8056' Liner 682' 7" 135 Sx CI 'G' 10213' 8555' Perforation depth: measured 9710-9720'; 9723-9786'; 9789-9925'; 9995-10015'; 10050-10149' true vertical 8101-8110'; 8113-8169'; 8171-8293'; 8356-8374'; 8406-8497' Tubing (size, grade, and measured depth) 7", 26#, NT-80, NSCC Tbg @ 9430' MD; 5-1/2", 17#, L-80, NSCC Tbg @ 9517' MD Packers and SSSV (type and measured depth) Baker FB-1 Packer @ 9437' MD; 7" Camco BaI-O SSSV @ 2219' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) SEE ATTACHED Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 206211 Tubing Pressure 3454 187868 .... 3461 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended __ Service ~'~'1~ Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FSiogr nme~0_4 R~ev 06/1~:8 ~¢J~ KRF cc: KZ, JWP Title Engineering Supervisor Date SUBMIT IN DUPLICATE AGI-2 STIMULATION TREATMENT DESCRIPTION OF WORK COMPLETED 4/1 8/9 5: MIRU CTU & PT equipment. Loaded wellbore w/1% NH4CI Water, then RIH w/CT & reciprocated an acid stimulation across the perforation intervals located above fill at: 9710 - 9720' MD (Z4) 9723 - 9786' MD (Z4) 9789 - 9925' MD (Z3/2) 9995 - 10015' MD (Z2) 10050 - 10149' MD (Z2/1) Ref. Log: BHCS. Pumped: a) 125 bbls 75% Diesel/25% Xylene @ 1.7 bpm & washed down to 10159' MD, followed by b) 208 bbls 10% HCI w/10% Xylene @ 1.8 bpm, followed by c) 101 bbls 9% HCI - 1% HF @ 2.9 bpm, followed by d) 105 bbls 10% HCI @ 2.9 bpm, followed by e) 85 bbls 75% Diesel/25% Xylene, followed by f) 33 bbls Diesel Flush, followed by g) 484 bbls 1% NH4CI Water Overflush down backside @ 3.2 bpm, followed by h) Shutdown. POOH w/CT. Rigged down. Returned well to gas injection & obtained a valid injection rate. A,Y l 0 1995 A aC, a & Oone. CommOn PERMIT DATA 9GCC Individual Well Geological Materials Inventory T DATA_PLUS Page: 1 Date: 11/10/94 RUN DATE_RECVD 92-120 5823 92-120 SURVEY 92-120 SURVEY 92-120 SURVEY 92-120 DAILY WELL OP 92-120 407 92 - 120 SBT/GR/CCL 92-120 PERF T 8691-10215 OH/DPR/GR R 0.00-10215 GCT R 0-10154 TELECO MD&TVD R 0-10154 TELECO MD&TVD R 11/30/92-04/08/93 R COMP DATE:05/20/93 L 10156-10163 L 9400-10043 1 92-120 JWL L 9360-10160 1 92-120 DPR/GR 92-120 DPR/GR L 7229-8521 TVD L 8691-10183 MD 4-8 4-8 10/19/93 08/26/93 02/01/93 01/28/93 08/26/93 08/26/93 03/19/93 07/30/93 07/30/93 02/01/93 02/01/93 Are dry ditch sample~ r~rg~? yes no And received? Was the well cored?/~~/n~/Analysis & description received? Are wel ests require~~ ~X ~"~ no . yes no esl t Received~ Well is in compliance 'A% \ ~i~ial COMMENTS yes no yes no P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-11-93 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS Please sign and return the attached copy as receipt of data. Have i Nice Day! Sonya Wallace APPROVED ATO-1529 Trans# 9311~ CENTRAI, FILES (CH) # PHILLIPS CHEVRON D&M # BOB (OH/GCT) # EXXON MARATHON MOBIL PB WELL FILF~ R&D # BPX # STATE OF ~KA TEXACO * The correct logging date for this tape is 12/24-31/92. INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL 08/30/1993 PAGE: 1 92-120 DPR/GR 92-120 DPR/GR 92-120 JWL 92-120 PERF 92-120 92-120 92-120 92-120 92-120 Are well tests required? Was well cored? Yes No... SBT/GR/CCL 407 DAILY WELL OP SURVEY SURVEY Yes No RUN4-8, 2&5" MD RUN4-8, 2&5" TVD 5" RUN 1 5" RUN 1 CH R1 5" COMP DATE:05/20/93 11/30/92-04/08/93 MWD DIRECTIONAL SS DIRECTIONAL If yes, was the core analysis & description received? Yes No Are dry ditch samples required? Yes No WELL IS ON COMPLIANCE. INITIAL CO~{MENTS: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO,v, MISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [~X Ar)ex ~a~/n. iector 2. Name of Operator 7. Permit Number ' /'~'~" ARCO Alaska, Inc. 92-120 ' 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22311 4. Location of well at surface 9. Unit or Lease Name 1701' NSL, 2411' WEL, SEC. 36, T12N, FI~.I~4ET.~.~ ~:.~r~,m -[-[~~t Prudhoe Bay Unit Top Producing Interval i ~ATE ~ At At Total Depthi~ ~_~_~C ~ Prudhoe Bay Field/Prudhoe Bay Pool 1517' NSL, 2520' EWL, SEC. 31, T12N, R'f5E~;~;jj-~- 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Sedal No. KBE = 49' I ADL 34628 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 11/30/92 12/15/92 5/20/93I N/A feet MSL I Zero 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD'.19. Directional Survey I0. DepthwheroSSSVset I1. Thickness of Permafrost 10215' MD/8551' TVD 10161' MD/8500' TVD YEs [] NO [] 2219' feet MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, Gyro 23. CASING, LINER AND CEMENTING ~ SETI'I',IG DEPTH MD CASING SIZE VVT. PER FT. GRADE TOP Be'I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5~ H-40 Surface 75' 30" 11 yds Arcticset 13-3/8" 68# BTC 41' 3750' 16" 2386cu ft PF "E"/460 cu ft Class "G" 9-5/8" 47# NT-80 37' 9658' 12-1/4" 500 sx Class "G" 7" 26# NTS80 9531' 10213' 8-1/2" 135 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SETIMD} PACKER SET (MD) Gun DiameterMD 3-3/8" 7~f 7" x 5-1/2" 9517' 9437' 9710'-9720' 8101 '-8110' NT-80/L-80 9723'-9786' 8113'-8169' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8789'-9925' 8171 '-8293' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIALUSED 9995'- 10015' 8356'-8374' 10050'-10149' 8406'-8497' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 5/31/93 Gas Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD II~ 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 dips, and presence of oil, gas or water. Submit core chips. Form 10-407 Submil in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS I-,..,~MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 9714' 8101' Zone 3 9792' 8174' Zone 2 9858' 8233' Zone 1 10079' 8433' Base Sadlerochit 10149' 8500' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Sig ~er~d~'~ ~, ~' ~~--~~k.. Title OrillingEn~_inoorSuoervisor Date ~'/~"'~"~' "'~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". J~ ~' C ~IV ~ ~ Form 10-407 U G 2 .¢; t99;5 Alaska Oil & Gas Cons. ~;on~iss~o~' Anchorage BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: AGI #2 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50-029-22311 PERMIT: APPROVAL: ACCEPT: 11/29/92 06:30 SPUD: 11/30/92 04:30 RELEASE: 04/07/93 09:00 OPERATION: DRLG RIG: AUDI 2 WO/C RIG: AUDI 2 11/30/92 ( 1) TD: 200'( 0) 12/01/92 (2) TD: 2053' (1853) DRLG. MW: 8.5 VIS: 0 RIG ACCEPTED @ 18:30 HRS, 11/29/92. R/U DIVERTER. MIX SPUD MUD. P/U BHA. SPUD WELL @ 04:30 HRS, 11/30/92. DRLG F/ 100'-200' DRLG. MW: 9.2 VIS:148 DRLG TO 2053'. CIRC. SHORT TRIP TO 218'. 12/02/92 (3) TD: 3760'(1707) 12/03/92 ( 4) TD: 3760' ( 0) 12/04/92 (5) TD: 6111' (2351) 12/05/92 (6) TD: 6837' ( 726) 12/06/92 (7) TD: 7952' (1115) 12/07/92 ( 8) TD: 8674' ( 722) RUNNING 13-3/8 CASING MW: 9.4 VIS:il0 DRILLING TO 3300' SERVICE RIG. DRILL TO 3760'. CBU. SHORT TRIP. CBU. RUN 13-3/8 CASING. DRILLING CEMENT MW: 9.0 VIS: 35 RAN 13-3/8 CASING. CIRC. RECIPROCATED CASING. TEST LINES. PUMPED WATER & CEMENT. PERFORMED TOP JOB. TESTED BOPE. RIH. TESTED CASING. DRILLING CEMENT & FLOAT EQUIPMENT. DRILLING AT 6111'. MW: 9.2 VIS: 40 DRILLED CEMENT TO 3760'. CBU FOR LOT. RAN LOT. DRILL TO 4393' PACKED OFF WITH CLAY. DRILL TO 4675'. CBU. SHORT TRIP. RIG SERVICE. DRILL TO 4527'_ PACKED OFF. DRILLED TO 5466'. PACKED OFF. DRILL TO 5990' CBU. DRILLED TO 6111' DRILLING @ 6837' MW: 9.2 VIS: 45 DRLD F/6111'-6629', TOP DRIVE FAILED, CBU, POH, L/D DP,RIG SERVICE, POH, L/D DP, L/D PIPE HANDLER F/TOP DRIVE, P/U KELLY, M/U HOSES & KELLY, M/U BIT # 3 & TIH TO 6547', WASH F/6547'-6629', DRLD F/6629'-6837' W/KELLY DRILLING @ 7952' MW: 9.5 VIS: 40 DRLD F/6337'-7711', RIG SERVICE, DRLD F/7711'-7689', REPAIR MUD PUMP #1, REPLACED LINER & WEAR PLATE (WASHED OUT), DRLD F/7869'-6627' DRILLING @ 8674' MW: 9.7 VIS: 43 CIRC FOR SHORT TRIP F/7954'-6454', NO FILL, DRLD F/7954'-8060', REPAIR SWAB & LINER IN PUMP #1, DRLD F/8060'-8401', RIG SERVICE, DRLD F/8401'-8530', REPAIR SWAB & LINER IN PUMP #2, DRLD F/8530'-8674 , A U G 6 Alaska 0il & Gas Cons. Commissior~ Anchorage WELL : AGI #2 OPERATION: RIG : AUDI 2 PAGE: 2 12/08/92 (9) TD: 8884' ( 210) 12/09/92 (10) TD: 9585' ( 701) 12/10/92 (11) TD: 9670' ( 85) 12/11/92 (12) TD: 9670' ( 0) 12/12/92 (13) TD: 9680' ( 10) 12/13/92 (14) TD: 9883' ( 203) 12/14/92 (15) TD:10181' ( 298) REPAIRING MUD PUMP ~2 MW: 9.9 VIS: 50 DRLD F/8674'-8744', CIRC & DROP SS, TRIP F/BIT, SERVICE RIG, RETRIEVED SS, CHG BHA, P/U MWD, RIH TO 8677', WASH F/8677'-8744', DRLD F/8744'-8765', CIRC OUT TRIP GAS, DRLD F/8765'-8842', REPLACED WAB & LINER IN PUMP #2, DRLD F/8842'-8874F', POH 5 STDS, REPLACED KELLY HOSE, RIH 5 STDS, DRLD F/8874'-8884', REPAIR PUMP #2, REPLACED SWAB & LINER DRILLING MW:10.0 VIS: 47 REPAIR CTR POT ON PUMP #2, POH & L/D 15 JTS HWDP, CHG JETS INB BIT & RIH, SLIP & CUT DRLG LINE, SERVICE RIG, RIH TO BTM, DRLG AHEAD RUN CSG. MW:10.0 VIS: 50 DRLG TO 9670'. CBU. 20 STDS SHORT TRIP. CIRC. POOH. R/U WOTCO. RIH W/ 9-5/8" CSG. L/D TOP DRIVE. MW:10.1 VIS: 60 RIH W/ 9-5/8" CSG. WASH CSG TO BTM. CIRC. R/U HOWCO. PUMP 20 BBLS PREFLUSH, 50 BBLS SPACER, 500 SX PREM CMT @ 15.8 PPG. DISP W/ MUD. L/D CSG TOOLS. INSTALL PACKOFF. TEST BOPE. OK. L/D BHA. P/U BHA. RIH TO FC. CBU. L/D TOP DRIVE. DRLG. MW: 9.1 VIS: 61 L/D TOP DRIVE. TEST CSG. OK. DRLG FC, FS, 10' NEW HOLE. CBU. FIT (12.5 PPG EMW). CLEAN PITS. DISP WELL W/ KCL MUD. DRLG TO 9680' DRLG. MW: 9.2 VIS: 62 DRLG F/ 9680'-9834' CBU. POOH. CHANGE BIT. RIH. REAM F/ 9735'-9834' DRLG F/ 9834'-9883' DRLG. MW: 9.2 VIS: 43 POOH. CHANGE BIT. RIH. REAM 45' TO BTM. DRLG TO 10181' 12/15/92 (16) TD:10215' ( 34) 12/16/92 (17) TD:10215 PB: 0 REV CIRC CMT. MW: 9.2 VIS: 55 DRLG TO 10215'. TD WELL @ 08:30 HRS, 12/15/92. CBU. SHORET TRIP TO SHOE. CIRC. POOH. RIH W/ 7" LNR ON DP. TAG BTM. CIRC. R/U HOWCO. PUMP 20 BBLS PREFLUSH, 40 BBLS SPACER, 135 SX CMT. BUMP PLUG. SET HGR, PKR. R/U TO REV OUT CMT. RIH. MW: 9.2 KC1 REV CIRC. CIRC. POOH. L/D RUNNING TOOL. RIH W/ BHA, CSG SCRAPER. TAG CMT @ 10098' BIT PLUGGED. POOH. L/D BHA PLUGGED W/ CMT. RIH W/ MILL, BHA. Ai.jG 2 6 199~ Alaska 0il & Gas Cons. uon~issio~' Anchorage WELL : AGI #2 OPERATION: RIG : AUDI 2 PAGE: 3 12/17/92 (18) TD:10215 PB:10171 04/06/93 (19) TD:10215 PB:10171 04/07/93 (20) TD:10215 PB:10171 04/08/93 (21) TD:10215 PB:10171 RIG RELEASED. MW: 9.3 NaC1 CIRC @ TOL (9520'). RIH. TAG CMT. DRLG CMT F/ 10064'-10161' CIRC. TEST CSG. DRLG LC, CMT TO FC @ 10171'. CIRCi DISP W/ BRINE. POOH. PUMP 50 BBLS DIESEL IN ANNULUS, DISP TO 600' W/ DIESEL. POOH. N/D BOPE. N/U DRY HOLE TREE. TEST TREE. RIG RELEASED @ 06:00 HRS, 12/17/92. R/U W/L. MW: 9.3 NaC1 RIG ACCEPTED @ 10:30 HRS, 4/5/93. N/D TREE. N/U BOPE. TEST BOPE. RIH TO 600' DISP OUT DIESEL. RIH W/ BAKER 'FB-i' PKR & 5-1/2" TAIL ASS'Y ON DP. SET PKR @ 9437' RELEASE F/ PKR. POOH. N/U TREE. MW: 9.3 NaC1 RIH W/ TSA MAGNET W/ ATLAS W/L. WORK TO XN NIPPLE. POOH SLOWLY. NO FISH. RIH W/ TBG. DISP TOP W/ DIESEL. LAND TBG. TEST TBG, ANNULUS. OK. N/D BOPE. N/U TREE. RIG RELEASED. MW: 9.3 NaC1 N/U TREE. TEST TREE. SECURE WELL. RIG RELEASED @ 09:00 HRS, 4/7/93. SIGNATURE: (drilling superintendent) DATE: L2 993 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. l:'.OJ3o~ 100~60 Anehorn~e, ~ GG~IO DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINALS 5-13 77~ ~ 5-28-93 5-24 ?/*/~ 5-22-93 5-32 ~ ~? ~ 5-27-93 6-12A ~-~ 5-29-93 6-14A ~-~75-19-93 7-147~! 5-25-93 9-37t,.~...- 5-18-93 9-3 5-24-93 * 9-4A ~-~¥ 5-26-93 9-5A ? ~-~- ~ 5-30-93 ** 9-28A ~]-~ 5-28-93 9-31A ~-~35-19-93 9-32 ~3--/1~'5-30-93 12-15 e~o~- 5-27-93 12-23 ~- ~t~ 5-27-93 14-22 .~. 5-23-93 14-22AA~l "]5-23-93 .(~~ 18-20A ~5-18-93 AGI-1- -i~ 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 , a5-21-93 Primary Perf Record AGI-4 ~A~5-22-93 Initial Peal Record ~ve A ~~ Son~ w~ce ~PP i~1529 'Ires, 9~7~~~-~/~/0~ # Ca~rritAL Fr~ #CHEVRON #BPX # STATE OF ALASKA Completion Record R~m 1, 5" Sch TDTP (Borax) R~m 1, 5" Sch GR/Collar Run 1, 5" Atlas TDTP (Borax) Run 1, 5" Sch TDTP (Borax) Run 1, 5" Sch Production Log R~n 1, 5" Sch Prod Profile Run 1, 5" Sch Perf Record Run 1, 5" Sch Frod Proffie R.n 1, 5" Sch Production Log Run 1, 5" Sch Completion Record R~m 1, 5" Sch Production Log R~_m 1, 5" Sch CBT Run 1, 5" Sch Completion Record R~_m 1, 5" Sch Completion Record Run 1, 5" Sch ' Leak Detection Run 1, 2" Sch Perf Record Run 1, 5" Sch PITS R-n 1, 5" Sch Perf Record R~m 1, 5" Sch Jewelry R~_m 1, 5" Sch Perf Record R~_n 1, 5" Sch Jewelry R-n 1, 5" Sch Run 1, 5" Sch Run 1, 5" Sch Run 1, 5" Sch Run 1, 5" Sch The correct well name for this log is 9-4A. The correct API# for 9-28A is 50-029-21292-01. ARCO Alaska, Inc. Post Office Bo~ _~360 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 FILE Re: Notice of Gas Injection Dear Mr. Johnston: This is to inform you that on May 30, 1993 ~ARC.0 began gas in]ection on the Apex Gas Injection pad. AGI. wells #1, #2, #3 and #4 are p~erf0ra't~d ana gas is being injected at this time. Injection volumes, tubing and casing 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 Atlantic Richfield Company RECEIVED d UN - 9 199 5 Alaska 011 & 6as Cons. CommiSSiO[~ Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-12-93 REFERENCE: ARCO CASED HOLE FINALS ~Z-IZ0 AGI-2 ~I~$AGI-3 8-4-92 TMD (Boron) 7-3-92 DSN **Corrected** 1-2-93 USIT Color 1-3-93 CBT Color 1-3-93 USIT Color 12-9-91 TMD 1-9-93 Segmented Bond/GR/CCL 1-14-93 Segmented Bond/GR/CCL R11n 1, R.n 1, Rl~n 1, Run 1, Run 1, Ru~ 1, Run 1, Please sign and return the attached copy as receipt of data. Have A Nice Day! Sonya Wallace ATO-1529 APPROVED Trans# 93031 1! 5" 5" HLS HLS Sch Sch Sch HLS Atlas Aths # CENTRAL FILES # CHEVRON D&M # LUCILLE JOHNSTON # EXXON MARATHON # MOBIL # PIHL~ PB WELL FILES R&D # BPX # STATE OF ALASKA. TEXACO RECEIVED MAR 1 9 1996 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 12-21-92 REFERENCE: ARCO DIRECTIONAL DATA Q~-ItD ll-13A 11-9-92 MWD Directional Survey Ana - _~12.~14-22A 11-29-92 MWD Directional Survey Aha 7-20 10/4-15/92 MWD Directional Survey Job~ 1149 Teleco ~--~7-21 12-3-92 MWD Directional Survey Job~1153 Teleco ~~18-22 11-30-92 'MWD Directional Survey Job#AK-MW-20092 Sperry ~~AGI-1 11-23-92 MWD Directional Survey Job~ 1152TAK Teleco ~7~/~'~ ~I-2 12-15-92 MWD Directional Survey Job~ 1156 Teleco Please sign and return tl~e attached copy u receipt of data. Have l Nice Day! ~~ / ATO-15~ .~ CENTRAL FILES CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON MOBIL PmLIAPS # PB WELL FILES R&D # BPX # ST. OF AK. (2 COPIES) RECEIVED FEB 0 1 199] ~aska Oil & Gas Cons. Commiss~Q' ~chorage ARCO Alask~__, Inc, P.O.Box 100360 Anchorage, Alaska 99510 DATE: 1-7-93 HEFERENCE: ARCO OPEN HOLE FINAI~ - ~ ~t~2~4A 12-22-92 ~__~9 12-25-92 9 12-25-~ (~ '"~ ~-~-~-~ 11/1~13/~ /~~-~ 11/1~13/~ , ~ ~~-~ 11/1~13/~ ~ ~k 7 ~'~ 11/1~13/~ ~*~ / ~-~ 11/1~13/~ -- ~ ~-~ 11/1~13/~ ~~ 11/1513/~ -/150~_ I-i 12/7-13/~ SSTVD Run 1, Dnm/GR ~un 1, BHCA/GR Run 1, 5" CNL/GR Run 1, SSTVD Color Run 1, DLL/MSFL/GR ~hm 1, BHCS Color Run 1, CNL/GR Color Run 1, DPR/GR Runs 56, DPR/DP/GR Runs 5-6, DP/GR Runs 5-6, BD/GR Runs 5-6, DFR/GR Runs 56, DPR/DP/GR Runs 5-6, DP/GR Runs 56, DPR/GR R~_mS_ 4-8, DPR/GR Rtms 4-8, 2' & ~' MD Please sign and return~ attach.~d~op~t of data. .E iVE Have A Nice Da~// R ~ C ~ [V E D Soriya Wallace ATO-1529 ~:~[3 0 '1 1995 APPROVED_ · Trans# 93004 Alaska 011 & 0as Co,~. Commis~ie, A,chora.q~ # CENTRAL FILES # CHEVRON #D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL Atlas Atlas Atlas Atlas Sch Sch Sch Sch Teleco Teleco Teleco Teleco Teleco Teleco Teleco Teleco Teleco # PHILLIPS # PB WELL FILES R&D # BPX # STATE OF ALASKA # TEXACO * The correct name for this well is 1-24A, not 1-24ST. STATE OF ALASKA ALASKA UlL AND GAS CONSERVATION CO,v MISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG Classification of Service Well OIL [] GAS [] SI..ISFT=t,,DED [] ABAN~X~,I~' [] SERVICE [~<x AD~x G~ In.i~l;tor 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 92-120 3. Address B. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22311 4. Location of well at surface 9. Unit or Lease Name 1701'NSL, 2411' WEL, SEC. 36, T12N, R14E,;..;:;;.~ : . ~1 Prudhoe Bay Unit At Top Producing Interval > ~";)!~ :! V[-~:|ED ] 10. Well Number At Total Depth Field/Prudhoe Bay Pool 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 49' ] ADL 34628 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 11/30/92 12/15/92 12/17/92! N/A feet MSL Zero 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey ]20. Depth where SSSV set ]21. Thickness of Permafrost / 10215' MD/8551' TVD 10161' MD/8500' 7-VD YES [] NO [] Noneleet MD ! 1900' (Approx.) 22. Type Eleclric or Other Logs Run None 23. CASING, LINER AND CEMENTING SETTING DEPTH MD CASING SIZE WT. PER F-I'. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 75' 30' 11 yds Arcticset 13-3/8" 68# B TC 41' 3750' 16" 2386cu ft PF "E'/460 cuft C/ass 'G' 9-5/8" 47# NT-80 37' 9658' 12-1/4" 500 sx C/ass 'G" 7" 26~ NTS80 9531' 10213' 8-1/2" 135 sx C/ass 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None None None 26. ACID, FRACTURE, CEMENTSQUEEZ]~, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) Not yet injecting I N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL ,.~,S-MCF WATER-BBL CHOKE SIZE ~GAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED..~ DIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS r,..,RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Shublik 9696' 8034'(ss) Top Sadlerochit 9722' 8057' (ss) Base Sadlerochit 10159' 8441' (ss) >i~% ,~..f ._ ii::' ,.., '.~ , ;,., ~ ., · ,,. ;: ,, '":" , 3]. LIST OF ATTACHMFNrrS 32. I hereby certify thai the [oregoing is true and correct to the best o[ my knowledge Signed J-~( TitleDr, iJ, nclEnc~,neerSuoerWsor D at e ~ '~'~-'~ ('~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24 · If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ANNULAR INJECTION DATA ENTRY SCREEN Asset ~GJ. ............................................ Legal Desc.1.7,D.1;.ESL,..2~.1.;[:EF_L,..S.ec..~6~.T..12_N,...B.1..4.E ....................... Research Ri g Name ..................................................... · ....................................................................................................................... C~rxec~ed..~ep~/..~s~..Le..~OG.C.C;..;~:.~.Z.=9;Z. ............... Inj Well Name ~,G.I,=2, ...................................... Permit Start ....... 1./..;I..~.~q.;~ ...... Permit End .....1.2~.3.,1,~..9.~... Sur Csg Dep ........................... ......1.2./..;I../.92_ ........ .l.2~.3..1.J..9.2... Cumulative Data Daily Data 5,947 60 6,007 ... _.O,O~n 1992 Year End Summary AGI-1 178 1 78 1993 SUMMARY .~..G...!.....:.2. ......................................................................................................................................................................................................... !...0....0. ............................................................ !..0...,0_ ............................................................. AGI #3 100 160 260 AGI #3 691 691 AGI #3 784 784 AGI #3 1,198 1,.!98 ~.~.~.....~ .......................................................... ~..:...o..~.~ .................... .~.~.~ .................................... ; ...................................................................................................................... ~.,.~.~..~ ........... ... 125~7~. ............... .-..5 ............................................................................................................................................................................................... i_._.....--5_....~......-~.~ ..................................... -~ ................................... i .................................................................................................................................................................... , I I !. I BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: AGI #2 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50-029-22311 PERMIT: APPROVAL: ACCEPT: 11/29/92 06:30 SPUD: 11/30/92 04:30 RELEASE: OPERATION: DRLG RIG: AUDI 2 WO/C RIG: AUDI 2 11/30/92 ( 1) TD: 200'( 0) 12/01/92 ( 2) TD: 2053' (1853) DRLG. MW: 8.5 VIS: 0 RIG ACCEPTED @ 18:30 HRS, 11/29/92. R/U DIVERTER. MIX SPUD MUD. P/U BHA. SPUD WELL @ 04:30 HRS, 11/30/92. DRLG F/ 100'-200'. DRLG. MW: 9.2 VIS:148 DRLG TO 2053' CIRC. SHORT TRIP TO 218' 12/02/92 (3) TD: 3760'(1707) 12/03/92 (4) TD: 3760' ( 0) 12/04/92 (5) TD: 6111' (2351) 12/05/92 (6) TD: 6837' ( 726) 12/06/92 (7) TD: 7952' (1115) 12/07/92 (8) TD: 8674' ( 722) RUNNING 13-3/8 CASING MW: 9.4 VIS:il0 DRILLING TO 3300' SERVICE RIG. DRILL TO 3760' CBU. SHORT TRIP. CBU. RUN 13-3/8 CASING. DRILLING CEMENT MW: 9.0 VIS: 35 RAN 13-3/8 CASING. CIRC. RECIPROCATED CASING. TEST LINES. PUMPED WATER & CEMENT. PERFORMED TOP JOB. TESTED BOPE. RIH. TESTED CASING. DRILLING CEMENT & FLOAT EQUIPMENT. DRILLING AT 6111' MW: 9.2 VIS: 40 DRILLED CEMENT TO 3760'. CBU FOR LOT. RAN LOT. DRILL TO 4393' PACKED OFF WITH CLAY. DRILL TO 4675'. CBU. SHORT TRIP. RIG SERVICE. DRILL TO 4527'_ PACKED OFF. DRILLED TO 5466'. PACKED OFF. DRILL TO 5990' CBU. DRILLED TO 6111' DRILLING @ 6837' MW: 9.2 VIS: 45 DRLD F/6111'-6629', TOP DRIVE FAILED, CBU, POH, L/D DP,RIG SERVICE, POH, L/D DP, L/D PIPE HANDLER F/TOP DRIVE, P/U KELLY, M/U HOSES & KELLY, M/U BIT # 3 & TIH TO 6547', WASH F/6547'-6629', DRLD F/6629'-6837' W/KELLY DRILLING @ 7952' MW: 9.5 VIS: 40 DRLD F/6337'-7711', RIG SERVICE, DRLD F/7711'-7689', REPAIR MUD PUMP #1, REPLACED LINER & WEAR PLATE (WASHED OUT), DRLD F/7869'-6627' DRILLING @ 8674' MW: 9.7 VIS: 43 CIRC FOR SHORT TRIP F/7954'-6454', NO FILL, DRLD F/7954'-8060', REPAIR SWAB & LINER IN PUMP #1, DRLD F/8060'-8401', RIG SERVICE, DRLD F/8401'-8530', REPAIR SWAB & LINER IN PUMP ~2, DRLD F/8530'-8674 WELL : AGI #2 OPERATION: RIG : AUDI 2 PAGE: 2 12/08/92 (9) TD: 8884' ( 210) 12/09/92 (10) TD: 9585' ( 701) 12/10/92 (11) TD: 9670' ( 85) 12/11/92 (12) TD: 9670' ( 0) 12/12/92 (13) TD: 9680' ( 10) 12/13/92 (14) TD: 9883' ( 203) 12/14/92 (15) TD:10181' ( 298) REPAIRING MUD PUMP #2 MW: 9.9 VIS: 50 DRLD F/8674'-8744', CIRC & DROP SS, TRIP F/BIT, SERVICE RIG, RETRIEVED SS, CHG BHA, P/U MWD, RIH TO 8677', WASH F/8677'-8744', DRLD F/8744'-8765', CIRC OUT TRIP GAS, DRLD F/8765'-8842', REPLACED WAB & LINER IN PUMP #2, DRLD F/8842'-8874F', POH 5 STDS, REPLACED KELLY HOSE, RIH 5 STDS, DRLD F/8874'-8884', REPAIR PUMP #2, REPLACED SWAB & LINER DRILLING MW:10.0 VIS: 47 REPAIR CTR POT ON PUMP #2, POH & L/D 15 JTS HWDP, CHG JETS INB BIT & RIH, SLIP & CUT DRLG LINE, SERVICE RIG, RIH TO BTM, DRLG AHEAD RUN CSG. MW:10.0 VIS: 50 DRLG TO 9670' CBU. 20 STDS SHORT TRIP. CIRC. POOH. R/U WOTCO. RIH W/ 9-5/8" CSG. L/D TOP DRIVE. MW:10.1 VIS: 60 RIH W/ 9-5/8" CSG. WASH CSG TO BTM. CIRC. R/U HOWCO. PUMP 20 BBLS PREFLUSH, 50 BBLS SPACER, 500 SX PREM CMT @ 15.8 PPG. DISP W/ MUD. L/D CSG TOOLS. INSTALL PACKOFF. TEST BOPE. OK. L/D BHA. P/U BHA. RIH TO FC. CBU. L/D TOP DRIVE. DRLG. MW: 9.1 VIS: 61 L/D TOP DRIVE. TEST CSG. OK. DRLG FC, FS, 10' NEW HOLE. CBU. FIT (12.5 PPG EMW). CLEAN PITS. DISP WELL W/ KCL MUD. DRLG TO 9680' DRLG. MW: 9.2 VIS: 62 DRLG F/ 9680'-9834' CBU. POOH. CHANGE BIT. RIH. REAM F/ 9735'-9834' DRLG F/ 9834'-9883' DRLG. MW: 9.2 VIS: 43 POOH. CHANGE BIT. RIH. REAM 45' TO BTM. DRLG TO 10181' 12/15/92 (16) TD:10215'( 34) 12/16/92 (17) TD:10215 PB: 0 REV CIRC CMT. MW: 9.2 VIS: 55 DRLG TO 10215'. TD WELL @ 08:30 HRS, 12/15/92. CBU. SHORET TRIP TO SHOE. CIRC. POOH. RIH W/ 7" LNR ON DP. TAG BTM. CIRC. R/U HOWCO. PUMP 20 BBLS PREFLUSH, 40 BBLS SPACER, 135 SX CMT. BUMP PLUG. SET HGR, PKR. R/U TO REV OUT CMT. RIH. MW: 9.2 KC1 REV CIRC. CIRC. POOH. L/D RUNNING TOOL. RIH W/ BHA, CSG SCRAPER. TAG CMT @ 10098' BIT PLUGGED. POOH. L/D BHA PLUGGED W/ CMT. RIH W/ MILL, BHA. WELL : AGI #2 OPERATION: RIG : AUDI 2 PAGE: 3 12/17/92 (18) TD:10215 PB:10171 RIG RELEASED. MW: 9.3 NaC1 CIRC @ TOL (9520'). RIH. TAG CMT. DRLG CMT F/ 10064'-10161'. CIRC. TEST CSG. DRLG LC, CMT TO FC @ 10171' CIRC. DISP W/ BRINE. POOH. PUMP 50 BBLS DIESEL IN ANNULUS, DISP TO 600' W/ DIESEL. POOH. N/D BOPE. N/U DRY HOLE TREE. TEST TREE. RIG RELEASED @ 06:00 HRS, 12/17/92. SIGNATURE: (drilling superintendent) DATE: 6324/6116 Nielson Way · Anchorage, AK 99518 Phone: (907) 563-3269/Fax: (907) 563-5865 Phone: (907) 562-2646 / Fax: (907) 561-1358 q'x- EASTMAN TELECO MWD SURVEY WELL AGI-#2 APEX GAS INJECTION PAD EASTMAN TELECO JOB # 1156 Eastman Teleco 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 MEASURED DEPTH NO INTERPOLATION Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : AGI #2 Location : Apex Gas Injection Pad : : No Interpolation Date DEC 15, 1992 Filename : 1156 Plane of Vertical Section : 92.3° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.18°WELLSITE North Grid convergence : +0.0000° +0° 0' 0'' (T) Eastman Teleco Client : Prudhoe Well Name : AGI #2 Location : Apex Gas : : No Interpolation Bay Drilling Group Injection Pad Page 1 of 2 Date DEC 15, 1992 Filename : 1156 MD CkL INC ft ft deg 0 0 0.0 421 421 0.1 872 451 0.7 1146 274 0.5 1240 94 1.8 DIR TVD VS LAT deg ft ft ft 0.0 0 0 0 203.1 421 -0 -0 172.9 872 0 .-3 155.7 1146 1 -6 117.4 1240 3 -7 DEP D'LEG BUILD ft °/100 °/100 0 0.0 0.0 -0 0.0 0.0 0 0.1 0.1 1 0.1 -0.1 2 1.5 1.4 TURN °/loo 0.0 -37,3 -6.7 -6.3 -40.7 1334 94 3.0 1427 93 3.8 1519 92 4.5 1613 94 5.7 1801 188 8.1 108.2 1334 103.0 1427 100.5 1518 95.2 1612 84.7 1799 6 -9 6 1.3 1.3 12 -10 11 0.9 0.9 18 -11 18 0.8 0.8 26 -13 26 1.4 1.3 49 -12 48 1.4 1.3 -9.8 -5.6 -2.7 -5.6 -5.6 1988 187 16.6 2176 188 17.2 2363 187 19.8 2549 186 23.5 2737 188 29.5 2925 188 34.4 3111 186 37.6 3299 188 40.6 3487 188 39.4 3695 208 38.4 90.3 1981 89 -11 88 4.6 4.5 93.1 2161 143 -13 143 0.5 0.3 88.5 2338 203 -13 202 1.6 1.4 92.4 2511 271 -14 271 2.1 2.0 90.3 2679 355 -16 355 3.2 3.2 92.1 2839 95.6 2989 90.6' 3135 88.2 3279 89.2 3441 454 564 682 8O3 933 3.0 1.5 -2.5 2.1 -1.1 -18 454 2 · 7 2 . 6 1.0 -26 563 2 · 0 1.7 1.9 -32 681 2 · 3 1.6 -2 · 7 -31 802 1.0 -0.6 -1.3 -28 933 0.6 -0.5 0.5 3954 259 38.7 4234 280 37.9 4514 280 39.3 4798 284 40.6 5080 282 40.5 90.3 3644 1094 -27 90.6 3864 1268 -28 90.3 4082 1442 -30 91.7 4300 1625 -33 93.1 4514 1808 -41 1094 0.3 0.1 0.4 1268 0.3 -0.3 0.1 1442 0.5 0.5 -0.1 1625 0.6 0.5 0.5 1808 0.3 -0.0 0.5 5362 282 40.0 5642 280 42.5 5925 283 42.5 6206 281 42.5 6488 282 43.1 94.2 4730 1990 -52 88.9 4940 2175 -57 88.2 5149 2365 -52 88.5 5356 2555 -47 89.1 5563 2746 -43 1990 0.3 -0.2 0.4 2174 1.5 0.9 -1.9 2365 0.2 0.0 -0.2 2555 0.1 0.0 0.1 2747 0.3 0.2 0.2 6772 284 43.5 7085 313 42.9 7396 311 42.5 7709 313 41.7 8056 347 39.6 90.3 5770 2941 -42 91.7 5998 3155 -45 92.4 6226 3366 -53 92.8 6459 3576 -62 93~5 6722 3802 -75 2941 0.3 0.1 0.4 3156 0.4 -0.2 0.4 3366 0.2 -0.1 0.2 3576 0.3 -0.3 0.1 3802 0.6 -0.6 0.2 8368 312 37.4 8679 311 34.3 8984 305 32.8 9296 312 31.7 9605 309 28.8 94.5 6966 3996 -88 95.9 7218 4178 -105 97.0 7472 4346 -124 95.6 7736 4512 -142 94.9 8003 4667 -156 3995 0.7 -0.7 0.3 4177 1 . 0 -1.0 0.5 4344 0.5 -0.5 0.4 4510 0.4 -0.4 -0.4 4665 0.9 -0.9 -0.2 Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : AGI #2 Location : Apex Gas Injection Pad : : No Interpolation MD CkL INC DIR TVD VS ft ft deg deg ft ft 9762 157 27.8 95.2 8141 4742 9827 65 27.1 95.2 8199 4771 9862 35 26.7 96.6 8230 4787 9959 97 25.8 96.3 8317 4830 10082 123 24.3 96.6 8429 4882 10154 72 23.3 96.3 8494 4911 LAT ft -163 -165 -167 -172 -178 Page 2 of 2 Date DEC 15, 1992 Filename · 1156 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 4739 0.6 -0.6 0.2 4769 1.1 -1.1 0.0 4784 2.1 -1.1 4.0 4827 0.9 -0.9 -0.3 4879 1.2 -1.2 0.2 -181 4908 1.4 -1.4 -0.4 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 4911 ft 92.1° MEASURED DEPTH 100' INTERPOLATED Client Well Name Location Eastman Teleco Prudhoe Bay Drilling Group AGI # 2 Apex Gas Injection Pad Page 1 of 3 Date DEC 15, 1992 Filename : 1156 Interpolated 100 ft of MD MD ft 0 100 200 3OO 400 5OO 6OO 700 8OO 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 35OO 3600 3700 3800 3900 CkL INC DIR TVD ft deg deg ft 0 0.0 0.0 0 100 0.0 48.2 100 100 0.0 96.5 200 100 0.1 144.7 300 100 0.1 193.0 400 100 0.2 197.8 500 100 0.3 191.1 600 100 0.5 184.4 700 100 0.6 177.7 800 100 0.7 171.1 900 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 0.6 164.9 1000 0.5 158.6 1100 1.2 133.7 1200 2.6 111.5 1300 3.6 104.5 1400 4.4 101.0 1500 5.5 95.9 1599 6.8 90.~ 1698 8.1 84.8 1798 12.6 87.7 1895 16.6 90.5 1993 17.0 92.0 2088 17.5 92.5 2184 18.9 90.0 2279 20.5 89.3 2373 22.5 91.4 2466 25.1 91.8 2557 28.3 90.7 2646 31.1 90.9 2733 33.7 91.9 2818 35.7 93.5 2900 37.4 95.4 2981 39.0 93.2 3059 40.6 90.6 3136 40.0 89.3 3213 39.3 88.3 3289 38.9 88.7 3367 38.4 89.2 3445 38.5 89.6 3523 38.6 90.1 3602 VS ft 0 0 0 0 -0 1 1 2 5 10 17 25 37 49 70 92 121 151 183 216 253 294 339 388 441 498 557 620 683 747 811 874 936 999 1061 LAT ft 0 -0 -0 -0 .--0 -1 -2 -2 -3 -4 -5 -6 -7 -8 -10 -11 -12 -12 -12 -12 -11 -12 -13 -13 -14 -14 -15 -16 -17 -18 -21 -25 -29 -32 -31 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 0 0.0 0.0 0.0 -0 0.0 0.0 48.2 -0 0.0 0.0 48.2 -0 0.1 0.0 48.2 -0 0.1 0.0 48.2 -0 0.1 0.1 4.8 -0 0.1 0 . 1 -6 . 7 -0 0.1 0.1 -6.7 0 0.1 0.1 -6.7 0 0.1 0.1 -6.6 0 0. 1 -0.1 -6.3 1 0. 1 -0.1 -6.3 2 0.8 0.7 -24.9 5 1.5 1.3 -22.2 10 1.1 1.0 -7.0 16 0.8 0.8 -3.5 25 1.3 1.2 -5.1 36 1.4 1.3 -5.6 48 1.5 1.3 -5.6 70 4.5 4.5 2.9 92 4.1 4.0 2.8 121 0.5 0.3 1.5 151 0.6 0.6 0.5 182 1.6 1.4 -2.5 216 1.6 1.6 -0.8 253 2.1 2.0 2.1 294 2.6 2.6 0.5 338 3.2 3.2 -1.1 388 2.8 2.8 0.2 441 2.7 2.6 1.0 498 2.2 1.9 1.7 557 2. 1 1.7 1.9 619 2. 1 1.6 -2.2 682 2 . 3 1. 6 -2.6 746 1.0 -0. 6 -1.3 -30 810 0.9 -0.6 -1.0 -29 873 0.6 -0.5 0.5 -28 936 0.5 -0.5 0.5 -27 998 0.3 0.1 0.4 -27 1061 0.3 0.1 0.4 Client Well Name Location Eastman Teleco Prudhoe Bay Drilling Group AGI #2 Apex Gas Injection Pad Page 2 of 3 Date DEC 15, 1992 Filename : 1156 Interpolated 100 ft of MD MD CkL INC DIR TVD VS ft ft deg deg ft ft 4000 100 38.6 90.3 3680 1123 4100 100 38.3 90.5 3758 1185 4200 100 38.0 90.6 3837 1247 4300 100 38.2 90.5 3915 1309 4400 100 38.7 90.4 3993 1371 4500 100 39.2 90.3 4071 1434 4600 100 39.7 90.7 4148 1498 4700 100 40.2 91.2 4225 1562 4800 100 40.6 91.7 4302 1626 4900 100 40.6 92.2 4378 1691 5OOO 5100 5200 5300 5400 55OO 5600 5700 5800 5900 6000 6100 6200 6300 6400 65O0 6600 6700 6800 6900 7000 7100 7200 7300 7400 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 40.5 92.7 4454 40.5 93.2 4530 40.3 93.6 4606 40.1 94.0 4682 40.3 93.5 4758 41.2 91.6 4833 42.1 89.7 4909 42.5 88.8' 4983 42.5 88.5 5057 42.5 88.3 5130 42.5 88.3 5204 42.5 88.4 5278 42.5 88.5 5352 42.7 88.7 5425 42.9 88.9 5498 43.1 89.2 5572 43.3 89. 6 5644 43.4 90. 0 5717 43.4 90.4 5790 43.3 90.9 5863 43.1 91.3 5936 42.9 91.7 6009 42.8 92.0 6082 42.6 92.2 6156 42.5 92.4 6229 1756 1821 1886 1950 2015 2081 2147 2214 2281 2349 2416 2483 2551 2619 2686 2754 2823 2891 2960 3028 3097 3165 3233 3301 3368 7500 100 42.2 92.5 6303 3435 7600 100 42.0 92.7 6378 3502 7700 100 41.7 92.8 6452 3569 7800 100 41.1 93.0 6528 3635 7900 100 40.5 93.2 6603 3700 LAT ft -27 -28 -28 -29 -29 -3O -31 -32 -33 -36 -38 -41 -46 -50 -53 -.55 -56 -56 -54 -53 -51 -49 -47 -45 -44 -43 -42 -42 -42 -43 -44 -46 -48 -51 -53 -56 -59 -62 -66 -69 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 1123 0.2 -0.1 0.3 1185 0.3 -0.3 0.1 1247 0.3 -0.3 0.1 1309 0.2 0.2 -0.0 1371 0.5 0.5 -0.1 1434 0.5 0.5 -0.1 1498 0.5 0.5 0.4 1562 0.6 0.5 0.5 1626 0.6 0.4 0.5 1691 0.3 -0.0 0.5 1756 0.3 -0.0 0.5 1821 0.3 -0.1 0.5 1885 0.3 -0.2 0.4 1950 0.3 -0.2 0.4 2015 0.4 0.2 -0.5 2081 1.5 0.9 -1.9 2146 1.5 0.9 -1.9 2213 0.7 0.4 -0.9 2281 0.2 0.0 -0.2 2348 0 . 2 0 . 0 -0 . 2 2416 0.0 0.0 0.0 2483 0.1 0.0 0.1 2551 0.1 0.0 0.1 2619 0.2 0.2 0.2 2687 0.3 0.2 0.2 2755 0.3 0.2 0.2 2823 0.3 0.1 0.4 2892 0.3 0.1 0.4 2960 0.3 0.0 0.4 3029 0.4 -0.2 0.4 3097 0.4 -0.2 0.4 3166 0.3 -0.2 0.4 3233 0.2 -0.1 0.2 3301 0.2 -0.1 0.2 3369 0.2 -0.1 0.2 3436 0.3 -0.3 0.1 3503 0.3 -0.3 0.1 3570 0.3 -0.3 0.1 3635 0.6 -0.6 0.2 3700 0.6 -0.6 0.2 Client : Prudhoe Well Name : AGI #2 Location : Apex Gas : : Eastman Teleco Bay Drilling Group Injection Pad Page 3 of 3 Date DEC 15, 1992 Filename : 1156 Interpolated 100 ft of MD MD CkL INC DIR TVD VS ft ft deg deg ft ft 8000 100 39.9 93.4 6679 3765 8100 100 39.3 93.6 6756 3829 8200 100 38.6 94.0 6834 3891 8300 100 37.9 94.3 6913 3953 8400 100 37.1 94.6 6992 4014 8500 100 36.1 95.1 7073 4073 8600 100 35.1 95.5 7154 4131 8700 100 34.2 96.0 7236 4189 8800 100 33.7 96.3 7319 4244 8900 100 33.2 96.7 7402 4299 9000 100 32.7 96.9 7486 4354 9100 100 32.4 96.5 7570 4407 9200 100 32.0 96.0 7655 4461 9300 100 31.7 95.6 7740 4514 9400 100 30.7 95.4 7826 4564 9500 100 29.8 95.1 7912 4614 9600 100 28.8 94.9 7999 4665 9700 100 28.2 95.1 8087 4712 9800 100 27.4 95.2 8175 4759 9900 100 26.3 96.5 8264 4804 10000 100 25.3 96.4 8354 4847 10100 100 24.0 96.5 8445 4889 10154 54 23.3 96.3 8494 4911 LAT ft -73 -77 -81 -85 -90 DEP D ' LEG BUILD TURN ft °/100 °/100 °/100 3765 0.6 -0.6 0.2 3829 0 . 7 -0.6 0.3 3891 0.7 -0.7 0.3 3953 0.7 -0.7 0.3 4014 0.8 -0.8 0.4 -95 4072 1.0 -1.0 0.5 -101 4131 1.0 -1.0 0.5 -106 4188 0.9 -0.9 0.4 -112 4243 0.5 -0.5 0.4 -~18 4298 0.5 -0.5 0.4 -125 4353 0.5 -0.5 0.2 -130 4406 0.4 -0.4 -0.4 -136 4459 0.4 -0.4 -0.4 -142 4512 0.4 -0.4 -0.4 -147 4562 0.9 -0.9 -0.2 -151 4612 0.9 -0.9 -0.2 -156 4662 0.9 -0.9 -0.2 -160 4710 0.7 -0.7 0.2 -164 4756 0.8 -0.8 0.1 -169 4801 1.2 -1.0 1.3 -174 4844 1.0 -1.0 -0.1 -179 4886 1.3 -1.2 0.1 -181 4908 2.0 -2.0 -0.1 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 4911 ft 92.1° TRUE VERTICAL DEPTH 100' INTERPOLATED Client Well Name Location Eastman Teleco Prudhoe Bay Drilling Group AGI #2 Apex Gas Injection Pad Page 1 Date DEC Filename Interpolated of 3 15, 1992 : 1156 100 ft of TVD MD ft 0 100 200 30O 400 5OO 6O0 700 8OO 900 1000 1100 1200 1300 1400 CkL INC DIR TVD ft deg deg ft 0 0.0 0.0 0 100 0.0 48.2 100 100 0.0 96.5 200 100 0.1 144.7 300 100 0.1 193.0 400 100 100 100 100 100 100 100 100 100 100 0.2 197.8 500 0.3 191.1 600 0.5 184.4 700 0.6 177.7 800 0.7 171.1 900 0.6 164.9 1000 0.5 158.6 1100 1.2 133.7 1200 2.6 111.5 1300 3.6 104.5 1400 1500 100 4.4 101.0 1500 1601 100 5.5 95.9 1600 1702 101 6.8 90.5 1700 1802 101 8.2 84.7 1800 1905 102 12.8 87.8 1900 2008 2112 2217 2322 2429 103 105 105 105 107 108 111 113 118 121 124 129 130 130 128 2537 2648 2761 2879 3000 3125 3253 3383 3514 3642 16.7 90.6 2000 17.0 92.1 2100 17.8 92.1 2200 19.2 89.5 2300 21.1 89.9 2400 VS ft 0 0 0 0 -0 LAT ft 0 -0 -0 -0 -0 1 1 2 5 10 17 25 37 49 71 94 125 156 190 227 DEP D ' LEG BUILD TURN ft °/100 °/100 °/100 0 0.0 0.0 0.0 -0 0.0 0.0 48.2 -0 0.0 0.0 48.2 -0 0.1 0.0 48.2 -0 0.1 0.0 48.2 0 -1 -0 0.1 0 -2 -0 0.1 0 -2 -0 0.1 0 -3 0 0.1 0 -4 0 0.1 -5 -6 -7 -8 -10 -11 -12 -12 -12 -12 0 0.1 1 0.1 2 0.8 5 1.5 10 1.1 16 0.8 25 1.3 37 1.4 49 1.5 71 4.6 0.1 4.8 0.1 -6.7 0.1 -6.7 0.1 -6.7 0.1 -6.6 -0. 1 -6.3 -0.1 -6.3 0.7 -24.9 1.3 -22.2 1.0 -7.0 0.8 -3.5 1.2 -5.1 1.3 -5.6 1.3 -5.5 4.5 3.0 -11 94 3.8 3.7 2.7 -12 124 0.5 0.3 1.5 -13 156 0.7 0.7 -0.1 -13 189 1.6 1.4 -2.5 -14 227 1.8 1.8 0.4 23.3 92.1 2500 267 -14 266 2.1 2.0 2.1 26.7 91.3 2600 315 -15 315 3.1 3.1 -0.8 30.1 90.5 2700 368 -16 367 3.1 3.1 -0.7 33.2 91.7 2800 430 -18 430 2.7 2.6 1.0 35.7 93.5 2900 499 -21 498 2.2 2.1 1.5 37.8 95.2 3000 572 -26 572 1.9 39.9 91.8 3100 653 -30 653 2.3 40.1 89.5 3200 736 -31 736 1.1 39.3 88.3 3300 819 -30 819 0.8 38.7 88.9 3400 900 -28 900 0.6 3770 128 38.5 89.5 3500 980 3898 128 38.6 90.1 3600 1060 4026 128 38.5 90.4 3700 1139 4153 127 38.1 90.5 3800 1218 4281 128 38.1 90.5 3900 1297 1.7 1.4 1.6 -2.7 0.1 -1.8 -0.6 -0.9 -0.5 0.5 -27 980 0.3 -0.1 0.4 -27 1059 0.3 0.1 0.4 -27 1139 0.2 -0.1 0.2 -28 1218 0.3 -0.3 0.1 -29 1297 0.0 0.0 0.0 Client Well Name Location Eastman Teleco Prudhoe Bay Drilling Group AGI #2 Apex Gas Injection Pad Page 2 of 3 Date DEC 15, 1992 Filename : 1156 Interpolated 100 ft of TVD MD ft 4409 4537 4667 4798 4930 5061 5192 5323 5456 5589 5723 5859 5994 6130 6266 6402 6539 6676 6814 6951 7088 7224 7360 7495 7630 7764 7895 8027 8156 8284 8410 8533 8657 8777 8897 9017 9135 9253 9370 9486 CkL ft 128 128 130 130 132 132 131 131 132 133 135 136 136 136 136 136 137 137 137 137 137 136 136 135 135 134 132 132 129 128 126 123 123 121 120 120 118 118 117 116 INC DIR TVD deg deg ft 38.8 90.4 4000 39.4 90.4 4100 40.0 91.1 4200 40.6 91.7 4300 40.6 92.4 4400 40.5 93.0 4500 40.3 93.5 4600 40.1 94.0 4700 40.8 92.4 4800 42.0 89.9 4900 42.5 88.7 5000 42.5 88.4 5100 42.5 88.3 5200 42.5 88.4 5300 42.6 88.6 5400 42.9 88.9 5500 43.2 89.3 5600 43.4 89.~ 5700 43.4 90.5 5800 43.2 91.1 5900 42.9 91.7 6000 42.7 92.0 6100 42.5 92.3 6200 42.2 92.5 6300 41.9 92.7 6400 41.4 92.9 6500 40.6 93.2 6600 39.8 93.4 6700 38.9 93.8 6800 38.0 94.2 6900 37.0 94.7 7000 35.8 95.2 7100 34.5 95.8 7200 33.8 96.3 7300 33.2 96.7 7400 32.7 96.9 7500 32.3 96.3 7600 31.9 95.8 7700 31.0 95.4 7800 29.9 95.2 7900 VS ft 1377 1457 1541 1625 1710 1796 1881 1965 2052 2139 2229 2321 2412 2504 2595 2688 2781 2875 2969 3063 3157 3249 3341 3432 3523 3611 3697 3783 3864 3943 4020 4092 4165 4232 4298 4363 4426 4489 4549 4607 LAT ft -29 -30 -31 -33 -36 -40 -45 -51 -54 -56 -56 -53 -51 -48 -46 -44 -42 -.42 -42 -44 -45 -49 -52 -56 -60 -64 -69 -74 -79 -85 -91 -97 -104 -111 -118 -126 -1~32 -139 -145 -151 DEP D ' LEG BUILD TURN ft °/100 °/100 °/100 1377 0.5 0.5 -0.1 1457 0.5 0.5 0.0 1541 0.6 0.5 0.5 1625 0.6 0.5 0.5 1710 0.3 -0.0 0.5 1796 0.3 -0 . 0 0 . 5 1880 0 . 3 -0 . 2 0 . 4 1965 0.3 -0.2 0.4 2051 1.0 0.6 -1.2 2139 1.5 0.9 -1.9 2229 0.7 0.4 -0.9 2321 0.2 0.0 -0.2 2412 0.0 0.0 -0.1 2504 0.1 0.0 0.1 2596 0.1 0.1 0.2 2688 0.3 0.2 0.2 2782 0.3 0.2 0.3 2876 0.3 0.1 0.4 2970 0.3 0.0 0.4 3064 0.4 -0.2 0.4 3158 0.4 -0.2 0.4 3250 0.2 -0.1 0.2 3342 0.2 -0.1 0.2 3433 0.2 -0.2 0.2 3523 0.3 -0.3 0.1 3611 0.4 -0.4 0.2 3697 0.6 -0.6 0.2 3783 0.6 -0.6 0.2 3864 0.7 -0.7 0.3 3943 0.7 -0.7 0.3 4020 0.8 -0.8 0.4 4092 1.0 -1.0 0.5 4164 1.0 -1.0 0.5 4231 0.6 -0.6 0.4 4297 0.5 -0.5 0.4 4362 0.5 -0.5 0.1 4424 0.4 -0.4 -0.4 4487 0.4 -0.4 -0.4 4547 0.7 -0.7 -0.3 4605 0.9 -0.9 -0.2 Client Well Name Location Eastman Teleco Prudhoe Bay Drilling Group AGI #2 Apex Gas Injection Pad Page 3 of 3 Date DEC 15, 1992 Filename : 1156 Interpolated 100 ft of TVD MD CkL INC DIR TVD ft ft deg deg ft 9602 116 28.8 94.9 8000 9715 114 28.1 95.1 8100 9828 113 27.1 95.3 8200 9940 112 26.0 96.4 8300 10051 111 24.7 96.5 8400 10154 103 23.3 96.3 8494 VS ft 4665 4719 4772 4822 4869 LAT ft -156 -161 -166 -171 -176 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 4663 0.9 -0.9 -0.2 4717 0.7 -0.6 0.2 4769 0.9 -0.9 0.1 4819 1.1 -1.0 1.0 4866 1.2 -1.2 0.1 4911 -181 4908 2.4 -2.4 -0.1 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 4911 ft 92.1° 6324/6116 Nielson Way · Anchorage, AK 99518 Phone: (907) 56&3269/Fax: (907) 563-5865 Phone: (907) 562-2646 / Fax: (907) 561-1358 EASTMAN TELECO MWD SURVEY WELL AGI-#2 APEX GAS INJECTION PAD EASTMAN TELECO JOB # 1156 Eastman Teleco 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 RECEIVED FEB 0'1 1993 Alaska 0il & Gas Cons. Commission. Anchorage Oate~ Eastman Teleco Anchorage, Alaska Prudhoe Bay Drilling Group Well Name Location Date Surveyed Survey Performed By : AGI #2 : Apex Gas Injection Pad : DEC 15, 1992 : : SCOTT BURKHARDT This survey is correct to the best of my knowledge and is supported by actual field data. . .~.~...~... COMPANY REPRESENTATIVE MEASURED DEPTH NO INTERPOLATION Eastman Teleco Client · Prudhoe Bay Drilling Group Well Name : AGI #2 Location : Apex Gas Injection Pad : : No Interpolation Page 1 Date DEC Filename of 2 15, 1992 : 1156 MD CkL INC DIR TVD ft ft deg deg ft 0 0 0.0 0.0 0 421 421 0.1 203.1 421 872 451 0.7 172.9 872 1146 274 0.5 155.7 1146 1240 94 1.8 117.4 1240 VS ft 0 -0 0 1 3 LAT ft 0 -0 -6 -7 DEP D ' LEG ft °/100 0 0.0 -0 0.0 0 0.1 1 0.1 2 1.5 BUILD °/100 0.0 0.0 0.1 -0.1 1.4 TURN °/lOO 0.0 -37.3 -6.7 -6.3 -40.7 1334 94 3.0 108.2 1334 1427 93 3.8 103.0 1427 1519 92 4.5 100.5 1518 1613 94 5.7 95.2 1612 1801 188 8.1 84.7 1799 6 -9 6 1.3 1.3 12 -10 11 0 . 9 0 . 9 18 -11 18 0.8 0.8 26 -13 26 1.4 1.3 49 -12 48 1.4 1.3 -9.8 -5.6 -2.7 -5.6 -5.6 1988 187 16.6 90.3 1981 2176 188 17.2 93.1 2161 2363 187 19.8 88.5 2338 2549 186 23.5 92.4 2511 2737 188 29.5 90.3 2679 2925 188 34.4 92.1 2839 3111 186 37.6 95.6 2989 3299 188 40.6 90.6 3135 3487 188 39.4 88.2 3279 3695 208 38.4 89.2 3441 89 -11 88 4. 6 4 143 -13 143 0.5 0 203 -13 202 1. 6 1 271 -14 271 2. 1 2 355 -16 355 3.2 3 454 564 682 803 933 .5 .3 .4 .0 .2 3.0 1.5 -2.5 2.1 -1.1 -18 454 2.7 2.6 1.0 -26 563 2 . 0 1.7 1.9 -32 681 2.3 1.6 -2.7 -31 802 1.0 -0.6 -1.3 -28 933 0.6 -0.5 0.5 3954 259 38.7 90.3 3644 4234 280 37.9 90.6 3864 4514 280 39.3 90.3 4082 4798 284 40.6 91.7 4300 5080 282 40.5 93.1 4514 1094 -27 1094 0.3 1268 -28 1268 0.3 1442 -30 1442 0.5 1625 -33 1625 0.6 1808 -41 1808 0.3 0 -0 0 0 -0 .1 .3 .5 .5 .0 0.4 0.1 -0.1 0.5 0.5 5362 282 40.0 94.2 4730 5642 280 42.5 88.9 4940 5925 283 42.5 88.2 5149 6206 281 42.5 88.5 5356 6488 282 43.1 89.1 5563 1990 -52 1990 0.3 -0 2175 -57 2174 1.5 0 2365 -52 2365 0.2 0 2555 -47 2555 0.1 0 2746 -43 2747 0.3 0 .2 .9 .0 .0 .2 0.4 -1.9 -0.2 0.1 0.2 6772 284 43.5 90.3 5770 7085 313 42.9 91.7 5998 7396 311 42.5 92.4 6226 7709 313 41.7 92.8 6459 8056 347 39.6 93.5 6722 2941 3155 3366 3576 3802 -42 -45 -53 -62 -75 2941 0.3 0 3156 0.4 -0 3366 0.2 -0 3576 0.3 -0 3802 0.6 -0 .1 .2 .1 .3 .6 0.4 0.4 0.2 0.1 0.2 8368 312 37.4 94.5 6966 8679 311 34.3 95.9 7218 8984 305 32.8 97.0 7472 9296 312 31.7 95.6 7736 9605 309 28.8 94.9 8003 3996 4178 4346 4512 4667 -88 -105 -124 -142 -156 3995 0.7 -0.7 0.3 4177 1.0 -1.0 0.5 4344 0.5 -0.5 0.4 4510 0.4 -0.4 -0.4 4665 0.9 -0.9 -0.2 MEASURED DEPTH 100" INTERPOLATED Client Well Name Location Eastman Teleco Prudhoe Bay Drilling Group AGI # 2 Apex Gas Injection Pad Page 2 of 3 Date DEC 15, 1992 Filename : 1156 Interpolated 100 ft of MD MD CkL INC DIR TVD VS ft ft deg deg ft ft 4000 100 38.6 90.3 3680 1123 4100 100 38.3 90.5 3758 1185 4200 100 38.0 90.6 3837 1247 4300 100 38.2 90.5 3915 1309 4400 100 38.7 90.4 3993 1371 4500 100 39.2 90.3 4071 1434 4600 100 39.7 90.7 4148 1498 4700 100 40.2 91.2 4225 1562 4800 100 40.6 91.7 4302 1626 4900 100 40.6 92.2 4378 1691 5000 100 40.5 92.7 4454 1756 5100 100 40.5 93.2 4530 1821 5200 100 40.3 93.6 4606 1886 5300 100 40.1 94.0 4682 1950 5400 100 40.3 93.5 4758 2015 5500 100 41.2 91.6 4833 2081 5600 100 42.1 89.7 4909 2147 5700 100 42.5 88.8 4983 2214 5800 100 42.5 88.5 5057 2281 5900 100 42.5 88.3 5130 2349 6000 100 42.5 88.3 5204 2416 6100 100 42.5 88.4 5278 2483 6200 100 42.5 88.5 5352 2551 6300 100 42.7 88.7 5425 2619 6400 100 42.9 88.9 5498 2686 6500 100 43.1 89.2 5572 2754 6600 100 43.3 89.6 5644 2823 6700 100 43.4 90.0 5717 2891 6800 100 43.4 90.4 5790 2960 6900 100 43.3 90.9 5863 3028 7000 100 43.1 91.3 5936 3097 7100 100 42.9 91.7 6009 3165 7200 100 42.8 92.0 6082 3233 7300 100 42.6 92.2 6156 3301 7400 100 42.5 92.4 6229 3368 LAT ft -27 -28 -28 -29 -29 -3O -31 -32 -33 -36 -38 -41 -46 -50 -53 -.55 -56 -56 -54 -53 -51 -49 -47 -45 -44 -43 -42 -42 -42 -43 -44 -46 -48 -51 -53 7500 100 42.2 92.5 6303 3435 -56 7600 100 42.0 92.7 6378 3502 -59 7700 100 41.7 92.8 6452 3569 -62 7800 100 41.1 93.0 6528 3635 -66 7900 100 40.5 93.2 6603 3700 -69 DEP D'LEG BUILD TUR~[ ft °/100 °/100 °/100 1123 0.2 -0.1 0.3 1185 0.3 -0.3 0.I 1247 0.3 -0.3 0.! 1309 0.2 0.2 -0.0 1371 0.5 0.5 -0.i 1434 0.5 0.5 -0.i 1498 0.5 0.5 0.4 1562 0.6 0.5 0.5 1626 0.6 0.4 0.5 1691 0.3 -0.0 0.5 1756 0.3 -0.0 0.5 1821 0.3 -0.1 0.5 1885 0.3 -0.2 0.4 1950 0.3 -0.2 0.4 2015 0.4 0.2 -0.5 2081 1.5 0.9 -1.9 2146 1.5 0.9 -1.9 2213 0.7 0.4 -0.9 2281 0.2 0.0 -0.2 2348 0.2 0.0 -0.2 2416 0.0 0.0 0.0 2483 0.1 0.0 0.I 2551 0.1 0.0 0.! 2619 0.2 0.2 0.2 2687 0.3 0.2 0.2 2755 0.3 0.2 0.2 2823 0.3 0.1 0.4 2892 0.3 0.1 0.4 2960 0.3 0.0 0.4 3029 0.4 -0.2 0.4 3097 0.4 -0.2 0.4 3166 0.3 -0.2 0.4 3233 0.2 -0.1 0.2 3301 0.2 -0.1 0.2 3369 0.2 -0.1 0.2 3436 0.3 -0.3 0.1 3503 0.3 -0.3 0.1 3570 0.3 -0.3 0.! 3635 0.6 -0.6 0.2 3700 0.6 -0.6 0.2 TRUE VERTICAL DEPTH 100' INTERPOLATED Client Well Name Location Prudhoe AGI #2 Apex Gas Eastman Teleco Bay Drilling Group Injection Pad Page 2 of 3 Date DEC 15, 1992 Filename : 1156 Interpolated 100 ft of TVD MD C~L INC DIR TVD VS LAT ft ft deg deg ft ft ft 4409 128 38.8 90.4 4000 1377 -29 4537 128 39.4 90.4 4100 1457 -30 4667 130 40.0 91.1 4200 1541 -31 4798 130 40.6 91.7 4300 1625 -33 4930 132 40.6 92.4 4400 1710 -36 5061 132 40.5 93.0 4500 1796 -40 5192 131 40.3 93.5 4600 1881 -45 5323 131 40.1 94.0 4700 1965 -51 5456 132 40.8 92.4 4800 2052 -54 5589 133 42.0 89.9 4900 2139 -56 5723 5859 5994 6130 6266 6402 6539 6676 6814 6951 7088 7224 7360 749'5 7630 7764 7895 8027 8156 8284 8410 8533 8657 8777 8897 9017 9135 9253 9370 9486 135 136 136 136 136 136 137 137 137 137 137 136 136 135 135 134 132 132 129 128 126 123 123 121 120 120 118 118 ,117 116 42.5 88.7 5000 2229 -56 42.5 88.4 5100 2321 -53 42.5 88.3 5200 2412 -51 42.5 88.4 5300 2504 -48 42.6 88.6 5400 2595 -46 42.9 88.9 5500 2688 -44 43.2 89.3 5600 2781 -42 43.4 89.9 5700 2875 -.42 43.4 90.5 5800 2969 -42 43.2 91.1 5900 3063 -44 42.9 42.7 42.5 42.2 41.9 41.4 40.6 39.8 38.9 38.0 37.0 35.8 34.5 33.8 33.2 32.7 32.3 31.9 31.0 29.9 91.7 6000 3157 -45 92.0 6100 3249 -49 92.3 6200 3341 -52 92.5 6300 3432 -56 92.7 6400 3523 -60 92.9 6500 3611 -64 93.2 6600 3697 -69 93.4 6700 3783 -74 93.8 6800 3864 -79 94.2 6900 3943 -85 94.7 7000 4020 -91 95.2 7100 4092 -97 95.8 7200 4165 -104 96.3 7300 4232 -111 96.7 7400 4298 -118 96.9 7500 4363 -126 96.3 7600 4426 -532 95.8 7700 4489 -139 95.4 7800 4549 -145 95.2 7900 4607 -151 DEP D ' LEG BUILD TURN ft °/100 °/100 °/100 1377 0.5 0.5 -0.1 1457 0.5 0.5 0.0 1541 0.6 0.5 0.5 1625 0.6 0.5 0.5 1710 0.3 -0.0 0.5 1796 0.3 -0.0 1880 0.3 -0.2 1965 0.3 -0.2 2051 1.0 0.6 2139 1.5 0.9 2229 0.7 0.4 2321 0.2 0.0 2412 0.0 0.0 2504 0.1 0.0 2596 0.1 0.1 0.5 0.4 0.4 -1.2 -1.9 -0.9 -0.2 -0.1 0.1 0.2 2688 0.3 0.2 0.2 2782 0.3 0.2 0.3 2876 0.3 0.1 0.4 2970 0.3 0.0 0.4 3064 0.4 -0.2 0.4 3158 0.4 -0.2 0.4 3250 0.2 -0.1 0.2 3342 0.2 -0.1 0.2 3433 0.2 -0.2 0.2 3523 0.3 -0.3 0.1 3611 0.4 -0.4 0.2 3697 0.6 -0.6 0.2 3783 0.6 -0.6 0.2 3864 0.7 -0.7 0.3 3943 0.7 -0.7 0.3 4020 0.8 -0.8 0.4 4092 1.0 -1.0 0.5 4164 1.0 -1.0 0.5 4231 0.6 -0.6 0.4 4297 0.5 -0.5 0.4 4362 0.5 -0.5 4424 0.4 -0.4 4487 0.4 -0.4 4547 0.7 -0.7 4605 0.9 -0.9 0.1 -0.4 -0.4 -0.3 -0.2 SUB - S URFA CE Oaten, DIRECTIONAL SURVEY ~] UIDANCE DONTINUOUS ~ OOL A U O 2 6 !99,! Aiaska Oil & Gas (]ohs. Anchorage Company Well Name Field/Location ARCO ALASKA, INC. . . AGI-2 (1701' FSL, 2411' FEL, SEC 36, T12N, R14E) PRUDHOE BAY? NORTH SLOPE, ALASKA Job Reference No. 93187 Logged By: SARBER Date 25-APR-93 Computed By: SINES · SCHLUMBERGER * GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. AGI - 2 PRUDHOE BaY NORTH SLOPE, ALASKA SURVEY DATE: APRIL-25-1993 ENGINEER: G. SARBER METHODS OF COMPUTATION TOOL LOCATION: MINIMUM CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 87 DEG 40 MIN EAST COMPUTATION DATE' 27-APR-93 PAGE I ARCO ALASKA INC. AGI - 2 PRUDHOE BaY NORTH SLOPE, ALASKA DATE Of SURVEY' APRIL-25-199 KELLY BUSHING ELEVATION' 49.00 FT ENGINEER' G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 O0 100 04 200 04 300 04 400 04 500 04 600 03 700 03 800 03 900 02 -49 O0 51 04 151 04 251 04 351 04 451 04 551 03 651 03 751 O3 851 02 0 0 N 0 0 E 0 11 S 80 14 W 0 15 S 55 21E 0 10 N 74 0 W 0 27 S 4 46 E 0 26 S 73 5 E 0 17 N 79 27 W 0 36 S 13 25 E 0 27 S 61 59 E 0 4O S 25 57 W 0 O0 -0 10 -0 14 0 O5 -0 16 0 31 0 80 0 51 1 21 1 39 0 O0 0 66 0 59 0 65 0 66 0 54 0 64 0 89 0 71 0 64 0 O0 N 0 07 N 0 26 S 0 15 S 0 61 S 1 lBS 1 19 S 1 94 S 2 58S 3 14 S 0 O0 E 0 09 W 0 15 W 0 04 E 0 18 W 0 26 E 0 75 E 0 43 E 1 11 E 1 26 E 000 N O O E Il N 54 19 W 30 S 30 53 W 15 S 16 34 E 64 S 16 35 W 21 S 12 35 E 4O S 32 18 E 99 S 12 23 E 81 S 23 15 E 38 S 21 54 E 1000 O0 1000 O1 1100 O0 1100 O1 1051 1200 O0 1200 O0 1151 1300 O0 1299 95 1250 1400 O0 1399 80 1350 1500 O0 1499 57 1450 1600 O0 1599.23 1550 1700 O0 1698.62 1649 1800 O0 1797.81 1748 1900 O0 1896.33 1847 951 O1 O1 O0 95 8O 57 23 62 81 0 41 0 32 1 4 2 36 3 34 4 12 5 17 6 54 7 56 33 12 21 S 19 49 E S 55 46 E S 59 38 E S 75 0 E S 79 18 E S 80 12 E S 85 54 E N 81 22 E N 84 26 E S 89 22 E 1 10 1 86 2 87 5 95 11 21 17 99 26 09 36 98 49 46 66 42 0 75 0 60 0 59 1 45 0 78 0 84 0 97 1 85 1 18 3 37 4 32 S 5 O1 S 5 63 S 6 81 S 7 95 S 9 13 S 10 24 S 9.46 S 7.69 S 7.29 S 0 93 E 1 65 E 2 65 E 5 67 E 10 89 E 17 63 E 25 7O E 36 62 E 49 19 E 66 18 E 4 42 S 12 9 E 5 6 8 13 19 27 37 49 66 28 S 18 16 E 22 S 25 10 E 87 S 39 47 E 48 S 53 53 E 86 S 62 37 E 66 S 68 16 E 83 S 75 31E 79 S 81 7 E 58 S 83 43 E 2000 O0 1992 85 1943 85 16 43 2100 2200 2300 2400 2500 2600 2700 2800 O0 2088 O0 2184 O0 2278 O0 2372 O0 2465 O0 2557 O0 2646 O0 2733 2900 O0 2817 54 2039 07 2135 78 2229 77 2323 87 2416 45 2508 57 2597 04 2684 23 2768 54 17 07 17 28 78 19 39 77 20 26 87 22 22 45 25 7 57 28 37 04 31 32 23 33 53 S 88 4O E S 87 9 E S 87 2 E N 88 14 E N 89 47 E S 87 45 E S 88 28 E S 89 14 E S 88 3 E S 87 31E 92 45 121 51 151 07 183 09 217 16 253 64 293 79 339 09 389 28 443 24 4 71 3 18 1 11 1 64 1 63 1 86 2 O7 2 80 3 10 2 91 7.76 S 8.78 S 121 10.42 S 150 10 51S 182 9 75 S 216 10 56 S 253 12 05 S 293 12 78 S 338 13 97 S 389 16 13 S 442 92 21E 25 E 121 77 E 151 82 E 183 94 E 217 42 E 253 54 E 293 85 E 339 03 E 389 95 E 443 92 54 S 85 11E 57 S 85 51E 13 S 86 3 E 12 S 86 43 E 16 S 87 26 E 64 S 87 37 E 79 S 87 39 E 09 S 87 50 E 28 S 87 57 E 24 S 87 55 E 3000 O0 2898 97 2849 97 36 27 3100 3200 33OO 3400 35OO 3600 3700 3800 O0 2978 O0 3O56 O0 3133 O0 32O9 O0 3286 O0 3364 O0 3443 O0 3521 3900 O0 3600 64 2929 86 3OO7 39 3084 67 3160 77 3237 61 3315 05 3394 89 3472 66 3551 64 37 48 86 39 30 39 4O 2O 67 4O 5 77 39 13 61 38 28 05 38 21 89 37 51 66 38 16 S 86 9 E S 83 37 E S 84 6 e S 89 37 E N 88 42 E N 88 59 E N 89 29 E N 89 51E S 89 20 E 1001 S 89 6 E 1063 500 81 561 17 623 29 687 62 752 17 815 74 878 41 940 37 85 43 2 66 2 35 2 17 2 45 2 48 2 O1 0 95 0 69 0 7O 0 64 19 15 S 500 45 E 500 81 S 87 49 E 24 31 35 34 33 32 32 32 33 62 S 560 84 S 622 58 S 686 54 S 751 28 S 815 42 S 877 05 S 939 29 S 1001 20 S 1062 63 E 561 51E 623 74 E 687 38 E 752 06 E 815 82 E 878 85 E 94O 37 E 1001 96 E 1063 17 S 87 29 E 33 S 87 4 E 66 S 87 2 E 18 S 87 22 E 74 S 87 40 E 42 S 87 53 E 40 S 88 3 E 89 S 88 9 E 48 S 88 13 E COMPUTATION DATE' 27-aPr-93 Page 2 ArCO ALASKA INC. agI - 2 PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY- APRIL-25-199 KELLY BUSHING ELEVATION' 49.00 FT ENGINEER' G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES h0RIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEg/IO0 FEET FEET FEET DEG 4000 O0 3678 75 3629.75 39 0 4100 4200 430O 4400 4500 4600 4700 4800 4900 O0 3756 O0 3835 O0 3913 O0 3991 O0 4068 O0 4146 O0 4223 O0 4300 O0 4376 68 3707.68 38 36 20 3786.20 37 54 99 3864.99 38 32 37 3942.37 39 33 64 4019.64 39 13 23 4097.23 38 59 90 4174.90 39 12 70 4251,70 40 34 59 4327.59 40 30 S 88 56 E 1125 89 S 88 42 E 1188 S 88 35 E 1250 S 89 14 E 1312 S 89 21E 1375 S 89 26 E 1438 S 89 37 E 1501 S 89 28 E 1564 S 88 23 E 1628 S 87 32 E 1693 53 45 O2 33 78 83 79 80 92 0 63 0 51 0 56 0 58 0 93 0 87 0 76 0 35 0 59 0 76 34 30 S 1125 42 E 1125 94 S 88 15 E 35 37 38 39 39 40 4O 41 44 63 S 1188 11S 1249 42 S 1311 18 S 1374 85 S 1438 39 S 1501 87 S 1564 99 S 1628 28 S 1693 06 E 1188 97 E 1250 54 E 1312 87 E 1375 35 E 1438 43 E 1501 42 E 1564 44 E 1628 52 E 1694 60 S 88 17 E 52 S 88 18 E 10 S 88 19 E 43 S 88 22 E 90 S 88 25 E 97 S 88 28 E 95 S 88 3O E 98 S 88 31E 10 S 88 30 E 5000 O0 4452.74 4403 74 40 14 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4528.98 4479 O0 4605.49 4556 O0 4682 18 4633 O0 4758 84 4709 O0 4834 O0 4785 O0 4907 68 4858 O0 4981 38 4932 O0 5055 15 5006 O0 5128 99 5079 98 40 21 49 39 56 18 39 52 84 40 15 O0 42 14 68 42 33 38 42 32 15 42 26 99 42 23 S 87 2 E 1758 74 S 86 57 E 1823 S 86 30 E 1887 S 86 14 E 1951 S 86 39 E 2016 N 89 7 E 2082 N 88 34 E 2149 N 88 24 E 2217 N 88 25 E 2284 N 88 36 E 2351 45 82 98 17 10 57 O1 35 65 0 85 0 57 0 44 0 36 0 33 1 O9 1 35 0 57 0 39 0 22 47 43 S 1758 26 E 1758 90 S 88 27 E 5O 54 58 62 64 62 60 58 57 85 S 1822 48 S 1887 58 S 1951 71S 2015 16 S 2081 58 S 2148 78 S 2216 86 S 2283 12 S 2351 89 E 1823 17 E 1887 22 E 1952 29 E 2016 21E 2082 80 E 2149 37 E 2217 85 E 2284 27 E 2351 60 S 88 24 E 95 S 88 21E 09 S 88 17 E 27 S 88 13 E 20 S 88 14 E 71 S 88 20 E 20 S 88 26 E 61 S 88 31E 96 S 88 37 E 6000 O0 5202 95 5153.95 42 15 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 5277 O0 5351 O0 5424 O0 5497 O0 5570 O0 5643 O0 5716 O0 5789 O0 5862 08 5228.08 42 12 10 5302.10 42 30 56 5375.56 42 57 75 5448.75 42 56 98 5521.98 43 7 87 5594.87 43 13 64 5667.64 43 19 49 5740.49 43 7 57 5813.57 42 58 N 88 43 E 2418 82 N 88 42 E 2485 N 88 55 E 2552 N 89 6 E 2620 N 89 11E 2688 N 89 30 E 2756 S 89 57 E 2825 S 89 34 E 2893 S 89 15 E 2962 S 88 46 E 3030 80 91 64 68 68 O8 62 09 33 0 16 0 17 0 21 0 34 0 32 0 33 0 32 0 38 0 38 0 34 55 58 $ 2418 56 E 2419 20 S 88 41E 54 52 51 50 49 49 49 5O 51 05 S 2485 64 S 2552 46 S 2620 45 S 2688 64 S 2756 32 S 2825 66 S 2893 34 S 2962 54 S 3030 66 E 2486 88 E 2553 72 E 2621 85 E 2689 94 E 2757 41E 2825 99 E 2894 49 E 2962 74 E 3031 24 S 88 45 E 42 S 88 49 E 22 S 88 53 E 32 S 88 56 E 39 S 88 58 E 84 S 89 0 E 42 S 89 1E 92 S 89 2 E 18 S 89 2 E 7000 O0 5935.75 5886 75 43 1 7100 7200 7300 7400 7500 76OO 7700 7800 7900 O0 6009.09 5960 09 42 41 O0 6082.60 6033 60 42 38 O0 6156.19 6107 19 42 28 O0 6230.00 6181 O0 42 20 O0 6303.98 6254 98 42 6 O0 6378.25 6329 25 41 48 O0 6452.92 6403.92 41 27 O0 6528.17 6479.17 40 57 O0 6603.93 6554.93 40 27 S 88 29 E 3098.48 S 88 3 E 3166.45 S 87 50 E 3234.24 S 87 43 E 3301 96 S 87 56 E 3369 43 S 87 50 E 3436 7I S 87 31E 3503 67 S 87 7 E 357O 18 S 86 46 E 3636 04 S 86 35 E 3701 30 0.30 0.33 0.26 0.25 0.27 0.56 0.45 0.38 O. 50 0.53 53 19 S 3098.88 E 3099 33 S 89 1 E 55 57 60 62 65 68 71 74 78 28 S 3166.82 E 3167 30 S 89 0 E 70 S 3234.57 E 3235 09 S 88 59 E 34 S 3302.23 E 3302 78 S 88 57 E 92 S 3369.65 E 3370 24 S 88 56 E 39 S 3436.89 E 3437 51 S 88 55 E 11 S 3503.80 E 3504 46 S 88 53 E 22 S 3570.23 E 3570 95 S 88 51E 74 S 3636.01 E 3636.78 S 88 49 E 53 S 3701,16 E 3702,00 S 88 47 E COMPUTATION DATE: 27-APR-93 PAGE 3 ARCO ALASKA ZNC. AGI - 2 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: APRIL-25-199 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000 O0 6680 37 6631 37 39 52 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 6757 O0 6836 O0 6915 O0 6995 O0 7076 O0 7157 O0 7240 O0 7323 O0 7407 60 6708 09 6787 50 6866 15 6946 04 7027 93 7108 53 7191 92 7274 60 38 54 O9 37 42 5O 37 29 15 36 39 04 35 25 93 34 48 53 33 48 92 33 16 67 7358.67 33 1 S 86 12 E 3765 75 S 85 35 E 3829 S 84 50 E 3891 S 85 9 E 3951 S 85 10 E 4012 S 84 35 E 4070 S 84 17 E 4128 S 83 34 E 41'84 S 83 46 E 4239 S 84 1E 4294 25 14 86 27 98 29 53 59 11 0 58 0 68 0 92 0 94 0 91 0 91 0 91 0 96 0 76 0 62 82 62 S 3765 51E 3766 41 S 88 45 E 87 92 97 102 107 113 119 125 131 13 S 3828 33 S 3890 75 S 3951 73 S 4011 96 S 4069 54 S 4127 51S 4183 66 S 4237 45 S 4292 87 E 3829 61E 3891 15 E 3952 41E 4012 96 E 4071 09 E 4128 13 E 4184 98 E 4239 31E 4294 86 S 88 42 E 70 S 88 38 E 36 S 88 35 E 72 S 88 32 E 39 S 88 29 E 65 S 88 25 E 84 S 88 22 E 84 S 88 18 E 33 S 88 15 E 9000 O0 7491 66 7442.66 32 45 9100 9200 9300 9400 9500 9600 9700 9800 9900 O0 7575 O0 7660 O0 7745 O0 7831 O0 7917 O0 8004 O0 8092 O0 8181 O0 8270 87 7526.87 32 27 48 7611.48 32 4 49 7696.49 31 36 02 7782.02 30 45 40 7868.40 29 53 70 7955.70 28 45 60 8043.60 28 10 21 8132.21 27 2 66 8221.66 26 5 S 84 16 E 4348 28 S 84 34 E 4402 S 84 33 E 4455 S 84 42 E 4507 S 84 31E 4559 S 84 37 E 4609 S 84 33 E 4658 S 82 44 E 4706 S 83 17 E 4752 S 83 31E 4797 11 34 93 66 97 67 23 42 O1 0 41 0 3O 0 6O 0 73 0 71 1 59 1 32 1 44 1 19 1 O9 137 O1 S 4346 31 E 4348.47 S 88 12 E 142 147 152 157 161 166 171 177 182 29 S 4399 30 S 4453 26 S 4505 13 S 4557 95 S 4607 52 S 4655 80 S 4703 37 S 4749 58 S 4793 96 E 4402.26 S 88 9 E 04 E 4455.47 S 88 6 E 46 E 4508 03 S 88 4 E 04 E 4559 75 S 88 2 E 20 E 4610 04 S 87 59 E 75 E 4658 73 S 87 57 E 13 E 4706 27 S 87 54 E 13 E 4752 44 S 87 52 E 55 E 4797 03 S 87 49 E 10000.00 8360.93 8311.93 24 54 10100.00 8451.93 8402.93 24 6 10200.00 8543.32 8494.32 23 50 10215.00 8557.04 8508.04 23 50 S 83 39 E 4839.92 S 84 4 E 4881.28 S 84 5 E 4921.70 S 84 5 E 4927.75 1 . 09 1 .01 O. O0 Om O0 187.38 S 4836.30 E 4839.93 S 87 47 E 191.79 S 4877.51 E 4881.28 S 87 45 E 195.89 S 4917.80 E 4921.70 S 87 43 E 196.52 S 4923.83 E 4927.75 S 87 43 E COMPUTATZON DATE: 27-APR-93 PAGE 4 ARCO ALASKA INC. AGI - 2 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: APRIL-25-199 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG 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 1000 O0 1992 O0 2898 O0 3678 O0 4452 O0 5202 O0 5935 O0 6680 O0 7491 -49 O0 O1 951 85 1943 97 2849 75 3629 74 4403 95 5153 75 5886 37 6631 66 7442 0 0 O1 0 41 85 16 43 97 36 27 75 39 0 74 40 14 95 42 15 75 43 1 37 39 52 66 32 45 N 0 0 E S 19 49 E 1 S 88 40 E 92 S 86 9 E 500 S 88 56 E 1125 S 87 2 E 1758 N 88 43 E 2418 S 88 29 E 3098 S 86 12 E 3765 S 84 16 E 4348 0 O0 10 45 81 89 74 82 48 75 28 0 O0 0 75 4 71 2 66 0 63 0 85 0 16 0 3O 0 58 0 41 0 O0 N 4 7 19 34 47 55 53 82 137 32 S 0 76 S 92 15 S 500 30 S 1125 43 S 1758 58 S 2418 19 S 3098 62 S 3765 O1S 4346 93 E 4 21E 92 45 E 500 42 E 1125 26 E 1758 56 E 2419 88 E 3099 51E 3766 31E 4348 0 O0 E 0 O0 N 0 0 E 42 S 12 9 E 54 S 85 11E 81 S 87 49 E 94 S 88 15 E 90 S 88 27 E 20 S 88 41E 33 S 89 1E 41 S 88 45 E 47 S 88 12 E 10000.00 8360.93 8311.93 24 54 10215.00 8557.04 8508.04 23 50 S 83 39 E 4839.92 S 84 5 E 4927.75 1 . 09 0. O0 187.38 S 4836.30 E 4839.93 S 87 47 E 196.52 S 4923.83 E 4927.75 S 87 43 E R ECEi'V D 4 G 2 {-,' ,,,.90 Alaska Oil~ Gas Cons. Comrfiissior' Anchorage COMPUTATION DATE' 27-APR-93 PaGE Arco ALASKA INC. AGI - 2 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY. APRIL-25-199 KELLY BUSHING ELEVATION' 49.00 FT ENGINEER. G. SARBER INTERPOLATED VALUES FOR EVEN 1OO FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 48 96 148 96 248 96 348 96 448 96 548 97 648 97 748 97 848 98 0.00 49.0O 149.00 249.00 349.00 449.00 549.00 649.00 749.00 849.00 -49 O0 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 0 0 N 0 0 E 0 10 N 8 40 E 0 15 S 17 17 W 0 13 N 53 50 E 0 21 S 29 34 W 0 27 S 35 21E 0 22 N 86 32 E 0 31 S 27 55 W 0 33 S 52 3 E 0 17 S 55 0 E 0 O0 0 O0 -0 21 0 O5 -0 10 -0 O2 0 65 '0 59 0 82 I 5'1 0 O0 0 O0 0 59 0 59 0 7O 0 60 0 48 0 78 0 87 0 5"1 0 O0 N 0 O0 N 0 06 S 0 25 S 0 27 S 0 97 S I 23 S 147S 2325 2 74 S 0 O0 E 0 O0 E 0 22 W 004 E 0 11 W 0 06 W 0 60 E 0 53 E 0 73 E I 40 E 0 O0 N 0 0 E O0 N 0 0 E 23 S 74 39 W 26 S 8 13 E 29 S 22 57 W 97 S 3 36 W 37 S 26 9 E 56 S 19 43 E 43 S '17 27 E 08 S 27 3 E 948 98 1048 1148 1249 1349 1449 1549 1650 1750 1851 949 O0 99 1049 99 1149 01 1249 11 1349 31 1449 58 1549 03 1649 76 1749 79 1849 900 O0 O0 1000 O0 O0 1100 O0 O0 1200 O0 O0 1300 O0 O0 1400 O0 O0 1500 O0 O0 1600 O0 O0 1700 O0 O0 1800 O0 0 43 S 22 25 W 0 35 S 48 14 E 0 37 S 58 4 E 1 53 S 67 10 E 3 1 S 77 43 E 3 56 S 80 15 E 4 39 S 81 23 E 6 24 N 85 30 E 7 13 N 81 21E 9 43 N 88 55 E 1 17 1 46 2 27 3 98 8 31 14 42 21 75 31 20 43 09 57 29 0.61 O. 62 0.42 1 17 1 04 0 89 0 77 1 62 1 56 2 02 3 68 S 4 71 S 5 27 S 6 19 S 7 37 S 8525 9 74 S 10 20 S 8 505 7 29 S 1 02 E 1 27 E 2 05 E 3 74 E 8 02 E 14 08 E 21 37 E 30 81 E 42 78 E 57 04 E 3 81 S 15 30 E 4 5 7 10 16 23 32 43 57 87 S 15 3 E 65 S 21 18 E 23 S 31 8 E 89 S 47 25 E 46 S 58 50 E 49 S 65 30 E 45 S 71 40 E 61 S 78 45 E 50 S 82 43 E 1954.32 1949 O0 1900.00 15 36 2058.66 2049 2163.27 2149 2268.41 2249 2374 66 2349 2481 77 2449 2590 70 2549 2702 78 2649 2818 75 2749 O0 2000.00 16 55 O0 2100.00 17 14 O0 2200.00 19 16 O0 2300.00 20 7 O0 2400.00 21 54 O0 2500.00 24 49 O0 2600.00 28 43 O0 2700.00 32 1 2938 50 2849 O0 2800.00 34 51 3062.60 2949 O0 2900 O0 37 21 3189.86 3049 3320.48 3149 3451 16 3249 3580 05 3349 3707 57 3449 3834 36 3549 3961 78 3649 4090 17 3749 4217 48 3849 O0 3000 O0 3100 O0 3200 O0 3300 O0 3400 O0 3500 O0 3600 O0 3700 O0 380O O0 39 17 O0 40 19 O0 39 29 O0 38 37 O0 38 17 O0 37 58 O0 38 46 O0 38 39 O0 37 49 S 88 58 E S 87 55 E S 86 43 E N 88 55 E N 89 4 E S 87 56 E S 88 17 E S 89 12 E S 87 52 E S 87 14 E 79 66 109 45 140 13 172 58 208 39 246 73 289 89 340.43 399.13 464.98 S 84 28 E 538 41 S 83 48 E 616 N 89 20 E 700 n 88 53 E 784 N 89 23 E 866 N 89 54 E 945 S 89 10 E 1022 S 88 58 E 11Ol S 88 43 E 1182 S 88 37 E 1261 90 86 83 O1 06 96 90 39 18 4 56 3 81 1 87 1 35 1 60 1 94 2 O0 2 81 3 13 2 78 2 52 2 18 2 57 2 35 1 16 0 67 0 73 0 64 0 51 0 54 7 50 S 8 9 10 9 10 11 12 14 27 S 109 81S 139 78 S 172 84 S 208 29 S 246 93 S 289 80 S 340 32 S 398 20 E 109 85 E 140 29 E 172 16 E 208 52 E 246 64 E 289 19 E 340 88 E 399 79 43 E 79 78 S 84 36 E 51 S 85 40 E 19 S 85 59 E 62 S 86 25 E 39 S 87 18 E 73 S 87 37 E 89 S 87 38 E 43 S 87 51E 14 S 87 57 E 17 13 S 464 66 E 464 98 S 87 53 E ~> -- 22 25 S 537 95 E 538 41 S 87 38 E ~ r.~ ,.,~,~ 31 13 S 616 35 59 S 699 33 85 S 784 32 54 S 865 32 04 S 944 32 58 S 1022 33 86 S 1101 35.49 S 1181 37.38 S 1260 15 E 616 99 E 700 10 E 784 40 E 866 54 E 945 48 E 1023 43 E 1101 93 E 1182 70 E 1261 93 S 87 6 E ~ o ~ 90 S 87 5 E~ ~ -.-, 83 S 87 32 E ® ' kD O1 S 87 51E c o4 08 S 88 3 e ~ O0 S 88 11E d 95 S 88 14 E ¢ 46 S 88 17 E ~ 26 S 88 18 E COMPUTATION DATE' 27-APr-93 PAGE 6 ArCO ALASKA INC. aGI - 2 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY. APRIL-25-199 KELLY BUSHING ELEVATION. 49.00 FT ENGINEER- G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 4345 02 3949 O0 3900 O0 39 27 4474 4603 4732 4863 4995 5126 5256 5387 5520 64 4049 56 4149 46 4249 68 4349 10 4449 25 4549 76 4649 12 4749 29 4849 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 4500 O0 4600 O0 4700 O0 480O O0 39 17 O0 38 59 O0 39 30 O0 40 38 O0 40 14 O0 40 13 O0 39 55 O0 4O 6 O0 42 27 S 89 21E 1340 3O S 89 27 E 1422 S 89 37 E 1504 S 89 17 E 1585 S 87 54 E 1670 S 87 2 E 1755 S 86 55 E 1840 S 86 18 E 1924 S 86 29 E 2007 N 88 42 E 2095 73 O7 36 3O 57 42 27 88 74 0 77 0 9O 0 75 0 34 0 72 0 85 0 46 0 39 0 3O 1 22 38 76 S 1339 84 E 1340 40 S 88 21 39 4O 41 43 47 51 56 62 63 69 S 1422 41S 1503 10 S 1585 33 S 1669 27 S 1755 76 S 1839 77 S 1923 20 S 2007 92 S 2094 30 E 1422 67 E 1504 O0 E 1585 92 E 1670 10 E 1755 83 E 1840 55 E 1924 O1E 2007 87 E 2095 85 S 88 24 21 S 88 28 54 S 88 31 48 S 88 31 74 S 88 27 56 S 88 23 39 S 88 19 97 S 88 13 84 S 88 15 5656 06 4949 O0 4900 O0 42 32 5791 5927 6062 6197 6333 6469 6607 6744 6881 66 5049 08 5149 13 5249 15 5349 40 5449 94 5549 05 5649 47 5749 45 5849 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 42 26 O0 42 20 O0 42 4 O0 42 29 O0 42 58 O0 42 56 O0 43 15 O0 43 17 O0 43 0 N 88 28 E 2187.38 N 88 24 E 2278.74 N 88 40 E 2369.86 N 88 41 E 2460.44 N 88 55 E 2550 98 N 89 9 E 2643 37 N 89 22 E 2736 20 S 89 55 E 2829 91 S 89 28 E 2924 10 S 88 50 E 3017 68 O. 65 0.41 0.18 0.17 0.20 0.35 O. 33 0.32 0.38 0.35 61 60 S 2186.68 E 2187 55 S 88 23 E 59 56 54 52 51 49 49 49 51 O1 S 2278.23 E 2278 68 S 2369.51 E 2370 63 S 2460.25 E 2460 67 S 2550.95 E 2551 11 S 2643.47 E 2643 84 S 2736.43 E 2736 33 S 2830.24 E 2830 92 S 2924.49 E 2924 28 S 3018.10 E 3018 99 S 88 31E 19 S 88 38 E 86 S 88 44 E 49 S 88 49 E 97 S 88 54 E 89 S 88 57 E 67 S 89 0 E 92 S 89 1E 53 S 89 2 E 7018 10 5949 O0 5900.00 42 56 7154 7290 7425 7560 7694 7827 7959 8088 8216 29 6049 25 6149 70 6249 69 6349 77 6449 57 6549 07 6649 94 6749 31 6849 O0 6000.00 42 42 O0 6100.00 42 30 O0 6200.00 42 20 O0 6300.00 42 6 O0 6400.00 41 29 O0 6500.00 40 55 O0 6600.00 40 5 O0 6700.00 39 2 O0 6800.00 37 32 8342 20 6949 O0 6900 O0 37 22 8466 8589 8710 8829 8949 9068 9186 9304 9420 74 7049 13 7149 20 7249 98 7349 25 7449 12 7549 45 7649 12 7749 93 7849 O0 7000 O0 7100 O0 7200 O0 7300 O0 7400 O0 750O O0 7600 O0 7700 O0 7800 O0 35 48 O0 34 51 O0 33 42 O0 33 9 O0 32 51 O0 32 37 O0 32 7 O0 31 36 O0 30 57 S 88 23 E 3110 80 S 87 57 E 3203 S 87 44 E 3295 S 87 54 E 3386 S 87 38 E 3477 S 87 8 E 3566 S 86 43 E 3654 S 86 19 E 3739 S 85 41E 3822 S 84 46 E 3901 26 36 73 4O 71 10 47 3O 10 S 85 22 E 3977 50 S 84 50 E 4051 S 84 21E 4122 S 83 32 E 4190 S 83 54 E 4255 S 84 7 E 4320 S 84 26 E 4384 S 84 37 E 4448 S 84 42 E 4510 S 84 26 E 457O 65 10 19 97 84 99 16 08 37 0 31 0 29 0 25 0 63 0 47 0 38 0 50 0 58 0 65 0 94 0 92 0 91 0 93 0 95 0 7O 0 54 0 3O 0 4O 0 72 0 69 53 54 S 3111 20 E 3111.66 S 89 1 E 56 56 S 3203 61E 3204.11 S 88 59 E 60 08 S 3295 65 E 3296.19 S 88 57 E 63 55 S 3386 95 E 3387.55 S 88 56 E 66 99 S 3477 56 E 3478.20 S 88 54 E 71 04 S 3566 78 E 3567.48 S 88 52 E 75 77 S 3654 04 E 3654.83 S 88 49 E 80 90 S 3739 27 E 3740.15 S 88 46 E 86 60 S 3821 94 E 3822.92 S 88 42 E 93 23 S 3900 53 E 3901.64 S 88 38 E 99.87 S 3976 73 E 3977 98 S 88 34 E 106.17 S 4050 68 E 4052 07 S 88 30 E 91E 4122 46 S 88 26 E ~ ~ ~,~ 77 E 4190 49 S 88 21E~ : - 31 E 4256 22 S 88 17 E 95 E 4321 04 S 88 13 E 90 E 4385 16 S 88 10 E - 88 E 4448 29 S 88 7 E 61 E 4510 19 S 88 4 E 72 E 4570 46 S 88 1 E 112.93 S 4120 120.15 S 4188 127.43 S 4254 134.22 S 4318 140.64 S 4382 146.61S 4445 152.46 S 4507 158.16 S 4567 COMPUTATION DATE: 27-APR-93 PAGE 7 ARCO ALASKA Inc. aGI - 2 PRUDHOE BAY NORTH SLOPE, ALASKA DATE Of SURVEY: aPRIL-25-199 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 9536.31 7949 O0 7900 O0 29 14 S 84 38 E 4627 82 9650.46 8049 O0 8000 O0 28 30 S 83 34 E 4682 78 9763.77 8149 O0 8100 O0 27 28 S 83 14 E 4735 88 9875.86 8249 O0 8200 O0 26 20 S 83 25 E 4786 37 9986.84 8349 O0 8300 O0 25 3 S 83 38 E 4834 36 10096.79 8449 O0 8400 O0 24 7 S 84 3 E 4879 97 10206.21 8549 O0 8500 O0 23 50 S 84 5 E 4924 20 10215.00 8557 04 8508 04 23 50 S 84 5 E 4927 75 1 43 1 36 1 37 1 07 1 09 1 02 0 O0 0 O0 163 60 S 4625.00 E 4627.89 S 87 58 E 168 98 S 4679.78 E 4682.83 S 87 56 E 175 42 S 4732.66 E.4735.91 S 87 53 E 181 36 S 4782.95 E 4786.38 S 87 50 E 186 76 S 4830.76 E 4834.37 S 87 47 E 191 65 S 4876.21 E 4879.97 S 87 45 E 196 15 S 4920.29 E 4924.20 S 87 43 E 196 52 S 4923.83 E 4927.75 S 87 43 E ARCO ALASKA INC. AGI - 2 PRUDHOE BAY NORTH SLOPE, ALASKA MARKER GCT LAST READING TD COMPUTATION DATE: 27-APR-93 PAGE 8 DATE OF SURVEY: APRIL-25-199 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 1701~ FSL, ~ 2411~ FEL, SEC36 T12N R14E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 10150.00 8497.63 8448.63 193.88 S 4897.69 E 10215.00 8557.04 8508.04 196.52 S 4923.83 E Alaska Oil & Gas Cons. Cor~r~issic,¢-, Anchorage ARCO ALASKA InC. AGI - 2 PRUDHOE BAY NORTH SLOPE, ALASKA MARKER TD COMPUTATION DATE: 27-APR-g3 PAGE 9 DATE OF SURVEY: APRIL-25-199 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: G. SARBER ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 1701' FSL, & 2411' FEE, SEC36 T12N R14E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 10215.00 8557.04 8508.04 196.52 S 4923.83 E FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 10215.00 85S7.04 8508.04 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 4927.75 S 87 43 E DIRECTIONAL SURVEY COMPANY FIELD ARCO ALASKA INC. PRUDHOE BAY WELL AGI - 2 COUNTRY USA RUN I DATE LOGGED 25 - APR DEPTH UNIT FEET REFERENCE 931 87 93 -- .;_ .-~ _-_ -;. _ ._ All interpretations are opinions based on Inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any Interpretations. and we shall not. except In the case of gross or wlffull negligence on our part. be liable or responsible for any loss. costs, damages or expenses Incurred or sustained by anyone resulting from any' interpretation 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 Schedule. .. _ WELL' AGI-2 (1701' FSL, 2411' FEL, SEC 36, T12N, R14E) HORIZONTAL PROJECTION NORTH4000 liEF 93187 SCALE = I / 1000 IN,d::T · . . : . . . 3000 ! ! ! : i ! ! i "! ~'i ! ! i !'i : i i ! i ! i ! !' ! ! i ! i ! ! i ; ! i ; : - i · · ~ i:~: ::': :::' :':' '::: ::' :::: ' : :. ' [~ -:~-:~ ..... :i .:-: '::: 2000 ! 'i";" ']i iiii:i'::i:iii :'ii:¢~i ii:i:'iiiii:i'i!"i' i ': ....... :'' iii .... i .......... i ' ' ............ ........................ ........ ............... ~!i.~ !i---!--i~-.i--~---!---i- :! i ~ ..... ..... i.-!;--i-~i..!!i-~.!.-i-.i ~!!~ !. i '-! }: .......' ........ -!hi'! :~'': :i-~ !:':: .::!. !!:: !..i 'ii'i': ..... i ' ' 1000 .... : - - ...... :::: :::: :::: :. :::: ;:.. :: ..... - -!:: : ; !i,! : .. .......... ~ : · :: :: : :.:: ..... i..:.~:.:.: .................... -lOOO .... ~-: ..~ _. ........ i::: ~ i!-!--.i i:~-..i-i-i!-!~i! :!!~ '~!i i~;~ ~.~:~ :,:: ~:~' ~ .......... ~'': i :'- !--~'-!':'-:---i: i-:: ..... ~-~!-!.!.i ::--; ::~: !-~- i.:: ::-:':: ....... ':: ; .... · : : :: :.: :.:: :: : .:. : . . ::: .... : . . : ....... soum-4OOO i '1 i'i .... !i!'}"!!! ?!"!'! i:!!i;~! .... ! ! -2000 -1000 0 1000 2000 3000 4000 5000 WEST AU G 2 6 t99;3 Alaska 0it & Gas 0ohs. commission :Anchorage 6000 BAS? WELL' AGI-2 (1701' FSL, 2411' FEL, SEC 36, T12N, R14E) VERTICAL PROJECTION 272.00 -2000 -1000 0 0 1000 2000 3000 4000 5000 6000 .:. ..:: : :: : :: :.,:. :::: :::::: : .::. : :: :: . :-:: ... ! ~ i i i i i ! i'!'! ' ! i-i'i' i i"!'i i !"! : i i i' i i i i 'i'!'! i ! ! ~ : : : .... i : ! : ~ : : : ' : ' ' ::-:-.~]!:,[i:~ i::: ~::] ::i: ~: : ~-, .................. -i ......... i" ........ :' :": ..... it' i ..... ::- :.-; , : ;.i :.i ..i-.~..i ..... i..i.~..;~.., ; i...i .... i.i..i i i.L..i.-.i ~.~..,.~,~ i-! ;-i-. ; ;.* i i-! : ~ Li :..i' ' ' : ............ ~?; :}i?:-.!--!!i -}i--i~J-i-i--!-.i i.!i; :..i..;.~. }.;;;:i!.~ oooo. . : .... : :'--: .... · ; ,,:: : ..... ~,,' ............................. !;! . , :.: :i** ii,; i;i~l iiii. i*:i i:!, i,:i:::~:,::~. :,:: ............ ~ ! m i ! : i ' ; : ~ '~ ! ; i :' ! ! i': : : : !'' ! : : : : ' : ' : ' : : : ; : ! ' ' :': ............... ~ ,... ::,, ,:, !e: ,~ ...................... -:: ::;; ilil :i: ........ ~' ~ . . ....'~ !'!!-i i':i i!;: iiil ::i: '- **i' 'i': : ........ ' 9000 :!::i:};', '-!!:~' Jf-!~ -i-!'i---}--:-i-ii'i-!!-bl--i-i*-! *: ---!! .i.. !'!'i !-:! :::i- -.: ....... :; i~ I::~'!~i:i~ 8oObi ! i :,:: :!:' ':'. ' " :'. __ ~ .:_ . '~--:~---~-( : · F-?'-! : ! i : ~ , :, : : : ~ ~ : i ~. : ; .......... : .............. ....... i ....................... '.i:5 ..... ': : :" :5 : i , ~ ; i ~ ; .i ; : ~ i ~..; ~ . i i i i i i ; i i i i..i : i i.i i i ~ ....... : ......... , .::: .... :.: .::: :: ............. -:.. ?~ii~---r:-:: i;.i.i-iiii ~.i~.i iiii--i~i; .::~i i.i.i ..il .,; .... · .: . :. . .; :::. ::.. .::: ..:. · . · .: , : ,:::--::z: ,, , ,,:: r., i : :' ~: .... ::;..:.-;..-:..~ ....... :--,..-i.-i. i.i-..i...i.--~..i-..i...i...iii--.; .i.;..i..i :.,...; .... i ...... ; ...!.i. 'i::i ............ . : ~: :: L..i. ;; .... ;., i ;.;..; i.i.i..; ..... i i i.i. ; i i ;..;, ; i. ~ i; .............. .i!: !~:: :!:~ :!ii ]i:~ ::i~ i:ii ': ' ! .i :i : . - ..:..: :::: ::.. ::: :: : ..... : :.:j~ ! - :. ;: :.:~ :;;. .;:.~: · . ,-:!i ........................ ;~; ~;,;.].d;, .~ ~;:; ;.;., ;,~; .i : : '' ..................... · . .......................................................................................... . . : ............ :~: :~:.[ ~.LL..~..:J.::.. ~.[.~..~ [~[[ ~: .... :[ ::: .. .: . :. . ........................ 92.00 PROJECTION ON VER'F1CAL PLANE27200 92.00 SCALED IN VERTICAL DEPTHS HORIZ SCALE ~ I / 1000 IN/FT in 2 6 199 ,,-lJaska Oil & Gas Cons, Corrlrnissio*: Anchorage AOGCC GEOLOGICAL MATERIALS iNVENTORY LiST P. RM~T~ ~ ~_ /~Z~ WELL NAM. ?~ ~ ~ G ~ ~ ~ COMPLETION DATE /~ //~ ~ ~ ~ CO, CONTACT ~~ ~'~ ~~,~' check off or l'ist data as it is received.*list received date for 407. i~ not reouircd list as NR drillinu histo~* su~ev well tgsts core dcscri cored intc~ais core analysis dw ditch intc~ais digital data i I r~,"~ 'rvnc | nrxUN | I: -v~ , ,~ INTERVAL~ SCALE , NO. (to thc ncarc~tfoot~ , . [inchtl00'~ I I 1~ ' I ! 11] ! 13) I ............ ~ ] ...... ~1 ! 16l I 171 ' ~81 ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 November 24, 1992 Marty Lemon Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit AGI-2 ARCO Alaska, Inc. Permit No: 92-120 Sur. Loc 1701'NSL, 2411'WEL, Sec. 36, T12N, R14E, UM Btmhole Loc. 1491'NSL, 2139'WEL, Sec. 31, T12N, R15E, UM Dear Mr. Lemon: 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. Si 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. ' - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrilll-lllb. Type of well. ExploratoryF'] Stratigraphic Test[] Development OilF'] Re-Entry [] DeepenI-'1! 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 -- 49'feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. 0. Box 196612. Anchora~Te. Alaska 99519-6612 ADL 34628 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(r~e 20 AAC 25.025) 1701'NSL, 2411' WEL, SEC. 36, T12N, R14E Prudhoe Bay Unit At top of productive interval 8. Well number Number 1500' NSl.., 2350' WEL, SEC. 31, T12N, R15E AGI-2 U-630610 At total depth 9. Approximate spud date Amount 1491' NSL, 2139' WEL, SEC. 31, T12N, R15E 11/26/92 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD a,d'rVD) property line ADL 34632-1491'feet LGI-8 /302'@ 7146' MD feet 2560 10329' MD/9550' TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (s~, 2o A~C 25.o35 Kickoff depth ~ooofeet Maximum hole angle 40 o Maximum surface 3330PS~g At total depth (TVD) ~O0'/4390PsIg 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement .- Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 70' 30' 30' 106' 106' 11 .yds Arcticset 16" 13-3/8" 68# L-80 B TC 3723' 29' 29' 3752' 3500' 1o27 sxPF "E'/400 sx 'G"/250 PF °C 12-1/4" 9-5/8" 47# L-80' NSCC 9700' 28' 28' 9728' 8078' 383 sx Class "G" 8-1/2" 7" 26# L-80 NSCC ~ 9550' 7982' 10329' 9550' 130 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet ,~j~.~h~.V~.--DTrue Casing Length Size Cemented Vertical depth Structural Conductor Surface Intermediate !".J 0 TM Production ,~laska 0ii & ~as Cons. 60m~! Liner Anch0ra§8 Perforation depth: measured ' true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program ITl Drilling fluid program [] Time vs depth plot [] Refraction analysis l-I Seabed report[] 20 AAC 25.050 requirementsl-I 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ¢"~ ~ Title Orillin9 Eng*eerSupervisor Date }[ Commission Use Only Permit Number IAPI number IApproval date ISee cover letter ~'~ ~- / ~ (~ 15 0- ~ ~ C~ _ ~ ~ .~ ) ~ I //" c~'/"/-'¢~'Jf°r other requirements Conditions of approval Samples required [] Yes I~No Mud log required []Yes I~ No Hydrogen sulfide measures [] Yes 12[ No Directional survey required [] Yes [] No Required working pressp, re for BOPE [] 2M' 1-13M; ~5M; []10M; I-]15M; Other: Or/a~n~l . E~Y by order of Approved by David ~v. UoDRsIop Commissioner ~ne commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate WELL PLAN Well: APEX GAS INJECTOR #Z (AGI #Z) LOCATION: Surface: Target: T.D.: 1701' FSL, 2411' FEL, Sec. 36, T12N, R14E 1500' FSL, 2350' FEL, Sec. 31, T12N, R15E 1491' FSL, 2139' FEL, Sec. 31, T12N, R15E ESTIMATED START: 26/NOV/92 OPR. DAYS TO COMPLETE: 20 (16 days drilling, 4 days completion) CONTRACTOR: AUDI RIG #2 MAX ANGLE/SECT COURSE/KOP/BUILD/MAX DEP: 40 deg/S87.67E/1000'/2.0/5154' Estimated Ground level elevation is 13' AMSL. KB to ground level elevation is 36'. Item TVD(BKB) MD(_BKB) Mud Wt. 20" CONDUCTOR 13-3/8" SHOE 9-5/8" SHOE TOP SADLEROCHIT 7" SHOE TARGET TOTAL DEPTH 106 106 8.5 3500 3752 9.0 8078 9728 8083 9734 9.2-10.0 8539 10329 9.2-10.0 8287 10000 9.2-10.0 8539 10329 9.2-10.0 CASING PROGRAM: Hole Csg 30" 20" 16" 13-3/8" 12-1/4" 9-5/8" 8-1/2" 7" Wt Grade Conn Length Top Btm 91.5# H-40 WELD 70 30 106 68# L-80 BTC 3723 29 3752 47# L-80 NSCC 9700 28 9728 26# L-80 NSCC 779 9550 10329 COMPLETION: Tubing: 7" GLMs: None Packer: Baker 26# L-80 NSCC 1 0231 29 10315 9-5/8" x 6" BORE Baker set at 9500/MD or +/- 50' above Top of liner LOGGING PROGRAM: Open Hole - Cased Hole 9-7/8" Hole: None 6-3/4" Hole: DIL/CNL/GR/SP/SDT CBT/CET IN 7" AND 9-5/8" before running tubing GAS INJECTOR #2 (AGI #,-) DRILLING DISCUSSION AGI #2 is the second 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 There are no annuli available for injection on this pad at present. The 13-3/8" x 9-5/8" annulus on AGI #1 is not to be injected into. Fluids can be injected at the central CC-2 injection facility. 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 PROTECTION The 7" tubing along with the 7" x 9-5/8" annulus will be freeze protected with diesel before the drilling rig moves off the well. CLOSE APPROACHES There are no wells within 2_00' of the planned wellbore trajectory of AGI #2_. The closest well is LGI- 08 which comes within 300' at 6100' TVD. , . . . 6. 7. 8. . 11. ° Anticipated BHP: ° Maximum Anticipated Surface Pressure: ° Planned Completion Fluid: Notes: a. PROPOSED DRILLING AND COMPLETION PROGRAM AGI #2 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, Bump cementing plug with mud, RIH and drill 8-1/2" hole through reservoir to TD, RU and run e-line logs. MU 7" liner on 5" DP, RIH to TD. Cement same, Set liner hanger and packer. Circulate excess cement from wellbore. POOH. MU casing scraper & clean out 7" liner. Run 7", L-80 and packer assembly with SSSV. Freeze protect with diesel. Test tubing and casing to 4000 psi. Have witnessed by state, NU tree and test to 5000 psi. Release drilling rig. 3850 psi @ 8800' TVD SS 2970 psi 9.8 ppg filtered brine The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. b. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/fi). c. No potential productive zones are anticipated above 8125' TVD (9-5/8" casing shoe). d. No potential hazardous levels of H2S are anticipated in this well. f,,,dD PROGRAM: Well AGI #Z 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 Doint: Mud Weight: ppg 8.5 - 9.5 8.5 - 9.0 Funnel Viscosity sec/qt ~300 <1 O0 YP lbs/100ft2 40 - 60 20 - 40 10 sec Gel Ibs/lOOft2 30 - 60 15 - 20 10 min Gel lbs/100ft2 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 IVlud Weight ppg 9.2-10.0 Yield Point lbs/100ft2 10 - 15 10 sec Gel lbs/100ft2 5 - 10 10 min Gel lbs/100ft2 10 - 20 APl Fluid Loss mi/30 rain 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/100ft2 10 - 20 10 sec Gel lbs/100ft2 5 - 10 10 min Gel lbs/100ft2 15 - 25 APl Fluid loss mi/30 min 6.0 - 8.0 pH -- 9.5 - 10.0 Hardness mg/Itr < 200 The mud salinity should be compatible with the Reservoir logging program. The mud should be run at 10,000- 20,000 ppm chlorides. AGI #Z Casing Design SURFACE CASING 13-3/8" 68#/FT K-55 & L-80 BTC CASING BURST COLLAPSE PBYS (#) K-55 3450 1950 1069000 L-80 5020 2260 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 IVlud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 2900 1433 Collapse S.F. 1.58 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) Mud Wt. 68 3752 9.5 ppg PBYS TJYS Tension S.F. 4.90 5.96 String Wt. (#) 21 8090 AGI #2 Casing Design Production Casing 9-5/8", 47#,L-80, NSCC Casing GRADE BURST COLLAPSE PBYS (#) L-80 6870 4750 1086000 TJYS (#) 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 2970 Burst S.F. 2.31 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 8078 0.1 3477 Collapse $,F, 1,37 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) Mud Wt. 47 9728 10.2 PBYS TJYS Tension S.F. 2.81 3.01 String Wt. (#) 385936 CEMENT PROGRAM - HALLIBURTON sr- VICES 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: 1027 PUMP TIME: 4:30 hrs MIX WATER: 11.63 gps FW Mix water temp: 50-65F TAIL CEMENT TYPE: CLASS G ADDITIVES: 2% Calcium Chloride WEIGHT: 15.8 ppg YIELD: 1.16 ft3/sx APPROX #SACKS: 400 PUMP TIME: 4 hfs MIX WATER: 5.00 gps FW Mix water temp: 50-65 F TOP ,lOB 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 SPACER: 100 bbls fresh water ahead of lead slurry. The WATER temperature should be 50-65F CEMENT VOLUME 1. Lead slurry to surface w/100% excess. 2. Tail slurry volume 400 sx 3. Top job volume +/- 250 sx. 9 5/8" INTERMEDIATE CASING CASING SIZE: 9 5/8", 47# CIRC. TEMP 135°F TAIL CEMENT TYPE: CLASS G ADDITIVES: 0.2% CFR-3 (Dispersant) + 0.25% HR-5 (Retarder) + 0.2% Halad 344 (Fluid Loss) WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx MIX WATER: 5.00 gps FW APPROX #SACKS: 383 PUMP TIME: 4 hfs 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 12-1 5 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. CASING SIZE: 7", 26# t'.! (.)~/ I '9 ~.~-- -. CIRC. TEMP: 140° F ' CEMENT TYPE: C~SS G Mcnr;ra,,~ ADDITIVES: 0.2% CFR-3 (Dispersant)+0.4% HR-5(Retarder)+0.3% Econolite (extender) + 0.4% HA~D 344 (Fluid Loss) + 2% KCI (Clay control) + +0.01% D-AIR-3 (defoamer)+0.9% ~P-1 (Fluid Loss) +0.1 gps Stabilizer 434B. WEIGHT: 15.7ppg YIELD:1.20 ~3/sx MIX WATER: 5.0 gps APPROX ~SACKS: 130 PUMP TIME: 3:30 hrs + 1 hr mixing ~surface FLUID LOSS: 150 cc Mix water temp: 70-80 F PREFLUSH: 20 bbls ARCO preflush + 296 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). AG! #2 Casing Design PRODUCTION LINER 7", 26#,L-80,NSCC Casing GRADE BURST COLLAPSE PBYS (#) L-80 7240 5410 604000 TJYS (#) 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 3062 2970 Burst $.F, 2,3 6 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Gas Grad. l~ud Wt. (ppg) TVD (FT) (psi/fi) Collapse Press 10.2 8539 0.1 3675 Collapse $.F. 1.47 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 26 779 Mud Wt. String Wt. (#) 10.2 17096 Tension S.F. PBYS TJYS 35.33 39.01 d E 000 000 000 000 O0 O0 000 000 000 O0 ~ ~.. .11 .1! Smith International, Inc. Proposal Report Page 2 Date: 11/18/92 Wettpath ID: AGI-O2WP Measured Inct Drift TVD Depth Dir. (ft) (deg.) (deg.) (ft) 2753.71 28.00 92.33 2698.65 2853.71 30.00 92.33 2786.11 2953.71 32.00 92.33 2871.82 3053.71 34.00 92.33 2955.68 3153.71 36.00 92.33 3037.59 3253.71 38.00 92.33 3117.45 END OF BUILD 3353.71 40.00 92.33 3195.16 3453.71 40.00 92.33 3271.77 3553.71 40.00 92.33 3348.37 3653.71 40.00 92.33 3424.98 13-3/8" CASING POINT 3751.65 40.00 92.33 3500.00 3753.71 40.00 92.33 3501.58 TOTAL Rectangular Offsets (ft) (ft) 13.64 S 335.05 E 15.61 S 383.49 E 17.70 S 434.95 E 19.92 S 489.37 E 22.25 S 546.67 E 24.70 S 606.80 E 27.26 S 669.68 E 29.87 S 733.90 E 32.49 S 798.13 E 35.10 $ 862.36 E 37.66 S 925.26 E 37.72 S 926.58 E 3853.71 40.00 92.33 3578.19 40.33 S 990.81 E 3953.71 40.00 92.33 3654.79 42.94 S 1055.03 E 4053.71 40.00 92.33 37-31.39 45.56 S 1119.26 E 4153.71 40.00 92.33 3808.00 48.17 S 1183.48 E 4253.71 40.00 92.33 3884.60 50.79 S 1247.71 E 4353.71 40.00 92.33 3961.21 53.40 S 1311.93 E 4453.71 40.00 92.33 4037.81 56.02 S 1376.16 E 4553.71 40.00 92.33 4114.42 58.63 S 1440.39 E 4653.71 40.00 92.33 4191.02 61.24 S 1504.61 E 4753.71 40.00 92.33 4267.63 63.86 S 1568.8/+ E 4853.71 40.00 92.33 4344.23 66.47 S 1633.06 E 4953.71 40.00 92.33 4420.83 69.09 S 1697.29 E 5053.71 40.00 92.33 4497.44 71.70 S 1761.51 E 5153.71 40.00 92.33 4574.04 74.32 S 1825.74 E 5253.71 40.00 92.33 4650.65 76.93 S 1889.96 E 5353.71 40.00 92.33 4727.25 79.54 S 1954.19 E 5453.71 40.00 92.33 4803.86 82.16 S 2018.42 E 5553.71 40.00 92.33 4880.46 84.77 S 2082.64 E 5653.71 40.00 92.33 4957.07 87.39 S 2146.87 E 5753.71 40.00 92.33 5033.67 90.00 S 2211.09 E 5853.71 40.00 92.33 5110.27 92.62 S 2275.32 E 5953.71 40.00 92.33 5186.88 6053.71 40.00 92.33 5263.48 6153.71 40.00 92.33 5340.09 6253.71 40.00 92.33 5416.69 6353.71 40.00 92.33 5493.30 6453.71 40.00 92.33 5569.90 95.23 S 2339.54 E 97.85 S 2403.77 E 100.46 S 2467.99 E 103.07 S 2532.22 E 105.69 S 2596.45 E 108.30 S 2660.67 E Geographic Coordinates Latitude / 'Longitucle 70.20.53.6997 N 148.27.49.8201 70.20.53.6803 N 148.27.48.4046 70.20.53.6597 N 148.27.46.9008 70.20.53.6379 N 148.27.45.3106 70.20.53.6149 N 148.27.43.6360 70.20.53.5909 N 148.27.41.8788 70.20.53.5657 N 148.27.40.0414 70.20.53.5400 N 148.27.38.1646 70.20.53.5143 N 148.27.36.2877 70.20.53.4886 N 148.27.34.4109 70.20.53.4634 N 148.27.32.5728 70.20.53.4629 N 148.27.32.5341 70.20.53.4371 N 148.27.30.6572 W 70.20.53.4114 N 148.27.28.7804 W 70.20.53.3857 N 148.27.26.9036 W 70.20.53.3600 N 148.27.25.0267 70.20.53.3343 N 148.27.23.1499 70.20.53.3086 N 148.27.21.2731 70.20.53.2829 N 148.27.19.3962 70.20.53.2572 N 148.27.17.5194 70.20.53.2314 N 148.27.15.6426 70.20.53.2057 N 148.27.13.7658 70.20.53.1800 N 148.27.11.8889 70.20.53.1543 N 148.27.10.0121 70.20.53.1286 N 148.27.08.1353 70.20.53.1029 N 148.27.06.2585 70.20.53.0772 N 148.27.04.3816 70.20.53.0515 N 148.27.02.5048 W 70.20.53.0258 N 148.27.00.6280 W 70.20.53.0000 N 148.26.58.7512 W 70.20.52.9743 N 148.26.56.8743 W 70.20.52.9486 N 148.26.54.9975 W 70.20.52.9229 N 148.26.53.1207 W 70.20.52.8972 N 148.26.51.2439 70.20.52.8715 N 148.26.49.3670 70.20.52.8458 N 148.26.47.4902 70.20.52.8201 N 148.26.45.6134 W 70.20.52.7943 N 148.26.43.7366 W 70.20.52.7686 N 148.26.41.8598 W GRID Coordinates Northing Easting (ft) (ft) 5979336.12 689212.80 5979335.38 689261.27 5979334.58 689312.77 5979333.74 689367.22 5979332.86 689424.57 5979331.93 689484.74 Closure Dist. Dir. (ft) deg. 335.33 @ 92.33 383.81 @ 92.33 435.31 @ 92.33 489.77@ 92.33 547.13 @ 92.33 607.30 @ 92.33 5979330.96 689547.65 5979329.98 689611.92 5979328.99 689676.19 670.23 @ 92.33 734.51 @ 92.33 798.79 @ 92.33 5979328.00 689740.46 863.07 @ 92.33 5979327.03 689803.41 926.02 @ 92.33 5979327.01 689804.73 927.35 @ 92.33 5979326.03 689869.00 991.63 a 92.33 5979325.04 689933.27 1055.91 @ 92.33 5979324.05 689997.54 1120.18 @ 92.33 5979323.07 690061.81 1184.46 @ 92.33 5979322.09 690126.08 1248.74 @ 92.33 5979321.10 690190.35 1313.02 @ 92.33 5979320.12 690254.62 1377.30 @ 92.33 5979319.14 690318.89 1441.58 @ 92.33 5979318.15 690383.16 1505.86 @ 92.33 5979317.17 690447.43 1570.14 @ 92.33 5979316.19 690511.70 1634.41 @ 92.33 5979315.21 690575.97 1698.69 @ 92.33 5979314.23 690640.24 1762.97 @ 92.33 5979313.25 690704.51 1827.25 @ 92.33 5979312.27 690768.78 1891.53 @ 92.33 5979311.29 690833.05 5979310.32 690897.32 5979309.34 690961.59 1955.81 @ 92.33 2020.09 @ 92.33 2084.37 @ 92.33 5979308.36 691025.86 2148.64 @ 92.33 5979307.39 691090.13 2212.92 @ 92.33 5979306.41 691154.40 2277.20 @ 92.33 5979305.44 691218.66 2341.48 @ 92.33 5979304.46 691282.93 2405.76 @ 92.33 5979303.49 691347.20 2470.04 @ 92.33 5979302.51 691411.47 2534.32 @ 92.33 5979301.54 691475.74 2598.60 @ 92.33 5979300.57 691540.01 2662.87 @ 92.33 Vertical DLS Subsea Section Depth (ft) (dg/lOOft) (ft) 335.33 383.81 435.31 489.77 547.13 607.30 670.23 734.51 798.79 863.07 926.02 927.35 991.63 1055.91 1120.18 1184.46 1248.74 1313.02 1377.30 1441.58 1505.86 1570.14 1634.41 1698.69 1762.97 1827.25 1891.53 1955.81 2020.09 2084.37 2148.64 2212.92 2277.20 2341.48 2405.76 2470.04 2534.32 2598.60 2662.87 2.00 2649.65 2.00 2737.11 2.00 2822.82 2.00 2906.68 2.00 2988.59 2.00 3068.45 2.00 3146.16 0.00 3222.77 0.00 3299.37 0.00 3375.98 0.00 3451.00 0.00 3452.58 · 0.00 3529.19 0.00 3605.79 0.00 3682.39 0.00 3759.00 0.00 3835.60 0.00 3912.21 0.00 3988.81 0.00 4065.42 0.00 4142.02 0.00 4218.63 0.00 4295.23 0.00 4371.83 0.00 4448.44 0.00 4525.04 0.00 4601.65 0,00 4678.25 0.00 4754.86 0.00 4831.46 0.00 4908.07 0.00 4984.67 0.00 5061.27 0.00 5137.88 0.00 5214.48 0.00 5291.09 0.00 5367.69 0.00 5444.30 0.00 5520.90 6553.71 40.00 92.33 5(>46.51 110.92 S 2724.90 E 70.20.52.7429 N 148.26.39.9830 ~ 5979299.60 691604.28 2727.15 @ 92.33 2727.15 0.00 5597.51 Smith International, Inc. Proposal Report Page 3 Date: 11/18/92 Wettpath ID: AGI-O2WP Measured Incl Drift TVD Depth Dir. (ft) (deg.) (deg.) (ft) 6653,71 40,00 92,33 5723,11 6753,71 40,00 92,33 5799,71 6853,71 40,00 92.33 5876,32 6953,71 40,00 92,33 5952.92 7053,71 40,00 92,33 6029,53 7153,71 40,00 92,33 6106,13 7253,71 40,00 92,33 6182,74 7353,71 40,00 92,33 6259,34 7453,71 40,00 92,33 6335,95 7553,71 40,00 92,33 6412,55 7653,71 40,00 92,33 6489,15 7753,71 40,00 92,33 6565,76 7853,71 40,00 92,33 6642,36 7953,71 40,00 92,33 6718,97 8053,71 40,00 92,33 6795,57 8153,71 40,00 92,33 6872,18 8253,71 40,00 92,33 6948,78 8353.71 40,00 92,33 7025,39 8453,71 40,00 92,33 7101,99 8553,71 40,00 92.33 7178,59 8653,71 40,00 92,33 7255,20 8753,71 40,00 92,33 7331,80 8853,71 40,00 92,33 7408,41 8953,71 40,00 92,33 7485,01 9053,71 40,00 92,33 7561,62 9153,71 40,00 92.33 7638.22 9253,71 40,00 92,33 7714,83 9353,71 40,00 92,33 7791,43 9453,71 40,00 92,33 7868,03 9553,71 40,00 92.33 7944,64 9653,71 40,00 92,33 8021,24 ~-5/8" CSG PT 9727,80 40,00 92,33 8078.00 lOS 9734.33 40,00 92,33 8083,00 9753,71 40,00 92,33 8097,85 9853,71 40,00 92,33 8174.45 9953,71 40,00 92,33 8251.06 TOTAL Rectangular Offsets (ft) (ft) 113,53 S 2789,12 E 116,15 S 2853,35 E 118,76 S 2917,57 E 121,37 S 2981,80 E 123,99 S 3046,03 E 126,60 S 3110,25 E 129,22 S 3174,48 E 131,83 S 3238,70 E 134,45 S 3302,93 E 137,06 S 3367,15 E 139,67 S 3431,38 E 142.29 S 3495,60 E 144,90 S 3559,83 E 147,52 S 3624,06 E 150,13 S 3688,28 E 152,75 S 3752,51 E 155,36 S 3816,73 E 157,97 S 3880,96 E 160,59 S 3945,18 E 163,20 S 4009,41 E 165,82 S 4073,63 E 168,43 S 4137,86 E 171,05 S 4202,09 E 173,66 S 4266,31 E 176,27 S 4330.54 E 178,89 S 4394.76 E 181,50 S 4458.99 E 184,12 S 4523,21 E 186,73 S 4587,44 E 189,35 S 4651.66 E 191,96 S 4715,89 E 193,90 S 4763,48 E 194,07 S 4767.67 E 194,57 S 4780.12 E 197,19 S 4844,34 E 199,80 S 4908.57 E fARGET 10000.63 40,00 92,33 8287,00 201,03 S 4938,70 E 10100,63 40,00 92,33 8363.60 203,64 S 5002.93 E 10200,63 40,00 92,33 8440,21 206,26 S 5067,15 E Geographic Coordinates Latitude / Longitude 70,20,52,7172 N 148,26,38,1061 70,20,52.6915 N 148,26,36,2293 70,20,52,6658 N 148,26,34,3525 70,20,52,6401 N 148,26,32,4757 70.,20,52,6144 N 148,26,30,5989 70,20,52,5887 N 148,26,28,7221 70,20,52,5629 N 148,26,26,8453 70,20,52,5372 N 148,26,24,9684 70,20,52,5115 N 148,26,23,0916 70,20,52,4858 N 148,26,21,2148 70,20,52,4601 N 148.26,19.3380 70,20,52,4344 N 148,26,17.4612 70,20,52,4087 N 148,26,15,5844 70,20,52,3830 N 148.26,13,7076 70,20,52,3572 N 148,26,11,8308 70,20,52,3315 N 148,26,09.9540 70,20,52,3058 N 148,26,08.0772 70,20,52.2801 N 148,26,06,2004 70,20,52,2544 N 148,26,04,3236 70,20,52.2287 N 148,26,02.4468 70120,52.2030 N 148.26,00,5700 70,20,52,1773 N 148.25,58,6932 70,20.52.1515 N 148.25,56.8163 70.20,52,1258 N 148.25,54,9395 70,20.52,1001 N 148,25,53,0627 70,20.52.0744 N 148,25,51,1859 70,20,52,0487 N 148.25,49,3091 70,20.52,0230 N 148,25,47,4323 70.20.51,9973 N 148,25,45,5556 70.20,51,9716 N 148,25,43,6788 70.20,51,9459 N 148.25,41,8020 70,20,51,9268 N 148,25,40,4114 70,20,51,9251 N 148,25,40,2889 70.20,51,9201 N 148,25.39,9252 70,20,51,8944 N 148,25,38,0484 70,20,51,8687 N 148,25,36,1716 70,20,51,8567 N 148,25,35,2910 70,20,51,8309 N 148,25.33.4142 70,20,51,8052 N 148,25,31,5374 GRID Coordinates Northing Easting (ft) (ft) Closure Dist. Dir. (ft) deg. 5979298,63 691668.55 2791,43 5979297,66 691732,82 2855.71 5979296,69 691797,09 29'19,99 92,33 92,33 92,33 5979295,72 5979294,75 5979293,78 691861,36 2984,27 691925,63 3048,55 691989.90 3112.83 92,33 92,33 92,33 5979292,81 5979291,84 5979290,88 692054,17 3177,10 692118,44 3241,38 692182,71 3305,66 92.33 92.33 92.33 5979289,91 5979288,95 5979287,98 692246,98 3369,94 692311,25 3434,22 692375,52 3498,50 92.33 92.33 92.33 5979287,02 5979286,05 5979285,09 692439,79 3562,78 692504,06 3627,06 692568,33 3691,34 a 92.33 a 92.33 @ 92.33 5979284,13 5979283,16 5979282,20 692632,60 3755,61 692696,87 3819,89 692761,14 3884,17 92,33 92.33 92,33 5979281,24 692825,41 3948,45 5979280,28 692889,68 4012,73 5979279,32 692953,95 4077,01 @ 92.33 @ 92.33 a 92.33 5979278,36 693018,22 4141,29 5979277,40 693082,49 4205,57 5979276,44 693146,76 4269,84 92.33 92.33 92.33 5979275,49 693211,03 5979274,53 693275.30 5979273,57 693339,57 4334,12 @ 92,33 4398,40 @ 92,33 4462,68 @ 92,33 5979272,61 693403,84 4526.96 @ 92,33 5979271,66 693468,11 4591,24 @ 92,33 5979270,70 693532,38 4655,52 @ 92,33 5979269,75 693596,65 4719,80 @ 92,33 5979269,04 693644,27 4767,42 @ 92,33 5979268,98 693648,47 4771,62 @ 92,33 5979268,80 693660,92 4784,07 @ 92,33 5979267,84 693725,19 4848,35 @ 92,33 5979266,89 693789,46 4912,63 @ 92,33 5979266,44 693819,62 4942,79 @ 92,33 5979265,49 693883,89 5007,07 @ 92,33 5979264,54 693948,16 5071,35 @ 92,33 Verticat Section (ft) 2791,43 2855,71 2919,99 2984,27 3048,55 3112,83 3177,10 3241,38 3305,66 3369,94 3434,22 3498.50 3562,78 3627,06 3691,34 3755,61 3819.89 3884,17 3948,45 4012,73 4077,01 4141,29 4205,57 4269,84 4334,12 4398,40 4462,68 4526,96 4591,24 4655,52 4719,80 4767,42 4771,62 4784,07 4848,35 4912,63 4942,79 5007,07 5071,35 DLS Subsea Depth (dg/lOOft) (ft) 0,00 5674,11 0,00 5750,71 0,00 5827,3Z 0.00 5903,92 0,00 5980,53 0,00 6057.13 0.00 6133,74 0.00 6210,34 0,00 6286,95 0,00 6363,55 0,00 6440,15 0,00 6516,76 0,00 6593,36 0,00 6669,97 0,00 6746,57 0,00 6823,18 0,00 6899,78 0,00 6976,39 0,00 7052,99 0,00 7129,59 0,00 7206,20 0,00 7282,80 0,00 7359,41 0.00 7436,01 0,00 7512,62 0,00 7589,22 0,00 7665,83 0.00 7742,43 0,00 7819,03 0.00 7895,64 0,00 7972,24 0.00 8029,00 0,00 8034,00 0,00 8048.85 0,00 8125,45 0,00 8202,06 0.00 8238.00 0.00 8314,60 0.00 8391,21 Smith International, Inc. Proposal Report Page 4 Date: 11/18/92 ~ettpath ID: AGI-O2UP Measured Inc[ Drift TVD Depth Dir. (ft) (deg.) (deg.) (ft) KAVIK 10264.33 40.00 92.33 8489.00 10300.63 40.00 92.33 8516.81 TOTAL DEPTH 10329.60 40.00 92.33 8539.00 TOTAL Rectangutar Offsets (ft) (ft) 207.92 S 5108.06 E 208.87 S 5131.38 E 209.63 S 5149.98 E Geographic Coordinates Latitude / 'Longitude 70.20.51.7889 N 148.25.30.3420 70.20.51.7795 N 148.25.29.6606 70.20.51.7721 N 148.25.29.1170 GRID Coordinates Northing Easting (ft) (ft) 5979263.93 693989.09 5979263.59 694012.43 5979263.31 694031.04 Ctosure Dist. Dir. (ft) deg. 5112.29 @ 92.33 5135.63 @ 92.33 5154.24 @ 92.33 Vertica[ DLS Subsea Section Depth (ft) (dg/lOOft) (ft) 5112.29 5135.63 5154.24 0.00 8440.00 0.00 8467.81 0.00 849O.OO Prudhoe Bay Drillins Prudhoe Day WELL' #AGI-02 File'AGI- 02WP , 1000t 0.00' ~ 1000 MD 0.00' ~ 1354 MD START OF BUILD 3UILD RATE, 2.00 DEG/IO0 FT 2.00' ~ 1454 MD 4.00' ~ 1554 MD 6.00' ~ 1634 MD $.00' ~ 1754 MD 10 00' @ 1854 MD 12 00' @ 1954 MD 14 00' @ 2054 MD 16,00' ~ El54 MD 18.00' ~ 2254 MD 20.00' @ 2354 MD 22,00' ~ 2454 MD 24.00' ~ 2554 MD 26.00' ~ 2654 MD 28.00' @ 2754 MD 30.00' @ 2@54 MD 32.00' ~ 2954 MB 34.00' ~ 3054 MD 36.00' ~ 3154 MD 670 HORIZONTAL SCALE 5 0 0 REFERENCE: 926 I I 40.00' 8 3354 MD END DFOBUtLD500 1000 VIEW ?±, / WELL DIVISION HEAD 40.00' @ 3752 MD 13-3/8' CASING P0tNT 13.375 OD, @ 3752 MD,'3500 TVD 9.625 OD. e 9728 MD, 8078 fVB 1500 2000 2500 3000 3500 4000 4500 5000 5500 iO0 000 6000 Tt£ IN CRITICAL POINT DATA Az. TVD No,-t~ Ea~ 0 0.00 0.00 0 ISTART OF BUILD 13540.00 0.00 1354 0 0 lEND OF 3UILD 3354 40.00 92.33 3]95 -27 670 113-3/8' CSG PT 375240.00 92.33 3500 -38 925 19-5/8' CSG PT 9728 40.00 9~.33 8078 -194 4763 IT05 9734 40.00 92.33 8083 -194 4768 ITARGET lOOOt40.00 92,33 8287 -201 4939 [KAVlK 1026440.00 92.33 8489 -208 5108 ITOTAL DEPTH 10330 40.00 92.33 8539 -~1o 515o BHL DATA ] TVD 8539.0q MO103~9.6q VS5154.2~ North -209.6~ Eo~t 5149.9~ VERTICAL VIEW SCALE 500 FL, / REFERENCE: WELL SURFACE LOCATION. 1701' FSL, 2411' FEL, SEC. 36, TIBN. RLAE, UM[AT MERIDIAN TARGET LOCATION. 1500' FSL, 2350' FEL, SEC. 31, TI2N, RISE, UMtAT MERIDIAN DIVISION HEAD 4767 4772 4943 51t2 5154 ]~OITDM HOLE LOCATION, 149l ' FSL, 2139' FEL, SEC. 3[, TIgN, R15Co UN[AT MERIAD[AN 9.625 OD, @ 97P8 MD, 8078 TVD ~ 40.00' ~ 10330 MD TOTAL DEPTH 500 1000 1500 2000 2500 3000 3500 VERTICAL SECTION PLANE: 92,33° I I I I 4000 4500 5000 5500 Pp udlnoe So, y ]9~'i~i n 9 P~ uollnoe ]}ay WELL: 8AGI-OS Tpavettin9 Cytindep - Nominal ReCepence WeLL - A5I-O3WP TVD 0 - 8539 ¢~, ALL Plane 5O Ft, Dimec~ion s I~eL ~o Tmue Nop ~h SMITHI 870° 240° 210o 4'~0 400 3~ 3OO 25O 2OO 150° 120° 180° 0 0 -27 670 -38 glo5 - t 94 4763 -I 94 4768 -L:~)I 4g"J9 -L:~3 StOB -210 5150 LG]-08 CLDSEST F~NTS Slot ])stance l)~ection I?e~' MD Re£ TVD 301.79 109.64 7145.71 6100.00 Smith International, inT..r,avelling Cylinder Report Computed by the Sii Win-CADDS System Normal Plane Method Page 1 Date: 11/18/92 REFERENCE WELL: Prudhoe Bay DriLLing Prudhoe Bay AG! AGI-02 AGI-02 TVD, N/S and E/W are measured from the WELLHEAD WeL[path SLot Distance [101 L1-01 4816.52 1102 L1-02 4788.87 L109 L1-09 4576.82 [110 L1-10 4549.43 [114 L1-14 3097.21 [115 L1-15 4397.26 [121 L1-21 4217.89 [127 L1-27 3383.55 [128 L1-28 2986.08 1130 L1-30 1578.55 Closest Points Direction 184.96 182.86 184.96 182.76 171.39 184.95 184.95 237.24 146.79 158.54 Ref MD 50.00 100.00 300.00 200.00 10278.68 0.00 0.00 5448.68 8124.76 10278.68 Ref TVD 50.00 100.00 300.00 200.00 8500.00 0.00 0.00 4800.00 6850.00 8500.00 Smith International, J nT~r. avelling. Cylinder Report Computed by the Sii Win-CADDS System Normal Plane Method Date: Page 1 11/18/92 REFERENCE WELL: Prudhoe Bay Drilling Prudhoe Bay AGI AGI-02 AGI-02 TVD, N/$ and E/W are measured from the WELLHEAD Wellpath Slot Distance Closest Points ngil NGI-01 8085.04 ngi2 NGI-02 7879.48 ngi3 NGI-03 7867.25 ngi4 NGI-04 4969.14 ngi5 NGI-05 6464.90 ngi6 NGI-06 7542.98 ngi7 NGI-07 7434.92 ngi8 NGI-08 7328.65 ngi9 NGI-09 7221.44 ngilO NGI-IO 5907.92 ngi11 NGI-11 6383.94 ngi12 NGI-12 6904.40 ngi13 NGI-13 6799.61 ngi14 NGI-14 5340.92 Direction 192.29 187.53 193.02 195.05 209.18 194.18 194.59 195.00 195.43 235.38 224.34 196.81 197.29 221.15 Ref MD 50.00 7210.98 50.00 9430.17 7602.60 50.00 1400.00 700.00 50.00 5970.84 3295.25 700.00 5O.OO 6819.36 Ref TVD 50.00 6150.00 50.00 7850.00 6450.00 50.00 1400.00 700.00 50.00 5200.00 3150.00 700.OO 50.00 5850.OO Smith International, [nT-.r.aveiling Cylinder Report Computed by the Sii Win-CADDS System Normal Plane Method Page 1 Date: 11/18/92 REFERENCE WELL: Prudhoe Bay Drilling Prudhoe Bay AG[ AG[ -02 AG[ -02 TVD, N/S and E/W are measured from the WELLHEAD Wel[path Slot Distance Closest Points wbeach01 WBCH01 3125.60 wbeachla WBCH01 3414.75 wbch03 WBCH03 3747.92 wbchO3a WBCH03 3747.92 wbchO3b WBCH03 3746.42 Direction 342.06 345.83 346.52 346.52 346.52 Ref MD 10278.68 8385.84 1400.00 1400.00 1200.00 Ref TVI) 8500.00 7050.00 1400.00 1400.00 1200.00 Smith International, lnT..r, avelling Cylinder Report Computed by the S# Win-CADDS System Page 1 Date: 11/18/92 Normal Plane Method REFERENCE WELL: Prudhoe Bay Drilling Prudhoe Bay AG! AGI-02 AGI-02 TVD, N/S and E/W are measured from the gELLHEAD ~ellpath Slot wgil WGI-01 wgi2 WGI-02 wgi3 WGI-03 wgi4 WGI-04 wgi5 ~GI-05 wgi6 WGI-06 wgi7 WG[-07 wgi8 WGI-08 Closest Points Distance Direction Ref MD Ref TVD 8306.55 209.36 50.00 50.00 8397.17 208.82 50.00 50.00 7445.26 229.67 5252.87 4650.00 7259.58 214.09 5122.33 4550.00 8953.92 205.80 100.00 100.00 8672.92 207.26 0.00 0.00 87~.28 206.7-/ 0.00 0.00 8860.28 206.28 0.00 0.00 Smith International, lnT.-r,avelling Cylinder Report Computed by the Sii Win-CADDS System Normal Plane Method Page 1 Date: 11/18/92 REFERENCE WELL: Prudhoe Bay Dritling Prudhoe Bay AGI-02 AGI-02 TVD, N/S and E/U are measured from the WELLHEAD ~e[[path Slot 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 1797.06 217.37 7472.06 6350.00 3104.18 165.61 100.00 100.00 1489.44 121.94 7080.44 6050.00 301.79 109.64 7145.71 6100.00 934.23 100.94 5448.68 4800.00 799.74 249.76 7015.17 6000.00 I ,uD PROGRAM: Well AGI #2 The mud program for this well shall follow the new Mud Policy. The following are the recommended mud parameters. MUD SPECIFICATIONS- SURFACE HOLE Surface: Casino point: v - Mud Weight: ppg 8.5 - 9.5 8.5 - 9.0 Funnel Viscosity sec/qt ~300 < 1 O0 YP Ibs/100ft2 40- 60 20 - 40 10 sec Gel lbs/100ft2 30 - 60 15 - 20 10 min Gel lbs/100ft2 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/100ft2 10 - 15 10 sec Gel lbs/100ft2 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/100ft2 10 - 20 10 sec Gel lbs/100ft2 5 - 10 10 min Gel lbs/100ft2 15 - 25 APl Fluid loss mi/30 min 6.0 - 8.0 pH -- 9.5 - 10.0 Hardness mg/Itr < 200 The mud salinity should be compatible with the Reservoir logging program. The mud should be run at 10,000- 20,000 ppm chlorides. AGI #Z Casing Design SURFACE CASING 13-3/8" 68#/FT K-55 & L-80 BTC CASING BURST COLLAPSE PBYS (#) K-55 3450 1950 1069000 L-80 5020 2260 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 2900 1433 Collapse S,F. 1.58 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) Mud Wt. 68 3752 9.5 ppg PBYS TJYS Tension S.F. 4,90 5,96 String Wt. (#) 21809O AGI #Z Casing Design Production Casing 9-5/8", 47#,L-80,NSCC Casing GRADE BURST COLLAPSE PBYS (#) L-80 6870 4750 1086000 TJYS (#) 1161 000 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 2970 Burst S.F. 2.31 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/~ Collapse press 10.2 8078 0.1 3477 Collapse S,F, 1,37 Tension Calculation Based on full string weight in mud Casg Wt. (#Iff) MD (FT) Mud Wt. 47 9728 10.2 PBYS TJYS Tension S.F. 2,81 3.01 String Wt. (#) 385936 AGI #Z Casing Design PRODUCTION LINER 7", 26#,L-80,NSCC Casing GRADE BURST COLLAPSE PBYS (#) L-80 7240 5410 604000 TJYS (#) 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 3062 2970 Burst S,F, 2,36 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 8539 0.1 3675 Collapse S.F. 1.47 Tension Calculation Based on full string weight in mud Casg Wt. (#Iff) MD (FT) 26 779 IVlud Wt. String Wt. (#) 10.2 17096 Tension S,F. PBYS TJYS 35.33 39.01 SUF .... C[.'~'OL,,- DIVERTER SYSTEM .. .... Two lines venting 90 deg. apart in directions that ensure sale down wind venling, and ex- ~ ,.-:... r -.. tending to a poinl at least 100' from any potential source o[ ignilion. 10' Full Opening Valves 35' or 2s required Dresser Sleeve 10' Diveder Line 1. All pipe connections 150¢ ANSI Flanges or welded connedbns and secured to prevent movemenL 2_ Manual 10" lull opening valves mechanically conned, ed to ensure that one valve is lail-sale open at all limes. 3. All lums ;~re g0 deg. and targeted. 10' Full opening ball valve w/Hydraulic Actuator Cell,~r 20' Diverter Spool w/10' Side MEM 1/"3~ 0 - 5UCTrON ]'8 k~ O 1 - 200 gpm Operating Capacity. Centrifuge 15 - Brandt ~-LA5 Hud Ft[x AgJ. hators 1- 150 bbl. Tr].p TaDk 1 - ~ecording drilling fluid pit level indicator with boU] visual and audio w~rning.devices at driller's console , OR,()]DF . ,. I::)d,rxL . IlI]D ~o 1., bri'llb~9 fluid fl~..] sen~or wil']] readouh at drill[/X~.,,s console ~. AUDI #2 13 $/8" 5,000 psi Stack 2.00 4.12 12.72 4.50 3.01 3.01 1 .$3 3.01 2.52 RKB 1 [ I DRIP PAN HYDRIL R G FLOOR PIPE RAM BLIND RAM CROSS PIPE RAM 17.88 J MUD CROSS 22.38 25~- .~... 3O.23 34.25 35.75 1.5 GROUND LEVEL ASE FLG / ITeM (1) Fee (2) Loc 'Il (3) Adm i n L :~L, (5) BOP~E ~ ~-~r~ ~/' (6) Othe_____~r _ iqt: [29 t~ru 3~' ~eology: engineerin( DWj ~ - rev 08/18/92 3o/6.011 I f 5D BSL · ~.J ( 1 - Brandt ~1 Tand~ Sidle Sh~er 1 - ~,~ 6-12" ~ne Shale ~s~der 1- ~~ 416ll w/16 ~nes & (1) ~ 481[ w/16 ~nes (~silter) 1 - Dril~ A~spheric Mud ~gasser 1 - 200 gpm Operating Capacity. Centrifuge 15 - Brandh ~5 Hud Mix Agitators 1- 150 bbl. Trip Ta.nk 1 - Recording drilling fluid pit level indicator with boU] visual and audio warning ,.devices at driller's console ~,, , DE.Co · - r^)JC Z 1,-Drilling fluid flo,-] sensor with readout at drill%~.'0s console 0 Well History File APPENDIX Information of detailed nature that is not padiculady 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 AGI-2 PRUDHOE BAY ATCM ATDC CADE CPDE DCCM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM Note: BELOW ARE THE MNEMONICS THAT CAN BE FOUND ON THE LIS TAPE GENERATED FOR ARCO ALASKA AGI-2 Attenuation Borehole Corrected [RWD] Attenuation Dielectric Corrected [RWD] Conductivity (AT) Dielectric Corrected [RWD] Conductivity (PD) Dielectric Corrected [RWD] Calculated Dielectric Constant Gamma Ray MEMORY (APl) [RWD] Phase Difference Borehole Corrected [RWD] Phase Difference Dielectric Corrected [RWD] Phase Difference Elapsed Time [RWD] Resistivity (AT) Borehole Corrected [RWD] Resistivity (AT) Corrected for Dielectric Effect [RWD] Rate of Penetration Averaged Rate of Penetration Resistivity (PD) Borehole Corrected [RWD] Resistivity (PD) Corrected for Dielectric Effect [RWD] CDS Temperature [RWD] -dB -dB mmho/m mmho/m MWD-API deg deg mins ohm-m ohm-m fi/hr fi/hr ohm-m ohm-m deg F AT is Attenuation PD is Phase Difference RWD is Recorded While Drilling Copyright 1987,1988,1989,1990,1991 By WESTERN ATLAS INTERNATIONAL, INC. All rights reserved. PROGRAM: TAPESCAN REVISION: 2.64 Start of execution: Tue 14 SEP 93 11:36a != = ECHOING INPUT PARAMETERS INPUT PARAMETER FILE: TAPESCAN.INP 1 2 3 4 5 6 7 12345678901234567890123456789012345678901234567~1234~7~1234567~12 1 AUTOCURV = 0., ! Automatic Curve renaming: O=OFF, I=ON 2 AUTOFILE = 0 , ! Automatic FILE= generation: O=OFF, I=ON 3 COMMENTS = 1 , ! Decode LIS Comment records: O=OFF, I=ON 4 INFORECS = 1 , ! Decode LIS Information records: O=NO, I=YES 5 LISTMETHOD = 0 , ! Listing Method: O=depth units 1=tape units 6 LISTFREQ = 50, ! Listing Frequency: Every n units 7 LISTMAX = 0 , ! Listing Maximum (O=no limit, value=list limit) 8 STATS = 0 , ! Statistics generation: 0 =OFF, 1 =ON 9 FORCETYP = 0 , ! (I=BIT,2=LIS ... thru 35=Array Accoustic) (see table) 10 WRITEASCII = 0 , ! If 1, all ascii files will be written (fileOOOl.dat,etc.) 11 WRITETAP = 1 , ! WriteTape-lmage File: O=NO, I=YES 12 SPLITLIS = 1 , ! If 1 and WRITETAP on, split LIS logical files to physical 13 SUBFILES = /0/, ! Tape Subtile write selection (WRITETAP must be on) 14 INTERPOLATE='YES' ! Set up for TAPE2WDS to interpolate datums ('YES'or'NO') 15 END != = USER INPUT PARAMETERS AUTOCURV = 0 , AUTOFILE = 0 , COMMENTS = 1 , INFORECS = 1 , LISTMETHOD = 0 , LISTFREQ = 50, LISTMAX = O, STATS = O, FORCETYP = 0 , WRITEASCII = 0 , WRITETAP = 1 , SPLITLIS = 1 , SUBFILES /0/, INTERPOLATE = 'YES' END !-- PROCESSING INTERVAL FROM 0.000 TO I.. CONSTANT PARAMETERS SUBFILES(93) = -9999.00 SUBFILES(95) = -9989.00 SUBFILES(97) = -9999.00 SUBFILES(99) = -9999.00 SUBFILES(101) = -9999.00 SUBFILES(103) = -9999.00 SUBFILES(105) = -9999.00 SUBFILES(107) = ~9999.00 SUBFILES(109) = -9999.00 SUBFILES(111) = -9999.00 SUBFILES(113) = -9999.00 SUBFILES(115) = -9999.00 SUBFILES(117) = -9999.00 SUBFILES(119) = -9999.00 SUBFILES(121) = -99cJ9.00 SUBFILES(123) = -9999,00 SUBFILES(125) = -9999.00 SUBFILES(127) = -9999.00 SUBFILES(94) SUBFILES(96) SUBFILES(98) SUBFILES(IO0) SUBFILES(102) SUBFILES(104) SUBFILES(106) SUBFILES(108) SUBFILES(110) SUBFILES(112) SUBFILES(114) SUBFILES(116) SUBFILES(118) SUBFILES(120) SUBFILES(122) SUBFILES(124) SUBFILES(126) SUBFILES(128) -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 -9999.00 !-- STRING PARAMETERS INTERPOL= YES Tape Subfile I is type: LIS **** REEL HEADER **** MWD 93/9/14 1156 01 **** TAPE HEADER **** MWD 93/9/14 1156 01 Tape Subtile: 1 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes LIS COMMENT RECORD(s): 1234567890123456789012345678,9012345678,901234567890123456789012345678901234567893 FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and dipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH MWD 8691.0 10215.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) .... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD MWD MWD MWD MWD $ REMARKS: $ CN WN FN COUN STAT 4 8691.0 8831.0 4 8831.0 9622.0 5 9622.0 9793.0 6 9793.O 9854.O 7 9854.0 10215.0 · Arco Alaska Inc. · AGI-2 · Prudhoe Bay · North Slope · Alaska LIS COMMENT RECORD(s)' 123456789012345678,9012345678901234567890123456789012345678,9012345678901234567890 THIS FILE CONTAINS EDITED MERGED MWD 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 1 0000000 1 000 1 Rep C(x~e Count Bytes ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 GR MWD 68 1 GAPI 4 4 98 660 71 6 2 RA MWD 68 1 OHMM 4 4 98660 71 6 3 ROP MWD 68 I FPHR 4 4 98 660 71 6 4 RP MWD 68 1 OHMM 4 4 98660 71 6 16 Tape Subfile 3 is type: LIS **** FILE HEADER **** MWD .002 1024 LIS COMMENT RECORD(s)' 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 2 RAW MWD Curves and Icg header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 8691.0 8831.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (Fr): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ STOP DEPTH 08 DEC 92 M1.33 M1.33 MEMORY 0.0 8691.0 8831.0 0 33.4 34.4 TOOL NUMBER 763-51 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 0.0 BOREHOLE CONDITIONS MUD TYPE: DISPERSED MUD DENSITY (LB/G): 9.90 MUD VISCOSITY (S): 50.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 1300 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units 1 ATOM MWD 68 1 -dB 2 ATDC MWD 68 1 -dB 3 CADE MWD 68 I MMHO 4 CPDE MWD 68 1 MMHO 5 DCCM MWD 68 1 6 GRAM MWD 68 1 GAPI 7 PDCM MWD 68 1 DEG 8 PDDC MWD 68 1 DEG 9 PDEM MWD 68 1 MINS 10 RACM MWD 68 1 OHMM 11 RADEMWD 68 1 OHMM 12 ROPA MWD 68 I FPHR 13 ROPSMWD 68 1 FPHR 14 RPCMMWD 68 1 OHMM 15 RPDEMWD 68 1 OHMM 16 TCDMMWD 68 1 DEGF APl APl APl APl Log Crv Crv Size Length Typ Typ CIs Mod 4 498660 71 6 4 4 98660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 4 98660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 Tape Subtile 4 is type: US **** FILE HEADER **** MWD .003 1024 LIS COMMENT RECORD(s): 123456789~123456789~123456789~123456789~123456789~123456789~123456789~123456789~ FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 8831.0 9622.O $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (1~!'): BoTroM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (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): 09 DEC 92 M1.33 M1.33 MEMORY BOREHOLE CONDITIONS MUD TYPE: DISPERSED MUD DENSITY (LB/G): 10.00 MUD VISCOSITY (S): 47.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 850 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 8831.0 9622.0 0 28.8 32.8 TOOL NUMBER 763-51 12,250 0.0 STOP DEPTH 0.0 ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 ATCM 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 DCCM MWD 68 1 4 6 GRAM MWD 68 1 GAPI 4 7 PDCM MWD 68 1 DEG 4 8 PDDC MWD 68 1 DEG 4 9 PDEM MWD 68 I MINS 4 10 RACM MWD 68 1 OHMM 4 11 RADEMWD 68 1 OHMM 4 12 ROPA MWD 68 1 FPHR 4 13 ROPS MWD 68 1 FPHR 4 14 RPCMMWD 68 1 OHMM 4 15 RPDEMWD 68 1 OHMM 4 16 TCDMMWD 68 1 DEGF 4 498660 71 6 4 98660 71 6 468660 71 6 498660 71 6 49866O 71 6 498660 71 6 4 98660 71 6 498660 71 6 498660 71 6 49866O 71 6 49866O 71 6 498660 71 6 498660 71 6 498660 71 6 4 98660 71' 6 498660 71 6 Tape Subtile 5 is type: LIS **** FILE HEADER **** MWD .004 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: 5 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 9622.0 9793.0 $ 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): BO'I-rOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12 DEC 92 M1.33 M1,33 MEMORY 0.0 9622.0 9793.0 0 27.8 28.8 TOOL STRING (TOP TO BO'I=I'OM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ TOOL NUMBER 1676-10 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 0.0 BOREHOLE CONDITIONS MUD TYPE: LDISP/KCI MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 61.0 MUD PH: 8.4 MUD CHLORIDES (PPM): 8800 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units 1 ATCM MWD 68 1 -dB 2 ATDC MWD 68 1 -dB 3 CADE MWD 68 1 MMHO 4 CPDE MWD 68 1 MMHO 5 DCCM MWD 68 1 6 GRAM MWD 68 1 GAPI 7 PDCM MWD 68 1 DEG 8 PDDC MWD 68 1 DEG 9 PDEM MWD 68 I MINS 10 RACM MWD 68 1 OHMM 11 RADEMWD 68 1 OHMM 12 ROPAMWD 68 1 FPHR 13 ROPSMWD 68 1 FPHR 14 RPCMMWD 68 1 OHMM 15 RPDEMWD 68 1 OHMM 16 TCDMMWD 68 1 DEGF APl APl APl APl Log Crv Crv Size Length Typ Typ CIs Mod 4 4 98660 71 6 4 4 98660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 49866O 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 Tape Subtile 6 is type: LIS **** FILE HEADER **** MWD .005 1 O24 LIS COMMENT RECORD(s): 12345678931234567893123456789012345678.901234567890123456789012345678.901234567890 FILE HEADER FILE NUMBER: 5 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 MWD 9793.0 9854.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING CrOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ STOP DEPTH 13 DEC 92 M1.33 M1.33 MEMORY 0.0 9793.0 9854.0 0 27.1 27.8 TOOL NUMBER 1676-10 BOREHOLE CONDITIONS MUD TYPE: KCI MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 62.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 10000 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 0.0 ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 ATCM 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 DCCM MWD 68 1 4 6 GRAM MWD 68 1 GAPI 4 7 PDCM MWD 68 1 DEG 4 8 PDDC MWD 68 1 DEG 4 9 PDEM MWD 68 1 MINS 4 10 RACMMWD 68 1 OHMM 4 11 RADEMWD 68 1 OHMM 4 12 ROPAMWD 68 1 FPHR 4 13 ROPSMWD 68 1 FPHR 4 14 RPCMMWD 68 1 OHMM 4 15 FIPDE MWD 68 1 OHMM 4 16 TCDMMWD 68 1 DEGF 4 49866O 71 6 498660 71 6 498660 71 6 498660 71 6 49866O 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 Tape Subtile 7 is type: LIS **** FILE HEADER **** MWD .006 1024 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: 7 DEPTH INCREMENT: 0.2500 # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 9854.0 10215.0 $ 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 INCUNATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ STOP DEPTH 14 DEC 92 M1.33 M1.33 MEMORY 0.0 9854.0 10215.0 0 23.3 27.1 TOOL NUMBER 2628-05 BOREHOLE CONDITIONS MUD TYPE: KCI MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 43.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 10000 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT)' 0.0 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 ATCM MWD 68 1 -dB 2 ATDC MWD 68 1 -dB 3 CADE MWD 68 1 MMHO 4 CPDE MWD 68 1 MMHO 5 DCCM MWD 68 1 6 GRAM MWD 68 1 GAPI 7 PDCM MWD 68 1 DEG 8 PDDC MWD 68 1 DEG 9 PDEM MWD 68 1 MINS 10 RACM MWD 68 1 OHMM 11 RADEMWD 68 1 OHMM 12 ROPA MWD 68 1 FPHR 13 ROPSMWD 68 1 FPHR 14 RPCMMWD 68 1 OHMM 15 RPDE MWD 68 1 OHMM 16 TCDMMWD 68 1 DEGF 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 49866O 71 6 4 498660 71 6 4 498660 71 6 4 49866O 71 6 4 49866O 71 6 4 498660 71 6 4 498660 71 6 Tape Subfile 8 is type: LIS **** TAPE TRAILER **** MWD 93/9/14 1156 01 **** REEL TRAILER **** MWD 93/9/14 1156 01 Tape Subfile: 8 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 14 SEP 93 11:37a Elapsed execution time = 41.63 seconds. SYSTEM RETURN CODE = 0 Tape Subfile I is type: LIS Tape Subfile 2 is type: LIS DEPTH GR 8691.0000 -999.2500 -999.2500 8691.5000 107.2148 -999.2500 8700.0000 91.1188 4.2316 8750,0000 95.5141 4,2593 8800,0000 103.3540 4.7978 8850,0000 101.7498 4.6911 8900.0000 88.7828 5.9250 8950.0000 103.0114 5.2494 9000.0000 90.8376 6,7417 9050.0000 95.8511 5.8390 9100.0000 98.5553 6.4868 9150.0000 115.8293 4.7589 9200.0000 154.8820 6.2457 9250.0000 92.4038 7.3499 9300. 0000 137. 0200 8. 7858 9350.0000 135.9911 5.3393 9400.0000 94.2991 5.8824 9450.0000 146.7342 4.1111 9500.0000 173.4852 5.0471 9550.0000 170.0966 5.5915 9600.0000 184.5213 6.7616 9650.0000 151.8390 -999.2500 9700.0000 751.2115 25.5139 9750.0000 54.3942 -999.2500 9800.0000 17.6253 -999.2500 9850.0000 20.3053 -999.2500 9900.0000 21.1600 56.2008 9950.0000 88.6566 8.1323 10000.0000 37.8413 13.9454 10050.0000 49.2315 15.2036 10100.0000 53.5010 18.1610 10150.0000 130.2384 10.6271 10200.0000 -999.2500 -999.2500 10215.0000 -999.2500 -999.2500 Tape File Start Depth = 8691.000000 Tape File End Depth = 10215.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet ROP -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 62.1228 69.4879 63.2836 24.8781 56.1583 62.0208 56.2521 63.1398 36.5349 67.8168 62.0696 96.3713 114.3188 118.4959 83.2298 122.0703 93.2601 41.5821 23.7845 26.9273 58.1287 23.4634 82.1812 34.9562 53.0741 52.8507 14.7662 13.4639 RP -999.2500 -999.2500 4.4974 4.8131 5.2085 5.3478 6.6354 6.1857 7.7029 6.1338 7.1760 5.1559 5.1254 10.3869 8.2882 4.6177 6.2842 4.4785 5.1985 5.1659 6.0150 -999.2500 20.3607 93.6245 41.4823 109.8420 78.9415 7.6100 25.2002 31.5199 37.5846 7.8209 -999.2500 -999.2500 Tape Subfile 3 is type: LIS DEPTH ATCM ATDC CADE CPDE DCCM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 8691.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8691.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8700.0000 0.8562 0.9118 236.3153 222.3489 110.3204 91.1188 11.1796 10.9033 -999.2500 4.5475 4.2316 -999.2500 -999.2500 4.3225 4.4974 -999.2500 8750.0000 0.8527 0.9066 234.7781 207.7672 106.9147 95.5141 10.7136 10.4399 -999.2500 4.5693 4.2593 -999.2500 -999.2500 4.6210 4.8131 118.5125 8800.0000 0.7622 0.8172 208.4279 191.9942 103.0508 103.3540 10.1913 9.9208 -999.2500 5.1919 4.7978 -999.2500 -999.2500 4.9987 5.2085 117.5716 8831.0000 -999.2500 -999.2500 196.6292 201.1494 103.3150 105.3717 5.2128 4.8754 -999.2500 5.0857 5.0857 -999.2500 -999.2500 4.9714 4.9714 120.4250 Tape File Start Depth = 8691.000000 Tape File End Depth = 8831.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subfile 4 is type: LIS DEPTH ATCM ATDC CADE CPDE DCCM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 8831.0000 -999.2500 -999.2500 196.6292 201.1494 103.3150 105.3717 5.2128 4.8754 -999.2500 5.0857 5.0857 -999.2500 -999.2500 4.9714 4.9714 120.4250 8831.2500 -999.2500 -999.2500 196.2984 200.4581 103.1487 104.1496 4.8256 4.4838 -999.2500 5.0943 5.0943 -999.2500 -999.2500 4.9886 4.9886 120.4250 8850.0000 0.7797 0.8335 213.1705 186.9911 101.8062 101.7498 10.0194 9.7520 -999.2500 5.0711 4.6911 -999.2500 -999.2500 5.1303 5.3478 113.9000 8900.0000 0.6222 0.6765 168.7760 150.7074 92.2052 88.7828 8.7152 8.4593 57.6833 6.4926 5.9250 53.4362 62.1228 6.3460 6.6354 120.6050 8950.0000 0.7015 0.7545 190.4995 161.6627 95.2154 103.0114 9.1230 8.8635 70.2000 5.6937 5.2494 66.7060 69.4879 5.9220 6.1657 109.8500 9000.0000 0.5470 0.6008 148.3300 129.8207 86.1366 90.8376 7.8968 7.6501 76.3500 7.4539 6.7417 54.9825 63.2836 7.3519 7.7029 113.7875 9050.0000 0.6296 0.6855 171.2619 163.0306 95.5856 95.8511 9.1728 8.9128 70.6333 6.4090 5.8390 43.8245 24.8781 5.8728 6.1338 116.8000 9100.0000 0.5680 0.6226 154.1587 139.3538 88.9778 98.5553 8.2787 8.0261 72.9167 7.1606 6.4868 46.6392 56.1583 6.8532 7.1760 120.4250 9150.0000 0.7679 0.8230 210.1325 193.9538 103.5420 115.8293 10.2557 9.9864 57.0000 5.1467 4.7589 62.0780 62.0208 4.9482 5.1559 121.8875 9200.0000 0.5820 0.6447 160.1092 195.1054 103.8246 154.8820 10.2943 10.0248 73.0492 6.9760 6.2457 56.2851 56.2521 4.9194 5.1254 123.3500 DEPTH ATCM ATDC CADE CPDE DCCM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 9250.0000 0.5054 0.5542 136.0568 96.2749 75.2669 92.4038 6.4486 6.2194 59.0823 8.1016 7.3499 65.5203 63.1398 9.8668 10.3869 125.3750 9300.0000 0.4091 0.4675 113.8206 120.6527 63.3283 137.0200 7.51 98 7.2768 59.2995 10.0747 8.7858 40.1941 36.5349 7.9004 8.2882 126.8938 9350.0000 0.6819 0.7431 187.2890 216.5562 108.9697 135.9911 10.9975 10.7210 58.1158 5.8737 5.3393 67.4601 67.8168 4.4373 4.6177 128.6375 9400.0000 0.6254 0.6809 169.9975 159.1299 94.5391 94.2991 9.0309 8.7712 46.2500 6.4554 5.8824 59.5584 62.0696 6.0135 6.2842 129.7625 9450.0000 0.8799 0.9348 243.2424 223.2911 110.5167 146.7342 11.2092 10.9328 43.2333 4.4092 4.1111 93.4560 96.3713 4.3062 4.4785 131.0375 9500.0000 0.7249 0.7814 198.1333 192.3636 103.1632 173.4852 10.2040 9.9332 90.5667 5.4891 5.0471 111.7206 114.3188 4.9871 5.1985 131.0000 9550.0000 0.6536 0.7129 178.8444 193.5777 103.4493 170.0966 10.2431 9.9738 40.0500 6.1532 5.5915 105.3922 118.4959 4.9577 5.1659 125.9214 9600.0000 0.5388 0.5991 147.8946 166.2497 96.4527 184.5213 9.2905 9.0288 39.9667 7.5733 6.7616 81.5510 63.2298 5.7600 6.0150 130.7375 9622.0000 0.3957 0.4507 109.5818 102.0983 77.2702 85.5673 6.7133 6.4815 32.6500 10.4224 9.1256 115.4477 118.1326 9.3146 9.7945 131.3375 Tape File Start Depth = 8831.000000 Tape File End Depth = 9622.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subfile 5 is type: LIS DEPTH ATCM ATDC CADE CPDE DCCM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 9622.0000 0.3957 0.4507 109.5818 102.0983 77.2702 85.5673 6.7133 6.4815 32.6500 10.4224 9.1256 115.4477 118.1326 9.3146 9.7945 131.3375 9622.2500 0.3917 0.4474 108.7523 104.1769 77.9778 84.7212 6.8070 6.5735 32.6500 10.5295 9.1952 115.4477 116.3427 9.1306 9.5991 131.3375 9650.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 151.8390 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 114.2641 122.0703 -999.2500 -999.2500 132.0969 9700.0000 0.0928 0.1521 39.1944 49.1142 56.3422 751.2115 3.9423 3.7582 41.5500 38.8720 25.5139 92.6198 93.2601 18.8354 20.3607 106.0250 9750.0000 -999.2500 -999.2500 -999.2500 10.6810 30.7915 54.3942 1.1395 1.0474 30.7500 -999.2500 -999.2500 50.5991 41.5821 81.1573 93.6245 107.6000 9793.0000 -999.2500 -999.2500 -999.2500 6.8885 26.3251 23.3773 0.7714 0.6984 115.0667 -999.2500 -999.2500 64.4343 64.4343 123.9250 145.1697 109.2875 Tape File Start Depth = 9622.000000 Tape File End Depth = 9793.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subfile 6 is type: LIS DEPTH ATOM ATDC CADE CPDE DOOM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 9793.0000 -999.2500 -999.2500 -999.2500 26.3251 23.3773 0.7714 0.6984 -999.2500 -999.2500 64.4343 64.4343 145.1697 109.2875 9793.2500 -999.2500 -999.2500 -999.2500 26.3069 22.9364 0.7700 0.6971 -999.2500 -999.2500 64.4343 64.4343 145.4739 109.2875 9800.0000 -999.2500 -999.2500 -999.2500 41.8312 17.6253 2.2607 2.1242 351.0325 -999.2500 24.4020 23.7645 41.4823 110.0188 9850.0000 -999.2500 -999.2500 -999.2500 29.0294 20.3053 0.9903 0.9055 -999.2500 -999.2500 26.4597 26.9273 109.6420 114.1250 6.8885 115.0667 123. 9250 6.8741 116.0750 124.1654 24.1066 139.9000 37.7351 9.1040 216.7333 94.8574 Tape File Start Depth = 9793.000000 Tape File End Depth = 9854.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet 9854.0000 2.0977 2.1052 -999.2500 7.5375 26.0552 18.4771 0.8333 0.7601 290.4666 -999.2500 -999.2500 20.3543 22.1946 127.5547 132.6693 114.8000 Tape Subtile 7 is type: LIS DEPTH ATOM ATDC CADE CPDE DOOM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 9854.0000 2.0977 2.1052 26,0552 18.4771 0.8333 -999.2500 -999.2500 20.3543 132.6693 114.8000 -999.25OO 0.7601 22.1946 7.5375 290.4666 127.5547 9854.2500 1.6911 1.6998 -999.2500 6.6106 26.0260 19.0433 0.7435 0.6717 417,6971 23.3493 -999.2500 20.3543 20.9678 127.9571 151.2727 114.8000 9900.0000 0.0177 0.0603 17.7933 12.6676 32,6817 21.1600 1.3207 1.2205 43.9333 212.6210 56.2008 60.0618 58.1287 69.5477 78.9415 116.9375 9950.0000 0.4403 0.4995 122.9667 131.4057 86.9045 68.6568 7.9253 7.6752 117.7333 12.0248 8.1323 21.9636 23.4634 7.2119 7.6100 118.5125 10000.0000 0.2482 0.2917 71.7083 39.6821 51.4871 37.8413 3.3523 3.1828 65.2167 16.1842 13.9454 80.5592 82.1812 23.1542 25.2002 123.8000 10050.0000 0.2257 0.2666 65.7740 31.726O 46.9133 49,2315 2.8162 2,6617 43.6500 22.7774 15.2036 44.3723 34.9562 28.7479 31.5199 128.0750 10100.0000 O. 1801 0.2208 55.0630 26.6066 43.6870 53.5010 2.4489 2.3053 52.4000 26.7784 18.1610 52.1409 53.0741 34.0539 37.5846 129.8750 10150.0000 0.3190 0.3845 94.0993 127.8624 85.8892 130.2384 7.7818 7.5332 155.9167 10.0700 10.6271 53.8392 52.8507 7.3979 7.8209 131.7875 10200.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14.2924 14.7662 -999.2500 -999.2500 135.7250 10215,0000 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13.4639 13.4639 -999.2500 -999,2500 136,7375 Tape File Start Depth = 9854.000000 Tape File End Depth = 10215.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subfile 8 is type: LIS
