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204-204
David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: Hilcorp North Slope, LLC Date: 06/14/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API PTD # Log Date Log Type Log Vendor 09-05B 500292021502 219001 5/7/2021 SCMT SCHLUMBERGER 13-19 500292069000 181180 5/4/2021 SCMT SCHLUMBERGER C-29B 500292147202 214049 1/26/2021 SCMT SCHLUMBERGER E-17A 500292047001 204204 4/28/2021 SCMT SCHLUMBERGER E-34A 500292243701 214096 5/3/2021 SCMT SCHLUMBERGER L-106 500292305500 201223 6/5/2021 PPROF SCHLUMBERGER V-109 500292312000 202202 6/11/2021 PPROF SCHLUMBERGER Z-34 500292346900 212061 5/22/2021 SCMT SCHLUMBERGER Z-35 500292288400 198093 5/23/2021 SCMT SCHLUMBERGER Please include current contact information if different from above. 06/14/2021 Received By: 37' (6HW By Abby Bell at 3:24 pm, Jun 14, 2021 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:204-204 6.50-029-20470-01-00 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 12673 9764 7977 9808 10600, 11904 8014 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" x 30" 33 - 113 33 - 113 Surface 2680 13-3/8" 33 - 2713 33 - 2668 5380 2670 Intermediate 10344 9-5/8" 30 - 10374 30 - 8466 6870 4760 Production 1020 7" 9890 - 10910 8081 - 8861 8160 7020 Perforation Depth: Measured depth: 10423 - 12530 feet True vertical depth:8503 - 9010 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 28 - 9955 28 - 8134 9808 8014Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker SAB Perm Packer Liner 2787 9886 - 12673 8078 - 9012 10160 10530 12. Stimulation or cement squeeze summary: Intervals treated (measured): Squeezed IA with 122-bbls 15.8-ppg Cement. Initial pressure = 3608-psi. Final pressure = 1249-psi. Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 116313502367 621673 300 24857 407 955 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: Aras Worthington Aras.Worthington@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.564.4763 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ 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 measured9012 Sundry Number or N/A if C.O. Exempt: 320-363 No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 IA Cement Repair Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028304 PBU E-17A 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 11115, 11800, 11950 3-1/2" x 3-3/16" x 2-7/8" 7570 - 9814' in IA By Meredith Guhl at 2:28 pm, May 13, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.05.13 13:56:07 -08'00' Stan Golis (880) RBDMS HEW 5/13/2021 SFD 5/17/2021DSR-5/13/21MGR28JUL2021 ACTIVITY DATE SUMMARY 12/2/2020 ***WELL S/I ON ARRIVAL***(cement squeeze) PULL 4.5" DSSSV @ 2028' MD SET 4.5" SLIP STOP @ 7610' SLM ***CONT. TO 12/3/20 WSR*** 12/3/2020 ***CONT. FROM 12/2/20 WSR*** (cement squeeze) SET 4.5" D&D PACKOFF W/3.70" PX-PLUG BODY @ 7610' SLM RIGDOWN DUE TO INCLEMENT WEATHER ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** 12/5/2020 ***CONT. FROM 12/3/20 WSR*** (cement squeeze) TRAVEL TO WLB, STANDBY FOR SNOW REMOVAL ***CONT. TO 12/6/20 WSR*** 12/6/2020 ***CONT. FROM 12/5/20 WSR*** (cement squeeze) SET 4.5" TBG STOP @ 7609' SLM SET 1.875" PX PRONG @ 7614' SLM SET 4.5" CA-DSSSV @ 2028' MD SEE MIT-T DATA LOG, PASS PULL 4.5" CA-DSSSV @ 2028' MD ***CONT. TO 12/7/20 WSR*** 12/7/2020 ***CONT. FROM 12/6/20 WSR*** (cement squeeze) PULL PX-PRONG @ 7608' SLM PULL 4.5" AA TBG STOP @ 7608' SLM PULL 4.5" D&D PACKOFF @ 7610' SLM PULL 4.5" AD-2 SLIP STOP @ 7615' SLM PULL PX PRONG @ 9873' MD PULL 4.5" PX PLUG BODY @ 9873' MD ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** 12/8/2020 ***WELL S/I ON ARRIVAL*** (E-Line CBP, TBG punch, Cement Retainer) THUNDERBIRD LOADED THE TBG W/ 180 BBL'S OF CRUDE. SET 4-1/2" NORTHERN SOLUTIONS CBP AT 9764' MD. TxIA TO 1650 PSI PASSED (lost 0/50 psi in 5 min). PUNCH TBG 9751' - 9756' W/ 2", 4 SPF, 0 DEG PHASE GUN (loaded w/ 7G, circ- 2107-4T381 charges). ALL LOGS CORRELATED TO SLB MEMORY COIL FLAG DATED 6-MAY-2010. ***JOB CONTINUED ON 09-DEC-2020*** 12/8/2020 T/I/O=700/300/0 Temp=SI (Assist E-line) Spear in to TBG with 2 bbls of 60/40 followed by 180 bbls of oil Pumped 7.8 bbls of oil down TxIA to reach test psi 1650/1600 monitored pressure for 5 min TxIA lost 50/0. Final WHPS=1600/1625/0 E-Line in control of well upon departure. 12/8/2020 T/I/O=1200/1400/0 SI Circ Well to DSL (CEMENT SQUEEZE OA/IA DWNSQZ) Spot equipment/MIRU to well ***Job continued on 12-9-20 WSR*** 12/9/2020 ***Job continued from 12-8-20 WSR*** Pumped 2 bbls 60/40 to confirm comms TxIA followed by 700 bbls DSL down TBG up IA taking returns down E-23 FL. Pumped 9 bbls 60/40 & 16 bbls crude down FL of E-23 for freeze protect. Pad Op/WSL notified. Valve positions=SV WV SSV closed MV open CVs OTG Hardline SI E-23 SV WV SSV closed FWHP=145/165/0 Daily Report of Well Operations PBU E-17A Daily Report of Well Operations PBU E-17A 12/9/2020 ***JOB CONTINUED FROM 08-DEC-2020*** (HES E-Line CBP, TBG Punch, Cement Retainer) SET 4-1/2" HES FASDRILL SVB AT 9746' ELMD. LOG CORRELATED TO SLB MEMORY COIL FLAG DATED 06-MAY-2010 ***JOB COMPLETE ON 09-DEC-2020*** 4/2/2021 T/I/O=440/440/0 SI Perform Pressure Test on CIBP (CEMENT SQUEEZE OA/IA DWN SQZ) Pumped 5 bbls DSL down IA to pressure up TxIA to 1650 psi. TxIA lost 19/17 psi in 10 mins. Bleed TxIA to 400 psi Pad Op/WSL notified Valve positions=SV WV SSV closed MV open CVs OTG FWHP=400/400/0 4/19/2021 CTU #6 1.75" CT Job Objective: Perform IA packer squeeze MIRU CT, Perform 7 Day BOP test ***Job Continued on WSR 4/20/21*** 4/20/2021 CTU #6 1.75" CT Job Objective: Perform IA packer squeeze, coil volume = 36.4 bbls. Displace CT to Diesel and RIH with BOT/HES stinger BHA. Circulate 20bbls 9.8ppg brine into TBG above retainer. Sting into retainer and pressure up on IA and tbg, good indications of stung in @ 9,763' ctm. Establish step up circulation rates through retainer and up IA. HES cement unit executed IA squeeze pump schedule: 5 bbls surfactant, 2 bbls FW, 123 bbls of 15.8 ppg cement, and 5 bbls FW. SLB chased w/5 bbl gel pill and diesel. Unsting from retainer and layed in 1 bbl of cement on top of retainer = 66 ft (11:00 am). Estimated TOC in IA = 7,500' MD. Cement 500 psi compressive strength @ 20:30 pm. Pooh w/BHA. On surface pumped 1.188" drift ball through coil. Recovered ball. MU BOT Milling BHA, RIH and start stacking weight at 8675', come online with pump and start clean out operations. ***Job continued on WSR 4/20/21*** 4/21/2021 CTU #6 1.75" CT Job Objective: Perform IA packer squeeze Continue cleanout from 9019' to 9,773'. SLB splitter box on tractor over heating, Pooh while FP coil and surface lines. Mechanic diagnosed bad power end on coil pump. SLB changed out tractor/pump. RIH w/3.80" 5 bladed junk mill, dry tag 9,774'. Pumped 5 bbl gel pill surface to surface 2.5 bpm. Continue milling plug from 9,774' to 9778', chase plug to top of liner at 9,893'. Pump final gel sweep and POOH with 3.80" milling BHA. MU 2.73" BOT milling BHA and RIH. ***Job continued on WSR 4/22/21*** 4/22/2021 CTU#6 1.75" CT Job Objective: Perform IA packer squeeze. Continue RIH w/Baker Milling BHA =2.73" 3 bladed junk mill. Tag CBP debris/liner top at 9,899' ctm. Mill through liner top with minimal motor work and run to 10,600'. FP coil then well w/38 bbls of diesel while Pooh. RDMO CTU#6. ***Job Completed*** Daily Report of Well Operations PBU E-17A 4/25/2021 *******WELL WAS SHUT IN PRIOR TO ARRIVING ( PRE COMBO MITT & IA )****** DRIFTED AND TAGGED TOP OF 3 1/2" BAKER DEPLOYMENT SLEEVE W/ 3.80" GAUGE RING AND 4 1/2" WIRE BRUSH @ 9886' MD, SEEING AND BRUSHING X NIPPLE @ 9873'MD. RIH W/4 1/2" X-LINE RT W/ 4 1/2" PX PLUG BODY 25.5" OAL SET IN SELECT POSITION, 4EA. 3/16 PORTS, FALLING SLOW DUE TO FLUID PACKED UNABLE TO PASS SLIDING SLEEVE @ 9740 MD, WANTED TO PRESET PULLED BACK OUT LOCK WAS JAMMED UP WITH COMPOSITE DEBRIS AND WAS JAMMING CLOSING OF LOCK AFTER PINS WERE REMOVED. *************JOB IN PROGRESS CONTINUE IN AM 4-26-21 WSR ********** 4/27/2021 *****CONTINUE FROM 4-25-21 WSR**** BRUSH & FLUSH WITH 4 1/2" BRUSH & 3.80 GAUGE RING TO TO TOP OF BKR LINER TOP @ 9886'MD LRS 123 BBLS CRUDE WHILE BRUSHING SET 4 1/2" PX PLUG @ 9873MD X NIPPLE SET 3.79 G BATED 2" RB W/ 96" X 1.75" PX PRONG @ 9873' MD PLUG BODY RUN 4 1/2" Z6 SET 3.83" NOGO CD-SSSV ( 54"OAL) MIN. ID.OF 2.12, (2 SETS PKG SPACED 39" MID. TO MID. SERIAL # BALO-478 ) DO A PRE UNOFFICIAL OBSERVED MIT T& IA (GOOD) ON BOTH *****JOB IN PROGRESS CONTINUE IN AM ***** 4/27/2021 T/I/O= 175/0/0. LRS unit 72 Assist Slickline (CEMENT SQUEEZE (OA/IA DWNSQZ). Pumped 123 bbls of 180* F crude into the TBG while S/L brushed. Combo the TxIA for 15 minutes, T/IA lost 49/112 psi. Bleed the IA to 350 psi. Pressure the TBG to 2510 ps with 0.25 bblsi. TBG lost 67 psi in 15 minutes while still bleeding the IA. Pre testing indicates the well will pass AOGCC test. Final T/I/O= 1500/0/0. 4/28/2021 **** CONTINUE JOB FROM 4-27-21 WSR *** AOGCC- WITNESS MIT 2437psi(pass) CMIT-TxIA 2375psi(pass) - see LRS log details LOG CBL SLB SCMT FROM ~PC PACKER 9835' SLM, TO 6000' SLM(good data) PULLED CAMCO DUMMY 3.8" DB LOCK DUMMY SSSV 2 SETS PKING SERIAL # BALO 478 *******JOB IN PROGRESS CONTINUE IN AM ******* 4/28/2021 T/I/O= 1394/0/0. LRS unit 72 AOGCC MIT's (CEMENT SQUEEZE (OA/IA DWNSQZ)) (Witnessed by Brian Bixby) MIT-T to 2300 psi. PASSED at 2437 psi (2500 psi max applied) TBG lost 58 psi during the 1st 15 minutes and 21 psi during the 2nd 15 minutes. Pumped 1 bbl of 41* F crude to achieve test pressure. Opened the TxIA jumper and let pressure equilize to T/I/O= 450/450/0. CMIT-TxIA to 2300 psi PASSED at 2375 psi (2500 psi max applied). T/IA lost 84/81 psi during the 1st 15 minutes. TxIA lost 41/40 psi during the 2nd 15 minutes. Pumped a total of 7.6 bbls of 41* F crude to achieve test pressure. Bled the TxIA back to 1400 psi. SI the TBG and continued to bleed the IA to Final T/I/O= 1400/0/0. Daily Report of Well Operations PBU E-17A 4/29/2021 ****CONTINUED FROM 4-28-21 WSR **** TROUBLE SHOOTING AND ATTEMPTING TO PULL STA# 6,7 DGLV @ 5625 MD', 3103' MD RUNNING DECENTRALIZER IN 1:00 AND 3:00 POSITION AND OTHER TOOL CONFIGURATIONS **** JOB IN PROGRESS CONTINUE TO AM**** 4/30/2021 *****CONTINUED FROM 4-29-21 WSR ***** TROUBLE SHOOTING AND ATTEMPTING TO PULL DGLV FROM STA# 6 5625' MD PULLED 4 1/2" G- BATED, 2''RB , 1.75 X 96" PX PRONG, ASSEMBLE ( 112" OAL ) AT 9873' FROM PX PLUG. AT REQUEST OF COMP REP. *******JOB IN PROGRESS ****** 5/1/2021 ***CONTINUED FROM 4-30-21 WSR ****** MADE ONE MORE ATTEMPT AT PULLING STA# 6 @ 5625' MD DGLV W/ DECENTRILIZER, CLOCK SET @ 1:00 UNABLE TO LATCH RAN 1.75 LIB TO STA# 5625' MD SAME SET UP WITH DECENT AND CLOCK (Pie shape triangle- see well file) RAN GS LATCHED PLUG BODY 9873' MD WORKED 20 MIN.(sheared) RAN GS UNABLE TO PASS OR RELATCH @ 9805' SLM RAN 10'X3.50"' PUMP BAILER TO 9805' SLM,( 1 Cup return PCT) ******* JOB IN PROGRESS CONTINUE IN AM *********** 5/2/2021 *****CONTINUED FROM 5-1-21 WSR **** RUN PUMP BAIL W/ 10' X 2.5" TO 9805' SLM (no sample, metal mark) RAN 2.70''LIB TO TAG TOP OF PLUG @ 9805' SLM (FN highly offcenter possible in 9-5/8" Bkr SAB Pkr) RAN KTJ GR & TAPERED BULL NOSE PULLED 4 1/2" PX PLUG BODY SET 4 1/2" CAMCO DB DSSSV @ 2028' MD 54" OAL ( 2 SETS 39" MID TO MID ) 2.12 MIN. ID SERIAL # BAL-O-413) NOTE :HUNG TAG IA FLUID PACKED w/ DUMMIES BE AWARE THERMAL EXPANSION WHEN BRINGING ON LINE NOTE: 4-1/2 Motherbore is PCT ***** JOB COMPLETED GAVE WELL TO PAD OP TO POP **** 4/28/21 MEMORANDUM State of Alaska Depth Alaska Oil and Gas Conservation Commission Well t. i -,a PTD zo4zo4o BBL Pumped: DATE: Thursday, May 6, 2021 TO: Jim Regg�O` ' P.I. Supervisor ' \1- q SUBJECT: Mechanical Integrity Tess l Hilcorp North Slope, LLC OTHER P/F E -17A FROM: Brian Bixby PRUDHOE BAY UNIT E -17A Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry—.1 R NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT E-1 7A API Well Number 50-029-20470-01-00 Inspector Name: Brian Bixby Permit Number: 204-204-0 Inspection Date: 4/28/2021 Insp Num: mitBDB210429044234 Rel Insp Num: �--0"1 produ'Co' Thursday, May 6, 2021 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well t. i -,a PTD zo4zo4o BBL Pumped: Type Inj N -.TVD - "Type Test sPT Test psl 7.6 - BBL Returned: . 8019 zsoo 6a 450 2500 2476 2375 S _ � Tubing -� 450 i IA I 1 2508 - ?427 2387_ - _ _ OA _j o 0 I L Interval OTHER P/F P ✓ Notes: CMIT-TxIA as per SUNDRY 320-363 �--0"1 produ'Co' Thursday, May 6, 2021 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Cas Conservation Commission DATE: Thursday, May 6, 2021 TO: Jim Regg p�r� P.I. Supervisor R �I//(�'IZ� SUBJECT: Mechanical Integrity Tests l ° Hilcorp Noah Slope, LIX E -17A FROM: Brian Bixby PRUDHOE BAY UNIT E -17A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry JF- -NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT E -17A Insp Num: mitBDB210429043928 Rel Insp Num: API Well Number 50-029-20470-01-00 Inspector Name: Brian Bixby Permit Number: 204-204-0 Inspection Date: 4/28/2021 - Packer Depth Well 1 I�-nA T}pe Inj N TVD 8019 PTD 2042010 Type Test SPI,,Test psi 2300 BBL Pumped: I BBL Returned: I Interval OTHER IP/F L—P Notes: MIT -T as per SUNDRY 320-363 n -oty Pretest Initial 15 Min 30 Min 45 Min 60 Min Tubing 1394 ' 2156 2458 ' +2437 - I 0 0 0 10 OA 0 0 0 0 Thursday, May 6, 2021 Page I of I Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 12/21/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU E-17A (PTD 204-204) PLUG SET RECORD, TUBING PUNCH, AND CEMENT RETAINER RECORD 12/08/2020 Please include current contact information if different from above. PTD: 2042040 E-Set: 34456 Received by the AOGCC 12/22/2020 Abby Bell 12/23/2020 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:204-204 6.API Number:50-029-20470-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028304 Property Designation (Lease Number):10. 8. PBU E-17A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown IA Cement Repair Op Shutdown GAS GSTOR WAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5Stratigraphic Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 12673 Effective Depth MD: L-80 11. 9/15/2020 Commission Representative: 15. Suspended Contact Name:Aras Worthington Contact Email: aras.worthington@hilcorp.com Authorized Name: Stan Golis Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9012 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 9808, 8014 No SSSV Installed Date: Liner 2787 3-1/2" x 3-3/16" x 2-7/8"9886 - 12673 8078 - 9012 10160 10530 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 33 - 2713 33 - 2668 14. Estimated Date for Commencing Operations: BOP Sketch 33 - 113 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker SAB Packer 10423 - 12530 8503 - 9010 4-1/2" 12.6# L-80 28 - 9955 Liner 9873 8067 11904 33 - 113 13-3/8" 9-5/8" Contact Phone:(907)564-4763 Date: 4760 80 20" x 30"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2680 4930 Intermediate 10345 30 - 10374 30 - 8466 1020 7"9890 - 10910 8081 - 8861 8160 7020 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. 9873, 11116, 11800, 11950 No SSSV Installed By Samantha Carlisle at 10:15 am, Aug 31, 2020 320-363 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.08.31 10:06:12 - 08'00' Stan Golis 10-404 SFD 8/31/2020 DSR-8/31/2020 Cement Bond Log to AOGCC for review. Biennial CMIT TxIA and MIT-T. MGR31AUG2020 Yes equired? Comm. 8/31/2020 JLC 8/31/2020 RBDMS HEW 9/1/2020 Well: E-17 IA Cement Repair Well Integrity Engineer:Aras Worthington (907) 564-4763 Ops Engineer:Noel Nocas (907) 564-5278 Ops Manager:Stan Golis (907) 777-8356 Expected Start Date:September 15, 2020 History E-17A was coil tubing sidetracked in October, 2004. TxIA communication developed and a subsequent LDL indicated tubing leaks at ~9820’, 9090’, and 8680’ MD with a LLR of 0.2bpm/2300 psi. A CMIT TxIA passed to 2300 psi on 5/25/2020 proving packer and production casing integrity. Current status The well is classified as Not Operable and is secured with a plug. Objective By repairing this well with an IA cement repair it is estimated that an incremental 500 mbo can be produced over the next several years. Without an IA cement repair the well has no utility in the foreseeable future. The proposed TOC in the IA is ~7500’ MD which is ~3615’ TVD deeper than the surface casing shoe and ~2180’ MD below the top of the UG4 marker @ 5321’ MD. Post-Job Evaluation x CMIT TxIA and MITT x SCMT to locate TOC Long-Term Integrity Monitoring x Record WHPs daily. x Biennial CMIT TxIA and MITT. Slickline 1. Pull TTP E Line/Fullbore 1. Set CBP in tubing near production packer. 2. Punch tubing just above CBP and confirm circulation TxIA. Coil Tubing 1. Set cement retainer above tubing punch. 2. Pump cement (15.8 ppg/~125 bbls) down CT taking returns from the IA to bring TOC in IA up to ~7500’ MD. Unsting from retainer and lay the last 1-2 bbls of cement on top of the retainer. 3. MU Motor and Mill. 4. Mill through Cement, Retainer, and CBP. Push remnants to bottom. Slick Line/Fullbore 1. Set TTP. 2. CMIT TxIA to 2300 psi. MITT to 2300 psi. 3. Run SCMT to locate TOC in IA. SCMT to AOGCC for review. 4. Pull TTP. Integrity Engineer 1. Add Biennial CMIT TxIA and MITT to Anncomm. Small Tubing Leaks @ ~9820’, 9090’, & 8680’ MD TOC in IA ~7500’MD E-17 Proposed E-17 Proposed P&A Reservoir Cement Plug Surface Cement Plug STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations m Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well 0 Other: d 1g P 11Y-'---- 2. 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 204-204 3. Address: P.O.Box 196612 Anchorage, Development ® Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20470-01-00 7. Property Designation(Lease Number): ADL 0028304 8. Well Name and Number: PRUDHOE BAY UNIT E-17A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 12673 feet Plugs measured See Attachment feet RECEIVED true vertical 9012 feet Junk measured 11904/11905 feet 2 Effective Depth: measured 11115 feet Packer measured 9808 feet MAY 0 2017 true vertical 8978 feet Packer true vertical 8014 feet AOGCC Casing: Length: Size: MD: ND: Burst Collapse: Structural Conductor 80 20"x 30" 33-113 33-113 Surface 2680 13-3/8"72#L-80 33-2713 33-2668 4930 2670 Intermediate 10345 9-5/8"47#L-80 30-10374 30-8466 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet • True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 28-9955 28-8134 Packers and SSSV(type,measured and 4-1/2"Baker SAB Perrn Packer 9808 8014 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 321 33464 14 660 943 Subsequent to operation: 595 33521 11 1580 850 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development m Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil RI Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ❑ WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Derrick,Laurie R Contact Name: Derrick,Laurie R Authorized Title: Pe1oleum Engineer Contact Email: Laurie.Derrick@bp.com Authorized Signature: _ V • Date: 5/2../J 7 Contact Phone: +1 907 564 5952 pA Form 10-404 Revised 04/2017�rt/4/,�J 1/17- 5//p/17" R B D M S UU,4AY - 3 2017 Submit Original Only • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary April 28, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for E-17A, PTD # 204-204 for Setting of a Plug and Add Perforations. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • Plugs Attachment PRUDHOE BAY UNIT E-17A SW Name Date MD Description E-17A 04/03/2017 11115 3-3/16"WFD CIBP • E-17A 10/06/2015 11800 2-7/8"CIBP E-17A 07/14/2007 11950 2-7/8" Baker CIBP • S m co 0. co co co0 CD ea m coo oD N I C r C.) '~ O O O 0 m d' M co M co 0 oc) - O N COCONCOM co NI- OD00T- N OD OD OD O O) Co Imo- T- OD CD M M O Ns OD N W- OD C/ M M O O — O N OD OD OD CD 15 4 E %.. co ul T_ CD c; N °.2 co O N CD QM M M O ODCDcI j 00 _ MMM OD CD CD CDCD r N <M .Q W F W O O O O • 0 OD0OD CO OD 03 _ G� MN4 # JN � CCOO ▪N N X ti 4 M 4 CO a/ CO O _ a0 N _ CO T- 0 a NMUlssssss � O C) , N M t C CBO 000 Nr N N CMO Co N c: op co 0000MMO) .J •— T- C)) W cc =0 Q U ww o 0CLGtEtCCZ Z W W W W W W m Q 0 Z Z Z Z m O U) Z J J J J F • • d w CO 0) C) C) — vCY) COvaO UlrnOo f- NNMNCflCOTt C3 to O , Ni a0 — OO O O d NO -- OOO CAO00 - c,• 00 00) CDCDCD CD CD CO CO C 0 CD CD CD a. O I- to I- CY) co 0) CO N- d N L CD O co C) C) CY) 0) O M 0) CA N- Tr NNOIs: N ' od ui OO) (di O o 0 00T- c- N."' OCA 0000 — W tn000000) 000000 > O CO 0) 0) 0) 0) 0) aO CO 0) 0) 0) 0) 0) re 0 W 0 0 W Z W H H O 0 R O O w Y Y g D inn 0 coc � W a) N-N- C O— 0 aa) --1 < J a d z _ d NNN � tn0titia0N01 04NN U_ U_ _.) J W W J C9 Q� Z Z Z O (51 p J O J 0 0 0 W oe & Z O Z W W W 0- E H Q J Q a Z _ 2 2 2 O u) fA Cn Cn Cn a O aQI- = . C) 00000000 U) 00 U) m Q, N 00 N to CY) C) 0) CO d' to 0) T- %0 a nt O '— N V) U) CO CO Ns O N N N 04N W 2220 u) Cl) Cl) Cl) Cl) CL r D. O C LL (n Cl) U) f!) CO CO Cl) U) Cl) U) V) CI) oaaaaaaaaaaaaa d < m m m m m m m m m m m m c. 0 t m a 2 C N. N- N- N- N- N- ti N- N- N- ti N- N- O 0 C 0000000000000 W t�0 CV CV CV CV N CV CV CV N CV N CV CV CCLU E N N N N N N N N N N N N N p a w J 0 N cc d' �t -I' �' Tr � � d � � si' d Z J 0 W W u. W 0 Cn 0 m W J J Q C7 W W Q Q o_ u_ to o_ m E m Z Q Q Q Q Q Q Q Q Q Q Q Q < 3NNNNNNNNNNNN- r- I I CO d 0- 0- 0 -10 0 1110. W W W W WWW W W < < m m u_ u o cO o_ O! • 0 coro v 0 II • F- o N• W v• 6 0 ti o n. M II V) ii J O dU - W _ - F- O Lo J acoQ Z c Zvi .- I- V " z' ;1 tiW a < N � = cc E J e2 < cO . (-31 = cc E a) 1:0 ui _m n 2U a. F- cn a OHD U = QN. 1- Q w F- Z w � wo Ow = "6 (nF- iII I- 0 W LL >"' W dUz mzO00 O 71 . ° 200 "6 w -IJ1_ � cn ▪ W mmLLJ ,i- O 004. /X J U o 0. i DU � O >I Et Qc) ce7o > sci D. > � 0 � A- 0 * O cclawQQ < I- QNgaWQF- ) Ca = w O II CVu_ oa E - QcJn1- rez2 a J � OcoaQUO U) w QzT- NJm s 1= rzz - O u. W » w7 o * Z1- cec * z W F- o N. T N co a5 m N FNI- - 0 Q • TREE= 6-3/8 UN FLS III SA NOTES:WELL ANGLE>70°@ 11172 . 1VVELLI-EAD= FIC E-1 7A ACTUATOR= BAKER C OKB.ELEv= 60 3'i BF. Ei_EV= 31.39' KOP= 2000'1 ' 2028' —14-1/2"CAMEO SSSV LANCING NP,1-.)=3.813"--1 Max Angle= 97'@ 11608'1 1 41110 Datum MD= 10908' GAS LFT MANORB_S i Datum TVD= 880(Y SSj i ST M) TVD EN TYPE VLV LATCH PORT DATE 7 3103 2991 39 CA-I*$3 DMY RK 0 02/13/11 1 I3-3/8CSG,72#,L-80,I)- 12347" 1-1- 2716' - 6 5625 4899 40 CA P& 3 DMY RK 0 01/22/081 5 7049 5974 45 CA-MMG! DMY FE 0 02/13/111 Minimum ID =2.44" @ 11315' LI 4 8006 6628 46 CA-NAG OW FE0 09/24/81ii 3 8682 7111 42 CA-M44G DMY Ric 0 09/24/811 2 9199 7510 36 CA-MING DAY I RC 0 02/13/111 TOP OF 2-718" LINER 1 ,971i7934 34 CA-1.6.1G DW 1 FE 0 109/24/811 I 1 97413' I—4-1/2"BKR L SLDSLV,ID=3.8131_1 I i19796. --1TUBING SEAL ASSY , ,,,,........--• 9814' H9-5/8'BKR SAB PKR, El=3.813' II - 9873 —4-1/2"OTIS X NP,D=3813" 9886' —13-1/2"BKR DEPLOY SLV,ID=3_00" TOP OF 7"LNR --1 9890' i o P I 9916' —13-1/2"X NP,ID=2.813" I 11.---------1 9917' —4-1/2"OTIS XN MILLED NP,ID=3.80" 3-1/2"LNR,8.81#, L-80,.0087 bpf,D=2.992' — 9947' (BEHIND PIPE) 4-1/2'TBG, 12.6#,1-80,.0152 bpf,ID=3.953" —E9964' / ..'s 9947' —3-1/2'X 3-3/16'XO,ID=279' 9964" H4-1/2"BKR TT(BEM/OPINE) 1 9-5/8'CSG,47#,L-80,ID=8.681" 1-1 10373' ' A L- -I. 104.40' —EsT TOP OF CAP"(DitotS 10/27/04) j cc, .s. 4•41 444 44 14 44. 444. MILLOtTT WINDOW 10910'-10915' 4. 44. WHPSTOCK vu/RA TAG§10917'(10/18/04) — 10907' , 4•' 44 IL 4 FF-TBG.29#,L-80,ID=6 182" — -10907' it 11116' —3-3/16'VVFD CEP(04/02/17)] PERFORATION SUM.%RY 1 P,,•TIPIP•- l ire r 11315' —3-3/16'X 2-7/8"X0, REF LOG:61-CS ON 09/21/81 • IID=2.44" ANGLE AT TOP PERF:40°a 10423' Note:Refer to Production DB for historical perf data • SIZE SPF I INTERVAL Opn/Sqz SHOT SQZ 11800'CTMD —2-7/8"CSP 2" 6 10423-10453 0 04/02/17 3-3/16"LNR,6.2#,L-80, 1,— 11315' I (10/06/15) 2" 6 11180 -11205 C 05/09/10 .0076 bpf,D=2 80" I i • I ' r 6 11220-11265 i C 10/30/04 • 11950' I—RKR CRP 2" 6 11350-11410j C 10/30/04 1(07/14/07) 2' 6 11530- 115951 C 10/30/04 FISH:rocLep&PUSHED CIBP(10(06/15) — 11904' CTMD 7'lie 2' 6 ' 11630-116601 C 10/08/15 2" 6 11690- 117201 C 10/07/15 T FISH:2-7/8"CI3P H ? • • 2" 6 ,11740- 117701 C 1 10/07/15 • 2" 6 11860- 11;45 C 10/30/04 1 . am 2" 6 12045-121101 C 10/30/04 PBTD — 12637' i 2" 6 12150-12300 C 10/30/04 2' 6 12390- 12480 i C 10/30/04 12-7/8"UR,6 16#,L-80, 0058 bpf,ID=2.441" — 12673' 2" 6 12515- 125301 C 10/30/04 i DATE 1 RB/BY COMAENTS DATE REV BY I 00h../ENTS FRUDHOE BAY INT 09/24/811 'ORIGINAL COMPLETION i 02/27/11 CJWPJC 1GLV C/O(32113/11) WELL. E-17A I 110/31/04 IBMI-1113JCICTO SIDETRACK(E-17A) 1 1 12/08/13 PJC ICIBP DEPTH COWECT1ON FATIb '1800480 i 07/19/071RWL/PJC SET CIBP© 11950'(07/14/07) 01/06/14 1 DU/JAI) !TREE 00 01/04/14) AR No- 50-029-20470-01 02/09/08 1 DAVIPJC GLV C./0(01/22108) I 10/09/15 1 JTVIJMD t PALLED&SET(IBRADFERFS SEC 6,MN,R14E, 1753'FNL&501'Fa I 1 1 1 05/18/10 1 JKIYSV I SET CERADD FE1 (05/09/10) i 04/04/16 MIS/J1.1) i SET CBF'&ADPERFS I 1 1 05/30/10 I CINPJC 1GLV 00(05/21/10) I 04/05/17 1 KFS/JM131,MN ID CORRECTION PER TALLY BP Exploration(Alaska)k a) • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations Q Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown 0 Suspend ❑ Perforate Q Other Stimulate ❑ Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well ❑ Other:Mill CIBP Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 204-204 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20470-01-00 7. Property Designation(Lease Number): ADL 0028304 8. Well Name and Number: PBU E-17A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL RECEIVED 11.Present Well Condition Summary: Total Depth: measured 12673 feet Plugs measured 11800/11950 feet N O V 0 3 2015 true vertical 9012 feet Junk measured 11904/11905 feet Effective Depth: measured 11800 feet Packer measured 9808 feet `.SCC true vertical 9001 feet Packer true vertical 8014 feet ase Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 33-113 33-113 Surface 2680 13-3/8"72#L-80 33-2713 33-2668 4930 2670 Intermediate 10345 9-5/8"47#L-80 30-10374 30-8466 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet SCANNED 1\10V 1 2 2015 Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 28-9955 28-8134 Packers and SSSV(type,measured and 4-1/2"Baker SAB Perm Packer 9808 8014 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 210 14591 9 925 239 Subsequent to operation: 589 38492 76 1350 903 14.Attachments:(required per 20 AAC 25.07a25 071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ❑ WAG 0 GINJ 0 SUSP ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer SignatureA C Phone +1 907 564 4424 Date 11/3/15 RBDMS nV 0 5 2015 Form 10-404 Revised 5/2015 Submit Original Only ! ! No 0 co 0 _a O N co O U o o O o 0 i co N- co C) CO N m 't CO N- Co co CO co CO CO N M r CO CO N— CO O O N CO CO CO O CA CO N- CO O) CO CO O N- CO N CO CO CO CO CD 0 O N CO CO CO O) 4.0 CDO CO CO in M C3) co co a) N O CA o r N C� � r r � I I I ▪ a r M CO O 00 CO M CO E C CO CO CO CO 00 O) N • W CA CD C D M CO I— a O O O O O co c co co 00 = ON *k J 1 coN y M CO CO .N N x N- CO # CO N O 00 - - CMV - M U N C j N r 00 N M ' M h T coM) i N � . In CD C)O CO N N ON CO in (NI C CO CO co O CO CO O) JN r r Ci) W C C 0 'Fo U W W U inu_ cc c w w Z Z w W W W W W E Q D H Z_ Z_ Z Z_ j O u) Z J J J J H • • a) f0 m M O = V' M CO � 00 Q O M L I� N N () N (O (O V' 7 O ' V' -400N- COuiN- o0 w o .- - ooCCOo = = O o C) O O C) 0) 0) O O O O D 000) 0) CD COCO0) rnrnrn I- a 0 L O O M M M C _. M O O N- Q- O N V 4)O1O M 0 0 0 0 O O v- v- v- 0 0 O 0 0 0 0 v- W 0 0 0 0 0 0 0 0 0 0 0 0 > O M 0) O) O O M 00 M M M 0) O) 0 w O▪ 0 w Z will w w Luz 0 H H J a w g g Y U O o 00 ;?, Y Y g (n 0 u) 0 0 0 (n 0 0 0 0 J U U www W cc L O co - O O N N- O v- O CO M J J J Q Q to W 0 N N V CO ~ M N N N N < < O W W U-1 0 Z 0 @ Q Q Q O D O W O O O w r z p z W W W 0_ 1- h < J < V Q 22 20 co co co co co Q %— a W = w00000COOcnoou> Q 00 N L0 M M O V' (0 V' u) O O 0 = N M = = = = = (O (O I- m O = M u, 0 r' r- = = = N (V (V (V M a L a) O 2 cn = IU- I- a J a a 2 20 co co co co cn a a 0 0 c ▪ LL Q' W d LL LL L_ U) U) U) W U) is a W W a. dd. a. da. aaa. cii < MO_ M ‹ QQmmmmm a 0 t a) a ~ o O o O o o O oo W z p N 0 0 N N N N N N N N N N N O CC Q NW • n o 0 z a U ww w w w Q = = = = = = = = = Q O J I--- J J J 0.. O Q W Q d J J cco LL u. u_ d a) E as Z « « « « « « Cl) ii i i i i i I I i i i CO 0- aa. a 0 J 00 00' w d W W W W W W W W W W W W < < m m w LL, cn cn a o • 0 ID § f z _0 \ / / 0 ri o tc ± co J/ 2 f 2 ® a) 2 § fE 2 2 $ E f o 't �_ 2 t co t a) » O & & a) ± t _ \ OGA = I 0- 73 73< aQ- p � , -o < ~ C & © O ® © E 0iNOa ' 0 CO - G o — a = CO - g & \ \ @O & Q U ® / u 15 \ CO 2 & ± o * G 7 = ± _/ 0 \ 2 aS < 2 f \/ ® § a E \ I D 48. / � _ C O 0 b = k / � O Q m - = 8 \a. I = e / . 1 6 5 a) k \ ca2E \ co .- a \2 W $ k o 2 \ / § o . # y = / / Et : R fm O - r 0. - / / -_aI, 0 f t a_ 2 0 O a 0 } / / O f ' taco c cc _0 / / >- ,- (1) , .-- a a \ / / a_0) \ / / \ g � E E -0 _ = .) / 0 £ •- c % . $ / t f 2 % - / \ oe E f \ 0 a $ 6 : ^ % © \ a 4 _ - a ll e t * # o # \ -9 a e # cc o / t ' co o : * 10 I O e w0 R ' E 2 / \ - \ / / I / CO � / Cl. k a \ . 5 - in\ w [ a 2/ - \ a) p 2 a / R / % \ _ o / c \ / / / gam / # i \ / / / u) LE © -al 0 . I E o - o £ _ - 2 \ - / -D CC \ / 0_/ / / E / / / �/ / / / / o 2 o ¢ » a & = o : m O I U : N m : o '- Z L < r co 10 r I- d " \ d / \ / r Q 6 w c Imran \ / / \ \ 0 < TEE= ' 6-3/8 CNV FLS • r—SlitY NOTES:WELL ANGLE>70'@ 11172'. WELLFEAD= FRC E-17 A ACTUATOR= BAKER C OKB.ELEV= 60.3' BF.ELEV= 31.39' KOP= 2000' 2028' H4-1/2"CAMCO SSSV LANDING NP,D=3.81T Pbx Angie= 97°@ 11608' frPO Datum M3= 10908' GAS LFT MANDRELS Datum ND= 8800'SS ST MD ND DV TYPE VLV LATCH PORT DATE 7 3103 2991 39 CA-AMG DW RK 0 02/13/11 [13-3/8"CSG,72#,L-80,D=12.347" 1-[ 2715' 6 5625 4899 40 CA-AMG DMY FE 0 01/22/08 5 7049 5974 45 CA-AMG DMY FE 0 02/13/11 4 8006 6628 46 CA-AMG DMY FaC 0 09/24/81 Minimum ID =2.377" @ 11315' 3 8682 7111 42 CA-PANG DMY Fa( 0 09/24/81 TOP OF 2-7/8" LINER 2 9199 7510 36 CA-AMG DMY FE 0 02/13/11 1 9711 7934 34 CA-MNG 1 SMY RK 0 09/24/81 I I 9740' —4-1/2'BKR LSLDSLV,ID=3.813' 9796' HTUBFUG SEAL ASSY L .,,,......_......1 9814' —19-5/8"BKR SAB PKR,D=3.813' z I 9873' 4-1/2'o-ns X NP,D=3.813" I ' v 9886' —3-1/2"BKR DEPLOY SLV,ID=3.00' TOP OF 7'LNR H 9890' 9915' —13-1/2"X NP,D=2.813' II I 9917' 41/Z'OTIS XN MLLED NP,D=3.80" 3-1/2'LNR,8.81#,L-80,.0087 bpi,D=2.992' H 9947' ( (BMW)PIPE) 4-1/2'TBG, 12.6#,L-80,.0152 bpf,D=3.953" —I 9954' f / 9947' H3-1/2'X 3-3/16"XO,D=2.79" 9954' H4-1/2"BKR TT(BEHIND PIPE) 9-5/8'CSG,47#,L-80,D -- =8.681" -I 10373' 141 , ��� V9.1 10440' HEST TOP OF CMT(DIMS 10/27/04) .. 11 WHPSTOCK w/RA TAG @ 10917'(10/18/04) — 10907' 0 -A. , MILLOUT WINDOW 10910'-10915' 7"TBG,29#,L-80,D=6.182" —10907' `. PERFORATION SUMMARY rJeiWAV. 11315' —3-3/16'X 2-7/8"XO, REF LOG BHCS ON 09/21/81 / D=2.44" ANGLE AT TOP PERE:700 @ 11180' Note:Refer to Roduction 08 for historical pert data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ �` 11800'CTMD —2-7/8"CUP 2' 6 11180-11205 0 05/09/10 3-3/16"LNR 6.2#,L-80, 11315' 6 11220-11265 0 10/30/04 2' (10/06/15) .0076 bpf,D=2.80' 2' 6 11350- 11410 0 10/30/04 NP % 11950' I—BKR ORP 2" 6 11530-11595 0 10/30/04 4e (07/14/07) 2' 6 11630- 11660 0 10/08/15 2' 6 11690- 11720 0 10107/15 FISH:MLLED&PUSHED CUP(10/06/15) — 11904'CTMD 0/ 2' 6 11740- 11770 0 10/07/15 FISH:2-7/8'CUP--I ? 2' 6 11860-11895 C 10/30/04 2" 6 12045- 12110 C 10/30104 T 6 12150- 12300 C 10/30/04 F'BTD 12637' �s 2' 6 12390- 12480 C 10/30/04 H Z' 6 12515-12530 C 10/30/04 2-7/8"LNR,6.16#,L-80,.0058 bpi,ID=2.441" —I 12673' DATE REV BY COMt.ENTS DATE REV BY COMMENNTS PRUDHOE BAY UNIT 09/24/81 ORIGINAL COMPLETION 02/27/11 CJN/PJC GLV C/O(02/13/11) VV3L: E-17A 10/31/04 BM WPJC CTD SIDETRACK(E-17A) 12/08/13 PJC CEP DEPTH CORRECTION PERMT Ib:'1800480 07/19/07 RIMJPJC SET CUP@ 11950'(07/14!07) 01/06/14 CU/JK) TEE C/O(01/04/14) AR No: 50-029-20470-01 02/09/08 DAV/PJC GLV C/O(01/22/08) 10/09/15 JTM'JMD MLLED&SET CURADPERFS SEC 6,T11 N,R14E, 1753'FTL&501'FEL 05/18/10 JKD'SV SET CURADD PERE(05/09/10) 05/30/10 CJWPJC GLV C/O(05/21/10) BP Exploration(Alaska) · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 'º Q if. - ~ Q Lþ. Well History File Identifier Organizing (done) o Two-sided 1/111111I1111111111 o Rescan Needed 1111111111111111111 RESCAN ~Ior Items: vi" Greyscale Items: DIGITAL DATA ~skettes, No. ~ o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: BY: ~ Date: 1/ J?;O / t) fa I " 151 mP Project Proofing 11111111111111 111I1 BY: ~ Date: 1/ /30/00 I I 151 -mlJ Scanning Preparation BY: x 30 = '3 0 + ~ 7 = TOTAL PAGES 5 7 '- ~nt does not include cover sheet) lAA Date: 0 t? Islr VI Production Scanning 11111111111111 11111 Stage 1 Page Count from Scanned File: ~ g (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: L YES ~ Date:/1/30/Dh If NO in stage 1, page(s) discrepancies were found: YES NO 151 rnp NO BY: Stage 1 BY: Maria Date: 151 111111111111111111I Scanning is complete at this point unless rescanning is required. ReScanned 11I1111111111111111 BY: Maria Date: 151 Comments about this file: Quality Checked "11111111111111111 10/6/2005 Well History File Cover Page.doc • Page 1 of 2 Regg, James B (DOA) - From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] zitif'l Sent: Monday, February 14, 2011 3:26 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Ramsay, Gavin; King, Whitney Subject: OPERABLE: Producer E -17A (PTD #2042040) Tubing Integrity Restored All, Producer E -17A (PTD #2042040) passed a MITIA to 3000 psi on 2/13/2011 after installing dummy gas lift valves in the well. The passing MITIA confirms the presence of two competent barriers in the wellbore. The well has been reclassified as Operable. The well may be returned to production after live gas lift valves are installed. Please be aware of the potential for annular fluid expansion when returning the well to production. Please call if you have any questions. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator AitiiikEDFEB 5 7 0 1 1 Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Friday, January 28, 2011 9:05 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Ramsay, Gavin Subject: UNDER EVALUATION: Producer E -17A (PTD #2042040) Sustained Casing Pressure on the IA - POP to perform TxIA diagnostics All, Producer E -17A (PTD #2042040) was classified as Not Operable during the shut down due to sustained casing pressure. The wellhead pressures were tubing /IA/OA equal to SSV /2470/0 psi on 01/13/2011. The well has been reclassified as Under Evaluation so that it may be placed on production to perform diagnostics. The plan forward is as follows: 1. Operations: POP 2. DHD: TIFL 3. Well Integrity Engineer: Write work request to mitigate TxIA communication pending TIFL results 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 2/14/2011 Page Regg, t � , James B (DOA) • Z 4-- From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] -7 741(U Sent: Friday, January 28, 2011 9:05 PM ?/ l To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Ramsay, Gavin Subject: UNDER EVALUATION: Producer E -17A (PTD #2042040) Sustained Casing Pressure on the IA - POP to perform TxIA diagnostics All, Producer E -17A (PTD #2042040) was classified as Not Operable during the shut down due to sustained casing pressure. The wellhead pressures were tubing /IA/OA equal to SSV /2470/0 psi on 01/13/2011. The well has been reclassified as Under Evaluation so that it may be placed on production to perform diagnostics. The plan forward is as follows: 1. Operations: POP 2. DHD: TIFL 3. Well Integrity Engineer: Write work request to mitigate TxIA communication pending TIFL results Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Harmony Radio x2376 F Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Friday, January 14, 2011 10:34 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; • moski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireli - Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; AK, ►'S FS2 OSS; AK, RES GPB East Wells Opt Engr; AK, OPS GC3 Wellpad Lead; AK, OPS GC3 Facility : ield OTL; AK, OPS GC1 OSM; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lea• • AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, OPS Well Pad DFT 1 2; AK, OPS GC1 Wellpad Lead; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, RES GPB Wes ells Opt Engr Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Bo arito, Olivia 0; Robertson, Daniel B (Alaska); Ramsay, Gavin; Stone, Christopher; Kirchner, . rolyn 3; Longden, Kaity; Phillips, Patti J; Sayed, Mohamed; Holt, Ryan P (ASRC) Subject: Producers with sustained casing pressur: on IA and OA due to proration All, The following producers were found to ave sustained casing pressure on the IA during the proration January 12 -14. The immediate act is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the w= s fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 11 -05A (PTD #1961570X C -15A (PTD #2090 E -17A (PTD #204 40) E -27A (PTD #1 0590) F -04B (PTD #2100870) 2/1/2011 • Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] / Sent: Friday, January 14, 2011 10:34 PM I/ lr To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr; AK, OPS GC3 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC1 OSM; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, OPS Well Pad DFT N2; AK, OPS GC1 Wellpad Lead; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Bommarito, Olivia 0; Robertson, Daniel B (Alaska); Ramsay, Gavin; Stone, Christopher; Kirchner, Carolyn J; Longden, Kaity; Phillips, Patti J; Sayed, Mohamed; Holt, Ryan P (ASRC) Subject: Producers with sustained casing pressure on IA and OA due to proration All, The following producers were found to have sustained casing pressure on the IA during the proration January 12 -14. The immediate action is to perform a T1FL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 11 -05A (PTD #1961570) - _ PTD ; 1.1 20) .r i -17A PTD #204204• ) E -27A (PTD #1990590) F -046 (PTD #2100870) EL W -01A (PTD #2031760) W -16A (PTD #2031000) W -21A (PTD #2011110) W -25A (PTD #2091020) W -38A (PTD #2021910) The following producers were found to have sustained casing pressure on the OA during the proration January 12 -14. The immediate action is to perform an OA repressurization test and evaluate if the IAxOA pressure is manageable by bleeds. If the IAxOA communication is unmanageable, a follow up email will be sent to the AOGCC notifying you of the remedial plan. 09 -34A (PTD #1932010) M -21A (PTD #1930750) N -22B (PTD #2061610) All the wells listed above will be classified as Not Operable until start -up operations commence and are stable or the well passes a pressure test proving integrity. After start -up, the wells will then be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 1/24/2011 STATE OF ALASKA '„'~~ ~ ~ 2~~o ALASKA AND GAS CONSERVATION COMMISS REPORT OF SUNDRY WELL OPERATIONS 1. Operations ~ epair Well ^ Plug Pertorations ~ timulate ^ Other ^ Pertormed: Alt Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate 0 Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development 0 Exploratory ^ 204-2040 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-20470-01-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ~ ADLO-028304 PBU E-17A 10. Field/Pool(s): ` PRUDH OE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12673 feet Plugs (measured) 11950' 11440' feet true vertical 9012.14 feet Junk (measured) None feet Effective Depth measured 12637 feet Packer (measured) 9814 true vertical 9011.57 feet (true vertical) 8019 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 2715 13-3/8" 72# L-80 SURFACE - 2715 SURFACE - 2669 5380 2670 Intermediate Production 10373 9-5/8" 47# L-80 SURFACE - 10373 SURFACE -8465 6870 4760 Liner 1047 7" 29# L-809860 10907 - 8081 8081 - 8859 8160 7020 Liner 2787 3-1/2"X3-3-16"X2-7/8" 9886 - 12673 8077 - 9012 10160 10530 L-80 Pertoration depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 SURFACE - 9954 SURFACE - 8133 Packers and SSSV (type, measured and true vertical depth) 9-5/8" SAB PKR 9814 8019 12. Stimulation or cement squeeze summary: Intervals treated (measured): IH #f ~(` ~- w`~S' '"~' ~~`' Treatment descriptions including volumes used and final pressure: ~ .. - 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 892 31952 625 1805 Subsequent to operation: 726 24457 541 1945 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre le Title Data Management Engineer Signature Phone 564-4944 Date 5/10/2010 Form 1 ttiUM~ P~IHI 1 G curu~-vtn-~ ~,~ S=OL-ice ~-`~i"i~,-%~ E-17A 204-204 PERF ATT~~'_NMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base E-17A 10/30/04 PER 11,220. 11,265. 9,010.91 9,017.29 E-17A 10/30/04 PER 12,515. 12,530. 9,010.42 9,010.48 E-17A 10/30/04 PER 12,390. 12,480. 9,009.71 9,010.19 E-17A 10/30/04 PER 12,045. 12,110. 9,006.97 9,009.1 E-17A 10/30/04 PER 12,150. 12,300. 9,009.94 9,007.05 E-17A 10/30/04 PER 11,530. 11,595. 9,012.33 9,008.34 E-17A 10/30/04 PER 11,350. 11,410. 9,017.31 9,014.21 E-17A 10/30/04 PER 11,860. 11,895. 9,005.36 9,005.48 E-17A 7/14/07 BPS 11,950. 12,530. 9,005.33 9,010.48 E-17A 5/8/10 BPS 11,440. 11,530. 9,013.46 9,012.33 E-17A 5/9/10 APF 11,180. 11,205. 9,001.07 9,007.73 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • E-17A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 5/6/2010~CTU #5 w/ 1.75" CT. Scope: CIBP/Adperf: MIRU CT Unit. MU and RIH w/ I `WOT MHA and SLB memory tools in 2.20" carrier w/2.25" JSN. Log GR/CCL from 11600' to 9600' for coil flag. **"Job Continued on 07 May 10"** 1 5/7/2010"*" ASSIST CTU #5"""(Profile modification) RAN 3.70" x 29.5" OVERSHOT W/ 2.125" GRAPPLE TO LINER TOP @ 9,886' MD (No recovery) aTAGGED 3-1/2" LINER TOP @ 9,873' SLM / 9,886' MD W/ 3.60" L.I.B. (Liner top clear). DRIFT TO 11,229' SLM W/ 2.13" BLIND BOX, STOP DUE TO DEVIATION (No issues) CURRENTLY POOH W/ 2.13" BLIND BOX. "'**JOB IN PROGRESS, CONTINUED ON 5_/8/10 WSR*_** _ _ _ 5/7/2010 CTU #5 w/ 1.75" CT. Scope: CIBP/Adperf: Continued from 06 May 10 WSR: MU and RIH with HES Map Oil Tools 2 7/8" CIBP. Unable to pass liner top at !9890'. POOH. No plug on setting tool. RU slick line unit to fish plug. Make 2 unsuccessful attempts to fish CIBP w/ overshot. RIH with LIB and get a good =impression of 3 1/2" deployment sleeve. Confirm plug is below deployment sleeve. MU and RIH with 2.13" blind box to chase plug to deviation with SL. ""*Job Continued on 08 May 10 WSR*"* 5/9/2010 CTU #5 w/ 1.75" CT Scope CIBP/Adperf: Continued from 08 May 10 WSR: 5/8/2010""*ASSIST SLB CTU #5"**(Profile modification) ;RIG DOWN SWCP 4517. ***WELL TURNED OVER TO CTU #5, NOTIFIED PAD OPERATOR OF WELL STATUS*** 5/8/2010CTU #5 w/ 1.75" CT Scope: CIBP/Adperf: Continued from 07 May 10 WSR: SL continues RIH with 2.13" blind box. Deviate out at 11229' SLMD. MU and .RIH with 2.25" JSN drift BHA with coiled tubing. Drift /push CIBP to 11600'.. POOH MU and RIH w/2.875" CIBP. Set 2 7/8" Mari Oil Tools CIBP to a~ t 114 40' corr. MU and RIH with TCP guns. ***Job Continued on 09 May 10 WSR*"" ;Continue RIH with TCP guns. Perforate from 11180' to 11205' with 2.0" guns loaded with 2006PJ charges, ti spf, 60 deg phasing. Perforation depths correlated to SLB Memory CNL dated 30 October 2004. Freeze protect well ¥with 38 Bbls 50/50 methanol water. RDMO. ""*Job Complete*** FLUIDS PUMPED BBLS 112 60/40 METH 86 1 % XS KCL 198 Total TREE = 6-3/8 CIW Wt=LLHEA~..= '' FMC ACTUATOR = OTIS KB. ELEV = 60.29' BF. ELEV = 31.39' kOP = 2000' Max Angle = 97 @ 11608' Datum MD = 10908' datum ND = 8800' SS i sA~nr ~s: E -'I 7A ,,,,,,,,,,,,,,,202$' 4-112'" CAMCO SSSV LANDING NIP, ID = 3.813" GAS LIFT MANDRELS 13-318" CSG, 72#, L-80, ID = 12.347" I-~ Z71 Minimum ID = 2.377" @ 11315' TOP OF 2-7/8" LINER I TOP OF 7" LNR I 3-1/2" LNR, 8.81#, L-80, .0087 bpf, ID = 2.992" 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.953" 9-5/8" CSG, 47#, L-80, ID = 8.681" WHIPSTOCK RA TAG (10/18104) PBTD 7" TBG, 29#, L-80, ID = 6.1$2" PERFORATION SUMMARY REF LOG: BRCS ON 09121!81 ANGLE AT TOP PERF: 79 @ 11220' Note: Refer to Production DB far historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11220 - 11265 O 10/30/04 2" 6 11350 - 11410 O 10(30/04 2" 6 11530 - 11595 O 10/30/04 2" 6 11860 -11895 O 10(30/04 2" 6 12045 - 12110 C 10/30/04 2" 6 12150 - 12300 C 10/30/04 2" 6 12390 - 12480 C 10/30/04 2" 6 12515 - 12530 C 10!30/04 ST MD ND DV TYPE VLV LATCH PORT DATE 7 3103 2931 35 CA-MMG DMY RK 0 01/22/08 6 5625 4839 40 CA-MMG DMY RK 0 01/22/08 5 7049 5913 45 CA-MMG DMY RK 0 09/24!81 4 8006 6568 46 CA-MMG DMY RK 0 09/24/81 3 8682 7051 42 CA-MMG DMY RK 0 09/24/81 2 9199 7450 36 CA-MMG DMY RK 0 09!24181 1 9711 7874 35 CA-MMG DMY RK 0 09(24!81 I I 9740' 4-112" BKR L SLD SLV, ID = 3.813" 9796' TUBING SEAL ASSY 9814' 9-5/8" BKR SAB PKR, ID = 3.813" 9873' 4-1 /2" OTIS X NIP, ID = 3.813 I 9886' 3-112" BKR DEPLOY SLV, ID = 3.00" 9915' 3-1/2" X NIP, ID = 2.813" 9917' 4-1/2" OTIS XN MILLED NIP, ID = 3.80" (BEHIND PIPE) 9947' 3-112" X 3-3/16" XO, ID = 2.79" 9954' 4-1/2" BKR TT (BEHIND PIPE} 10440' EST TOP OF CMT (DIMS 10/27104) MILLOUT WINDOW 10910' -10915' ~ 3-3116" LNR, 6.2#, L-80, .0076 bpf, ID = 2.80" ~ 11315' 3-3116" X 2-7/8" XO, ID = 2.44" ~r3P l(y~(D',w~ ~ 11950' ~ KR CIBP 07114/07) PBTD 2-718" LNR, 6.16#, L-$0, .0058 bpf, ID = 2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS 09!24!81 ORIGINAL COMPt_ETION 07!19107 RWL/PJC SET CIBP@ 11950' (07/14!07} 10!31/04 BMH/PJC CTDSIDETRACK(E-17A) 02/09(08 DAVIPJC GLV Ci0(01/22/08) 11(19!04 DAV/TLH GLV C(O 09!28!05 SGS/TLH DRLG DRAFT CORRECTIONS 10!04/06 CJN/TLH XX TTP 5ET 10/15!06 KSB/TLH XX TTP PULLED PRUDHOE BAY UNIT WELL: E-17A PERMR' No: 1800480 API No: 50-029-20470-01 SEC 6, T11 N, R14E, 1753' SNL & 501' WEL BP Exploration (Alaska) • ~ .~.~~-. R MICRt)FILMED 03/0'1 /2048 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CvrFgs_InsertslMicmfclm Markercioc ~ ;f ~, . STATE OF ALASKA ~ ~t77 JUL ALASKA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERA TtGNSii ¿:~ D D D ,-_IVL-U 'I.··· '.ì. '7. 0 0 7 ~.,l .,) ,. Cons. Commission 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Ope rat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic Stimulate D æ;eSET PLUG Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (It): Exploratory Service 204-2040 r 3. Address: 6. API Number: 50-029-20470-01-00 9. Well Name and Number: 60.3 KB PBU E-17A - 8. Property Designation: ADLO-028304 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Total Depth measured 12673 r feet Plugs (measured) None true vertical 9012.14 - feet Junk (measured) None Effective Depth measured 12637 . feet true vertical 9011.57 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" Surface - 110' Surface - 110' Surface 2715' 13-3/8" 72# L-80 Surface - 2715' Surface - 2669' 5380 2670 Production 10373' 9-5/8" 47# L-80 Surface 10373' Surface - 8465' 6870 4760 Liner 1047' 7" 29# L-80 9860' 1 0907' 8081' - 8859' 8160 7020 Liner 2787' 3-1/2"x3-3/16x2-7/8" L- 9886' 12673' 8077' - 9012' 10160 10530 Perforation depth: Measured depth: 11220' - 12530' True Vertical depth: 9011' - 9010' - - - Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 Surface - 9954' Packers and SSSV (type and measured depth) 9-5/8" BAKER SAB o o o 9814' o o o 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED JUL 3 1 2007 R8DMS 8FL JUL 3 020D7 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 13.658 0 45.407 0 0 15. Well Class alter proposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl 2118 6077 Tubing pressure 852 847 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service x Contact Gary Preble WINJ WDSPL Title Data Management Engineer Signature Phone 564-4944 Date 7/19/2007 Form 10-404 R vised 04/200V RIG I N A L ~l)¥ ~ ~~ Submit Original Only . . . E-17 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY CTU #5***Drift/Set CIBP***MIRU. RIH with 2.25" nozzle for drift of tubing to 12010' pooh. Rih with Baker 27/8" CIBP to 11950' set and Dooh, ***Release well to DSO*** Job Complete FLUIDS PUMPED BBLS 100 1 % KCL 10 50/50 METH 110 TOTAL Schlumberger 02/16/2007 NO. 4151 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 db4 -doLI sJ. ¡4lfi1 Field: Prudhoe Bay WI! J b# L D CI CD D BL e 0 og escrlptlOn ate o or MPB-21 11628749 MEMORY PROD PROFILE 01/15/07 1 C-35A 11209595 MCNL 03/27/06 1 1 E-17 A 11285948 MCNL 10/21/06 1 1 D-19B 11209597 MCNL 04/20/06 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc Petrotechnical Data Center LR2-1 900 E. Benson Blvd SCANNED FES 2 0 2007 Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: Received by: :) . . Sc~fombøpgør cJCI-I-é)û4 NO. 4047 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay CI CD Well Job# Loa Description Date BL o or E-17A 11285948 MEM PROD PROFILE 10/21/06 1 E-17A 11285948 SCMT 10/21/06 1 L-04 N/A SCMT (REDO) 10/21/06 1 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 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 A",","". AK ""'If ATTN: Beth ' Received by:ê ~ Date Delivered: N(. )H "~ 9 1)ODC ~ W ... f..) Ii ft~ ~ 11/21/06 . . ~ ~ iJ\1I ~t,o DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Permit to Drill 2042040 Well Name/No. PRUDHOE BAY UNIT E-17A Operator BP EXPLORATION (ALASKA) INC S(J~ ;l '10 á--~ 'f API No. 50-029-20470-01-00 MD 12673 r TVD 9012 / Completion Date 10/31/2004 / Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD GR / EWR, MGR / CCL / CNL Well Log Information: Electr Digital Dataset Med/Frmt Number D Asc (data taken from Logs Portion of Master Well Data Maint . Name Directional Survey Directional Survey Neutron Log Log Scale Media Run No Interval OH/ Start Stop CH Received 10900 12673 Open 11/15/2004 10900 12673 Open 11/15/2004 9557 12550 Case 2/3/2005 10838 12630 Open 10/26/2005 10932 12673 Open 2/22/2006 Comments IIFR IIFR o cnl/mem gr/ccl/nut GR EWR4 ROP ROP DGR EWR plus Graphics Open 7/25/2006 DEPT, CCL w/Graph~~~~ 2 Blu D Lis 13330 Induction/Resistivity C Lis 13634 Induction/Resistivity C Lis 13994 Induction/Resistivity o Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y .(ti) . Daily History Received? GIN &N Chips Received? ~ Formation Tops Analysis Received? ~ Comments: Compliance Reviewed By: ~ Date: ~JJ ~ J ~~ e 0 og escrlptlon ate oor D 15-UA 1u114¡¡:0 t(~ I uKAvt:L PACK u6/¡¡::¡/uti 1 17-08 112115u1I INJt:~T ,~~ ut)/¡¡:4/06 1 P2-11A 11221564 JEWELRY/STATIC SURVEY 04/27/06 1 13-06A 11217266 INJECTION PROFILE 07/12/06 1 P2-01 11223106 STATIC PRESSURE/JEWELRY 03/25/06 1 L5-08 11217256 PROD PROFILE W/GHOST & DEFT 06/06/06 1 16-04A 11217245 PROD PROFILE W/DEFT 05/08/06 1 05-40 11223123 LDL 07/07/06· 1 17-09 11211412 PROD PROFILE W/DEFT & GHOST 06/26/06 1 MPC-07 N/A SENSA/MEMORY GLS 04/22/06 1 04-18 1121584 USIT 06/27/06 1 1..!-51 11212873 USIT 06/28/06 1 04-31 11217264 USIT 07/07/06 1 D-14A 11217265 USIT 07/09/06 1 PSI-07 10703937 MDT 10/13/03 1 02-16B 11209601 MCNL 04/25/06 1 1 L2...,8A 11217234 MCNL 04/06/06 1 1 L5-09 11212847 MCNL 04/25/06 1 1 Z-26A 11216205 MCNL 07/05/06 1 1 12-01 11072866 RST 07/06/05 1 1 E-17A 10928602 MCNL (Prints sent 1/24/05) 10/30/04 1 Sc~IIn~....... Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth dD "I-()Cl'¡ WII J b# L D D BL 1?J Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 07/19/06 NO. 3880 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay CI C . . Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth . . WELL LOG TRANSMITTAL JD4- ;204- To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 February 17,2006 ~ ?J{p2J4-- RE: MWD Formation Evaluation Logs E-17 A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 E-17 A: LAS Data & Digital Log Images: 50-029-20470-01 1 CD Rom ~ P/~ . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm.. Attn.: Helen Wannan 333 West 7th Avenue, Suite 100 Anchorage, Alaska 9950 I September 28, 2005 RE: MWD F onnation Evaluation Logs: E-17 A, AK-MW-3353779 1 LDWG fonnatted Disc with verification listing. API#: 50-029-20470-01 ) ]3 3 ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: 1 7 0 ~ r Signed: 'lLJdLJ ^(J\JI-~ ~~ :;2 0 c( - ;;<J-' cf 01/24/05 Schlumberger NO. 3318 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay . Color /C¡/?~I F11- r3 fC'¡f-(:,Z 1.Pf; f{ .~e-D1 ¡qq-Of; 1Pf- f} J 15- 0 :).ot{·J.Ð ~t:4-icg i7,..,v).{).. ,-v ~ ·'''ii{.it; Î1j- {~3 Z {)II- 2.1 . Well Job# Log Description Date Blueline Prints CD '7L C-29A 10715422 MCNL 08/20/04 1 j E-25 10715423 MCNL 08/21/04 1 q G-02A 10715424 MCNL 08/23/04 1 W-27A 10670031 MCNL 08/24/04 1 ~.. D-25A (__ 10854314 MCNL 08/27/04 1 .(.. DS 15-25A "- 10715428 MCNL 09/11/04 1 1ft: E-39A 10715430 MCNL 09/13/04 1 02-16B 10928597 MCNL 10/02/04 1 {I C-25A 10928598 MCNL 10/03/04 1 1 E-17A I 10928602 MCNL 10/30/04 1 ~ C-41A I 10928606 MCNL 11/24/04 1 ,- DS 07-30A / 10715445 MCNL 12/09/04 1 ~t. DS 15-38A a£.. 10715446 MCNL 12/11/04 1 ;{ 02-28A 10928607 MCNL 12/11/04 1 D-11A 10928608 MCNL 12/16/04 1 f) DS 05-24A 10928609 MCNL 12/22/04 1 I(Prints_ only-Job not complete) 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: ~ih$' Alaska Data & Consulting Services 2525 Gambell Street, S~~OO Anchorage, AK 9950 J838, ATTt::. e I , / Rece \(!'!d by: I .1. ~J! /I~ / v-- , (/, · STATE OF ALASKA _ ALASKA AND GAS CONSERVATION COMrvTWlON WELL COMPLETION OR RECOMPLETION REPORT AND LO%aska Oil & Gas Cons. Commission Revised: 12/14/04AR&ùleøModuction RECEIVED DEC 1 5 2004 ........... 1a. Well Status: IS! Oil DGas D Plugged D Abandoned D Suspended DWAG 1 b. Well Class: 20MC 25.105 20MC 25,110 IS! Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions One Other D Stratigraphic D Service 2. Operator Name: 5. Date Camp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 10/31/2004 204-204 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 10/24/2004 50- 029-20470-01-00 4a. Location of Well (Governmental Section): 7. Date T.O. Reached 14. Well Name and Number: Surface: 10/28/2004 PBU E-17A 1753' SNL, 501' WEL, SEC. 06, T11 N, R14E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 3665' SNL, 4790' EWL, SEC. 05, T11 N, R14E, UM 60.3' Prudhoe Bay Field I Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+ TVD) Pool 2609' SNL, 4486' EWL, SEC. 05, T11 N, R14E, UM 12637 + 9012 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 664485 y- 5975311 Zone- ASP4 12673 + 9012 Ft ADL 028304 TPI: x- 669822 y- 5973517 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 669492 y- 5974566 Zone- ASP4 (Nipple) 2028' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey IS! Yes DNa NIA MSL 1900' (Approx.) 21. Logs Run: MWD GR I EWR, MGR I CCL I CNL 22. CASING, LINER AND CEMENTING RECORD CASING SElTING EPTlfMP i SEl'TING I EPTH TVD HôLS SIZE V'Jr. PERF.... GRADE lOP BOTTOM lOP II:$OTTOM SIZE ·ÞuÜ"èb···· 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu vds Concrete 13-3/8" 72# L-80 Surface 2715' Surface 2669' 17-1/2" 3720 cu ft Arcticset II 9-5/8" 47# L-80 Surface 10373' Surface 8465' 12-1/4" 1500 cu ft Class 'G', 130 cu ft AS I 7" 26# L-80 9890' 10907' 8081' 8859' 8-1/2" 480 cu ft Class 'G' 3-1/2" x 3-3116" x 2-7/8" 8.81# 16.2# 16.16# L-80 9886' 12673' 8077' 9012 4-1/8" x 3-3/4" 157 cu ft Class 'G' 23. Perforations open to Production (MO + TVD of To£ and 24. TUBINGiRECORO ... Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 4-112", 12.6#, L-80 9954' 9814' MD TVO MD TVD 11220' - 11265' 9011' - 9017' 25. I\C/D, 11350' - 11410' 9017' - 9014' . 11530' -11595' 9012' - 9008' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11860' - 11895' 9005' - 9005' 12045' - 12110' 9007' - 9009' 2200' Freeze Protected with 25 Bbls of MeOH 12150' - 12300' 9010' - 9007' 12390' - 12480' 9010' - 9010' 12515' - 12530' 9010' - 9010' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): December 1, 2004 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF WATER-BBl CHOKE SIZE I GAS-Oil RATIO 12/5/2004 4 TEST PERIOD .. 287 2,321 -0- 960 8,080 Flow Tubing Casing Pressure CALCULATED .. Oll-BBl GAs-McF W A TER-BBl Oil GRAVITY-API (CORR) Press. 79;: 983 24-HoUR RATE 1,723 13,924 -0- 25.9 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None RBDMS 8FL DEC 2 0 2004 ~ /' {yy Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ... 28. GEOLOGIC MARKERS 29. MATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Zone 1 B 11105' 8974' None Zone 1A ITDF 11218' 9011' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date \~ 14 0 PBU E-17A Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Scott Kolstad, 564-5347 204-204 Permit No. I A roval 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only . STATE OF ALASKA . ALAS~ AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil DGas D Plugged D Abandoned D Suspended DWAG 1b. Well Class: 20AAC 25.105 20AAC 25,110 181 Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions One Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Dl'ill Number BP Exploration (Alaska) Inc. 10/31/2004 204-204 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 10/24/2004 50- 029-20470-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 10/28/2004 PBU E-17 A 1753' SNL, 501' WEL, SEC. 06, T11N, R14E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 3665' SNL, 4790' EWL, SEC. 05, T11N, R14E, UM 60.3' Prudhoe Bay Field I Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 2609' SNL, 4486' EWL, SEC. 05, T11 N, R14E, UM 12637 + 9012 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 664485 y- 5975311 Zone- ASP4 12673 + 9012 Ft ADL 028304 TPI: x- 669822 y- 5973517 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 669492 y- 5974566 Zone- ASP4 (Nipple) 2028' MD 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost 181 Yes DNa NIA MSL 1900' (Approx.) 21. Logs Run: MWD GR I EWR, MGR I CCL I CNL 22. CASING, LINER AND CEMENTING RECORD i9~~~~ ....... SE¡TTI \j(; ~~·MD ·~mJNG·1 JE¡PTlil"VD >~~r WT.PER!:t C3Rt.DE ToF' .BOTTOM TOF' !ti$OTJ"OM PÜ[~D 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu yds Concrete 13-3/8" 72# L-80 Surface 2715' Surface 2669' 17-1/2" 3720 cu ft Arcticset II 9-5/8" 47# L-80 Surface 10373' Surface 8465' 12-1/4" 1500 cu ft Class 'G', 130 cu ft AS I 7" 26# L-80 9890' 10907' 8081' 8859' 8-1/2" 480 cu ft Class 'G' 3-1/2" x 3-3/16" x 2-7/8" 8,81# 162# / 6.16# L-80 9886' 12673' 8077' 9012 4-1/8" x 3-3/4" 157 cu ft Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. T )ßfNG· ..... Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 9954' 9814' MD TVD MD TVD 11220' - 11265' 9011' - 9017' 25. <Aclc .....;"'.. ,..,.,...",iET.C. 11350' - 11410' 9017' - 9014' ....':'"!..~.., .. i 11530' - 11595' 9012' - 9008' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11860' -11895' 9005' - 9005' 12045' -12110' 9007' - 9009' 2200' Freeze Protected with 25 Bbls of MeOH 12150' - 12300' 9010' - 9007' 12390' - 12480' 9010' - 9010' 12515' - 12530' 9010' - 9010' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas lift, etc.): Not on Production Yet N/A Date of Test Hours Tested PRODUCTION FOR Oll-BSl GAs-McF WATER-Bsl CHOKE SIZE I GAS-all RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ... Oll-Bsl GAs-McF WATER-BSl all GRAVITY-API (caRR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". r"-;.;~... ; Nonef;;~i ! RBDMS 8Fl DEC 0 6 1004 ¡ , ¡ ¡ JE"'C:' ;; ¡ , \~! Gf l' . ,'_ i .__....,...,.""'...~.. ...,..."",,\, Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS 29. RMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Zone 1 B 11105' 8974' None Zone 1A I TDF 11218' 9011' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date 11?b PBU E-17A Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Scott Kolstad, 564-5347 204-204 Permit No. I A roval 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-17 E-17 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 1 0/23/2004 1 0/31 /2004 N1 Spud Date: 9/7/1981 End: 10/31/2004 10/23/2004 03:00 - 04:00 1.00 RIGD P PRE Rig released from F-11 B @ 03:00Hrs on 10/23/2004. R/D CT reel. 04:00 - 04:15 0.25 RIGD P PRE PJSM with Peak crew on CT reel swap. Review the recent BP GoM DWP Hipo incident on dropped CT reel & Peak pre-pick checklist. 04:15 - 07:00 2.75 RIGD P PRE P/U & lower reel to Peak double drop trailer. Replace reel drive bushings. P/U replacement reel into reel house & align drive pins & bushing. 07:00 - 08:00 1.00 MOB P PRE Move rig off of well and press test tree cap on F-11 B. 08:00 - 08:30 0.50 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigation with all personnel involved with rig move to E pad. 08:30 - 12:45 4.25 MOB P PRE Move rig to E pad via road behind GC-1. No incidents. Good move. 6 miles. 12:45 - 13:00 0.25 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigation for backing rig over well. 13:00 - 14:30 1.50 BOPSU P PRE ACCEPT NORDIC 1 ON E-17A AT 13:00 HRS, 10/23/04. N/U BOPE. 14:30 - 15:30 1.00 RIGU P PRE Position tanks, generator 3, camp, general rig up. 15:30 - 16:30 1.00 RIGU P PRE Stab coil into injecter head. RU hardline inside reel. 16:30 - 21 :30 5.00 BOPSU P PRE Perform initial BOPE pressure/function test. AOGCC test witnessed by Chuck Scheve. Meanwhile fill rig pits with 2% KCL bio-water. RIU & PIT hardline to flowback tank. Open up well & observe Opsi WHP, Opsi lAP & 90psi OAP. 21 :30 - 23:30 2.00 RIGU P PRE Inspect injector & CIO packoff. 23:30 - 00:00 0.50 RIGU P PRE Cut coil & install Baker CTC. 10/24/2004 00:00 - 00: 15 0.25 STWHIP P WEXIT Pull test Baker CTC to 35k. 00:15 - 01:00 0.75 STWHIP P WEXIT Pump 5bbls of MeOH spear & fill coil with KCL-bio water. 01 :00 - 01 :30 0.50 STWHIP P WEXIT Install dart catcher. Load wiper dart. Launch & chase with KCL-bio water. Dart hit @ 56.9bbls. Press test inner reel valve & CTC to 3500psi - OK. 01 :30 - 01 :45 0.25 STWHIP P WEXIT Held pre-operations safety meeting. Reviewed well plan, potential hazards & milling BHA MIU procedures. 01 :45 - 02:30 0.75 STWHIP P WEXIT M/U window milling BHA #1 with a 3.80" HC DSM, 3.79" diamond string reamer, Baker straight Xtreme motor, MHA & 2 jts of PH6 tbg. M/U injector. 02:30 - 04:30 2.00 STWHIP P WEXIT RIH with BHA #1 choking FP fluid & gassy returns to the tiger tank. Wt check @ 10850': Up = 41.5k, down = 18.5k. Continue RIH BHA#1 & tag @ 10930'. P/U & retag @ same depth. Establish freespin @ 2.5bpm/1700psi. 04:30 - 04:45 0.25 STWHIP P WEXIT Mill with 2.5bpm/1700psi & hit hard spot @ 10932.5'. Stall2x & suspect we're @ WS/Lnr pinch pt. Flag pipe & correct depth to 10914.6' (pinch pt ELMO). 04:45 - 05:00 0.25 STWHIP P WEXIT Mill from 10914.6' to 10915' with 2.5/2.5bpm, 1700/2000psi, <1 k WOB. 05:00 - 06:00 1.00 STWHIP P WEXIT Mill from 10917' with 2.5/2.5bpm, 1700/2200psi, 3k WOB & 2fph ave ROP. 06:00 - 07:30 1.50 STWHIP P WEXIT Mill window, 2.5 bpm, 1900-2200 psi, 2-3K WOB, milled to 10,918'. 07:30 - 09:00 1.50 STWHIP P WEXIT Mill window, 2.5 bpm, 1900-2200 psi, 2-3K WOB, milled to 10,919'. 09:00 - 11:15 2.25 STWHIP P WEXIT Mill window, 2.5 bpm, 1900-2300 psi, 2-3K WOB, milled to 10,921'. Up wt = 37K, Back ream window, Dwn wt = 15.5K, ream Printed: 11/1/2004 1:51:57 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-17 E-17 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 10/23/2004 Rig Release: 10/31/2004 Rig Number: N1 Spud Date: 9/7/1981 End: 10/31/2004 1 0/24/2004 09:00 - 11 :15 2.25 STWHIP P !WEXIT window. 11 : 15 - 12:00 0.75 STWHIP P WEXIT Mill window, 2.5 bpm, 1900-2300 psi, 2-3K WOB, milled to 10,921.7'. Stalled 2 times at exit point of 10,921.5'. 7 ft window. Top of window at 10,915'. Bottom of window at 10,922'. 12:00 - 12:40 0.67 STWHIP P WEXIT Mill formation to 10,932'. 2.7 bpm, 2200 psi, 1-2K wob, Milled to 10932'. 12:40 - 13:30 0.83 STWHIP P WEXIT Back ream window. Swap to Re-built FloPro. 2.7 bpm, 2800 psi. Ream down, up and down. Window is clean. Stop pump, RIH clean thru window. Window is clean. 13:30 - 15:45 2.25 STWHIP P WEXIT POH while circ. Flag CT at 10,700' EOP. POH, 15:45 - 16:30 0.75 STWHIP P WEXIT PJSM. UD BHA#1 & inspect mills. DWM gauge 3.80" go / 3.79" no-go & DSR gauge 3.79" go /3.78" no-go. Wear on window mill face indicates center crossed the 1m wall. 16:30 - 16:45 0.25 STWHIP P WEXIT Rehead & M/U DS CTC. Pull & pressure test. 16:45 - 17:00 0.25 DRILL P PROD1 Held pre-spud safety meeting. Reviewed well plan, potential hazards & drilling BHA M/U procedures. 17:00 - 18:15 1.25 DRILL P PROD1 M/U build section BHA #2 with a rebuilt Hughes RWD2ST 3-3/4" x 4-1/8" bicenter bit, 3.06deg bend motor & MWD/GR/RES. Initialize RES tool & M/U orienter & MHA. M/U injector. 18:15 - 20:45 2.50 DRILL P PROD1 RIH with BHA #2. SHT MWD & orienter - OK. Correct CTD by -17' @ the flag. RIH with pumps down & tag TD @ 10930'. Correct CTD to 10932'. PUH above W/S to 10905' for GR tie-in. 20:45 - 21 :20 0.58 DRILL P PROD1 Log up GR & tie-in into Geology PDC log - Add l' to CTD. 21 :20 - 21 :30 0.17 DRILL P PROD1 RIH clean thru window without pumps. Tag btm @ 10931'. Check TF - @ 25L. Establish freespin @ 2.7bpm/3430psi. P/U wt = 36k, S/O wt = 27k. PVT = 333bbls. lAP = 76psi, OAP '" 206psi. 21 :30 - 22:00 0.50 DRILL P PROD1 Orient TF to 30R. 22:00 - 00:00 2.00 DRILL P PROD1 Commence driling build/turn section. Drill with 20R TF, 2.7/2.7bpm, 3450/3700psi, 2k WOB & 15fph ave ROP. Drill to 10950' with frequent motor stalling. 1 0/25/2004 00:00 - 00:45 0.75 DRILL P PROD1 Drill to 10964' with 20R TF, 2.7/2.7bpm, 3450/3700psi, 2k WOB & 15fph ave ROP. Getting occasional motor stalls. 00:45 - 00:55 0.17 DRILL P PROD1 Orient TF to 90R. 00:55 - 02:00 1.08 DRILL P PROD1 Drill to 11000' with 85R TF, 2.7/2.7bpm, 3450/3700psi, 2k WOB & 35fph ave ROP. 02:00 - 02:10 0.17 DRILL P PROD1 Pump up off btm survey. 02:10 - 02:45 0.58 DRILL P PROD1 Orient & drill to 11012' with 11 0-120R TF, 2.7/2.7bpm, 3450/3700psi, 2k WOB & 45fph ave ROP. 02:45 - 03: 15 0.50 DRILL P PROD1 Orient at btm - not getting clicks. PUH above window & orient TF around to 20R. RBIH to btm & grab 2 more clicks. 03:15 - 05:45 2.50 DRILL P PROD1 Drill to 11064' with 65R TF (rolling to 95R), 2.7/2.7bpm, 3450/3700psi, 2k WOB & 35fph ave ROP. 05:45 - 06:30 0.75 DRILL P PROD1 Orient TF to 60R. - Crew Change. 06:30 - 07:20 0.83 DRILL P PROD1 Drill ahead to 11,088' MD - TF at 60R. - 2.7/2.8 bpm - 3600 psi (3400 psi free spin) Printed: 11/1/2004 1 :51 :57 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-17 E-17 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 10/23/2004 10/31/2004 N1 Spud Date: 9/7/1981 End: 10/31/2004 10/25/2004 06:30 - 07:20 0.83 DRILL P PROD1 - 50 - 60 fph ROP. 07:20 - 07:50 0.50 DRILL P PROD1 Orient TF to 25R. 07:50 - 08:20 0.50 DRILL N SFAL PROD1 Union fitting in reel house failed. Pull up to window, shut down pumps. - No fluid outside reel house. 08:20 - 08:40 0.33 DRILL P PROD1 I Orient TF to 70R. 08:40 - 10:20 1.67 DRILL P PROD1 Drill ahead to 11,162' MD - TF at 80R. - 2.7 1 2.8 bpm - 3600 psi (3400 psi free spin) - 50 - 60 fph ROP. [ - Ratty drilling through pyrite section. 10:20 - 11 :20 1.00 DRILL P PROD1 Orient TF to 70R. I - Trouble getting clicks in open hole. Pull up into casing. 11 :20 - 15:00 3.67 DRILL P PROD1 Drill ahead to 11,215' MD. - TF at 70R. ·2.7/2.8 bpm - 3600 psi (3400 psi free spin) - 15 - 40 fph ROP. - Drilling WOB 2-4k. - Pyrite diminishing in cuttings samples. - Penetrated Zone 1 at approximately 11,080' MD. - Stacking weight on bit, bit would stall or continue to stack out, up to 4k. 15:00 - 17:30 2.50 DRILL P PROD1 POOH with build BHA #2. - C/O HC bit (graded 2-4-BT). - Check motor -- OK. 17:30 - 19:45 2.25 DRILL P PROD1 RIH with build BHA #3 -- 4.125" bicenter. - SHT at 2100' MD. RIH below window for GR tie-in. 19:45 - 19:55 0.17 DRILL P PROD1 Log up GR & tie-in into RA PIP tag - Subtract 4.5' from CTD. 19:55 - 20:00 0.08 DRILL P PROD1 Continue RIH with drilling BHA #3 & tag TD @ 11215'. 20:00 - 20:30 0.50 DRILL P PROD1 PUH & orient TF around to 60R. RBIH to btm. Establish freespin @ 2.6bpm/3500psi. P/U wt = 33k, S/O wt = 17k. PVT = 314bbls. lAP = 433psi, OAP = 317psi. 20:30 - 22: 15 1.75 DRILL P PROD1 Orient & drill to 11251' with 70R TF, 2.6/2.6bpm, 3500/3650psi, 2k WOB & 40fph ave ROP. 22:15 - 23:50 1.58 DRILL P PROD1 Orient & drill to 11297' with 70R TF, 2.6/2.6bpm, 3500/3750psi, 4k WOB & 45fph ave ROP. Very ratty drilling with lots of pyrite in BU samples. Crossing prognosed fault-1 zone. - HOT at 8958' TVD /11,275' MD. 23:50 - 00:00 0.17 DRILL P PROD1 Orient at btm - not getting clicks. PUH to window & orient TF around to 90R. 10/26/2004 00:00 - 00:10 0.17 DRILL P PROD1 RBIH to btm. 00:10 - 00:20 0.17 DRILL P PROD1 Drill to 11307' with 115R TF, 2.6/2.6bpm, 3500/3850psi, 5k WOB & 35fph ave ROP. Geo wants to drill up. 00:20 - 01 :30 1.17 DRILL P PROD1 Wiper to window & orient - not getting clicks. PUH above window & orient TF around to 50R. RBIH to btm. 01 :30 - 02:15 0.75 DRILL P PROD1 Drill to 11326' with 60R TF, 2.6/2.6bpm, 3500/3750psi, 6k WOB & 35fph ave ROP. Very ratty drilling. 02: 15 - 02:40 0.42 DRILL P PROD1 Wiper to window & orient TF to 70R. RBIH to btm. 02:40 - 03:35 0.92 DRILL P PROD1 Drill to 11373' with 80R TF, 2.6/2.6bpm, 3500/3750psi, 6k WOB & 55fph ave ROP. Grind on & finally break thru @ Printed: 11/1/2004 1:51:57 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-17 E-17 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 10/23/2004 1 0/31 /2004 N1 Spud Date: 917/1981 End: 10/31/2004 1 0/26/2004 02:40 - 03:35 0.92 DRILL P PROD1 11365'. 03:35 - 04:20 0.75 DRILL P PROD1 Wiper to window & orient TF to 120R. RBIH to btm. 04:20 - 04:45 0.42 DRILL P PROD1 Drill to 11393' with 130R TF, 2.6/2.6bpm, 3500/3850psi, 4k WOB & 55fph ave ROP. 04:45 - 05:45 1.00 DRILL P PROD1 Wiper to above window & orient TF to 60R. RBIH to btm. 05:45 - 06:00 0.25 DRILL P PROD1 Drill to 11395' with 80R TF, 2.6/2.6bpm, 3500/3650psi, 2k WOB & 55fph ave ROP. 06:00 - 07:30 1.50 DRILL P PROD1 Drill to 11423' MD - 90 R TF - 2.6/2.7 bpm - 3850 psi (3600 psi free spin) - 4-5k WOB. - 40 - 50 fph. 07:30 - 08:00 0.50 DRILL P PROD1 Orient TF to 110 R TF - Pull uphole to get click for 25' of drop. - Difficulty getting clicks. - Decision: We are on plan and will drop with the lateral BHA. 08:00 -10:15 2.25 DRILL P PROD1 POOH with Build BHA #3 for lateral BHA. - Paint flag at 10,700' EOP. - Test orienter in 7", 20 degree clicks. 10: 15 - 12:30 2.25 DRILL P PROD1 Lay down BHA. - Download data. - C/O directional/GR package internals. - Change bend to 1.06 deg. - Re-run bit (grade 0-0). Unplugged one jet. 12:30 - 14:45 2.25 DRILL P PROD1 RIH with lateral BHA #4. - SHT at 2100 psi. - Correct to flag depth 10,790' MD o PU 33k; S014k 14:45 - 15:45 1.00 DRILL P PROD1 Tie in to RA tag. o Correction (+ 14) RIH to bottom 15:45 - 16:15 0.50 DRILL P PROD1 Drill to 11453' MD - 130 R TF - 2.6/2.7 bpm - 3750 psi (3450 psi free spin) - AVG: 50 fph. 16:15-17:45 1.50 DRILL P PROD1 Orient TF to 90 R. - Would not orient in the OH. Trip to window. - Orient 10 deg clicks with bit outside window. 17:45 - 18:35 0.83 DRILL P PROD1 Drill to 'MD - 80 R TF - 2.5/2.6 bpm - 3900 psi (3600 psi free spin @ 2.5 bpm) - AVG: 80 fph. 18:35 - 19:07 0.53 DRILL P PROD1 Drilling at 90R TF, need 12 to 13 deg DL for this turn Work CT to clean up lots of stacking in the shale Resultant TVD set at 8954 to 8953 ft TVD Qp = 2.5/2.60bpm. CTP = 3750/4100 psi ROP ave = 66 fph when drilling at negative WOB Started Mud Swap at 11,511 ft 19:07 - 19:35 0.47 DRILL P PROD1 OrientTF around to 85L at 11,515 ft getting clicks 19:35-21:05 1.50 DRILL P PROD1 Drilling TF @ 83R. Printed: 11/1/2004 1:51:57 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-17 E-17 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 1 0/23/2004 1 0/31 /2004 N1 Spud Date: 9/7/1981 End: 10/31/2004 10/26/2004 19:35 - 21 :05 1.50 DRILL P PROD1 Qp = 2.60/2.67 bpm CTP = 3500/3990 psi. ROP = 45 to 70 fph average. Still conducting mud swap. The CTP is decreasing as new mud is circulated around. Drilling shale and trying to build hole angle. Better WOB transfer with new mud 21 :05 - 21:45 0.67 DRILL P PROD1 Wiper Trip to tie-in (Corrected +2 ft) TOWS @ 10907 ft TOW @ 10910ft BOW @ 10915 ft RA Marker @ 10917 ft 21 :45 - 22:00 0.25 DRILL P PROD1 RIH Clean wiper trip 22:00 - 22:30 0.50 DRILL P PROD1 Drilling TF @ 95R. Qp = 2.63/2.76 bpm CTP = 3200/3750 psi. ROP = 30 to 88 fph average. Looking for sand and trying to level out. ROP inc at 11,625 ft 22:30 - 22:45 0.25 DRILL P PROD1 Orient TF to 180 deg 22:45 - 23:20 0.58 DRILL P PROD1 Drilling TF @ 156R. Qp = 2.63/2.76 bpm CTP = 3350/3600 psi. ROP = 30 to 88 fph average. Found sand and turned TF down Max angle 97.44 deg at 11,626 ft 23:20 - 00:00 0.67 DRILL P PROD1 Orient TF 10/27/2004 00:00 - 00:20 0.33 DRILL P PROD1 Orient TF 00:20 - 00:45 0.42 DRILL P PROD1 Drilling at 86R TF Qp = 2.78/2.89 bpm; CTP = 3350/3878 psi Vp = 291 bbl ROP=50-70 fph Hole angle still to high +93.5 deg TVD wanted = 8,947 ft 00:45 - 00:55 0.17 DRILL P PROD1 Orient TF to 180 00:55 - 01 :55 1.00 DRILL P PROD1 Drilling at 156R TF Qp = 2.78/2.89 bpm; CTP = 3350 /3700 psi Vp = 289 bbl ROP=50-86 fph Sand w/ API of 40 to 45 units 01 :55 - 02:45 0.83 DRILL P PROD1 Wiper trip after 150 ft drilled 02:45 - 02:55 0.17 DRILL P PROD1 Drilling at 165R TF Qp = 2.78/2.89 bpm; CTP = 3350/3700 psi Vp = 286 bbl ROP=50-70 fpf 02:55 - 03:45 0.83 DRILL P PROD1 Pump up survey, orient 1 click. Angle = 88 deg, orient TF to 110R 03:45 - 04:45 1.00 DRILL P PROD1 Drilling at 11 OR 168R TF Qp = 2.70/2.78 bpm; CTP = 3450/3780 psi Vp = 285 bbl ROP=30-120 fpf With these LS TF its still not dropping angle. Need to be at 8947 ft TVD 04:45 - 05:05 0.33 DRILL P PROD1 Projected angle at 84.5 deg, Orient TF around to 105R 05:05 - 06:10 1.08 DRILL P PROD1 Drilling at 95 to 1 04R TF Qp = 2.77/2.88 bpm; CTP = 3450/3880 psi Vp = 289 bbl ROP= 50 to 120 fph. WOB @ 2500 to 3500 Ibf Printed: 11/1/2004 1 :51 :57 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-17 E-17 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 1 0/23/2004 1 0/31/2004 N1 Spud Date: 9/7/1981 End: 10/31/2004 10/27/2004 05:05 - 06:10 1.08 DRILL P PROD1 At 11,800 ft hole angle at 84.93 deg 06: 10 - 06:40 0.50 DRILL P PROD1 Orient TF 1 OR. 06:40 - 07:15 0.58 DRILL P PROD1 Drilling at 10R TF Qp = 2.6/2.7 bpm; CTP = 3250 /3500 psi Vp = 281 bbl (computer failed and reset) ROP= 50 to 120 fph. WOB @ 2500 to 3500 Ibf At 11,885 ft hole angle at 86.70 deg 07:15 - 07:20 0.08 DRILL P PROD1 Orient TF 100R 07:20 - 07:30 0.17 DRILL P PROD1 Drilling at 100R TF Qp = 2.6/2.7 bpm; CTP = 3250/3600 psi Vp = 279 bbl ROP= 50 to 120 fph. WOB @ 3000 to 9000 Ibf At 11,900 ft hole angle at 86.70 deg 07:30 - 08:45 1.25 DRILL P PROD1 Wiper trip to window. 08:45 - 09:45 1.00 DRILL P PROD1 Drilling at 100 - 115 R TF Qp = 2.6/2.7 bpm; CTP = 3400 /3700 psi Vp = 277 bbl ROP= 50 to 120 fph. WOB @ 3000 to 9000 Ibf PU 36k; SO 14k At 11940 ft hole angle at 90.57 deg 09:45 - 09:50 0.08 DRILL P PROD1 Orient TF to 80R. 09:50 - 12:15 2.42 DRILL P PROD1 Drilling at 80 -145 RTF Qp = 2.7/2.8 bpm; CTP = 3400/3700 psi Vp = 274 bbl ROP= 30 to 120 fph. WOB @ 3000 to 9000 Ibf PU 36k; SO 14k Sticky off bottom (5-7k overpull) At 12,030 ft hole angle at 89.25 deg 12:15 - 14:00 1.75 DRILL P PROD1 Wiper trip to tubing tail. - PU 36k; SO 14k - No problem going through window. 14:00 - 14:15 0.25 DRILL P PROD1 Orient TF to 90 R. 14:15 - 14:45 0.50 DRILL P PROD1 Drilling at 100 R TF Qp = 2.7/2.8 bpm; CTP = 3400/3700 psi Pulling flo pro out of the pits, prepping for mud swap. (Existing system with 600', 0.7%DS as of 09:00 hrs) ROP= 30 to 120 fph. WOB @ 3000 to 9000 Ibf PU 36k; SO 14k Sticky off bottom (1 0-12k overpull) At 12073 ft hole angle at 87.75 deg 14:45 - 16:00 1.25 DRILL N STUC PROD1 Pick up off bottom for orienting. Stuck on bottom. - PU in intervals of 20k until 84k, pumps off. - Wait 15 minutes. Did not pull free. - PU in intervals of 20k until 84k, pumps on (2.5 bpm at 3500 psi). - Bleed all pressure off. - Wait 15 minutes. - Pull/pump combinations -- 1.4 bpm at 3400 psi. - Work plan forward with Eng. . Order 100 bbls dead crude. 16:00 - 16:30 0.50 DRILL N STUC PROD1 Waiting on Crude - Continue the cycle of "Pull" and "Relax" while waiting. - Monitoring Rate vs Pressure Printed: 11/1/2004 1:51:57 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-17 E-17 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 10/23/2004 1 0/31 /2004 N1 Spud Date: 9/7/1981 End: 10/31/2004 - Wait 15 min. - Pull free at 90k. Restoration of pump pressure to 3500 psi at 2.5 bpm 16:30 - 18:00 1,50 DRILL N STUC PROD1 Wiper trip to window. - Tie in (+29 feet correction). Computer locked up on wiper trip - Tag bottom at 12.089' MD 18:00 - 19:50 1.83 DRILL P PROD1 Drilling at 90 L TF Qp = 2.45/2.52 bpm at 3200/3700 psi. Started mud swap at 18:35 hrs at 12,118 ft Drilling in shale, lots of stacking and stalls New mud helped WOB to be constant IAJOA = 600/394 psi Mud swap completed. Density 0.2ppg less. CTP lower 19:50 - 20:35 0.75 DRILL P PROD1 Drilling at 70-80 L TF Qp = 2.76/2.70 bpm at 3380/3450 psi. ROP 140 fph in sand and 50 fph in shale Building hole angle at 12,225 ft 91.86 deg 20:35 - 21 :45 1.17 DRILL P PROD1 Wiper trip to window. 21 :45 - 22:00 0,25 DRILL P PROD1 Orient TF to LS to drop some hole angle 22:00 - 22:25 0.42 DRILL P PROD1 Drilling at 174R TF Qp = 2.76/2.70 bpm at 3280/3650 psi. Drilled from 12,225 ft to 12,255 ft at LS TF 22:25 - 22:30 0.08 DRILL P PROD1 Orient TF around to 111 L 22:30 - 00:00 1.50 DRILL P PROD1 Drilling at 116R to 95 TF Qp = 2.62/2.70 bpm at 3280/3650 psi. Need 16 deg to come around inside the polygon and only getting 11 deg turns Vp = 295 bbl; IAJOA = 439/355 psi 10/28/2004 00:00 - 00:15 0.25 DRILL P PROD1 Drilling at 116R to 95 TF Qp = 2.62/2.70 bpm at 3280/3650 psi. Need 17 deg to come around inside the polygon and only getting 11 deg turns. Having to fight TVD, lossing turn ability with 1.06 deg motor. 00:15 - 03:00 2.75 DRILL P PROD1 POOH to change motor bend. Pulled tight at 12,127 ft Area is where we turned from R to L TF. Backed reamed slowly at 45R TF from 12,127 ft to 12,050 ft. POOH 03:00 - 04:30 1.50 DRILL P PROD1 OOH, change bend setting to 1.37 deg, bit good, download Res Tool 04:30 - 08:00 3.50 DRILL P PROD1 RIH, pumping minimum rate, - PU 34 k; SO 15k at window. - Tie in. Correct -24.5 feet. - Orient at 12,137' to 90 L. 08:00 - 08:30 0.50 DRILL P PROD1 Backream shale at 12,120 - 12,145' 08:30 - 09:00 0.50 DRILL P PROD1 Continue RIH to bottom at 12,337' MD 09:00 - 09:15 0.25 DRILL P PROD1 Orient to 90L. 09:15 - 10:15 1.00 DRILL P PROD1 Drill at 90L TF to 12,418' MD. Qp = 2.5/2.6 bpm; CTP = 3150 /3600 psi Vp = 277 bbl ROP=50-100 fph 10:15 - 10:35 0.33 DRILL P PROD1 Orient TF to 100L. 10:35 - 12:30 1.92 DRILL P PROD1 Drill at 100 L TF to 12,489' MD. Printed: 11/1/2004 1:51:57 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-17 E-17 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 10/23/2004 1 0/31/2004 N1 Spud Date: 9/7/1981 End: 10/31/2004 10/28/2004 10:35 - 12:30 1.92 DRILL P PROD1 Qp = 2.5/2.6 bpm; CTP = 3150 /3600 psi ROP=50-100 fph 12:30 - 14:30 2.00 DRILL P PROD1 Wiper trip to window. - Some "bobbles" but no reaming required on TOOH - Tie in. Correct +9.5' - OH clean. 14:30 - 16:15 1.75 DRILL 'p PROD1 Drill at 100 L TF to 12587' MD Qp = 2.7/2.7 bpm; CTP = 3400 /3800 psi Vp = 261 bbl ROP=50-100 fph Sticky off bottom (10-12k overpull) 16:15 - 16:35 0.33 DRILL P PROD1 Orient TF to 90L. 16:35 - 18:00 1.42 DRILL P PROD1 Drill at 90 L TF to 12,645' MD Qp = 2.8/2.8 bpm; CTP = 3400 / 3900 psi Vp = 254 bbl ROP=50-100 fph 18:00 - 18:45 0.75 DRILL P PROD1 Wiper trip to WS. - Sticky at 12,200' - 12,160' MD; 12,115' MD, 18:45 - 19:05 0.33 DRILL P PROD1 Tie-in at RA Marker. (Corrected +6.5 ft) 19:05 - 20:00 0.92 DRILL P PROD1 RIH, clean OH 20:00 - 20:35 0.58 DRILL P PROD1 Drilling w/91 L TF Qp = 2.75/2.85 bpm CTP 3500/3800 psi Vp = 244 bbl IAlOA = 767/530 psi ROP = 50 fph drilling in shale 20:35 - 20:45 0.17 DRILL P PROD1 Pumped 30 bblliner pill while POOH. Pulled little tight at 12,200 ft. Unable to go down due to TF orientation. Lost liner pill 20:45 - 21:10 0.42 DRILL P PROD1 Orient TF 90R to 90L as drilled RIH and WR to bottom Tagged at 12,673 ft 21:10 - 22:00 0.83 DRILL P PROD1 PUH to conduct wiper trip and check hole integrity Pulled a little tight at 12,208 ft 12,111 ft and 11,853 ft Clean above 11,853 ft 22:00 - 22:30 0.50 DRILL P PROD1 RIH to 11,850 ft. and setup to MAD Pass the Res area between 11,800 ft to 11,400 ft 22:30 - 23:40 1.17 DRILL P PROD1 MAD Pass up from 11,850 ft to 11,400 ft Area 11,700 ft repeated the resisitivity deep signal Area at 11,500 ft didn't repeat on recorded data 23:40 - 00:00 0.33 DRILL P PROD1 RIH. Wt bobble at 12,115 ft 12,604 ft 10/29/2004 00:00 - 00:20 0.33 DRILL P PROD1 RIH and tagged at 12,673 ft. 00:20 - 00:30 0.17 DRILL P PROD1 Circulated liner pill down CT and work same. 00:30 - 01 :35 1.08 DRILL P PROD1 PUH laying in liner pill. Open hole OK. 01 :35 - 03:30 1.92 DRILL P PROD1 POOH, Painted flag @ 8100 ft, EOP. 03:30 - 05:30 2.00 DRILL P PROD1 OOH, LD bit, and motor, download Res tool and bring in Liner equipment. LD BHA. 05:30 - 06:00 0.50 CASE P RUNPRD RU to run liner. Ran BOT Shoe, 1 jt 2-7/8" FC and LC. Crew change 06:00 - 10:15 4.25 CASE P RUNPRD RIH with liner. - FS, Jt, FC, LC, 41 its 2-7/8", LSL XO, 18 its 3-3/16" wlcent, 26 its 3-3/16" w/o cent, XO, 1 jt 3-1/2", X nipple, 2 ea 10' pup, Dep sleeve w/pup. - Fill liner at 2-7/8" XO. 10:15-11:00 0.75 CASE P RUNPRD MU dart catcher. Pump dart, hit at 56.5 bbls. LD dart catcher. 11 :00 - 11 :30 0.50 CASE P RUNPRD MU coil connector (cut 8'). Printed: 11/1/2004 1:51:57 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-17 E-17 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 1 0/23/2004 10/31/2004 N1 Spud Date: 9/7/1981 End: 10/31/2004 10/29/2004 11 :00 - 11 :30 0.50 CASE P RUNPRD - Pull test to 3500 Ibs. - Pressure test to 3500 psi 11 :30 - 13:00 1.50 CASE P RUNPRD RIH with liner to window at 100 fpm, pumping minimal rate at 0.2 bpm. - Correct depth at flag to 10,910' MD. - PU 41k; SO 18k 13:00 - 13:30 0.50 CASE P RUNPRD Run in to open hole. - Slick to bottom. - Tag at 12,675' MD. - PU to 47k (12,646' MD) to confirm TD. - Land at 12,673' MD. 13:30 - 14:30 1.00 CASE P RUNPRD PU CT to drop ball. Drop 5/8" steel ball. Circulate ball at 1350 psi at 0.2 bpm prior to seat. Ball on seat with 48 bbls away. Shear at 4100 psi. Confirm release. 14:30 - 17:30 3.00 CEMT P RUNPRD Circulate well to 2% double slick KCI. - No losses to formation. - Mix bio pill. - Spot cementers. 17:30 - 18:00 0.50 CEMT P RUNPRD PJSM Batch cement at 15.8 ppg. 18:00-19:15 1.25 CEMT P RUNPRD Pumped 1.5 bbl water, PT lines to 4000 psi, OK Pumped 28 bbl Class G 15.8ppg Cement. MM showed 15.8 ppg SD, vac lines, dropped dart, Pressured up to 200 psi, launch dart Pumped 30 bbl Bio water, Landed dart at 58.1 bbl. Sheared at 3000 psi Pumped 18.1 bbl and LWP landed in LC at 1000 psi. 100% returns throughout job. SD. Circulated 28 bbl cement up annulus. Estimated TOC @ 10440 ft. Released pressure, floats held. Pressured up to 200 psi, unstung from deployment sleeve. Cir 2 bbl at TOL. 19:15 - 21 :45 2.50 CEMT P RUNPRD POOH replacing CT displacement. 21 :45 - 23:00 1.25 EVAL P LOWER1 LD BOT CTLRT and load out. PU 2-1/8" Motor and 2.3" mill, 1 std 1-1/4" CSH 23:00·23:15 0.25 EVAL P LOWER1 PJSM on handling Radioactive Neutron Source 23: 15 . 00:00 0.75 EVAL P LOWER1 Load RA source, RIH with 1-114" CSH 10/30/2004 00:00 . 00:45 0.75 EVAL P LOWER1 RIH with 1-1/4" CSH. 00:45 . 01 :05 0.33 EV AL P LOWER1 Make up upper MHA and stab injector. 01:05·02:10 1.08 EVAL P LOWER1 RIH with MCNL GR Tool 02:10 - 03:15 1.08 EVAL P LOWER1 Stopped at 9000 ft and work CT while WOC to reach 500 psi compressive strength at DS lab. Cement at 500 psi at 0300 hrs 03:15 - 03:25 0.17 EVAL P LOWER1 RIH to 9700 ft to start logging 03:25 - 05:10 1.75 EVAL P LOWER1 RIH logging at 30 fpm from 9700 ft Op = 1.5 bpm, CTP = 2000 psi. Tagged at 12,649 ft (-18 ft = 12,631 ft 05:10 - 05:20 0.17 EVAL P LOWER1 PUH logging at 60 fpm Op = 0.5 bpm laying in perf pill 05:20 - 06:10 0.83 EVAL P LOWER1 SLB failure to recording data, Stopped logging, RIH and started another perf pill down CT. Cir Perf pill # 2 down CT Printed: 11/1/2004 1:51:57 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-17 E-17 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 1 0/23/2004 1 0/31 /2004 N1 Spud Date: 9/7/1981 End: 10/31/2004 10/30/2004 06:10 - 07:00 07:00 - 08:15 08:15 - 10:00 10:00 - 11 :00 11 :00 - 11:45 11 :45 - 13:45 13:45 - 14:30 14:30 - 16:00 16:00 - 17:00 17:00 - 18:45 18:45 - 19:20 19:20 - 21 :30 21 :30 - 22:30 0.83 EV AL P 1.25 EVAL P LOWER1 I' PUH logging at 60 fpm, laying in perf pill LOWER1 POOH at 100 fpm, 0.85 bpm, 630 psi. Rig down injector. LOWER1 Rack back cleanouVlogging BHA. - Drop 5/8" ball to circ sub. - 45 stnds CSH 1.75 EVAL P 1.00 EVAL P 0.75 CEMT P Off Critical Path: Place painted sills next to rig for vac truck "no-go". LOWER1 PJSM -- LD source. RUNPRD Pressure test liner lap to 2000 psi for 30 min. Compressive strength at 2000 psi at 09:42 am. Time Psi Delta 0 2128 5 2106 22 10 2098 8 15 2090 8 20 2080 10 25 2073 7 30 2065 8 Total pressure loss 63 psi, 3% decline. 2.00 PERFO P Off Critical Path: - Begin loading pipe shed. - Download logging data -- good. LOWER1 Continue loading perf guns into shed. Take on liner pill. FINAL PICKS: - TOL at 9,876' ELM. - PBTD at 12,637' ELM. LOWER1 PJSM - Identified gap in Perforating strategy. - Discussed plan forward with Anchorage. - Will run guns in two runs to eliminate use of HDF firing head LOWER1 Pick up 32 perf guns LOWER1 RIH with 35 stands of CSH. LOWER1 RIH with perf guns/CSH on coil tubing. Max pressure set at 400 psi as per SLB perforator. Tagged bottom at 12,652 ft, PU string wt, corrected to 12,637 ft (-15ft) LOWER1 Pumped 5 bbl perf pill, dropped ball, launched with 10 bbl perf pill. Circulate ball down. LOWER1 Perf at 3360 psi Run #1as follows: 11,860 ft to 11,895 ft - 35 ft - 6 spf 12,045 ft to 12,110 ft - 65 ft - 6 spf 12,150 ft to 12,300 ft - 150 ft - 6 spf 12,390 ft to 12,480 ft - 90 ft - 6 spf 12,515 ft to 12,530 ft - 15 ft - 6 spf POOH keeping 300 psi WHP Check flow at 9700 ft, OK LOWER1 OOH, checked flow, OK 0.75 PERFO P 1.50 PERFO 1.00 PERFO 1.75 PERFO 0.58 PERFO 2.17 PERFO 1.00 PERFO P Printed: 11/1/2004 1 :51 :57 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 21 :30 - 22:30 22:30 - 22:45 22:45 - 00:00 10/31/2004 00:00-01:30 01 :30 - 03:30 03:30 - 04:45 04:45 - 05:20 05:20 - 07:00 07:00 - 07:30 07:30 - 09:00 09:00 - 11 :00 11 :00 - 12:00 12:00 - 13:30 13:30 - 16:00 E-17 E-17 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 10/23/2004 10/31/2004 N1 Spud Date: 9/7/1981 End: 10/31/2004 1.25 Stand CSH in derrick PJSM on handling perf guns RU and POH LD perf guns LD Perf Run #1 All shots fired Daylite Saving Time at 0200 hrs. "Great". RU to PU Perf Run #2 (19 guns) PU / RIH Perf BHA #2 LOWER1 RIH with Perf BHA #2 Corrected -15 ft at 11,610 ft LOWER1 Pumped 5 bbl Perf Pill, launched 5/8" ball and foil wed with 8 bbl Perf Pill Perforated as followed using 55 bbl and 3380 psi: 11 ,220 ft to 11 ,265 ft - 45 ft - 6spf 111,350 ft to 11,410 ft - 60 ft - 6spf 11,530 ft to 11,595 ft - 65 ft - 6spf Flow check at 9700 ft, OK LOWER1 POOH and trapping 200-300 psi on annulus LOWER1 Flow check. LOWER1 Stand back injector. RU tools to pull CSH. POOH with 40 stands CSH. LOWER1 PJSM Well control Drill Lay down 19 guns. LOWER1 Rig down tools. 0.58 1.67 0.50 1.50 1.50 WHSUR P Off Critical Path: - Unload pipe shed. - Back trucks in for fluid transfer. MU nozzle. RIH to 2200' MD. POOH, pump 25 bbls MEOH. RD nozzle. POST 2.50 F~IGD P (Master closed) Clean pits. Nipple down BOPE. Move rig equipment. Rig down tiger tank hardline and berm. NU and test tree cap. POST RIG RELEASE: 16:00 hrs 10/31/04 Printed: 11/1/2004 1:51:57 PM . . 14-Nov-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well E-17 A Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 10,900.00' MD 10,907.00' MD 12,673.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date l ~--IJ 'P(I~ Signed 1~ Ûj¡J Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) TIVE I DEFt Halliburton Sperry-Sun North Slope Alaska BPXA E-17A . Job No. AKMW3353779, Surveyed: 28 October, 2004 Survey Report 2004 9 November, Your Ref: API 500292047001 Surface Coordinates: 5975311.99 N, 664484.86 E (70020'19.8690. N, 211020' 05.1344" Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Survey Ref: svy4438 E) 60.30ft above Mean Sea Level SI:1Bf'""f'""'J-SUi'" DRILLING SeR.VIc:.es A Halliburton Company Kelly Bushing Elevation: Halliburton Sperry-Sun Survey Report for E-17A Your Ref: API 500292047001 Job No. AKMW3353779, Surveyed: 28 October, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10900.00 43.470 129.700 8793.93 8854.23 1760,96 S 5261.60 E 5973666.87 N 669783.82 E -3748.80 Tie On Point MWD Magnetic 10907.00 43.480 129.700 8799.01 8859.31 1764.04 S 5265.31 E 5973663.88 N 669787.60 E 0.143 -3753.12 Window Point 10940.41 47.300 146.520 8822.55 8882.85 1781.69 S 5280.99 E 5973646.57 N 669803.66 E 37.534 -3775,63 10994.42 55.250 165.310 8856.50 8916.80 1819.98 S 5297.68 E 5973608.66 N 669821.19 E 30.778 -3817.39 11027.62 58.410 175.160 8874.69 8934.99 1847.31 S 5302.34 E 5973581.43 N 669826.45 E 26.580 -3844.26 . 11052.38 57.220 182.060 8887.89 8948.19 1868.24 S 5302.85 E 5973560.52 N 669827.42 E 24.065 -3863.59 11095.64 62.930 192,210 8909.51 8969.81 1905.34 S 5298.11 E 5973523.32 N 669823.50 E 24.223 -3895.56 11130.89 68.720 207.610 8924.01 8984.31 1935.41 S 5287.12E 5973493.02 N 669813.16 E 43.064 -3918.55 11171.51 70.840 218.710 8938.08 8998.38 1967.24 S 5266.29 E 5973460.74 N 669793.04 E 26.161 -3939.16 11203.70 76.560 227.870 8947.13 9007.43 1989.67 S 5245.11 E 5973437.85 N 669772.36 E 32.570 -3951.04 11237.10 81.230 238.800 8953.58 9013.88 2009.19 S 5218.86 E 5973417.77 N 669746.54 E 35.013 -3958.18 11274.02 85.990 253.950 8957.72 9018.02 2023.82 S 5185.34 E 5973402.40 N 669713.35 E 42.756 -3957,92 11305.05 89.600 264.170 8958.91 9019.21 2029.69 S 5154.95 E 5973395.87 N 669683.09 E 34.902 -3950.92 11345.36 94.710 281.620 8957.39 9017.69 2027.68 S 5114.88 E 5973397.00 N 669642.99 E 45.064 -3932.79 11380.77 92.600 297.650 8955.11 9015.41 2015.84 S 5081.71 E 5973408.11 N 669609.57 E 45.566 -3908.48 11416.86 91.980 305.760 8953.67 9013.97 1996.90 S 5051.06 E 5973426.37 N 669578.51 E 22.519 -3878.71 11448,12 90.040 311.750 8953.12 9013.42 1977.34 S 5026.70 E 5973445.39 N 669553.73 E 20.138 -3850.94 11477.27 90.480 316.510 8952.98 9013.28 1957.05 S 5005.78 E 5973465.21 N 669532.37 E 16.399 -3823.89 11505.20 91.190 320.560 8952.58 9012.88 1936.13 S 4987.30 E 5973485.73 N 669513.43 E 14.720 -3797.26 11534.16 91.370 324.610 8951.93 9012.23 1913.14 S 4969.71 E 5973508.33 N 669495.34 E 13.995 -3769.10 11580.59 94.890 332.900 8949.39 9009.69 1873.55 S 4945.68 E 5973547.38 N 669470.45 E 19.371 -3723.16 11607.62 96.650 337.830 8946.67 9006.97 1849.11 S 4934.47 E 5973571.57 N 669458.71 E 19.279 -3696.28 . 11637.85 96.560 343.290 8943.19 9003.49 1820.81 S 4924.48 E 5973599.65 N 669448.10 E 17.944 -3666.36 11666.74 94.710 346.460 8940.36 9000.66 1793.06 S 4916.98 E 5973627.23 N 669439.99 E 12.658 -3637.95 11705.64 92.690 349.640 8937.84 8998.14 1755.08 S 4908.95 E 5973665.01 N 669431 .13 E 9.670 -3600.00 11746.37 88.460 355.980 8937.44 8997.74 1714.71 S 4903.86 E 5973705.27 N 669425.15 E 18.709 -3561.04 11780,66 86.520 356.330 8938.94 8999.24 1680.53 S 4901.56 E 5973739.39 N 669422.10 E 5.749 -3528.88 11811.70 84.670 0.910 8941.32 9001.62 1649.60 S 4900.81 E 5973770.29 N 669420.68 E 15.872 -3500.32 11843.15 85.370 6.020 8944.05 9004.35 1618.33 S 4902,70 E 5973801.59 N 669421.89 E 16.339 -3472.53 11879.29 90.480 8.490 8945.36 9005.66 1582.52 S 4907.27 E 5973837.49 N 669425.66 E 15.702 -3441.67 11911.68 91.190 12.190 8944.89 9005.19 1550.67 S 4913.08 E 5973869.47 N 669430.77 E 11.630 -3414.93 11946.28 88.630 15.190 8944.94 9005.24 1517.06 S 4921.26 E 5973903.25 N 669438.22 E 11 .398 -3387.56 11978.33 89.520 22.240 8945.46 9005.76 1486.73 S 4931.54 E 5973933.80 N 669447.83 E 22.168 -3364.03 12010.75 89.430 28.230 8945.76 9006.06 1457.41 S 4945.35 E 5973963.41 N 669461.00 E 18.478 -3342.87 12042.12 87.670 34,220 8946.55 9006,85 1430.61 S 4961.60 E 5973990.56 N 669476.65 E 19.895 -3324.99 9 November, 2004 - 15:18 Page 2 of4 Dril/Quest 3.03.06.006 Halliburton Sperry-Sun Survey Report for E-17A Your Ref: API 500292047001 Job No. AKMW3353779, Surveyed: 28 October, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 12074.90 88.020 38.090 8947.79 9008.09 1404.17 S 4980.93 E 5974017.42 N 669495.39 E 11.846 -3308.69 12107.29 88.630 36.510 8948,73 9009.03 1378.41 S 5000.54 E 5974043.60 N 669514.44 E 5.227 -3293.15 12141.85 88.810 33.160 8949.51 9009.81 1350.06 S 5020.28 E 5974072.38 N 669533.54 E 9.705 -3275.27 12182.57 91.540 28.050 8949.38 9009.68 1315.02 S 5041.00 E 5974107.86 N 669553.49 E 14.227 -3251.69 12211.77 92.860 20.120 8948.26 9008.56 1288.41 S 5052.90 E 5974134.73 N 669564.81 E 27.511 -3232.22 12247.13 91.370 18.890 8946.95 9007.25 1255.10 S 5064.70 E 5974168.29 N 669575.87 E 5.463 -3206.59 . 12275.69 89.960 15.540 8946,62 9006.92 1227.83 S 5073.15 E 5974195.74 N 669583.72 E 12.725 -3185.11 12307.86 89.250 11.840 8946.84 9007.14 1196.58 S 5080.76 E 5974227.15 N 669590.64 E 11.711 -3159.66 12353.36 87.490 6.380 8948.14 9008.44 1151.69 S 5087.96 E 5974272.19 N 669596.86 E 12.603 -3121.58 12378.39 88.110 1 .440 8949.10 9009.40 1126.74 S 5089.66 E 5974297.16 N 669598.01 E 19.877 -3099.48 12410.96 90.220 356.860 8949.58 9009.88 1094.19 S 5089.18 E 5974329.70 N 669596.82 E 15.480 -3069.55 12450.87 89.520 350.170 8949,67 9009.97 1054.56 S 5084.67 E 5974369.22 N 669591.44 E 16.854 -3031.51 12490.43 89.600 345.230 8949.97 9010.27 1015.92S 5076.25 E 5974407.67 N 669582.17 E 12.489 -2992.79 12526.96 89.780 339.420 8950.17 9010.47 981.13 S 5065.16 E 5974442.21 N 669570.33 E 15.912 -2956.50 12558,83 89.600 335.010 8950.34 9010.64 951.76 S 5052.82 E 5974471.30 N 669557.35 E 13.849 -2924.64 12597.07 89.160 328.840 8950.76 9011.06 918.03 S 5034.84 E 5974504.62 N 669538.62 E 16.175 -2886.52 12625.12 89.340 324.090 8951.12 9011.42 894.66 S 5019.35 E 5974527.65 N 669522.62 E 16.945 -2858.87 12650.26 89.070 319.860 8951.47 9011.77 874.86 S 5003.87 E 5974547.10 N 669506.71 E 16.858 -2834.48 12673.00 89.070 319.860 8951.84 9012.14 857.48 S 4989.21 E 5974564.16 N 669491.68 E 0.000 -2812.64 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). . Vertical Section is from Well Reference and calculated along an Azimuth of 336.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12673.00ft., The Bottom Hole Displacement is 5062.36ft., in the Direction of 99.752° (True). 9 November, 2004 - 15:18 Page 3 of 4 Dri/lQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for E-17 A Your Ref: API 500292047001 Job No. AKMW3353779, Surveyed: 28 October, 2004 North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10900.00 10907.00 12673.00 8854.23 8859.31 9012.14 1760.96 S 1764.04 S 857.48 S 5261.60 E 5265.31 E 4989.21 E Tie On Point Window Point Projected Survey . Survey tool program for E-17A Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 10900.00 0.00 10900.00 8854.23 12673.00 8854.23 BP High Accuracy Gyro - Boss Gyro (E-17) 9012.14 MWD Magnetic (E-17A) . 9 November, 2004 - 15:18 Page 4 of 4 DrillQuest 3.03.06.006 Minimum ID == 4-1/2" OTIS XN REF LOG: BHCS ON09/.21/S1 ANGLE AT TOP PERF: 43 @ 10841' 1 Note: SIZE 3-3/S" 3-3/8" 3-3/8" 3-3/8" 3-3/8" 3-3/8" 3-3/8" 3-3/8" SPF 6 4 4 4 4 6 6 6 10841 10844 10940 - 10961 10979·11016 11030 11065 11065 -111.20 11120 -11145 11150 -11158 11168 11178 . ~u~1TŒ (ill fÆ . AI¡ASIL\. OILAlWD GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Scott Kolstad CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay E-17A BP Exploration (Alaska) Inc. Permit No: 204-204 Surface Location: 1753' SNL, 501' WEL, SEC. 06, T11N, R14E, UM Bottomhole Location: 2653' SNL, 4404' EWL, SEC, 05, T11N, R14E, UM Dear Mr. Kolstad: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 9 7 (pager). . ce el BY ORDER OF THE COMMISSION DATED this.i.('day of October, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. · STATE OF ALASKA . ALASKA M AND GAS CONSERVATION COM!flSSION PERMIT TO DRILL 20 AAC 25.005 RECEIVED OCT 1 B 2004 o Drill II Redrill 1a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1753' SNL, 501' WEL, SEC. 06, T11N, R14E, UM Top of Productive Horizon: 3369' SNL, 4579' EWL, SEC. 05, T11 N, R14E, UM Total Depth: 2653' SNL, 4404' EWL, SEC. 05, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 664485 y- 5975311 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 10910 feet Maximum Hole Angle: 93 dearees 11b. Current Well ClaÖ Stratigraphic Test 8 ~~~?~tory ~ g:~~~~~~~r ¡!:;,~~~~~ftlmiss an 5. Bond: 181 Blanket 0 Single Well 11. Well Name an I/UmDe/ Bond No. 2S100302630-277 PBU E-17A 6. Proposed Depth: 12. Field I Pool(s): MD 12655 TVD 8954ss Prudhoe Bay Field I Prudhoe Bay 7. Property Designation: Pool ADL 028304 8. Land Use Permit: 13. Approximate Spud Date: October 19, 2004 / 14. Distance to Nearest Property: 15,585' 9. Acres in Property: 2560 4-1/8" x 3·3/4" 3·3116" x 2-7/8" Weiaht 6.2# I 6.5# " Grade L-80 .'....n.....tIo. ';:IfT CouplinQ Le ~ ¡¡, !.MO ; T~ MD TCIII ST /lllA .~ 12655' 1 '5" !880 \J.J .. 10. KB Elevation 15. Distance to Nearest Well Within Pool V (Height above GL): 60.3' feet K-12A is 358' away at 12597' MD 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Downhole: 3300 Surface: 2244 / W ~--, TVD (includinQ staae data) 8954' 140 cu ft Class 'G' r 118. caSing_ 'v,.' ... SI7A Hole Casina 119. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): 11295 I"'~ð;""" ~+r' 'M' 'r~1 r.nnnllr.tnr .... ,~ Total Depth TVD (ft):~IU9S (measured): I Effective Depth MD (ft): Effective Depth TVD (ft): 9139 None 11253 9109 I _" ' I - - I " - ,'", "" MIJ ." Junk (measured): None TVD , ,. 110' 20" x 30" 8 cu yds Concrete 110' 110' 2715' 13-3/8" 3720 cu ft Arcticset II 2715' 2669' 10373 9-5/8" 1500 cu ft Class 'G', 130 cu ft Arcticset I 10373' 8465' 1405' 7" 1480 cu ft Class 'G' 9890' - 11295' 8081' - 9139" I I Production I inAr Perforation Depth MD (ft): 10841' -11178' 20. Attachments 181 Filing Fee, $100 181 BOP Sketch o Property Plat 0 Diverter Sketch /perfOration Depth TVD (ft): 8811' - 9055' 181 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report IS Drilling Fluid Program 18120 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Scott Kolstad, 564-5347 Printed Name Scott Kolstad tî .... Title CT Drilling Engineer 'J ~ '" L \ I.A . i Prepared By Name/Number: SiQnature .If/' -- O.;¡u tv¡- f&r- 5f:.. Phone 564-5347 Date /tJi1/oL/- Terrie Hubble, 564-4628 1/......" .".,. ,....,......... ','/ ./.1 .."..sT)"...'...,.¡..",i...'....,....; .,;,.;;,...........;...;).. '.!ii~,'1· """';'.',. 'ii' ,,""".';. Permit To Drill ;;CPI Number: v Permit Approval See cover letter for Number: .2ot?-' - 20Q 50- 029-20470-01-00 Date: /0//5/0 '/- other requirements Conditions of Approval: Samples Required 0 Yes $No Mud Log Required 0 Yes JRNo ~úHYdr Sulfide Measures ~es 0 No Directional Survey Required ~Yes 0 No Other' AODroved (Ji CI n [) I ¡!~, f ,¡ ! A. ~~~~~~~I~~ION Date ¡r> j,ó) oC; (.. V Form 10-401 ~sed ~ \.. ~ ¡:¡~ i,.,,!; \'l'1 L st.bmit ~ Duplicate . . BP E-17 A CTD Sidetrack Phase 1 Operations: Prep Work: · Integrity pressure test OA, IA &tbg, wellhead seals & Xmas tree valves. · Drift tubing. · Set thru-tubing whipstock. · Squeeze cement past whipstock to P&A existing perforations. Phase 2 Operations: MIRU Nordic 1 CTD RiQ. Mill window. Drill and Complete sidetrack. Mud Program: · Phase 1: Seawater/1 % KCI .,./ · Phase 2: Mill with 1 % KCI / biozan, drill with Solids Free Flo-Pro (8.5 - 8.6 ppg) Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. ~) \d6k Casing Program: q .q~ . 33h6TCII x2Ys" STL fro , ,j,,,a-, 2'ss) to 12,655'MD (-8,954'ss). . The liner will be cement . ~-25b of 15.8 ppg class G cement with a planned TOC at~ Parent Well Casin s 133/8" 72# L-BO 9%" 47#, L-80 7" 29#, L-80 liner Sidetrack Casin s 3-3/16" 6.2#, L-80, TCII- Prod LNR 2Ys" 6.5#, L-BO, STL - Prod LNR Hole Size Burst si 5380 6B70 8160 4.125 3.75 8520 10570 7660 11160 ,/ Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. / · The annular preventer will be tested to 250 psi and 2500 psi. Directional · Distance to near property line, 15,585'. · Distance to nearest well within pool: E-17A is 358' from K-12A at 12,597'. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · See attached directional plan. Logging · MWD Gamma Ray and Resistivity will be run in the open hole section. · Memory CNL will be run inside the liner. Hazards · H2S information: o Closest Surface location measured recently: E24B, 10 ppm. o Closest bottom hole location: K-16A, 10 ppm. o Max H2S measured E Pad: E-12,~ppm. · The risk of a lost circulation event is considered moderate, one small fault will be crossed. Reservoir Pressure · Res. press. is estimated to be 3300 psi at 8800'ss (7.21 ppg emw). · Max. surface pressure with gas (0.12 psi/ft) to surface is 2244 psi. .../ TREE = , WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum lVD = 6-3/8 erN FMC OTIS 60.29' 31.39' 2000' 48 @ 7700' 10908' 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I 2715' Minimum ID = 3.725" @9917' 4-1/2" OTIS XN NIPPLE I TOP OF 7" LNR I . E-17 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" I 9954' 9-5/8" CSG, 47#, L-80, ID = 8.681" I PERFORATION SUMMARY REF LOG: BHes ON 09/21/81 ANGLE AT TOP PERF: 43 @ 10841' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10841 - 10844 0 01/22/01 3-3/8" 4 10940 - 10961 S 07/09/87 3-3/8" 4 10979 - 11016 S 07/09/87 3-3/8" 4 11030 - 11065 S 07109/87 3-3/8" 4 11065 - 11120 0 07/23/87 3-3/8" 6 11120 - 11145 0 03/31/93 3-3/8" 6 11150 - 11158 0 03/31/93 3-3/8" 6 11168 - 11178 0 03/31/93 I PBTDI 7" TBG, 29#, L-80, 0.0383 bpf, ID = 6.182" I DATE 09/24/81 04/27/01 09/17/03 REV BY COMMENTS ORIGINAL COM PLETION RN/TP CORRECTIONS CMOITLP PERF ANGLE & LOCATION 11253' 11295' DATE REV BY . NOTES: 2028' -14-1/2" CAMCO SSSV LANDING NIP, ID = 3.813" I GAS LIFT MANDRELS ST MD lVD DV TYÆ VLV LATCH PORT DATE 7 3103 2931 35 CA-MMG RK 6 5625 4839 40 CA-MMG RK 5 7049 5913 45 CA-MMG RK 4 8006 6568 46 CA-MMG RK 3 8682 7051 42 CA-MMG RK 2 9199 7450 36 CA-MMG RK 1 9711 7874 35 CA-MMG RK I I 9740' -14-1/2" BKR L SLIDING SLV, ID = 4.313" 9796' -1 TUBING SEAL ASSY I 9814' -19-5/8" BAKER SAB PKR, ID = 3.813" 9873' -i4-1/2" OTIS X NIP, ID = 3.813" I 9917' -i4-1/2" OTIS XN NIP, ID = 3.725" I 9954' -i4-1/2" BAKER TBG TAIL I 9950' H ELMD TT LOGGED 08/24/82 COMMENTS 10898' -iMARKERJOINT I PRUDHOE BAY UNIT WELL: E-17 PERMIT No: 1800480 API No: 50-029-20470-00 SEC6, T11N, R14E,1753'SNL&501'WEL BP Exploration (Alaska) TREE = , WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = ... ....----......... Datum MD = Datum 1VD = . 6-3/8 erN FMC OTIS 60.29' 31.39' 2000' 48 @ 7700' 10908' 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I 2715' Minimum IC = 3.725" @ 9917' 4-1/2" OTIS XN NIPPLE I TOP OF 7" LNR I 14-112" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" I 9954' 9-5/8" CSG, 47#, L-80, ID = 8.681" I ÆRFORA TION SUMMARY REF LOG: BHCS ON 09/21/81 ANGLEATTOPÆRF: 43 @ 10841' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10841 - 10844 isolated proposed 3-3/8" 4 10940 - 10961 isolated proposed 3-3/8" 4 10979 - 11016 isolated proposed 3-3/8" 4 11030 - 11065 isolated proposed 3-3/8" 4 11065 - 11120 isolated proposed 3-3/8" 6 11120 - 11145 isolated proposed 3-3/8" 6 11150 - 11158 isolated proposed 3-3/8" 6 11168 - 11178 isolated proposed I PBTDI 7" TBG, 29#. L-80, 0.0383 bpf, ID = 6.182" I DATE 09/24/81 04/27/01 09/17/03 REV BY COMMENTS ORIGINAL COMPLETION RNITP CORRECTIONS CMOITLP ÆRF ANGLE & LOCATION DATE E-17 A / NOTES: PROPOSED CTD SIDETRACK 2028' 44-112" CAMCO SSSV LANDING NIP, ID = 3.813" I . GAS LIFT MANDRELS ST MD 1VD DV TYÆ VLV LATCH PORT DATE 7 3103 2931 35 CA-MMG RK 6 5625 4839 40 CA-MMG RK 5 7049 5913 45 CA-MMG RK 4 8006 6568 46 CA-MMG RK 3 8682 7051 42 CA-MMG RK 2 9199 7450 36 CA-MMG RK 1 9711 7874 35 CA-MMG RK I I 9740' -14-112" BKR L SLIDING SLV, ID = 4.313" 9796' -1 TUBING SEAL ASSY I -19-5/8" BAKERSAB PKR,ID= 3.813" -14-112" OTIS X NIP, ID = 3.813" I -1 Top of 3~3/16" Liner I 9890' -13-1/2" X NIP ID = 2.813" 9917' 4-112" OTIS XN NIP, ID = 3.725" 9954' 4-112" BAKER TBG TAIL 9950' ELMD TT LOGGED 08/24/82 1/ I 3-3/16" X 2-7/8" Liner I IWHIPSTOCK H 10910' I I WG4"- 10898' HMARKERJOINT I REV BY COMMENTS PRUDHOE BAY UNIT WELL: &17 ÆRMIT No: "'1800480 API No: 50-029-20470-01 SEC 6, T11 N, R14E, 1753' SNL & 501' WEL BP Exploration (Alaska) Obp . . ... .... mTB.Q BP-GDB Baker Hughes INTEQ Planning Report Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: PB E Pad TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5973160.88 ft 662538.97 ft Latitude: 70 19 Longitude: 148 40 North Reference: Grid Convergence: 59.134 N 53.054 W True 1.24 deg Well: E-17 Slot Name: E-17 Well Position: +N/-S 2107.59 ft Northing: 5975311.00 ft Latitude: +E/-W 1992.31 ft Easting: 664485.00 ft Longitude: Position Uncertainty: 0.00 ft 17 70 20 19.859 N 148 39 54.862 W Wellpath: Plan#7 E-17A 500292047001 Current Datum: 30: 179/7/1981 00:00 Magnetic Data: 10/12/2004 Field Strength: 57621 nT Vertical Section: Depth From (TVD) ft 30.30 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: . +E/-W ft 0.00 E-17 10900.0Q ft Mean Sea Level 25.06 deg 80.87 deg Direction deg 336.00 Height 60.30 ft Targets E-17A Polygon7.1 0.00 -2099.68 5380.61 5973330.00 669910.00 70 19 59.190 N 148 37 17.748 W -Polygon 1 0.00 -2099.68 5380.61 5973330.00 669910.00 70 19 59.190 N 148 37 17.748 W -Polygon 2 0.00 -2272.57 5281.79 5973155.00 669815.00 70 19 57.491 N 148 37 20.637 W -Polygon 3 0.00 -2146.51 4779.40 5973270.00 669310.00 70 19 58.734 N 148 3735.304 W -Polygon 4 0.00 -1862.76 4840.64 5973555.00 669365.00 70 20 1.524 N 148 37 33.511 W -Polygon 5 0.00 -1402.18 4820.74 5974015.00 669335.00 70 20 6.054 N 148 37 34.083 W -Polygon 6 0.00 -828.27 4878.35 5974590.00 669380.00 70 20 11.698 N 148 37 32.390 W -Polygon 7 0.00 -779.37 4929.44 5974640.00 669430.00 70 20 12.178 N 148 37 30.897 W -Polygon 8 0.00 -1135.57 5206.71 5974290.00 669715.00 70 20 8.673 N 148 37 22.806 W -Polygon 9 0.00 -1847.81 5071.04 5973575.00 669595.00 70 20 1.669 N 148 37 26.782 W E-17A Fault 1 0.00 -1337.95 5312.30 5974090.00 669825.00 70 20 6.682 N 148 37 19.727 W -Polygon 1 0.00 -1337.95 5312.30 5974090.00 669825.00 70 20 6.682 N 148 37 19.727 W -Polygon 2 0.00 -1682.23 5274.74 5973745.00 669795.00 70 20 3.297 N 148 37 20.831 W -Polygon 3 0.00 -2159.73 5154.23 5973265.00 669685.00 70 19 58.601 N 148 37 24.360 W -Polygon 4 0.00 -1682.23 5274.74 5973745.00 669795.00 70 20 3.297 N 148 37 20.831 W E-17A Fault 3 0.00 -1800.69 4746.98 5973615.00 669270.00 70 20 2.135 N 148 37 36.245 W -Polygon 1 0.00 -1800.69 4746.98 5973615.00 669270.00 70 20 2.135 N 148 37 36.245 W -Polygon 2 0.00 -1598.20 4636.38 5973815.00 669155.00 70 20 4.127 N 148 37 39.470 W E-17A Fault 2 0.00 -2197.30 5498.51 5973235.00 670030.00 70 19 58.229 N 148 37 14.307 W -Polygon 1 0.00 -2197.30 5498.51 5973235.00 670030.00 70 19 58.229 N 148 37 14.307 W -Polygon 2 0.00 -1816.53 5696.92 5973620.00 670220.00 70 20 1.973 N 148 37 8.505 W -Polygon 3 0.00 -1421.97 5950.66 5974020.00 670465.00 70 20 5.851 N 148 37 1.087 W -Polygon 4 0.00 -1816.53 5696.92 5973620.00 670220.00 70 20 1.973 N 148 37 8.505 W E-17A Fault 4 0.00 -1240.13 4729.27 5974175.00 669240.00 70 20 7.648 N 148 37 36.751 W -Polygon 1 0.00 -1240.13 4729.27 5974175.00 669240.00 70 20 7.648 N 148 37 36.751 W -Polygon 2 0.00 -1120.69 4756.90 5974295.00 669265.00 70 20 8.823 N 148 37 35.942 W E-17A Fault 6 0.00 -786.39 5249.38 5974640.00 669750.00 70 20 12.107 N 148 3721.553 W . . .c Obp BP-GDB Baker Hughes INTEQ Planning Report INTKQ· -Polygon 1 0.00 -786.39 5249.38 5974640.00 669750.00 70 20 12.107 N 148 37 21.553 W -Polygon 2 0.00 -694.65 5171.37 5974730.00 669670.00 70 20 13.010 N 148 3723.830 W E-17A Fault 7 0.00 -2300.56 4505.94 5973110.00 669040.00 70 19 57.220 N 148 37 43.292 W -Polygon 1 0.00 -2300.56 4505.94 5973110.00 669040.00 70 19 57.220 N 148 37 43.292 W -Polygon 2 0.00 -2365.86 4974.65 5973055.00 669510.00 70 19 56.575 N 148 3729.607 W -Polygon 3 0.00 -2408.42 5318.82 5973020.00 669855.00 70 19 56.154 N 148 37 19.559 W E-17A Fault 5 0.00 -890.84 4766.94 5974525.00 669270.00 70 20 11.083 N 148 37 35.645 W -Polygon 1 0.00 -890.84 4766.94 5974525.00 669270.00 70 20 11.083 N 148 37 35.645 W -Polygon 2 0.00 -596.83 4588.33 5974815.00 669085.00 70 20 13.976 N 148 3740.856 W E-17A T7.2 8955.00 -1387.11 5000.13 5974034.00 669514.00 70 20 6.201 N 148 37 28.844 W E-17A T7.3 8955.00 -900.58 4891.77 5974518.00 669395.00 70 20 10.986 N 148 37 31.999 W E-17A T7.1 8960.00 -2063.40 5049.31 5973359.00 669578.00 70 19 59.549 N 148 37 27.421 W Annotation 10900.00 10910.00 10930.00 10970.00 11279.34 11379.34 11479.34 12104.34 12655.00 8793.93 8801.19 8815.48 8840.45 8959.25 8956.74 8954.23 8954.23 8954.23 TIP KOP end 9 DLS I begin 34 DLS 4 5 6 end 34 DLS I begin 12 DLS 8 TD Plan: Plan #7 Date Composed: Version: Tied-to: 10/12/2004 1 From: Definitive Path Principal: Yes Plan Section Information 10900.00 43.47 129.70 8793.93 -1760.94 5261.61 0.00 0.00 0.00 0.00 10910.00 43.48 129.70 8801.19 -1765.33 5266.90 0.10 0.10 0.00 360.00 10930.00 45.28 129.70 8815.48 -1774.27 5277.66 9.00 9.00 0.00 0.00 10970.00 57.37 137.73 8840.45 -1795.91 5300.03 34.00 30.22 20.06 30.00 11279.34 90.00 245.83 8959.25 -2023.39 5223.84 34.00 10.55 34.95 100.00 11379.34 92.79 279.73 8956.74 -2035.78 5126.12 34.00 2.79 33.90 85.00 11479.34 90.00 313.63 8954.23 -1991.53 5038.11 34.00 -2.79 33.90 94.15 12104.34 90.00 28.63 8954.23 -1417.16 4948.48 12.00 0.00 12.00 90.00 12655.00 90.00 322.55 8954.23 -898.05 4908.45 12.00 0.00 -12.00 -90.00 . . ..E: INT&Q Obp BP-GDB Baker Hughes INTEQ Planning Report 10970.00 57.37 137.73 8840.45 -1795.91 5300.03 5973631.91 669822.78 -3796.36 34.00 27.10 4 10975.00 57.09 139.72 8843.16 -1799.07 5302.81 5973628.81 669825.63 -3800.38 34.00 100.00 MWD 11000.00 56.18 149.84 8856.93 -1816.08 5314.83 5973612.06 669838.02 -3820.81 34.00 98.92 MWD 11025.00 56.11 160.08 8870.89 -1834.85 5323.60 5973593.49 669847.20 -3841.53 34.00 93.34 MWD 11050.00 56.88 170.24 8884.71 -1854.96 5328.92 5973573.50 669852.96 -3862.06 34.00 87.63 MWD 11075.00 58.45 180.13 8898.11 -1875.97 5330.67 5973552.54 669855.17 -3881.97 34.00 82.01 MWD 11100.00 60.76 189.62 8910.78 -1897.42 5328.82 5973531.06 669853.79 -3900.80 34.00 76.71 MWD 11125.00 63.70 198.63 8922.45 -1918.83 5323.41 5973509.54 669848.85 -3918.16 34.00 71.90 MWD 11150.00 67.17 207.17 8932.85 -1939.73 5314.55 5973488.44 669840.46 -3933.66 34.00 67.69 MWD 11175.00 71.08 215.25 8941.77 -1959.68 5302.45 5973468.24 669828.79 -3946.96 34.00 64.14 MWD 11200.00 75.32 222.95 8949.01 -1978.22 5287.36 5973449.37 669814.11 -3957.76 34.00 61.25 MWD 11225.00 79.80 230.35 8954.40 -1994.95 5269.61 5973432.26 669796.74 -3965.83 34.00 59.02 MWD 11250.00 84.45 237.53 8957.82 -2009.51 5249.61 5973417.27 669777.06 -3970.99 34.00 57.42 MWD 11275.00 89.18 244.61 8959.22 -2021.57 5227.78 5973404.73 669755.50 -3973.12 34.00 56.44 MWD 11279.34 90.00 245.83 8959.25 -2023.39 5223.84 5973402.83 669751.61 -3973.18 34.00 56.04 5 11300.00 90.61 252.83 8959.14 -2030.67 5204.52 5973395.12 669732.45 -3971.98 34.00 85.00 MWD 11325.00 91.34 261.30 8958.71 -2036.26 5180.18 5973389.00 669708.24 -3967.19 34.00 85.04 MWD 11350.00 92.03 269.78 8957.98 -2038.20 5155.29 5973386.51 669683.40 -3958.84 34.00 85.18 MWD 11375.00 92.69 278.26 8956.94 -2036.46 5130.40 5973387.71 669658.48 -3947.12 34.00 85.43 MWD 11379.34 92.79 279.73 8956.74 -2035.78 5126.12 5973388.30 669654.18 -3944.76 34.00 85.78 6 11400.00 92.27 286.74 8955.82 -2031.05 5106.04 5973392.58 669634.00 -3932.27 34.00 94.15 MWD 11425.00 91.58 295.22 8954.98 -2022.11 5082.73 5973401.00 669610.51 -3914.63 34.00 94.46 MWD 11450.00 90.86 303.69 8954.45 -2009.83 5060.99 5973412.80 669588.50 -3894.56 34.00 94.75 MWD 11475.00 90.13 312.16 8954.23 -1994.48 5041.28 5973427.72 669568.47 -3872.53 34.00 94.93 MWD 11479.34 90.00 313.63 8954.23 -1991.53 5038.11 5973430.60 669565.23 -3868.54 34.00 95.00 end 34 11500.00 90.00 316.11 8954.23 -1976.95 5023.46 5973444.85 669550.27 -3849.26 12.00 90.00 MWD 11525.00 90.00 319.11 8954.23 -1958.49 5006.61 5973462.94 669533.02 -3825.54 12.00 90.00 MWD 11550.00 90.00 322.11 8954.23 -1939.17 4990.75 5973481.90 669516.74 -3801.44 12.00 90.00 MWD 11575.00 90.00 325.11 8954.23 -1919.05 4975.92 5973501.69 669501.47 -3777.03 12.00 90.00 MWD 11600.00 90.00 328.11 8954.23 -1898.18 4962.16 5973522.26 669487.26 -3752.37 12.00 90.00 MWD 11625.00 90.00 331.11 8954.23 -1876.62 4949.52 5973543.54 669474.15 -3727.52 12.00 90.00 MWD 11650.00 90.00 334.11 8954.23 -1854.42 4938.02 5973565.47 669462.16 -3702.57 12,00 90.00 MWD 11675.00 90.00 337.11 8954.23 -1831.65 4927.70 5973588.00 669451.35 -3677.57 12.00 90.00 MWD 11700.00 90.00 340.11 8954.23 -1808.38 4918.58 5973611.07 669441.72 -3652.60 12.00 90.00 MWD 11725.00 90.00 343.11 8954.23 -1784.66 4910.69 5973634.61 669433.32 -3627.73 12.00 90.00 MWD 11750.00 90.00 346.11 8954.23 -1760.56 4904.06 5973658.56 669426.16 -3603.01 12.00 90.00 MWD 11775.00 90.00 349.11 8954.23 -1736.14 4898.70 5973682.85 669420.26 -3578.52 12.00 90.00 MWD 11800.00 90.00 352.11 8954.23 -1711.48 4894.62 5973707.42 669415.64 -3554.34 12.00 90.00 MWD 11825.00 90.00 355.11 8954.23 -1686.64 4891.84 5973732.19 669412.32 -3530.51 12.00 90.00 MWD 11850.00 90.00 358.11 8954.23 -1661.68 4890.36 5973757.10 669410.29 -3507.11 12.00 90.00 MWD 11875.00 90.00 1.11 8954.23 -1636.69 4890.19 5973782.09 669409.57 -3484.21 12.00 90.00 MWD 11900.00 90.00 4.11 8954.23 -1611.72 4891.33 5973807.08 669410.16 -3461.86 12.00 90.00 MWD 11925.00 90.00 7.11 8954.23 -1586.84 4893.77 5973832.00 669412.06 -3440.13 12.00 90.00 MWD 11950.00 90.00 10.11 8954.23 -1562.12 4897.51 5973856.79 669415.26 -3419.07 12.00 90.00 MWD 11975.00 90.00 13.11 8954.23 -1537.64 4902.54 5973881.38 669419.75 -3398.75 12.00 90.00 MWD 12000.00 90.00 16.11 8954.23 -1513.45 4908.85 5973905.70 669425.52 -3379.21 12.00 90.00 MWD 12025.00 90.00 19.11 8954.23 -1489.62 4916.41 5973929.68 669432.56 -3360.52 12.00 90.00 MWD 12050.00 90.00 22.11 8954.23 -1466.23 4925.21 5973953.26 669440.84 -3342.73 12.00 90.00 MWD . . ....: Obp BP-GDB Baker Hughes INTEQ Planning Report 12075.00 90.00 25.11 8954.23 -1443.32 4935.22 5973976.38 669450.35 -3325.88 12.00 90.00 MWD 12100.00 90.00 28.11 8954.23 -1420.97 4946.42 5973998.97 669461.05 -3310.01 12.00 90.00 MWD 12104.34 90.00 28.63 8954.23 -1417.16 4948.48 5974002.83 669463.03 -3307.37 12.00 90.00 8 12125.00 90.00 26.15 8954.23 -1398.81 4957.98 5974021.38 669472.13 -3294.47 12.00 270.00 MWD 12150.00 90.00 23.15 8954.23 -1376.09 4968.41 5974044.32 669482.05 -3277.96 12.00 270.00 MWD 12175.00 90.00 20.15 8954.23 -1352.86 4977.63 5974067.75 669490.76 -3260.48 12.00 270.00 MWD 12200.00 90.00 17.15 8954.23 -1329.17 4985.63 5974091.60 669498.24 -3242.10 12.00 270.00 MWD 12225.00 90.00 14.15 8954.23 -1305.10 4992.37 5974115.81 669504.45 -3222.85 12.00 270.00 MWD 12250.00 90.00 11.15 8954.23 -1280.71 4997.85 5974140.31 669509.39 -3202.80 12.00 270.00 MWD 12275.00 90.00 8.15 8954.23 -1256.07 5002.04 5974165.04 669513.04 -3181.99 12.00 270.00 MWD 12300.00 90.00 5.15 8954.23 -1231.24 5004.93 5974189.93 669515.39 -3160.48 12.00 270.00 MWD 12325.00 90.00 2.15 8954.23 -1206.30 5006.52 5974214.90 669516.43 -3138.34 12.00 270.00 MWD 12350.00 90.00 359.15 8954.23 -1181.30 5006.81 5974239.89 669516.17 -3115.62 12.00 270.00 MWD 12375.00 90.00 356.15 8954.23 -1156.32 5005.78 5974264.84 669514.59 -3092.39 12.00 270.00 MWD 12400.00 90.00 353.15 8954.23 -1131.44 5003.45 5974289.67 669511.72 -3068.71 12.00 270.00 MWD 12425.00 90.00 350.15 8954.23 -1106.70 4999.82 5974314.31 669507.55 -3044.63 12.00 270.00 MWD 12450.00 90.00 347.15 8954.23 -1082.19 4994.90 5974338.71 669502.09 -3020.24 12.00 270.00 MWD 12475.00 90.00 344.15 8954.23 -1057.98 4988.71 5974362.78 669495.37 -2995.60 12.00 270.00 MWD 12500.00 90.00 341.15 8954.23 -1034.12 4981.25 5974386.47 669487.39 -2970.77 12.00 270.00 MWD 12525.00 90.00 338.15 8954.23 -1010.68 4972.56 5974409.71 669478.19 -2945.83 12.00 270.00 MWD 12550.00 90.00 335.15 8954.23 -987.73 4962.65 5974432.43 669467.78 -2920.83 12.00 270.00 MWD 12575.00 90.00 332.15 8954.23 -965.33 4951.56 5974454.58 669456.20 -2895.85 12.00 270.00 MWD 12600.00 90.00 329.15 8954.23 -943.54 4939.31 5974476.10 669443.47 -2870.97 12.00 270.00 MWD 12625.00 90.00 326.15 8954.23 -922.42 4925.93 5974496.91 669429.64 -2846.23 12.00 270.00 MWD 12650.00 90.00 323.15 8954.23 -902.04 4911.47 5974516.98 669414.73 -2821.73 12.00 270.00 MWD 12655.00 / 90.00 322.55 8954.23 -898.05 4908.45 5974520.90 669411.63 -2816.86 12.00 270.00 TD Plan: Plan #7 (E~17íPlan#7 E~17A) Patois Date: 10112t2004 M Totopl BP Amoco WEU,.PATH DfS:'rAU.S Ptal1#1E47A 5002:9:2047001 (;·11' 10900.00 ''''''!le' 30 I 1'1 IJl7tt98't 00;00 GO.3Oft: o.1lJ!$ ~j; :::::nTk 0.00 0.00 30.30 REFERENCE INFORMATiON Parent WelIJmtÞ: Tie on MO: ""', Ref. ÐatuM! ......... ...... 3311_ , , , , : ¡ 4600470048004900 5000 5100 5200 5300 5400 West{-)/East(+) [100ft/in] ;"- ...... .II: 1: -1500- o Z_ ;:ït. . ...... .11:- .. :'I eJ- ,- Nordic 1 bighole All Measurements are from top of Riser ~ Q) en .- cr: top of bag .........y.. .................... bttm of bag middle of blind/shears Blind/Shears middle of pipe/slips middle of flow cross middle of VBR middle of pipe/slips Flow Tee 10/6/2004 BAG 71/16" 5000psi TOTs 7 1/16" 5000psi Mud Cross 71/16" 5000psi TOTs 71/16" 5000psi . . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /Øk ~ /74 PTD# :2djv2~Y X Development Service Exploration Stratigraphic CHECKWßAT ADD-ONS ~'CLUEn APPLIES (OPTIONS) MULTI Tbe permit is for a new weUbore 'segment of LATERAL existing wen . Permit No, API No. . (If API Dum ber Production. sbould continue to be reponed as last two. (2) digits a function 'of tbe original API Dumber, stated are between 60-69) above. .- Pll..OT HOLE In accordance witb' 20 AAC 25.005(1), an (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated "in botb name (name on permit plus PH) .' and API Dumber (SO - 70/80) from records, data and logs acquired for we)) (name on permit). SPACING Tbe permit is approved subject ·to fuU EXCEPTION compliance witb 20 AAC 25..05S~ Approval to perforate and produce is contingeDt UpOD issuance of ~ conservation order approving a spaciDg e:J reptioD. (Company Name) assumes tbe liability of aDY protest to tbe spacing ,e:JceptioD tbat may occur. DRY DITCH AU dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater 1haD 30' sample intervaJs from below tbe permafrost or from wbere samples are first caught and ] 0' sample iIiter:vals tbrougb target zones. .' . . D Well bore seg Annular Disposal Field & Pool PRUDHOE BAY. PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT E-17A _Program XPLORATION (ALASKA) INC Initial Classffype _I t-OIL GeoArea 890 Unit 1165~ On/Off Shore On - Administration Permit fee attached. - - - - - - - - - - - - - - - - - ' .Yes - - - - ~ - - - 2 Lease number .appropriate. , . - - -- Yes 3 .U.nique weltn.a!T1e.and oumb.er . . . . . . . . . . . . . . . . . . . . . _ ........ .Yes - - - - - - - - - - - - - - - - - - - - 4 Well IQcated ina d.efinedpool. , - - - - · .Yes 5 WeJIJQcated proper .distance. from driJling unitb.oundj;lry. . . . · Yes - - - - - - - - - - - - - - - - - - - 6 WeJIJQcated proper ,distance, from other wells. . . . . , . . , . . . . ' .Yes - - - - - - - - - - - - 7 .S.utficientacreage.ayailable indrilliog unit. . .Yes - - - - - - - - - - 8 If.deviated. js weJlbore platinc!uded . . . , . . . . . . . . . · . .Yes - - - - - - - - - - - - - 9 O-per.ator only: affected party. . . . - - - - - - -- Yes - - - - - - - - - - - - 10 .O-per:ator bas,appr9pr¡ate.Qond ¡n.force . . . . . . . . . . . . . . . . . ........ Yes - - - - . ~ - - - - - - - - - - - - - - 11 Permit can be issued withQut co.nserva,tion order. . . . . . . . . . . ' .Yes - - - - - - - - - - - - - Appr Date 12 Permit C<lO be issued withQut ad.ministratillea-ppr9val . . . . . , · . Yes - - - - - - - - - - - - - RPC 10/13/2004 13 Can permit be approved before 15-day wait Yes 14 WellJQcated within area and.strata ,authorized by.lojectioo Ord.er #I (putlQ# in.c91J1!T1eots) (For. .NA - - - - - - - - - - - 15 AJlweUs.WithinJl4.roite.area.ofreyiewideot¡fied(F9rseNjcewell only:). .............. .NA - - . - - - - - - - - - - - - - - - - - 16 Pre-prOduœcl injector; duration of pre--produGtionless than. 3 months. (for service well on!y) . NA - - - - - - - - - - - 17 ,ACMPFindjngof Con.si$teOCy,h.as bee.nJssued. forJbis pr.oject . - - - - - - ..NA - - - - - - - Engineering 18 .C.ooductor string.provided . · NA - - - - - - - - - - - - - 19 S.urface ,casing, protects alLknown USDWs . - - - -- - - - - - - - - - .. NA - - - - - - - - - - - - 20 .CMTvoladeQuateJo circ.ulate,on.cond.uctor& SUJfcsg . . . . . . . . . , . . . · .NA - - - - - - - - - - - - - - - 21 .CMT vol adeQu.ateto tie-in long string to surf çsg. - - - - - - - · .NA - - - - - - - - - - - 22 .CMTwill coyer.aU !<oown.pro.ductiye bori¡!:ons , - - - - - - - - · .Yes - - - - - - -- - - - - - 23 C.asiog desigos aclec¡ua.te for C..t, B.&perroafr9St. - - - - - - · Yes - - - - - - - - - - 24 Adequatetankage.oJ re.serye pit. . . . . - - - -- · Yes CTDU........ . - - - - 25 Ifa.re-drill" basa. tOc403 for abandonment beeo apPJov¡;¡d . . . - - - - - - Yes 1018/2004.. . . - - - -- 26 Adequatewellbore separation.pro-posed. . . . . . . . . . . . . . . . . . . . . . . .. .. .Yes - - - - - - - - - - - - - - - - - - - - 27 Jf.diverter.required, doe~ itmeet reguJa.tions. . . . . . . - - - - - - - - .NA Sidetrack.. . - - - -- Appr Date 28 DriUiog fluid program sGhematic.& eq.uip listadequate. . . . . . . . . . . . . .. Yes MaxMW.8~6.ppg.. . . . . . . . . . WGA 10/14/2004 29 .BOPEs.d.o .they meet r¡;¡gulation , - - - - -- - - - - -- Yes - - - - - - 30 .BOPEwes$ ratiog ap-propriate;test to (put p$ig i.ncomr:nents). . ' Yes Test to .350Q psi. . MSf' 22.44 psi. 31 .C.hokeroanjfold complies w/API. Rf'-53 (May 84L . . . . . . . . . . Yes 32 Work will occur withoutoperatjonsbutdo.wn . . . . . . . . . , . . . . . . . . · Yes 33 Is presence of H2S gas. prob.able. . , - - - - - - - - - - - · . Yes 10 ppm. 34 Mecha.nicai.coodjt[on 9t wells within AOR yerifiecl (for s.ervice welJ only). . · .NA - Geology 35 Permit c,an be Î.ssued wlo. hydr.ogen sulfide meaSJJre~. . . . , , . . . . .. No 36 .D.atapreseotecl on pote.ntial pverpres.surezoneß. . . . . . , . . . ' .NA Appr Date 37 .Sei$lJ1ic.analysjs. Qf shallow gaS.Z90es. . . . . , . . . . . . . . , NA RPC 10/13/2004 38 .Seabed .conditioo $l!rvey(if off-sh.ore) . . · .NA - - - - - - - - - - - - 39 . Contact l1amelphoneJor.we¡;¡kly progress.reports [explQratory .only]. NA - - = Geologic Engineering Date Date commissioner:. Date: 1'"'" ~ Commissioner: oner 'Ý0( OrtgJi\II~g.,D~f,(,o D,~¡q I ' e e 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 infonnation. 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 infonnation. . Sperry-Sun Drilling Services LIS Scan Utility . $Revision: 3 $ LisLib $Revision: 4 $ Wed Sep 28 13:14:20 2005 Reel Header Service name............ .LISTPE Date.................... .05/09/28 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. ! ) :r~ -:> ~ 0ò\..{ - ).~ v( Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/09/28 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA E-17A 500292047001 B.P. Exploration (Alaska) Inc. Sperry Drilling Services 28-SEP-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003353779 S. LATZ EGBEJIMBA/HO MWD RUN 2 MW0003353779 S. LATZ HOLT/HILDRET MWD RUN 3 MW0003353779 S. LATZ HOLT/HILDRET JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003353779 S. LATZ HOLT/HILDRET MAD RUN 4 MW0003353779 S. LATZ HOLT/HILDRET # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 6 UN 14E 1753 501 MSL 0) 60.30 31.40 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING . BIT SIZE (IN) 4.125 SIZE (IN) DEPTH (FT) 7.000 10912.0 . # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 10907'MD IN THE ORIGINAL E-17A WELLBORE. 4. MWD RUNS 1 - 4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MAD PASS DATA WERE ACQUIRED WHILE POOH AFTER REACHING FINAL TD. 5. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY RUN IN THE E-17A WELLBORE ON 30 OCTOBER 2004. THESE LOG DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 15 SEPTEMBER 2005. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES 6. MWD RUNS 1 - 4 REPRESENT WELL E-17A WITH API#: 50-029-20470-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12673'MD/8952'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. RESISTIVITY (EXTRA RESISTIVITY ( SHALLOW RESISTIVITY (MEDIUM RESISTIVITY (DEEP AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/28 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPX FET RPS RPD RPM ROP $ . . .5000 START DEPTH 10838.0 10905.5 10905.5 10905.5 10905.5 10905.5 10936.5 STOP DEPTH 12630.5 12643.5 12643.5 12643.5 12643.5 12643.5 12675.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------- BASELINE DEPTH 10838.0 10843.0 10847.0 10848.0 10849.5 10851.5 10856.0 10900.5 10908.5 10918.0 10920.5 10923.0 10934.0 10944.5 10954.0 10959.0 10997.5 11002.0 11014.5 11035.5 11057.5 11085.0 11111.0 11133.0 11164.5 11170.5 11189.5 11203.0 11242.0 11246.5 11250.0 11255.5 11260.0 11267.5 11300.5 11325.0 11338.5 11357.5 11388.0 11416.5 11427.5 11430.5 11441.0 11448.5 11484.5 11494.0 11513.5 11530.0 11562.5 11577.5 11583.0 GR 10837.0 10842.0 10846.0 10847.5 10849.5 10851.5 10855.5 10897.5 10903.5 10915.5 10917.5 10919.0 10930.5 10939.0 10948.5 10956.0 10994.0 10998.5 11010.0 11033.0 11056.5 11083.5 11106.5 11130.5 11159.0 11167.5 11185.5 11199.0 11243.5 11247.0 11249.5 11254.0 11257.5 11263.5 11297.0 11322.0 11335.5 11353.5 11385.5 11412.5 11420.5 11425.5 11437.0 11444.0 11479.5 11488.5 11509.0 11526.5 11558.5 11572.0 11580.0 11611.5 11655.0 11665.0 11695.5 11704.0 11737.0 11749.5 11770.0 11783.0 11806.5 11844.5 11858.5 11862.5 11872.0 11891.5 11906.5 11917.5 11924.5 11934.5 11945.5 11995.5 11999.0 12032.0 12047.0 12064.5 12072.5 12113.0 12122.5 12128.0 12150.5 12159.5 12170.0 12179.0 12190.0 12230.5 12251.5 12302.5 12312.0 12324.5 12354.0 12400.5 12441.0 12445.0 12457.5 12480.5 12490.0 12495.0 12498.0 12500.0 12507.0 12518.0 12531.5 12537.5 12540.5 12675.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ # REMARKS: . 11609.5 11651. 5 11661.0 11692.0 11701.5 11735.0 11749.5 11767.5 11780.5 11804.5 11843.0 11861.5 11864.5 11872.0 11890.5 11907.5 11916.5 11925.0 11932.5 11944.0 11997.0 12000.5 12031.5 12045.0 12059.0 12068.0 12110.0 1211 7.5 12124.0 12147.0 12153.5 12166.5 12175.5 12188.0 12229.5 12252.0 12299.0 12311.5 12321.5 12352.0 12394.5 12443.5 12445.5 12455.5 12480.5 12489.0 12492.0 12494.5 12497.5 12505.0 12514.5 12529.5 12534.0 12538.5 12673.0 BIT RUN NO 1 2 3 4 # MERGED MAIN PASS. $ MERGE TOP 10837.0 11215.0 11432.0 12337.0 . MERGE BASE 11215.0 11432.0 12337.0 12673.0 . Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value... . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10838 12675 11756.5 3675 10838 12675 ROP MWD FT/H 0.09 2032.55 77.8294 3478 10936.5 12675 GR MWD API 15.09 407.59 63.017 3533 10838 12630.5 RPX MWD OHMM 0.33 2000 26.7149 3477 10905.5 12643.5 RPS MWD OHMM 0.55 2000 35.7553 3477 10905.5 12643.5 RPM MWD OHMM 0.2 2000 33.6015 3477 10905.5 12643.5 RPD MWD OHMM 0.08 2000 55.9957 3477 10905.5 12643.5 FET MWD HOUR 0.21 10.8 1.72125 3477 10905.5 12643.5 First Reading For Entire File......... .10838 Last Reading For Entire File.......... .12675 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/28 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/28 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted DEPTH INCREMENT: 2 and clipped curves; all MAD runs merged using earliest passes. .5000 # FILE SUMMARY PBU TOOL CODE GR RPM RPD RPS RPX FET RAT $ # MERGED DATA SOURCE PBU TOOL CODE MWD $ # REMARKS: . . START DEPTH 11438.5 11448.0 11448.0 11448.0 11448.0 11448.0 11475.5 STOP DEPTH 11817.5 11831.0 11831.0 11831.0 11831. 0 11831. 0 11857.5 MAD RUN NO. MAD PASS NO. MERGE TOP 4 1 11434.0 MERGE BASE 12673.0 MERGED MAD PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11438.5 11857.5 11648 839 11438.5 11857.5 RAT MAD FT/H 3.15 450.03 335.602 765 11475.5 11857.5 GR MAD API 20.13 182.95 64.1799 759 11438.5 11817.5 RPX MAD OHMM 1. 36 41.89 11.0784 767 11448 11831 RPS MAD OHMM 1.5 64.83 14.9104 767 11448 11831 RPM MAD OHMM 1.5 1413.75 22.4084 767 11448 11831 RPD MAD OHMM 1. 83 2000 86.6385 767 11448 11831 FET MAD HOUR 40.89 55.4 48.1259 767 11448 11831 First Reading For Entire File......... .11438.5 Last Reading For Entire File.......... .11857.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/28 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 . Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/28 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD FET RPX RPS RPM ROP $ 3 . header data for each bit run in separate files. 1 .5000 START DEPTH 10837.0 10901.5 10901.5 10901. 5 10901.5 10901.5 10932.5 STOP DEPTH 11170.0 11183.5 11183.5 11183.5 11183.5 11183.5 11215.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 25-0CT-04 Insite 4.3 Memory 11215.0 10932.0 11215.0 43.5 70.8 TOOL NUMBER 78012 171170 4.125 10912.0 Flo-Pro 8.60 65.0 9.3 26000 6.4 .100 .050 .140 65.0 138.0 65.0 · MUD CAKE AT MT: .130 6. # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10837 11215 11026 757 10837 11215 ROP MWD010 FT/H 0.09 305.79 37.8317 566 10932.5 11215 GR MWD010 API 15.09 329.74 29.8923 617 10837 11170 RPX MWD010 OHMM 0.33 2000 75.0247 565 10901.5 11183.5 RPS MWD010 OHMM 0.55 1987.52 73.2006 565 10901.5 11183.5 RPM MWD010 OHMM 0.2 2000 59.897 565 10901.5 11183.5 RPD MWD010 OHMM 0.08 2000 91.1384 565 10901.5 11183.5 FET MWD010 HOUR 0.6 4.21 1.88184 565 10901.5 11183.5 First Reading For Entire File......... .10837 Last Reading For Entire File.......... .11215 File Trailer Service name........... ..STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/28 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 . Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/28 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM RPD FET ROP $ 4 . header data for each bit run in separate files. 2 .5000 START DEPTH 11170.5 11184.0 11184.0 11184.0 11184.0 11184.0 11215.5 STOP DEPTH 11387.0 11400.5 11400.5 11400.5 11400.5 11400.5 11432.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # 26-0CT-04 Insite 4.3 Memory 11432.0 11215.0 11432.0 81.2 94.7 TOOL NUMBER 78012 171170 4.125 10912.0 Flo-Pro 8.60 65.0 9.2 26000 6.0 .100 .048 .140 .130 65.0 144.0 65.0 65.0 . . TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value...................... -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11170.5 11432 11301.3 524 11170.5 11432 ROP MWD020 FT/H 0.85 1009.99 75.943 434 11215.5 11432 GR MWD020 API 27.95 129.44 58.3756 434 11170.5 11387 RPX MWD020 OHMM 8.02 48.24 19.2994 434 11184 11400.5 RPS MWD020 OHMM 10.88 58.25 20.1481 434 11184 11400.5 RPM MWD020 OHMM 12.12 70.37 20.5643 434 11184 11400.5 RPD MWD020 OHMM 14.5 54.78 22.0895 434 11184 11400.5 FET MWD020 HOUR 0.46 8.36 2.52396 434 11184 11400.5 First Reading For Entire File......... .11170.5 Last Reading For Entire File.......... .11432 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/28 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/28 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 . Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX FET RPD RPS RPM ROP $ 5 . header data for each bit run in separate files. 3 .5000 START DEPTH 11387.5 11401.0 11401.0 11401.0 11401.0 11401.0 11432.5 STOP DEPTH 12292.0 12305.5 12305.5 12305.5 12305.5 12305.5 12337.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTRO MAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record 26-0CT-04 Insite 4.3 Memory 12337.0 11432.0 12337.0 84.7 96.7 TOOL NUMBER 78005 171170 4.125 10912.0 Flo-Pro 8.60 65.0 9.5 25000 5.8 .200 .090 .160 .180 65.0 150.0 65.0 65.0 . Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value... . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11387.5 12337 11862.3 1900 11387.5 12337 ROP MWD030 FT/H 0.35 2032.55 84.8285 1810 11432.5 12337 GR MWD030 API 20.03 191.13 63.8274 1810 11387.5 12292 RPX MWD030 OHMM 1. 66 93.96 18.7045 1810 11401 12305.5 RPS MWD030 OHMM 1. 76 2000 36.6616 1810 11401 12305.5 RPM MWD030 OHMM 1. 79 2000 31.9225 1810 11401 12305.5 RPD MWD030 OHMM 1. 93 2000 65.3001 1810 11401 12305.5 FET MWD030 HOUR 0.21 10.81 1.43467 1810 11401 12305.5 First Reading For Entire File......... .11387.5 Last Reading For Entire File.......... .12337 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/28 Maximum Physical Record. .65535 File Type.. . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/28 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: 6 header data for each bit run in separate files. 4 .5000 # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ . START DEPTH 12292.5 12306.0 12306.0 12306.0 12306.0 12306.0 12337.5 STOP DEPTH 12628.5 12641.5 12641.5 12641.5 12641.5 12641.5 12673.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined . 28-0CT-04 Insite 4.3 Memory 12673.0 12337.0 12673.0 87.5 90.2 TOOL NUMBER 78005 171170 4.125 10912.0 Flo-Pro 8.60 65.0 9.5 30000 6.8 .110 .049 .150 .140 65.0 155.0 65.0 65.0 . . Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12292.5 12673 12482.8 762 12292.5 12673 ROP MWD040 FT/H 2.06 548.48 92.658 672 12337.5 12673 GR MWD040 API 31.76 407.59 93.1116 673 12292.5 12628.5 RPX MWD040 OHMM 5.44 27.26 16.0227 672 12306 12641.5 RPS MWD040 OHMM 5.5 27.6 17.4461 672 12306 12641.5 RPM MWD040 OHMM 5.87 27.54 17.9481 672 12306 12641.5 RPD MWD040 OHMM 8.31 27.38 20.1817 672 12306 12641.5 FET MWD040 HOUR 0.35 9.3 1.87217 672 12306 12641.5 First Reading For Entire File......... .12292.5 Last Reading For Entire File.......... .12673 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/28 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.007 Physical EOF File Header Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/28 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM 7 header data .5000 4 1 for each pass of each run in separate files. START DEPTH 11434.0 11443.5 11443.5 STOP DEPTH 11815.5 11829.5 11829.5 RPS RPX FET RAT $ . 11443.5 11443.5 11443.5 11470.5 11829.5 11829.5 11829.5 11860.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 28-0CT-04 Insite 4.3 Memory 11860.0 11470.0 11860.0 87.5 90.2 TOOL NUMBER 78005 171170 4.125 10912.0 Flo-Pro 8.60 65.0 9.5 30000 6.8 .110 .049 .150 .140 65.0 155.0 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 . . RAT MAD041 FT/H 4 1 68 4 2 GR MAD041 API 4 1 68 8 3 FET MAD041 HOUR 4 1 68 12 4 RPX MAD041 OHMM 4 1 68 16 5 RPS MAD041 OHMM 4 1 68 20 6 RPM MAD041 OHMM 4 1 68 24 7 RPD MAD041 OHMM 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11434 11860 11647 853 11434 11860 RAT MAD041 FT/H 3.15 450.03 335.764 780 11470.5 11860 GR MAD041 API 20.13 182.95 64.3943 764 11434 11815.5 FET MAD 0 41 HOUR 40.89 55.4 48.1212 773 11443.5 11829.5 RPX MAD041 OHMM 1. 36 41.89 11. 031 773 11443.5 11829.5 RPS MAD041 OHMM 1.5 64.83 14.8763 773 11443.5 11829.5 RPM MAD041 OHMM 1.5 1413.75 22.3646 773 11443.5 11829.5 RPD MAD041 OHMM 1. 83 2000 88.7362 773 11443.5 11829.5 First Reading For Entire File......... .11434 Last Reading For Entire File.......... .11860 File Trailer Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/28 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.008 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/09/28 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date.................... .05/09/28 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
