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Home My WebLink About197-055MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 25, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 17-19A PRUDHOE BAY UNIT 17-19A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2025 17-19A 50-029-22297-01-00 197-055-0 N SPT 8652 1970550 2250 421 2505 2432 2408 140 394 391 388 OTHER P Kam StJohn 6/9/2025 CMIT- TxIA 2250 per CO. 736 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 17-19A Inspection Date: Tubing OA Packer Depth 416 2491 2421 2399IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS250609150227 BBL Pumped:3.3 BBL Returned:3.7 Friday, July 25, 2025 Page 1 of 1            IA remedial cement; 1-Oil producer MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 25, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 17-19A PRUDHOE BAY UNIT 17-19A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2025 17-19A 50-029-22297-01-00 197-055-0 N SPT 8652 1970550 2250 394 2512 2388 2351 135 145 146 147 OTHER P Kam StJohn 6/9/2025 MIT-T to 2250 per CO. 736 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 17-19A Inspection Date: Tubing OA Packer Depth 379 470 482 482IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS250609150009 BBL Pumped:1.6 BBL Returned:1.7 Friday, July 25, 2025 Page 1 of 1            IA remedial cement; 1-Oil producer MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 17-19A PRUDHOE BAY UNIT 17-19A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 17-19A 50-029-22297-01-00 197-055-0 N SPT 8652 1970550 2163 1430 2719 2669 2657 9 14 15 14 OTHER P Adam Earl 6/16/2023 CMIT-T&IA tested as per CO736 / Sundry 319-096 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 17-19A Inspection Date: Tubing OA Packer Depth 1424 2709 2659 2247IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230620115308 BBL Pumped:1.5 BBL Returned:1.5 Thursday, July 27, 2023 Page 1 of 1              1-Oil producer; IA remedial cement MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 3, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 17-19A PRUDHOE BAY UNIT 17-19A Jim Regg InspectorSrc: 17-19A N SPT 8652 1970550 2163 998 2712 2610 2576 4 5 5 5 Other (describe in notes)Pass MIT-T tested as per CO736 / Sundry 319-096 30 MinPretestInitial15 Min Type Test Notes: Interval P/F Well Type Inj TVD PTD Test psi Tubing OA Packer Depth 355 443 449 449IA 45 Min 60 Min 50-029-22297-01-00 197-055-0 Adam Earl 6/16/2023 Well Name Permit Number: API Well Number Inspector Name:PRUDHOE BAY UNIT 17-19A Inspection Date:Insp Num: Rel Insp Num: mitAGE230620114739 MITOP000009888 BBL Pumped:1.2 BBL Returned:1.2 Thursday, August 3, 2023 Page 1 of 1 5(9,6(' 9 9 9 9 9 99 9 2LOSURGXFHU,$UHPHGLDOFHPHQW UHYLVHGPLQ,$SUHVVXUH 449 MIT-T James B. Regg Digitally signed by James B. Regg Date: 2023.08.03 09:54:31 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday, July 7, 2021 P.I. Supervisor 7(/ 41 rtrz4 SUBJECT: Mechanical Integrity Tests 1 Hilcorp North Slope, LLC 17-19A FROM: Adam Earl PRUDHOE BAY UNIT 17-19A Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv�� NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 17-19A API Well Number 50-029-22297-01-00 Inspector Name: Adam Earl Permit Number: 197-055-0 Inspection Date: 6/23/2021 Insp Num: mitAGE210627182514 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 17-19A Type Inj Type Test 1TVD SPT..�,Test psi 8652 2163 'Tubing IA 639 j 454 2754- 564 2638 •, 2604 576 - 576 ' — PTD 1970550 BBL Pumped: 1.5 BBL Returned: 1.3 OA 0 ; 0 0 - 0. Interval L OTHER -- P/I+ P Notes: MIT -T Tested as per CO 736 to 2500psi Wednesday, July 7, 2021 Page 1 of I MEMORANDUM TO: Jim Regg \� e Zex -7/ (/d *74P.I. Supervisor FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 22, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 17-19A PRUDHOE BAY UNIT 17-19A Src: Inspector Reviewed By- P.I. Supry Comm Well Name PRUDHOE BAY UNIT 17-19A API Well Number 50-029-22297-01-00 Inspector Name: Bob Noble Insp Num' mitRCN210621092509 Permit Number: 197-055-0 Inspection Date: 6/20/2021 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min -- ell 17 19A Type Inj Type N VD 8130 - Tubing 1 W PTD, 1970550 T e Test SPT (Test psi 2033 IA BBL Pumped: 0 et p I Returned: 0 � OA j Inter - - - -- ✓I-- - Interval OTHER lP/F ' — — - _ _ - F Notes: MIT - T to 2500 psi as per Sundry 319-096. Unable to get a pressure test as the IA tracked with the tubing. Suspected the screened orifice wou n't close. Tuesday, June 22, 2021 Page I of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor � (I �� /�� FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 22, 2021 SUBJECT: Mechanical Integrity Tests Hilco p North Slope, LLC 17-19A PRUDHOE BAY UNIT 17-19A Src: Inspector Reviewed By: P. 1. Supry y� Comm Well Name PRUDHOE BAY UNIT 17-19A API Well Number 50-029-22297-01-00 Inspector Name: Bob Noble Permit Number: 197-055-0 Inspection Date: 6/20/2021 Insp Num: mitRCN210621091801 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 17-19A 'Type Inj N - TVD 8130 Tubing 69 2724 - 2646• 2617 ' PTD 1970550 Type Test SPT- Test psi 2500 IA 53 2731 - 2649 - 2619 - BBL Pumped: 4 'BBL Returned: 4 OA 0 0 0 0 Interval L OTHER p/F P - Notes' CMIT-T x UA to 2500 psi as per sundry #319--0,96 1,/&WevhiMi, LS �ll Tuesday, June 22, 2021 Page 1 of 1 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:197-055 6.50-029-22297-01-00 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 13181 13140 8830 9763 , 9844 12636 none 8655 , 8726 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 30 - 110 30 - 110 1490 470 Surface 3815 10-3/4" 29 - 3844 29 - 3746 4560 1730 Intermediate 9983 7-5/8" x 7" 27 - 10010 27 - 8872 6890 / 7240 4790 / 5410 Production Perforation Depth: Measured depth: 10001 - 13138 feet True vertical depth:8864 - 8830 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 25 - 9909 25 - 8783 9763 8655Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker SABL-3 Liner 3410 2-7/8" 9730 - 13140 8627 - 8830 10566 11165 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 35913544062118 2881322 1860 4154 126 305 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: Torin Roschinger Torin.Roschinger@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564-4887 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service 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 measured8828 Sundry Number or N/A if C.O. Exempt: n/a 4/1/2" TIW HBBP 9844 8726 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate 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 028330 & 028331 PBU 17-19A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 3:16 pm, Jan 26, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.01.26 15:09:28 -09'00' Bo York SFD 1/27/2021DSR-1/27/21MGR18FEB2021 RBDMS HEW 1/27/2021 ACTIVITYDATE SUMMARY 12/23/2020 ***WELL S/I ON ARRIVAL*** (drift for perf) SPOT EQUIPMENT ***JOB CONTINUED ON 12/24/2020*** 12/24/2020 ***JOB CONTINUED ROM 12/23/20*** (drift for perf) DRIFT W/ 2.25" CENT TO DEVIATION @ 10183' SLM. (no sample). DRIFT W/ 30' 2" (2.29" od) DUMMY GUNS TO 10086' SLM ***WELL S/I UPON DEPARTURE*** 1/2/2021 ***WELL S/I ON ARRIVAL*** (HES E-Line Perforating) PERFORATE 10,001' - 10,031' W/ 2", 6 SPF, 60 PHASE MAXFORCE GUN. LOG CORRELATED TO SLB SBHPS DATED 17-NOV-2011. ***JOB COMPLETE ON 02-JAN-2020*** 1/2/2021 T/I/O = 1950/1950/0. Temp = SI. TBG FL (E-Line call in). AL SI @ casing valve (1950 psi). TBG FL @ 8090' (172' below #5, DMY). E- Line in control of all valves upon departure. 16:20 1/5/2021 T/I/O = 325/1890/600. Temp = . IA FL (GLE). AL on line (1900 psi) no companion valve. IA FL @ 5650' ( STA #2 SO, 148 bbls). SV = C. WV, SSV, MV = O. IA & OA = OTG. 18:00 Daily Report of Well Operations PBU 17-19A MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: October 15, 2019 R�c� Izj'zjkq P.I. Supervisor � �� 13IC�j SUBJECT: IA Remedial Cement Job PBU 17-19A FROM: Matt Herrera BPXA Petroleum Inspector PTD 1970550; Sundry 319-096 Section: Drilling Rig: Operator Rep: 22 Township: 10N N/A Rig Elevation: N/A Nathan Williams - Casing/Tubing Data (depths ai Conductor: 20" O.D. Shoe@ Surface: 103/4" O.D. Shoe@ Intermediate: 7 5/8" O.D. Shoe@ Production: Feet O.D. Shoe@ Liner: 27/8" O.D. Shoe@ Tubing: 41/2" O.D. Tail@ Plugging Data: Test Data: Range: 15E - Total Depth: 13181 ft MD 110 - Feet 3844 - Feet 10010 Feet Csg Cut@ Feet 13140 Feet 9909 Feet Suspend: NIA Meridian: Umiat Lease No.: ADL028331 - P&A: N/A Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Type Plug Founded on Depth (13tm) De th To MW Above Verified Tubing Bridge plug - 5916 ft MD' N/A 15.8 N/A 2 2 5 5 5 Initial 15 min in min as min P...df Tubing 2763 - 2697 2680 - 2713 - IA 201 225 230 - P ' OA 2 2 2 5 Initial 15 min in min es mm o—....0 Tubing 2733 - 3727 2720 - 2713 - IA 2745 2675 2655 2644 - P OA 5 5 5 5 Remarks: PBU 17-19A slated for a remedial cement job to repair IA communication leak. Well Operations conducting a second cement squeeze per Sundry 319-096. MIT -T and CMIT-TxIA both showed integrity and stabilization. v Attachments: NONE rev. 11-28-18 2019-1015_Plug_Verification_PBU_17-19A_mh Well To: AOGCC Natural Resources Technician 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 CAS HOLE Transmittal RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) 197055 31468 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : BP Exploration (Alaska), Inc. SIM Data Manager Attn: Merion Kendall MB 7-5 900 Benson Blvd. Anchorage, AK 99508 GANCPDCna USAANC hou xwh BP com and READ Cased Hole, Inc. Attn: Diane Williams 4141 B Street Suite 308 Anchorage, AK 99503 Diane.williams@readcasedhole.com 1) RBT-Cement Evaluation 2) RBT-Cement Signed Print Name: 17 -Oct -19 E -02B CD 14 -Oct -19 ,, 17-19A CD Date: RECEIVED NOV 19 2019 / /` OGC'C 50-029-20175-02 50-029-22297-010 READ CASED HOLE, INC.., 4141 B STREET, SURE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL: READ-ANCHORAGE(uiREADCASEDHOLECOM WEBSITE: WWW.READCASrDHOLECOM https://Mdus�hele.my.shmepoint.c--/pmsons1/diene_vrillimns readcasedhole_com/DocementsNeskrop/Bp_Trensmitd= STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program 69 Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: IA Cement Squeeze 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number: 197-055 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stretigraphic ❑ 1 6. API Number: 50-029-22297-01-00 7 Property Designation (Lease Number): AOL 028331 & 028330 S. Well Name and Number: PBU 17-19A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: SCMT PRUDHOE BAY, PRUDHOE OIL 'R. 11. Present Well Condition Summary: Total Depth: measured 13161 feet Plugs measured None feet V true vertical 8626 feet Junk measured 12636 feet NOVU 04 2019 Effective Depth: measured 13140 feet Packer measured 9763, 9844 feet true vertical 8830 feet Packer true vertical 8655,8726 feet A®GC1V _ Casing: Length: Size: MD: TVD: Burst: Collapse: Structure] Conductor 80 20" 30-110 30-110 1490 470 Surface 3815 10-3/4" 29-3844 29-3746 4560 1730 Intermediate 9983 7-5/8" x 7" 27-10010 27-8872 6890 / 7240 4790/5410 Production Liner 3410 2-7/8" 9730-13140 8627-8830 10566 11165 Perforation Depth: Measured depth: 10725 - 13138 feet True vertical depth: 8869-8830 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 25-9909 25-8783 Packers and SSSV (type, measured and 4-1/2" Baker SABL-3 Packer 9763 8655 true vertical depth) 4-1/2"TIW HBBP Packer 9844 8726 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9760'- 5650' Treatment descriptions including volumes used and final pressure: tat IA Squeeze 12/11/2018 (SN 318-470): Pump 121 bible 15.8ppg Cement down Coil taking IA returns. Pump 103 bbls cement into IA with no losses to PC -Leak. Unsting & attempt to lay in remaining cement in Coil (18 bbls). Wait on Cement Compressive Strength. Mill cement to CBP at 9677'. 2nd IA Squeeze 9/30/2019 (SN 319-096): Pump 25 bbls of class G 15.8 ppg cement. Unsling sting with 1 bbls remaining in mil and begin reversing out while performing hesitation squeeze on the IA. POOH and achieved 3000 psi squeeze on IA. Keep WHP constant at —500 psi while awaiting compressive strength. Mill Cement and CBP. Final Pressures: IA = 0 psi, OA = 35 psi, TBG = 0 psi. 16. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Md Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut In 1139 225 Subsequent to operation: Shut In 35 0 14. Attachments: (mqulred per 20 nac 25.070.25.07, &25.283) 15. Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development 71 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318470 & 319-096 Authorized Name: Smith, Travis T Contact Name: Smith, Travis T Authorized Title: _Erign96r Contact Email: travis.smith1@bp.com Authorized Signature. Date: Contact Phone: +1 9075645412 Form 10-404 Revised 04201h�gDMS fir/ Nnv n minSubmit Original Only Daily Report of Well Operations PBU 17-19A ACTIV ITYDATF 01 uAAA AM ***WELL S/I ON ARRIVAL*** (pre coil) EQUALIZE 4-1/2" WRP @ 9714' SLM / 9718' MD PULLED 4-1/2" WRP FROM 9714' SLM / 9718' MD (Missing piece of element) RAN 3" PUMP BAILER TO 9725' SLM (No recovery) RAN 2.34" CENT, 1.75" SAMPLE BAILER TO TOL AT 9725' SLM (No sample) RAN 2.30" CENT, 1.75" SAMPLE BAILER TO TOL AT 9725' SLM (Light ring impression) RAN 2.25" CENT, 2.25" DO BAILER TO 9729' SLM (Drift sticking lightly) RAN 2.0" CENT, 1.75" SAMPLE BAILER TO 9847' SLM, WORK EASILY TO 9925' SLM 12/6/2018 ***CONT. TO 12/7/18 WSR*** ***CONT. FROM 12/6/18 WSR*** (cement squeeze) RAN 1.75" LIB TO 9774' SLM (no impression) TAG 2-7/8" LINER W/ 3.50" LIB (clear picture of liner) SET 3.59" BAKER CBP @ 9670' SLM/ 9683' MD LRS PERFORM PASSING 2000 PSI P/T ON CBP SET 4-1/2" WHIDDON CATCHER SUB @ 9665' SLM 12/7/2018 ***STANDBY TO CONT. WELLWORK*** ***CONT. FROM 12/07/18 WSR*** (cement squeeze) PULLED EMPTY 4-1/2" WHIDDON CATCHER SUB FROM 9665' SLM SET 4-1/2" SLIP STOP CATCHER SUB @ 9670' SLM TAG STA #7 @ 9403' MD W/ 1.25" LIB (impression of valve) PULLED BK-DGLV FROM STA #8 @ 9665' MD LRS CIRCULATED 420 BBLS OF DIESEL DOWN TBG & OUT IA TO TANKS 12/8/2018 ***CONT. TO 12/9/18 WSR*** ***CONT. FROM 12/8/18 WSR*** (cement squeeze) PULLED STA#2 BK-DGLV @ 5650' MD SET STA# 2 BK-DGLV @ 5650' MD PULLED EMPTY SLIP STOP CATCHER FROM 9670' SLM SET 4-1/2" FAS DRILL CEMENT RETAINER @ 9640' MD PERFORMED PASSING PRESSURE TEST ON TUBING TO 2000psi 12/9/2018 **WELL S/I ON DEPARTURE, DSO NOTIFIED*** CTU#8 1.75". Job Scope: IA SQZ MIRU. MU & RIH HES Cement Retainer Stinger BHA. Take diesel pipe displacement returns while RIH. Sting into HES Retainera t 9633'. PT backside to 1500psi, confirm retainer holding & isolated from Coil. Verify communication into IA. 12/10/2018 ***Continue Job on 12/11/18 WSR*** CTU#8 1.75" CT. Job Scope: Cement IA / Mill Plugs Pump 121 bbls 15.8ppg Cement down Coil taking IA returns. Pump 103 bbls cement into IA with no losses to PC -Leak. Unsting & attempt to lay in remaining cement in Coil (18 bbls). Pull heavy at 9396 ( Glm #7). Unable to pull thru. Unable to reverse out cement due to volume of cement in coil. Circulate cement ooh w/ gel pills. Circulate 12bbls of diesel down IA through screen orifice at 5650' (GLM #2). Swap well to 60/40 methanol. Able to pull past 9396' GLM #7. Pooh. Lay down stinger BHA. MU & RIH w/ 3.70" side jet nozzle. Wash BOP stack. Jet down to Sta#2. Reciprocate across GLM#2. Drift clean down to 9440'. No issues passing down/up thru GLM#7. Pooh. Freeze Protect Coil & Tbg from 2100'. Wait on Cement Compressive Strength. 12/11/2018 ***Continue Job on 12/12/18 WSR*** CTU#8 1.75" CT. Job Scope: Cement IA / Mill Plugs Wait on compressive strength. MU & RIH w/ Baker 3.79" Milling Assy. Dry tag at 9628'. Mill cement to retainer at 9635'. Mill cement to CBP at 9677'. Pooh. Lay down milling bha. Perform Weekly BOP Test. 12/12/2018 ***Continue Job on 12/13/18 WSR*** Daily Report of Well Operations PBU 17-19A CTU#8 1.75" CT. Job Scope: Cement IA / Mill Plugs Finish Weekly BOP Test. RIH w/ Baker Venturi/Burnshoe BHA. Dry tag CBP at 9690'. Mill CBP & push down to TOL at 9734'. Work Venturi. Minimized any milling on Liner Top. Pooh. Recover 2 elements, pieces of cement & composite pieces. Picture of what recovered in Well File Picture Folder. Consult with APE. Freeze Protect Tbg w/ 38 bbls 60/40 Methanol. Rig Down CTU. 12/13/2018 ***Job Complete*** T/I/0= Vac/Vac/Vac (LRS Unit 72 - Assist Slickline: Load & Test) Pumped 20 bbls crude down to ensure TBG is clear, Pumped 230 bbls crude down TBG to load, 12/21/2018 ***WSR Continued on 12-22-18*** ***WELL S/I ON ARRIVAL*** (Cement Squeeze) DRIFTED w/ 1 O' x 3-3/8" DMY GUN, 3.77" WRP DRIFT, AND 3.0" LIB, TOOK IMPRESSION OF MILLED CBP SITTING ON LNR TOP AT 9,720' SLM. SET 4-1/2" SLIP STOP CATCHER AT 5,759' SLM PULLED STA#2 BK-DGLV FROM 5,650' MD. SET STA#2 BK-DGLV AT 5,650' MD. PULLED 4-1/2" SLIP STOP CATCHER FROM 5,759' SLM. DRIFTED w/ 3.77" WRP DRIFT TO TAG @ 9,720' SLM. RAN 2.75" DPU w/ 4-1/2" EVOTRIEVE. 12/21/2018 ***WSR CONTINUED ON 12/22/18*** ***WSR CONTINUED FROM 12/21/18*** (Cement Squeeze) SET 4-1/2" EVOTRIEVE MID ELEMENT @ 9,708' SLM 9718 MD LRS PERFORMED PASSING 2,500 psi MIT -T. LRS OBTAINS LLR OF —0.36 BPM @ 2,600 psi ON IA. RAN SLB SCMT LOG PER PROGRAM. 12/22/2018 ***JOB COMPLETE, WELL LEFT S/I*** SET 4-1/2" EVOTRIEVE MID ELEMENT @ 9,708' SLM 9718 MD 01/09/19: EVO TRIEVE MONTHLY RENTAL FOR 01/22/19 - 02/22/19. MO 02 (CF) 02/06/19: EVO TRIEVE MONTHLY RENTAL FOR 02/22/19 - 03/22/19. MO 03 (MM) 03/05/19: EVO TRIEVE MONTHLY RENTAL FOR 03/22/19 - 04/22/19. MO 04 (MM) 04/05/19: EVOTRIEVE MONTHLY RENTAL FOR 04/22/19 - 05/22/19. MO 05 (MM) 05/20/19: EVOTRIEVE MONTHLY RENTAL FOR 05/22/19 - 06/22/19. MO 06 (CF) 06/02/19: EVOTRIEVE MONTHLY RENTAL FOR 06/22/19 - 07/22/19. MO 07 (MM) 07/02/19: EVOTRIEVE MONTHLY RENTAL FOR 07/22/19 - 08/22/19. MO 08 (CF) 08/10/19: EVOTRIEVE MONTHLY RENTAL FOR 08/22/19 - 09/22/19. MO 09 (CF) 12/22/2018 08/13/19: EQUALIZE & PULL EVO-TRIEVE FROM 9,718' MD ***WSR Continued from 12-21-18*** Temp- S/I (LRS Unit 72 - Assist Slickline: Load & Test) MIT -T PASSED at 2589 psi, Max Applied Pressure= 2750 psi, Target Pressure= 2500 psi. Pumped 4 bbls crude down TBG to reach test pressure, TBG lost 103 psi in 1st 15 min and 39 psi in 2nd 15 min for a total loss of 142 psi in 30 min test, Bleed TBG pressure, Bled back —1.5 bbls, Attempt MIT -IA, unable to reach test pressure. Pumped a total of 17 bbls crude down IA, Established a LLR of —.37 bpm @ 2650 psi, S/L had control of the well and DSO notified upon departure. 12/22/2018 Final T/1/0= 0/436/0. ***WELL S/I ON ARRIVAL***(cement squeeze) EQUALIZE & PULL EVO-TRIEVE FROM 9,718' MD SET 4-1/2 WHIDDON CATCHER ON LINER @ 9,730' MD PULLED BK-DGLV/SET PORTED BK -SHEAR VALVE (2000#) IN STA #2 @ 5,650' MD PULLED EMPTY 4 1/2" WHIDDON FROM 9,710' SLM 8/13/2019 ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** Daily Report of Well Operations PBU 17-19A ***WELL S/I ON ARRIVAL***(IA cement squeeze) SET HES 4 1/2" OBSIDIAN CBP @ 5916', CCL TO ME=7.8', CCL STOP DEPTH=5908.2' PUNCH TUBING 5903'- 5907'W/ 4 SPF ODEG PHASING SMALL CHARGES, CCL TO TOPSHOT=6.6' CCL STOP DEPTH=5896.4' ALL LOGS CORRELATED TO CBL DATED 12/22/2018 LRS PERFORMED PASSING MIT -T TO 2500 PSI (see Irs wsr for details) FINAL T/1/0=600/528/80 9/11/2019 ***LDFN, WELL LEFT S/I*** ***JOB CONT FROM 121SEPTEMBER-2019***(SLB ELINE) LRS CIRCULATED 300 BBL DIESEL DOWN TUBING AND UP IA TAKING RETURNS TO 17-09 SET 4 1/2" FASDRILL CEMENT RETAINER @ 5876', CCL TO MID ELEMENT=7.83 FT, CCL STOP DEPTH=5868.2'. CORRELATED TO CBL DATED 12/22/2018 9/12/2019 ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED*** CTU #9.1.75" Coil Objective: IA Cement Squeeze, Mill retainer and CBP MIRU CTU. Make up Cement stinger BHA for HES FasDrill Cement Retainer and RIH. Sting into retainer and pump 25 bbls of class G 15.8 ppg cement. Unsling sting with 1 bbls remaining in coil and begin reversing out while performing hesitation squeeze on the IA. POOH and achieved 3000 psi squeeze on IA. Bled down tubing while holding 3000 psi on IA and shear valve popped @ —1200 psi. Pumped 40 bbls diesel down IA taking returns up tubing and verified good flow path. RIH w/ 3.50" JSN and jetted retainer and GLM's # 2 & 1 w/ PowerVis. POOH 9/30/2019 ....Job in Progress... CTU #9.1.75" Coil Objective: IA Cement Squeeze, Mill retainer and CBP Finish jetting tree and BOP'S w/ PowerVis. Pop off well, install night cap and keep WHIP constant at —500 psi while awaiting compressive strength. Make up 3.80" 4 -bladed junk mill and 2 7/8" motor and RIH. ...Job in Progress... 10/1/2019 CTU #9.1,75" Coil ***Continue from 10/01/19*** Objective: IA Cement Squeeze, Mill retainer and CBP Hard milling on cement retainer and unable to make progress. POOH and make up venturi with 3.70" shoe and RIH. Tag at 5886' and reciprocate above retainer. POOH and recover —1/2 cup of composite retainer debris including element rubber and brass from valve. Make up Milling BHA with 3.79" 3 -bladed convex junk mill and RIH. Resume milling and make it down 5888', unable to achieve any motor work even while stacking 10k. POOH to check tools and bottom face of mill untouched. Large gouges in side of mill. MU & RIH w/ venturi w/ 3.70" mule shoe. 10/2/2019 ...Job in Progress... CTU #9. 1.75" Coil ***Continue from 10/02/19*** Objective: IA Cement Squeeze, Mill retainer and CBP Finished POOH w/ venturi w/ 3.70" mule shoe. Recovered 1/2 of mainly metal shavings and metal slip buttons. Trim 100' pipe. MU Baker milling MHA w/ 3.80" 3 blade junk mill. Mill from —5890' - 5924'. RIH to liner top at 9732'. Mill CBP on top of LTP, POOH. Minimal wear on bottom of mill, but some on sides again. MU & RIH w/ 3.79" venturi w/ burn shoe, tag @ 9732', make venturi passes & POOH. 10/3/2019 ...In progress... Daily Report of Well Operations PBU 17-19A CTU #9. 1.75" Coil ***Continue from 10/03/19*** Objective: IA Cement Squeeze, Mill retainer and CBP Finish POOH with venturi. Recovered —2 cups metal shavings and composite material in venturi. Trim 100' pipe, change packoffs, and perform chain inspection. MU & RIH w/ 2.13" motor and 2.29" 3 -bladed junk mill. Tag obstruction just inside liner top at —9739' CTM. Push obstruction down to 12634'& have to POOH for BOP test. 10/4/2019 ...Job in Progress... CTU #9. 1.75" Coil ***Continue from 10/04/19*** Objective: IA Cement Squeeze, Mill retainer and CBP Perform seven day BOP test. Re -align goose neck. MU & RIH w/ 2.13" motor w/ ventud and 2.23" burnshoe. Reach 10751' CTM, setting down repeatedly, likely in fill. POOH. Venturi packed with formation sand and cement lodged in the burnshoe. MU & RIH w/ 2.13" motor and 2.29" 3 -bladed junk mill. Tag fill @ 10,763' and jet down to 10,900', returns were intermittent. PUH and overpulled @ 10,700'. PUH out of liner and bull headed a well bore volume of 1 % KCI down the backside @ 3 bpm. RIH and tagged fill @ 11,300'. Jet into fill taking 200' bites and pulling back up to vertical section @ 10,100' each time 10/5/2019 ...Job in Progress... CTU #9. 1.75" Coil ***Continue from 10/05/19*** Objective: IA Cement Squeeze, Mill retainer and CBP Finished cleaning out back down to obstruction @ 12636'. Still could not achieve anything, motor would go straight to stall as soon as touching. When killing pump after stalls we would tag higher on the next attempt then have to dig back down as if the fill was coming in right at that depth. After 90 minutes of no luck POOH to check tools pumping pipe displacement down backside. FP coil and well with 50/50. RDMO. 10/6/2019 ...Job Complete... ***WELL S/I ON ARRIVAL*** (IA cement squeeze) SET 3.69" SPECIAL CLEARANCE WRP @ 9710' MD 10/13/2019 ***CONT. ON 10/14/19 WSR*** ***CONT. FROM 10/13/19 WSR*** (IA cement squeeze) RUN SCMT LOG FROM 8 500' SLM TO 3 089' SLM SET 4-1/2" SLIP STOP CATCHER @ 5697' SLM PULLED BK-DCR @ 5650' MD PULLED BK-DGLV @ 3014' MD SET BK-LGLV @ 3014' MD SET BK-S/O @ 5650' MD 10/14/2019 ***CONT. ON 10/15/19 WSR*** ***CONT. FROM 10/14/19 WSR*** (IA cement squeeze) PULLED 4-1/2" SLIP STOP CATCHER @ 5697' SLM LRS PERFORMED AOGCC WITNESSED PASSING MIT -T & CMIT-T PULLED 3.69" SPECIAL CLEARANCE WRP @ 9710' MID ... MISSING 1.5" x 4" PEICE OF ELEMENT ***JOB COMPLETE, DSO TO POP*** 10/15/2019 *****NOTE: MISSING 1.5" x 4" PEICE OF ELEMENT FROM CENTER ELEMENT OF WRP***** TREE = WELLHEAD FMC SUM HOLE SAFETY NOTES: FHL/ I IW HABBP PKRS HAVE REDUCED TEST PRESSURE LIMITS IN SOME ACTUATOR= OTIS 17-19A CASES. CONTACT ACE ()(5102) PRIOR TO KB. REV w REF REV TESTING *** 4-12' & 7" CHROME TBG / CSG*** = 64' BE RCA/ = 36.66' 20" COPD, 80' ❑� 2089' LOCKS OUT ( SSSV,) = 3.813" KOP= 2703' 91.5#, H-40, LOCKED OUT (12(07110) Max Angle = 103" Q 10260' D = 19-124" Datum MD= 10182' = 88 • —5104' wcMeCLU�(.0ros/oc)' Datum TVD00'SS .6#, 13C"0 FOX XO TO TDS CSG, 45.5#, NT -80, ID = 9.950" 3646' TBGPUNCH,4 SPF (09/11/79) 6903'-6907'' b CMT PLUG TOC (1222/18) 6990' Minimum ID = 2.408" @ 9730' TIW HANGER aLJ 4-1/2" TBG, 12.6#, 13CR-80 TDS, 9827' .0152 bpf, D = 3.958" L-80 NSCC, D = 6.875" 982W PERFORATION SUMMARY REF LOG: BHCS ON 10/31/92 ANGLEATTOPPERF: Q' Note: Refer to Production DB for historical perf data SIZE SPF Kn3WAL Opn/Sgz DATE 2-7/8" SLTD 1 10725-13138 SLOT 0426/97 4-1/2" TBG, 12.6#, 13CR-80 T0.S, 9911' .0152 bpf, D = 3.958" 7 " CSG, 269, 13CR FOX, .0383 bpf, ID = 6.276"10009' 2-710" LNR 6.5#, L-80 STL, .058 bpf , D = 2.441" I ST MD TVD DEV TWE VLV LATCH PORT DATE 1 3014 3005 16 KBMG DOME BK 16 10/14/19 2 5650 5231 36 KBMG SO BK 24 10/14/19 *3 7426 6693 34 KBMG DMY BK 0 04/07/94 *4 8262 7381 34 KBMG DMY BK 0 1128/17 *5 8721 7762 34 KBMG DMY BK 0 04/07/94 *6 9101 8080 32 KBMG DMY BK 0 04/07/94 *7 9403 8339 29 KBMG DMY BK 0 04107/94 *8 9665 8570 28 - EMPTY - 12109/18 'STA #3, 4, 5, 6, 7, & 8 ARE CEMENTED 9701' 4-12" OTIS X NIP, D = 3.813" ( 9/30' 1�4-12"X2-7/8"TNV HGR, D=2.408" 9760' 7-510" X 4-12" BKR S-3 PKR D = 3.93' 9794' 4-12' OTS X MP, D = 3.813" 9811'4-12" OTS XNNIP, D = 3.725' 9827' 4-1/2" OV H1SH0T GUDE 9828' 7-5/8" XO TO 7", D = 6.276" 9846' 7" TNV HBBP PKR (FAL® PRE WO) 9880' 4-1/2" PARKER SWS NP, D=3813- D46 SIDETRACK 17-19A) -FB -MD TT LOGGED 12/10/94 7" MLLOUT WNDOW (17-19A) 10006' -10021' 2-7/8" SLTD LNR 6.4#, L-80 STL, .0058 bpf, D = 2.441" 13138' 2-7/8" LNR, 6.5#, L-80, .0058 bpf, D = 2.441"13140' DATE REV BY COMMENTS DATE REV BY COMMENTS 11104192 N18E ORIGINAL COMPLETION 0820/19 JB/JMD PULLED EVOTREVE 08!13/19 04108194 D46 RWO 09197/19 NXW/JMD SETCBP, TBG PUNCH, CMT RET 0426197 D46 SIDETRACK 17-19A) 10107/19 JTM/JMD MLLED/PUSHEDCMTRET-CMTW 01/02/19 JMG/JMD SET EVOTRIEVE(1222M8) 10/16/19 MWJMD GLVC/0(10/14/19) 01/02199 JPK/JMD GLV C/O 1222/18 08/20/19 JPK/JMO GLV C/O 08/13/19 PRUDHOE BAY UNIT WELL: 17-19A PERMITNO: 61970550 API No: 50-029-22297-01 TI ON, RI 5E, 992' FWL & 2534' BP Exploration (Alaska) & CBP I Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: rr AOGCC ATTN: Natural Resources Technician II �#✓ Alaska Oil & Gas Conservation Commision <1 333 W. 7th Ave, Suite 100 lye Anchorage, AK 99501 197055 30 45 1 . • 14 -Mar -19 14Mar19JW02 WELL NAME API # 50-02 SERVICE ORDER # FIELD NAME PRILICI-HOEBAY SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE COLOR DATE LOGGED PRINTS CDs ® ' ' r 0 ..:.moo. Print Nam Signature Please return via courier or sign/scan and email a copy A Transmittal Receipt signature confirms that a package (box, 4 envelope, etc.) has been received and the contents of the �j ) package have been verified to match the media noted above. Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this Schlumberger and BP point. Sch I u mberger-P rivate THE STATE ALASKA GOVERNOR MIKE DUNLEAVY Travis Smith Engineer BP Exploration (Alaska), Inc. P.O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 17-19A Permit to Drill Number: 197-055 Sundry Number: 319-096 Dear Mr. Smith: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner T~ DATED this? day of March, 2019. a80�Ss� MAR 0 71019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.260 FEB 2 8 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair well ❑ /�( �OOp�p�eelIIration sh down ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ CIIBNga.ItpP�m 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other 2nd IA Cement 0 2. Operator Name. SP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0- 5. Permit to Drill Number 197-055 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612Stretigrephic ❑ Service ❑ 6. API Number: 50-029-22297-01-00 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 ❑ No 0 PBU 17-19A 9. Property Designation (Lease Number): 10. Field/Pools:ADL 028331 8 028330 PRUDHOE BAY. PRUDHOE OIL' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (6): Total Depth TVD(6): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13181 8828 - 9718 8616 9718 None Casing Length Size MD TVD Buret Collapse Structural Conductor 80 20" 30-110 30-110 1490 470 Surface 3815 10-3/4" 29-3844 29-3746 4560 1730 Intermediate 9983 7-5/8" x 7" 27-10010 27-8872 6890 / 7240 4790/5410 Production Liner 3409 2-7/8" 9730- 13140 8627-8830 10566 1 11165 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grace: Tubing MD (ft): 10725 - 13138 8869 - 8830 4-1/2" 12.6# 13Cr80 25-9909 Packers and SSSV Type: 4-12- Baker SABL-3 Packer Packers and SSSV MD (ft) and TVD (ft): 9763 / 8655 4-1/2" TIW HBBP Packer 9844 / 8726 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: April 1, 2019 15. Well Status after proposed work: Oil 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Smith, Travis T be deviated from without prior written approval. Contact Email: travis.smithlC%bp.com Authorized Name: Smith, Travis T Contact Phone: +1 907 564 5412 Authorized Title: Engineer Authorized Signature: Date: / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 319 - �9 tp 911, Plug Integrity ty ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: M 17-1 c -PA IT T v rAr TO Z. $pp Q7 Post Initial Injechon MIT Req'd? Yes ❑ No ❑—/ Spacing Exception Required? 0 No GY Subsequent Form Required. to „ Ll OLl /Yes APPROVED YTHE Approved b G COMMISSIONER COMMISSION Form 10-403 Revised 04/2017 ORIGINAL RBDMS 072019 p Submit Form and Approved application is valid for 12 months from the date of approval. � �,r Attachments Duplicate Engineers: Well: 17-19A 17-19A IA Remedial Cement Job Overview Travis Smith: 907-564-5412 Meredyth Richards: 907-564-4867 History: 17-19A is a Sag -only producer shut-in since December 2017 due to a production casing leak at approximately 6250' MD. An IA cement job was attempted in December of 2018 under Sundry #318- 470, designed to fill the IA with cement from the packer to approximately 500' above the leak depth in the production casing. While the job did place the intended cement in the IA, a subsequent MITIA failed with a LLR of 0.37 BPM. Based on a CBL, it is believed the upper portion of the cement job is channeled to the production casing leak. This job will perform a second IA cement squeeze to remediate the communication to the production leak. Scope of Work: Repair production casing leak with second IA cement job. Return well to production, lifting from GLM#2. Overview Steps: Slickline and Fullbore: 1. Pull 4-1/2" Evotrieve plug from 9718' MD. 2. Run drift for CBP and cement retainer. 3. Set CBP with top at 5916' MD. 4. Pull DV from GLM#2 at 5650' MD. Set shear -out valve (configured to shear with 2000 psi differential.Fullbore: perform M T T to 2500 psi. AJo 5. Fire tubing punch from 5892'-5896' MD. a. Fullbore: pumping down the tubing and taking returns through the IA, confirm circulating rates and pressure through tubing punch. b. Circulate tubing and IA to diesel. 6. Set cement retainer at 5876' MD. Coiled Tubing: 1. Sting into cement retainer and pressure test. Pumping down coil, establish returns up the IA. Pump freshwater spacer followed by cement pill into the IA. Control IA pressure with choke at surface to maintain 1:1 returns: do not allow IA leak to inflow. With 1 BBL of cement remaining by Well: 17-19A in coil, disengage retainer and lay the last 1 BBL of cement on the retainer. Begin circulating down the coil and up the tubing while coil POOH to surface. Swap stinger BHA for nozzle BHA. 2. Pressure up tubing to hold back pressure against shear -out valve, and then begin hesitation squeezes down the IA. a. Coil tubing RIH to GLM#2 during IA squeeze schedule. 3. After achieving either maximum pressure or maximum volume pumped down IA, stop squeezing and hold pressure on IA. Drop pressure on tubing to shear the shear -out valve and begin circulating down IA taking returns up tubing. Pump down the IA to clear cement above GLM#2, taking returns through GLM#2 and up the tubing. After pumping full circulation schedule, shut down pumps and trap pressure on tubing and IA. a. Coil tubing wash GLM#2, GLM#1, and tubing to surface after IA circulation. Ensure IA pressure doesn't drop during jetting. 4. Wait on cement to cure, return with milling BHA. Mill cement retainer, cement, and CBP. Slickline and Fullbore 1. Set retrievable plug between 9701' MD and 9730'' MD. 2. Log SCMT. rjc_m r R4Fs cr L. TS TO/a d6 CC - 3. Pull DV from GLM#1 and Shear -out Valve from GLM#2 and replace with live GLVs per design. 4. State Witnessed MIT -T and CMIT-TxIA to 2500 psi with any non -freezable fluid. Max applied pressure of 2750psi. Well Intearity Eneineer 1. Add Biennial (every 2 years) MIT -Ts and CMIT-TxIAs to AKIMS. Well: 17-19A 11193= FMC SLtJ HOLE SAFETY NOTES: FHVIIWN178H4'f'KRSHAVE Nk1LFGA0 17-19A REDUCED TEST PRESSURE UMTTS N SCHE ACMTOR= -- --- -OT6CASES. CONTACT ACE(J6102)PRIOR TO U RFV= _Be TES-nNO"'4-1YY&7•CNROAE TDG/CSG"' eF G;EV ,- __. __— _73.96' 20' COf•D, �Tw 2089' CAACO TCF 4A SSSV, D = 3817 70= _ 2707 91.38. "0, My Ang, = 103' 10260 D-14124• LOCIOD our (17197110) rte6an t0= 19187 fiCIRWNEYFIC X070 TDs Minimum ID = 21908" 8730' TNYHANGER X.v 4-12• TBG, 12.88.13CW00 TB. 0152 tor. D • 3.058• FearoRAT1ONSM ARY FEF LOG BHCS ON 10'31192 AIGLEATTOPR32F. @' Nbb: refer to Rodmbon CS ror HerodW parr Me SEE I SIE I NTERIAL IOpNSaQ GATE 2-7 &LTD 10725.73738 1 SLOT 0426197 10152 tp1, D=3958^ 7 • CSG, %8. leers rox, .oaoa e"r. o -esTo• 10008• Sf NO TVD I DEV I TYPE I VLV LAT01 FORT! DOTE 1 3014 3005 16 KOMG Dt11OK D3 -4W RLL®4MF(0MMS) 0 112&17 2 56M 5731 36 KBMG DMI BK 0 1282/18 -3 7426 669:1 34 KBAG DMI BK 0 OWIA4 4 82Q 7791 39 I®MO Otf! 01( 0 1128177 '5 8721 7782 34 KENO CMI BK 0 OW711A '6 9101 8080 32 1®tIG OMI SK 0 0W7A4 '7 9403 8339 29 I®MG OMI N( 0 0607194 '8 9665 8570 ?8 B.Pry 12A IS 4, 6, 6, 7. L 9 AM CW&Wrm B90B' _ 4-12'MriOSi seal M'.m-a-Tec [_99061 HH W M L0 001311211"- y 9rMLLOUINT17JW117.19A)tD006 1X121' DATE FEV BY I COLtA M DATE REV BY I COWAENTS 111"W NISE OR WAL COMPLETION 17713/15 CWJMD MIS VQFPSET CWr FET 6 CBP 0408194 D13 RYO 12113118 CN'JAO GLV 0-0(12X&18) o416m7 D18 amETRACN(17.10A) 12/17118 TPAIJKM N GM -8911 -LM SET FISH 03112118 D3 -4W RLL®4MF(0MMS) 01/07119 JM31Jk0 ISETEVOTREVE(1282/1B) 0321118 MUM SET%FDVAB(0320118) 01/07119 JP10JL0 JCiv GO (1281118) 1011SH3 JN-IJND Am® C1(S REF, B BF AEV rRJCFDEBAY IBR 'AIaL 17-19A P80ATND 9970550 ARN. 50.029-22297.01 TION. R15F 997 FAL & 26M FN_ BP Eq loraOon (Ares ka) Trac. wr:,r u rra c WB1lfiVD=CM ACTUATOR. OIB tm ELEV = w PORT w OF. ELLV = 38.86' KOP=-- 2703 Mu Arg*= 103'4 10260' Dift IA= 10182• muan TVD = 880055 Proposed Schematic 20 COPD, 91.56, H40. D -19-12P 4-1 Ir TBG, t2 Be, 15CR- FOX XO TO TOS Cement squeezed from 5650'-5896' Minimum ID = 2.008" 870' TM HANGER Tubing Punch from5892' - 5896' 2 -Ire• L W 0-3.958' {9SORATION SIARWRY REF LOG BNB ON 1&31192 AN#.EAT TOPPHs:: a' NNe: Refer W Rodmtbn OB for holaroal peff da SIZE I SPF I INTERVAL OPMSyz I DATE 2-7 SLTD 18725-13138 SLDT 042897 1.0152 bpf, D - J 958- 7•(50.266, 1,,RreK..0—ber. a)-c2ro• 70009' S AFETY NOTES: FHL/RW HAB13P PKRS HAVE SCW 17-19AN ACACE()(5102)P�RORTO G •'• 4-I/Y 8 7-CHROW TBGI CSG••• —�v.ACr) 1'Cf dA SSSV, D * 7.817 GAS LIFT MANORR S 5T UD TVD OCV TYPE VLV LATCH PORT DATE 1 3014 3005 16 KBLD OW SK 0 1128/17 2 5650 6231 36 KBMG OW BK 0 1=18 -3 7626 6M 34 KBUD DLA/ BC 0 04.07/91 '4 8262 7381 34 KBMO DW BK 0 112817 •5 ern 7762 34 KBMG DAM BK 0 04007194 '6 9101 8080 32 KBLD OMH B4 0 04,07/94 •T 9403 8339 29 KBkD OW SK D 04007/94 •B 9865 85'70 28 EMPTY 12009/t8 r, NET )l-:-1NN: -ZMV: Y 9809'_-4-12'MlaOZt�ar rar+,0-a.1n• �.. 8908' Hr w H LGGGeT 1v1dm� \ 7'MLLOUTwN7JVY117•iM)t000R•11021' DATE REV BY COM.BBS DATE REV BY COKOA34TS 1M4= NIKE ORDINAL COMPLERON 12117/18 CNVMD RA -LED V.tBT'SET CW RET B CBP 04MWU 0-16 RWO 12/13MB C" AD GLV 00 (12(0918) 04rAW D-16 SIDETRACK(17-19A) 12/17/18 TFA/JMO IA CW -BLL RUGS, SET FISH 03112718 MAD RAIMWFP(03009H8) 01102/19 ,*"JKC SEFEVOTREVE(12/ Ma) 0321118 MrJW SEr WFDVLFP10320/18) 01102M9 SW AD GLV GO(12rMIS) 10115/18 JNIJAD AW®OKB, R6.& OF ELEV PR C DEI&AY LINT WELL: 17-19A PGWT '1970550 API,, 50-029-22297-01 T10K RISE 992' FWL 8 2531' FTL BP BtploraOOR (Alaska) Lf) _ v Ln cot o - -- r I-- CD w X C N v _, s=2O en rn zV) cD "" f3 T no h 0 i- ro N z4- .- r Y v E v Cl. a aa)) C a O C.13 •L -o Y C q -It p ra On 0 J w r cp rb L V E >o C a � CJ r '- �' a) E Oa' m t. CD C1Q1 u ' J O d a E a... r -3 O r^ c to 1- N 0 r i4= C U -C U) Q •1 N N N O "6 L C p +./ r etu E) E v C O C i Jro 0 0 a) -0 N o am w J J J C '- a p } W W W to C w V O I- IL IT. It ti a) 'i w J J J a+ a) O a) O_ _C > t _./ I in< Z Z Z u (,) a) , no ) t L Y. LL ti aa) �O a •• = -O C > — U a) a) C 4- 4-+ > 4-4 a) ro C a) ren ri 0 E§ Z N a- a a u a) .- O 5 F- C @ a) +0 .0 U a O O U a a) a C C M O r u C L.L. O J ~ ar o o re 0 HD L" a J V o m a rn u a, ,-1 Q 15) N• U C) • J' > N CC w CPLs/ Vt- w a) CO a) Y �: ''s....-... a [L > a i J o mai .a 4-, — .0 a) C dD CD L- U CO • w 0 O > o E > 0 Z H 7 u lJ a J J J F. C 01 0 a a Q M Q w C.) - N V) VI 1u E E, 0 7O Jo >-• z �)z Qp a. Q W .0 Z Z O 2 CLW f , 0 y .1, Fw- C U CI 03 LL• J J v Z 7 0. =�LLI N 0. ro Ou D N w 110 C) n X 'v Q0oU Q o 000 al E L .1 xQ No4 W0 O 0 C no x co C r0f6 u , N O W 0 0 0 D Tr M r- oo az E n X# VO N n L. O N a N N N O u Cit O O O 1. C. 0cc D i, �0 in LC) 1n , 0 y a N OQi fa)IiiI z � � r �E J r J"' �+C t C )J " U O e� o COM d a 01 (/ C awl n6 H a a Q 20- DEC -2011 Sch Winner 5843 Alaska Data & Consulting Services Company: State of Alaska 262$ Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 09 -18 BVYC -00017 SLIM CEMENT MAP TOOL 26- Nov -11 1 1 MPS -01A BY05 -00003 ISOLATION SCANNER 25- Nov -11 1 1 F -05A BINC -00084 LEAK DETECTION LOG 19- Nov -11 1 1 P1 -03 BINC -00082 PPROF W/ DEFT & GHOST 17- Nov -11 1 1 17 -19A BJGT -00082 SBHPS / '/ 7 ^ 05 17- Nov -11 1 1 09 -12 BD88 -00183 MEMORY LDL 28- Nov -11 1 1 C -02 BYS4 -00005 PRIMARY DEPTH CONTROL 16- Nov -11 1 1 II 04-350 BYS4 -00006 USIT 16- Nov -11 1 1 GC -2E BYS4 -00011 RST WATERFLOW 6- Dec -11 1 1 15 -09A BINC -00085 PRIMARY DEPTH CONTROL 8- Dec -11 1 1 09 -17 BAUJ -00104 MEMORY INJECTION PROFILE 30- Nov -11 1 1 MPE -12 BD88 -00185 MEMORY INJECTION PROFILE 14- Dec -11 1 1 16 -03 BG4H -00099 INJECTION PROFILE 28- Oct -11 1 1 MPL -24 BUTT-00004 MEMORY INJECTION PROFILE 6- Aug -11 1 1 2- 50/U -08 BD88 -00184 MEMORY IPROF W /DEFT GHOST 11- Dec -11 1 1 A -11 BSM4 -00018 INJECTION PROFILE 30- Oct -11 1 1 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 OPERABLE: Producer 17-19A (PTD 970550) IAxOA communication mana~able by bleeds Page 1 c~2~ Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Wednesday, September 08, 2010 2:51 PM ~~~ ~ I ~ I I Q To: AK D&C Well Inte ri Coordinator Maunder Thomas E DOA ~ Re James B DOA ~ Schw~ar'tz Gu L 9 tY ~ ( ), 99, ( )~ Y (DOA); AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer Cc: Janowski, Carrie Subject: OPERABLE: Producer 17-19A (PTD #1970550) IAxOA communication manageable by bleeds All, An OA repressurization test was completed on Producer 17-19A (PTD #1970550) on 09/06/10. There was not any noticeable BUR durin the five da m ~ r making the well manageable. The well has been reclassi ie as perable an may continue on production. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: AK, D&C Well Integrity Coordinator Sent: Wednesday, September Ol, 2010 8:48 PM ~~ c., z .,.,, ,~ To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy (DOA) <guy.schwartz@alaska.gov>'; AK, OPS F OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, D&C Well Services Operations Team L ; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB East Production Optimization Engin ; AK, RES GPB West Production Optimization Engineer Cc: AK, D&C Well Integrity Coordinator; Janowski, Carrie; King, Whitney Subject: UNDER EVALUATION: Producer 17-19 (PTD #1970550) Sustained OA Pressure B king MOASP All, Producer 17-19 (PTD #1970550) had sustained OA pres re breaking MOASP on 8/31/2010. The wellhead pressures were tubing/IA/OA equal to 379/1 5/1180 psi on 8/31/2010. The well has been reclassified as Under Evaluation. The well may re in online while work is conducted to attempt to restore integrity. The plan forward: 1. DHD: DART 2. Wellhead: PPPOT-IC A TIO plot and wellbore sGh(ematic have been included for review. « File: Producer 1 -19 (PTD # 1970550) TIO Plot.doc» Please call if u have any questions or concerns. 010 UNDER EVALUATION: Producer (PTD #1970550) Sustained OA Pres~e Breaking M... Page 1 of 1 i ikq Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Wednesday, September 01, 2010 8:48 PM ~~ ~~~~~~ To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 DS Operators; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer Cc: AK, D&C Well Integrity Coordinator; Janowski, Carrie; King, Whitney Subject: UNDER EVALUATION: Producer 17-19 (PTD #1970550) Sustained OA Pressure Breaking MOASP Attachments: Producer 17~J (PTD # 1970550) TIO Plot.doc; Producer 1~3 (PTD #1970550) wellbore schematic.pdf All, ~7-t `i,"~ 17~~~ Producer 1711'9 (PTD #1970550) had sustained OA ressure breakin MOASP on 8/31/2010. The wellhead pressures were tubing/IA/OA equal o /1625/1180 psi on 8/31/2010. The well has been reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to restore integrity. The plan forward: 1. DHD: DART 2. Wellhead: PPPOT-IC ~ ~ "~ ~~~~ ~ ~ ~ ~~ ~ ~f, ~~~ ~~' A TIO plot and wellbore schematic have been included for review. t?-i~t~ i -~~/~ «Producer 17.-1~9 (PTD # 1970550) TIO Plot.doc» «Producer (PTD #1970550) wellbore schematic.pdf» Please call if you have any questions or concerns. ~~ - 1~3/q~ 1J 1`-f~0~ 4~ SP~F Thank you, 1 Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 ~~~ . 5zt GPs; ~f~~" ~kr-- PB.- C.~ q ~Z 9/7/2010 PBU 17-19A PTD # 1970550 9/1/2010 TIO Pressures Plot _ .___ Well:17-19 a,aoo anon 2,000 1:000 -~- T bg -~ IA ~ OA OOA _ OOOA On 06105!10 0611910 07103110 07!17;'10 07!31110 08!14!10 08!28!10 • TREE = FMC SLIM HOLE WELLHEAD = CNV ACTUATOR = OTIS KB. ELEV = 66~ __ BF. ELEV = ~? KOP = 2703'', Max Angle =103 ~ 10260'', Datum MD = 10182". Datum TVD = 8800' SS'. SAFI=TY ES: FHLiTIW HABBP PKRS HAVE -~ REDU~EST PRESSURE LIMITS IN SOME CASES. CONTACT ACE (X5102) PRIOR TO TESTING ~*` 4-112" & 7"CHROME TBG ! CSG"'" 20" CONDUCTOR, $O' - ~ ? 91.5#, H-40, 2p$g' CAMCO TCF-4A SSSV, ID = 3.813" ID = 19-124" GAS I__IFT MANDRELS 4-1/2" TBG, 12.6#, 13CR-80 FOX XO TO TDS 663` 10-314" CSG. 45.5#, NT-80, ID = 9.950" 3$46' Minimum ID = 2.408" ~ 9730" TIW HANGER ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3014 3005 16 KBMG DOME BK 16 04/27/97 2 5650 5231 36 KBMG DOME BK 16 04/27/97 3 7426 6693 34 KBMG DMY BK 0 04/fl7194 4 8262 7381 34 KBMG DOME BK 20 04/27/97 5 8721 7762 34 KBMG DMY BK 0 04!07194 6 9101 8080 32 KBMG DMY BK 0 04107194 7 9403 8339 29 KBMG DMY BK 0 04107!94 8 9665 8570 28 KBMG S/O BK 20 11/28/03 4-1i2" OTIS X NIP, ID = 3.813" TOP OF 2-7/8" LNR 4-1/2" TBG, 12.6#, 13CR-80 TDS, 9$27' .0152 bpf, ID = 3.958" 4-1/2" TBG STUB (050/13/95 TAGGED) 9$27' 7-518" CSG, 29.7#, L-8p NSCC, ID = 6.875" 9$2$' PERFORATION SUMMARY REF LOG: BRCS ON 10/31/92 ANGLE AT TOP PERF: @ ' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-718" SLTD 10725-13138 SLOT 04/26197 4-112" TBG, 12.6#, 13CR-80 TDS, .0152 bpf, ID = 3.958" 7 "CSG, 26#, 13CR FOX, .0383 bpf, ID = 6.276" I 9911' I I 10009' I 7" TNV HBBP PKR {FAILED PRE WO) 4-112" PARKER SWS NIP, ID = 3.813" (4-1/2" PARKER SWN NIP, ID = 3.725" I 9911' J-j4-1/2" WIEG, ID = 3.958" ggp$' ELMD TT LOGGED 12!10/94 7" MILLOUT WINDOW (17-19A} 10006' - 10021' 2-7/8" LNR, 6.5#, L-80 STL, .058 bpf , ID = 2.441" ~-~ 10725' 730' -~4-112" X 2-7/8" TNV HGR, ID = 2.408" g760" 7-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.93" 9794` 4-112" OTIS X NIP, ID = 3.813" 9811' -~4-112"' OTIS XN NIP, iD = 3.725" 9$27' 4-1/2" OVERSHOT GUIDE 982$" 7-5/8" XO TO 7", ID = 6.276" ` e ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 11!04192 N18E ORIGINAL COMPLETION 07/17/10 ?/ PJC CSG XO CORRECTION 04!08194 0-18 RWO 07/18(10 PJC CONVERSK7N CORRECTIONS 04/26/97 D-1& SIDETRACK (17-19A} 11/28/03 RWL/TLP GLV CIO 11/16/05 PJPIPJC SLT LNRIPERF CORRECTION 07/14!10 OOB/SV LNR CORRECTION PRUDHOE BAY UNIT WELL: 17-19A PERMIT No: 1970550 API No: 50-029-22297-01 SEC 22, T10N, R15E, 992' FWL & 2534' FNL BP Exploration {Alaska} Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well W-19AL 1 17-19A V·04 Z-21A Z-03 05-38 Y -29A B-16 Z-22B Z-14B P2-45A 17-09 F-33 4-08/P-27 3-17F/K-30 MPB-50 S-125 Job# 11890312 11855512 11855513 11594526 11767142 11686787 11855514 11676969 11594525 11849935 11594529 11846820 11661176 11630506 11649961 40011604 40015467 $'¡;AANED OCT 3 1 2007 Log DescriPtion SBHP & TEMP ;:)(),q - ~ I~<Ç SBHPSURVEY Iq~-n~ ~ SBHP SURVEY ~1()Ú1 _ /::. C,,/ SBHP SURVEY 'V1l) -/ () / LDL I C:I '+-M t LDL IC1t~ -/ fÇ DDL l~{ð- "AI PRODUCTION PROFILE f<JC. -âr95 SBHP SURVEY - f).,LAA-"'F^ ",t!. SBHP SURVEY .:Jt')(o-cAe::: SBHP SURVEY J C; <:; -/'?I (./ LDL 11f I - òC¡ D MEMORY SBHPS I &)G" - ro? LDL ()'I(' 11\'"".}--(){")'7( MCNL .;;)ò3 -:J.tlA -tt J~("IL{ OH MWD/LWD EDITÜI(\_ ::JHJ-::Jh:::J 1-51/>1,~ OH MWD/LWD EDIT ~()~-()"X?,. tt #~ t.Q PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Date 09/29/07 09/26/07 09/27/07 10/07/07 10/01/07 09/27/07 09/28/07 10/12/07 10/06/07 10/02/07 10/16/07 10/19/07 10/19/07 10/04/07 04/17/07 02/27/05 07/14/07 NO. 4464 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 10/25/07 BL , 1 1 1 1 1 1 1 1 1 1 1 1 1 1 2 2 Color Field: P.Bay, Endicott, Aurora, Miln'~ Pt., pt. Mac CD 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-28 8 ATTN: Beth Received by: . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO' DATE: THRU: FROM: SUBJECT: Julie HeUsser' ~¢' CommiSsioner Tom Maunder, ~'/-~~ . P. I. Supervisor ~.c.. ChuCk SCheve; Petroleum Inspector December 15, 2000 Safety Valve Tests Prudhoe Bay Unit Drill Site 17 Friday, December 15, 2000' I traveled to BPX's Drill Site 17 and witnessed the semi annual safety valve System testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 15 wells and 30 components with one failure. The Surface Safety Valve on Well 17-4 Failed to close on its initial test. After this valve was serviced and the · hyd lines flushed it operated properly and passed the retest. Mark Womble performed the testing today; he demonstrated good test procedures and was a pleasure to work with. I also inspected the wellhouses on this location while witnessing SVS tests. All the wellhouses and associated equipment appeared clean and in good condition Summary: I witnessed SVS testing at BPX's PBU Drill Site 17. PBU DS17, 15 wells 30 components 1 failure 3.3% failure rate · 19 Wellhouse inspections' AttaChment: SVS PBU DS17 12-15-00 CS X Unclassified Confidential (Unclassified if doc. removed ) Confidential· Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: BPX Operator Rep: Mark Womble AOGCC Rep: Chuck ScheVe .' Submitted By: Chuck Scheve Field/Unit/Pad: Prudhoe / PBU / DS 17 Separator psi: LPS 165 Date: 12/15/00 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 17-01 1800550 165 150! 130~ p p OIL 17-02 1800700 165 1501 100! p p OIL 17-03A 1972160 165 150 110 P P OIL 17-04A 1960500 165 150 120 P 5 12/15/00 OIL 17-05 1800960 165 150i 1101 P P OIL 17-06 1801320 17-07 1810660' 165 150 140! P P OIL 17-08 1810740 17-09 1810900 165! 150 100 P P OIL 17-10A 1991100 17-11 1842440 165 150!. 120! P P OIL 17-12 1842450 165! 1501 120 P P OIL 17-13 '1841790 165 150 110: P P OIL 17-14 1841660 165 150 140 P P OIL 17-15A 1991310 17-16 1920910 165 150 -130 P P OIL 17-19A 1970550 165 150 130 P P OIL 17-20 1921150 165 150 1201 P P OIL 17-21 1921250 165 150 130! P P OIL Wells: 15 CompOnents: 30 Failures: 1 Failure Rate: 3.3% Remarks: SUrface Safety on 17-4 failed to close, it was serViced and retested. ,',,,,,,^,, p~o~ 1 r, fl SVS PBU DS17 12-15-00 CS.xls ON OR BEFORE W PERMIT DATA --- AOOCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 04/07/99 T / RUN RECVD D .............. 97-055 OR-TVD ~.i~:~ <~/~8850 97-055 GR-TVD ~L 8870-8960 97-055 GR-TVD ~:8870-8960 97-055 GR/SSTVD ~800-8900 FINAL 05/12197 FINAL 05/12/97 FINAL 05/12/97 FINAL 05/12/97 97-055 OR/NEO SSTVD ~B"8850 97-055 GR-MD ~L'~0000-13170 97-055 GR/SSTVD ~L~-8800-8900 97-055 OR-MD ~/~0000-13170 FINAL 05/12197 FINAL 05/12/97 FINAL 05/12/97 FINAL 05/12/97 97-055 7705 ~:MWD 9999-13183 97-055 SRVY LSTNG ~'BH 10003-13118 97-055 TEMP-PRES ~,~ 9850-10148 / J ~-~-~ 97-055 STAT TEM/PRES ,-L 95o0-10176 1~1~-? 97-055 PRES/TEM SRV-Y ~m'~9850-10155 06/09/97 08/18/97 FINAL 07/02/98 ~INAL O7/O2/98 ~iNAL 12/03/98 10-407 ~COMPLETION DATE @ ~/~JT~)/ DAILY WELL OPS R @~_ /~'~/~.2/ TO Are dry ditch samples required? yes received? Was the well cored? yes ,n~? Analysis & description received? Are well tests required? ,yes ~q::~.Received? Well is in compliance I~itial COMMENTS /. :./~/// @: /~//:-.> / ye s--~n~ ..... yes .... no- · BOX 11/30/98 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12105 Companl Alaska Oil & Gas Cons Comm Attn: Loft Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL Sepia Disk Tape GNI #3 PRESS/TEMP SURVEY 980803 1 1 D.S. 1-14 PRODUCTION PROFILE 980907 1 1 D.S. 07-34 PRODUCTION PROFILE 980924 1 D.S.11-01A RST-SIGMA 980609 ] ] D.S. 12-09 PRODUCTION PROFILE W/DEFT 980806 I ] D.S. 12-19 [/,~ INJECTION PROFILE 980913 I 1 D.S. 12-23 IxJ~/ INJECTION PROFILE 980922 ] ] D.S. 13-01 PRODUCTION PROFILE W/DEFT 980818 I ] D.S. 13-22 (~lc INJECTION PROFILE 980810 I 1 D./S. 13-32 %~[~ INJECTION PROFILE 980804 1 D.S. 14-21 Lit f_, INJECTION PROFILE 980811 I 1 D.S. 16-04A PRODUCTION PROFILE 980923 1 ] D.S. 17-15 ~, INJECTION PROFILE 980828 ] ] D.S. 17-19~ PRESSURE & TEMPERATURE SURVEY 980601 SIGNE.~t~ /~_~J/ DAT~:' ,. Please sign and return o py of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well I~ Oil I--I Gas [] Suspended I--I Abandoned [--I Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 97-55 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22297-01 4. Location of well at surface ................. ~1 9. Unit or Lease Name 2534 SNL, 4288 WEL, SEC. 22, T10N, RI~E" 'i~,¥~' ~ ,~~ ~~--;--.-,;'~ ~ Prudhoe Bay Unit At top of productive interval i. /_MJ)/~/~ ! 10. Well Number 2859' SNL, 2856' WEL, SEC. 21, T10N, RI~iE-~.'~.~"~' i 17-19A At total depth ' ' ~4~ 11. Field and Pool 1760 SNL, 493 WEL, SEC. 20, T10N, R15.E Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 64' AMSLI ADL 028330 12. Date Spudded4/4/97 113' Date T'D' Reached ] 14' Date C°mp" Susp" °r AbanO'115' water depth' if °ffshOre 116' NO' °f C°mpleti°ns4/22/97 4/25/97 N/A MSLI One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 13181 8828 FTI 13181 8828 FTI J~Yes J--JNoI (Nipple) MD I 1900' (Approx.) 22. Type Electric or Other Logs Run GR, CCL, MWD, LWD/FE, RES, GR 23. CASINGr LINER AND CEMENTING RECORD CASING S E"I-I-ING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 76' 30" ill yds Arctic Set 10-3/4" 45.5# NT-80 31' 3846' 13-1/2" _~257 cuft Arctic Set III, 404 cuft Class 'G' 7-5/8" 29.7# L-80 29' 9828' 9-7/8" 7" 26fl 13Cr FOX 9828' 10010' 9-7/8" A49 cu ft Class 'G' 2-7/8" 6.4# L-80 9730' 13140' 3-3/4" LJncemented Slotted Liner 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Slotted Liner 4-1/2", 12.6#, 13Cr8~/ 99~1.0' 9761' MD TVD MD TVD 10725' - 13138' 8869' - 8830' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 40 Bbls of Diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) April 29, 1997! Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAWTY-API (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. ORIGINAL · ~ ,,'~ - I - .-~ Ci;.; clJ~j,l; ..,;.'. - .; Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Sag River 10002' 8865' Shublik 10034' 8892' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I herebYsigned certifYDan Stoltzthat ~.h e~~~~~the, ore oing~~~7.is ,-t r.u e.an~ co rrect, to theTitlebeStseniorOf my Drillingkn°wledgeEn~lineer Date 7-19A 551 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No. / Approval No. 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility PB DS 17 Progress Report Well 17-19A Rig Doyon 16 Page Date 1 09 July 97 Date/Time 29 Mar 97 30 Mar 97 31 Mar 97 01 Apr 97 05:00-06:00 06:00-06:30 06:30-08:30 08:30-12:00 12:00-12:15 12:15-18:00 18:00-18:30 18:30-19:30 19:30-22:30 22:30-02:00 02:00-05:00 05:00-06:00 06:00-06:30 06:30-08:00 08:00-12:00 12:00-12:30 12:30-12:45 12:45-18:00 18:00-18:30 18:30-20:30 20:30-21:00 21:00-21:45 21:45-23:00 23:00-00:00 00:00-02:00 02:00-02:15 02:15-06:00 06:00-06:30 06:30-08:30 08:30-10:00 10:00-12:00 12:00-12:15 12:15-14:30 14:30-17:00 17:00-18:00 18:00-18:30 18:30-19:00 19:00-22:00 22:00-23:30 23:30-01:00 01:00-01:15 01:15-04:00 04:00-04:30 04:30-06:00 06:00-06:30 06:30-07:30 07:30-07:45 07:45-10:00 10:00-10:30 10:30-11:00 11:00-14:30 14:30-15:30 15:30-16:00 16:00-16:15 Duration lhr 1/2 hr 2hr 3-1/2 hr 1/4 hr 5-3/4 hr 1/2 hr lhr 3hr 3-1/2 hr 3hr lhr 1/2 hr 1-1/2 hr 4hr 1/2 hr 1/4hr 5-1/4 hr 1/2 hr 2hr 1/2hr 3/4 hr 1-1/4 hr lhr 2hr 1/4 hr 3-3/4 hr 1/2 hr 2hr 1-1/2 hr 2hr 1/4 hr 2-1/4 hr 2-1/2 hr lhr 1/2 hr 1/2 hr 3hr 1-1/2 hr 1-1/2 hr 1/4 hr 2-3/4 hr 1/2 hr 1-1/2 hr 1/2hr lhr 1/4 hr 2-1/4 hr 1/2 hr 1/2 hr 3-1/2 hr lhr 1/2 hr 1/4 hr Activity Rig moved 0.00 % Held safety meeting Rig moved 90.00 % Rig moved 100.00 % Held drill (Spill) Installed BOP stack Held safety meeting Rigged up Lubricator Installed BOP stack Tested BOP stack Rigged down Lubricator Singled in drill pipe to 30.00 ft Held safety meeting Rigged up Wellhead connector Singled in drill pipe to 2030.00 ft Circulated at 2030.00 ft Held drill (Kick while tripping) Singled in drill pipe to 9030.00 ft Held safety meeting Singled in drill pipe to 10105.00 ft Circulated at 10105.00 ft Mixed and pumped slurry - 20.000 bbl Reverse circulated at 10100.00 ft Pulled Drillpipe in stands to 8530.00 ft Rigged up Kelly/top drive hose Held drill (Fire) Pulled Drillpipe in stands to 30.00 ft Held safety meeting Rigged down Bell nipple Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Held drill (Fire) Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Rigged up Bell nipple Held safety meeting Made up BHA no. 1 R.I.H. to 9785.00 ft Milled Other sub-surface equipment at 9810.00 ft Circulated at 10040.00 ft Flow check Pulled out of hole to 0.00 ft Rigged down Bell nipple Conducted slickline operations on Slickline equipment - Tool run Held safety meeting Conducted slickline operations on Slickline equipment - Tool run Held drill (H2S) Conducted slickline operations on Slickline equipment - Tool run Rigged up Bell nipple Made up BHA no. 2 R.I.H. to 10070.00 ft Reamed to 10030.00 ft Circulated at 10030.00 ft Flow check Facility Date]Time 02 Apr 97 03 Apr 97 04 Apr 97 05 Apr 97 PB DS 17 Progress Report Well 17-19A Rig Doyon 16 Duration Activity 16:15-17:30 17:30-18:00 18:00-18:30 18:30-18:45 18:45-21:00 21:00-21:30 21:30-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-10:00 10:00-14:00 14:00-15:00 15:00-17:30 17:30-18:00 18:00-18:30 18:30-19:00 19:00-22:00 22:00-22:30 22:30-23:00 23:00-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-09:00 09:00-09:30 09:30-10:00 10:00-13:30 13:30-17:00 17:00-22:30 22:30-02:00 02:00-02:30 02:30-03:00 03:00-04:00 04:00-06:00 06:00-06:30 06:30-08:00 08:00-09:00 09:00-10:00 10:00-11:30 11:30-04:00 04:00-04:30 04:30-05:00 05:00-05:30 05:30-06:00 06:00-08:30 08:30-09:00 09:00-10:00 10:00-13:30 13:30-14:30 14:30-15:30 15:30-18:00 18:00-20:00 20:00-21:00 1-1/4 hr 1/2 hr 1/2 hr 1/4 hr 2-1/4 hr 1/2 hr 7hr lhr 1/2 hr 1/2hr 3-1/2 hr 4hr lhr 2-1/2 hr 1/2hr 1/2 hr 1/2 hr 3hr 1/2 hr 1/2 hr 5hr lhr lhr 1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 3-1/2 hr 5-1/2 hr 3-1/2 hr 1/2hr 1/2 hr lhr 2hr 1/2 hr 1-1/2 hr lhr lhr 1-1/2 hr 16-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 1/2hr lhr 3-1/2 hr lhr lhr 2-1/2 hr 2hr lhr Pulled out of hole to 9100.00 ft Circulated at 9100.00 ft Held safety meeting Circulated at 9100.00 ft Pulled out of hole to 0.00 ft Rigged down Bell nipple Conducted electric cable operations Rigged up Bell nipple Made up BHA no. 3 Held safety meeting R.I.H. to 10006.00 ft Milled Casing at 10010.00 ft Circulated at 10010.00 ft Pulled out of hole to 87.00 ft Pulled BHA Held safety meeting Made up BHA no. 4 R.I.H. to 9871.00 ft Reamed to 9871.00 ft R.I.H. to 10010.00 ft Milled Casing at 10017.00 ft Circulated at 10017.00 ft Serviced Block line Held safety meeting Pulled out of hole to 87.00 ft Pulled BHA Made up BHA no. 5 R.I.H. to 10006.00 ft Milled Casing at 10021.00 ft Circulated at 10021.00 ft Pulled out of hole to 87.00 ft Pulled BHA Made up BHA no. 6 Tested MWD - Via string R.I.H. to 2500.00 ft Held safety meeting R.I.H. to 10016.00 ft Set tool face Drilled to 10040.00 ft Performed formation integrity test Drilled to 10192.00 ft Circulated at 10192.00 ft Worked toolstring at 10010.00 ft Circulated at 10192.00 ft Pulled out of hole to 9250.00 ft Pulled out of hole to 49.00 ft Pulled BHA Made up BHA no. 7 R.I.H. to 10058.00 ft Worked toolstring at 10058.00 ft Washed to 10192.00 ft Drilled to 10229.00 ft Worked toolstring at 10201.00 ft Reamed to 10201.00 ft Page Date 2 09 July 97 Facility Date/Time 06 Apr 97 07 Apr 97 08 Apr 97 09 Apr 97 PB DS 17 Progress Report 21:00-04:00 04:00-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-07:00 07:00-07:30 07:30-09:00 09:00-11:30 11:30-12:30 12:30-13:00 13:00-14:00 14:00-15:00 15:00-17:30 17:30-18:00 18:00-19:00 19:00-20:00 20:00-06:00 06:00-09:00 09:00-09:30 09:30-10:00 10:00-12:30 12:30-13:30 13:30-18:00 18:00-18:30 18:30-19:00 19:00-20:30 20:30-21:30 21:30-00:30 00:30-01:00 01:00-02:00 02:00-03:00 03:00-04:00 04:00-06:00 06:00-06:30 06:30-11:00 11:00-13:00 13:00-17:30 17:30-18:00 18:00-21:00 21:00-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-08:00 08:00-09:00 09:00-11:00 11:00-11:30 11:30-13:30 13:30-15:00 15:00-18:00 18:00-18:30 18:30-21:30 21:30-22:00 Duration 7hr 1/2 hr lhr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 2-1/2 hr lhr 1/2 hr lhr lhr 2-1/2 hr 1/2 hr lhr lhr 10hr 3hr 1/2hr 1/2hr 2-1/2 hr lhr 4-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr lhr 3hr 1/2 hr lhr lhr lhr 2hr 1/2 hr 4-1/2 hr 2hr 4-1/2 hr 1/2hr 3hr 8hr lhr 1/2hr 1/2hr lhr lhr 2hr 1/2 hr 2hr 1-1/2 hr 3hr 1/2 hr 3hr 1/2 hr Well 17-19A Rig Doyon 16 Activity Drilled to 10301.00 ft Pulled out of hole to 9916.00 ft Rest hole at 9916.00 ft Circulated at 10301.00 ft Pulled out of hole to 10020.00 ft Circulated at 10020.00 ft R.I.H. to 10301.00 ft Drilled to 10323.00 ft Circulated at 10323.00 ft Pulled out of hole to 9100.00 ft Circulated at 9100.00 ft Pulled out of hole to 7300.00 ft R.I.H. to 9994.00 ft Circulated at 9994.00 ft R.I.H. to 10323.00 ft Circulated at 10323.00 ft Circulated at 10323.00 ft Pulled out of hole to 1500.00 ft Pulled out of hole to 148.00 ft Pulled BHA Rigged up High pressure lines Tested BOP stack Made up BI-IA no. 8 R.I.H. to 8925.00 ft Held safety meeting R.I.H. to 9920.00 ft Circulated at 9920.00 ft Circulated at 10323.00 ft Rest hole at 10323.00 ft Circulated at 9920.00 ft R.I.H. to 10058.00 ft Circulated at 9940.00 ft Pulled out of hole to 9208.00 ft Circulated at 9208.00 ft Held safety meeting Pulled out of hole to 49.00 ft Pulled BHA R.I.H. to 10058.00 ft Set tool face Circulated at 9930.00 ft Pulled out of hole to 50.00 ft Pulled BHA Held safety meeting Made up BHA no. 8 R.I.H. to 2325.00 ft Serviced Block line R.I.H. to 9931.00 ft Tested M.W.D. tool - Via string Washed to 10058.00 ft Circulated at 9932.00 ft Pumped out of hole to 5800.00 ft Held safety meeting Pumped out of hole to 85.00 ft Pulled BHA Page Date 3 09 July 97 Facility Date/Time 10 Apr 97 11 Apr 97 12 Apr 97 13 Apr 97 14 Apr 97 PB DS 17 Progress Report Well 17-19A Page 4 Rig Doyon 16 Date 09 July 97 22:00-23:00 23:00-04:00 04:00-06:00 06:00-06:30 06:30-08:00 08:00-14:30 14:30-15:00 15:00-15:30 15:30-18:00 18:00-18:30 18:30-19:30 19:30-22:30 22:30-00:00 00:00-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-09:30 09:30-13:30 13:30-14:00 14:00-14:30 14:30-22:30 22:30-23:00 23:00-23:30 23:30-00:30 00:30-01:30 01:30-06:00 06:00-09:00 09:00-09:30 09:30-10:00 10:00-14:30 14:30-15:00 15:00-17:30 17:30-19:00 19:00-20:30 20:30-21:00 21:00-23:00 23:00-04:30 04:30-05:00 05:00-06:00 06:00-06:30 06:30-09:00 09:00-10:00 10:00-11:00 11:00-12:00 12:00-22:00 22:00-23:00 23:00-01:00 01:00-03:00 03:00-06:00 06:00-09:30 09:30-10:00 10:00-21:00 Duration lhr 5hr 2hr 1/2 hr 1-1/2 hr 6-1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 1/2 hr lhr 3hr 1-1/2 hr 6hr 1/2 hr lhr 1/2 hr 1-1/2 hr 4hr 1/2 hr 1/2 hr 8hr 1/2 hr 1/2 hr lhr lhr 4-1/2 hr 3hr 1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 2-1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 2hr 5-1/2 hr 1/2 hr lhr 1/2hr 2-1/2 hr lhr lhr lhr 10hr lhr 2hr 2hr 3hr 3-1/2 hr 1/2 hr llhr Activity Made up BHA no. 9 R.I.H. to 10026.00 ft Washed to 10070.00 ft Held safety meeting Circulated at 9960.00 ft Pulled out of hole to 80.00 ft Pulled BHA Made up BHA no. 10 R.I.H. to 7200.00 ft Held safety meeting R.I.H. to 10058.00 ft Reamed to 10070.00 ft Circulated at 10058.00 ft Pumped out of hole to 5300.00 ft Held safety meeting Pumped out of hole to 80.00 ft Pulled BHA Made up BHA no. 11 R.I.H. to 9960.00 ft Tested M.W.D. tool - Via string R.I.H. to 10070.00 ft Drilled to 10227.00 ft Flow check Laid down 220.00 ft of 2-3/8in OD drill pipe Circulated at 9963.00 ft Flow check Pumped out of hole to 2500.00 ft Pumped out of hole to 80.00 ft Pulled BHA Made up BHA no. 12 R.I.H. to 10115.00 ft Washed to 10227.00 ft Drilled to 10260.00 ft Tested M.W.D. tool - Via string Circulated at 9931.00 ft Pulled out of hole to 9745.00 ft Circulated at 9745.00 ft Pumped out of hole to 80.00 ft Pulled BHA Made up BHA no. 12 Held safety meeting R.I.H. to 7285.00 ft Serviced Block line R.I.H. to 10216.00 ft Logged hole with LWD: Formation evaluation (FE) from 10216.00 ft to 10260.00 ft Drilled to 10415.00 ft Circulated at 9931.00 ft Circulated at 9931.00 ft Circulated at 9931.00 ft Circulated at 9931.00 ft Circulated at 9931.00 ft R.I.H. to 10415.00 ft Drilled to 10700.00 ft Facility Date/Time 15 Apr 97 16 Apr 97 17 Apr 97 18 Apr 97 19 Apr 97 PB DS 17 Progress Report Well 17-19A Rig Doyon 16 Page Date Duration Activity 21:00-22:00 22:00-23:00 23:00-06:00 06:00-06:30 06:30-07:00 07:00-07:30 07:30-08:00 08:00-11:00 11:00-11:30 11:30-12:00 12:00-16:00 16:00-16:30 16:30-17:30 17:30-19:00 19:00-21:30 21:30-22:00 22:00-23:00 23:00-06:00 06:00-06:30 06:30-07:00 07:00-08:00 08:00-13:00 13:00-17:30 17:30-18:00 18:00-18:30 18:30-00:00 00:00-00:15 00:15-06:00 06:00-06:30 06:30-13:00 13:00-13:15 13:15-18:00 18:00-18:30 18:30-22:30 22:30-23:30 23:30-00:30 00:30-01:00 01:00-06:00 06:00-06:30 06:30-09:00 09:00-09:30 09:30-10:00 10:00-11:00 11:00-11:15 11:15-16:30 16:30-18:00 18:00-18:30 18:30-22:30 22:30-00:00 00:00-01:00 01:00-01:30 01:30-06:00 06:00-06:30 06:30-08:30 1/2 hr lhr 7hr 1/2 hr 1/2 hr lhr 5hr 4-1/2 hr 1/2 hr 1/2 hr 5-1/2 hr 1/4 hr 5-3/4 hr 1/2 hr 6-1/2 hr 1/4 hr 4-3/4 hr 1/2hr 4hr lhr lhr 1/2 hr 5hr 1/2 hr 2-1/2 hr 1/2hr 1/2hr lhr 1/4hr 5-1/4 hr 1-1/2 hr 1/2 hr 4hr 1-1/2 hr lhr 1/2 hr 4-1/2 hr 1/2 hr 2hr Circulated at 9931.00 ft Circulated at 9931.00 ft Pumped out of hole to 1500.00 ft Held safety meeting Pulled out of hole to 80.00 ft Pulled BHA Retrieved B ore protector Tested BOP stack Installed B ore protector Made up BHA no. 13 R.I.H. to 10670.00 ft Washed to 10700.00 ft Took MWD survey at 10671.00 ft Drilled to 10762.00 ft Took MWD survey at 10071.00 ft Pulled out of hole to 9963.00 ft Circulated at 9963.00 ft Pumped out of hole to 80.00 ft Held safety meeting Pulled BHA Made up BHA no. 14 R.I.H. to 10762.00 ft Drilled to 10872.00 ft Held drill (Fire) Held safety meeting Drilled to 11077.00 ft Held drill (Kick while drilling) Drilled to 11360.00 ft Held safety meeting Drilled to 11550.00 ft Held drill (Spill) Drilled to 11780.00 ft Held safety meeting Drilled to 11908.00 ft Circulated at 11908.00 ft Pulled out of hole to 9963.00 ft Circulated at 9963.00 ft Pulled out of hole to 5300.00 ft Held safety meeting Pulled out of hole to 0.00 ft Pulled BHA Made up BHA no. 15 R.I.H. to 2980.00 ft Held drill (H2S) R.I.H. to 11908.00 ft Drilled to 11918.00 ft Held safety meeting Drilled to 11962.00 ft Functioned downhole tools at 11962.00 ft Pulled out of hole to 11001.00 ft R.I.H. to 11962.00 ft Drilled to 12000.00 ft Held safety meeting Drilled to 12023.00 ft 5 09 July 97 Facility Date]Time 20 Apr 97 21 Apr 97 22 Apr 97 23 Apr 97 24 Apr 97 PB DS 17 Progress Report Well 17-19A Rig Doyon 16 Page Date Duration Activity 08:30-09:30 09:30-11:00 11:00-13:00 13:00-15:00 15:00-15:15 15:15-18:00 18:00-18:30 18:30-21:30 21:30-22:00 22:00-02:00 02:00-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-09:00 09:00-16:00 16:00-17:00 17:00-18:00 18:00-22:30 22:30-23:30 23:30-06:00 06:00-06:30 06:30-06:00 06:00-06:30 06:30-10:30 10:30-14:30 14:30-15:30 15:30-18:00 18:00-21:00 21:00-21:30 21:30-23:00 23:00-00:00 00:00-04:30 04:30-05:00 05:00-06:00 06:00-06:30 06:30-11:00 11:00-11:30 11:30-12:00 12:00-13:00 13:00-17:30 17:30-18:00 18:00-18:30 18:30-01:00 01:00-02:30 02:30-06:00 06:00-06:30 06:30-07:00 07:00-13:00 13:00-14:30 14:30-16:30 16:30-18:00 18:00-19:30 19:30-21:00 lhr 1-1/2 hr 2hr 2hr 1/4 hr 2-3/4 hr 1/2hr 3hr 1/2 hr 4hr 4hr 1/2hr lhr lhr 1/2hr 7hr lhr lhr 4-1/2 hr lhr 6-1/2 hr 1/2 hr 23-1/2 hr 1/2 hr 4hr 4hr lhr 2-1/2 hr 3hr 1/2 hr 1-1/2 hr lhr 4-1/2 hr 1/2 hr lhr 1/2 hr 4-1/2 hr 1/2 hr 1/2 hr lhr 4-1/2 hr 1/2 hr 1/2 hr 6-1/2 hr 1-1/2 hr 3-1/2 hr 1/2hr 1/2hr 6hr 1-1/2 hr 2hr 1-1/2 hr 1-1/2 hr 1-1/2 hr Took MWD survey at 12023.00 ft Drilled to 12035.00 ft Circulated at 12035.00 ft Pulled out of hole to 9963.00 ft Held drill (Fire) Pulled out of hole to 6379.00 ft Held safety meeting Pulled out of hole to 0.00 ft Pulled BHA Made up BHA no. 16 R.I.H. to 9000.00 ft Held safety meeting R.I.H. to 12024.00 ft Circulated at 12024.00 ft Circulated at 12024.00 ft Pulled out of hole to 113.00 ft Laid down fish Made up BHA no. 17 R.I.H. to 11975.00 ft Washed to 12035.00 ft Drilled to 12176.00 ft Held safety meeting Drilled to 13086.00 ft Held safety meeting Drilled to 13137.00 fl Drilled to 13181.00 ft Circulated at 13181.00 ft Circulated at 13181.00 ft Pulled out of hole to 9963.00 ft Serviced Block line R.I.H. to 13181.00 ft Circulated at 13181.00 ft Laid down 3255.00 ft of 2-3/8in OD drill pipe Circulated at 9963.00 ft Pulled out of hole to 9000.00 ft Held safety meeting Pulled out of hole to 125.00 ft Downloaded MWD tool Pulled BHA Installed Internal BOPs Ran Liner to 3393.00 ft (2-7/8in OD) Rigged up sub-surface equipment - Liner hanger Serviced Drillfloor / Derrick Ran Liner on landing string to 9730.00 ft Set packer at 9730.00 ft with 4200.0 psi Laid down 3000.00 ft of Drillpipe Held safety meeting Flow check Laid down 6000.00 ft of Drillpipe Installed Internal BOPs Removed BOP stack Installed Xmas tree Installed BOP test plug assembly Freeze protect well - 40.000 bbl of Diesel 6 09 July 97 Facility Date/Time 25 Apr 97 PB DS 17 Progress Report 21:00-22:30 22:30-01:00 01:00-04:30 04:30-05:00 05:00-06:00 Duration 1-1/2 hr 2-1/2 hr 3-1/2 hr 1/2 hr lhr Well 17-19A Rig Doyon 16 Activity Functioned Xmas tree Rigged down BOP stack Rig moved 100.00 % Rigged up Drillfloor / Derrick Installed Drillfloor / Derrick Page Date 7 09 July 97 Performance Enquiry Report Operator ARCO Date 15:57, 13 Aug 97 Page 1 The analysis is from - 11:30, 04 Apr 97 - to - 11:30, 04 Apr 97 Programs in Result Table: 17-19A Drill and Complete ST Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) 17-19A Event 11:30, 04 Apr 97 11:30, 04 Apr 97 0 hr 0 min Obtained leak off 9.400 Hole Size MDR 3-3/4 ~ALASKA,O eare. d rvice$ rilling BP Exploration / Arco To: Alaska Oil & Gas Conservation Commission Date: August 13, 1997 From: Subject: Terrie Hubble Technical Assistant Permit To Drill #97-55, 17-19A Due to a conversion error, the location of the well at total depth was listed incorrectly on the original Permit To Drill. This was discovered while computing this location for the Completion Report. Originally Permitted (Incorrectly) Should Have Been Permitted Location of well at total depth Location of well at total depth 4142' NSL, 205' WEL, SEC. 20, T10N, R15E 3495' NSL, 1455' WEL, SEC. 20, T10N, R15E Additionally, the well was planned to a TD of 14063', but only achieved 13181 '. This, of course, explains the discrepancy between the planned and actual TD location for this well. I apologize for any inconvenience this may have caused. Please let me know if there is any further action required. Thank you for your assistance and patience in this matter. /tlh ORIGINAL ARCO ALASKA, Inc. D.S. 17 19A slot #19 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : PMSS <10003-13118'> 01-May-97 Our ref : svy5568 License : Date printed : 5-May-97 Date created : 2-May-97 Last revised : 2-May-97 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on nTO 12 49.747,w148 19 15.042 Slot location is n70 12 24.824,w148 18 46.109 Slot Grid coordinates are N 5928109.983, E 709245.718 Slot local coordinates are 2534.04 S 996.95 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO ALASKA, Inc. D.S. 17,19A Prudhoe Bay, North Slope, Alaska SURVEY LISTING Page 1 Your ref : PMSS <10003-13118'> 01-May-97 Last revised : 2-May-97 Measured Inclin. Azin~Jth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S Dogleg Vert Deg/lOOft Sect 10003.00 27.91 266.29 8866.00 324.07 S 3848.69 W 0.00 3657.27 10010.00 27.91 266.29 8872.19 324.28 S 3851.96 W 0.00 3660.39 10036.57 40.50 267.00 8894.12 325.14 S 3866.84 W 47.41 3674.63 10060.00 46.64 267.32 8911.08 325.94 S 3882.96 W 26.22 3690.08 10071.70 43.30 271.18 8919.36 326.05 S 3891.23 W 36.85 3698.08 10104.80 56.20 275.88 8940.71 324.40 S 3916.37 W 40.43 3722.88 10135.10 68.60 280.50 8954.73 320.53 S 3942.88 W 43.08 3749.54 10165.50 83.50 281.80 8962.03 314.83 S 3971.74 W 49.19 3778.92 10197.00 98.30 284.40 8961.54 307.71 S 4002.33 W 47.70 3810.32 10232.70 102.40 291.40 8955.12 296.94 S 4035.72 W 22.44 3845.33 10260.20 103.10 289.90 8949.05 287.48 S 4060.82 W 5.90 3871.97 10292.20 102.30 292.40 8942.02 276.22 S 4089.93 W 8.02 3902.93 10326.10 100.60 295.90 8935.28 262.62 S 4120.24 W 11.29 3935.63 10357.40 100.90 295.90 8929.45 249.19 S 4147.90 W 0.96 3965.71 10387.00 101.30 296.20 8923.75 236.43 S 4174.00 W 1.68 3994.11 10418.60 101.70 295.40 8917.45 222.96 S 4201.88 W 2.79 4024.41 10450.10 101.00 296.50 8911.25 209.44 S 4229.65 W 4.08 4054.62 10480.40 100.00 297.40 8905.73 195.94 S 4256.20 W 4.41 4083.65 10511.40 100.10 297.70 8900.32 181.82 S 4283.27 W 1.01 4113.31 10542.90 99.20 298.50 8895.04 167.20 S 4310.66 W 3.80 4143.42 10577.60 98.00 298.50 8889185 150.82 S 4340.81 W 3.46 4176.63 10608.90 98.10 298.90 8885.46 135.94 S 4367.99 W 1.31 4206.60 10639.70 98.00 297.90 8881.15 121.44 S 4394.82 W 3.23 4236.13 10671.70 98.00 302.40 8876.69 105.52 S 4422.21 W 13.93 4266.55 10703.40 98.20 302.30 8872.23 88.73 S 4448.73 W 0.70 4296.33 10733.10 98.40 303.20 8867.94 72.83 S 4473.44 W 3.07 4324.15 10761.00 97.70 301.40 8864.03 58.07 S 4496.79 W 6.86 4350.37 10795.90 95.70 296.80 8859.96 41.22 S 4527.07 W 14.29 4383.81 10824.50 91.90 297.60 8858.06 28.18 S 4552.45 W 13.58 4411.58 10858.90 91.90 296.50 8856.92 12.55 S 4583.07 ~ 3.20 4445.07 10890.50 90.80 291.70 8856.18 0.35 N 4611.90 W 15.58 4476.15 10921.90 90.90 290190 8855.71 11.75 N 4641.15 W 2.57 4507.29 10952.10 91.40 291.60 8855.11 22.70 N 4669.29 ~ 2.85 4537.24 10984.10 91.40 292.20 8854.33 34.63 N 4698.97 W 1.87 4568.92 11017.30 90.90 290.30 8853.66 46.66 N 4729.91 W 5.92 4601.84 11048.70 89.80 289.90 8853.47 57.45 N 4759.39 ~ 3.73 4633.06 11080.40 90.70 289.80 8853.33 68.21 N 4789.21 W 2.86 4664.59 11112.10 91.10 290.10 8852.83 79.03 N 4819.00 ~ 1.58 4696.11 11143.30 91.10 289.60 8852.23 89.62 N 4848.34 W 1.60 4727.14 11174.70 90.20 288.50 8851.88 99.87 N 4878.02 W 4.53 4758.41 11205.60 90.70 288.40 8851.63 109.65 N 4907.33 W 1.65 4789.22 11237.50 90.80 288.70 8851.22 119.79 N 4937.57 W 0.99 4821.01 11268.90 90.70 288.00 8850.80 129.68 N 4967.37 W 2.25 4852.32 11300.40 90.40 288.20 8850.50 139.46 N 4997.31 W 1.14 4883.73 11332.30 90.10 288.30 8850.36 149.45 N 5027.61 W 0.99 4915.54 11360.80 90.20 289.50 8850.29 158.69 N 5054.57 W 4.23 4943.93 11392.20 89.60 289.50 8850.34 169.17 N 5084.17 W 1.91 4975.18 11423.60 90.50 288.10 8850.32 179.29 N 5113.89 W 5.30 5006.47 11456.80 90.60 287.40 8850.00 189.41 N 5145.51 W 2.13 5039.60 11488.20 90.90 288.60 8849.59 199.11 N 5175.37 W 3.94 5070.91 All data is in feet unless otherwise stated. Coordinates from slot #19 and TVD from rotary table (64.00 Ft above mean sea level). Bottom hole distance is 6749.21 on azimuth 276.39 degrees from wellhead. Vertical section is from S 0.00 E 0.00 on azimuth 283.94 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO ALASKA, Inc. D.S. 17,19A Prudhoe Say,North Slope, Alaska SURVEY LISTING Page 2 Your ref : PMSS <10003-13118'> 01-May-97 Last revised : 2-May-97 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect 11518.50 90.90 287.80 8849.11 208.57 N 5204.15 W 2.64 5101.13 11551.10 91.00 288.40 8848.57 218.70 N 5235.13 W 1.87 5133.64 11581.60 91.30 288.60 8847.96 228.37 N 52(>4.05 W 1.18 5164.03 11613.00 91.40 287.70 88/+7.22 238.15 N 5293.E,B W 2.E,B 5195.34 11644.20 91.40 288.60 8846.46 247.87 N 5323.52 W 2.8,B 5226.45 11675.70 91.60 287.20 8845.63 257.55 N 5353.48 W 4.49 5257.~ 11707.40 92.10 286.50 8844.61 266.73 N 5383.80 W 2.71 5289.50 11739.10 92.50 2~.00 8843.34 275.59 N 5414.21 ~ 2.02 5321.15 11773.50 91.90 285.70 8842.01 28/+.98 N 5447.28 W 1.95 5355.50 11805.00 92.20 285.30 8840.89 293.40 N 547-/.62 W 1.59 5386.97 11836.60 92.50 285.50 8839.59 301.78 N 5508.06 W 1.14 5418.54 11868.30 92.90 285.20 8838.10 310.16 N 5538.59 W 1.58 5450.19 11903.90 93.80 285.90 8836.02 319.69 N 5572.83 W 3.20 5485.72 11933.50 93.20 286.10 8834.21 327.83 N 5601.23 W 2.14 5515.24 11960.80 92.70 286.20 8832.81 335.42 N 5627.42 W 1.87 5542.48 11992.30 91.00 285.90 8831.79 344.12 N 5657.67 W 5.48 5573.95 12019.00 88.60 291.90 8831.88 352.76 N 5682.92 W 24.20 5600.53 12052.20 86.80 292.40 8833.22 365.27 N 5713.64 W 5.63 5633.36 12084.10 86.50 292.60 8835.08 377.46 N 5743.06 ~ 1.13 5664.85 12114.10 86.50 292.30 8836.91 388.89 N 5770.74 ~ 1.00 5694.47 12147.30 87.60 292.90 8838.62 401.63 N 5801.35 W 3.77 5727.25 12179.00 88.70 292.50 8839.64 413.86 N 5830.58 W 3.69 5758.56 12210.20 88.80 291.10 8840.32 425.44 N 5859.54 W 4.50 5789.46 12241.80 88.90 291.00 8840.96 436.79 N 5889.02 W 0.45 5820.81 12273.60 88.90 291.00 8841.57 448.19 N 5918.71 W 0.00 5852.36 12304.70 89.10 290.10 8842.11 459.10 N 5947.82 W 2.96 5883.25 12334.80 89.50 290.40 8842.48 469.52 N 5976.06 W 1.66 5913.16 12368.00 89.60 290.60 8842.74 481.14 N 6007.16 W 0.67 5946.15 12399.50 89.70 290.70 8842.93 492.25 N 6036.63 W 0.45 5977.43 12431.40 90.10 290.60 8842.99 503.50 N 60~.48 ~ 1.29 6009.11 12462.70 90.20 290.60 8842.91 514.52 N 6095.78 W 0.32 6040.20 12493.90 90.40 290.90 8842.74 525.57 N 6124.96 W 1.16 6071.18 12525.00 90.60 290.50 8842.47 536.56 N 6154.05 ~ 1.44 6102.06 12556.10 90.90 290.80 8842.06 547.53 N 6183.15 ~ 1.36 6132.95 12588.00 91.20 290.30 8841.48 558.72 N 6213.01 W 1.83 6164.63 12619.60 91.50 289.70 8840.73 569.53 N 6242.70 W 2.12 6196.04 12650.50 91.30 289.10 8839.98 579.79 N 6271.83 W 2.05 6226.79 12681.50 91.30 290.70 8839.28 590.34 N 6300.97 W 5.16 6257.62 12713.10 91.40 291.10 8838.53 601.61 N 6330.49 W 1.30 6288.98 12744.10 91.00 291.30 8837.88 612.82 N 6359.38 g 1.44 6319.72 12776.60 90.60 291.40 8837.43 624.65 N 6389.65 W 1.27 6351.95 12808.20 90.60 291.70 8837.10 636.25 N 6419.04 W 0.95 6383.27 12839.40 90.90 291.80 8836.69 647.81 N 6448.02 W 1.01 6414.17 12868.50 90.90 292.10 8836.23 658.69 N 6475.00 W 1.03 6442.99 12901.80 90.70 292.10 8835.77 671.22 N 6505.85 W 0.60 6475.95 12933.10 90.80 292.40 8835.36 683.07 N 6534.82 ~ 1.01 6506.91 12963.70 90.70 292.10 8834.96 694.65 N 6563.14 W 1.03 6537.19 12993.50 90.90 291.70 8834.54 705.77 N 6590.79 W 1.50 6566.70 13024.00 91.20 291.30 8833.98 716.94 N 6619.16 W 1.64 6596.93 13056.50 91.70 291.20 8833.16 728.72 N 6649.44 ~ 1.57 6629.16 All data is in feet unless otherwise stated. Coordinates from slot #19 and TVD from rotary table (64.00 Ft above m~an sea level). Bottom hole distance is 6749.21 on azimuth 276.39 degrees from wellhead. Vertical section is from S 0.00 E 0.00 on azimuth 283.94 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO ALASKA~ Inc. D.S. 17~ 19A Prudhoe Bay~North $lope~ Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D ! N A T E S 13088.60 92.10 291.30 8832.10 740.35 N 6679.34 13118.60 92.40 291.30 8830.92 751.24 N 6707.27 SURVEY LISTING Page 3 Your ref : PMSS <10003-13118'> 01-May-97 Last revised : 2-May-97 Dogleg Vert Deg/lOOft Sect 1.28 6660.98 1.00 6690.71 All data is in feet unless otherwise stated. Coordinates from slot #19 and TVD from rotary table (64.00 Ft above mean sea level). Bottom hole distance is 6749.21 on azimuth 276.39 degrees from wellhead. Vertical section ~s from S 0.00 E 0.00 on azimuth 283.94 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO ALASKA, Inc. D.S. 17,19A Prudhoe Bay, North Slope, Alaska SURVEY LISTING Page 4 Your ref : PMSS <10003-13118'> 01-May-97 Last revised : 2-May-97 Casing positions in string '7' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 8866.00 324.07S 3848.69~ 10003.00 8866.00 324.07S 3848.6914 7" Casing NO PROPOSAL 7/1/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11312 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia Disk LIS Tape GNI #1 TEMPERATURE LOG W/PRESSURE 980606 I 1 GNI #2 TEMPERATURE/PRESSURE LOG 980512 I 1 GNI #3 PRESSURE TEMPERATURE LOG 980606 1 1 -- D.S. 2-25 PRODUCTION PROFILE LOG 980511 1 1 D.S. 3-22 PRODUCTION LOG 980531 I 1 D.S. 3-24A GPJCCL LOG 980529 I I -- D.S. 3-31 STATIC PRESSURE SURVEY 98051 4 I 1 D.S. 9-44 PRODUCTION PROFILE LOG 980511 I 1 D.S. 11-2 INJECTION PROFILE LOG 98051 3 I 1 D.S. 11-05A PRODUCTION PROFILE 980527 I 1 D.S. 11-6 PRODUCTION PROFILE 980522 I 1 D.S. 11-24A PRODUCTION LOG & GAS LIFT SURVEY 980531 I 1 D.S. 12-33 bi. I (.~ INJECTION PROFILE 980528 I 1 D.S. 14-36 {~ ! ~ INJECTION PROFILE LOG 980604 I 1 ~).S, 17-19A STATIC PRESSURE SURVEY 9 8051 4 1 1 D.S, 17-19A PRESSURE & TEMPERATURE SURVEY 9 80601 1 1 ~. ~. o_~ DATE: JUL i, ~ Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Thank you. "7260 Homer Drive, Anchorage, Alaska 99518 907-267-6600 Fax: 907-267-6623 TRANSMITTAL State of Alaska Alaska Oil & Gas Conservation Com. 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Howard Okland 6/6/97 Well Reference Data: Well Name: DS 17-19A County: North Slope State: Alaska BItI Job No:84656 Enclosed is the following data as listed below: 1 MAGNETIC TAPE 1 LIS VERItlCATION LISTING Upon receipt, please sign and FAX to: Baker Hughes INTEQ ATTN: Raquel Olsbo Fax: 267-6623 Received By: Date: 7260 Homer Drive, Anchorage, Alaska 99518 907-267-6600 Fax: 907-267-6623 State of Alaska Alaska Oil Gas Conservation Comm. Attn: u ...... a ~,.-,- --,. L~(~ .~]~q.; vv ~s.,u,]~ ~J~ njg~lglll~l 3001 Porcupine Drive Anchorage, AK 99501 5/8/97 Well Reference Data: ~]~- 0~' ~ QTY Description QTY Description Well Name' DS 17-19A Field: Pmdhoe Bay County: North Slope State' Alaska 1:600 Measured Depth 1 Reversed Folded Sepia 1 OH Bluelines 1:600 Tree Vertical Depth 1 Reversed Folded Sepia 1 OH B uelines 1:600 Subse A TVD 1 Reversed Folded Sepia1 OH B uelines 1:240 Measured Depth 1 Reversed Folded Sepia1 OH B.,.uelines .. 1:240 Tree Vertical Depth 1 Reversed Folded Sepia1 OH Bluelmes 1:240 Subse A TVD 1 Reversed Folded Sepia1 OH Bluelines 1:240 Subse A Negative TV 1 Reversed Folded Sepia1 OH Bluelines 1:240 Negative TVD 1 Reversed Folded Sepia1 OH B,.uelines Total: 8 8 RECE Upon receipt, please fax this transmittal to:Raguel Olsbo 26'7-6623 TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPII'~= _.~RIVE ANCHORAGE, ... ,SKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 27, 1997 Dan Stoltz Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 17-19A BP Exploration (Alaska) Inc. Permit No. 97-55 Sur. Loc 2534'SNL, 4288'WEL, Sec. 22, T10N, R15E, UM Btmhole Loc. 4142'NSL, 205'WEL, Sec. 20, TION, R15E, UM Dear Mr. Stoltz: Enclosed is the approved application for permit to redrill the above referenced xvell. The permit to redrill 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission mav witness the test. Notice may be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ., Commissioner BY ORDER OF THE COMMISSION. dltTenclosures cc: Department of Fish & Game. Habitat Section w/o encl. Department of Envinornment Conservation ~/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMIVi,¢SION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Typeofwork []Re-Entry []Deepeni []Service []Development Gas []Single Zone []Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RKB 61.5' -- Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028330 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2534' SNL, 4288' WEL, SEC. 22, T10N, R15E Prudhoe Bay Unit At top of productive interval 8. Well Number '" Number U-630610 2763' NSL, 3675' WEL, SEC. 21, T10N, R15E 17-19A At total depth 9. Approximate spud date Amount $200,000.00 4142' NSL, 205' WEL, SEC. 20, T10N, R15E 03/28/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028331, 205'I DS 12-30, 301' at 11000' MD 2560 14063' MD / 8780' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10005' MD Maximum Hole Angle 99°i Maximum surface 3300 psig, At total depth (TVD) 8800' / 4390 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.4# L-80 ST-L 1500' 9730' 8562' 11334' 8781' Uncemented Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary 03RIGINAL Total depth: measured 10415 feet Plugs (measured) Fill at 10165' MD (05/2 " true vertical 9123 feet Effective depth: measured 10165 feet Junk (measured) true vertical 9011 feet Casing Length Size Cemented MD TVD Structural Conductor 76' 20" 11 yds Arcticset 76' 76' Surface 3780' 10-3/4" 2257 c.f. Arcticset III, 404 c.f. 'G' 3846' 3748' Intermediate 9762' 7-5/8" 9828' 8712' Production Liner 578' 7" 449 c.f. Class 'G' 9828'- 10406' 8712'-9226' RECEIVED Perforation depth: measured 10166'-10186' true vertical (Subsea) 8945'-8963' MAR 2 ~ 199 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Sea[~b¢. ~J[] ~.~~,m,a ' ' r m [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis []___.___ ..epu~.~.~u-..~,~--~JJ~jquirements Contact Engineer Name/~u~nber: Chris ~own, 564-5582 Prepared By Name/Numb¢r"'. '"'~ Campoamor, 564-5122 21. I hereby certify that th,~' for,~going i)¢t, rce ,a/,H'9~correct to the best of my knowledge Signed . Dan Sto,tz /~/'~- ,¢~~ Title Senior Drilling Engineer Date ~ -- ~'~' - "' Commission Use Only / ' / ' ' Permit Number I APINumber I ApprovalDate I Seecoverletter ~',~-,~',~ 50-0.2..."~'-- .,.~... ~ '~:~7 '"' ~ / O,~-. ~ ~..--¢¢ for other requirements j Yes No Conditions of Approval: Samples Required [] /h~i!¢~Yes Mud Log Required [] Yes .,~_/No Hydrogen Sulfide Measures [] No Directional Survey Required ~ Yes [] No Required Working Pressure for BOPE [] 2M; []3M; J~ 5M; [] 10M; [] 15M Other: by order of Approved By Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ii APPLICATION FOR SUNDRY APPROVAL 1 Type of Request:i Aban¢ m [] Suspend [] Plugging [] Time Extension [] Perforate · ~ Alter C ~sing [] Repair Well [] Pull Tubing [] Variance [] Other [ Chang Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operato~ .; 5. Type of well: 6. Datum Elevation (DF or KB) ~ Development KBE = 66' ARCO Alaska Inc. i.~ ~, [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Prudhoe Bay Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 17-19 2534' SNL, 992' EWL, SEC. 22, T10N, R15E 9. Permit Number At top of productive interval 92-111 2861' SNL, 2356' EWL, SEC. 21, T10N, R15E 10. APl Number At effective depth 50-029-22297 2864' SNL, 2349' EWL, SEC. 21, T10N, R15E 11. Field and Pool At total depth Prudhoe Bay Field / Prudhoe Bay 2872' SNL, 2236' EWL, SEC. 21, T10N, R15E Pool 12. Present well condition summary Total depth: truemeasuredvertical 191041235 feetfeet Plugs (measured) Fill at 10165' MD (0.~R~,-~~ ~ Effective depth: measured 10165 feet Junk (measured) true vertical 9011 feet Casing Length Size Cemented MD / TVD Structural Conductor 76' 20" 11 yds Arcticset 76' 76' Surface 3780' 10-3/4" 2257 c.f. Arcticset Ill, 404 c.f. 'G' 3846' 3748' Intermediate 9762' 7-5/8" 9828' 8712' Production Liner 578' 7" 449 c.f. Class 'G' 9828'-10406' 8712'-9226' Perforation depth: measured 10166'-10186' RECEIVED true vertical (Subsea) 8945'-8963' MAR 2 4 ]997 Tubing (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 to 9827' ~SJ(a 0il & Bas Cons. Commission A~chorage Packers and SSSV (type and measured depth) 7-5/8" Baker "SAB-3" packer at 9761'; Camco TRCF-4A SSSV at 2089' 13. Attachments ~ Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation 15. Status of well classifications as: March 26, 1997 16. If proposal was verbally approved [] Oil [] Gas [] Suspended Service Name of approver Date approved Contact Engineer Name/~umber: Chris Brown, 564-5582 Prepared By Name/Number: Kathy Campoamor, 564-5122 17. I hereby certify that/t~'~fo/)egoing/j~/"~/t,/¢ a~/X~orrect to the best of my knowledge Signed~ ~ Senior ' Date ,~/~//¢ Commission Use Only Conditions of Approval: Notify Commission so representative may witness I Approval No.,~- Plug integrity_ BOP Test ~ Location clearance __ Mechanical Integrity Test~ Subsequent form required 10- Approved by order of the Commission Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate I Well Name: 117-19A I TTRD Sidetrack Plan Summary IType of Redrill (producer or injector): I Shut In Producer Surface Location: 2534' FNL, 4288' FEL, S22, T10N, R15E, UM Target Location: 2763' FSL, 3675' FEL, S21, T10N, R15E, UM Bottom Hole Location: 4142' FSL, 205' FEL, S20, T10N, R15E, UM I AFE Number: ]4J0343 I Estimated Start Date: 1 3/28/97 I MD: I14,063' I ITVD: Im~: I Doyon 16 I I Operating days to complete: 124 18,780ss ~I~ 16~.5' I Well Design (conventional, slimhole, etc.): I Through tubing horizontal sidetrack I Objective: Access 970mstbo of new reserves west of existing wellbore Mud Program Drilling Fluids18.7 ppg QUIKDRILn (solids free) Density LSRV PV Chlor. pH Lubetex Biocide K:N SOLIDS ppg C.P.G. (CP) mg/L Concen. Ratio (%) 8.6 45,000 6 27,000 8.5 1.0% +100 ppm 2.4 <1.0% to to to to to to to to to 8.8+ 55,000 10 27,000 9.0 3.0% +-100 ppm 1 <1.0% Directional [KOP: I _+ ~ 0,005' MD (estimated) Maximum Hole Angle: Close Approach Well: +_99° DS 12-30, close approach distance 300.76' @ 11000'MD (plan), 12359.76'MD (DS 12-30) Casing/Tubing Program Hole Size Csg Wt/Ft Grade Conn Length Top Btm MDfrVDss MDfrVDss 3-3/4" 2-7/8 6.4 L-80 ST-L 1,500' 9730'/8562 11334'/8781' 17-19 Drilling Permit Page 2/3 Cement The liner will be of a slotted type on this well, and will not required cementing unless severe losses are encountered in the Shublik, in which cased a solid liner will be cemented and perforated. Well Control Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Hazards Sadlerochit pressure is _+3,308 psi at 8,800' TVDss or _+7.2 ppg EMW. There is a possible fault which will be encountered while drilling the Shublik. Should this be encountered, it is possible that severe losses may be encountered. Operational Summary 1. MIRU. ND tree, NU BOP's and test same. Remove BPV and retrieve plug in XN nipple. . . Test 9-5/8" packoff to 5,000psi, and function lock down screws (wellhead representative to do this). If any problems with the 9-5/8" packoff are observed, contact the wellhead manufacturer to initiate repairs. If repairs are not possible, the TTRD sidetrack will be halted, and an alternative sidetrack method used. M/U 3.8" OD milling assembly and RIH. Circulate out freeze protection. Mill out XN nipple at 9,811'. RIH to 3.64" ID obstruction at overshot guide at +9,822'. Mill out obstruction to 3.8". Mill second XN nipple at 9,899'. RECEIVED MAR 2 ,~- 1.~ ? Alaska Oil.& Gas Cons. Commissio~ Anchorage 17-19 Drilling Permit Page 3/3 , RIH to PBTD at 10,322' (elm) with cement stinger and spot a balanced cement plug from base of the well to 9,988'. Perform a hesitation squeeze and pump 5-10bbls of cement to the open perforations (10,008' to 10,186'). RIH to 10,025' reverse circulating out excess cement. Tag TOC as required for AOGCC representative. While POOH, stop and circulate at each GLM station to ensure no cement is left above the dummy gas lift valves. Pick up underreamer sized for 7" 26# casing, and underream interval from 10,000' to 10,025'. Tag TOC and POOH. , R/U electric line. Set Baker through tubing whipstock oriented for a 265° azimuth kickoff with top of whipstock at 10,005'. This will put the top of the whipstock 3' below the base of the Kingak formation at 10,002' which is known to be troublesome. Do not set the top of the whipstock any higher than 10,005'. If problems occur with setting the whipstock, call the operations engineer. 6. RIH with 3.75" window milling assembly. Tag whipstock/liner and mill out into formation. Do not mill out more than 6'. Dress window with second mill run if necessary. 7. RIH with 3.75" drilling assembly and drill 3.75" hole section to TD of 13,169'. If conditions allow, continue drilling to TD of 14,063'. 8. M/U and run 1,500ft of 2-7/8" slotted L80 liner. Hang off liner in 4-1/2" tubing at depth of _+9,730'. Circulate kill weight fluid and freeze protect. 9. R/U and set plug in 3.813" X nipple at _+9,701'. Set and test BPV, ND BOP, NU tree. RDMO. A II hared Services Drilling/ Field: Prudhoe Bay Location: Alaska Scale 1 ' 500.00 East -> -8100 -7800 -7500 -7200 -6900 -6600 -6300 -6000 -5700 -5400 -5100 -4800 -4500 -4200 -5900 -3600 -3500 1500., 1200 - 900 - -- 600 ' -- 300 - 0 - -- -300 - -600 - -900- -1200- -- -1500 ) I I I I J J I I _J I I .... I . I I _1 l, J. J I ~ARGiFJr. DAT J,,,., I .J I I I I I 1 5O0 ldo Inc Dir 'PVD Nori:h Fast: -- Nome .... Po~l[Jon -- - 14064 89.17 273.18 8844 754 -7728 Tar§et 3 701500. 5928650 12911 90.60 288.85 8829 672 -0580 l'orget 2 702650,5928600 10890 90.55 288.85 8849 19 -4667 Target 1 704580,5928000 - 900 Target ~~ - - 600 ~ - 300 tl ~ -- 0 ~- -300 ~ m --600 ,.o ~ - -900 o --1200 .. - I I '1 I I -I I -I I I ( '1 I I I ' ) I I I I I I I I I I ) I I ) I --1500 --8100 --7800 --7500 --7200 --6900 --6600 --6300 --6000 --5700 --5400 --5100 --4800 --4500 --4200 --5900 --5600 --5,300 A II Z O II V Scale 1 ' 500.00 East -> tShared Services Drilling S--~ru-~-u~e .'--~-~'7 ~/e~ 1 17-19A Field: Prudhoe B~y Loc~lion · Alqskq O 6600 - O ~ 69 O0 2 . ~ ~ 7200 - 7500 7800 8~00 8400 8700 9000 9300 - 9600 - 9900 - 10200 f 17-19AWp4 Tie on KOP End of Build End of Hold forget target --nd of Drop Torget WELL PROFILE DATA .... Point .... MD Inc Dir TVD NoAh East OLS(deg/lOOft) 9951 28.16 265.40 8802 -522 -5815 0.00 9945 29.00 267.00 8815 -522 -5822 8.00 10114 95,28 295.28 8895 -287 -5956 40.00 10877 95.28 293.28 8849 14 -4655 0.00 10890 90.55 288.85 8849 19 -4667 40.00 12911 90.60 288.85 8829 672 -6580 0.00 13042 89,17 275.18 8829 697 -6708 12.00 1~064 89,17 275.18 8844 754 -7728 0.00 3000 3300 3600 3900 4200 4500 4800 51 O0 5400 5700 6000 6300 6600 6900 7200 7500 7800 81 O0 Sco[e ] ' 300.00 Vertical Section on 283.88 azimuth with reference O.OO N, O.OOEfrom 19A 17-19A Wp4 Vertical Section 283.88° RKB 64.00' MD Inc. Azi. TVDss TVDrkb Rect. Coordinates Northing 9931.00 28.16 265.40 8738.44 8802.44 321.57S 9945.22 29.00 267.00 8750.93 8814.93 322.02S 0000.00 49.26 280.64 8793.28 8857.28 318.85S 0009.10 52.74 282.04 8799.00 8863.00 317.46S 0065.76 74.61 288.73 8824.00 8888.00 303.80S ~10-100.00 87.92 292.00 8829.19 8893.19 292.04S 10113.76 93.28 293.28 8829.04 8893.04 286.75S 10200.00 93.28 293.28 8824.11 8888.11 252.73S 10300.00 93.28 293.28 8818.40 8882.40 213.28S '~0.00 93.28 293.28 8812.68 8876.68 173.83S , O5'00.00 93.28 293.28 8806.96 8870.96 134.38S 10600.00 93.28 293.28 8801.24 8865.24 94.94S 10700.00 93.28 293.28 8795.52 8859.52 55.49S 10800.00 93.28 293.28 8789.81 8853.81 16.04S 10876.50 93.28 293.28 8785.43 8849.43 14.14n 10889.52 90.53 288.85 8785.00 8849.00 18.81n 10918.50 90.53 288.85 8784.73 8848.73 28.18n 11018.50 90.53 288.85 8783.80 8847.80 60.48n 11118.50 90.54 288.85 8782.87 8846.87 92.79n 11218.50 90.54 288.85 8781.92 8845.92 125.10n 11318.50 90.55 288.85 8780.97'-, 8844.97- 157.41n 11418.50 90.55 288.85 8780.02 8844.02 189.72n 11518.50 90.55 288.85 8779.06 8843.06 222.02n 11618.50 90.56 288.85 8778.09 8842.09 254.33n 11718.50 90.56 288.85 8777.11 8841.11 286.64n ~ ,~II8.50 90,56 288.85 8776.13 8840.13 318.95n . ~ ~18.50'J 90.57 288.85 8775.14 8839.14 351.26n 12018.50 90.57 288.85 8774.15 8838.15 383.56n 12118.50 90.57 288.85 8773.15 8837.15 415.87n 12218.50 90.58 288.85 8772.14 8836.14 448.18n 12318.50 90.58 288.85 8771.13 8835.13 480.49n 12418,50 90.59 288.85 8770.11 8834.11 512.80n 12518.50 90.59 288.85 8769.09 8833.09 545.10n 12618.50 90.59 288.85 8768.05 8832.05 577.41 12718.50 90.60 288.85 8767.02 8831.02 609.72n 12818.50 90.60 288.85 8765.97 8829.97 642.03n 12910.84 90.60 288.85 ' 8765.00 8829.00 671.86n 13000.00 89.63 278.20 8764.82 8828.82 692.68n 13041.93 89.17 273.18 8765.26 8829.26 696.83n Easting 3814.96W 3821.74W 3855.82W 3862.75W 3911.31W 3942.95W 3955.65W 4034.73W 4126.43W 4218.13W 4309.83W 4401.53W 4493.23W 4584.93w 4655.08W 4667.22W 4694.65W 4789.28W 4883.91W 4978.55W 5073.18W 5167.81W 5262.44W 5357.08W 5451.71W 5546.34W 5640.97W 5735,61W 5830.24W 5924.87W 6019.50W 6114.13W 6208.76W 6303.40W 6398.03W 6492.66W 6580.04w 6666.60w 6708.31w Grid Coordinates DLS Easting No~hing de~100ff 705441.28 5927683.27 0.00 705434.51 5927682.64 8.00 705400.36 5927684.87 40.00 705393.40 5927686.07 40.00 705344.48 5927698.38 40.00 705312.53 5927709.26 40.00 705299.69 5927714.20 40.00 705219.71 5927746.03 0.00 705126.96 5927782.93 0.00 705034.21 5927819.83 0.00 704941.46 5927856.73 0.00 704848.71 5927893.63 0.00 704755.96 5927930.53 0.00 704663.22 5927967.44 0.00 704592.26 5927995.67 0.00 704580.00 5928000.00 40.00 704552.33 5928008.61 0.00 704456.84 5928038.29 0.00 704361.36 5928067.97 0.00 704265.88 5928097.66 0.00 704170.39 5928127.34 0.00 704074.91 5928157.02 0.00 703979.43 5928186.71 0.00 703883.95 5928216.39 0.00 703788.46 5928246.07 0.00 703692.98 5928275.76 0.00 703597.50 5928305.44 0.00 703502.02 5928335.12 0.00 703406.54 5928364.81 0.00 703311.05 5928394.49 0.00 703215.57 5928424.18 0.00 703120.09 5928453.86 0.00 703024.61 5928483.54 0.00 702929.13 5928513.23 0,00 702833.64 5928542.91 0.00 702738.16 5928572.59 0.00 702650.00 5928600.00 0.00 702562.90 5928618.42 12.00 702521.09 5928621.43 12.00 Ve~ical Section 3626.42 3632.90 3666.74 3673.80 3724.22 3757.76 3771.36 3856.29 3954.78 4053.26 4151.75 4250.23 4348.72 4447.20 4522.55 4535.45 4564.33 4663.95 4763.57 4863.19 4962.80 5062.42 5162.04 5261.66 5361.28 5460.90 5560.52 5660.14 5759.76 5859.38 5959.00 6058.62 6158.23 6257.85 6357.47 6457.09 6549.07 6638.10 6679.59 Comment KOP: 9931 MD TSAG: 10009 MD Shublik A: 10066 MD BSAG Target (1): 10890 MD SAG Target (2) · 12911 MD 3/19/97 10:55 AM Page I of 2 17-19A Wp4 Vertical Section 283.88° RKB 64.00' MD Inc. Azi. TVDss TVDrkb Rect. Coordinates Northing Easting 13100.00 89.17 273.18 8766.09 8830.09 700.06n 6766.28w 13200.00 89.17 273.18 8767.54 8831.54 705.61 n 6866.12w 13300.00 89.17 273.18 8768.98 8832.98 711.16n 6965.95w 13400.00 89.17 273.18 8770.42 8834.42 716.72n 7065.79w 13500.00 89.17 273.18 8771.87 8835.87 722.27n 7165.62w 13600.00 89.17 273.18 8773.31 8837.31 727.82n 7265.46w 13700.00 89.17 273.18 8774.75 8838.75 733.38n 7365.29w 13800.00 89.17 273.18 8776.20 8840.20 738.93n 7465.13w ,,' ~O0.00 89.17 273.18 8777.64 8841.64 744.48n 7564.96w ':~ ~0.00 89.17 273.18 8779.08 8843.08 750.04n 7664.80w 140'63.59 89.17 273.18 8780.00 8844.00 753.57n 7728.28w Grid Coordinates Easting 702463.06 702363.11 702263.17 702163.22 702063.28 701963.33 701863.39 701763.44 701663.50 701563.55 701500.00 Northing 5928623.05 5928625.85 5928628.65 5928631.44 5928634.24 5928637.04 5928639.83 5928642.63 5928645.43 5928648.22 5928650.00 DLS deg/100ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Vertical Section 6736.64 6834.90 6933.15 7031.40 7129.65 7227.91 7326.16 7424.41 7522.66 7620.91 7683.39 SAG Target/TD/2 7/8" Liner: 14064 MD 3/19/97 10:55 AM Page 2 of 2 WELL PERMIT cHECKEi-ST-C- [o ; PROGRAM: exp[] der [] redr~serv[] wellbore segD ann disp para req[q ~70 UNIT~ ~'~ ON/OFFSHORE O~ .... ADMINISTRATION 1o 2. 3. 4. 5. 6. 7. 8. 9. 10. Permit fee attached .................. Y Lease number appropriate ............... Y Unique well name and number .............. Well located in a defined pool .............. Y Well located proper distance from drlg unit boundary...Y Well located proper distance from other wells ...... Sufficient acreage available in drilling unit ...... If deviated, is wellbore plat included ......... Operator only affected party .............. Operator has appropriate bond in force ......... I.YI Permit can be issued without conservation order .... Permit can be issued without administrative approval.. Can permit be approved before 15-day wait ....... ENGINEERING REMARKS 15. Surface casing protects all known USDWs ......... Y N 16. CMT vol adequate to circulate on conductor & surf csg.. Y N 17. CMT vol adequate to tie-in long string to surf csg . . . Y N ~ 18. CMT will cover all known productive horizons ....... Y 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............ N ~ ~----~--~_~_~ 21. If a re-drill, has a 10-403 for abndnmnt been approved..~ ~ 22. Adequate wellbore separation proposed ......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ............. ~ ....... ~ N 26. BOP~ press rating adequate; test to ~-t~ psig~ N 27. ChoKe manifold complies w/API RP-53 (May 84)...~ . . 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ .Q~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysts of shallow gas zones ......... 33. Seabed condition survey (if off-shore) ....... /. Y N - ' 34. Contact name/phone for weekly progress reports . ./.. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: _ mcm '~¥~-~,./ JDH ~ .... / Comments/Instructions: HOW/dE - A:\FORMS~cheklist rev 01197 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. LIS VERIFICATION LISTING FOR: SHARED SERVICES DS 17-19A WELL PRUDHOE BAY BELOW ARE THE MNEMONICS THAT CAN BE FOUND ON THE LIS TAPE GENERATED FOR SHARED SERVICES DS 17-19A WELL PRUDHOE BAY AZT GRAX GRBX GRDX GRIX GRTX INC ROPS TCDX TVD WBCS Azimuth - True (Posted) Gamma Ray (APl) [MWD] Gamma Ray Base [MWD] Gamma Ray Data Density [MWD] Gamma Ray Data Density Integrated [MWD] Gamma Ray Time Since Drilled [MWD] Inclination - True (Posted) Rate of Penetration CDS Temperature [MWD] True Vertical Depth Surface Weight On Bit deg MWD-API cps puff pts mins deg fi/hr deg F ft klbs Note: AT is Attenuation PD is Phase Difference MWD is Measurement While Drilling Copyright 1987,1988,1989,1990,1991 By WESTERN ATLAS INTERNATIONAL, INC. All rights reserved. PROGRAM: TAPESCAN REVISION: 2.64 Start of execution: Wed 28 MAY 97 3:28p ~== ECHOING INPUT PARAMETERS: INPUT PARAMETER FILE: TAPESCAN.INP 1 2 3 4 5 6 7 123456789012345678901234567890123456789012345678901234567890123456789012 1 AUTOCURV = 0 , ! Automatic Curve renaming: 0=OFF, I=ON 2 AUTOFILE = 0 , ! Automatic FILE= generation: 0=OFF, I=ON 3 COMMENTS = 1 , ! Decode LIS Comment records: 0=OFF, I=ON 4 INFORECS = 1 , ! Decode LIS Information records: 0=NO, I=YES 5 LISTMETHOD = 0 , ! Listing Method: 0=depth units 1---tape units 6 LISTFREQ -- 50, ! Listing Frequency: Every n units 7 LISTMAX = 0 , ! Listing Maximum (O--no limit, value=list limit) 8 STATS = 0 , ! Statistics generation: 0--OFF, I=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 (file0001.dat,etc.) 11 WRITETAP = 1 , ! Write Tape-Image File: 0=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 = 0 , STATS = 0 , FORCETYP = 0, WRITEASCII = 0 , WRITETAP = 1 , SPLITLIS = 1 , SUBFILES =/0/, INTERPOLATE='YES' END I-- PROCESSING INTERVAL FROM 0.000 TO 0.000 ............. ~-- CONSTANT PARAMETERS ........................................... AUTOCURV= 0.000000E+00 AUTOFILE= 0.000000E+00 COMMENTS= 1.00000 FORCETYP= 0.000000E+00 INFORECS= 1.00000 LISTFREQ= 50.0000 LISTMAX = 0.000000E+00 LISTMETH= 0.000000E+00 SELFTEST= 0.000000E+00 SPLITLIS= 1.00000 STATS = 0.000000E+00 WRITEASC= 0.000000E+00 WRITETAP= 1.00000 dpcoef = 1.00000 dpcte = 1.00000 drlength= 0.000000E+00 listwave= 0.000000E+00 maxrecln= 0.000000E+00 minrecln= 0.000000E+00 nsamples= 0.000000E+00 numcurvs= 0.000000E+00 numdatar= 0.000000E+00 numrecfl= 0.000000E+00 tfendep = 0.000000E+00 tflevsp = 0.000000E+00 tfstdep = 0.000000E+00 wcrbot = 0.000000E+00 wcrlevsp= 0.000000E+00 wcrtop = 0.000000E+00 ~-- ARRAY PARAMETERS .............................................. SUBFILES(1) = 0.000000E+00 SUBFILES(2) =-9999.00 SUBFILES(3) =-9999.00 SUBFILES(4) =-9999.00 SUBFILES(5) =-9999.00 SUBFILES(6) =-9999.00 SUBFILES(7) =-9999.00 SUBFILES(8) =-9999.00 SUBFILES(9) =-9999.OO SUBFILES(lo) =-9999.00 SUBFILES(11) =-9999.00 SUBFILES(12) =-9999.O0 SUBFILES(13) =-9999.00 SUBFILES(14) =-9999.00 SUBFILES(15) =-9999.00 SUBFILES(16) =-9999.00 SUBFILES(17) = -9999.OO SUBFILES(18) = -9999.oo SUBFILES(19) =-9999.00 SUBFILES(20) =-9999.0o SUBFILES(21) = -9999.00 SUBFILES(22) = -9999.0O SUBFILES(23) = -9999.00 SUBFILES(24) = -9999.00 SUBFILES(25) = -9999.O0 SUBFILES(26) = -9999.0O SUBFILES(27) = -9999.00 SUBFILES(28) = -9999.00 SUBFILES(29) = -9999.00 SUBFILES(30) = -9999.00 SUBFILES( 31) = -9999.00 SUBFILES(32) = -9999.00 SUBFILES(33) = -9999.00 SUBFILES(34) = -9999.00 SUBFILES(35) = -9999.00 SUBFILES(36) = -9999.00 SUBFILES(37) = -9999.00 SUBFILES(38) = -9999.00 SUBFILES(39) = -9999.00 SUBFILES(40) = -9999.00 SUBFILES( 41) = -9999.00 SUBFILES(42) = -9999.00 SUBFILES(43) = -9999.00 SUBFILES(44) = -9999.00 SUBFILES(45) = -9999.00 SUBFILES(46) = -9999.00 SUBFILES(47) = -9999.00 SUBFILES(48) = -9999.00 SUBFILES(49) = -9999.00 SUBFILES(50) = -9999.00 SUBFILES( 51) = -9999.00 SUBFILES(52) = -9999.00 SUBFILES(53) = -9999.00 SUBFILES(54) = -9999.00 SUBFILES(55) = -9999.00 SUBFILES(56) = -9999.00 SUBFILES(57) = -9999.00 SUBFILES(58) = -9999.00 SUBFILES(59) = -9999.00 SUBFILES(60) = -9999.00 SUBFILES(61) = -9999.00 SUBFILES(62) = -9999.00 SUBFILES(63) = -9999.00 SUBFILES(64) = -9999.00 SUBFILES(65) -- -9999.00 SUBFILES(66) = -9999.00 SUBFILES(67) =-9999.00 SUBFILES(69) =-9999.00 SUBFILES( 71) = -9999.00 SUBFILES(73) = -9999.00 SUBFILES(75) =-9999.00 SUBFILES(77) = -9999.00 SUBFILES(79) = -9999.00 SUBFILES( 81) = -9999.00 SUBFILES(83) = -9999.00 SUBFILES(85) = -9999.00 SUBFILES(87) -- -9999.00 SUBFILES(89) = -9999.00 SUBFILES( 91) = -9999.00 SUBFILES(93) = -9999.00 SUBFILES(95) =-9999.00 SUBFILES(97) = -9999.00 SUBFILES(99) =-9999.00 SUBFILES(101) = -9999.00 SUBFILES(103) = -9999.00 SUBFILES(105) = -9999.00 SUBFILES(107) = -9999.00 SUBFILES(109) = -9999.00 SUBFILES(111) = -9999.00 SUBFILES(113) = -9999.00 SUBFILES(115) = -9999.00 SUBFILES(117) = -9999.00 SUBFILES(119) = -9999.00 SUBFILES(121) = -9999.00 SUBFILES(123) = -9999.00 SUBFILES(125) = -9999.00 SUBFILES(127) = -9999.00 SUBFILES(68) = -9999.00 SUBFILES(70) = -9999.00 SUBFILES(72) = -9999.00 SUBFILES(74) = -9999.00 SUBFILES(76) = -9999.00 SUBFILES(78) = -9999.00 SUBFILES(80) =-9999.00 SUBFILES(82) = -9999.00 SUBFILES(84) =-9999.00 SUBFILES(86) =-9999.00 SUBFILES(88) =-9999.00 SUBFILES(90) = -9999.00 SUBFILES(92) = -9999.00 SUBFILES(94) = -9999.00 SUBFILES(96) = -9999.00 SUBFILES(98) = -9999.00 SUBFILES(100) = -9999.00 SUBFILES(102) = -9999.00 SUBFILES(104) = -9999.00 SUBFILES(! 06) = -9999.00 SUBFILES(108) = -9999.00 SUBFILES(110) = -9999.00 SUBFILES(112) = -9999.00 SUBFILES(114) -- -9999.00 SUBFILES(116) = -9999.00 SUBFILES(118) -- -9999.00 SUBFILES(120) -- -9999.00 SUBFILES( ! 22) = -9999.00 SUBFILES(124) = -9999.00 SUBFILES(126) = -9999.00 SUBFILES(128) = -9999.00 ~-- STRING PARAMETERS ............................................. 1NTERPOL= YES Input Tape-Image file, LU (1) is: CSDATA\TOMMYED\84656.TAP Output Tape-Image file, LU (2) is: C:~DATA\TOMMYED\T84656.TAP (Output Tape-Image file will be created) Listing Method ("LISTMETH") = 0, Depth Unit oriented listing. Listing Frequency ("LISTFREQ") is every ( 50) units of Depth. Listing output limiting (LISTMAX) not enabled... (to enable list limiting set LISTMAX positive) Data Statistics reporting ("STATS") has not been enabled. (Specify STATS=I to enable this feature) Automatic curve renaming has been disabled by user input (AUTOCURV=0). Automatic "FILE--n" card generation is disabled. (This is the program default, AUTOFILE=0) (Specify AUTOFILE= 1 to enable this feature) LIS comment record decoding (COMMENTS=l) has been enabled by user input. LIS information record decoding (1NFOKECS= 1) has been enabled by user input. The WRITEASC option has not been enabled... (to write ASCII subfiles specify WRITEASC=I) Tape Subtile 1 is type: LIS **** REEL HEADER **** LIS 97/05/28 TELECO 01 ** LIS CUSTOMER LIBRARY TAPE BAKER HUGHES INTEQ ** ** TAPE HEADER **** LIS 97/05/28 00084656 01 TELECO NG LOG DATA FROM SHARED SERVICES DS 17-19A. Tape Subtile: 1 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes Tape Subtile 2 is type: LIS **** FILE HEADER *** * MAIN .001 1024 CN : WN : FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS THE NG DATA FROM SHARED SERVICES DS 17-19A WELL. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 000 1 0000000 1 000 1 Rep Code Count Bytes 68 11 44 Sum: 11 44 44 fndun a [FT ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: FT 11 Curves: API API AP1 API Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ Cls Mod 1 AZT MAIN 68 1 DEG 4 4 95 191 02 1 2 GRAXMAIN 68 1 API 4 4 95 580 03 1 3 GRBXMAIN 68 1 CPUT 4 4 95 580 03 1 4 GRDXMAIN 68 1 PTFT 4 4 95 580 03 1 5 GRIXMAIN 68 1 PTS 4 4 95 580 03 1 6 GRTXMAIN 68 1 MINS 4 4 95 580 03 1 7 INC MAIN 68 1 DEG 4 4 95 970 01 1 8 ROPSMAIN 68 1 FPH 4 4 95 180 03 1 9 TCDXMAIN 68 1 DEGF 4 4 95 980 01 1 10 TVD MAIN 68 1 FT 4 4 95 181 03 1 11 WBCSMAIN 68 1 KLB 4 4 95 980 01 1 44 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 21 FRAMES * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 607 Tape File Start Depth = 9999.000000 Tape File End Depth = 13183.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 20108 datums Tape Subtile: 2 612 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subtile 3 is type: LIS **** TAPE TRAILER **** LIS 97/05/28 00084656 01 **** REEL TRAILER *** * LIS 97/05/28 TELECO 01 Tape Subtile: 3 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 28 MAY 97 3:28p Elapsed execution time = 17.74 seconds. SYSTEM RETURN CODE = 0 Tape Subtile 1 is type: LIS Tape Subtile 2 is type: LIS DEPTH AZT GRIX GRTX TVD WBCS GRAX GRBX GRDX INC ROPS TCDX 9999.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10000.0000 -999.2500 102.5875 70.7500 1.3333 5.3333 -999.2500 -999.2500 -999.2500 -999.2500 1.0000 -999.2500 10050.0000 267.1834 163.5600 112.8000 136.8000 10189.8008 44.0196 3.4000 8904.0469 0.0000 1.8000 -999.250O 10100.0000 275.1988 63.0750 43.5000 267.5000 86.0000 54.3298 32.4000 8937.9531 0.0000 3.0000 -999.2500 10150.0000 281.1374 69.6000 48.0000 395.0000 44.0000 75.9035 24.3500 8959.2383 0.0000 2.0000 -999.2500 10200.0000 284.9883 363.9500 251.0000 483.0000 66.0000 98.6446 26.7000 8961.0937 0.0000 3.0000 -999.2500 10250.0000 290.4564 165.3000 114.0000 577.0000 1171.0000 102.8404 14.4000 8951.3437 0.0000 3.0000 -999.2500 10300.0000 293.2056 181.4917 125.1667 720.5000 102.0000 101.9088 28.3667 8940.3789 0.0000 3.0000 -999.2500 10350.0000 295.9000 99.5667 68.6667 859.0000 62.0000 100.8291 22.7500 8930.8477 0.0000 3.0000 -999.2500 10400.0000 295.8708 -999.2500 -999.2500 -999.2500 -999.2500 101.4646 21.1667 8921.1758 0.0000 -999.2500 -999.2500 10450.0000 296.4905 -999.2500 -999.2500 -999.2500 -999.2500 100.9897 52.3667 8911.2695 0.0000 -999.2500 52.0000 DEPTH GRIX TVD AZT GRTX WBCS GRAX INC GRBX ROPS GRDX TCDX 10500.0000 -999.2500 8902.3164 297.5898 -999.2500 0.0000 -999.2500 100.0633 -999.2500 32.7833 -999.2500 -999.2500 10550.0000 -999.2500 8893.9180 298.5001 -999.2500 0.0000 -999.2500 98.9545 -999.2500 63.5333 -999.2500 -999.2500 10600.0000 -999.2500 8886.7227 298.7864 -999.2500 0.0000 -999.2500 98.0716 -999.2500 34.8000 -999.2500 -999.2500 10650.0000 -999.2500 8879.7187 299.3484 -999.2500 0.0000 -999.2500 98.0001 -999.2500 39.6000 -999.2500 -999.2500 10700.0000 1017.4999 8872.7109 302.3109 1245.9998 0.0000 196.4750 98.1786 135.5000 69.5333 1.0000 -999.2500 10750.0000 1082.5000 8865.5391 302.1096 1144.0000 0.0000 102.2250 97.9760 70.5000 90.3333 2.5000 -999.2500 10800.0000 1187.0000 8859.5781 296.9148 39.0000 0.0000 113.1000 95.1551 78.0000 92.4000 2.0000 -999.2500 10850.0000 1265.0000 8857.2148 296.7845 75.0000 0.0000 95.7000 91.9001 66.0000 100.1500 3.0000 -999.2500 10900.0000 1353.4998 8856.0430 291.4581 38.0000 0.0000 100.0500 90.8303 69.0000 52.7500 1.0000 -999.2500 10950.0000 1404.5002 8855.1602 291.5498 26.000O 0.0000 100.0500 91.3593 69.0000 85.9333 1.0000 -999.2500 11000.0000 1485.0000 8853.9766 291.2899 55.0000 0.0000 97.1500 91.1605 67.0000 86.7667 2.0000 -999.2500 11050.0000 1557.3333 8853.4687 289.8998 16.0000 0.0000 99.5667 89.8636 68.6667 87.5000 1.6667 -999.2500 DEPTH GRIX TVD AZT GRTX WBCS GRAX INC GRBX ROPS GRDX TCDX 11100.0000 1609.2500 8853.0469 289.9856 29.0000 0.0000 105.1250 90.9473 72.5000 88.3000 1.0000 -999.2500 11150.0000 1678.0002 8852.1094 289.3651 42.0000 0.0000 110.2000 90.9079 76.0000 58.8000 2.0000 -999.2500 11200.0000 1737.2498 8851.6953 288.4181 26.0000 0.0000 106.9375 90.6094 73.7500 91.5333 1.0000 -999.2500 11250.0000 1794.5002 8851.0430 288.4213 28.0000 0.0000 106.5750 90.7602 73.5000 77.3500 1.0000 -999.2500 11300.0000 1840.5000 8850.5039 288.1941 12.0000 0.0000 107.3000 90.4039 74.0000 121.2000 1.0000 -999.2500 11350.0000 1898.3333 8850.3164 289.0452 55.0000 0.0000 95.7000 90.1621 66.0000 134.8600 1.0000 -999.2500 11400.0000 2015.9998 8850.3828 289.1520 94.0000 0.0000 94.2500 89.8236 65.0000 52.4500 3.0000 -999.2500 11450.0000 2103.3999 8850.0664 287.5436 78.0000 0.0000 100.3400 90.5795 69.2000 118.7000 1.0000 -999.2500 11500.0000 2172.0000 8849.3945 288.2885 40.0000 0.0000 98.6000 90.9000 68.0000 81.5000 5.0000 -999.2500 11550.0000 2257.5000 8848.5859 288.3705 50.5OOO 0.0000 92.8000 91.0018 64.0000 22.7500 1.5000 -999.25OO 11600.0000 2333.9995 8847.5234 288.0725 25.0000 0.0000 94.2500 91.3586 65.0000 99.2000 1.0000 -999.2500 11650.0000 2385.0000 8846.3125 288.3423 14.0000 0.0000 105.8500 91.4368 73.0000 111.1667 2.0000 -999.2500 DEPTH GRIX TVD AZT GRTX WBCS GRAX INC GRBX ROPS GRDX TCDX 11700.0000 2444.0000 8844.8633 286.6633 27.0000 0.0000 98.6000 91.9833 68.0000 90.0000 2.0000 -999.2500 11750.0000 2506.0000 8842.8828 285.9050 35.6667 0.0000 89.4167 92.3O98 61.6667 75.6000 5.0000 .-999.2500 11800.0000 2591.6665 8841.0742 285.3638 30.0000 0.0000 103.4333 92.1524 71.3333 73.1000 1.0000 -999.2500 11850.0000 2669.7495 8838.9805 285.3732 49.0000 0.0000 118.9000 92.6691 82.0000 60.0000 1.0000 -999.2500 11900.0000 2832.8750 8836.2734 285.8234 1247.7500 0.0000 354.1625 93.7014 244.2500 8.0000 3.0000 -999.2500 11950.0000 3002.5000 8833.3281 286.1606 390.5000 0.0000 129.0500 92.8978 89.0000 10.8833 4.0000 -999.2500 12000.0000 3160.0000 8831.7031 287.6304 137.0000 0.0000 271.1500 90.3078 187.0000 48.5000 5.0000 -999.2500 12050.0000 3298.7993 8833.0898 292.3641 18.4000 0.0000 242.1500 86.9336 167.0000 14.9500 1.0000 -999.2500 12100.0000 3356.0000 8836.0469 292.4409 51.0000 0.0000 368.3000 86.5000 254.0000 104.3750 5.0000 -999.2500 12150.0000 3487.2500 8838.7227 292.8658 101.5000 0.0000 104.7625 87.6938 72.2500 40.1500 1.0000 -999.2500 12200.0000 3710.0000 8840.1094 291.5575 150.0000 0.0000 89.9000 88.7673 62.0000 121.5000 1.0000 -999.2500 12250.0000 3775.9995 8841.1055 291.0001 30.0000 0.0000 88.4500 88.9000 61.0000 112.8000 3.0000 -999.2500 DEPTH GRIX TVD AZT GRTX WBCS GRAX 1NC GRBX ROPS GRDX TCDX 12300.0000 3910.2500 8842.0352 290.2361 26.0000 0.0000 90.2625 89.0698 62.2500 105.4667 1.0000 -999.2500 12350.0000 3969.7500 8842.6055 290.4915 41.7500 0.0000 89.5375 89.5458 61.7500 99.5333 1.0000 -999.2500 12400.0000 4016.2500 8842.9297 290.6925 13.0000 0.0000 92.0750 89.7146 63.5000 99.2571 1.0000 -999.2500 12450.0000 4064.1997 8842.9414 290.5997 24.8000 0.0000 89.3200 90.1594 61.6000 105.0000 1.0000 -999.2500 12500.0000 4110.6670 8842.6914 290.8217 12.6667 0.0000 91.3500 90.4392 63.0000 109.5667 2.3333 -999.2500 12550.0000 4158.8008 8842.1484 290.7411 22.2000 0.0000 96.2800 90.8412 66.4000 98.4000 1.0000 -999.2500 12600.0000 4213.6660 8841.2148 290.0721 27.6667 0.0000 93.7667 91.3139 64.6667 94.3000 1.6667 -999.2500 12650.0000 4299.5000 8839.9844 289.1805 26.5000 0.0000 92.8000 91.3098 64.0000 98.3000 2.0000 -999.2500 12700.0000 4380.0000 8838.8516 290.9343 31.0000 0.0000 95.7000 91.3586 66.0000 62.9500 2.0000 -999.2500 12750.0000 4457.0000 8837.7852 291.3181 21.0000 0.0000 97.1500 90.9274 67.0000 68.3000 2.0000 -999.2500 12800.0000 4520.5000 8837.1836 291.6222 30.0000 0.0000 89.1750 90.6000 61.5000 82.7000 2.0000 -999.2500 12850.0000 4592.6660 8836.5234 291.9093 33.0000 0.0000 91.3500 90.9000 63.0000 73.8000 1.6667 -999.2500 DEPTH AZT GRAX GRIX GRTX INC TVD WBCS GRBX ROPS GRDX TCDX 12900.0000 292.1046 87.0000 4662.2500 15.0000 90.7152 8835.7891 0.0000 60.0000 90.0000 1.0000 -999.2500 12950.0000 292.2343 92.0750 4715.4990 25.0000 90.7448 8835.1250 0.0000 63.5000 97.9000 1.0000 -999.2500 13000.0000 291.6149 95.7000 4788.3330 19.0000 90.9639 8834.4336 0.0000 66.0000 76.7000 2.3333 -999.2500 13050.0000 291.2198 104.4000 4852.6670 30.0000 91.6000 8833.3477 0.0000 72.0000 72.0000 1.0000 -999.2500 13100.0000 291.2998 236.3500 4949.5000 45.0000 92.2136 8831.6602 0.0000 163.0000 47.9000 2.0000 -999.2500 13150.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 0.0000 -999.2500 49.2000 -999.2500 -999.2500 13183.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File StartDepth = 9999.000000 Tape File End Depth = 13183.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 3 is type: LIS