Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
204-052
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG rr^, r, 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned m Suspended ❑ tib. Well Class: 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG 13WDSPL ❑ No. of Completions: Zero Development 0 Exploratory -- ❑ Service O StratigrapNc Test ❑ 2. Operator Name: S. Date Comp., Susp., or Abend.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 1/7/2019 204-052 318-367 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 196612 Anchorage, AK 99519-6612 4/12/2004 50.029-20938-01-00 4a. Location of Well (Governmental Section): S. Date TO Reached: 16. Well Name and Number: 4/15/2004 PBU 07-25A Surface: 1751' FNL, 269' FEL, Sec. 33, T11 N. R14E, UM 9 Ref Elevations KB 57 0 17. Field/Pool(s): Top of Productive Interval: 2580 FNL, 3015' FEL, Sec. 33, T11N ,R14E, UM GL 26.44 BF 28.85 PRUDHOE BAY, PRUDHOE OIL 10. Plug Back Depth(MDfTVD). 18, Property Designation: Total Depth: 1963' FNL, 40.59' FEL, Sec. 33, T1 IN. R14E, UM 6601'/ 6287' ADL 028309 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/TVD): 19. DNR Approval Number Surface: x- 675947 y- 5949168 Zone - ASP 4 10952'/ 9013' 74-064 TPI: x- 673222 y- 5948295 Zone - ASP 4 12. SSSV Depth (MD/TVD): 20 Thickness of Permafrost MDrrVD: Total Depth: x- 672163 y- 5948868 Zone - ASP 4 None 1900' (Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No El 13. Water Depth, if Offshore: 21. Re-oldfl/Lateral Top Window Submit electronic and printed information per 20 AAC 25.050 N/A (It MSL) MDRVD: 9376'/ 8781' 22. Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary SGRC w/ GR 8 ENR, MGR / CCL / CNL 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZEAMOUNT CEMENTING RECORD PULLED TOM TOP BOTTOM 20" 91.5# 0' 30' 110' 30" 195W Poleset 13-3/8" 72# 27' 30' 2527' 17-1/2" 1800 sx Fondu, 400 sx PF'C' 9-5/8" 47# g876O' 6' 27' 8461' 12-1/4" 500 sx Ckes'G', 50 bba PF'C' 7" 29# 6' 8207' 8781' 8-1/2" 350 sx Class'G' 3-1/2" 9.3# 7fi' 8247 8781' Scab Liner 172 sx LARC 2-3/8" 1 4.6# L -so 1 9108' 10952' 8549' 9013' 3" 58 sx Class'G' 24. Open to production or injection? Yes ❑ No ® 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): GRADE DEPTH SET (MD) PACKER SET (MO/TV 5-1/2" 17# L -BO 6776'- 8775' 8655'/ 8154' x 4-117'12.6# L-80 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. S/UY� 'IA DATE 11 �1 Was hydraulic fracturing used during completion? Yes ❑ No m Per 20 AAC 25.283 (i)(2) attach electronic and printed information VERIFIED DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED See Attached 27. PRODUCTION TEST Data First Production: Not on Production Method of Operator, (Flowing, gas lig, etc.): WA Date of Test : Hours Testetl: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period y Flow Tubing Press Casing Press: I Calculated 24 Hour Rale -1 Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity- API (cor): Forth 10407 Revised 52017 CONTINUED ON PAGE 2 Submit ORIGINAL only RBDMS MG f B 0 5 2019 �%G 28. CORE DATA Conventional Cores) Yes ❑ No 0 Sidewall Cores Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MO TVD Permafrost - Top Well Tested? Yes ❑ No 0 Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 9723' 8978• separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. CGL - Zone 3 9375' 8781' Base of CGL - Zone 2 9493' 8864' 23 SB - Zone 2B 9598' 8914' 22TS 9723' 8976' Formation at total depth: Zone 28 9723' 1 8976' 31. List of Attachments: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Gorham, Bradley M Authorized Title: SIM pecialis Contact Email: Bmdley.Gorham@bp.com Authorized Signatur : jk�ate; -/LF'' Contact Phone: 907-584-4649 INSTRUCTIONS General: This forth is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10407 well completion report and 10404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a. 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 1b. Well Class Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cemenfing and the location of the cementing tool. Item 24. 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 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the coresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10407 Revised 512017 Submit ORIGINAL Only WELL NAME: 07-25A 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 8643'- 8648' Tubing Punch 7381'- 8643' 87.5 Bbls Class 'G' 6776' Cut & Pull Tubing 6764' Set Whipstock 6601' Set 2nd Whipstock ***WSR Continued from 09-30-18*** T/1/0= 360/450/10 Temp= S/I (LRS Unit 72 - MIT -T, C M IT-TxIA) MIT -T PASSED to 2637 psi, Max Applied Pressure= 2750, Target Pressure= 2500 psi, Pumped 3.8 bbls crude down TBG to reach test pressure, TBG lost 69 psi in 1st 15 min and 26 psi in 2nd 15 min for a total loss of 95 psi in 30 min, CMIT-TxIA FAILED at 2707/2653 psi, Max Applied Pressure= 2750, Target Pressure= 2500 psi, Pumped a total of 5.4 bbls crude down T/IA to reach test pressure, T/IA lost 13/34 psi in 1st 15 min and 10/32 psi in 2nd 15 min for a total loss of 23/66 psi, Calculated LLR of .24 gpm, Bleed T/IA pressure, Bled back total of 9 bbls, AFE sign and tags hung on well, Valve position at departure- WV, SSV, SV= Closed, MV= Open, IA & OA= OTG, 10/1/2018 FWHP= 216/219/60 *"*WELL S/I UPON ARRIVAL**** (Sidetrack) SET 5-1/2" WHIDDON CATCHER SUB ON XO @ 8,660' SLM RAN BAITED 5-1/2" OM -1 TO STA#8 GLM @ 8,585' SLM / 8,589' MD (No recovery) PULLED 5-1/2" WHIDDON CATCHER FROM 8,660' SLM (Empty) RAN PDS MTT LOG FROM 6,000' TO 7,500' PER SOR (Good data) RAN 5-1/2" OM -1, (2x) 7" EXT, 1.70" LIB TO STA #8 @ 8,589' MD (Impression of eq prong on side of Iib) 10/2/2018 ****CONT JOB ON 10/3/18**** ****CONT. JOB FROM 10/2/18**** (Sidetrack) SET 5-1/2" WHIDDON CATCHER ON XO @ 8,660' SLM / 8,675' MD RAN BAITED 5-1/2" OM -1, 1-5/8" JD (Coreless) TO STA#8 (Unable to latch) RAN BAITED 5-1/2" OM -1, 1-5/8" JD (Coreless), S/D IN STA #6 @ 8,255' MD WHILE RIH (Jarred 1 hr, Shucked dogs) PULLED EQ PRONG FROM STA#8 RKED-DGLV @ 8,585' SLM / 8,589' MD MADE 1 ATTEMPT TO PULL STA#8 DGLV (Unable to latch) 10/3/2018 ****MOVE TO WEATHER STANDBY, HIGH WINDS*** ****CONT. JOB FROM 10/3/18**** (Sidetrack) RAN 5-1/2" OM -1, 7" EXT, 1-5/8" JDS (Split skirt) TO STA #8 @ 8,589' MD (Unable to latch, metal marks on skirt) RAN 5-1/2" OM -1, 7" EXT, 1-1/2" JDS TO STA #8 @ 8,587' SLM / 8,589' MD (Jar up 10 min, Sheared) 10/4/2018 ****CONT JOB ON 10/5/18**** ****CONT. JOB FROM 10/4/18**** (Side track) MADE 1 ATTEMPT TO PULL STA #8 FROM 8,587' SLM / 8,589' MD (Recovered fish neck and core of RKED latch) RAN 5-1/2" OM -1, 1.70" LIB TO STA #8 GLM (Impression of wobble ring & no-go of dglv in pocket) ATTEMPTING TO PULL STA #7 FROM 8,517' SLM / 8,519' MD (-4 Hrs jarring up to 1000 LBS) 10/5/2018 ****CONT JOB ON 10/6/18**** ****CONT. JOB FROM 10/5/18**** (Sidetrack) MADE 3 ATTEMPTS TO PULL STA #7 DGLV FROM 8,517' SLM / 8,520' MD (unable to latch - see log) PULLED 5-1/2" WHIDDON CATCHER FROM 8,660' SLM (Recovered wobble ring, spring, shucked JD dog, & metal pcs) ****WELL LEFT S/I & DSO NOTIFIED OF STATUS UPON DEPARTURE**** 'NOTE: STA#8 RKED-EQ DGLV = LATCH NO-GO & VALVE LEFT IN POCKET 10/6/2018 STA #7 RK-DGLV = STRIPPED FISH NECK Daily Report of Well Operations 07-25A ***WELL S/I ON ARRIVAL*** (SLB ELINE TUBING PUNCH) INITIAL T/VO = 400/300/0 PSI. MIRU & PT TO 3650 PSI. RUN 1: PUNCH TBG 8643'- 8648'W/ 1.56" X 5' TBG PUNCHER, 4 SPF, 0 DEG PHASE, 1606M CHARGES. ALL LOGS CORRELATED TO TBG TALLY DATED 01 -JUN -1989. RMDO. WELL LEFT S/I ON DEPARTURE. FINAL T/I/0 = 680/490/0. 10/14/2018 ***JOB COMPLETE ON 14 -OCT -2018*** SLB Fullbore Pumping Crew. Plug and Abandonment - Balance Plug (Sidetrack) Balance Plug pumped down 5-1/2" TBG w/ IA returns to production via 07-24 FL. DH circ point was TBG punch at 8643' MD Pumped 5 bbls 60/40 spear, 563 bbls hot freshwater TxIA hydrocarbon flush, 43 bbls annular diesel freeze protect, 298 bbls 10.0 PPG NaCl annular spacer, 87.5 bbls 15.8 PPG Class G CMT, 2 x 7" Foam balls, 156.5 bbls 10.0 PPG NaCl tubular spacer, 15.2 bbls diesel tubular freeze protect Total displacement: 171.75 bbls (171.25 downhole + 0.5 surface). Class G CMT in TBG from 8643' MD to 7381' MD (Tubular plug length = 1262' MD) 10/20/2018 Class G CMT in IA from 8643' MD to 7314' MD (Annular plug length = 1329' MD T/I/O=SSV/300/0, Temp=Sl. PPPOT-T (FAIL), PPPOT-IC (PASS), Pre rig. PPPOT-T: Stung into test port (800 psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all moved freely. Single port, unable to pump through void. Pressured void to 5000 psi for 30 min test, lost 500 psi in 15 min, lost 300 psi in second 15 min (FAIL). Bled void to 0 psi. PPPOT-IC: Stung into test port (0+ psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all were stiff but fully functioned. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 10/21/2018 ***WELL S/I ON ARRIVAL SWCP 4518***(pre-rig sidetrack) RIG UP SWCP 4518. 10/23/2018 ***CONTINUE WSR TO 10/24/18*** ***CONTINUE WSR FROM 10/23/18 SWCP 4518***(sidetrack) BRUSHED BPV PROFILE W/ DOUBLE 5-1/2" BRUSH DRIFTED 2'x 1 7/8" stem, 4.25" CENT, 2.50" SAMPLE BAILER. TAG TOC @ 7163' SLM, (recovered approx 2 cups of cement) SET 5-1/2" SLIP STOP CATCHER @ 3909' SLM PULLED ST #1 RK -DUMMY GLV FROM 2880' SLM (2889' MD) PROVED TBG & IAARE COMMUNICATING, IA NOT FROZEN SET ST #1 RK -DUMMY GLV @ 2880' SLM (2889' MD) PULLED 5-1/2" SLIP STOP CATCHER FROM 3909' SLM PURGED 2.5gals OF HYDRO THROUGH CONTROL LINE (front) BALANCE LINE APPEARS TO BE PUGGED OFF (back) 10/24/2018 ***WELL LEFT S/I DSO NOTIFIED ON DEPARTURE*** IT/I/O= 0/vac/0. Temp = SI. (IA FL for slickline) IA FI @ 60'(2.6 bbls) Apply positive 10/24/2018 pressure from adjoining well. Daily Report of Well Operations 07-26A T/l/O = 30/45/vac. Temp = SI. MIT- T, CMIT- Tx IA, OA INT, Inflow Test (Pre -Rig) MIT T to 2748 psi (Target = 2500 psi). PASSED. Pump 2.5 bbls diesel to bring pressure from 30 psi to 2748 psi. TBG lost 78 psi in first 15 minutes & 29 psi in second 15 minutes. Total loss = 107 psi. CMIT Tx IA to 3748/3738 psi (Target = 3500 psi). FAILED. Pump 7 bbls diesel to bring to test pressure. T/ IA lost 79/72 psi in first 15 minutes & 54/53 psi in second 15 minutes. Total loss = 133/125 psi. Perform 3 tests. Bleed T/ IA pressures down to 10 psi. Bled back 4.4 bbls. Pressure up on OA to 1200 psi. Took 1 bbls to reach test pressure. Hold for 5 minutes. OA intergity test good. RU mfor TBG inflow test. TBG inflow test passed. Final WHIP = 0/0/0. 10/25/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:45. T/I/O = 0/0/20. Temp = SI. WHPs (Post MIT) No AL. TP, IAP unchanged, OAP increased 20 psi overnight. 10/26/2018 SV, SSV, WV = C. MV = O. IA, OA = OTG. 13:30. TWO = O/Vac/20. Temp = SI. Assist Cameron w/LPE (Pre Rig). Pressured IA to 2500 psi with 6.3 bbls of diesel. Held 2500 psi while Cameron monitored hanger for 15 min (See Cameron log for details). Bled IA to 0 psi. Bled back 6 bbls. Turned well over to valve 10/29/2018 crew. 16:30 T/I/O = BPV/0/20 Temp = SI. PPPOT-T (PASS) Valve crew set BPV and test dart. PPPOT-T: Stung into test void. (100 psi) bled void to 0 psi. Monitored for 10 min. Void stayed at 0 psi. single port, unable to pump through void. Pressured void to 5000 psi for 30 min. lost 300 psi in first 15 min. lost 100 psi in second 15 min. Waited another 15 min. lost 20 psi. ( PASS) Bled void to 0 psi. Valve crew pressure tested tree to 2500 psi. Test void gained 0 psi during 15 min test. Bled tree to 0 psi. DHD crew increase IA pressure to 2500 psi. Test void gained 0 psi during 15 min test. 10/29/2018 1 Bled IA pressure to 0 psi. T/1/0=0/0/0. Assist Cameron with PPPOT-T and LPE. Set 5" "K" BPV #606 @138", BPV LTT Passed. Set 5" "K" Test Dart @135". See Cameron's log on PPPOT-T (10/29/18) Pull 5" "K" BPV #606 @138". PT tree cap to 500 psi. Pass. ***Job Complete*** See Log. Final 10/29/2018 WHP's 0/0/0. 11/1/2018 Cost Placeholder: Cement kits for control lines. WELL SHUT IN ON ARRIVAL. INITIAL T/l/O = 0/0/0 RU PT RIH W/ SLB 4.15" JET CUTTER CUT 5-1/2" TUBING AT 6776'. CORRELATED TO PDS MTT LOG 10-2-18 FINAL T/I/O = 0/0/0 PSI WELL SHUT IN ON DEPARTURE 11/2/2018 ***JOB COMPLETE*** T/I/0= 0/0/16 Temp=S/I. (LRS Unit 70 - CMIT-TxIA Post Eline Jet Cut) CMIT-TxIA **FAILED** Max applied pressure 3750 psi and Target 3500 psi. Pressured TxIA to 3652/3681 psi. Pumped a total of 7.6 bbIs o iese down IA to reach test pressure. TxIA lost 75/75 psi in 1st 15 min and 67/68 psi in 2nd 15 min for a total loss of 142/143 psi in 30 min test. (2 attempts with similar results to pre-Eline Jet Cut) Bled back - 5 bbls. 11/2/2018 Tags and Fluid packed annulus sign hung. SV, SSV, WV= Shut MV, IA, OA= Open Daily Report of Well Operations 07-25A T/I/O = SI/0/0 Temp = SI PPPOT-T (PASS) PPPOT-T: Hooked up 1 HPBT to test port on Tubing head adapter and 1 to top port on tubing spool. Stung into void 0 psi. Monitored for 10 min. No change in pressure 0 psi. Pumped through both test ports both ways and got good returns. Pressured up to 5000 psi 11/2/2018 for 30 min. test. Lost 100 psi in first 15 min. Lost 25 psi. in second 15 min. (PASS) bled TWO = SSV/vac/20. Temp = SI. Cement Control & Balance line with SqueezeCrete ultra fine cement. Injected 1.1 gallons of SqueezeCrete cement down Balance line and 2 gallons down the Control line before pressuring up to 3000 psi. Wait 48 hours before 11/4/2018 pressure testing. No red line required. ***Job Complete*** T/I/O = SSVNac/20. Temp = SI. WHPs (post Cement job). No AL. Heater in WH and is working properly. 11/5/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:40 TWO = SSVNac/20. Temp = SI. PT C&B lines (pre sidetrack). PT PASSED on C & B lines. Bled psi off C & B lines. Hung tags. 11/9/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:40 T/I/O=O/O/O. Pre -Parker 272, Set 5" K BPV #615 at 130", BPV LTT Passed. RD upper tree, RU Dryhole SV Temp #2. RU Piggyback IA Temp #7 .RD OA 3" blind flange, RU 3" OA Integral. PTDryhole tree 300/5000PSI 5 Min ea. Passed charted, and saved. PT IA piggyback valve and IA companion flange /3" Gray VR plug,300/3500 PSI 5 min ea passed, charted, and saved. PT 3" OA Integral / 3" Gray VR plug, 300/5000 PSI 5 min ea, Passed , charted, and saved. Pulled 5" K BPV #615 at 130". PT tree cap 500 PSI passed. Job 11/24/2018 complete. See log. Final WHP'S= 0/0/0 T/I/O = VactVac/Vac. Temp = SI. Increased IAP (post Rig). Dry hole tree installed. No WH or scaffolding installed. Used 19 bbls of DSL through the IA to pressure up Tbg/IAP to 131/204 psi to establish communication. Bled Tbg/IAP to 0 psi (3 bbls). Final WHPs = 0/ONac. 12/10/2018 SV, MV = C. IA, OA = OTG. 14:30 T/I/O = 0/0/0. Pumped through IA to verify Communication 300 PSI (Pass). Set 5" K BPV #613 through Dryhole Tree @105" with Lubricator 840, Performed LTT on BPV (Pass). 12/15/2018 RDMO. ***Job Complete***. FWPs = BPV/0/0. T/I/O = BPV/20/10. Temp = SI. WHPs. (Pre -Rig). Well house, flow line, ssv, flow cross & scaffold removed. BPV in TBG, IA has double casing valves @ the 12:00 position, OA has integral flange installed. 12/20/2018 SV, MV = C. IA, OA = OTG. 04:40 T/I/O = BPV/20/10. Temp = SI. Bleed WHPs to 0 psi (Pre -Rig). Well house, flow line, SSV, flow cross & scaffold removed. IA FL @ surface, OA FL @ near surface. Bled IAP to BT from 20 psi to 0 psi in 30 min total, all fluid, returned 1 bbl. Bled OAP from 10 psi to 0 psi in 1 min, all gas. Monitor for 30 min. Final WHPs = BPV/0/0. 12/21/2018 SV, MV = C. IA, OA = OTG. 09:45 T/I/O = BPV/0/1. Temp = SI. Eval DSL stains (Pre rig handover). No wellhouse, AL or flowline. IA has 2 casing valves. Used a 4 way meter to test wellhead for hydrocarbon vapors (none found). There is some slightly discolored snow on the upper SV x lower SV connection, Dug through the snow to gravel in several spots, no discoloration found. 12/21/2018 SV, MV = C. IA, OA = OTG. 14:30. T/I/O = BPV/0/10. Temp = SI. WHPs (post bleed). Dry Hole tree installed, no well house, scaffold, flow line or AL. IAP unchanged, OAP increased 10 psi overnight. Bled OAP from 10 psi to 0 psi in <1 min (all gas). Monitored for 30 min. Cleaned fluid around Outer casing spool for further eval. WHPs unchanged during monitor. Final WHPs = BPV/0/0. 12/22/2018 ISV, MV = C. IA, OA = OTG. 15:15 07-25A valve installed. No scaffold, flow line or AL. IAP went on Vac & OAP increased 8 psi since 12/22/18. 1/1/2019 SV. MV = C. IA. OA = OTG. 1015 hrs. North America - ALASKA - BP Page 1 of3r9' Operation Summary Report Common Well Name: 07-25 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 1/12019 End Date: X3 -0197G -C: (4,996,677.00) Project: PBU Site: 07 Rig Name/No.: PARKER 272 Spud Datemme: 4/13/1983 12:00:00AM Rig Release: 1/24/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000904 Active datum. P272 KB Q73.84usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations "'RIG ACCEPTED AT 06_:0.0^' - - (hr) _ 9.50 RIGU (usft) 6.84 PRE 1/1/2019 08:00 - 09:00 1.00 MOB P 6.84 PRE SEPARATE MODULES AND PREPARE TO - CALIBRATE PIT SENSORS MOVE TO DS -07 09:00 - 00:00 15.00 MOB P 6.84 PRE MOVE MODULES 19.5 MILES FROM 7-11-12 - INSTALL TREE SENSOR _ PAD TO DS07 1/2/2019 00:00 - 0200 2.00 MOB P 6.84 PRE SPOT DRILL MOD OVER WELLAND MARRY - VERIFY VR PLUG INSTALLED ON NON UP UTILITY MOD AND MUD MOD WORKING SIDE OF WELLHEAD AND WBS:RU 02:00 - 04:00 �2.00 RIGU P 6.84 PRE GENERAL RIG UP PERFORM EVAC DRILLAND AAR 16:00 - 16:30 0.50 RIGU P 6.84 - RIG UP DRILL FLOOR AND PIPE SHED HOLD PRESPUD MEETING WITH LYLE L. -SPOT CUTTINGS BOX BUCKLER'S CREW 16:30 - 19:30 3.00 RIGU P 6.84 HOOK UP INTERCONNECTS 04:00 - 05:30 1.50 RIGU P 6.84 PRE RAISE DERRICK (MAX PU 562 KLBS) - TEST TO 3500 PSI FOR 5 MIN (FAILED TEST) -SKID FLOOR INTO PLACE - BLEED PRESSURE TO 600 PSI FOR ROLLING '- HOOK UP MUD, CEMENT AND BLEEDER TEST FOR 5 _MIN (NO FLUID LEAKING BY BPV) 1930 _ 4.50 WHSUR P 6.84 LINES UNDER FLOOR 05:30 - 08:00 50 RIGU P 6.84 PRE 'BRIDALDOWN - CAMERON REP ON LOCATION TO BLEED -TEST GENERATOR ESD Printed 1/282019 11:22:19AM **All depths reported in Drillers Depths" "'RIG ACCEPTED AT 06_:0.0^' 06:00 - 15:30 9.50 RIGU P 6.84 PRE GENERAL RIG UP - CALIBRATE PIT SENSORS - HOOK UP STEAM TO WELLHOUSE - INSTALL TREE SENSOR - CHANGE OUT SAVER SUB TO HT -38 - VERIFY VR PLUG INSTALLED ON NON WORKING SIDE OF WELLHEAD AND PRESSURE TEST �ODTEST) 15:30 - 16:00 0.50 RIGU P 6.84 PRE PERFORM EVAC DRILLAND AAR 16:00 - 16:30 0.50 RIGU P 6.84 PRE HOLD PRESPUD MEETING WITH LYLE L. BUCKLER'S CREW 16:30 - 19:30 3.00 RIGU P 6.84 PRE RIG AND TEST THE BPV FROM BELOW - TEST TO 3500 PSI FOR 5 MIN (FAILED TEST) - BLEED PRESSURE TO 600 PSI FOR ROLLING TEST FOR 5 _MIN (NO FLUID LEAKING BY BPV) 1930 - 0000 4.50 WHSUR P 6.84 PRE NIPPLE DOWN TREE AND ADAPTER FLANGE - CAMERON REP ON LOCATION TO BLEED HANGERVOID - REMOVE TREE AND ADAPTER FLANGE - CLEAN UP HANGER - FUNCTION LDS - INSTALL DART IN BPV - CONFIRM ROUNDS ON CROSSOVER (18-1/2 _ ROUNDS) 1/3/2019 0000 - 04.30 4.50 BOPSUR P 6.84 PRE NIPPLE UP 13-5/8" 5K BOP STACKAS FOLLOWS -ANNULAR -4-1/2" X 7" VBR UPPER RAMS - BLIND/SHEAR RAMS -MUD CROSS - 2-718"X 5" VBR LOWER RAMS - INSTALL FLOW RISER AND FLOW LINE - HOOK UP TURN BUCKLES Printed 1/282019 11:22:19AM **All depths reported in Drillers Depths" Common Well Name. 07-25 Event Type'. RE-ENTER- ONSHORE (RON) Project: PBU Rig Name/No.. PARKER 272 North America - ALASKA - Blo Operation Summary Report Start Dale: 1/1/2019 End Date. Site: 07 Spud Oate/Time: 4/13/1983 12:00:OOAM AFE No K3 -0197G -C: (4,996,677.00 ) Rig Release: 1/242019 Active datum: P272 KB @73.84usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 04:30 - 06:30 2.00 BOPSUR P 6.84 PRE RIG UP TO TEST BOPE 06.30 - 1400 7.50 BOPSUR P 14:00 - 15:00 100 BOPSUR P 15:00 - 21:00 6.00 BOPSUR P 2100 - 22'.00 1.00 BOPSUR P 2200 - 00:00 2.00 STCTPL P 1/4/2019 00:00 - 02:30 2.50 STCTPL P Page 2 Printed 1282019 11.22:19AM **All depths reported in Drillers Depths" - BUILD MANIFOLD TO TEST SAFETY VALVES 6.84 DECOMP - BUILD TEST JOINTS - FILL LINES AND SUFACE EQUIPMENT -PERFOM SHELL TEST - RETORQUE BOLTS ON BOP STACK 6.84 PRE PRESSURE TEST BOPE TO 250 PSI LOW AND 5000 PSI HIGH FOR 5 MIN EACH - PRESSURE TEST ANNULAR TO 250 PSI LOW 6.84 DECOMP AND 3500 PSI HIGH FOR 5 MIN EACH - TEST AGAINST RAM LOCKS - TEST WITH 4", 4-1/2", AND 7" TEST JOINTS - TEST PVT, FIRE AND GAS ALARMS - NO FAILURES -TEST WITNESSED BYAOGCC REP BRIAN _ BIXBY 6.84 PRE RIG DOWN PRESSURE TESTING EQUIPMENT -MAKE UP 4" SAFETY JOINT - BLOW DOWN BOPE _ 6.84 DECOMP ,PULL DART AND BEV - RIG UP DUTCH RISER - MAKE UP LUBRICATOR AND PRESSURE TEST TO 3500 PSI - BREAK OFF LUBRICATOR AT THE QUICK TEST SUB AND PULL DART WITH DRY ROD -MAKE UP LUBRICATOR EXTENSIONS, INSTALL LUBRICATOR ON QUICK TEST SUB AND TEST - VERIFY NO PRESSURE ON IAAND PULL BPV WITH LUBRICATOR -RIG DOWN LUBRICATOR AND DUTCH RISER SYSTEM Printed 1282019 11.22:19AM **All depths reported in Drillers Depths" WBS:DECOMP 6.84 DECOMP ROCK OUT DIESEL FREEZE PROTECT FROM TUBING AND IA - PUMP DOWN IA WITH 25 BBL OF 10 PPG BRINE AT 5 BPM, 1100 PSI -PUMP DOWN TUBING WITH 75 BBL OF 10 PPG BRINE AT 5 BPM, 400 PSI -TAKE ALL RETURNS TO TIGER TANK 6.84 DECOMP MAKEUP SLB FISHING SPEAR AND BUMPER SUB -ATTEMPT TO SPEAR TUBING WITH 4.802" - 4.961" GRAPPLE - SPEAR HANGING UP AT THE TOP OF THE HANGER 6.84 DECOMP LAY DOWN SPEAR AND BUMPER SUB, PICK UP 4-3/4" TAPERED MILLAND DRIFT HANGER WITH NO ISSUES - MAKE UP SPEAR AND BUMPER SUB - REMOVE RACKOFF FROM SPEAR AND ATTEMPT TO SPEAR TUBING WITH 4.802" - 4.961"GRAPPLE - SPEAR STILL HANGING UP AT THE TOP OF THE HANGER - OBSERVE MARKINGS ON BOTTOM WICKER OF GRAPPLE, NONE OF THE UPPER WICKERS LOOK LIKE THEYARE BEING ENGAGED Printed 1282019 11.22:19AM **All depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Common Well Name: 07-25 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 1/1/2019 End Date. XM197G-C'. (4,996,677.00 ) Project: PBU Site: 07 Rig Name/No.: PARKER 272 Spud DateTme: 4/13/1983 12'.00:OOAM Rio Release 1 /2412 01 9 Page 3 041V Rig DonaactoC PARKER DRILLING CO. _ Active datum: P272 KB @73.84usft (above Mean Sea Level) BPUOI: USA00000904 Date From - To Hrs Task Code NPT Total Depth Phase Descnpdon of Operations (hr) (usft) 02:30 - 04:00 1.50 STCTPL P 6.84 DECOMP CHANGE OUT GRAPPLE ON SPEAR 7O 4.719" - 4.89" GRAPPLE - RUN IN AND SPEAR TUBING - CAMERON REP ON LOCATION TO BACK OUT LOCK DOWN SCREWS - 202 KLBS TO OFF -SEAT THE HANGER - PULL HANGER TO FLOOR WITH 137 KLBS 'STRING WEIGHT - THE LOWER METAL TO METAL SEAL ON HANGER IN GOOD SHAPE -ONLY 1/4 OF UPPER RUBBER SEAL iRECOVERED 04:00 - 05:00 1.00 STCTPL P 6.84 DECOMP LAY DOWN SPEAR AND BUMPER SUB ASSEMBLY 05:00 08:00 3.00 STCTPL P 6.84 DECOMP _ RIG UP AND CIRCULATE SOAP PILL SURFACE TO SURFACE - 5 BPM, 183 PSI - STRING IN 1 BBL OF SOAP WHILE PUMPING SURFACE TO SURFACE 08:00 - 17:00 9.00 STCTPL P 6.84 DECOMP PULL 5-1/2",17#, 8 RND TUBING FROM CUT AT 6776' MD TO SURFACE - PULL 168 JOINTS, 1 SSSV, 3 GLM, AND 1 - 10.77'CUT JOINT - LAY TUBING DOWN IN MOUSEHOLE WITH ELEVATORS, PULL OUT OF MOUSEHOLE WITH SINGLE JOINT ELEVATORS AND LAY DOWN TO PIPE SKATE - RECOVER 63 SS BANDS, NO SIGNS OF MISSING BANDS - NO EXCESSIVE CORROSION OBSERVED 17:00 - 18:00 1.00 STCTPL P 6.84 DECOMP RIG DOWN TUBING HANDLING EQUIPMENT - CLEAN AND CLEAR RIG FLOOR - CHANGE OUT MOUSEHOLE TO 30' MOUSEHOLE 1800 - 00:00 6.00 STCTPL P 6.84 DECOMP PERFORM 5 MIN ASSURANCE TEST ON TUBING HANGER SEALAREA IN TUBING HEAD - DRAIN STACK - PICK UP NEW TUBING HANGER WITH TWC INSTALLED - THREADS LEAKING ON LANDING JOINT CROSSOVER DURING INITIAL TEST - CAMERON REP ON LOCATION TO RUN IN LOCK DOWN SCREWS AND PULL LANDING JOINT - PRESSURE TEST WITH BLIND RAMS CLOSED - PRESSURE TEST HANGER FROM ABOVE TO 3500 PSI FOR 5 MIN (GOOD TEST) - WHILE BACKING OUT THE LOCK DOWN SCREWS TO PULL THE HANGER, THE CAMERON REP NOTICED ONE OF THE GLAND NUTS TO THE LOCK DOWN SCREWS IS STRIPPED OUT - WSL NOTIFY ODE AND DISCUSS PLAN FORWARD, ODE NOTIFY WSUP AND ETL TO DISCUSS PLAN FORWARD SIMOPS: - MAKE UP STANDS OF 4" DP IN OFFLINE STAND BUILDING EQUIPMENT Printed 1/28/2019 11:22:19AM **All depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Common Well Name 07-25 APE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 1/1/2019 End Dale'. %3 -0197G -C'. (4,996,677.00 ) Pmlect: PBU — — - ---Site Rig Name/Nc.: PARKER 272 Spud Date/Time: 4/13/1983 12:00:OOAM Rig Release: 1/24/2019 Page 4 19$3 Rig Contractor: PARKER DRILLING CO, BPUOI: USA00000904 Active datum: P272 KB @73.84usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) _ 1/5/2019 00:00 - 03:00 3.00 STCTPL N 6.84 DECOMP DEVELOP PLAN FORWARD WITH ODE, WSUP, AND ETL TO CHANGE OUT THE LOCK DOWN SCREW SIMOPS: MAKE UP STANDS OF 4" DP IN OFFLINE STAND BUILDING EUQIPMENT _ 03:00 - 03:30 0.50 STCTPL P 6.84 DECOMP PRESSURE TEST THE TUBING HANGER AND TWC FROM BELOW TO 500 PSI FOR 5 MIN (GOOD TEST) -TEST APPROVED BY WSUP 03:30 - 05:30 2.00 STCTPL P 6.84 DECOMP CAMERON REP ON LOCATION TO REPAIR TUBING HEAD - BARRIERS WHILE CHANGING OUT LOCK DOWN SCREW: KWF MONITORED THR UGH CONTINUOUS HOLE FILL THROUGH IA VALVES, TESTED TUBING HANGER WITH TWC INSTALLED - PULL STRIPPED LOCK DOWN SCREW FROM TUBING HEAD - CHASE THREADS IN TUBING HEAD WITH THREAD TAP TO CLEAN OUT DEBRIS FROM STRIPPED LOCK DOWN SCREW REPLACE LOCK DOWN SCREW - RUN IN LOCK DOWN SCREW ON TUBING HANGER AND TORQUE TO SPEC SIMOPS: MAKE UP STANDS OF 4" DP IN OFFLINE __STAN D BUILDING EUQIPMENT 05:30 - 06:30 1.00 STCTPL P 6.84 DECOMP PRESSURE TEST THE TUBING HEADLOCK DOWN SCREWS RUN IN REPLACED LOCK DOWN SCREW ON HANGER - TEST LOCK DOWN SCREWS TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MIN EACH 06:30 - 08:30 2.00 STCTPL P 6.84 DECOMP LAY DOWN TUBING HANGER - BACK OUT LOCK DOWN SCREWS - LAY DOWN TUBING HANGER - INSTALL WEAR BUSHING (8-7/8" ID) - LAY DOWN LANDING JOINT _ 0830 - 0900 0.50 STCTPL P 6.84 DECOMP CLEAN AND CLEAR RIG FLOOR 0900 - 16:00 7.00 EVAL P 1-6.84 DECOMP RUN IN THE HOLE WITH BAKER TEST PACKER ASSEMBLY TO SET DEPTH AT 5550' MD - RUN IN THE HOLE WITH 37 STANDS THEN SINGLE IN THE HOLE TO SET DEPTH - PU 1_14 KL_BS, SO 113 KLBS AT 5550' MD 16:00 - 19:00 3.00 EVAL P 6.84 DECOMP SET PACKER AND TEST 9-5/8" CASING FROM ABOVE TO 3500 PSI HIGH FOR 30 MIN (FAILED -'DISCUSS PLAN DECIDEH ODE, TO PULL UP THE HOWARD LE 00' AND ERFROMANOTHER PRESSURE TEST ✓✓✓✓✓✓HOLD D2 KICK WHILE DRILLING DRILL WITH AAR 19:00 - 19:30 0.50 EVAL P 6.84 DECOMP PULL UP THE HOLE 510' TO 5540' MD Printed 1/28/2019 11:22:19AM **All depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Common Well Name: 07-25 AFE No Event Type. RE-ENTER- ONSHORE (RON) Start Date. 111/2019 Enc Date: X3 -0197G -C: (4,996,677.00 ) Project: PBU Site: 07 Rig Name/No.: PARKER 272 Spud Date/rime: 4/13/1983 12:00 OOAM Rig Release: 1/24/2019 Page 5 606 1 Rig Contractor: PARKER DRILLING CO. Active datum: P272 KB @73.84usft (above Mean Sea Level) BPUOL USA00000904 Date From - To Him Task Code NET Total Depth Phase Description of Operations (hr) (usft) 19:30 - 23:00 3.50 EVAL --��" _ P 6.84 _LyryyryglP SET PACKER AND TEST 9-5/8" CASING FROM , '7�'f�r• • — ABOVE TO 3500 PSI HIGH FOR 30.MIN _(FAILED ® TEST) --BCEEQOPF PRESSURE AND BREAKOUT OF TOPDRIVE - PRESSURE UP TO 3500 PSI AND OBSERVE ` FLOW UP THE DRILLSTRING INDICATING THE y ( PACKER IS LEAKING - REVERSE CIRCULATE BRINE AT 3 BPM, 50 PSI FOR 10 MIN -RESET PACKER AND TEST 9-5/8" CASING � G FROM ABOVE TO 3500 PSI HIGH FOR 30 MIN (PASSING TEST) 0 - PROVED BY WSUP 0.� IY DISCUSS PLAN FORWARD WITH ODE AND WSUP, DECIDE TO USE PRESSURE TEST FROM 5040' MD, PULL OUT OF THE HOLE AND PICK UP 8 -1/2" -CLEANOUT BHA 23.00 - 00:00 1.00 EVAL P 6.84 DECOMP PULL OUT OF THE HOLE WITH TEST PACKER FROM 5040'MD TO 4577'MD AT MIDNIGHT - MONITOR WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM (STATIC) -BLOW DOWN CHOKE AND KILL LINES 1/6/2019 00:00 - 03:00 3.00 EVAL P 6.84 DECOMP PULL OUT OF THE HOLE WITH THE TEST PACKER FROM 4577' MD TO SURFACE - THE TEST PACKER ELEMENT IN GOOD CONDITION WITH NO VISIBLE DAMAGE - OBSERVE PIECE OF TUBING HANGER RUBBER LAYING LOOSELY BEHIND THE DIES ON THE PACKER, UNSURE IF THE PIECE OF RUBBER CAME FROM DOWN HOLE OR IN THE WELLHEAD LAY DOWN TEST PACKER 03:00 - 04:30 1.50 CLEAN P 674.84 WEXIT MAKE UP 8-1/2" CLEANOUT BHA TO TOTAL LENGTH OF 668' MD - 8-1/2" MILLTOOTH TRICONE BIT - SINGLE IN WITH 3 DRILL COLLARS WITH 2 STABILIZERS IN BETWEEN, AND 18 HWDP _ WBS: WEXIT_ _ 04'.30 - 0900 4.50 CLEAN P 6,800.84 WEXIT TRIP IN THE HOLE WITH 8-1/2" CLEANOUT BHA ON 4" DP FROM 668' MD TO THE TUBING STUB AT 6794' MD - FILL PIPE EVERY 20 STANDS _ - BRINE WEIGHT = 10 PPG IN/OUT 09:00 - 10:30 1.50 CLEAN P 6,800.84 WEXIT DISPLACE 10 PPG BRINE WITH 10 PPG MILLING FLUID - 330 GPM, 736 PSI - PUMP 40 BSL HIGH VIS SPACER - MONITOR WELL FOR 10 MIN AFTER DISPLACEMENT (STATIC) 1030 - 1500 4.50 CLEAN P 6,800.84 WEXIT PULL OUT OF THE HOLE ON ELEVATORS FROM 6794' MD TO THE TOP OF THE BHAAT 668' MD - MONITOR WELLAT THE TOP OF THE BHA (STATIC) - PU 155 KLBS, SO 142 KLBS AT 6794' MD - MUD WEIGHT = 10 PPG IN/OUT - PERFORM Di KICK WHILE TRIPPING DRILL, Printed 1/28/2019 11:22:19AM •'A8 depths reported in Drillers Depths— Printed 1/2812019 11.22:19AM **All depths reported in Drillers Depths" North America - ALASKA - BP Page 6 ali B Operation Summary Report Common Well Name'. 07-25 AFE No Event Type: RE -ENTER -ONSHORE (RON) Start Date: 1/1/2019 End Date. X3 -0197G -C'. (4,996,677.00 ) Project: PBU Site: 07 Rig NamPJNo.: PARKER 272 Spud Date(Time: 4/13/1983 12:00:OOAM Rig Release: 1/24/2019 Rig Contractor: PARKER DRILLING CO. BPUO1: USA00000904 Active datum: P272 KB @73.84usft (above Mean Sea Level) Date From - To HIM Task Code NPT Total Depth Phase Description of Operations (hr) _ _ _(usft) 1500 - 1800 3.00 CLEAN P 6,800.84 WEXIT STAND BACK THE CLEANOUT BHA FROM 666' MD TO SURFACE 18:00 - 21:30 3.50 CLEAN P 6,800.84 WEXIT MAKE UP 9-5/8" WHIPSTOCKAND MILLING BHA TO TOTAL LENGTH OF 956'MO '- FUNCTION TEST MWD AND SCRIBE MILLS PRIOR TO PICKING UP WHIPSTOCK 2130 - 00:00 2.50 CLEAN P 6,800.64 WEXIT RUN IN THE HOLE WITH THE WHIPSTOCK AND MILLING ASSEMBLY ON 4" DP FROM 956' MD TO 3614' MDAT MIDNIGHT - RUN IN THE HOLEAT 2 MIN/STAND PER SLB REP 117/2019 0000 - 0200 2.00 STWHIP P 6,800.84 WEXIT RUN IN THE HOLE WITH THE WHIPSTOCK AND MILLING ASSEMBLY ON 4" DP FROM 3614' MD TO THE TOP OF THE TUBING STUB AT 6794' MD - RUN IN THE HOLE AT 2 MIN/STAND PER SLB :REP _ 0200'. - 0300 1.00 STWHIP P 6,800.84 WEXIT ORIENTAND SET WHIPSTOCK - ORIENT WHIPSTOCK 7O 28.37' RIGHT OF HIGHSIDE -SET DOWN 10 KLBS ON WHIPSTOCK TO TRIPANCHOR - PICK UP T AND SETANCHOR - TOP OF WHIPSTOCK SETAT 6744'MD, BOTTOM OF SLIDE AT 6778' MD (}moi 03:00 - 12:30 9.50 STWHIP P 6,804.84 WEXIT KICKOFF"B" SIDETRACKAND MILL B -1/2"X i 4'11UI 9-5/8" WINDOW FROM 6764' MD TOP OF 01 Z5 t3 WINDOWTO 6778'MD*201OF NEW l FORMATION TO 6798' MD - 500 GPM, 1675 PSI, 100 RPM, 6-10/6 KFT-LBS TRQ ON/OFF BTM - MW IN/OUT = 10 PPG -SND, NO LOSSES - NO CEMENT OBSERVED BEHIND 9-5/8" CASING, NO PRESSURE OBSERVED ON OA 1 CLOSE MANUAL VALVES ON MUD CROSS 12:30 - 13:00 0.50 DRILL P 6,804.84 INT1 CIRCULATE HOLE CLEAN - 500 GPM, 1700 PSI - VERIFY 10 PPG MUD WEIGHT IN/OUT WBS: INTI 1300 - 1330 0.50 DRILL P 6,804.84 1 INT1 RIG UP AND PERFORM FIT - PULL MILLS TO TOP OF THE WINDOWAT 6764' MD - MUD WEIGHT: 10 PPG, 4780' TVD, 5000' MD - PRESSURE UP TO 531 PSI ON SURFACE - FIT EMW = 12.1 PPG - KICK TOLERANCE 25 WITH EMW >12.1 PPG - FIT APPROVED BY ODE 13.30 - 1730 4.00 DRILL P 6,804.84 INTI PULL OUT OF THE HOLE FROM THE TOP OF THE WINDOW AT 6764' MD TO THE TOP OF THE BHAAT 956' MD - MONITOR WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM (STATIC) - MUD WEIGHT 10 PPG IN/OUT - CORRECT DISPLACEMENT ON TRIP Printed 1/2812019 11.22:19AM **All depths reported in Drillers Depths" Common Well Name. 07-25 Event Type: RE-ENTER- ONSHORE (RON) Project: PBU - --- Rig Name/No.: PARKER 272 North America - ALASKA - BP Operation Summary Report Start Date. 1/1/2019 End Date: Site: 07 — Spud DateTrlle: 4/13/1983 12:00:OOAM Active datum: P272 KB @73.84usft (above Mean Sea Level) Date From - To Hrs Task Code (hr) 17:30 - 19:30 2.00 DRILL P 19.30 - 2000 0.50 DRILL P 2000 - 2330 3.50 DRILL P 23:30 - 00:00 0.50 DRILL P 1/8/2019 0000 - 03:00 3.00 DRILL P 4.00 0300 - 0700 4.00 DRILL P 0700 - 08:00 1.00 DRILL P 0800 - 1200 4.00 DRILL P 1200 - 14:00 2.00 DRILL P Page 7 OrM AFE No K3 -0197G -C:(4,996,677.00) BPUOI: USA00000SO4 NET Total Depth Phase Description of Operations (usft) 6,804.84 INTI RACK BACK THE HWDP AND LAY DOWN THE BHA FROM 956' MD TO SURFACE - MONITOR WELL PRIOR TO PULLING THE BHA INTO THE BOP STACK FOR 10 MIN (STATIC) -STARTER MILL- 1/8" UNDER, FOLLOW MILL - 1/16' UNDER, DRESS MILL- IN GAGE 6,804.84 INTI FLUSH THE BOP STACK WITH JETTING TOOL - OPEN MANUAL CHOKE AND KILL LINE VALVES 6,804.84 INTI MAKE UP THE B-1/2"X9-1/2"INTERMEDIATE 'DRILLING BHATO TOTAL LENGTH OF 855' MO .-8-V2" X 9-1/2" BI -CENTER BIT, 1.5-AKO MUD MOTOR, MWD/LWD (GAM/RES/PRESNSS/SURVEY) --SURFACE TEST MWD, (GOOD) 6,804.84 INTI : RUN IN THE HOLE WITH 9-1/2" INTERMEDIATE DRILLING BHA ON 4" DP FROM 855' MD TO __ ,I _ 1140'MDAT MIDNIGHT 6,798.00 INTI RUN IN THE HOLE WITH 8-1/2" X 9-1/2" INTERMEDIATE DRILLING BHA ON 4" DP FROM 1140'_MD TO BOTTOM AT 6798' MD_ 7,015.00 INTI : DIRECTIONAL DRILL THE 8-1/2" X 9-1/2" INTERMEDIATE HOLE FROM 6798' MD TO 7015' MD (217' IN 5 HRS = 43 FPH WITH CONNECTIONS). -INSTANTANEOUS ROP: 80 - 120 FPH SLIDING, 125 FPH ROTATING - 600 GPM, 2600/2500 PSI ON/OFF BOTTOM, 50 RPM, 6/5 KFT-LBS TRQ ON/OFF BTM, UP TO 5 KLBS WOB - MW IN/OUT = 10 PPG, NO LOSSES DRILLING AHEAD -ECD CLEANHOLE= 10.59 PPG, ACTUAL= 10.59 PPG, HARDLINE = 11.9 PPG - GASWATCH BACKGROUND RANGE =13 UNITS, MAX = 53 UNITS - NO BACKREAMING AT CONNECTIONS - SURVEY EVERY -90' - INC ON CHECKSHOTS INDICATE SIGNS OF TRACKING ORIGINAL WELLBORE, DECISION MADE TO PULL OUT OF THE HOLE AND DIAL MOTOR UP TO 1.9° AKO AND PICK UP TRIGONE FOR BETTER CONTROL 7,015.00 INTI CIRCULATE HOLE CLEAN - 600 GPM, 2700 PSI 7,015.00 INTI PULL OUT OF THE HOLE FROM 6647' MD TO THE TOP OF THE BHAAT 855' MD - MONITOR WELL FOR 10 MIN PRIOR TO PULLWG OFF BOTTOM (STATIC) - MUD WEIGHT 10 PPG IN/OUT 7,015.00 INTI RACK BACK HWDP FROM 855' MD TO 83' MD AND CHANGE OUT BHA COMPONENTS - MONITOR WELL FOR 10 MIN PRIOR TO PULLING BHA INTO BOP STACK (STATIC) -RACK BACK HWDP - CHANGE OUT THE BIT, MAKE UP 8-1/2" MILLTOOTH TRI -CONE - BI -CENTER BIT GRADE: 1-6-1/16 - LAY DOWN LOWER STABILIZER Printed 1/28/2019 11:22:19AM **All depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Common Well Name: 07-25 Event Type: RE-ENTER- ONSHORE (RON) Start Date'. 1/1/2019 End Date'. Project: PBU Site: 07 APE No K3 -0197G -C: (4,996,677.00 ) Page 6 of -n Rig Name/No.: PARKER 272 Spud Date rime: 4/13/1983 12:00:OOAM Rig Release: 1/24/2019 Rig Contractor. PARKER DRILLING CO. BPUOI: USA00000904 Active datum: P272 KB @73.84usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) _ (usft) _ 14:00 - 17:30 3.50 DRILL P 7,015.00 INTI TRIP IN THE HOLE WITH 8-1/2" KICK OFF BHA FROM 83' MD TO THE TOP OF THE WHIPSTOCK AT 6764' MD - SHALLOW HOLE TEST THE TOOLS AT 848' MD, 500 GPM, 990 PSI (GOOD TEST) 1730 - 18:30 1.00 DRILL P 7,015.00 INTI WASH DOWN FROM 6764' MD TO 7015' MD - ORIENT MOTOR TO 30° ROHS PRIOR TO ENTERINGWINDOW - OBSERVE 8700 UNITS OF GAS AT BOTTOMS UP, OBSERVE 3% LEL AT SHAKERS - MONITOR WELL (STATIC) - WSL MADE NOTIFICATIONS OF LEL .READINGS -COMPLETE BOTTOMS UPAT REDUCED RATE _ 18:30 - 00:00 5.50 DRILL P 7,015.00 INTI 'DIRECTIONAL DRILL 8-112" INTERMEDIATE HOLE FROM 7015' MD TO 7067' MD 100% SLIDE - 525 GPM, 2240/2530 PSI ON/OFF BOTTOM, UP TO 32 KLBS WOB - MW IN/OUT = 10 PPG, NO LOSSES DRILLING AHEAD -ECD CLEANHOLE= 10.59 PPG, ACTUAL= 10.59 PPG, HARDLINE = 11.9 PPG - GASWATCH BACKGROUND RANGE =200 UNITS, MAX = 1400 UNITS - OBSERVE HIGH GAS COUNTS ON GAS WATCH AND LEL IN THE SHAKERS FROM BOTTOMS UP EVERY TIME THE PUMPS ARE DOWN, DISCUSS WITH WSUP AND ODE, DECIDE TO PERFORM THE FIRST WEIGHT UP TO 10.2 PPG, NO ISSUES WITH GAS AFTER WEIGHTING UP - MOTOR STALLING AND HANGING UP FROM 7060' MD, WORK PIPE FREE FROM STALLAND RESET BIT EACH TIME, DISCUSS ISSUES WITH SR WSL, DECIDE TO CONTINUE TO WORK THE PIPE BACK TO BOTTOM AND _ATTEMPT TO DRILL _ _ 1/9/2019 00.00 - 06'.00 6.00 DRILL P 7,110.00 INTI DIRECTIONAL DRILL 8-112" INTERMEDIATE HOLE FROM 7067' MD TO 7110' MD -100% SLIDE - 525 GPM, 2240/2530 PSI ON/OFF BOTTOM, UP TO 32 KLBS WOB - MW IN/OUT = 10 PPG, NO LOSSES DRILLING AHEAD - ECD CLEANHOLE = 10.59 PPG, ACTUAL = 10.59 PPG, HARDLINE = 11.9 PPG - GASWATCH BACKGROUND RANGE =200 UNITS, MAX = 1400 UNITS - CONTINUE TO ENCOUNTER MOTOR STALLING WHILE DRILLING SECTION - SURVEY SHOWS NO INDICATION OF DEPARTURE FROM MOTHER WELLBORE, DISCUSS PLAN FORWARD WITH ODE, DECISION MADE TO PULL OUT OF THE HOLE AND PICK UPANOTHER WHIPSTOCK Printed 1/28/2019 11:22:19AM **All depths reported in Drillers Depths" Printed 1282019 11:22:19AM --All depths reported in Drillers Depths" North America - ALASKA - BP Page 9 oWS Operation Summary Report Comon Well Name: 07-25 m AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 1112019 Era Date X3 -0197G -C: (4,996,677,00) Project: PBU -— -- Site: 07 Rig Name/No.: PARKER 272 Spud Date/Time: 4/13/1983 12:00:OOAM Rig Release: 1/24/2019 Rig Contractor: PARKER DRILLING CO. _ - BPUOI: USA00000904 - Active datum: P272 KB @73.84usft (above Mean Sea Level) Date From - To Hm Task Code NPT Total Depth Phase Description of Operations (h1) (usft) '0:00-- 0700 1.00 DRILL N 7,110.00 INTI CIRCULATE HOLE CLEAN WITH 2X BOTTOMS UP - 525 GPM, 2250 PSI WORK PIPE 30' WHILE CIRCULATING 0700 - 1000 3.00 DRILL N 7,110.00 INTI _- PULL OUT OF THE HOLE FROM BOTTOM AT 7110' MD TO THE TOP OF THE BHAAT 848' MD - MONITOR WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM (STATIC) MUD_W_EIGHT 10.2 PPG IN/OUT _ 10:00 - 12:00 2.00 DRILL N 7,110.00 _ INTI _- PULL OUT OF THE HOLE LAYING DOWN THE BHA FROM 848' MD TO SURFACE '- MONITOR THE WELL FOR IO MIN PRIOR TO PULLING BHA INTO THE BOP STACK (STATIC) - RACK BACK THE HWDPAND LAY DOWN THE DIRECTIONAL TOOLS •-BITGRADE:1-1-1/16 _ 12:00 - 18:00 6.00 DRILL N 7,110.00 INTI MAKE UP 9-5/8"HYDRAULIC WHIPSTOCK BHA TO TOTAL LENGTH OF 971' MD - FUNCTION TEST THE MULTI CYCLE BYPASS VALVE PRIOR TO PICKING UP THE WHIPSTOCK - SCRIBE MILLS PRIOR TO PICKING UP WHIPSTOCK - SHALLOW HOLE TEST THE MWD WITH 525 GPM, 1705 PSI, FIRST CYCLE ON BYPASS VALVE 18:00 - 22:30 4.50 DRILL N 7,110.00 INTI RUN IN THE HOLE WITH THE 9-5/8" WHIPSTOCK ASSEMBLY FROM 971' MD TO 6625' MD (TOP OF WHIPSTOCK AT 6601' MD) - PU 173 KLBS, SO 154 KLBS AT 66.25' MD 2230 - 00:00 1.50 DRILL N 7,110.00 INT1 SETWHIPSTOCK -ORIENT WHIPSTOCK TO 79° - RUN PAST 6625' MD 10' AND PICK UP TO SET DEPTH - CYCLE BYPASS VALVE 4 MORE TIMES THEN PRESSURE UP TO 2000 PSI TO SET WHIPSTOCK - WORK PIPE UP AND DOWN STAGING UP WEIGHT FROM /- 10 KLBS TO+/ -40 KLBS, SET DOWN 50 KLBS TO SHEAR OFF WHIPSTOCK 1/10/2019 00.00 - 05:30 5.50 DRILL N 7,110.00 INTI KICK OFF "B" SIDETRACK AND MILL B -1/2"X 9-5/8" WINDOW FROM 8601' MD TOP OF WINDOW 706615' MD+ 10' OF NEW FORMATIONT 25' MD TO GET DRESS MILL N OU T OW - 460 GPM, 2600 PSI, 120 RPM, 6-12/6 KFT-LBS TRO ON/OFF BTM - MW IN/OUT = 10.2 PPG _SND, NO LOSSES - NO CEMENT OBSERVED BEHIND 9-5/e" CASING, NO PRESSURE OBSERVED ON OA - CLOSE MANUAL VALVES ON MUD CROSS - REAM THROUGH WINDOW WITH MILLS TO DRESS OFF WINDOW_ 05.30 - 07:30 2.00 DRILL N 7,110.00 INTI CIRCULATE HOLE CLEAN - 460 GPM, 2550 PSI 07:30 - 08:00 0.50 DRILL N 7,110.00 INTI RIG SERVICE 08:00 - 12:00 4.00 DRILL N 7,110.00 INT1 LUBE PUMP ON TOP DRIVE SYSTEM FAILED - REPAIR LUBE PUMP - MONITOR WELL WITH CONTINUOUS HOLE FILL Printed 1282019 11:22:19AM --All depths reported in Drillers Depths" TREE= , 5-1/8• GREY Hf3AD= GRAY ACRIATOR= AAKERC OKB. ELEV = 5T OF. E -EV = OprJSqz KOP= 2900 M4x Angle = 95' @ 10223' Datum MD= 9481' Datum T'VD= 8800 SS WIN SAFETY NOTES: WELL ANGLE> 70 @ 9715''•' 07-25A MAX DOGLEG: 44.6" @ 9558' 133/8' CSG. 720, L-80 BTC, D=12.347^ I� z6z7• _ I6601' Minimum ID = 121" @ 9114' 2.26" "A SEAL ASSY IN KB LTP 6764 IET cur TBG (11/o2r1 a) 6776 3-12' LNR - 19-5/B• WHFSTOCK (01/1(V19) I PUNCH, a SPF (latarla) I 86:88648-BKR Fill LOG: SLB ME ON 04117/04 ANGLEAT TOP Ff3iF:93'@10610* Nato: %far to Reduction 013 for historical perf data SIZE SPF INTERVAL OprJSqz SHOT SQZ 1-11/16" 6 10610-10910 G-22 LOCATOR SUB, D70, L-80.0232 bpf, D = 4.892"8666' I 10/18/17 JGIJMD SETEV0-TREVEPLUG(10/15117) 5-1/2' BKRSBE ASSFdMBLY, [8669' 7-5/8^ MLL OUT l7RBNSION ID70POF 7^ LNR 8676' 7-5/8'X4-1/2^ XO. D = 3.948' VO-TREVE PLUG(10115117) 8726' 8715 9-5/8'X 7'BROVMI'f�KSLV w / SHORTY HYD HGR D = 7 4-12- TBG -FC, 12.60, L-80 BTC AB- MOD, .0152 but. D = 3.958" LSX WHPSTOCK TRAY (03/31/04) r 9 39. L-110. 0076 hof_ D = 2.79' 7' ARY PERFORATDN SLIMMARY Fill LOG: SLB ME ON 04117/04 ANGLEAT TOP Ff3iF:93'@10610* Nato: %far to Reduction 013 for historical perf data SIZE SPF INTERVAL OprJSqz SHOT SQZ 1-11/16" 6 10610-10910 C I 8776• 4-12'vmr.,0=3.958^ BEHIND CT LNR 877Y B-MDTTL0GG®06n3/90 9093' 3-V2' HES EZ DRLL SV B SOZ PKR (CBP) (09/05/17) 9108' 35 KB LTP, D - 1.81' (08124/14) MLLOUT WNDOW (07-25A) 9376' - 9384' 2-3/8" LW 4.6#, L-80 STL, H 10952- .0036 bpf, D= 1.920' 1 �m PRLCHOE BAY (NT WELL: 07-25A PEIWT Kb: 12040520 API No: 50-029-20938-01 SEC 33, T11N, R14E� 1751' FNL & 270' FEL DATE PEV BY COMMENTS DATE REV BY COMMENTS 04f29183 PKR 176 ORIGINAL COM PLEnON 10117118 CJNVJMD STA #7 NECK STTRIFP® & #8 KILL PROM 04/18104 KAK CTDSIDETRACK(07-25A) 10117/18 MS/JM[) 5.12' TBG PUNCH(1(W14/18) 0825114 PJC REFORMMT WBS 10129/18 JJUJM) TBG & IA BALANCE PLUG (102x18) 05/15/17 JCF/JMD SET CBP(05112117) 10/29/18 GIB/JGLV CIO (10/24118) 09/06117WGV GLVCIO&SETCBP(09/05/17) 11105/18 BTNfJ JETCUTTBG(11/02118) BP Exploration (Alaska) 10/18/17 JGIJMD SETEV0-TREVEPLUG(10/15117) • • 2-04-Ob/2- 291 o\3 WELL LOG TRANSMITTAL #904388809 To: Alaska Oil and Gas Conservation Comm. January 17, 2018 Attn.: Makana Bender RECEIVED 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 FEB 01 2018 DATA LOGGED 2./Y/201% M.K.BENDER RE: Leak Detect Log with ACX: 07-25A AOGCC Run Date: 10/28/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 07-25A Digital Log Image files 1 CD Rom 50-029-20938-01 Leak Detection Log 1 Color Log 50-029-20938-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. SCANNED 1 Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com&AKGDMINTERNAL@bp.com Date: Signed:M/442~-4) �N:� 2_04-05-2, • WELL LOG TRANSMITTAL#904029305 2'(6-35S To: Alaska Oil and Gas Conservation Comm. July 3, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED DATA LOGGED JUL O 1 2017 ""I AO/2011 RE: Coil Flag Log: 07-25A M.K.BENDER Run Date:5/11/2017 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari,Halliburton Wireline &Perforating, 6900 Arctic Blvd.,Anchorage,AK 99518 07-25A Digital Data(LAS), Digital Log file(Field Data) 1 CD Rom 50-029-20938-01 Coil Flag Log(Field Print) 1 Color Log 50-029-20938-01 SCANNED JUL 1 72014 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:/ ' ✓aLk.1• a.., / `eA"_"_C ' • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: SL1---C 16/ 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 204-052 3. Address: P.O.Box 196612 Anchorage, Development ® Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20938-01-00 7. Property Designation(Lease Number): ADL 0028309 8. Well Name and Number: PBU 07-25A 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: 1,�° ED Total Depth: measured 10952 feet Plugs measured 10549 feet !'i V 1 2 �/ true vertical 9013 feet Junk measured 10903 feet J U2017 Effective Depth: measured 10549 feet Packer measured 8655 feet true vertical 9007 feet Packer true vertical 8154.21 feet C Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 31-111 31-111 1490 470 Surface 2497 13-3/8"72#L-80 31 -2528 31 -2528 4930 2670 Intermediate 8979 9-5/8"47#L-80 28-9007 28-8462 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10610 10910 feet 9515-9516 feet SCANNED J U L 2 42017, True vertical depth: 9006-9008 feet feet 8817.08-8817.54 Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 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: 227 25946 94 550 796 Subsequent to operation: 225 26286 16 550 1499 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development m Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ 0 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: Vohra,Prachi Contact Name: Vohra,Prachi Authorized Title: Production Enqr Contact Email: Prachi.Vohra@bp.com Authorized Signature: ( s ---_ -- Date: ‘1 j al 2_0 I,1- Contact Phone: +1 9075644677 � Form 10-404 Revised 04/2017 177-L—9717P 10,7 RBDMS u'/ JUN 1 4 2017 Submit Original Only • • • Alaska Oil and Gas Conservation Commission 333 West Seventh AvenueneCEI Anchorage, AK 99501-3572 g VED JUN 12 ?017 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary June 9, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Plug above the Perforations for Well 07-25A, PTD # 204-052. 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 • • m ao00003 000 Rt` ((DDNsC)CAD CV COV � N 'Cf CO r 0 y 0 0 0 0 c) 0 0 iCAMN` CO Tr 01 TtO) OD rN- Tr 'TN QD OD Ns OD O N M N O N O OD — t• CO N▪ COCoO) Oao co 'r N ✓ r co O Lo CO N- Cr) M N N LO N T- O CO Co CO r` co (N (o N O t` O (O N LO O M O CO t` = N co CD OD O sea LOQ Q N • TO � �- COti M M N I i- N CO = O O O 00 a o g o c) Q� I• J J OD J J 'J = d4t 04 J A # (0 CO) N f/•) • - CD 53 i3c)U M N - N N O . to ti Mr N 0M- CA N U) C▪)00r0M � 0 C O N OOD O Co O J W � Q c •; 0U W (a Q 0 0 00u_ WreceZZ ZceLuLUEE Z ZDD �UCO ZJJ1- I- • • Packers and SSV's Attachment PBU 07-25A SW Name Type MD TVD Depscription 07-25A TBG PACKER 8655 8154.21 7-5/8" FB-1 Perm Packer 07-25A PACKER 9104.8 8546.28 KB Liner Top Packer • • b tth mm to k 0 c0 Ci RAE - . 0 R E � 2 § ¥ _ / $ / - / o_ ' / 0 co ff ® $ 2 E o k ch � nn2o 2 2 & a , as = 2 0 2 § ? # 2 � 2J o / � / E 7� \ $ Fn" _ = a ± -I \ E » e @ z � I- z kkk : 2 i 2 o _, W 0 - - 0 2 o >- = % / w \ w ± : I t(NI O 0 ca ® o e mE 2 e , � / �� m0 22 : / fc :E / k -- t 2 0 0 O as as ¥ � O f ® 0 Q / 2 ƒ ■ & b n < 4 « 3 a ■ o a) 8 _ � a .3 ( 2 0 1 = R 2 ¢ a) » ° ƒ @ � ® 2 ca f.--) Xc ® � o 03 -, m © & ate o %k0 : / \ LI b k > � $ 77702k o 't � E � � - = ƒ � 7 % § I � kw % ' 03 \wD � « 22 / 2 & g 4= 2 / fI0 0. .ix � to cc 63w < < 0_ 0 7 / -0 2 $ \ CL : ƒ 0 k Y 0 / 2 : § § S 7 = ._j 1/4_, / 0 �/ Ce b_ _am / 0m_ � / � � . a. co 10 C3 ƒ 2 0 co E M / i / - ° m a) 0 c k - o- k . / � R Ok � z Id / 2 / 2 0 � �i 0 2 0 & O G O L = •■ 2 ° - •a — ® o $ - O _ a)- 9 > @ @ > - ' � 6 & Z Q m E 6 ' ° % O R § E co _1 .in 00 k . 1- -J o) 0 •ca % al� a) 780 2 k < i / / aCe / 0 / � - � k / 22omk k $ | F- : : 0_ 20 : Z O k % : 0 , 2 _j . q : O 2 & r- 0 c c ¥ - E. d d 2 — c > « 2 CO \ — \ \ « 7REE= f 5-118"GREY _ WL3..L.F1`AD= GRAY ACTUATOR= BAKER C 07-25A MAX DOGLEG:44.6°la855N8' GL E>70 9715' rr OKB.ELEV= 57' BE ELEV= I 2187' H5-1/2-CAMCO BAL-O SSSV NP,D=4.562" KOP= 2900' Max Angle= 95 @ 10223' --"AOR. H ? 0 Datum MD= 9481' _#. , Datum TVD= 8800'SS D= GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE 13-3/8"CSG,72#,L-80 BTC, D=12.347" H 2527' 1 2889 2887 9 MG OW RK 0 04/20/09 2 4513 4384 25 MMG DMY FE 0 04/20/09 3 5686 5456 24 MIG 'DMY RK 0 06/02/89 4 6815 6482 23 MAG DMY RK 0 06/02/89 Minimum ID = 1.81" 9114' 5 7752 7337 24 MAG DMY RK 0 06/0289 2.26"AVA SEAL ASSY IN KB LTP 6 8255 7795 25 MNG DMY RK 0 06/02/89 7 8520 8034 27 MAG 'DMY RK 0 06/0289 8 8589 8095 27 MAG DMY FE 0 06/0289 STA'S#3=ASHAVG NECK STRIP/®OFF 02/11/94 8654' H BKR G-22 LOCATOR SUB,D=4.875" ��t 8655' .--9-5/8"X "BKR FB-1 PERAA PKR D=6.00" 5-112"TBG,17#,L 80,.0232 bpf,D=4.892"--I 8654' 8668' 5-1/2"BKR SBE ASSEMBLY,D=6.00" 8669' N7-5/8"ALL OUT EXTENSION D=6.625" ` 8675' I--17-5/8"X 4-1/2'XO,D=3.948" TOP OF 7"LNR H 8715' J 8715' 19-5/8-X r BROWN TRK SLV w/SHORTY HY D HGR,D=? TOP OF 3-1/2"LNR-CT W74-1/2"G LANDNG SUB H 8760' ' 8762' --14-1/2"OTIS XN NP,13=3.725' 4-1/2"TBG PC,12.6#,L-80 BTC AB MOD, J 8775' ♦ BEHIND 1 8775 H4-1/2-WLEG,D=3.958" CT LNR .0152 bpf,D=3.958" 8772' H E3.ND TT LOGGED 06/13/90 fl 8998' -jTOP OF Cat.IT(PIM 12/95 CBL) 9-5/8"CSG,47#,L-80 BT&C D=8.681' H9006' J • 11 �: . • �i ♦, ♦! 11I,_ ,_� 9108'e. --1 35 KB LIRD=1.81'(08/24/14) 4.1 I" "e'' 9114' --12.625'BKR DEPLOY SLV,D=2.250" •3-1/'2"LSX WHPSTOCK TRAY(03/31/04) H 9381' .I1 '•♦4 4/4 %i 3-1/2-LNR-CT,9.311,L-80,.0076 bpf,D=2.79" ,..9 1/,1, 4 MLLOUT WNDOW(07-25A) 9376'-9384' 7` 29#,L-80 BTC,.0371bpf,D=6.184" I\�1�% '�♦ LNR —{ ~9384 '*�,�� �♦♦i Al� ! 10550' —2-3/8"WFT CBP(05/12/17) PERFORATION SUMMARY REF LOG:SLB MCNL ON 04/17/04 /r ANGLE AT TOP PERF:93"@ 10610' Note:Refer to Production DB for historical perf data SIZE SPF IITERVAL Opn/Sqz SHOT SOZ I4.4.4.4.4.4.4 10903'CTM FISH:Pa..L8) 1-11/16' 6 10610-10910 C 04/17/04 MAGNUM CBP REM 1091 {11!12!15} a. 2-318"LM 4.6#,L-80 STL, H 10952' ! r r .0036 bpf,ICI=1.920" DATE REV BY COI/RENTS DATE REV BY COMMENTS FRUDHOE BAY UNIT 04/28183 PKR 176 ORIGINAL COMPLETION 12/07/15 CS/JMD MLLED CBP WELL: 07-25A 04/18!04 KAK CTD SIDETRACK(07-25A) 12/07/15 DLHI C SET DRIyAMCATCFU (12/06/15) PEZMF No:"2040520 0824/144AGS/PJC SET 35 KB LTP(08/21/14) 12/31/15 SWC/JMC RESET DREAMCATC B2(12/27/15) AR No: 50-029-20938-01 08/25/14 MGS/PJC FULU REST KB LTP(08/24/14) 11/07/16 CJPYJND PILLED DREAMCATC (11/05/16) SEC 33,T11N,R14E,1751'RC&270'FEL. 08/25/14 PJC FORMAT WB S 05/15/17 JC F/JMD SET CBP(05/12/17) 03/03/15 FM'PJC FERFNCEI GLV UPDATES BP Exploration(Alaska) STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well Q Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 204-052 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20938-01-00 7. Property Designation(Lease Number): ADL 0028309 8. Well Name and Number: PBU 07-25A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 10952 feet Plugs measured 10903 feet true vertical 9013 feet Junk measured feet DEC 31 2015 Effective Depth: measured 2165 feet Packer measured 8655 feet true vertical 2165 feet Packer true vertical 8154.21 feet A ®.r1 CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 31 -111 31-111 1490 470 Surface 2497 13-3/8"72#L-80 31 -2528 31-2528 4930 2670 Intermediate 8979 9-5/8"47#L-80 28-9007 28-8462 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10610-10910 feet �q True vertical depth: 9006 9008 feet �L's��cEsj .,,-i-,0 - 4 101 Tubing(size,grade,measured and true vertical depth) See Attachment & See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9113'-9585'. Treatment descriptions including volumes used and final pressure: 96 Bbls 60/40 Methanol/Water,200 Bbls Diesel,48 Bbls Fresh Water,16 Bbls 14 ppg SqueezeCrete,45 Bbls PowerVis,283 Slick 1%KCL,2840 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 228 36331 66 550 973 Subsequent to operation: Shut In 920 20 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 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: 315-299 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer SignatureSignature "ila4.7Phone +1 907 564 4424 Date 12/31/15 Form 10-404 Revised 5/2015 i/7-/- ///3/ii A b,' . J(ARBDMS JAN 0 5 201�bmit Original Only • • Q 0 0 0 0 0 � N- CO N Co co - CO N CO O N O U y co 0 0 c c i 6) co 1- CO O M 3 V O) CO N CO r- 'Cr CO CO N- CO CONCOCONO N O CO N- CC) V CY) O c- N OO 00 0) 00 C70 H CO Cr N x- 00 O LO O N- CO CO N N Cn N x- 00 CO CO C W CO ti r N Cf) L[) N O O Cr) N- ti O 0 CO N- N N = N CA CT CO 00 V p co Q2 Lo QN r co - - co N. co CO N CO N CO _ o M Q. Ocoa O O O co c) co O 00 co i = J J co J J . U) N_ � ti N• °_° COCD V- Ct) NMN 7 ? Lr) N-- N N M O) t N L .0 N- CS) COO) 0)O CD M co O co V 0) 9 Co co O JN CO - '- CO w H Ca ' U W W U 0 u_cc E (DO ZWUJW O D H z z_ D U (OZJJHH • • • Packers and SSV's Attachment PBU 07-25A SW Name Type MD TVD Depscription 07-25A TBG PACKER 8655 8154.21 5-1/2" Baker FB-1 Packer 07-25A PACKER 9108 8549.04 KB Liner Top Packer 0 • • oc G° H - / \ g CO c co / � \ / m / 2 2 Z E D — o + _1 2 = c m 7 b o d / o . / o / I / Csi 2 = 6 _ 22 / w / / / \ R k£ / ® in\ 0\ � $ ¥ I E ID\ 0 + E c . > co £ ch 0 / 2 o c , / ■ / Z u mtt o C F.- O &/ E / o > G 0 % o e 2 e CU < Z LU ® a ) / _ % / / 0 ¢ 0) / - / \ \ / k 0 ID' CNI Z 2 « o / // / I ' a) w 0 % 2 / CO14- • ƒ ° 5 CSo o M \ / Z / \ m >"` U)m � v- - t ; . e = « -o / / 2 \ \ \ \ > — c r / $ 2 E ' % E W \ 2 - < \ < _ 2 § f \ § \ ® � � og2 ƒ � iii � 2 ® ° a # ° . 2 < ® 6 O < u I •7 e 5 7 - \ o 7 co ± z EZU ± IO0 q \ 5 ® ± N- � a CI < / h 2 / ƒ ± R 2 / 1 ( R I 0 - > R % O 222 � L » = E Gs Ca O m / rm D , ® i - / D / / .c r E E �\ C - EE — A — I O ± R 2@ A 71 @ o 0 E ° @ o 0 2 / % 2 m — 9 0 = / 0 0 >3 U t / / § U / _1 # $ \ _j 6 2 ¥ I — Q m . o \ 6 e ® _ .c \ b e a < — m 6 & = 5 § o .» I y m .» I L I R L E < > 2 _i -I E II ° ® t # » U o k » * / \ — ƒ < Z 47 2 0 ._ 030 .\- 7 ? O = e / t m 0 « i R 2 ¢ E i i= ° 44:5 -0002081 0 0 & E < r r n r r ® CV rd d / \ R r CO /_ \$ CO e \ < • 0 \ E g 2 ƒ • , < / q = e ± aO . e § 2K § o CU 2 2 O oto o1. Tii . E ) f >) c _ 2 § q �f777 2 ® e £ - ± o § / k .§ L_ \ o E E co E k > / c � ce � _ ok � ocd � � U0 b o G- o c o ® _ E 1 / § \ E E $ O ® O 6 c c S 2 O / E \ k / I / % 2 a , A = S ± , o 2 _ , - ,- a = C - e * .i .g $ t f I U) a) 5 t 7 - e $ 0 � ƒ / .\ m - :0 MI \ .2•f \ § \ o a. e = o E 7 E \ / .0 f \ ID \ 0_/ / 2 .m10 c1-5 / 6 ITD CN 0 3 2 ƒ \ / / / 0 g" 9 y - m _e ° - o w ± _ i 22 _§ f t o - S $ a, // \/ - k t Ca 7 / \k o (D o o \ @ $ o m E 7 P § 2 % @ _ ,- m a W c 6 \ / 1 \ E E 2 I \ > / / / = R ' 2 = am &- o CN m cc ' ¥ c# o m a RS 0 0 / k 9 f / E / ) Es i 0 ® 0 E \ k E ® 0- c a m c/ _� 7 / E = U E / g 1 e m = o E 3 / / 2 R / c U a E . o_ a) § A \ & 7O .§ c$ G � a2 / 2 / CO n c m f = 0 e * \ \ o.-I e � .. g -8 D / Cr) / •& n o * \ 0 O : E o I .- -2 c o 2 i _I LO r 77 / / \ / R4±l- 5-1/8"GREY WELLHEAD= GRAY_ SA NOTES: WELL ANGLE>70 @ 9715'*'* ACTUATOR'- BAKER C MAX DOGLEG:44.6°@ 9558' OKB.EIEV= 57' BE ELEV= I I 2187' H5-1/2"CAMCO BAL-O SSSV NP,ID=4.562" KOP= 2900' Max Angle= 950 @ 10223' —"AOR. H ? ^M I 2187' —5-1/2"DREAMCATC-ER(12/06/15) Datum MD= 9481' N#, , Datum TVD= 8800'SS D= GAS LSI MAM)REI.S ST kV TVD DEV TYPE VLV LATCH FORT DATE 13-3/8"CSG,72#,L-80 BTC, D=12.347" --I 2527' 1 2889 2887 9 MIG 13-MY RK 0 04/20/09 2 4513 4384 25 MMG DMY RK 0 04/20/09 3 5686 5456 24 MIG "DMY RK 0 06/0289 4 6815 6482 23 MAG DMY FE 0 06/02/89 Minimum ID = 1.81" @ 9114' I LI 5 7752 7337 24 MMG DMY RK 0 06/02/89 2.26" AVA SEAL ASSY IN KB LTP 1 6 8255 7795 25 MMG DMY RK 0 06/02/89 7 8520 8034 27 MNG 'UMY RK 0 06/02/89 8 8589 8095 27 MIG DMY RK 0 06/02/89 STA'S#3=FLSHING PECK STRPPED OFF 02/11/94 8654' {—BKR G-22 LOCATOR SUB,D=4.875" 8655' ._9-5/8"X_"BKR FB-1 PERM PKR,D=6.00" 5-112"TBG,17#,L-80,.0232 bpf,D=4.892"—I 8654' • 1 8658' —5-1/2"BKR SBE ASSEMBLY,D=6.00' J 8669' —17-5/8"PALL OUT EXTENSION ID=6.625' 8675'1—7-5/8"X 4-1/2"XO,D=3.948" TOP OF 7"LNR — 8715' —1... 8715' —9-5/8"X 7"BROWN TEJ3K SLV (TOP OF 3-1/2"LNR-CT W/4-1/2"G LANDING SUB H 8760' w/SHORTY HYD HGR,D=? 8762' —{4-1/2"076 XN NP,D=3.725" 4-1/2"TBG PC,12.6#,L-80 BTC AB MOO, — 8775' BEHIND 8775'j--14-1/2"WLEG,ID=3.958" CT LNR .0152 bpf,ID=3.958" 8772' H ELMD TT LOGGED 06/13/90 VI ••- 8998' --j TOP OF CEMNT(PER 12/95 CBL) ,. IV 9-5/8"CSG,47#,L-80 BT&C,D •=8.681" --1 9006' • .1 /• *'t_• q�. . 9108' —{35 KB LTP,D=1.81"(08/24/14) �I • i i or 9114' H2.625"BKR DEPLOY SLV,D=2.250" V I 3-1/*2"LSX WHPSTOCK TRAY(03/31/04) — 9381' — '� • 3-1/2'LNR-CT,9.3#,L-80,.0076 bpf,D=2.79" —j —9384 t•'!. MILLOUT WINDOW(07-25A) 9376'-9384' 7"LNR,29#,L-80 BTC,.0371 bpf,D=6.184" —I —9384 h •4 \,•�\** \*I • Al • � / PB2FORATION SUMMARY REF LOG:SLB MCNL ON 04/17/04 ANGLE AT TOP PERF:930(41 10610' Note:Refer to Production DB for historical pert data ....... SIZE SPF INTERVAL Opn/Sgz SHOT SO2 (.4A.4.4.4.4.* L10903'CTM —FISH PALLED 1-11/16" 6 10610-10910 0 04/17/04 MAGNUM C8P r PBTD H 10919" ; (11/12/15) z 2-3/8"LNR 4.6#,L-80 STL. —{ 10952' ' '• .0036 bpf,ID=1.920" DATE REV BY COkfENTS DATE REV BY COMvENTS PRUDHOE BAY UNIT 04/29/83 PKR176 ORIGINAL DOM PLETION 12/07/15 CS/JM? MLLEDCBP(11/12115) WELL: 07-25A 04/18/04 KAK CTD SIDETRACK(07-25A) 12/07/15 DLit r SET DREAMCATa-U (12/06/15) FERMI No:'2040520 08/24/14 MGS/P •SET 35 KB LTP(08/21/14) API No: 50-029-20938-01 08/25/14 P •FULL/REST KB LTP(08/24/14) SEC 33,T11N,R14E,1751'Fly.&270'FEL 08/25/14 PJC REFORMAT WB S 03/03/15 PMPJC FERF REFERE E/GLV UPDATES BP Exploration(Alaska) 2-O 1-352. • • 2. 35 WELL LOG TRANSMITTAL DATA LOGGED PROACTIVE DIAGNOSTIC SERVICES, INC. /2:112015 K. BENDER To: AOGCC Makana Bender 333 W. 7th Ave DC12371tS' Suite 100 Anchorage, Alaska 99501 (907) 793-1225 GCC RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2— 1 900 Benson Blvd. Anchorage,AK 99508 uancpdcabp.com , AtiOEti and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Temperature Survey 18-Oct-15 07-25A BL/CD 50-029-20938-01 2) Signed : 1�/ �Q:� 'A242ov 6,4:at Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE( MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM DiAchives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\BP_Transmit.docx • OF TJX s� THE STATE Alaska Oil and Gas of/` L1SJ(A Conservation Commission toi "i-t2_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279 1 433 OF ALAS '� >>n44 Fax 907.276 7542 JUN � L'J1� www aogcc alaska.gov Matt Brown Well Interventions Engineer cQ b 05 1- BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07-25A Sundry Number: 315-299 Dear Mr. Brown: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P)ott., Cathy . Foerster Chair DATED this X23/4 of May,2015 Encl. BEDEWED STATE OF ALASKA MAY 14 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION P73 57 Z7)/ APPLICATION FOR SUNDRY APPROVALS AOGCC / ' 20 AAC 25 280 1.Type of Request. Abandon❑ Plug PerforationsIN Fracture Stimulate El Pull Tubing ❑ Operations shutdown❑ Suspend❑ Perforate❑ Other Stimulate ❑ Alter Casing El Change Approved Program❑, Plug for Redrill ID Perforate New Pool 1=1 Repair Well I]• Re-enter Susp Well CI Other: WeIlLock 45 IJ 2.Operator Name. 4.Current Well Class: 5.Permit to Drill Number: BP Exploration(Alaska),Inc. Exploratory ❑ Development 0 204-052-0 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-20938-01-00 • 7.If perforating. 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 07-25A • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9 Property Designation(Lease Number): 10.Field/Pool(s). ADL0028309 • PRUDHOE BAY, PRUDHOE OIL • 11 PRESENT WELL CONDITION SUMMARY Total Depth MD(ft). Total Depth TVD(ft). Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured). Junk(measured): 10952 • 9013 • 10917 • 9009 • None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 31.4-111.4 31.4-111.4 Surface 2497 13-3/8"72#L-80 30.9-2528 09 • 30 9-2528.03 4930 2670 Intermediate 8979 9-5/8"47#L-80 28.15-9007.24 28.15-8462.22 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size. Tubing Grade: Tubing MD(ft): 10610-10910 9006 04-9007 81 See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Descrption Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program I] BOP Sketch ❑ Exploratory El Stratigraphic El Development CI •Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: OIL 1] • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Matt Brown Email Matt Brown@BP.Com Printed Name / / _ ;rown Title Well Intervetions Engineer Signature Mif///r Phone 564-5874 Date r Or Prepared by Garry Catron 564-4424 COMMISSION USE ONLY Conditions of approval. Notify Commission so that a representative may witness Sundry Number: 315-29.`1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required9 Yes ❑ No [il Subsequent Form Required: /Q —40 4- APPROVED BY Approved by. / COMMISSIONER THE COMMISSION Date'...5---Z7 _/S1 V'TL /I X115' R IN I - , -f/.fis - r-,:&-_„- Form 10-403 Revised 5/2015 / ravld i li aLICh is valid for 12 months from the datef a proval. Submit Form and Attachments in Duplicate RBDMS� MAY 2 8 2015 0 0 0 0 0 0 0 ozs v CO CO 00 CO CO CO 0 = J J J J J J a) Q 0 O O 00C3 O O 0 r 0 N r` O CD O (O p N- N �t N N- (O U p O p o p O p O) N- (O O co co ' 7 co N O) m CO CO CO r- (13 N N CO CO CO O N CO O 0 N O r� O) O IC) N r- co (10 6) N 00 GO I co NI- Q x— co O IC) — N- Q M N N to M N CO CO CO CZ a) E a) E co co co rv , cotn �n 0 0 0 N N- (y � or- Otn � co co O p O) o) N co co � O 2 C J •— D Q 0 U CO Hoo � _� LC)M N (` M (O N CO O CO 0 p O 0 0 CO p 0 en • co 0 co J J 00 a) J N (p [� CA = 0p N Qo - CA O- � � MCO i N O) N 4 to Q) co O 0 co O co N co W CC H cn D 1-1-1 W c`�oD2 QUU U p CC CC ctW Z Z Z W W W m m p H Z Z_ j D D U Z J J (/) F- H Packers and SSV's Attachment ADL0028309 Well Facility Type MD Top Description TVD Top 07-25A PACKER 8655 5-1/2" Baker FB-1 Packer 8154 07-25A PACKER - 9108 KB Liner Top Packer 8549 . 07-25A CT GSO with WeliLock To: AK, D&C Wireline Operations Team Lead AK, D&C Well Services Team Lead Date: April 7, 2015 Code: From: Paulina Meixueiro, DS7 IOR: Est. Cost: Matt Brown, Well Interventions Engineer Subject: 07-25A 1.5" Coiled Tubing GSO with WeIlLock Please perform the following procedure: 1 S Drift to deviation for composite plug 2 E Set composite plug 3 F Injectivity test 4 C WeIlLock Squeeze with Cement Retainer 5 C Wait on WeIlLock 7 days. Mill Retainer/WellLock/Composite plug 6 S Set Dream Catcher 7 0 POP well Current Status: Operable Max Deviation: Max 95° @ 10223' Last Downhole Op: 2/12/15 CT caliper/borax log Last Tag 2/11/15 CT mill @ 10618' MD Minimum ID 1.81" @ 9114' Depl sleeve Last BHP/BHT: Est. 3250 psi @ 8800' TVDSS (no measured pres) 200 F Last test 11/27/14 228 BOPD, 65 BWPD, 36 MM form gas, 973 FTP Latest H2S Value: 20 ppm on 9/30/14 Note: 403 Sundry Required for this New Technology Work Program Objectives: The objective of this procedure is to shut off gas production from a hole in the liner. / Well History: Drilled in 04/04 and completed with 300' of perforations in Z2B in a 2-3/8" L-80 Inr. The well was a steady fulltime producer until 09/12, when it was SI for 6 months to address a flowline issue. After the 6-month shut down, the gas rate went from 18 mmscfd to 36 mmscfd. An LTP was set in 8/14 thinking that a liner lap leak might have been the cause of the gas jump, but gas rates stayed at 36mmsfd. Given that the well was no longer competitive, in 2/15 a PDS caliper was run in the 2-3/8" liner to see if a hole could be the cause of the gas jump. Additionally an RPM Borax log was run to look for channeling behind pipe/LTP and estimate the GOC. During the drift run, coil was unable to pass 5,693' md. Coil also attempted jetting thru the obstruction without success. The call was made to Page 1 of 11 07-25A CT GSO with WellLoc k try a 1.74" excalibur mill. Coil was able to make it all the way to 10,622' (right at the top of the perforations), then came to a sudden stop. The caliper showed the 2-3/8" liner in poor condition and the Borax log confirmed a hole around 9515'md as seen in the PDS caliper. There was no indication of the LTP leaking. The objective of this program is to squeeze the hole at—9,510' with the expectation of shutting in —15 mmscf of gas and having a full time well. Program Contacts Contact Phone -Work Phone -Mobile/Home Interventions Engineer Matt Brown 907-564-5874 907-223-7072 Petroleum Engineer Paulina Meixueiro 907-564-5971 Interventions Engineer Todd Sidoti 907-564-5113 907 632 4113 CC: Well File North Slope Page 2 of 11 • 07-25A CT GSO with We11LokK Procedure Volumes Tubing top MD bot MD Size ID bbl/ft ft vol, bbls 5-1/2"tub 0 8675 5-1/2"17# 4.892 0.0232 8675 201.7 4-1/2"tub 8675 9108 4-1/2"12.6# 3.958 0.0152 433 6.6 Casing top MD bot MD Size ID bbl/ft ft vol, bbls 2-3/8"liner above perfs 9108 10610 2-3/8"4.39# 1.999 0.0039 1502 5.8 2-3/8"liner in perfs 10610 10910 2-3/8"4.39# 1.999 0.0039 300 1.2 2-3/8"liner below perfs 10910 10919 2-3/8"4.39# 1.999 0.0039 9 0.0 Notes: - The hole targeted for shutoff is located -150' outside the millout window - The caliper shows ratty liner near the hole. The method of placing WeIlLock in the hole is to set a composite plug below the hole, set a retainer above the hole and squeeze WeIlLock into the hole. The corrosion in the liner necessitates setting the composite & retainer-150' apart to set in good pipe - The procedure calls for circulating 9.8 ppg brine on top of the composite plug prior to setting the retainer above the hole. This will result in 9.8 ppg brine below the hole down to the composite plug. The WeIlLock will float on top of the 9.8 brine and minimize the amount of WeIlLock that must be milled out after the job (procedure leaves a WeIlLock plug from retainer to hole to mill out) - WSL to review WeIlLock lab testing prior to pumping per WeIlLock RP Slickline 1. MIRU 2. Drift to deviation with dummy composite bridge plug. 3. RDMO SL. E-Line 1. MIRU 2. Set composite bridge plug at 9581' MD ref. tie in log SLB Memory CNL 17-Apr-2004. POOH. 3. POOH. 4. RDMO. Fuilbore 1. MIRU 2. Perform injectivity test per attached pumping template 3. RDMO. Coiled Tubing-Set Retainer 1. MIRU 1.5" CT, tanks, associated squeeze equipment. 2. Determine exact coil volume & calibrate Micromotion meter by pumping to tanks. Exact volumes are needed in order to avoid overdisplacing Welllock during treatment. 3. Liquid pack well by bullheading 1.5 tubing volumes of 2% KCI at-120 F down tubing. RIH with Cement retainer performing wt checks as needed. 4. Lightly tag composite bridge plug at 9581' (ref. tie in log SLB Memory CNL 17-Apr-2004) 5. Circulate 5 bbls of 9.8 ppg brine on top of retainer while POOH. Note: 6. PUH to 9448' MD and set retainer ref. tie in log SLB Memory CNL 17-Apr-2004 Page 3 of 11 07-25A CT GSO with Wel1Lo,x 7. Line up to pump 120F 1% KCI water down CT and establish injectivity below retainer. 8. Pump at minimum rate while Halliburton prepares to pump WeIlLock. Halliburton Cementers: 1. Mix WeIlLock base components at yard for a total of 6 bbls of WeIlLock. 2. Travel to location. 3. Rig up at location. Add final WeIlLock chemicals. 4. Once Coil has set retainer and established injectivity, line up to pump down coil as follows: a. 2 bbls FW spacer b. 6 bbls WeIlLock c. 2 bbls FW spacer d. 20 bbls Musol A e. Coil volume of 1% KCI 5. Squeeze WeIlLock below retainer. When -1 bbl of Welllock is remaining in coil, unsting from retainer. 6. Pump remaining WeIlLock out of coil while pulling OOH. 7. Once all WeIlLock and 2 bbl FW spacer are out of coil, RIH jetting Musol down to top of retainer 8. Ensure that any WeIlLock above retainer is contaminated at least 3:1 Musol:WellLock 9. POOH, pumping 1% KCI and chasing contaminated WeIlLock/Musol out of hole. 10. FP well on way out of hole. 11. RDMO coil. 12. Dispose of waste per attached waste management plan. CTU Post Squeeze(CT riq up#2-post wait on WeIlLock): 13. MIRU CT&ASRC or tanks?? Plan on milling with 1% slick KCL & Powervis sweeps. 14. MU milling BHA: CTC, DFCV, U/D Jars, Hyd Disconnect, Dual Circ Sub, 1.69" Motor, 1.74" mill with 1/8" opticut. 15. RIH, performing wt checks as needed. 16. Tag top of retainer at+/-9448'MD. PUH -50'. Begin pumping down CT&establish returns. 17. Mill out cement retainer & WeIlLock down to composite bridge plug at 9581' MD. Perform sweeps and short trips as necessary. 18. Circulate bottoms up. POOH to above liner top. 19. Perform a 500 psi MIT of squeeze by pumping down CT with choke closed. Once WHP increases 500 psi, SD pumping & monitor pressure for 15 min. a. Contact program authors and CT Scheduler with test results to confirm next steps. • Test Criteria-slow bleed-off is okay. • If injectivity is observed, establish LLR at 500 psi. If LLR at 500 psi is more than 0.5 bpm, stop procedure & contact intervention engineer. If LLR is less than 0.5 bpm, continue with milling composite bridge plug 20. Re-establish returns to mill plug. 21. RIH milling. Mill composite plug & push as deep as possible. Note that there is a tight spot at 10622' so it is likely that we won't be able to get deeper than that. 22. POOH, chasing returns to surface. 23. FP well. 24. RDMO Coil Slickline 25. MIRU SL. 26. MU dream catcher for setting in SSSV nipple 27. Set dream catcher at 2187' in 5.5" tubing. 28. RDMO SL. Page 4 of 11 07-25A CT GSO with We11IA.,K WellLock Resin System: Volume to pump: 6 bbls Resin thickening time: 6 hrs minimum Static BH Temp: 200 F Pre-Job Testing Requirements - Rheology at surface conditions - Viscosity vs. Time - Graphical illustration of Slurry temperatures/Compressive strength vs. Time - Plot of Exothermic Reaction Temperatures vs. Time - Curing time at BH conditions Page 5 of 11 07-25A CT GSO with WellLoux ......._....... 114±. 5-118'x 7-1116'Eta; SAFETY NOTES:RSH PE-CK STRIPPED OFF 'Aril HEAD C.,FVO 07-25A ACTUATOR= BAKER STATIONS 3 E 7 Ctrs 02/11/94. KB HIV- 51 E3F REV- KOP= 290P 2187' —5-1/7 CA/A20 BAL-0 SS-SV NP,D.4 567 'Max Angle= 95 0 10223' 1 Datum M)- 9481'''' CalumTVD" 8800'SS GAS 1FTMAtO1_S STM) TVD DEV TYR. V?.V LATCN FORT DATE—' 1 288828863 9 MAGI DAN' RK 0 04/20/C9- 133/8'CSG,12#.1.80,D=12 347' 1---1 J l 2527' I 2 4513 i 43841 25 AMG MY RI( 0 04/2G0 3 5686!5455 124 MING! DMY 14( 0 I 4 6815 6482 23 MAC, CAN Ai( 0 5 7752 7337 23 1.111G; DMV ti( ! 0 6 8254 7794 25 MAG j ()MY Fi( 0 7 18520 8034 26 AMC; DAK Fa( 0 8 8588 8095 27 MG DMY R( 0 8666' —9-518'x 5-1/7 BKR Frit FEW PKR-1 8868' 5 112"0/02 SDI ASSEIAB1Y 5-t/2'TBG,174,1.80,.0231 bp1.r i=4 892'{-{u 8854' ..dJ I 86N' I-{ -OUT EXTENSOR D 8.825' 1 8875' 5-117 x 4-112-xo.D=3 948' Minimum in= 1 81"@9114' I 2.25"AVA SEAL ASSY 8715' j—BROVArI TE BACK SLV,SHORTY Fr1 D----- 8762' —41/7 0715 XNNI ,D-3725"(BE}N)GT LNFT)-14TBG,126w l-80, 0152be,D 398' 87757 __8776' {-{4 112"VYt EGD958' (BT L8772':�,—E M)I r L000&D06113190 1vi'vlop Of C'EirNr(HR12/95C8L){ G,47 ,l-808681'1-{ 900G1kFERCRAI SAMARY -35 KBLTRIT-181-(08/71/14) RFT i OO i• i i I 911-47-1-2625'BKR DEPLOYMENT SLV.D-.2 250' AN1EATTOPFU4 94010610 !►•1 Nolo.Pieter lo Produiucbon CO3 for hmbncat NA data SEE SP1 T NtLRVAL ° Om/55w 8•1 I MLLUUE WItiX7W 107 25A! 9316' 93$4 1 11118' 6 110610-10910 0 /0111/04, • • �!••i •4 ►•• • A• ii 4 • ►• • • A. Ai. FETE) 1091W .4.1... 1••4••1••••4• \I . ••••• 4 4.4•4• {7 LNFt 290 t 80, 0311 tp1 t).6 184' ji 9855' ' . 'Tr• Y-3/8'LM2,460.1.80. 0036 Dpt,[)=1 920' .-1- 10952' { DATE I REV BY C0.EU1TS (ZAT1E REV BY' C0144B4TS FRUODOE BAY LINT 04/291$3 ORIGINAL COMPLETION '08!25/141MOS/PJC SPT 35 KR t IP(08121114) Mt l 07-2SA 04/18/04 KAK .CTD SIDETRACK(07-25A) FUATT 14)`2040520 0420/041.k314/4KA GtGLV 00 AR Na. 50-029-20938-01 07/22108 DSNNSV TREE C/O(0623.08) i SED 33.T1 IN,R14E 1751'FM.&270 FEL 05/31/09 GJF1Tt.RIG)V 00104;20/39) 0'/11/09 AI HTL11 SAFETY NOW CX)t CT1ONS 1 1, BP Exploration(Alaska) Page 6 of 11 07-25A CT GSO with WellLock Tie In Log I- 0 H Cc w Z Schlumberger COMPENSATED NEUTRON LOG <Z o s< u—VT W us MEMORY GR/CCL/CNL W F u_a 3W<LLV, 17APRIL2004 QuQoo FINAL Z0 -00a izrLLO Company BP Exploration(Alaska), Inc. W<0 7.. ell Well DS 07-25A g ai h/ << Z E. Field Prudhoe Bay o w 3 0 w E Borough North Slope State Alaska g 4 W < V r •- Location: SEC 33,TWP I1N,RGE 14E other Services b ~o tri OO 1 Cc O cc Surface: 1751.1 FML,268_7'FEL B $ a 0 W I w iX H^ API Number 50-029 20938-0Ig 0 <m E.in Permanent Datum MSL Elevation 0 Elev.: K.B. 57' h. _u w=Ci.o Log Measured from KB 57 Ft.Above Datum DT < ¢a Elo Drilling•Heal.from KB G.L. c g- u w Date 17 APRIL 2004 Shot No of Perf Interval $ W~ >Cr—Y~ Run No. ONE Density Stens From To g W O Z W y of LQaW<� Type Log remove GR/ccl/CM d�1 `�a m=Np Ffrst Reading IO910 FT f a e N LL aor O W Last Reading as16 FT QV O u V)W .�J Max.Dogleg n c C m F'4 rtao Deviation 94 DEG•1(1222 Fl 4 =V) W 1-z J 1 Z W<u Depth Reached 10941 FT • �'� cccL ia Z Bottom°filial 109'.2 FT F 0 0 0 1 7 Well Head Presslre 0 PSI Gun Tit a W aa ZO O< N O 0 w FIwO tevN Surface and Size vt°g a>W<OL Truck No 8388P CASING RECORD m U ta p, V7<IZm WWj Size Inches Wei it..16/fy From I To T�< O 0 ID 0 F 0 Recorded By BRANDON PEE TIER 2 375 IN 4 6 LBIFT ' 9113 FT 10952 FT 2 u t=.D 1 W Z Witnessed By I PETER Ol1CANE 1 a a 0,„z,,,<W<r�t� COLLAR LOCATION OTTER SERVICES o c o Q M-i z casing Tubing Service type Site Death o 0 G a w 1":n u --_ g ct ei e 0 • Z F J( W W iiO g .. % 0.1x0,- -4 .ui $o FO:a1'Jw Im X aaoo ax `_ 1 {r W J ± is w 0 u W J g, Y Z . fa g !�{ 0) sla ¢i'° _r C w ,...“.,„..,-0 1 I TI S I lz a: - kg°=1-z g W 2 O . pp W Z Timm('Bolton I Spann,Winnie ,+ 8` a o Z d G Page 7 of 1 1 07-25A CT GSO with WellLocx .^..".'— , 1 ! i G l } ... .,) �(�� 1 9400 { 4...r. ` i :: c E 1 . Cement retainer �,,� .. - 9448' •:...,: i....... I -' T i / 1 011 i I i F _ 1 t �' I 4) .1 1 r r_ 1 Q _ r _ i,,, r = 9500 1 � l t� N, !' ....... L. 9550 ( t _ .c" i le .' ) r Hole in liner % ^_ 4 — Composite �= Bridge Plug _ _ = 9581' , - — I 1 9600 t � I 1 T i I 07-25A CT GSO with We11Lo,r( Waste Management Plan — WellLockTreatment Prepared by: Matt Brown/Jess Sayers Date: August 13, 2014 Purpose and Scope: Pump Halliburton's WeIlLock treatment to seal holes/leaks in the wellbore to shut off reservoir fluids. WeIlLock is resin that sets up with temperature to a hard, plastic-like material. It is used for squeeze applications to repair cement or tubulars/casing. WeIlLock consists of four chemicals that are mixed on location. Once mixed, the WeIlLock system is designed to set up at bottom hole temperatures. Prosect Contacts: Ken Bulloch/Dan Scrapella/Mel Iveson 659-5580 Secondary contact: Matt Brown 564-5874 or 907-223-7072 Jess Sayers 564 4281 or 907 602 8715 Activity Description: The WeIlLock treatment will be bullheaded down the well and allowed to set up. Treatment volume may vary from 1/2 bbl for a small job up to 10 bbls of WeIlLock for a larger job. Once the WeIlLock resin has set up, coiled tubing will mill out any remaining WeIlLock in the tubing. The MSDS sheets for the chemicals listed in the table are attached. The chemicals are approved in the NCE process. The MSDS for the solidified WeIlLock is attached. WeIlLock Description WeIlLock in its liquid state weighs about 9 ppg and has a viscosity of 30-50 cp. Fluid compatibility testing with common intervention fluids shows that WeIlLock is immiscible with brine, methanol, 60/40 Methanol/water, diesel and acid. To stop WeIlLock from setting up, Musol is added in proportions of 25%WellLock/75% Musol. Cleanup of surface equipment is performed by flushing pumps/lines with Musol, then freshwater. The anticipated waste streams from a WeIlLock job include: 1. Surface equipment washup water with some WeIlLock and Musol 2. Small volumes (<1 bbl) of WeIlLock+Musol from OA squeezes 3. Larger volumes (+20 bbls) of WeIlLock+Musol mixed with 2%KCI from cleaning out a well with coiled tubing after a WeIlLock squeeze 4. Solidified WeIlLock at surface (if the job can't be pumped after additives are put in WeIlLock due to weather, equipment issues etc.) 5. WeIlLock cuttings from milling solid WeIlLock downhole (cuttings look like ground up plastic) Anticipated Waste and/or Recycle Streams Stream Classification Amount Disposal/ReUse Accountable/ Options contact numbers Solidified WeIlLock Up to 6 bbls Take unused WeIlLock Ken Bulloch/Dan to Halliburton shop, put Scarpella 659-5580 into 55 gal drums to set up, and then to Environmental Advisor landfill after WeIlLock Central 659-5893 solidifies Page 9 of 11 07-25A CT GSO with We11L.,.,K Mix of 25%WeIlLock+ Put in 55 gal drum and Ken Bulloch/Dan 75%Musol Small vols(<1bbl) comingle with Scarpella 659-5580 inceneration and hazardous waste Environmental Advisor stream. Central 659-5893 2%KCI water+Mix of 25% Slipstream direct inject Ken Bulloch/Dan WeIlLock+75% Musol. >20 bbls of mixture into GNI Scarpella 659-5580 The fluid would be about 90% KCI water and 10% Environmental Advisor WellLock/Musol Central 659-5893 Cleanup water for washing Up to 10 bbls Slipstream direct inject Ken Bulloch/Dan surface equipment after into GNI Scarpella 659-5580 pumping WeIlLock:95% Fresh water with 5% mix of Environmental Advisor WeIlLock+Musol Central 659-5893 Solid WeIlLock particles Up to 2 bbls Slipstream direct inject Ken Bulloch/Dan from milling with coiled into GNI Scarpella 659-5580 tubing Environmental Advisor Central 659-5893 MSDS_WLR1.pdf MSDS_WLR2.pdf MSDS_WL1i1.pdf MSDS_WLA2.pdf MSDS_WeIlLock_Set. pdf Musol.pdf Page 10 of 11 07-25A CT GSO with WellLook From: AK, HSSEE Env Adv Central Sent: Friday,August 15, 2014 9:21 AM To: Brown,Matt(CONTRACT PROFESSIONALS) Cc: Saye,Jessica; Bill, Michael L(ASRC);AK,HSSEE Ener Waste Coord Subject: RE:Well Lock waste management plan Looks good. Recall for solidified drums that we or we in concert with Halliburton should fill out a NSB Serrice Area 10 Oxbow landfill disposal request_ Attached.pdf http://north-slope_org/departmentsjadm i nistration-finance/sa10-Industria I-development/oxbow-landfill-information Using water to flush equipment is a good choice and preferred,but note if you Jse methanol or diesel or any solvent, coordinate with Env Advisor Central or Waste Coord since that would likely make the rinsate ignitable hazardous waste. For 55 gallon drums of liquids,even if non-haz,that would be easiest to ship out for incineration,you can contact us initially or suggest also adding in "Waste Coordinator Vic/Larry 659-4810"since we'd be making ar-angments with them to deliver it to their Hazardous Waste Process Facility ll-WPF)on WOA BOC Pad. And on the last wastestream Solid'NellLock panicles from milling with rAiled tubing. I could see bagging it uc and Landfilling it if it's riot staying in solution or partic e diameter too big for G&I or Mike Bill's operational concerns. Thanks for drafting this up WMP! Geoff Kany Environmental Advisor Central BP Exploration (Alaska) Inc. Alternate: Alex Reyes -4- 1 907 659 5893 Harmony Radio: 2332 From: Brown, Matt(COXWTRACT PROFESSIONALS) Sent: Thursday,August 14, 2014 11:20 AM To: AK, HSSEE Env Adv Central; Bill, Michael L(ASRC) Cc: Saye,Jessica Subject:Well Lock waste management plan Geoff/Mike, Can you please review the attached WMP for WellLock&let me and Jess know your thoughts/changes? We plan on using WellLack for some OA micro annulus repairs,surface casing leak repairs and some downhole gas shutoffs. Thanks, Matt Brown Well Interventions 907-564-5874 desk 907-223-7072 cell Cube 784D matt coni bp.ccr Page 11 of 11 2D ii-O52 //� /2-5 2-V)1 BAKER PRINT DISTRIBUTION LIST HUGHES C1 COMPANY BP Exploration Alaska,Inc. INTERMEDIATE FINAL Yes ill V-2 V y o f•t► mandatory) DATA LOGGED 1 N �/ WELL NAME 07-25A RUN NUMBER 1 3/1,0/201 Imo', O (mandatory) i I K.BENDER 6� FIELD Prudhoe Bay Unit BH SALESMAN Henry Giordanelli t� (mandatory) (mandatory) ui = Q COUNTY North Slope BH DISTRICT Prudhoe Bay,AK (mandatory) (mandatory) CC STATE Alaska PAGE 1 OF 1 (mandatory) LOG DATE: February 12,2015 TODAYS DATE: 3/5/2015 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: Henry Giordanelli (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY A B C D ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) L.I.S. FILM PERSON ATTENTION #OF PRINTS#OF COPIES#OF COPIES#OF COPIES#OF COPIES#OF COPIES 1 ConocoPhillips Alaska Inc. 2 1 1 1 Attn:Ricky Elgaricio A= 07-25A_RPM_PNC3D_BORAX_RAW_12FEB2015_BHI ATO 3-344 700 G Street Anchorage,AK 99510 B= *(Folder 1 on cd/dvd) 07-25A_RPM_PNC3D_BORAX_RAW_12FEB2 C= **(Folder 2 on cd/dvd) 07-25A_RPM_PNC3D_BORAX_RAW_12FEB2 D= ***(Folder 3 on cd/dvd) 07-25A_RPM_BORAX_RAW_PASSO1UP_12F1 1 07-25A RPM BORAX_RAW_PASS021 07-25A_RPM_PNC3D_RAW_PASS01 UP_12F1 07-25A RPM PNC3D RAW PASSO2UP 12F1 SCANNED MAR 1 U 2015 ****(Folder 4 on cd/dvd 07-25A_RPM_BORAX_RAW_PASSO1 UP_12FI 07-25A_RPM_BORAXRAW_PASSO2UP_12FI 07-25A_RPM_PNC3D__RAW_PASSO1 UP_12FI 07-25A_RPM_PNC3D_RAW_PASSO2U P_12FI W Folder 1 on cd/dvd needs to be named"META" ** Folder 2 on cd/dvd needs to be named"PDF" **>k Folder 3 on cd/dvd needs to be named"DLIS" yr*** Folder 4 on cd/dvd needs to be named"LAS" 2 ExxonMobil,Alaska 1 I 1 I 1 1 Attn:Lynda M.Yaskell and/or Leonardo Elias 3700 Centerpointe Dr.Suite 600 I Anchorage,AK 99503 3 State of Alaska-AOGCC 1 I I 1 I 1 I 1 I Attn:Makana Bender 1 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 4 DNR-Division of Oil&Gas 0 I 0 I 1 I 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 I Anchorage,Alaska 99501 TOTALS FOR THIS PAGE: 4 3 4 4 0 #REF! TOTALS FOR ALL PAGES: 4 3 4 4 0 #REF! e e 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. .Q. () !j - 0 5 ~ Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 1111111111111111111 R5PCAN ~ Color Items: o Greyscale Items: DIGITAL DATA ~iskettes, No. ¡ o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: o Other: OVERSIZED (Non-Scannable) o Logs of various kinds: NOTES: Date: o Other:: BY: ~ 151 VVlP III 11111111111 111I1 Project Proofing BY: ~ 151 MP Scanning Preparation BY: --1 + d.. 5 = TOTAL PAGES 5 0 (Count does not include cover sheet) 151 p Date: Production Scanning Stage 1 Page Count from Scanned File: 5' (P (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY c:- Mada} Date b 1/1 / () 0 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 11111111111111 "III 151 NO VV\ P NO BY: Maria Date: 151 11I11111111I1111111 Scanning is complete at this point unless rescanning is required. ReScanned "' 11111111111 "III BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 1016/2005 Well History File Cover Page.doc • • -~,._ -,n~~.. - ,~ ~° MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\I,aserFiche\CvrPgs_Inserts\lklicrofilm_Marker.doc ) g f1It'J ~ ~ DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 )f¡ u. cL l,t A.¡1 À.l)\\ c..r API No. 50-029-20938-01-00 Permit to Drill 2040520 Well Name/No. PRUDHOE BAY UNIT 07·25A Operator BP EXPLORATION (ALASKA) INC MD 10952,., ~,.~ TVD 9013 ~ Completion Date 4/18/2004 r' Current Status 1-01L UIC N Completion Status 1-01L --' --- REQUIRED INFORMATION Mud Log No Samples No Directional surv~_ .--- DATA INFORMATION Types Electric or Other Logs Run: SGRC Combined with GR & EWR, MGR 1 CCL 1 CNL Well Log Information: Logl Data Digital Type MedlFrmt j: ~ ~:' I I ~CPd' (data taken from Logs Portion of Master Well Data Maint Electr Dataset Log Log Run Interval OHI Number Name Scale Media No Start Stop CH Received Comments Directional Survey 5112/2004 l 12512 I nd uctionlResistivity 9040 10950 Open 6/9/2004 MWD EWR4 GR ROP 13564 Gamma Ray 9370 10952 Open 2/22/2006 ROP NGP plus Graphics Directional Survey 13112 Neutron 5/12/2004 8585 10910 4/28/2005 MCNUMEMORY GRlCCLlCNL 2 Blu 8585 10910 4/28/2005 MCNUMEMORY GRlCCUCNL --.J Sample Interval Set Start Stop Sent Received Number Comments 13112 Neutron Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y ® Chips Received? -.'(~ Analysis Received? Daily History Received? &/N "@I N Formation Tops "y~ Comments: . . ,- Permit to Drill 2040520 MD 10952 TVD 9013 Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Well Name/No. PRUDHOE BAY UNIT 07-25A Operator BP EXPLORATION (ALASKA) INC Completion Date 4/18/2004 Completion Status 1-01L Current Status 1-01L #-0 API No. 50-029-20938-01-00 UIC N Date: / '7 ~ ~-Ý . . . . WELL LOG TRANSMITTAL ,QD4 - tJ 5:;-- 13SZo+ February 16, 2006 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 07-25A, 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 07-25A: LAS Data & Digital Log Images: 50-029-20938-01 1 CD Rom A~ì oQ.!LDJ-h C- - \DLD d\,9'0' . . . WELL LOG TRANSMITfAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska June 09, 2004 RE: MWD Formation Evaluation Logs 07-25A, AK-MW-3017317 1 LDWG formatted Disc with verification listing. ~I#: 50-029-20938-01 * IJ-.ÇlJ- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENllON OF: Sperry-Sun 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: ~ ){¡w... ~ '-'I L1 diJJ Signed: ;} OL(- Oç,( · STATE OF ALASKA _ ALASKA~IL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEIVED MAY 11 2004 1a. Well Status: IHI Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well ~liifa Oil & (jas t,;ons. I,,;omrn 20AAC 25.105 20AAC 25.110 IHI Development AliUR11lftg9itory DGINJ DWINJ o WDSPL No. of Completions One Other o Stratigraphic Test 0 Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 4/18/2004 204-052 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 4/12/2004 50- 029-20938-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 4/15/2004 PBU 07 -25A 1751' SNL, 269' WEL, SEC. 33, T11 N, R14E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 2560' SNL, 3015' WEL, SEC. 33, T11N, R14E, UM 57' Prudhoe Bay Field I Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 1963' SNL, 4059' WEL, SEC. 33, T11N, R14E, UM 10917 + 9009 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 675947 y- 5949168 Zone- ASP4 10952 + 9013 Ft ADL 028309 ~- 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 673222 y- 5948295 Zone- ASP4 ---.-.-- --- (Nipple) 2187' MD Total Depth: x- 672162 y- 5948868 Zone- ASP4 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey IHI Yes DNo NIA MSL 1900' (Approx.) 21. Logs Run: SGRC Combined with GR & EWR, MGR I CCL I CNL 22. CASING, LINER AND CEMENTING RECORD C~¢~G V\lT,PER FT. SETTING DEPTIiMP SETTINGPEPTI"I.'1'VQ HOLE AMOUNT GRADE Top BOTTOM Top I BOTTOM SIZE PULLED 20" 91.5# H-40 Surface 79' Surface 79' 30" Installed wI 1956# Poleset 13-3/8" 72# L-80 Surface 2527' Surface 2527' 17-1/2" 1800 sx Fondu, 400 sx PF 'C' 9-5/8" 47# L-80 Surface 9006' Surface 8461' 12-1/2" 500 sx Class 'G', Top Job: 50 Bbls PF 'C' 7" 29# L-80 8715' 9376' 8207' 9207' 8-1/2" 350 sx Class 'G' 3-1/2" 9.3# L-80 8760' 9376' 8247' 8993' NIA 112 sx LARC 2-3/8" 4.6# L-80 9114' 10952' 8554' 9013' 3" 58 sx Class 'G' 23. Perforations op'en to Production (MD + TVD of Top and 24. iT JEIlNG. Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 1.56" Gun Diameter, 6 spf 5-112", 17#, L-80 8675' 8655' MD TVD MD TVD 4-1/2", 12.6#, L-80 8675' - 8775' 10610' - 10910' 9006' - 9008' 25. ACID, FRACTURE,CEMENT « DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protected with MeOH 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): April 21, 2004 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BsL GAs-McF WATER-BSL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + OIL-BsL GAs-McF W A TER-BSL OIL GRAVITY-API (CORR) 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). SU~~9,r~.chips; if none, state "none". 1 >} I CjL,.·: nD1~'t\1 ^ 1 MÄ~ None I ~~ .1 .RJI)MS BfL 1Jc"~ ~¡ , '" c.t) f .-- _t --"-.....J issio Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE (9 F 28. GEOLOGIC MARKERS 29. FORMATION 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". Top CGL I Zone 3 Base CGL I Zone 2C 9375' 8781' None 9493' 8864' 23SB I 26N 9598' 8914' 22TS 9723' 8976' RECE\VEf) M~'{ 11 '2\1G4 I" ,,\,.,u\¡\m\sß\OIì i\ & Gas 1.1\),,;), Mas\r-a 0 ~ncMta\\e 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 PBU 07-25A Well Number 204-052 Permit No. / 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. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Mary Endacott, 564-4388 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-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 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-25 07-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/8/2004 Rig Release: 4/18/2004 Rig Number: N1 Spud Date: 4/13/1983 End: 4/812004 18:00 - 20:30 2.50 MOB P PRE Rig released from D-04B @ 18:00Hrs on 4/8/2004. secure BOP. Install tilt rams & bridle up. Load out trucks & prep to move rig off well. 20:30 - 20:45 0.25 MOB P PRE PJSM for moving rig off well. 20:45 - 21 :30 0.75 MOB P PRE Pull rig off well & set down. Clean up location & conduct post operations pad inspection. 21 :30 - 00:00 2.50 MOB P PRE PJSM. LID windwalls. Scope down & UD derrick. 4/9/2004 00:00 - 06:00 6.00 MOB N WAIT PRE W. O. BP security (currently moving 4ES from Sag Delta 2A to Milne pt via K-pad road). Not enough security personnel to cover both rig moves. Meanwhile inspect derrick, koomey bottles, injector & carried out misc. rig maintenance. 06:00 - 19:00 13.00 MOB N WAIT PRE W. O. BP security (currently moving 4ES from Sag Delta 2A to Milne Pt via K-pad road). Not enough security personnel to cover both rig moves. Also CPS was scheduled to be done with the GC1 power crossing at 1800 hrs, which would allow Nordic 1 to move down the spine road past CPS to DS7, which is a 10 mile shorter move. 19:00 - 19:30 0.50 MOB P PRE Held pre-move safety meeting with security, tool service, CPS & all personnel. 19:30 - 00:00 4.50 MOB P PRE Move rig from D-04 to DS#07. 4/1 0/2004 00:00 - 01 :00 1.00 MOB P PRE Continue moving rig from D-04 to DS#07. Meanwhile lay rig mats in front of 07-25 & confirm WHP to be Opsi. 01 :00 - 01 :30 0.50 MOB P PRE Park rig in front of well & set down. Conduct pre-operations pad inspection. 01 :30 - 01 :45 0.25 MOB P PRE PJSM. Review procedure, hazards & mitigation for raising derrick & windwalls. 01 :45 - 04:00 2.25 MOB P PRE Raise derrick & windwalls. Secure guy wires. Secure tilt rams in storage frame. 04:00 - 04:15 0.25 MOB P PRE PJSM for stabbing CT into injector. 04:15 - 07:30 3.25 MOB P PRE P/U injector head. MIU guide arch & stab CT into injector head. Meanwhile grease Xmas tree valves. 07:30 - 07:45 0.25 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigation for backing rig over well. 07:45 - 08:00 0.25 MOB P PRE Back rig over well and set down rig. 08:00 - 10:30 2.50 BOPSU P PRE ACCEPT RIG AT 08:00 HRS, 04/10/2004 Nipple up BOP stack. Position trailers. Fill rig pits with Biozan KCL water. Rig up hardline and tiger tank with berm. M/U Kendall CTC. Pull test CTC with 34K. 10:30 - 16:15 5.75 BOPSU P PRE Perform initial BOPE Pressure 1 Function test. Witness was waived by AOGCC inspecter, John Spalding. Send test report to AOGCC. 16:15 - 17:00 0.75 STWHIP P WEXIT Circ. MEOH out of coil. Press test CTC. 17:00 - 17:15 0.25 STWHIP P WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for M/U Window Milling BHA. 17:15 - 18:00 0.75 STWHIPI P WEXIT M/U 2.74" HC Diamond window mill with 2.75" go/2.74" no-go HC diamond string reamer on straight motor with WF MHA and 2 jts of 2-16" PH6 and CTC. BHA = 80.23 FT. 18:00 - 19:25 1.42 STWHIP P WEXIT RIH with BHA #1, 2.74" Window milling BHA. Take gassy I returns to tiger tank. Up wt check @ 8400' = 31.8k, Run-in wt = Printed: 4/19/2004 12:10:10 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-25 07-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/8/2004 Rig Release: 4/18/2004 Rig Number: N1 Spud Date: 4/13/1983 End: 4/10/2004 18:00 - 19:25 1.42 STWHIP P WEXIT 21.5k. 19:25 - 08:00 12.58 STWHIP P WEXIT Continue RIH BHA#1 & dry tag TOWS/pinch pt @ 9380'. Up wt check = 35k, Run-in wt = 23k. Bring on pumps. Establish freespin @ 1.6bpm/1650psi. Retag TOWS/pinch pt @ 9378'. Correct depth to the TOWS ELM of 9375'. Flag pipe. 08:00 - 21 :50 13.83 STWHIP P WEXIT Stall 2x @ TOWS. Ease into milling from 9374'. Mill window in 3-1/2" scab liner from 9375' with 1.67/1.67bpm, 1650/1950psi, 0-1k WOB & 1fph ave ROP. Stall2x @ 9375.9'. Continue milling to 9376'. 21:50-22:15 0.42 STWHIP P WEXIT Mill to 9377' with 1.67/1.67bpm, 2000/2450psi, 0-1k WOB & 2fph ave ROP. 22: 15 - 23:00 0.75 STWHIP P WEXIT Mill to 9378' with 1.65/1.65bpm, 2000/2450psi, 1 k WOB & 2fph ave ROP. 23:00 - 23:40 0.67 STWHIP P WEXIT Mill to 9380.5' with 1.65/1.65bpm, 2000/2250psi, 1-2k WOB & 3fph ave ROP. 23:40 - 00:00 0.33 STWHIP P WEXIT Ream & backream 2x from TOW to 9380.5'. 4/11/2004 00:00 - 01 :25 1.42 STWHIP P WEXIT Paint EOP flag @ 8600' & POOH milling BHA #1. 01 :25 - 02:00 0.58 STWHIP P WEXIT OOH. LID motor & mills. Window mill gauge 2.74" go/2.73" no-go & wear on mill face indicates crossing the 3-1/2" csg wall. String reamer gauge 2.74" go/2.73" no-go. 02:00 - 02:15 0.25 STWHIP P WEXIT Held PJSM for M/U Window milling BHA#2. 02: 15 - 02:55 0.67 STWHIP P WEXIT M/U & lock tite window milling BHA #2 with new 2.74" window mill, new 2-3/8" WF 2.5deg fixed motor, Sperry GR-DIR MWD & orienter & WF MHA (OAL = 60.11 '). Scribe tools. M/U injector. 02:55 - 04:45 1.83 STWHIP P WEXIT RIH window milling BHA #2. SHT MWD & orienter @ 5000' - OK. Continue RIH. Correct -3' @ the flag. Set down @ TOL. P/U & fall thru. RIH to 9350'. 04:45 - 04:55 0.17 STWHIP P WEXIT PT well bore to 500psi for 5 mins - lost 15psi. Bled down lAP from 550psi to 25psi & OAP from 340psi to 75psi. 04:55 - 05:00 0.08 STWHIP P WEXIT Orient TF to HS. 05:00 - 05:05 0.08 STWHIP P WEXIT Establish freespin @ 1.6bpm/2450psi. Tag window @ 9379.3'. Correct TD to 9380.5'. 05:05 - 06:00 0.92 STWHIP P WEXIT Start time-milling schedule. Mill to 9380.8' with 17R TF, 1.6/1.6bpm, 2450/2550psi. 06:00 - 07:30 1.50 STWHIP P WEXIT Time milling window as per schedule, window is started in 7" liner, stacking wt when moving pipe, also seeing reactive torqueonTF. 1.6bpm, 2550 psi, 5L TF, 1.0 FPH, 1200# WOB. Milled to 9381.8 ft. 07:30 - 09:00 1.50 STWHIP P WEXIT Milling window as per schedule. 1.6 bpm, 2550 psi, 17L, 1.0 fph, 1500# WOB. Milled to 9383.4 ft. 09:00 - 10:30 1.50 STWHIP P WEXIT Milling window as per schedule. 1.6 bpm, 2550 psi, 33L, 1.0 fph, 4000# WOB. Stacking more WOB. Milled to 9384.5 ft. 10:30 - 11 :30 1.00 STWHIP P WEXIT Milling window as per schedule. 1.6 bpm, 2550 psi, 33L, 1.0 fph, 4000# WOB. Stacking more WOB. Milled to 9384.5 ft. Stalled at 9384.5 ft. Clean pick up and back ream clean. Ream down. Milled to 9384.5 ft. Stalled 3 times. Ream in hole. WOB drilled off quickly below this depth. Top of window at 9375 ft. Bottom of window at 9383.5 ft. 11:30-13:15 1.75 STWHIP P WEXIT Milling formation, 1.6 bpm, 2700 psi, 17L, 10 fph, 5000# WOB, 4 FPH. Pump 25 bbl high vis Biozan sweep. Stacking wt. Milled to 9386 ft. 13:15 - 14:00 0.75 STWHIP P WEXIT Ream window area. 5K overpull off bottom 2 times. Ream up I Printed: 4/19/2004 12:10:10 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-25 07-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/8/2004 Rig Release: 4/18/2004 Rig Number: N1 Spud Date: 4/13/1983 End: 4/11/2004 13:15 - 14:00 0.75 STWHIP P WEXIT and down twice. 14:00 - 14:30 0.50 STWHIP P WEXIT Milling formation, swap to re-conditioned FloPro. Stacking 8K WOB with very little motor work. Mill appears worn. No progress. RIH and tag TD at 9,386 ft. 14:30 - 16:30 2.00 STWHIP P WEXIT POH. Chase FloPro. 1.6 bpm, 3120 psi, 16:30 - 17:40 1.17 STWHIP P WEXIT Layout mill and motor. MIU diamond speed mill, string reamer and 1.75 deg motor, Sperry MWD and MHA. BHA = 61.2 ft. 17:40 - 19:30 1.83 STWHIP P WEXIT RIH with BHA #3, 2.73" HC diamond Speed window mill, 2.73" diamond string reamer and 1.75 deg motor. Correct CTD -3.7' @ the flag at 9,358.1 ft. 19:30 - 19:40 0.17 STWHIP P WEXIT Orient TF to HS. 19:40 - 19:50 0.17 STWHIP P WEXIT Establish freespin @ 1.6bpm/3180psi. Tag window @ 9378.4'. 19:50 - 21 :35 1.75 STWHIP P WEXIT Ease into milling from 9378.4'. Mill to 9386' with 5-20L TF, 1.6/1.6bpm, 3180/3300psi, 2-3k WOB & 5fph ave ROP. 21 :35 - 21:40 0.08 STWHIP P WEXIT Orient TF to HS. 21 :40 - 00:00 2.33 STWHIP P WEXIT Mill formation to 9394' with 5-20L TF, 1.6/1.6bpm, 3180/3550psi, 2-3k WOB & 3fph ave ROP. 4/12/2004 00:00 - 00:55 0.92 STWHIP P WEXIT Backreamlream windowlrat hole several times with 1.6bpm/3150psi. Drift window without pumping - looks clean. Tentative TOW/TOWS = 9375', BOW = 9383.5', RA PIP Tag = 9380.7'. 00:55 - 02:15 1.33 STWHIP P WEXIT POOH window milling BHA#3. EOP flag @ 9296.9'. 02:15 - 02:45 0.50 STWHIP P WEXIT OOH. SIB injector. LID BHA#3 & inspect mills. Window mill gauge 2.73" go 12.72" no-go & string mill gauge 2.74" go / 2.73" no go. 02:45 - 03:00 0.25 DRILL P PROD1 Held pre-spud safety/operations meeting. Reviewed well plan, potential hazards & drilling BHA M/U procedures. 03:00 - 03:30 0.50 DRILL P PROD1 M/U & lock tite build section BHA #4 with rebuilt HC DOSTRWD 2.7" x 3" bicenter bit, 2.1deg BHI Xtreme motor, Sperry GR-DIR MWD, orienter & BKR MHA (OAL = 59.14'). Scribe tools. M/U injector. 03:30 - 05:00 1.50 DRILL P PROD1 RIH drilling BHA #4. SHT MWD & orienter @ 2800' - OK. Continue RIH. Correct -2.5' @ the flag. RIH clean thru window & tag TD @ 9390'. Correct CTD to 9394'. 05:00 - 05:05 0.08 DRILL P PROD1 Check TF - @ 35R. Establish frees pin = 1.65bpm/3000psi. PVT = 327bbls. lAP = 165psi, OAP = 380psi. 05:05 - 05:30 0.42 DRILL P PROD1 Begin drilling buildlturn section with 7L TF, 1.65/1.65bpm, 3000/3350psi & 40fph ave ROP. See RA PIP tag @ 9380.2'. Drill to 9412' with occasional motor stalling. Lost ca. 3bbls mud & gained it back. Also TF flopped around from 30L to 80L - suspect we're in fault-1 zone. 05:30 - 05:45 0.25 DRILL P PROD1 PUH to 9058' for tie-in log. 05:45 - 07:00 1.25 DRILL P PROD1 Log GR & tie-into TSAD logging down. Added 1 ft to CTD. RIH and logged down across RA tag. Tied-in RA tag is at 9381 .5 ft. Corrected top of window at 9376 ft, Bottom of window at 9384 ft. 07:00 - 08:10 1.17 DRILL P PROD1 Drilling Build section in Zone 3, 1.6 bpm, 3000-4000 psi, 10R, 45 deg incl, Drilled to 9450'. TF jumped to low side. 08:10 - 08:25 0.25 DRILL P PROD1 Orient TF back to high side. 08:25 - 10:00 1.58 DRILL P PROD1 Drilling Build section in Zone 3, 1.6 bpm, 3000-4000 psi, 10R, 45 deg incl, Drilled to 9500 ft. Lost returns at 9460 and 9475 ft. Quicklly had full returns, 2-6 Printed: 4/19/2004 12:10:10 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-25 07-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/8/2004 Rig Release: 4/18/2004 Rig Number: N1 Spud Date: 4/13/1983 End: 4/12/2004 08:25 - 10:00 1.58 DRILL P PROD1 min. full to partial losses. Geo said just high perm sections in Z3. 10:00 - 11 :40 1.67 DRILL P PROD1 Drilling build I turn section in Zone 2. 1.6 bpm, 3000 - 3700 psi, 90R, 62 deg incl, 80 FPH, Drilled to 9585 ft. 10 BPH fluid loss. 11 :40 - 12:00 0.33 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. 12:00 - 12:30 0.50 DRILL P PROD1 Orient TF to 90R. 12:30 - 14:00 1.50 DRILL P PROD1 Drilling build / turn section in Zone 2. 1.6 bpm, 3000 - 3700 psi, 90L, 56 deg incl, 30 FPH, Drilled to 9630' 10 BPH fluid loss. 14:00 - 15:30 1.50 DRILL P PROD1 Drilling build / turn section in Zone 2. 1.6 bpm, 3100 - 3700 psi, 40L, 57 deg incl, 80 FPH, Drilled to 9660'. 15:30 - 16:20 0.83 DRILL P PROD1 Drilling build I turn section in Zone 2. 1.6 bpm, 3100 - 3700 psi, 90L, 64 deg incl, 70 FPH, Drilled to 9681 '. Unable to orient. 10 BPH fluid loss. 16:20 - 18:00 1.67 DRILL N DFAL PROD1 POH for failed orienter. Clean hole to window. Clean window. Flag CT at 9200' EOP. POH. Bleed lAP to 20 psi, and OAP to 120 psi. Pump 1.7 bpm while POH. 18:00 - 18:15 0.25 DRILL P PROD1 Held PJSM for C/O drilling BHA. 18:15 -19:00 0.75 DRILL N DFAL PROD1 SIB injector. Check motor - OK. LlO bit - 6/3/1. C/O MWD probes. Check orienter - leaking oil from blown seals. Readjust motor bend to 1.5degs. Phase-1 driving conditions declared in GPB. 19:00 - 20:00 1.00 DRILL N DFAL PROD1 MIU & lock tite build section BHA #5 with used HYC DS100 2.7" x 3" bicenter bit, 1.5deg BHI Xtreme motor, Sperry GR-DIR MWD, new orienter & BKR MHA (OAL = 59.14'). Scribe tools. M/U injector. 20:00 - 21 :50 1.83 DRILL N DFAL PROD1 RIH drilling BHA #5. SHT MWD & orienter @ 2800' - OK. Continue RIH. Correct -5' @ the flag. RIH clean thru window & tag TD @ 9680'. Correct CTD to 9681'. 21 :50 - 22:30 0.67 DRILL P PROD1 Orient TF around to 65R. Establish freespin = 1.65bpm/3000psi. P/U wt = 31 k, SIO wt = 16k. PVT = 185bbls. lAP = 85psi, OAP = 20psi. Phase-2 driving conditions declared in all GPB access roads & pads. 22:30 - 23:00 0.50 DRILL P PROD1 Drill to 9693' with 90R TF, 1.7/1.55bpm, 3000/3400psi, 3k WOB & 25fph ave ROP. Drilling very ratty with TF allover. 23:00 - 23:30 0.50 DRILL P PROD1 Orient & drill to 9703' with 75R TF, 1.7/1.55bpm, 3000/3400psi, 3k WOB & 20fph ave ROP. Losing 10bbls/hr. 23:30 - 00:00 0.50 DRILL P PROD1 Orient & drill to 9710' with 40R TF, 1.7/1.55bpm, 3000/3400psi, 3k WOB & 15fph ave ROP. 4/13/2004 00:00 - 00:50 0.83 DRILL P PROD1 Orient & drill to 9714' with HS TF, 1.7/1.55bpm, 3000/3400psi, 3k WOB & 1 Of ph ave ROP. 00:50 - 01 :30 0.67 DRILL P PROD1 Attempt to orient on btm - not getting clicks. PUH to 9400' & orient to 90R. RBIH & TF flop to LHS again. PUH & reorient again - not getting clicks. Retry @ btm - no luck. 01 :30 - 03:10 1.67 DRILL N DFAL PROD1 POOH for orienter change. PVT = 155bbls. Try to orient in the 5-1/2" tbg - still no luck. Continue POOH. 03: 1 0 - 03:20 0.17 DRILL N DFAL PROD1 OOH. SIB injector. Flush BHA. Check orienter - hear some internal clunk sound. Check bit - OK. C/O orienter. Pltest CTC - OK. 03:20 - 03:50 0.50 DRILL N DFAL PROD1 M/U & lock tite build section BHA #6 with same HYC DS100 2.7" x 3" bicenter bit, 1.5deg BHI Xtreme motor, Sperry GR-DIR Printed: 4/19/2004 12: 1 0: 1 0 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -25 07-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/8/2004 Rig Release: 4/18/2004 Rig Number: N1 Spud Date: 4/13/1983 End: 4/13/2004 03:20 - 03:50 0.50 DRILL N DFAL PROD1 MWD, new orienter & BKR MHA (OAL = 59.14'). Scribe tools. Mark orienter & M/U injector. 03:50 - 04:00 0.17 DRILL N DFAL PROD1 Function test orienter @ surface. Unstab injector & check orienter mark - got 3 for 3 clicks. M/U injector. 04:00 - 05:35 1.58 DRILL N DFAL PROD1 RIH drilling BHA #6. Correct -8' @ the flag. RIH clean thru window & tag TD @ 9711'. Correct CTD to 9714'. 05:35 - 06:00 0.42 DRILL N DFAL PROD1 PUH to 9470' (above 44degs DLS) & orient TF to 50R. RBIH to btm. 06:00 - 07:30 1.50 DRILL P PROD1 Drilling 22 build section. 1.6 bpm, 3150 - 3800 psi, 14R, 70 deg incl, 60 fph, Drilled to 9750 ft. 07:30 - 08:00 0.50 DRILL P PROD1 Drilling 22 build section. 1.6 bpm, 3150 - 3800 psi, 30R, 82 deg incl, 100 fph, Drilled to 9800'. 10 BPH fluid loss. 08:00 - 09:15 1.25 DRILL P PROD1 Drilling 22 build section. 1.6 bpm, 3150 - 3800 psi, 130R, 85 deg incl, 60 fph, Drilled to 9856'. Swap well to new FloPro while drilling. Drilling with New FloPro at 9850'. 09:15-10:11 0.93 DRILL P PROD1 Orient TF to 70R. Not getting all clicks. 10:11 -10:45 0.57 DRILL P PROD1 Drilling 22. 1.7 bpm, 2820-3600 psi, 80R, 83 deg incl, 100 FPH, Drilled to 9880'. Getting 27 deg DLS from 1.5 deg bent motor. 10:45 - 12:50 2.08 DRILL P PROD1 POH for Lateral BHA. Flag CT at 9200' EOP. POH while circ at 1.8 bpm. 12:50 - 13:30 0.67 DRILL P PROD1 LlO MWD Build BHA. 13:30 - 21 :00 7.50 DRILL N SFAL PROD1 Found reel spokes were cracked and broken where spokes connect to the reel hub. Discuss with ANC team. Well is full of New FloPro & swab valve is closed. SWS welder weld cracks in spokes using metal plates to spread out stress area. Tuboscope conduct MPI on welds. 21 :00 - 21 :15 0.25 DRILL N PROD1 PJSM for PU BHA. 21:15 - 22:00 0.75 DRILL N PROD1 PU BHA. MU bit. PU MWD and install probe. Scribe MWD and motor. 22:00 - 22:15 0.25 DRILL P PROD1 Pull test and PT CTC. Mark BHA. Stab on well and function orienter. Unstab and verify orientations. 22:15 - 00:00 1.75 DRILL P PROD1 RIH. SHT MWD. RIH and test orienter at. Correct depth to 9,200' EOP flag. -6' correction. 4/14/2004 00:00 - 00:15 0.25 DRILL P PROD1 RIH to window. Set down on whipstock with pump off. PU and get TF, low side. Orient to 13R. Run through window. 00: 15 - 00:30 0.25 DRILL P PROD1 Tie in to RA marker. + 4.5' correction. 00:30 - 00:45 0.25 DRILL P PROD1 RIH. Tag at 9,881'. Orient. 00:45 - 03:20 2.58 DRILL P PROD1 Drill to 10,034'. 03:20 - 04:10 0.83 DRILL P PROD1 Wiper trip to window from 10,034'. 04: 10 - 06:30 2.33 DRILL P PROD1 Drill to 10139' at 1.7/1.7 bpm, 3050/3220 psi. 06:30 - 07:15 0.75 DRILL P PROD1 Orient TF to 95L. Establish freespin = 1.6bpm/2900psi. PIU wt = 31 k, S/O wt = 17k. PVT = 299bbls. lAP = 240psi, OAP = 150psi. 107:15 - 07:50 0.58 DRILL P PROD1 Drill to 10165' with 90-100L TF, 1.6/1.6bpm, 2900/3000psi, 2k WOB & 55fph ave ROP. 107:50 - 08:10 0.33 DRILL P PROD1 Orient 2 clicks & drill to 10188' with 70L TF, 1.6/1.6bpm, 2900/3200psi, 3k WOB & 70fph ave ROP. Not getting good surveys. 108:10 - 08:25 0.25 DRILL P PROD1 Orient 2 clicks & drill to 10196' with 45L TF, 1.6/1.6bpm, i 2900/3200psi, 3k WOB & 35fph ave ROP. I I Printed: 4/19/2004 12:10:10 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-25 07-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/8/2004 Rig Release: 4/18/2004 Rig Number: N1 Spud Date: 4/13/1983 End: 4/14/2004 08:25 - 09:10 0.75 DRILL P PROD1 Wiper trip clean to window. RBIH to btm. 09:10 - 09:25 0.25 DRILL P PROD1 Drill to 10207' with 45L TF, 1.6/1.6bpm, 3000/3300psi, 5k WOB & 45fph ave ROP. 09:25 - 09:50 0.42 DRILL P PROD1 Pump up survey. 09:50 - 10:00 0.17 DRILL P PROD1 Drill to 10215' with 45L TF, 1.6/1.6bpm, 3100/3400psi, 5k WOB & 95fph ave ROP. Geo wants to target 8949 - 8950ftvd 10:00 - 10:30 0.50 DRILL P PROD1 Orient TF to 70R. 10:30 - 10:45 0.25 DRILL P PROD1 Attempt to drill ahead but not getting any differential & motor work. Decide to POOH to inspect BHA. 10:45 - 12:45 2.00 DRILL N DFAL PROD1 Paint EOP flag @ 9200' & POOH lateral BHA # 7. 12:45-13:15 0.50 DRILL N PROD1 OOH. SIB injector. Flush BHA. Check BHA - nothing amiss. Check bit - chewed up (8/4/1). C/O orienter, motor & bit. P/test CTC - OK. 13:15 - 13:40 0.42 DRILL N PROD1 M/U & lock tite drilling BHA #8 with new HYC DS100 2.7" x 3" bicenter bit, new 0.8deg BHI Xtreme motor, Sperry GR-DIR MWD, new orienter & BKR MHA (OAL = 59.15'). Scribe tools. M/U injector. 13:40 - 15:40 2.00 DRILL N PROD1 RIH drilling BHA #8. SHT orienter & MWD @ 3000' - OK. Continue RIH. Correct -4.7' @ the flag. RIH clean thru window to 9410'. 15:40 - 16:00 0.33 DRILL N PROD1 Log up GR & tie-into RA PIP tag. Add 4.5' to CTD. 16:00 - 16:20 0.33 DRILL N PROD1 RIH drilling BHA #8 to TD tagged @ 10219'. 16:20 - 16:45 0.42 DRILL N PROD1 Orient TF to 70R. Establish freespin = 1.6bpm/2900psi. P/U wt = 30k, SIO wt = 17k. PVT = 262bbls. lAP = 250psi, OAP = 170psi. 16:45 - 17:20 0.58 DRILL P PROD1 Drill to 10239' with 90R TF, 1.6/1.6bpm, 2900/31 OOpsi, 2k WOB & 40fph ave ROP. 17:20-18:15 0.92 DRILL P PROD1 Orient & drill to 10273' with 130-170R TF, 1.6/1.6bpm, 2780/3050psi, 4k WOB & 50fph ave ROP. 18:15-18:30 0.25 DRILL P PROD1 Orient to 90R. 18:30 - 20:00 1.50 DRILL P PROD1 Pit volume=255bbls. IA=321, OA=228. Drill to 10332.' 20:00 - 20:30 0.50 DRILL N DFAL PROD1 MWD failure. Trouble shoot MWD. 20:30 - 22:30 2.00 DRILL N DFAL PROD1 POOH to change MWD. Adjust reel brace plates. 22:30 - 22:45 0.25 DRILL N DFAL PROD1 PJSM for handling BHA. 22:45 - 23:50 1.08 DRILL N DFAL PROD1 Break bit. MU new bicenter bit. Inspect BHA. Change MWD probes and pulser. 23:50 - 00:00 0.17 DRILL N DFAL PROD1 PT coil connecter, failed. 4/15/2004 00:00 - 00:50 0.83 DRILL N DFAL PROD1 Change CTC. PT and Pull test. 00:50 - 02:50 2.00 DRILL N DFAL PROD1 RIH. SHT MWD. RIH to 3,000'. test orienter. RIH. Tag at 10,331 '. Correct to 10,332'. 02:50 - 03:00 0.17 DRILL N DFAL PROD1 Orient TF to 90R. 03:00 - 06:00 3.00 DRILL P PROD1 Pit volume 235 bbls. Drill to 10500' at 1.7/1.73,000/3,200 psi. Losing 4 bph. 06:00 - 07:05 1.08 DRILL P PROD1 Wiper trip clean to window. RBIH to btm. 07:05 - 07:20 0.25 DRILL P PROD1 Drill to 10515' with 35-45L TF, 1.6/1.6bpm, 3050/3420psi, 3k WOB & 60fph ave ROP. 07:20 - 07:40 0.33 DRILL P PROD1 Drill to 10540' with 25-35L TF, 1.6/1.6bpm, 3050/3350psi, 3k WOB & 75fph ave ROP. 07:40 - 08:00 0.33 DRILL P PROD1 Orient TF to 90R. 08:00 - 08:20 0.33 DRILL P PROD1 Drill to 10572' with 90R TF, 1.6/1.6bpm, 3050/3340psi, 3k WOB & 95fph ave ROP. 08:20 - 08:50 0.50 DRILL P PROD1 Orient TF around to 45R. 08:50 - 08:55 0.08 DRILL P I PROD1 Drill to 10579' with 45R TF, 1.6/1.6bpm, 3050/3460psi, 5k Printed: 4/19/2004 12:10:10 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-25 07-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/8/2004 Rig Release: 4/18/2004 Rig Number: N1 Spud Date: 4/13/1983 End: 4/15/2004 08:50 - 08:55 0.08 DRILL P PROD1 WOB & 85fph ave ROP. 08:55 - 09:20 0.42 DRILL P PROD1 Orient 2 clicks & drill to 10601' with 45-60R TF, 1.6/1.6bpm, 3050/3350psi, 2k WOB & 55fph aye ROP. Geo does not want to drill deeper than 8950ftvd. 09:20 - 09:25 0.08 DRILL P PROD1 Orient 1 click & drill to 10608' with 60R TF, 1.6/1.6bpm, 3050/3350psi, 2k WOB & 85fph aye ROP. 09:25 - 09:55 0.50 DRILL P PROD1 Orient 2 clicks & drill to 10642' with 115R TF, 1.6/1.6bpm, 3050/3350psi, 2k WOB & 70fph aye ROP. 09:55 - 11 :40 1.75 DRILL P PROD1 Wiper trip to window. Observe slight 10k O/pull @ 9800'. RBIH to 9850'. Backream 2x to 9790' - clean. RBIH to btm. 11 :40 - 11 :50 0.17 DRILL P PROD1 Orient TF to LS. 11 :50 - 11 :55 0.08 DRILL P PROD1 Drill to 10655' with 170R TF, 1.6/1.6bpm, 3180/3460psi, 3k WOB & 155fph ave ROP. 11 :55 - 12: 10 0.25 DRILL P PROD1 Orient 2 clicks & drill to 10671' with 150L TF, 1.6/1.6bpm, 3180/3460psi, 3k WOB & 65fph aye ROP. 12:10 - 12:25 0.25 DRILL P PROD1 Orient 2 clicks & drill to 10680' with 135L TF, 1.6/1.6bpm, 3180/3460psi, 2k WOB & 35fph ave ROP. 12:25 - 13:10 0.75 DRILL P PROD1 Orient 2 clicks & drill to 10763' with 90-100L TF, 1.6/1.6bpm, 3180/3380psi, 2k WOS & 110fph aye ROP. Geo wants to target 8948 - 8950ftvd. 13:10 - 13:40 0.50 DRILL P PROD1 Orient TF around to 120R. P/U wt = 31 k, S/O wt = 15k. PVT = 180bbls. lAP = 470psi, OAP = 400psi. 13:40 - 14:05 0.42 DRILL P PROD1 Drill to 10796' with 11 OR TF, 1.6/1.6bpm, 3000/3150psi, 1 k WOB & 100fph ave ROP. 14:05 - 15:20 1.25 DRILL P PROD1 Wiper trip clean to window. RBIH to btm. 15:20 - 15:25 0.08 DRILL P PROD1 Orient TF to 180R. Pump down 50bbls fresh mud. 15:25 - 17:35 2.17 DRILL P PROD1 Drill & TD well @ 10950' with 130L-170R TF, 1.7/1.7bpm, 3280/3450psi, 5k WOB & 95fph ave ROP. 17:35 - 19:30 1.92 DRILL P PROD1 Wiper trip clean to window. Tie in to RA tag, +3.5'. RIH, start pumping liner running pill. Tag bottom at 10952', corrected TD. 19:30 - 21 :45 2.25 DRILL P PROD1 Lay in liner running pill in OH. POOH to run liner. 21 :45 - 22:30 0.75 DRILL P PROD1 LD BHA. Bit 2-2-BT-T-X-NA-NO-TD 22:30 - 00:00 1.50 CASE P COMP Cut off BD Kendall CTC. Weld on CTC. Pull test and PT connecter. 4/16/2004 00:00 - 00:30 0.50 CASE P COMP PJSM for PU liner. RU to run liner. 00:30 - 04:00 3.50 CASE P COMP Run 2 3/8",4.6#, L-80, STL liner. 04:00 - 04:30 0.50 CASE P COMP MU deployment sleeve and stab liner running tool. PU to confirm running tool is latched in to lower GS profile. Running tool pulled free and damaged the top GS profile. Send Baker to shop to change out deployment sleeve and running tool. 04:30 - 05:15 0.75 CASE P COMP MU dart catcher. Pump dart. Dart hit at 39.5bbls. RD dart catcher. Lots of thick black debis (schmoo) in front and behind dart. 05:15 - 06:00 0.75 CASE P COMP BOT on location wI new deployment sleeve. RU to pump second dart. Pump dart. Still getting some schmoo in front of dart. Cleaner behind dart. RD injector, RU elevators. 06:00 - 06:45 0.75 CASE P COMP M/U Baker new deployment sleeve & LSRT. Confirm LBRT engagement - OK. 06:45 - 08:30 1.75 CASE P COMP RIH with liner on CT. See 1st flag @ 9346'. Correct to 9340'. Check up wt - 31.5k, down wt - 18.5k. RIH smoothly @ 50 fpm thru window. See 2nd flag right on depth. Tag TD @ 10950' CTD. P/U @ 32.5k. RSIH @ 14k & retag TD @ same Printed: 4/19/2004 12:10:10 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-25 07-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/8/2004 Rig Release: 4/18/2004 Rig Number: N1 Spud Date: 4/13/1983 End: 4/16/2004 06:45 - 08:30 1.75 CASE P COMP depth. Set down 10k on LBRT. 08:30 - 09:05 0.58 CASE P COMP Loadllaunch 5/8" steel ball with 800psi. Chase ball to seat with mud @ 1.7/1.7bpm, 3000psi. Slow down @ 29bbls away. Ball on seat @ 30.8bbls. Pressure up to 4360psi & release LBRT. P/U @ 27k & confirm release. Set back 1 Ok down on LBRT. 09:05 - 12:15 3.17 CASE P COMP Displace well to 2% KCI at 2.17/1.90bpm & 3650psi. Meanwhile R/U Dowell cementers. Ship back used mud to MI. 12:15 -12:40 0.42 CEMT P COMP PJSM with all personnel concerning cementing operations. PVT = 281bbls. 12:40 - 13:35 0.92 CEMT P COMP Batch mix 12bbls 15.8ppg 'G' latex cmt with additives. Cmt to wt @ 12:45hrs. Flush/PT lines to 4k. Pump 12bbls cmt slurry @ 1.96/1.71bpm & 3100psi. Close inner reel valve & clean lines. Loadllaunch CTWP with 750psi. Chase with bio-KCL @ 2.1/1.23bpm & 2150psi. Losses start healing with cement @ the shoe. CTWP engage LWP @ 39.5bbls away. Shear plug with 3300psi. Zero MM-in. Continue displacing LWP @ 1.60/1.01 bpm, 3520psi & bump @ 7bbls away with 1000psi over. Bleed off & check floats - held. Pressure up to 200psi & sting out of liner. 8.9bbls cmt pumped around shoe. CIP @ 13:30hrs. PVT = 277bbls. 13:35 - 15:00 1.42 CEMT P COMP POOH @ 100fpm pumping @ 0.40bpm to replace CT voidage only. 15:00 - 15:30 0.50 CEMT P COMP OOH I lay down LRT. 15:30 - 17:45 2.25 CLEAN P COMP PJSM I MU cleanout run BHA 17:45 - 19:00 1.25 CLEAN P COMP RIH to 8500'. 19:00 - 22:00 3.00 CLEAN P COMP WOC. 22:00 - 23:30 1.50 CLEAN P COMP RIH to PBTD pumping 1.2 bpm (max flow rate through motor). Tag at 10,926' uncorrected. Drop 1/2" steel ball to open circ. sub. Pull up hole to 10,050' while circulating ball down. Shear out circ sub with 2,600 psi. 23:30 - 00:00 0.50 CLEAN P COMP POOH pumping at 1.4 bpm, 4,000 psi. 4/17/2004 00:00 - 01 :30 1.50 CLEAN P COMP POOH pumping 1.4 bpm all the way. Started getting contaminated cement returns wI the BHA 500' from surface. Circulated out contaminated cement returns. 01 :30 - 03:00 1.50 CLEAN P COMP Rack back CSH. LD motor and mill. 03:00 - 03:15 0.25 EV AL P COMP PJSM for PU RA logging tool and TIH wI CSH. 03:15 - 03:30 0.25 EV AL P COMP RU SWS depth encoder. Place radiation signs on rig. Bring logging tools to rig floor. 03:30 - 05:00 1.50 EVAL P COMP PU logging BHA. TIH wI 31 stands of CSH. MU to CTC. 05:00 - 06:25 1.42 EVAL P COMP RIH to 8,600'. 06:25 - 07: 10 0.75 EVAL P COMP Log down at 60 fpm. 07: 10 - 07:50 0.67 EVAL P COMP Tag bottom @ 10914.7'. Start to pump 30 bbl perforation pill. 07:50 - 09:40 1.83 EVAL P COMP Pill reaches bottom of string, start logging out of hole at 60 ftlmin laying in perf pill. Stop to mark a flag at 6600' EOP. Continue POOH @ 86 ftlmin 2 bbl/min. Laydown logging BHA 09:40 - 11 :30 1.83 EVAL P COMP Lift off injector head, disconnect coil from BHA, rack back 26 stands of CSHydrill, lay down 10 joints. Lay down logging BHA. 11:30 -13:00 1.50 EVAL P COMP RU to test liner lap. Test lap to 2000 psi (1.8 bbls pumped). Good liner test. Pressure dropped to 1945 psi after 30 mins shut in. Logging showed logging run tagged bottom at 10914' and top of liner at 9110 ft. 13:00 - 13:15 0.25 PERF P COMP Safety meeting prior to running guns. 13:15 - 15:00 1.75 PERF P COMP Make up perforation BHA. TIH wI CSH. Replace injector Printed: 4/19/2004 12: 1 0: 1 0 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-25 07-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/8/2004 Rig Release: 4/18/2004 Rig Number: N1 Spud Date: 4/13/1983 End: 4/17/2004 13:15 - 15:00 1.75 PERF P COMP head. 15:00 - 16:30 1.50 PERF P COMP RIH with perf BHA @ 120 ftlmin. Tag bottom at 10914'. PU weight = 30400 Ib, SO weight = 17000 lb. 16:30 - 17:25 0.92 PERF P COMP Drop ball. Position bottom of guns at 10,912'. Circulate ball down. Slow rate at 34 bbls pumped. Ball on seat at 38.7 bbls pumped. Pit volume 241 bbls. Pressure up to 2,000 psi. Start moving guns up hole at 5 fpm. Pressure up to 3,600 psi and fire guns. Perforate wI 1.56", 6SPF, PJ 1606 guns from 10,610' to 10,910'. 17:25 - 19:30 2.08 PERF P COMP POOH at 36 fpm circulating down the coil. Pull guns above the liner top. Flow check well. Well dead. Line up to circulate across the top. POOH circulating across the top holding back pressure with the choke. 19:30 - 19:45 0.25 PERF P COMP PJSM for LD CSH. 19:45 - 21 :00 1.25 PERF P COMP LD 52 joints CSH. 21 :00 - 21 :15 0.25 PERF P COMP PJSM for LD perf guns. 21:15 - 22:45 1.50 PERF P COMP LD perf guns and off load guns. 21:45 - 23:30 1.75 WHSUR P COMP MU swizzle stick. RIH to 2,200' to freeze protect well. Lay in MeOH at 60/40. Tag up. Shut master. Clean pits. 23:30 - 00:00 0.50 RIGD P POST RU to purge reel wI nitrogen. PT lines to 4,000 psi. 4/18/2004 00:00 - 01 :00 1.00 BOPSU P POST Blow down reel with nitrogen. 01 :00 - 02:00 1.00 RIGD P POST Unstab coil. Secure to reel. 02:00 - 03:15 1.25 RIGD P POST RD goose neck. Stab injector in box. 03:15 - 04:00 0.75 RIGD P POST ND BOP. Release rig at 02:30 on 04/18/2004. Will NU and test tree cap after moving off the well due to the height of the tree. Printed: 4/19/2004 12:10:10 PM e e 05-May-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 7-25 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: 9,300.00' MD 9,376.00' MD 10,952.00' 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 11 ' ()' /IJ' Signed "MNv-J)z4, , ' Date Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager d..OL{~OC)À- RECEIVED MAY 1 2 2004 Alaska Oil & Gas Cans. Commission Anchorage AUachment(s) e Halliburton Sperry-Sun North Slope Alaska BPXA PBU_EOA DS 07 07-25A 2004 15 April, Job No. AKMW3017317, Surveyed: Survey Report 7 May, 2004 e Your Ref: API 500292093801 Surface Coordinates: 5949167.66 N, 675946.76 E (70016' 00.2358" N, 148034' 38.0053" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 svy4258 Survey Ref: Surface Coordinates relative to Project H Reference: 949167.66 N, 175946.76 E (Grid) Surface Coordinates relative to Structure Reference: 1056.83 N, 1412.27 W (True) Kelly Bushing Elevation: 57.00n above Mean Sea Level Kelly Bushing Elevation: 57.00n above Project V Reference Kelly Bushing Elevation: 57.00ft above Structure Reference SpE!..........;~-su.., DAILLING seAVlces A Halliburton Company Halliburton Sperry-Sun Survey Report for PBU_EOA OS 07 - 07-25A Your Ref: API 500292093801 Job No. AKMW3017317, Surveyed: 15 April, 2004 BPXA North Slope Alaska 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) C/100ft) 9300.00 29.600 280.170 8658.19 8715.19 889.21 S 2442.24 W 5948221.61 N 673525.97 E 1805.27 Tie On Point MWD Magnetic 9376.00 29.170 280.480 8724.41 8781.41 882.53 S 2478.93 W 5948227.44 N 673489.13 E 0.600 1841.17 Window Point 9407.13 39.640 276.760 8750.06 8807.06 879.97 S 2496.30 W 5948229.59 N 673471.71 E 34.290 1857.91 9444.82 47.550 273.730 8777.34 8834.34 877.65 S 2522.16 W 5948231.31 N 673445.80 E 21.702 1882.17 e 9476.60 54.090 271.830 8797.41 8854.41 876.47 S 2546.75 W 5948231.91 N 673421.19 E 21.093 1904.79 9507.33 62.580 278.650 8813.54 8870.54 874.01 S 2572.74 W 5948233.75 N 673395.15 E 33.445 1929.22 9557.70 64.070 303.780 8836.45 8893.45 857.85 S 2614.20 W 5948248.94 N 673353.32 E 44.604 1973.57 9585.16 57.220 315.030 8849.93 8906.93 842.76 S 2632.69 W 5948263.59 N 673334.49 E 43.513 1996.80 9616.03 55.280 298.860 8867.16 8924.16 827.39 S 2653.07 W 5948278.49 N 673313.75 E 43.955 2021.86 9647.51 60.730 285.500 8883.89 8940.89 817.43 S 2677.73 W 5948287.86 N 673288.87 E 39.893 2048.39 9678.01 61.000 274.780 8898.77 8955.77 812.76 S 2703.90 W 5948291.93 N 673262.60 E 30.703 2073.96 9710.37 64.420 276.010 8913.61 8970.61 810.05 S 2732.52 W 5948293.97 N 673233.92 E 11.095 2100.87 9742.98 72.070 277 .420 8925.68 8982.68 806.50 S 2762.58 W 5948296.81 N 673203.79 E 23.800 2129.44 9775.78 81.280 277.920 8933.24 8990.24 802.24 S 2794.18 W 5948300.33 N 673172.10 E 28.118 2159.71 9807.78 87.890 283.750 8936.26 8993.26 796.25 S 2825.43 W 5948305.59 N 673140.71 E 27.482 2190.43 9840.54 84.290 292.710 8938.49 8995.49 786.04 S 2856.44 W 5948315.07 N 673109.47 E 29.412 2222.77 9876.34 85.340 301.500 8941.74 8998.74 769.81 S 2888.14 W 5948330.55 N 673077.40 E 24.627 2258.38 9935.70 85.630 312.350 8946.42 9003.42 734.32 S 2935.38 W 5948364.94 N 673029.35 E 18.228 2316.40 9964.31 87.360 315.740 8948.17 9005.17 714.47 S 2955.90 W 5948384.30 N 673008.37 E 13.283 2343.54 9996.88 90.530 322.240 8948.77 9005.77 689.91 S 2977.25 W 5948408.35 N 672986.44 E 22.199 2373.50 10027.47 89.810 316.410 8948.68 9005.68 666.72 S 2997.18 W 5948431.07 N 672965.98 E 19.203 2401.58 e 10085.38 90.530 304.840 8948.51 9005.51 629.08 S 3041.06 W 5948467.68 N 672921.23 E 20.018 2457.52 10120.29 89.220 299.540 8948.59 9005.59 610.49 S 3070.59 W 5948485.57 N 672891.27 E 15.638 2492.21 10178.42 87.420 285.460 8950.30 9007.30 588.31 S 3124.14 W 5948506.50 N 672837.23 E 24.407 2550.06 10222.58 94.830 281.280 8949.43 9006.43 578.10 S 3167.05 W 5948515.69 N 672794.09 E 19.261 2593.10 10259.21 93.600 286.210 8946.74 9003.74 569.43 S 3202.52 W 5948523.54 N 672758.42 E 13.836 2628.79 10293.49 91.850 289.550 8945.11 9002.11 558.91 S 3235.11 W 5948533.29 N 672725.60 E 10.990 2662.68 10323.31 88.070 289.900 8945.13 9002.13 548.85 S 3263.17 W 5948542.69 N 672697.31 E 12.730 2692.32 10352.34 89.470 293.240 8945.75 9002.75 538.18 S 3290.16 W 5948552.73 N 672670.08 E 12.4 72 2721.25 10390.37 92.280 298.860 8945.17 9002.17 521.49 S 3324.30 W 5948568.61 N 672635.55 E 16.519 2759.26 7 May, 2004 - 8:52 Page 2 of 4 OrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_EOA OS 07 - 07-25A Your Ref: API 500292093801 Job No. AKMW3017317, Surveyed: 15 April, 2004 BPXA North Slope Alaska 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) 10424.36 90.090 300.270 8944.47 9001.47 504.73 S 3353.86 W 5948584.68 N 672605.61 E 7.662 2793.17 10483.52 85.600 299.040 8946.69 9003.69 475.48 S 3405.22 W 5948612.72 N 672553.58 E 7.869 2852.15 10519.13 87.630 296.050 8948.79 9005.79 459.05 S 3436.73 W 5948628.41 N 672521.70 E 10.136 2887.68 10549.01 89.300 296.400 8949.59 9006.59 445.85 S 3463.53 W 5948640.98 N 672494.60 E 5.710 2917.55 10584.10 90.180 299.740 8949.75 9006.75 429.34 S 3494.48 W 5948656.76 N 672463.27 E 9.843 2952.61 e 10622.24 94.310 308.180 8948.26 9005.26 408.08 S 3526.06 W 5948677.28 N 672431.20 E 24.617 2990.31 10653.77 91.930 307.650 8946.54 9003.54 388.73 S 3550.90 W 5948696.04 N 672405.92 E 7.733 3021 .11 10692.72 88.770 305.890 8946.30 9003.30 365.42 S 3582.09 W 5948718.62 N 672374.19 E 9.286 3059.37 10727.67 89.740 303.610 8946.76 9003.76 345.50 S 3610.80 W 5948737.86 N 672345.02 E 7.089 3093.91 10763.25 90.530 303.260 8946.67 9003.67 325.90 S 3640.49 W 5948756.76 N 672314.88 E 2.428 3129.19 10798.82 91.670 310.290 8945.99 9002.99 304.62 S 3668.96 W 5948777.37 N 672285.92 E 20.018 3164.10 10830.04 88.940 308.180 8945.82 9002.82 284.88 S 3693.14 W 5948796.54 N 672261.29 E 11.051 3194.49 10868.38 86.310 308.180 8947.41 9004.41 261.20 S 3723.25 W 5948819.51 N 672230.63 E 6.860 3231.93 10918.15 83.930 305.540 8951.65 9008.65 231.46 S 3762.92 W 5948848.32 N 672190.28 E 7.127 3280.62 10938.87 81.650 305.720 8954.25 9011.25 219.49S 3779.63 W 5948859.90 N 672173.30 E 11 .038 3300.89 10952.00 81.650 305.720 8956.15 9013.15 211.90 S 3790.17W 5948867.23 N 672162.57 E 0.000 3313.69 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). e Vertical Section is from Well Reference and calculated along an Azimuth of 296.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 1 0952.00ft. , The Bottom Hole Displacement is 3796.09ft., in the Direction of 266.800° (True). 7 May, 2004 . 8:52 Page 3 of 4 OrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_EOA OS 07 - 07-25A Your Ref: API 500292093801 Job No. AKMW3017317, Surveyed: 15 April, 2004 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9300.00 9376.00 10952.00 8715.19 8781.41 9013.15 889.21 S 882.53 S 211.90 S 2442.24 W 2478.93 W 3790.17 W Tie On Point Window Point Projected Survey e Survey tool program for 07-25A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 19300.00 0.00 9300.00 8715.19 10952.00 8715.19 CB-GYRO-MS (07-25) 9013.15 MWD Magnetic (07-25A) e 7 May, 2004 - 8:52 Page 4 of 4 OrillQuest 3.03.06.002 Halliburton Sperry-Sun e North Slope Alaska BPXA PBU_EOA DS 07 07-25 Surveyed: 2 February, 1998 r .( c ,> ~ , .:> ~ Survey Report t'" {. ~ "t -~ I-~ 7 May, 2004 e Surface Coordinates: 5949167.66 N, 675946.76 E (70016' 00.2358H N, 148034' 38.0053" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 949167.66 N, 175946.76 E (Grid) Surface Coordinates relative to Structure Reference: 1056.83 N, 1412.27 W (True) Kelly Bushing Elevation: 57.00ft above Mean Sea Level Kelly Bushing Elevation: 57.00ft above Project V Reference Kelly Bushing Elevation: 57.00ft above Structure Reference SIOE!f""'f""'Y-SU:ï! DRfLLfNGSSRVIC:SS A Halliburton Company ,-.¡ ~ <0 .) ~ ,j o ~ Survey Ref: svy897 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 07 - 07-25 Surveyed: 2 February, 1998 BPXA North Slope Alaska 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) 0.00 0.000 0.000 -57.00 0.00 0.00 N 0.00 E 5949167.66 N 675946.76 E 0.00 CB-GYRO-MS 100.00 0.200 182.000 43.00 100.00 0.17 S 0.01 W 5949167.49 N 675946.76 E 0.200 0.06 200.00 0.180 176.020 143.00 200.00 0.51 S 0.00 E 5949167.15 N 675946.77 E 0.028 0.15 300.00 0.170 168.450 243.00 300.00 0.81 S 0.04 E 5949166.85 N 675946.82 E 0.025 0.20 400.00 0.220 192.570 343.00 400.00 1.14 S 0.03 E 5949166.52 N 675946.81 E 0.095 0.31 e 500.00 0.200 181.000 443.00 500.00 1.50 S 0.02W 5949166.16 N 675946.78 E 0.047 0.47 600.00 0.180 183.970 543.00 600.00 1.83 S 0.03W 5949165.83 N 675946.77 E 0.022 0.58 700.00 0.180 176.170 643.00 700.00 2.15 S 0.03W 5949165.51 N 675946.78 E 0.024 0.67 800.00 0.220 184.470 743.00 800.00 2.49 S 0.04W 5949165.16 N 675946.78 E 0.049 0.78 900.00 0.180 176.500 843.00 900.00 2.84 S 0.04W 5949164.82 N 675946.78 E 0.049 0.89 1000.00 0.150 174.630 942.99 999.99 3.13 S 0.02W 5949164.53 N 675946.81 E 0.030 0.95 1100.00 0.070 215.450 1042.99 1099.99 3.31 S 0.04W 5949164.35 N 675946.79 E 0.107 1.03 1200.00 0.150 283.750 1142.99 1199.99 3.33 S 0.21 W 5949164.33 N 675946.63 E 0.140 1.19 1300.00 0.200 263.330 1242.99 1299.99 3.32 S 0.51 W 5949164.33 N 675946.33 E 0.079 1.47 1400.00 0.280 222.380 1342.99 1399.99 3.52 S 0.84W 5949164.12 N 675946.00 E 0.184 1.86 1500.00 0.450 222.720 1442.99 1499.99 3.99 S 1.28W 5949163.64 N 675945.58 E 0.170 2.41 1600.00 0.470 217.300 1542.99 1599.99 4.60S 1.79W 5949163.02 N 675945.08 E 0.048 3.08 1700.00 0.400 209.630 1642.99 1699.99 5.23 S 2.21 W 5949162.38 N 675944.67 E 0.091 3.67 1800.00 0.350 183.680 1742.98 1799.98 5.84 S 2.40 W 5949161.76 N 675944.49 E 0.175 4.04 1900.00 0.320 69.650 1842.98 1899.98 6.05 S 2.16W 5949161.56 N 675944.74 E 0.562 3.87 2000.00 0.400 49.070 1942.98 1999.98 5.72 S 1.64W 5949161.90 N 675945.26 E 0.151 3.27 2100.00 0.530 78.130 2042.98 2099.98 5.40 S 0.92W 5949162.24 N 675945.97 E 0.265 2.49 2200.00 0.750 117.120 2142.97 2199.97 5.60 S 0.12 E 5949162.06 N 675947.01 E 0.475 1.56 e 2300.00 0.700 120.600 2242.96 2299.96 6.21 S 1.22 E 5949161.48 N 675948.13 E 0.067 0.69 2400.00 0.720 120.850 2342.96 2399.96 6.84S 2.29 E 5949160.87 N 675949.21 E 0.020 -0.14 2500.00 0.750 123.920 2442.95 2499.95 7.53 S 3.37 E 5949160.21 N 675950.31 E 0.049 -0.97 2600.00 0.700 129.380 2542.94 2599.94 8.28 S 4.39 E 5949159.48 N 675951.34 E 0.085 -1.71 2700.00 5.800 252.470 2642.78 2699.78 10.20 S 0.04 E 5949157.47 N 675947.03 E 6.210 3.01 2800.00 8.270 252.950 2742.02 2799.02 13.83 S 11.66 W 5949153.56 N 675935.43 E 2.471 15.25 2900.00 9.030 249.020 2840.88 2897.88 18.75 S 25.86 W 5949148.31 N 675921.34 E 0.962 30.28 3000.00 11.130 245.380 2939.33 2996.33 25.58 S 41.97 W 5949141.11 N 675905.40 E 2.193 47.69 3100.00 13.830 244.770 3036.96 3093.96 34.69 S 61.56 W 5949131.54 N 675886.03 E 2.703 69.10 3200.00 16.180 245.630 3133.54 3190.54 45.54 S 85.06 W 5949120.14 N 675862.78 E 2.360 94.78 3300.00 18.520 246.720 3228.99 3285.99 57.57 S 112.35 W 5949107.48 N 675835.79 E 2.362 124.41 3400.00 21.120 246.300 3323.06 3380.06 71.09 S 143.44 W 5949093.24 N 675805.02 E 2.604 158.12 7 May, 2004 - 8:38 Page 2 of 5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 07 - 07-25 Surveyed: 2 February, 1998 BPXA North Slope Alaska 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) (O/100ft) 3500.00 24.780 242.370 3415.13 3472.13 88.06 S 178.52 W 5949075.46 N 675770.35 E 3.966 196.66 3600.00 26.280 241.430 3505.36 3562.36 108.36 S 216.53 W 5949054.27 N 675732.83 E 1.554 239.00 3700.00 26.270 241.320 3595.03 3652.03 129.57 S 255.38 W 5949032.16 N 675694.47 E 0.050 282.41 3800.00 26.020 241.300 3684.80 3741.80 150.72 S 294.04 W 5949010.10 N 675656.32 E 0.250 325.62 3900.00 25.820 241.120 3774.74 3831.74 171.78 S 332.35 W 5948988.16 N 675618.52 E 0.215 368.46 e 4000.00 25.880 240.550 3864.73 3921.73 193.02 S 370.42 W 5948966.03 N 675580.95 E 0.256 411.14 4100.00 25.950 240.580 3954.68 4011.68 214.50 S 408.48 W 5948943.67 N 675543.40 E 0.071 453.88 4200.00 25.750 240.500 4044.67 4101.67 235.95 S 446.45 W 5948921.34 N 675505.95 E 0.203 496.51 4300.00 25.670 240.100 4134.77 4191.77 257.44 S 484.13 W 5948898.98 N 675468.78 E 0.191 538.89 4400.00 25.450 239.970 4224.99 4281.99 278.99 S 521.51 W 5948876.56 N 675431.92 E 0.227 581.00 4500.00 25.330 239.900 4315.33 4372.33 300.47 S 558.62 W 5948854.22 N 675395.32 E 0.124 622.83 4600.00 24.850 239.750 4405.89 4462.89 321.78 S 595.27 W 5948832.05 N 675359.17 E 0.484 664.18 4700.00 24.680 239.980 4496.69 4553.69 342.81 S 631.50 W 5948810.18 N 675323.44 E 0.195 705.03 4800.00 24.950 240.030 4587.46 4644.46 363.79 S 667.85 W 5948788.36 N 675287.59 E 0.271 745.98 4900.00 24.650 240.350 4678.24 4735.24 384.65 S 704.24 W 5948766.66 N 675251.70 E 0.329 786.94 5000.00 23.750 240.250 4769.45 4826.45 404.96 S 739.85 W 5948745.52 N 675216.57 E 0.901 826.99 5100.00 23.470 240.120 4861.08 4918.08 424.87 S 774.60 W 5948724.80 N 675182.30 E 0.285 866.10 5200.00 23.150 240.020 4952.92 5009.92 444.61 S 808.90 W 5948704.26 N 675148.48 E 0.322 904.72 5300.00 23.030 240.050 5044.91 5101.91 464.20 S 842.87 W 5948683.89 N 675114.97 E 0.121 942.99 5400.00 23.380 240.980 5136.82 5193.82 483.59 S 877.17 W 5948663.70 N 675081.13 E 0.507 981.51 5500.00 23.870 241.050 5228.43 5285.43 503.01 S 912.22 W 5948643.47 N 675046.54 E 0.491 1020.77 5600.00 23.930 241.220 5319.86 5376.86 522.57 S 947.71 W 5948623.08 N 675011.53 E 0.091 1060.47 5700.00 24.430 241.120 5411.09 5468.09 542.32 S 983.59 W 5948602.50 N 674976.12 E 0.502 1100.61 e 5800.00 24.770 241.180 5502.01 5559.01 562.41 S 1020.05 W 5948581.57 N 674940.13 E 0.341 1141.40 5900.00 24.830 241.400 5592.79 5649.79 582.56 S 1056.84 W 5948560.56 N 674903.83 E 0.110 1182.53 6000.00 25.200 241.270 5683.41 5740.41 602.84 S 1093.94 W 5948539.42 N 674867.21 E 0.374 1223.99 6100.00 25.250 240.880 5773.87 5830.87 623.45 S 1131.24 W 5948517.94 N 674830.40 E 0.174 1265.75 6200.00 25.150 240.950 5864.35 5921.35 644.15 S 1168.45 W 5948496.38 N 674793.68 E 0.104 1307.44 6300.00 24.570 241.580 5955.09 6012.09 664.36 S 1205.31 W 5948475.31 N 674757.30 E 0.638 1348.65 6400.00 24.550 241 .400 6046.04 6103.04 684.20 S 1241.84W 5948454.62 N 674721.25 E 0.077 1389.43 6500.00 24.500 240.750 6137.02 6194.02 704.28 S 1278.17 W 5948433.70 N 674685.40 E 0.274 1430.10 6600.00 23.950 239.800 6228.21 6285.21 724.62 S 1313.80 W 5948412.53 N 674650.25 E 0.674 1470.18 6700.00 23.480 239.170 6319.77 6376.77 745.04 S 1348.45 W 5948391.31 N 674616.09 E 0.534 1509.34 6800.00 23.070 238.480 6411.63 6468.63 765.49 S 1382.26 W 5948370.07 N 674582.77 E 0.492 1547.71 6900.00 22.650 238.220 6503.77 6560.77 785.88 S 1415.33 W 5948348.92 N 674550.19 E 0.432 1585.36 7 May, 2004 - 8:38 Page 3 of5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 07 - 07-25 Surveyed: 2 February, 1998 BPXA North Slope Alaska 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) 7000.00 22.200 238.450 6596.21 6653.21 805.90 S 1447.80 W 5948328.14 N 674518.19 E 0.458 1622.32 7100.00 23.370 246.320 6688.43 6745.43 823.76 S 1482.07 W 5948309.49 N 674484.35 E 3.262 1660.36 7200.00 24.850 252.550 6779.72 6836.72 838.03 S 1520.29 W 5948294.33 N 674446.48 E 2.942 1701.10 7300.00 25.220 253.320 6870.32 6927.32 850.44 S 1560.74 W 5948280.97 N 674406.32 E 0.493 1743.41 7400.00 25.300 253.900 6960.76 7017.76 862.48 S 1601.68 W 5948267.98 N 674365.68 E 0.260 1786.08 e 7500.00 25.370 254.700 7051.14 7108.14 874.06 S 1642.87 W 5948255.44 N 674324.77 E 0.349 1828.85 7600.00 24.930 255.720 7141.66 7198.66 884.91 S 1683.96 W 5948243.63 N 674283.94 E 0.618 1871.31 7700.00 24.380 257.520 7232.55 7289.55 894.57 S 1724.54 W 5948233.02 N 674243.60 E 0.931 1912.92 7800.00 23.750 259.170 7323.86 7380.86 902.82 S 1764.47 W 5948223.85 N 674203.87 E 0.922 1953.49 7900.00 23.830 261.020 7415.36 7472.36 909.75 S 1804.20 W 5948215.99 N 674164.32 E 0.751 1993.48 8000.00 24.400 262.580 7506.63 7563.63 915.58 S 1844.64 W 5948209.22 N 674124.03 E 0.855 2033.81 8100.00 24.650 263.700 7597.61 7654.61 920.53 S 1885.85 W 5948203.30 N 674082.94 E 0.528 2074.62 8200.00 25.100 264.850 7688.34 7745.34 924.72 S 1927.70 W 5948198.13 N 674041.20 E 0.661 2115.82 8300.00 25.130 266.920 7778.88 7835.88 927.77 S 1970.03 W 5948194.10 N 673998.95 E 0.879 2157.13 8400.00 25.720 268.070 7869.20 7926.20 929.64 S 2012.92 W 5948191.23 N 673956.12 E 0.769 2198.62 8500.00 26.480 269.730 7959.00 8016.00 930.48 S 2056.90 W 5948189.36 N 673912.17 E 1.054 2240.85 8600.00 27.020 270.720 8048.30 8105.30 930.30 S 2101.91 W 5948188.49 N 673867.17 E 0.700 2283.75 8700.00 27.700 272.570 8137.11 8194.11 928.97 S 2147.84 W 5948188.75 N 673821.22 E 1.089 2327.20 8800.00 28.820 274.450 8225.20 8282.20 926.06 S 2195.09 W 5948190.55 N 673773.91 E 1.431 2371.43 8900.00 29.600 276.600 8312.48 8369.48 921.35 S 2243.66 W 5948194.13 N 673725.25 E 1.307 2416.37 9000.00 30.620 278.800 8398.99 8455.99 914.61 S 2293.36 W 5948199.70 N 673675.40 E 1.503 2461.80 9200.00 30.180 280.120 8571.49 8628.49 897.99 S 2393.19 W 5948213.99 N 673575.21 E 0.400 2552.12 e 9300.00 29.600 280.170 8658.19 8715.19 889.21 S 2442.24 W 5948221.61 N 673525.97 E 0.581 2596.32 9400.00 29.030 280.120 8745.39 8802.39 880.58 S 2490.44 W 5948229.11 N 673477.58 E 0.571 2639.74 9500.00 27.870 280.520 8833.31 8890.31 872.05 S 2537.31 W 5948236.54 N 673430.53 E 1.176 2681.93 9600.00 27.220 280.680 8921.97 8978.97 863.55 S 2582.76 W 5948243.98 N 673384.89 E 0.654 2722.78 9700.00 26.280 280.720 9011.27 9068.27 855.19 S 2626.99 W 5948251.30 N 673340.48 E 0.940 2762.49 9750.00 26.230 280.750 9056.11 9113.11 851.D7 S 2648.72 W 5948254.92 N 673318.66 E 0.103 2782.01 9816.00 26.230 280.750 9115.31 9172.31 845.63 S 2677.38 W 5948259.68 N 673289.88 E 0.000 2807.73 9855.00 26.230 280.750 9150.30 9207.30 842.41 S 2694.31 W 5948262.50 N 673272.87 E 0.000 2822.94 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 252.63r (True). 7 May, 2004 - 8:38 Page 4 of5 Dril/Quest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 07 - 07-25 Surveyed: 2 February, 1998 BPXA North Slope Alaska Based upon Minimum Curvature type calculations, at a Measured Depth of 9855.00ft., The Bottom Hole Displacement is 2822.94ft., in the Direction of 252.637° (True). Survey too/prOgram for 07-25 e Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 0.00 9855.00 9207.30 CB-GYRO-MS e 7 May, 2004 - 8:38 Page 50f5 Dril/Quest 3.03.06.002 PRUDHOE SA Y UN!T WELL: 07-25A PERMIT No: AANo: S8:;33 T11 · -- ~ r=t) } '~ FRANK H. MURKOWSKI, GOVERNOR AItASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Explûration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 07-25A BP Exploration (Alaska) Inc. Permit No: 204-052 Surface Location: 1751' SNL, 269' WEL, SEe. 33,TIIN, R14E, UM Bottomhole Location: 2013' SNL, 4020' WEL, SEC. 33, T11N, R14E, UM Dear Ms. Endacott: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you rrom obtaining additional permits or approvals required by law rrom 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 resuh in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commiss' n 0 witness any required test. Contact the Commission's North Slope petroleum field inspe or 659-3607 (pager). BY ORDER ~9HE COMMISSION DATED this~day of March, 2004 èè: Dèpartment ofFish & Gamè, Habitat SèètiOn w/o ènèl. Department of Environmental Conservation w/o encl. lrJ4,f "3' 2. '5( l-ootj- . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 1 20 MC 25.005 1b. Current Well Class 0 Exploratory II Development Oil 0 Multiple Zone I 0 Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 5. Bond: IBI Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 PBU 07-25A / 6. Proposed Depth: 12. Field / Pool(s): MD 10900 TVD 8957 Prudhoe Bay Field / Prudhoe Bay 7. Property Designation: Pool ADL 028309 o Drill II Redrill 1 a. 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): Suñace: 1751' SNL, 269' WEL, SEC. 33, T11 N, R14E, UM Top of Productive Horizon: 2653' SNL, 2644' WEL, SEC. 33, T11 N, R14E, UM Total Depth: 2013' SNL, 4020' WEL, SEC. 33, T11 N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Suñace: x- 675947 y- 5949168 Zone- ASP4 16. Deviated Wells: .eo:."" 9370 ftc, :~~mum Hate Angle gOO Hole Casina Weiaht Grade 3" 2-3/8" 4.6# L-80 8. Land Use Permit: 13. Approximate Spud Date: April 10, 2004 ,/ 14. Distance to Nearest Property: 29,813' 9. Acres in Property: 2560 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 57' feet 7-11A is 487' away at 10343' MD 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3250 psig Suñace: 2194 psig /' T :etting~lom ~aCKS) I MD TVD MD TVD ~aaedata) 9100' 8485' 10900' 8957' 44 sx Class 'G' ~ > ...... CouDlina Lenath STL 1800' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft):1 9855 9207 None I 9816 I 9172 Size . .... MD ~tr\Jr.t\Jr;::¡1 Conductor ~ .r. 79' 2527' 9006' 20" 13-3/8" 9-518" ProdlJctinn Liner 1140' 856' 7" 3-1/2" Liner Peñoration Depth MD (ft): 9517' - 9667' 20. Attachments IBI Filing Fee, $100 IBI BOP Sketch o Property Plat 0 Diverter Sketch Junk (measured): 9656 IVU 1956# Poleset 1800 sx Fondu, 400 sx PF 'C' 500 sx Class 'G', 50 Bbls PF 'C' TOD Job 79' 2527' 9006' 79' 2527' 8461' 350 sx Class 'G' 112 sx LARC 8207' - 9207' 8247' - 8993' 8715' - 9855' 8760' - 9616' IPeñoration Depth TVD (ft): 8905' - 9039' IBI Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report IBI Drilling Fluid Program IBI 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Mary Endacott Sianature / / '")7 }¡j ) /jiø1d /J (' lif I /1 . . . Permit To Drill IAPI Number: Number: ~;I- 05'2- 50- 029-20938-01-00 Conditions of Approval: Samples Required Hydrogen Sulfide Measures Othe, ~st BO~ ~(JO f>i, Annmv~ ct2t;/t1 Form 10-401\...R€'vised W003 Date: Contact Mary Endacott, 564-4388 Title CT Drilling Engineer Phone . / Prepared By Name/Number: Date "3j¡~ / t4 Terrie Hubble, 564-4628 I , . # . .. Permit Appr~vpl _ / / See cover letter for Date: 3/¿)5//J U other requirements Mud Log Réquired / D Yes ~No Directional Survey Required ~Yes D No 564-4388 'L ...... DYes J8'No J1!.Yes D No OR\G\r~AL BY ORDER OF ::2iS- / I / THE COMMISSION Date~' í {)Lf'" 'SubmitÆn Du¡:llicate . . BP 7-25A CTD Sidetrack Phase 1 Operations: Prep work · Integrity test annuli, wellhead seals & Xmas tree valves -r · Set a CIBP and whipstock Phase 2 Operations: Mill window, Drill and Complete sidetrack: Planned for April 10th, 2004. Mud Program: · Phase 1: Seawater/1 % KCI / Y2 Ib biozan · Phase 2: Mill with seawater / 'Y2lb biozan, drill with Solids Free Flo-Pro (8.5- 8.7 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. Casing Program: · 2%" 9,100' (-8485sstvd) to 10,90~{;8957sstvd) · The liner will be cemented wi~9 b1>ts with a planned TOC at top of liner and we plan to run a liner top packer due to the sm~r lap volume. Parent Well Casings OH size Burst (psi) Collapse (psi) 133/8" 72# L-80 BTC - Surface CSQ 5380 2670 9%" 47#, L-80, BTC - Intermediate csg 6870 4750 7" 29#, L-80, BTC - Production liner 8160 7020 Sidetrack Casing 23/8" 4.6#, L-80, STL - Prod LNR 3" 11200 11780 Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. /' · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 89 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · 7 -25A will be 487' away from well 7-11 A at 10,343' · 7-25A is -29,813' from the change of ownership boundary, (Prudhoe Bay Unit) Logging · MWD Gamma Ray will be run in the open hole section. · Memory CNL will be run inside the liner. Hazards · No evidence of significant H2S in the area. / · One fault will be cut by the wellpath. The risk of a lost circulation event is considered low. · Zone 3 Conglomerates, rapid bit wear Reservoir Pressure · Res. press. is estimated to be 3250 psi at 8800'ss (7.1 ppg emw). · Max. surface pressure with gas (0.12 psi/ft) to surface is 2194psi. ../ TREE'" GRAY GEN 3 3·1/2" LNR-CT, 9.3#, Plan: Plan #5 (01-251Pfan#5 07 -25A) Created By: Brij Potnis Date: 2/25/2004 BP Amoco WEf..LPATK DP'A(t.S Pitrll#& 074iA ............ -- ..... ...-.... ....... - ae t 2$ 4f13l1MZ 00t00 1f7..... ... -- ......... - - ~ - ."", ....... ....... .... .... - REFERENCE INFORMATION =r(~~=~ ~~~~=~ 57.00 C__, '" .. "'" VIiN TII<t'f!ri · 1.....1 , ian.1:i! , iM1.1t 4 ....... · ....... , "$.1.35 , 11....., · U52,.' · UU.21 .. 2....11 H U1Ui .. S2ii'1.31J 2350 2550 2750 2800 Section at 296.00' tEIW $!\1Ip\I TAf'«>eTDET"'Il$- NO <W..$ ANNOTATION$ TVO YO ~ .....1. 11. a'Me;i# ((OP ........ . ..,...32 ... a:aI&.'31 . _"7.$4 .- ....... 7 ~. II ~ " ......1* 10 ........, 11 1M.,.... Te 83' 83 84, ....' I: j851 1085 .... i8BI t g8BI 'i871 :e .87' :> .8800' i! ... 8850- . 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 bggm2003 Site: PB DS 07 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5948144.78 ft 677382.28 ft Latitude: 70 15 Longitude: 148 33 North Reference: Grid Convergence: 49.847 N 56.934 W True 1.35 deg Well: 07-25 Slot Name: 25 07-25 Well Position: +N/-S 1 056.48 ft Northing: 5949167.66 ft Latitude: 70 16 0.236 N +E/-W-1411.11 ft Easting : 675946.76 ft Longitude: 148 34 38.005 W Position Uncertainty: 0.00 ft +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 07-25 9300.00 ft Mean Sea Level 25.41 deg 80.85 deg Direction deg 296.00 Wellpath: Plan#507-25A 500292093801 Current Datum: 36 : 25 4/13/1983 00:00 Magnetic Data: 2/25/2004 Field Strength: 57589 nT Vertical Section: Depth From (fVD) ft 30.00 Height 57.00 ft Targets 07-25A Polygon5.1 0.00 -879.08 -2733.23 5948225.00 673235.00 70 1551.585N 148 35 57.549 W -Polygon 1 0.00 -879.08 -2733.23 5948225.00 673235.00 70 1551.585N 148 35 57.549 W -Polygon 2 0.00 -481.49 -3694.26 5948600.00 672265.00 70 15 55.491 N 148 36 25.523 W -Polygon 3 0.00 -223.97 -3798.28 5948855.00 672155.00 70 15 58.024 N 148 3628.554 W -Polygon 4 0.00 -352.36 -3441.15 5948735.00 672515.00 70 15 56.763 N 148 36 18.158 W -Polygon 5 0.00 -531.37 -2630.06 5948575.00 673330.00 70 15 55.005 N 148 35 54.550 W 07-25A Fault 1 0.00 -799.47 -2501.29 5948310.00 673465.00 70 15 52.369 N 148 35 50.800 W -Polygon 1 0.00 -799.47 -2501.29 5948310.00 673465.00 70 15 52.369 N 148 35 50.800 W -Polygon 2 0.00 -1047.46 -2377.04 5948065.00 673595.00 70 15 49.930 N 148 35 47.181 W 07-25A Fault 3 0.00 -227.38 -3438.23 5948860.00 672515.00 70 15 57.992 N 148 36 18.075 W -Polygon 1 0.00 -227.38 -3438.23 5948860.00 672515.00 70 15 57.992 N 148 36 18.075 W -Polygon 2 0.00 1052.47 -3413.31 5950140.00 672510.00 70 16 10.579 N 148 36 17.367 W 07-25A Fault 2 0.00 523.26 -4310.99 5949589.99 671625.00 70 16 5.370 N 148 3643.489 W -Polygon 1 0.00 523.26 -4310.99 5949589.99 671625.00 70 16 5.370 N 148 36 43.489 W -Polygon 2 0.00 -846.18 -3712.79 5948234.99 672255.00 70 1551.905N 148 36 26.057 W 07-25A T5.1 8942.00 -747.47 -2800.17 5948355.00 673165.00 70 15 52.879 N 148 35 59.499 W 07-25A T5.2 8948.00 -472.85 -3421.96 5948615.00 672537.00 70 15 55.578 N 148 36 17.598 W 07-25A T5.3 8958.00 -263.08 -3751.17 5948817.00 672203.00 70 15 57.639 N 148 3627.183 W . BP-GDB Baker Hughes INTEQ Planning Report . 9300.00 8658.19 TIP 9370.00 8719.18 KOP 9390.00 8736.48 3 9480.62 8799.32 4 9595.62 8858.31 5 9711.62 8917.34 6 9809.51 8942.01 7 9974.51 8943.05 8 10264.51 8946.43 9 10434.51 8948.13 10 10544.51 8949.61 11 10900.00 -57.00 TD Plan: Plan #5 Date Composed: 2125/2004 Identical to Lamar's Plan #5 Version: 3 Principal: Yes Tied-to: From: Definitive Path Plan Section Information 9300.00 29.60 280.50 8658.19 -894.85 -2439.14 0.00 0.00 0.00 0.00 9370.00 29.20 280.48 8719.18 -888.59 -2472.93 0.57 -0.57 -0.03 181.40 9390.00 31.00 280.48 8736.48 -886.77 -2482.79 9.00 9.00 0.00 0.00 9480.62 60.00 280.48 8799.32 -875.13 -2545.67 32.00 32.00 0.00 0.00 9595.62 60.63 323.08 8858.32 -824.25 -2627.57 32.00 0.55 37.05 100.00 9711.62 60.57 280.23 8917.34 -773.07 -2710.57 32.00 -0.06 -36.95 259.00 9809.51 90.00 291.45 8942.01 -746.95 -2800.31 32.00 30.07 11.47 22.00 9974.51 89.29 311.24 8943.05 -661.54 -2940.52 12.00 -0.43 11.99 92.10 10264.51 89.42 276.44 8946.43 -546.12 -3201.70 12.00 0.04 -12.00 270.00 10434.51 89.45 296.84 8948.13 -497.69 -3363.71 12.00 0.02 12.00 90.00 10544.51 89.01 283.65 8949.61 -459.72 -3466.68 12.00 -0.40 -11.99 268.00 10900.00 88.59 326.31 8957.40 -260.65 -3751.20 12.00 -0.12 12.00 91.00 Survey 9300.00 29.60 280.50 8658.19 -894.85 -2439.14 5948216.11 673529.36 1800.01 0.00 0.00 TIP 9325.00 29.46 280.49 8679.95 -892.60 -2451.25 5948218.07 673517.19 1811.88 0.57 181.40 MWD 9350.00 29.31 280.49 8701.73 -890.37 -2463.32 5948220.02 673505.08 1823.70 0.57 181.40 MWD 9370.00 29.20 280.48 8719.18 -888.59 -2472.93 5948221.57 673495.43 1833.12 0.57 181.41 KOP 9375.00 29.65 280.48 8723.53 -888.14 -2475.34 5948221.97 673493.01 1835.49 9.00 360.00 MWD 9390.00 31.00 280.48 8736.48 -886.77 -2482.79 5948223.17 673485.53 1842.79 9.00 0.00 3 9400.00 34.20 280.48 8744.90 -885.79 -2488.09 5948224.02 673480.21 1847.98 32.00 0.00 MWD 9425.00 42.20 280.48 8764.53 -882.98 -2503.28 5948226.48 673464.96 1862.86 32.00 360.00 MWD 9450.00 50.20 280.48 8781.82 -879.70 -2521.01 5948229.34 673447.16 1880.23 32.00 0.00 MWD 9475.00 58.20 280.48 8796.44 -876.01 -2540.93 5948232.56 673427.16 1899.75 32.00 360.00 MWD 9480.62 60.00 280.48 8799.32 -875.13 -2545.67 5948233.33 673422.40 1904.40 32.00 0.00 4 9500.00 59.11 287.60 8809.15 -871.09 -2561.86 5948236.99 673406.12 1920.73 32.00 100.00 MWD 9525.00 58.56 296.93 8822.11 -863.00 -2581.63 5948244.61 673386.17 1942.04 32.00 96.39 MWD 9550.00 58.68 306.30 8835.15 -851.83 -2599.77 5948255.35 673367.77 1963.24 32.00 91.55 MWD 9575.00 59.48 315.58 8848.01 -837.80 -2615.94 5948269.01 673351.28 1983.93 32.00 86.67 MWD 9595.62 60.63 323.08 8858.32 -824.25 -2627.57 5948282.28 673339.34 2000.32 32.00 81.89 5 9600.00 60.37 321.50 8860.47 -821.24 -2629.90 5948285.23 673336.94 2003.73 32.00 259.00 MWD 9625.00 59.27 312.33 8873.06 -805.47 -2644.63 5948300.65 673321.85 2023.88 32.00 259.78 MWD 9650.00 58.82 303.02 8885.94 -792.39 -2661.57 5948313.33 673304.61 2044.84 32.00 264.40 MWD 9675.00 59.04 293.68 8898.86 -782.24 -2680.38 5948323.04 673285.56 2066.20 32.00 269.20 MWD 9700.00 59.93 284.45 8911.57 -775.22 -2700.71 5948329.58 673265.08 2087.55 32.00 274.02 MWD 9711.62 60.57 280.23 8917.34 -773.07 -2710.57 5948331.50 673255.18 2097.35 32.00 278.72 6 . BP-GDB Baker Hughes INTEQ Planning Report . 9725.00 64.55 282.00 8923.51 -770.78 -2722.21 5948333.52 673243.48 2108.82 32.00 22.00 MWD 9750.00 72.04 285.03 8932.75 -765.34 -2744.77 5948338.43 673220.80 2131.48 32.00 21.18 MWD 9775.00 79.57 287.81 8938.88 -758.49 -2768.00 5948344.74 673197.42 2155.36 32.00 20.06 MWD 9800.00 87.12 290.46 8941.77 -750.35 -2791.44 5948352.33 673173.80 2180.00 32.00 19.37 MWD 9809.51 90.00 291 .45 8942.01 -746.95 -2800.31 5948355.52 673164.85 2189.47 32.00 19.07 7 9825.00 89.93 293.31 8942.02 -741.05 -2814.64 5948361.08 673150.39 2204.92 12.00 92.10 MWD 9850.00 89.82 296.31 8942.08 -730.56 -2837.33 5948371.04 673127.47 2229.91 12.00 92.10 MWD 9875.00 89.71 299.31 8942.18 -718.90 -2859.43 5948382.18 673105.09 2254.90 12.00 92.09 MWD 9900.00 89.60 302.31 8942.33 -706.10 -2880.90 5948394.47 673083.33 2279.81 12.00 92.08 MWD 9925.00 89.50 305.30 8942.52 -692.19 -2901.67 5948407.89 673062.24 2304.57 12.00 92.06 MWD 9950.00 89.39 308.30 8942.77 -677.21 -2921.69 5948422.39 673041.89 2329.13 12.00 92.04 MWD 9974.51 89.29 311.24 8943.05 -661.54 -2940.52 5948437.62 673022.69 2352.93 12.00 92.01 8 9975.00 89.29 311.18 8943.05 -661.21 -2940.89 5948437.94 673022.31 2353.40 11.98 270.00 MWD 10000.00 89.29 308.18 8943.36 -645.25 -2960.13 5948453.44 673002.71 2377.69 12.00 270.00 MWD 10025.00 89.29 305.18 8943.67 -630.32 -2980.17 5948467.90 672982.33 2402.25 12.00 270.04 MWD 10050.00 89.30 302.18 8943.98 -616.46 -3000.97 5948481.27 672961.21 2427.02 12.00 270.08 MWD 10075.00 89.30 299.18 8944.29 -603.70 -3022.47 5948493.52 672939.42 2451.93 12.00 270.11 MWD 10100.00 89.31 296.18 8944.59 -592.09 -3044.60 5948504.61 672917.02 2476.91 12.00 270.15 MWD 10125.00 89.32 293.18 8944.88 -581.65 -3067.31 5948514.52 672894.08 2501.90 12.00 270.18 MWD 10150.00 89.34 290.18 8945.18 -572.42 -3090.54 5948523.21 672870.64 2526.83 12.00 270.22 MWD 10175.00 89.35 287.18 8945.46 -564 .41 -3114.22 5948530.66 672846.78 2551.62 12.00 270.26 MWD 10200.00 89.37 284.18 8945.74 -557.65 -3138.28 5948536.85 672822.57 2576.21 12.00 270.29 MWD 10225.00 89.38 281.18 8946.02 -552.17 -3162.67 5948541 .76 672798.06 2600.53 12.00 270.32 MWD 10250.00 89.40 278.18 8946.28 -547.96 -3187.31 5948545.39 672773.33 2624.52 12.00 270.36 MWD 10264.51 89.42 276.44 8946.43 -546.12 -3201.70 5948546.90 672758.90 2638.27 12.00 270.39 9 10275.00 89.42 277.70 8946.54 -544.83 -3212.11 5948547.95 672748.47 2648.19 12.00 90.00 MWD 10300.00 89.42 280.70 8946.79 -540.83 -3236.78 5948551.36 672723.71 2672.12 12.00 89.99 MWD 10325.00 89.42 283.70 8947.04 -535.55 -3261.22 5948556.07 672699.16 2696.39 12.00 89.96 MWD 10350.00 89.43 286.70 8947.30 -528.99 -3285.34 5948562.06 672674.90 2720.95 12.00 89.93 MWD 10375.00 89.43 289.70 8947.55 -521.19 -3309.08 5948569.31 672650.98 2745.71 12.00 89.90 MWD 10400.00 89.44 292.70 8947.79 -512.15 -3332.39 5948577.80 672627.47 2770.62 12.00 89.87 MWD 10425.00 89.45 295.70 8948.04 -501.90 -3355.19 5948587.51 672604.44 2795.60 12.00 89.84 MWD 10434.51 89.45 296.84 8948.13 -497.69 -3363.71 5948591.52 672595.81 2805.11 12.00 89.81 10 10450.00 89.39 294.98 8948.28 -490.92 -3377.64 5948597.96 672581.73 2820.60 12.00 268.00 MWD 10475.00 89.29 291.99 8948.57 -480.96 -3400.57 5948607.38 672558.58 2845.57 12.00 268.02 MWD 10500.00 89.18 288.99 8948.91 -472.22 -3423.98 5948615.58 672534.97 2870.45 12.00 268.05 MWD 10525.00 89.09 285.99 8949.28 -464.70 -3447.82 5948622.53 672510.96 2895.17 12.00 268.09 MWD 10544.51 89.01 283.65 8949.61 -459.72 -3466.68 5948627.08 672492.00 2914.31 12.00 268.14 11 10550.00 89.00 284.31 8949.70 -458.39 -3472.01 5948628.28 672486.64 2919.67 12.00 91.00 MWD 10575.00 88.95 287.31 8950.15 -451.58 -3496.05 5948634.52 672462.44 2944.27 12.00 90.99 MWD 10600.00 88.90 290.31 8950.62 -443.53 -3519.71 5948642.02 672438.60 2969.07 12.00 90.93 MWD 10625.00 88.86 293.31 8951.11 -434.24 -3542.92 5948650.76 672415.19 2993.99 12.00 90.88 MWD 10650.00 88.82 296.31 8951.62 -423.76 -3565.60 5948660.71 672392.27 3018.98 12.00 90.82 MWD 10675.00 88.78 299.31 8952.14 -412.10 -3587.71 5948671.85 672369.90 3043.96 12.00 90.76 MWD 10700.00 88.74 302.31 8952.68 -399.30 -3609.17 5948684.15 672348.14 3068.86 12.00 90.70 MWD 10725.00 88.71 305.31 8953.24 -385.39 -3629.94 5948697.56 672327.06 3093.62 12.00 90.63 MWD 10750.00 88.68 308.31 8953.81 -370.42 -3649.95 5948712.06 672306.70 3118.17 12.00 90.56 MWD 10775.00 88.66 311.31 8954.39 -354.42 -3669.14 5948727.61 672287.14 3142.44 12.00 90.50 MWD 10800.00 88.64 314.31 8954.98 -337.44 -3687.48 5948744.16 672268.42 3166.36 12.00 90.43 MWD 10825.00 88.62 317.31 8955.58 -319.52 -3704.90 5948761.66 672250.58 3189.87 12.00 90.36 MWD 10850.00 88.61 320.31 8956.18 -300.71 -3721.35 5948780.08 672233.69 3212.91 12.00 90.28 MWD 10875.00 /88.60 323.31 8956.79 -281.07 -3736.80 5948799.35 672217.79 3235.40 12.00 90.21 MWD 10900.00 88.59 326.31 8957.40 -260.65 -3751.20 5948819.43 672202.92 3257.30 12.00 90.14 TO Nordic 1 slim hole All Measurements are from top of Riser 3/18/2004 ),..., CD 00 .- e: bttm of bag BAG 7 1/16" 5000psi top of bag middle of slips Blind/Shears .......................... middle of pipes TOTs ....................·····7 1/16" 5000psi middle of flow cross Mud Cross Mud Cross 71/16" 5000psi middle of blind/shears ......................... middle of pipe/slips TOTs ....................·····7 1/16" 5000psi . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELLNAME/ßà 07-ZS/! PTD# 2oC¡ -OS 2- Y Development Service Exploration Stratigraphic CHECK WBA T ADD-ONS ~'CLUEn APPLIES (OPTIONS) MULTI The permit is for a new weJlbore segment of LATERAL existing well . Permit No, API No. . (If API num ber Production sbould continue to be reported as last two (2) digits a function 'oftbe original API number. stated are between 6.0-69) above. Pll.OT HOLE In accordance witb 2.0 AAC 25..0.05(1), all (PH) records, data and logs acquired for tbe pilot hole must be clearly differentiated in both name (name on permit plus PH) and API Dum ber (5.0 - 7.0/8.0) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject ·to fuD EXCEPTION compliance with 2.0 AAC 25..055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing ex ception. (Companv Name) assumes the liability of any protest to the spacing exception tbat may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 3.0' sample inten'als from below tbe permafrost or from where samples are first caught and 10' sample intervals through target zones. p 055259 DATE 3/2/2004 CHECK NO. 055259 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 3/2/2004 PR022604A PERMIT TO DRILL PPLlCATIONS 07·7-S/t H POUCH TO TERRI UBBLE MB7-5 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ . BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK9951~-6612 NATIONAL CITY BANK Ashland. Ohio 56·389 4'i2 No. p 055259 CONSOLIDATED COMMERCIAL ACCOUNT PAY: ., BP r;' '¡,... (lIhl . . ~ .:1..11. ,",,1 . . TO THE ORDER OF: STATE OF ALASKA AOGCC 333 WEST 7TH AVENUE SUITE 100 . ANCHORAGE AK 99501 DATE AMOUNT 31212004, . .I~I. ,~t"'$;eOOO""'~ ';1!,"f8;\.,:~t~t(;;1 ~.·...,)t1:~i~;i;;;:~;:;:~;:;:;ill1~ 1110 5 5 2 5 '1111 I: 0... ¡. 20 :I B '1 5 I: 0 ¡. 2 7 B '1 bill . . D D Well bore seg Annular Disposal -- Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 07-25A _Program DEV PLORATION (ALASKA) INC Initial ClasslType DEV j 1-~ GeoArea 890 Unit j1~ On/Off Shore On Administration Permit fee attaçhe~. - - - - - - - - - - - - - - · Y.es. - - - - - - - - - - - 2 Lease .numberapprOPJiat.e. - - - - - - - - - - - - - - .. . . . . . . Yes. 3 .U.nique well.n.ame.anq lJu.mb.er . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . . . _ . . . . . _ _ Y.es _ _ - - - - - - - - - - - - - - - - - - ~ 4 WellJocat.ed in a d.efine.d .pool. - - - - - - - - - - - - - - - . . . . . . . . Y.es. - - - - - - - - - - - - 5 WellJoC<lt.ed proper .distance from qriJling unitbound.ary. . . - - - - - - · Yes __ 6 WellJoC<lted proper .distance. from otber wells. . . . Y.es. - - - - - - - - ,7 .SJJtfiçient ;acreag.e .ayail;able in dJilIilJg unit. - - - - - - - - - - - - · Y.es 8 Jf.deviated, is weJlbore platincJuded . . . . . - - - - - - - - - - - - - · Yes - - - - 9 Operator onlY' affected party. - - - - - - - - - - · Y.es 10 .Oper.ator bas.apprj)priate.bond inJorce . . . _ _ . . . . . . . _ . . . . . . . . . . Y.es. . - - - - - - . - - - - - - - - - - - - 111 Permit can be issued witbout co.nserva.tion order. . . . · Yes . - - - - - - - - Appr Date 12 Permit c.an Þe issued witbout ad.ministratilteapprovaJ . . . . . . . Y.es. - - - - - - - - RPC 3/22/2004 13 Can permit be approved before 15-day wait Yes 14 WellJocated within area and.strata .authorized by.lnjectiolJ Order # (puUO# in commelJts) (For. Yes. - - - - - - 15 AJI wells.wit!1i.n.1l4.mile.area.of reyiew id.elJtified (For servic.e.well onlY'L . . . . _ . . . . . . . . . Y.es. . - - - - - - - - - - - - - -. - - - - 16 Pre-produced injector: ~ur;ation.of pre-pro~uctiOI) less than 3 montbs. (For.service well only) . Y.es. - - - - - - 17 ACMP. Finding of Con.si.stency h.as bee.n .issued. for tbis pr.ojeçt · Yes - - - - Engineering 18 C.onqu~tor string provided . . - - - - - - - - - - - - - .NA. - - - - - - - - - - - - 19 .S.urface casing protects. alLknown USDWs . .NA - - - - - - - - - - - - - - 20 .CMT vol adequ.ate. to çirculateon .cond.uctor 8< su.rf. C$g -. · NA. - - - - - - - - - - - - - 21 CMT vol adequate.to tie-in Jongstring to.surf csg. . NA __ - - - - - - - - - - - - - - 22 CMTwill coyer.aJl klJownpro.ductiye bori;!:ons. . . . Y.es. - - - - - - - - 23 .C.asing designs adeQua.te for C, T, B.& permafrost . . . . . . · Y.es. 24 .A~equ;atetan.kage.or re.serye pit. . . . . . . . . . . . . · . . Y.es. CTDU. - - - - - - - 25 Jf.are-~rilt hasa. 10c4.03 for ;abandonment be.en approved. No * - - - - - - -- 26 Agequate .wellbore. separatio.n .propo!!ed. . . . . . . . . . . . . . . . . _ . . . . . · . _ y~s. . . - - - - - - - - - - - - - - - - - - 27 Jf.divßr:ter required, doe$ jt meßt reguJations. . . - - - - - - - .NA. Sidetrack. . Appr Date 28 DrillilJg fluid Rrogram schematic.& eq,uip Jistadequat.e . . . . · Y.es Max MW 8Jppg, . . . . . . . . WGA 3/23/2004 29 .BOPEs,do.they meßtreguJation . . . . . . . . . . . . . · . . Y.es . - - - - - - 30 BOPE.pre.ss rating appropriate; test to(pu.t psig Lncomments). · Y.es Test to 3500 psi. .MSF' 2194 psi 31 .C.hokemanjfold compJies. w/APIRF'-53 (May 84). - - - - - - - · Yes. 32 Work will occur without.operatjon .sbutdo.wn - - - - - - - · Yes. 33 J$. pre$.ence of H2S gas probablß. . . - - - - - - - - - - No 34 Meçba.nicç¡lcoodit[on otwells within AOß yerified (for.s.ervice w~1J only). . · NA. ---- Geology 135 P.ermit. can Þe issued w/o. hydrogen sulfide meaSJJ(e$. . No 36 .D.ata.presented on. pote.ntial ove.rpres.sure .ZOne$. . . . - - - - - - __ .NA Appr Date 37 S.ei.smic.analysjs of $baJlow gas.zolJes. . .NA RPC 3/22/2004 138 - - - - - S~ªbe9 .conditioo sUl"\ley(if oft'-!!h.o{e) . . . . . . . . . . . . . . . . . . NA 39 . Conta.ct nam.elp!1oneJorweßkly progress.reports [explorç¡toryonly). . .. NA - - Geologic Date: Engineering Date Public Date Commissioner Commissioner: Commissioner ()\\S 3\<.J11- 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 information, information of this lature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. e e Sperry-Sun Drilling Services LIS Scan Utility ft I ). $- I 1- $Revision: 3 $ LisLib $Revision: 4 $ Tue Jun 08 15:53:39 2004 Reel Header ~./ C L(... () f ;J- Service name...... .......LISTPE ~ Date.... .................04/06/08 Origin.................. .STS Reel Name................UNKNOWN Continuation Number......Ol Previous Reel Name.......UNKNOWN Comments........ .........STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date...... ..... ..........04/06/08 Origin...................STS Tape Name................UNKNOWN Continuation Number......Ol 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 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION 1FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 7-25A 500292093801 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 08-JUN-04 MWD RUN 1 MWD RUN 2 MWD RUN 3 MWOOO3017317 MWOO03017317 MWOOO3017317 S. LATZ S. LATZ S. LATZ WHITLOW/EGBE WHITLOW/EGBE WHITLOW/EGBE MWD RUN 4 MWD RUN 5 MWD RUN 6 MWOO03017317 MWOO03017317 MWOO03017317 S. LATZ S. LATZ S. LATZ WHITLOW/EGBE WHITLOW/EGBE KOLSTAD/EGBE MWD RUN 7 MWD RUN 8 MW0003017 31 7 MWOO03017317 S. LATZ S. LATZ KOLSTAD/EGBE KOLSTAD/EGBE 33 UN 14E 1751 269 MSL 0) 57.00 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: e e 3.000 3.500 9380.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 9376' MD AND THE BOTTOM WAS AT 9384' MD. 4. MWD RUNS 1 - 8 COMPRISED DIRECTIONAL WITH NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A CASED-HOLE GAMMA RAY PROVIDED TO SSDS BY K. COONEY (SIS/BP) ON 6/4/04. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1 - 8 REPRESENT WELL 7-25A WITH API#: 50-029-20938-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10952'MD/8956'TVDSS. SROP SGRD $ SMOOTHED RATE OF PENETRATION WHILE DRILLING. SMOOTHED NATURAL GAMMA RAY. File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/06/08 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 9040.5 9380.0 STOP DEPTH 10926.0 10949.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9040.5 9041.5 9044.5 9049.0 9056.0 9082.0 9369.5 9376.0 9380.5 9392.5 9402.0 9494.0 9521. 5 9609.5 GR 9035.5 9036.5 9041. 0 9047.0 9054.0 9080.5 9367.5 9375.5 9380.5 9394.5 9402.0 9492.5 9521.0 9610.0 e e 9641. 0 9667.0 9731. 0 9739.5 9759.5 9815.0 9819.0 9827.5 9844.0 9849.5 9855.5 9868.0 9871. 5 9931. 0 9944.5 9990.0 10047.0 10087.5 10092.5 10095.5 10099.5 10118.5 10160.5 10231. 0 10414.5 10468.5 10489.0 10492.5 10495.0 10500.5 10505.0 10510.0 10537.0 10556.0 10572.5 10624.5 10677.5 10732.5 10759.5 10818.5 10823.5 10827.5 10836.0 10860.0 10882.5 10898.5 10949.5 $ 9641. 5 9665.5 9730.5 9738.5 9758.0 9814.0 9817.0 9826.0 9842.5 9848.0 9855.5 9862.0 9867.5 9930.0 9944.5 9989.0 10046.5 10085.5 10092.0 10095.0 10099.5 10118.0 10160.0 10234.0 10415.5 10466.5 10488.5 10490.0 10491. 5 10497.5 10500.5 10506.5 10537.5 10555.0 10574.5 10624.5 10677.5 10731.5 10759.0 10820.0 10824.0 10827.5 10836.0 10859.5 10883.0 10900.5 10951.5 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD MWD $ BIT RUN NO 1 2 3 4 5 6 7 8 MERGE TOP 9035.5 9386.0 9394.0 9681.0 9714.0 9880.0 10215.0 10333.0 MERGE BASE 9386.0 9394.0 9681.0 9714.0 9880.0 10215.0 10333.0 10951. 5 # REMARKS: MERGED MAIN PASS. $ # Data Format Sp€cification R€cord Data Record Typ€.................. 0 Data Specification Block Typ€.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per r€cord.............Undefin€d Absent value...................... -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O e e Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD MWD Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9040.5 10949.5 9995 3819 9040.5 10949.5 ROP MWD FT/H 0.03 1650.33 86.8491 3140 9380 10949.5 GR MWD API 1. 76 855.28 35.5248 3249 9040.5 10926 First Reading For Entire Fi1e..........9040.5 Last Reading For Entire File...........10949.5 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/06/08 Maximum Physical Record..65535 Fi 1 e 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.......04/06/08 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 9035.5 9380.0 STOP DEPTH 9358.0 9386.0 # 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: ll-APR-04 Insite Memory 9386.0 9380.0 9386.0 .0 .0 # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray TOOL NUMBER TLG015 # BOREHOLE AND CASING DATA e e OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 2.740 9380.0 # 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: Biozan Water 8.30 .0 .0 o .0 .000 .000 .000 .000 .0 146.0 .0 .0 # 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 Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD010 MWD010 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9035.5 9386 9210.75 702 9035.5 9386 ROP MWD010 FT/H 0.03 1. 07 0.689231 13 9380 9386 GR MWD010 API 19.23 296.45 66.397 124 9035.5 9358 First Reading For Entire File..........9035.5 Last Reading For Entire File...........9386 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number... ....... .1. O. 0 Date of Generation.......04/06/08 Maximum Physical Record..65535 Fi 1 e 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.... ...04/06/08 Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ e Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD 2 .5000 START DEPTH 9358.5 9386.5 STOP DEPTH 9366.0 9394.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO 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 PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH 1FT): # 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.................. 0 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. . . . .. . . . . . . . . . . . . . . . . . e 12-APR-04 Insite Memory 9394.0 9386.0 9394.0 .0 .0 TOOL NUMBER TLG015 2.740 9380.0 Flo Pro 8.60 65.0 9.3 28000 7.6 .000 .000 .000 .000 .0 145.9 .0 .0 e e 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9358.5 9394 9376.25 72 9358.5 9394 ROP MWD020 FT/H 0.01 4.66 2.19031 16 9386.5 9394 GR MWD020 API 18.97 23.24 21. 355 16 9358.5 9366 First Reading For Entire File..........9358.5 Last Reading For Entire Fi1e...........9394 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..04/06/08 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.......04/06/08 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 ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 9366.5 9394.5 STOP DEPTH 9657.0 9681.0 # 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: 12-APR-04 Insite Memory 9681.0 9394.0 9681.0 29.6 64.1 # TOOL STRING (TOP TO VENDOR TOOL CODE PCG " BOTTOM) TOOL TYPE Natural gamma ray TOOL NUMBER TLG015 e e BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.000 9380.0 # 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: Flo Pro 8.70 65.0 8.9 30000 6.6 .000 .000 .000 .000 .0 150.0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 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 ./\bsent value...................... -999 Depth Units......... . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD030 GR MWD030 Units FT FT/H API Size 4 4 4 Nsam Rep Code 1 68 1 68 1 68 Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9366.5 9681 9523.75 630 9366.5 9681 ROP MWD030 FT/H 3.44 220.68 53.3569 574 9394.5 9681 GR MWD030 API 18.65 855.28 43.3083 582 9366.5 9657 First Reading For Entire File..........9366.5 Last Reading For Entire File...........9681 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/06/08 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.005 Physical EOF File Header Service name... ....... ...STSLIB.005 Service Sub Level Name... Version Number.. . . . . . . . . .1. 0.0 e Date of Generation.......04/06/08 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 ROP $ 5 e header data for each bit run in separate files. 4 .5000 START DEPTH 9657.5 9681.5 STOP DEPTH 9690.0 9714.0 # 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 PCG $ BOTTOM) TOOL TYPE Natural gamma ray # 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. ....0 Logging Direction............ .....Down Optical log depth units....... ....Feet Data Reference Point. .......... ...Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 13-APR-04 Insite Memory 9714.0 9681.0 9714.0 61.0 61. 0 TOOL NUMBER TLG013 3.000 9380.0 Flo Pro 8.70 65.0 8.9 30000 6.6 .000 .000 .000 .000 .0 150.1 .0 .0 e e Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD040 GR MWD040 Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9657.5 9714 9685.75 114 9657.5 9714 ROP MWD040 FT/H 0.32 81. 9 28.5308 66 9681. 5 9714 GR MWD040 API 20.69 43.42 26.0698 66 9657.5 9690 First Reading For Entire File..........9657.5 Last Reading For Entire File...........9714 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number. . . . . . . . . . .1.0.0 Date of Generation.......04/06/08 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...........l.0.0 Date of Generation.......04/06/08 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 6 header data for each bit run in separate files. 5 .5000 START DEPTH 9690.5 9714.5 STOP DEPTH 9856.0 9880.0 # 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: 13-APR-04 Insite Memory 9880.0 9714.0 9880.0 64.4 87.9 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray " TOOL NUMBER TLG013 e e # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.000 9380.0 # 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: Flo Pro 8.70 65.0 8.9 30000 6.6 .000 .000 .000 .000 .0 154.0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.. ................0 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 Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD050 MWD050 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9690.5 9880 9785.25 380 9690.5 9880 ROP MWD050 FT/H 1.32 14 9.67 71. 8351 332 9714.5 9880 GR MWD050 API 19.12 151. 69 38.5653 332 9690.5 9856 First Reading For Entire File..........9690.5 Last Reading For Entire File...........9880 File Trailer Service name.............STSLIB.006 Service Sub Level Name... Version Number.......... .1. O. 0 Date of Generation.......04/06/08 Maximum Physical Record..65535 File Type................ LO Next File Name....... ....STSLIB.007 Physical EOF File Header Service name.............STSLIB.007 Service Sub Level Name... e Version Number.......... .1. O. 0 Date of Generation.......04/06/08 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 7 header data for each bit run 6 .5000 START DEPTH 9856.5 9880.5 STOP DEPTH 10191.0 10215.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO 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 PCG $ BOTTOM) TOOL TYPE Natural gamma ray # 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.... ...... ........0 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 e in separate files. 14-APR-04 Insite Memory 10215.0 9880.0 10215.0 85.6 90.5 TOOL NUMBER TLG013 3.000 9380.0 Flo Pro 8.70 65.0 9.5 25000 9.6 .000 .000 .000 .000 .0 154.0 .0 .0 e e Absent value...................... -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name DEPT ROP GR Code Offset o 4 8 Channel 1 2 3 Service Orde.r Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 MWD060 MWD060 First. Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9856.5 10215 10035.8 718 9856.5 10215 ROP MWD060 FT/H 4.31 265.91 96.4789 670 9880.5 10215 GR MWD060 API 20.33 68.56 31.0212 670 9856.5 10191 First Reading For Entire Fi1e..........9856.5 Last Reading For Entire File...........10215 File Trailer Service name.............STSLIB.007 Service Sub Level Name... Version Number. . . . . . . . . . .1.0.0 Date of Generation...... .04/06/08 Maximum Physical Record..65535 Fil e Type................ LO Next File Name...........STSLIB.008 Physical EOF File Header Service name............. STSLIB. 008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/06/08 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 8 header data for each bit run in separate files. 7 .5000 START DEPTH 10191.5 10215.5 STOP DEPTH 10309.0 10333.0 # 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: 14-APR-04 Insite Memory 10333.0 10215.0 10333.0 91. 9 94.8 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray TOOL NUMBER TLG013 e e $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.000 9380.0 # 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: Flo Pro 8.70 65.0 9.2 25000 6.8 .000 .000 .000 .000 .0 162.8 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.......... ........0 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 DEPT ROP MWD070 GR MWD070 Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10191.5 10333 10262.3 284 10191. 5 10333 ROP MWD070 FT/H 4.98 480.91 80.0043 236 10215.5 10333 GR MWD070 API 23.61 43.42 31. 0165 236 10191. 5 10309 First Reading For Entire File..........10191.5 Last Reading For Entire File...........10333 File Trailer Service name.............STSLIB.008 Service Sub Level Name... Version Number.......... .1. O. 0 Date of Generation.......04/06/08 Maximum Physical Record..65535 File Type.............. ..LO Next File Name...........STSLIB.009 Physical EOF File Header Service name..... ........STSLIB.009 e Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/06/08 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.008 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 9 e header data for each bit run in separate files. 8 .5000 START DEPTH 10309.5 10333.5 STOP DEPTH 10928.0 10951. 5 # 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 PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER r S CASING DE PTH (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.................. 0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN 15-APR-04 Insite Memory 10952.0 10333.0 10952.0 81. 7 92.3 TOOL NUMBER TLG015 3.000 9380.0 Flo Pro 8.70 65.0 9.3 23000 6.2 .000 .000 .000 .000 .0 167.0 .0 .0 e e Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name DEPT ROP GR Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Rep 68 68 68 Code Offset o 4 8 Channel 1 2 3 MWD080 MWD080 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10309.5 10951. 5 10630.5 1285 10309.5 10951. 5 ROP MWD080 FT/H 3.36 1650.33 107.225 1237 10333.5 10951. 5 GR MWD080 API 1. 76 109.89 32.3425 1238 10309.5 10928 First Reading For Entire File..........10309.5 Last Reading For Entire Fi1e...........10951.5 File Trailer Service name.............STSLIB.009 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/06/08 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.OIO Physical EOF Tape Trailer Service name.... .........1ISTPE Date.....................04/06/08 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.................... .04/06/08 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
